TransAtlantic Petroleum (TAT) 10-Q 9 Aug 17 2017 Q2 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2017	Aug. 07, 2017
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2017
Document Fiscal Year Focus	2,017
Document Fiscal Period Focus	Q2
Trading Symbol	TAT
Entity Registrant Name	TRANSATLANTIC PETROLEUM LTD.
Entity Central Index Key	1,092,289
Current Fiscal Year End Date	--12-31
Entity Filer Category	Smaller Reporting Company
Entity Common Stock, Shares Outstanding		47,705,336

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($)	Jun. 30, 2017	Dec. 31, 2016
Current assets:
Cash and cash equivalents	$ 12,253,000	$ 10,034,000
Restricted cash	5,219,000	2,555,000
Accounts receivable, net
Oil and natural gas sales	10,935,000	17,885,000
Joint interest and other	2,388,000	3,230,000
Related party	790,000	762,000
Prepaid and other current assets	3,158,000	4,756,000
Derivative asset	794,000
Inventory	3,659,000	3,647,000
Assets held for sale		25,217,000
Total current assets	39,196,000	68,086,000
Oil and natural gas properties (successful efforts method)
Proved	200,686,000	197,214,000
Unproved	30,033,000	21,109,000
Equipment and other property	19,264,000	20,273,000
Property and equipment, gross	249,983,000	238,596,000
Less accumulated depreciation, depletion and amortization	(130,231,000)	(120,638,000)
Property and equipment, net	119,752,000	117,958,000
Other long-term assets:
Other assets	2,671,000	2,725,000
Note receivable - related party	7,185,000	7,624,000
Total other assets	9,856,000	10,349,000
Total assets	168,804,000	196,393,000
Current liabilities:
Accounts payable	4,878,000	7,036,000
Accounts payable - related party	2,138,000	1,844,000
Accrued liabilities	8,359,000	12,492,000
Derivative liability		596,000
Loans payable	25,950,000	34,750,000
Loan payable - related party	525,000	3,444,000
Liabilities held for sale		15,938,000
Total current liabilities	41,850,000	76,100,000
Long-term liabilities:
Asset retirement obligations	4,937,000	4,833,000
Accrued liabilities	8,860,000	8,126,000
Deferred income taxes	20,725,000	18,806,000
Loans payable		3,750,000
Derivative liability		242,000
Total long-term liabilities	34,522,000	35,757,000
Total liabilities	76,372,000	111,857,000
Commitments and contingencies
Shareholders' equity:
Common shares, $0.10 par value, 200,000,000 shares authorized; 47,705,336 shares and 47,220,525 shares issued and outstanding as of June 30, 2017 and December 31, 2016, respectively	4,771,000	4,722,000
Treasury stock	(970,000)	(970,000)
Additional paid-in-capital	573,557,000	573,278,000
Accumulated other comprehensive loss	(117,265,000)	(140,316,000)
Accumulated deficit	(413,711,000)	(398,228,000)
Total shareholders' equity	46,382,000	38,486,000
Total liabilities, Series A preferred shares and shareholders' equity	168,804,000	196,393,000
Series A Preferred Shares [Member]
Long-term liabilities:
Preferred shares, value	21,300,000	21,300,000
Related Party [Member] | Series A Preferred Shares [Member]
Long-term liabilities:
Preferred shares, value	$ 24,750,000	$ 24,750,000

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - $ / shares	Jun. 30, 2017	Dec. 31, 2016
Common shares, par value	$ 0.10	$ 0.10
Common shares, authorized	200,000,000	200,000,000
Common shares, issued	47,705,336	47,220,525
Common shares, outstanding	47,705,336	47,220,525
Series A Preferred Shares [Member]
Preferred shares, par value	$ 0.01	$ 0.01
Preferred shares, authorized	950,000	950,000
Preferred shares, issued	426,000	426,000
Preferred shares, outstanding	426,000	426,000
Preferred shares, liquidation preference per share	$ 50	$ 50
Related Party [Member] | Series A Preferred Shares [Member]
Preferred shares, par value	$ 0.01	$ 0.01
Preferred shares, issued	495,000	495,000
Preferred shares, outstanding	495,000	495,000
Preferred shares, liquidation preference per share	$ 50	$ 50

Consolidated Statements of Comp

Consolidated Statements of Comprehensive Income (Loss) (Unaudited) - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Revenues:
Oil and natural gas sales	$ 12,283	$ 16,162	$ 28,051	$ 30,688
Sales of purchased natural gas		1,520	654	2,546
Other	58	16	72	30
Total revenues	12,341	17,698	28,777	33,264
Costs and expenses:
Production	2,714	3,069	5,801	5,955
Exploration, abandonment and impairment	2	128	108	1,433
Cost of purchased natural gas		1,341	568	2,237
Seismic and other exploration	65	15	80	81
General and administrative	3,181	3,899	6,771	8,742
Depreciation, depletion and amortization	4,255	7,807	8,752	15,773
Accretion of asset retirement obligations	47	96	95	188
Total costs and expenses	10,264	16,355	22,175	34,409
Operating income (loss)	2,077	1,343	6,602	(1,145)
Other income (expense):
Loss on sale of TBNG			(15,226)
Interest and other expense	(2,288)	(2,614)	(4,659)	(5,270)
Interest and other income	188	190	481	402
Gain (loss) on commodity derivative contracts	676	(3,003)	1,664	(2,232)
Foreign exchange gain (loss)	1,116	(611)	(1,007)	(269)
Total other expense	(308)	(6,038)	(18,747)	(7,369)
Income (loss) from continuing operations before income taxes	1,769	(4,695)	(12,145)	(8,514)
Income tax expense	(1,203)	(1,849)	(3,338)	(3,596)
Net income (loss) from continuing operations	566	(6,544)	(15,483)	(12,110)
Loss from discontinued operations before income taxes		(118)		(1,056)
Gain on disposal of discontinued operations				749
Income tax benefit				204
Net loss from discontinued operations		(118)		(103)
Net income (loss)	566	(6,662)	(15,483)	(12,213)
Other comprehensive income (loss):
Foreign currency translation adjustment	2,132	(2,265)	23,051	709
Comprehensive income (loss)	$ 2,698	$ (8,927)	$ 7,568	$ (11,504)
Basic net income (loss) per common share
Continuing operations	$ 0.01	$ (0.16)	$ (0.33)	$ (0.30)
Discontinued operations	$ 0	$ 0	$ 0	$ 0
Weighted average common shares outstanding	47,412	41,001	47,355	40,870
Diluted net income (loss) per common share
Continuing operations	$ 0.01	$ (0.16)	$ (0.33)	$ (0.30)
Discontinued operations	$ 0	$ 0	$ 0	$ 0
Weighted average common and common equivalent shares outstanding	47,826	41,001	47,355	40,870

Consolidated Statement of Equit

Consolidated Statement of Equity (Unaudited) - 6 months ended Jun. 30, 2017 - USD ($) $ in Thousands	Total	Common Shares [Member]	Treasury Stock [Member]	Warrants [Member]	Additional Paid-in Capital [Member]	Accumulated Other Comprehensive Loss [Member]	Accumulated Deficit [Member]
Beginning balance at Dec. 31, 2016	$ 38,486	$ 4,722	$ (970)	$ 699	$ 573,278	$ (140,316)	$ (398,228)
Beginning balance, shares at Dec. 31, 2016	47,220,525	47,220,000	333,000
Issuance of restricted stock units		$ 49			(49)
Issuance of restricted stock units, shares		485,000
Tax withholding on restricted stock units	$ (86)				(86)
Share-based compensation	414				414
Foreign currency translation adjustment	23,051					23,051
Net loss	(15,483)						(15,483)
Ending balance at Jun. 30, 2017	$ 46,382	$ 4,771	$ (970)	$ 699	$ 573,557	$ (117,265)	$ (413,711)
Ending balance, shares at Jun. 30, 2017	47,705,336	47,705,000	333,000

Consolidated Statements of Cash

Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Thousands		3 Months Ended		6 Months Ended		12 Months Ended
		Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016	Dec. 31, 2016
Operating activities:
Net loss		$ 566	$ (6,662)	$ (15,483)	$ (12,213)
Adjustment for net loss from discontinued operations			118		103
Net loss from continuing operations		566	(6,544)	(15,483)	(12,110)
Adjustments to reconcile net loss to net cash provided by operating activities:
Share-based compensation				414	354
Foreign currency loss				143	357
(Gain) loss on commodity derivative contracts		(676)	3,003	(1,664)	2,232
Cash settlement on commodity derivative contracts				32	1,459
Loss on sale of TBNG				15,226
Amortization on loan financing costs				61	331
Deferred income tax expense				2,479	684
Exploration, abandonment and impairment		2	128	108	1,433
Depreciation, depletion and amortization		4,255	7,807	8,752	15,773
Accretion of asset retirement obligations		47	96	95	188	$ 373
Changes in operating assets and liabilities:
Accounts receivable				7,188	(4,514)
Prepaid expenses and other assets				1,340	(283)
Accounts payable and accrued liabilities				(5,114)	5,692
Net cash provided by operating activities from continuing operations				13,577	11,596
Net cash used in operating activities from discontinued operations					(202)
Net cash provided by operating activities				13,577	11,394
Investing activities:
Additions to oil and natural gas properties				(11,331)	(3,182)
Additions to equipment and other properties				(356)	(3,399)
Restricted cash				(3,453)	(139)
Proceeds from the sale of TBNG				17,779
Net cash provided by (used in) investing activities				2,639	(6,720)
Financing activities:
Issuance of common shares					1,658
Tax withholding on restricted share units				(86)	(41)
Loan repayment				(12,775)	(12,152)
Loan repayment - related party				2,694
Net cash used in financing activities				(15,555)	(10,535)
Effect of exchange rate on cash flows and cash equivalents				7	(19)
Net increase (decrease) in cash and cash equivalents				668	(5,880)
Cash and cash equivalents, beginning of period	[1]			11,585	7,480	7,480
Cash and cash equivalents, end of period		$ 12,253	$ 1,600	12,253	1,600	$ 11,585	[1]
Supplemental disclosures:
Cash paid for interest				4,400	3,216
Cash paid for taxes				$ 1,460	263
Supplemental non-cash financing activities:
Issuance of common shares					$ 2,312
[1]	Includes TBNG cash held for sale of $1.6 million at December 31, 2016.

Consolidated Statements of Cas7

Consolidated Statements of Cash Flows (Parenthetical) $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)
Thrace Basin Natural Gas (Turkiye) Corporation [Member]
Cash held for sale	$ 1.6

General

General	6 Months Ended
	Jun. 30, 2017
Organization Consolidation And Presentation Of Financial Statements [Abstract]
General	1. General Nature of operations TransAtlantic Petroleum Ltd. (together with its subsidiaries, “we,” “us,” “our,” the “Company” or “TransAtlantic”) is an international oil and natural gas company engaged in acquisition, exploration, development and production. We have focused our operations in countries that have established, yet underexplored petroleum systems, are net importers of petroleum, have an existing petroleum transportation infrastructure and provide favorable commodity pricing, royalty rates and tax rates to exploration and production companies. We hold interests in developed and undeveloped oil and natural gas properties in Turkey and Bulgaria. As of August 7, 2017, approximately 47.9% of our outstanding common shares were beneficially owned by N. Malone Mitchell 3rd, our chief executive officer and chairman of our board of directors. TransAtlantic is a holding company with two operating segments – Turkey and Bulgaria. Its assets consist of its ownership interests in subsidiaries that primarily own assets in Turkey and Bulgaria. 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 the 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, contingencies and income taxes. Changes in facts and circumstances may result in revised estimates and actual results may differ from these estimates. During the six months ended June 30, 2017, we reclassified certain balance sheet amounts previously reported on our consolidated balance sheet at December 31, 2016 to conform to current year presentation. 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, 2016. On February 24, 2017, we closed the sale of our ownership interests in our subsidiary Thrace Basin Natural Gas (Turkiye) Corporation (“TBNG”) for gross proceeds of $20.7 million, and approximate net cash proceeds of $16.1 million, effective as of March 31, 2016. We classified the assets and liabilities of TBNG within the captions “Assets held for sale” and “Liabilities held for sale” on our consolidated balance sheets as of December 31, 2016. Although the sale of TBNG met the threshold to classify its assets and liabilities as held for sale, it did not meet the requirements to classify its operations as discontinued as the sale was not considered a strategic shift in the Company’s operations. As such, TBNG’s results of operations are classified as continuing operations for all periods presented (See Note 13, “Assets and liabilities held for sale and discontinued operations”).

Recent Accounting Pronouncement

Recent Accounting Pronouncements	6 Months Ended
	Jun. 30, 2017
Accounting Changes And Error Corrections [Abstract]
Recent accounting pronouncements	2. Recent accounting pronouncements In March 2016, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2016-08, Revenue from Contracts with Customers (Topic 606): Principal versus Agent Considerations (Reporting Revenue Gross versus Net) In April 2016, the FASB issued ASU 2016-10, Revenue from Contracts with Customers (Topic 606): Identifying Performance Obligations and Licensing In June 2016, the FASB issued ASU 2016-13, Financial Instruments - Credit Losses In August 2016, the FASB issued ASU 2016-15, Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments In November 2016, the FASB issued ASU 2016-18, Statement of Cash Flows (Topic 230): Restricted Cash 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.

Series A Preferred Shares

Series A Preferred Shares	6 Months Ended
	Jun. 30, 2017
Temporary Equity Disclosure [Abstract]
Series A preferred shares	3. Series A Preferred Shares Series A Preferred Shares On November 4, 2016, we issued 921,000 shares of our 12.0% Series A Convertible Redeemable Preferred Shares (“Series A Preferred Shares”). Of the 921,000 Series A Preferred Shares, (i) 815,000 shares were issued in exchange for $40.75 million of our 13.0% Convertible Notes due 2017 (“2017 Notes”), at an exchange rate of 20 Series A Preferred Shares for each $1,000 principal amount of 2017 Notes, and (ii) 106,000 shares were issued and sold for $5.3 million of cash to certain holders of the 2017 Notes. All of the Series A Preferred Shares were issued at a value of $50.00 per share. We used $4.3 million of the gross proceeds to redeem a portion of the remaining 2017 Notes on January 1, 2017. The remaining proceeds were used for general corporate purposes. The Series A Preferred Shares contain a substantive conversion option, are mandatorily redeemable and convert into a fixed number of common shares. As a result, under U.S GAAP, we have classified the Series A Preferred Shares within mezzanine equity in our consolidated balance sheets. As of June 30, 2017, there were $21.3 million of Series A Preferred Shares and $24.8 million of Series A Preferred Shares – related party outstanding. Pursuant to the Certificate of Designations for the Series A Preferred Shares (the “Certificate of Designations”), each Series A Preferred Share may be converted at any time, at the option of the holder, into 45.754 common shares of the Company (which is equal to an initial conversion price of approximately $1.0928 per common share and is subject to customary adjustments for stock splits, stock dividends, recapitalizations or other fundamental changes). During the period ending on November 4, 2017, the conversion rate will be adjusted on an economic weighted average anti-dilution basis for the issuance of common shares for cash at a price below the conversion price then in effect. Such anti-dilution protection excludes (i) dividends paid on the Series A Preferred Shares in common shares, (ii) issuances of common shares in connection with acquisitions, (iii) issuances of common shares under currently outstanding convertible notes and warrants and (iv) issuances of common shares in connection with employee compensation arrangements and employee benefit plans. This non-standard dilution adjustment clause results in a contingent beneficial conversion feature. If not converted sooner, on November 4, 2024, we are required to redeem the outstanding Series A Preferred Shares in cash at a price per share equal to the liquidation preference plus accrued and unpaid dividends. At any time on or after November 4, 2020, we may redeem all or a portion of the Series A Preferred Shares at the redemption prices listed below (expressed as a percentage of the liquidation preference amount per share) plus accrued and unpaid dividends to the date of redemption, if the closing sale price of the common shares equals or exceeds 150% of the conversion price then in effect for at least 10 trading days (whether or not consecutive) in a period of 20 consecutive trading days, including the last trading day of such 20 trading day period, ending on, and including, the trading day immediately preceding the business day on which we issue a notice of optional redemption. The redemption prices for the 12-month period starting on the date below are: Period Commencing Redemption Price November 4, 2020 105.000% November 4, 2021 103.000% November 4, 2022 101.000% November 4, 2023 and thereafter 100.000% Additionally, upon the occurrence of a change of control, we are required to offer to redeem the Series A Preferred Shares within 120 days after the first date on which such change of control occurred, for cash at a redemption price equal to the liquidation preference per share, plus any accrued and unpaid dividends. Dividends on the Series A Preferred Shares are payable quarterly at our election in cash, common shares or a combination of cash and common shares at an annual dividend rate of 12.0% of the liquidation preference if paid all in cash or 16.0% of the liquidation preference if paid in common shares. If paid partially in cash and partially in common shares, the dividend rate on the cash portion is 12.0%, and the dividend rate on the common share portion is 16.0%. Dividends are payable quarterly, on March 31, June 30, September 30, and December 31 of each year. The holders of the Series A Preferred Shares also are entitled to participate pro-rata in any dividends paid on the common shares on an as-converted-to-common shares basis. For the three and six months ended June 30, 2017, we paid $1.4 million and $2.8 million, respectively, in our consolidated statements of comprehensive (loss) income under the caption Except as required by Bermuda law, the holders of Series A Preferred Shares have no voting rights, except that for so long as at least 400,000 Series A Preferred Shares are outstanding, the holders of the Series A Preferred Shares voting as a separate class have the right to elect two directors to our Board of Directors. For so long as between 80,000 and 399,999 Series A Preferred Shares are outstanding, the holders of the Series A Preferred Shares voting as a separate class have the right to elect one director to our Board of Directors. Upon less than 80,000 Series A Preferred Shares remaining outstanding, any directors elected by the holders of Series A Preferred Shares shall immediately resign from our Board of Directors. The Certificate of Designation also provides that without the approval of the holders of a majority of the outstanding Series A Preferred Shares, we will not issue indebtedness for money borrowed or other securities which are senior to the Series A Preferred Shares in excess of the greater of (i) $100 million or (ii) 35% of our PV-10 of proved reserves as disclosed in our most recent independent reserve report filed or furnished by us on EDGAR. We have agreed to use commercially reasonable efforts to file a shelf registration statement for the resale of the Series A Preferred Shares and the common shares issuable upon conversion of the Series A Preferred Shares prior to November 5, 2017 and have such shelf registration statement declared effective by the SEC as soon as practicable after filing.

Property and equipment

Property and equipment	6 Months Ended
	Jun. 30, 2017
Property Plant And Equipment [Abstract]
Property and equipment	4. 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, 2017 December 31, 2016 (in thousands) Oil and natural gas properties, proved: Turkey $ 200,176 $ 196,743 Bulgaria 510 471 Total oil and natural gas properties, proved 200,686 197,214 Oil and natural gas properties, unproved: Turkey 30,033 21,109 Total oil and natural gas properties, unproved 30,033 21,109 Gross oil and natural gas properties 230,719 218,323 Accumulated depletion (124,460 ) (115,401 ) Net oil and natural gas properties $ 106,259 $ 102,922 For the six months ended June 30, 2017, we recorded foreign currency translation adjustments, which increased proved properties and decreased accumulated other comprehensive loss within shareholders’ equity on our consolidated balance sheet. At June 30, 2017 and December 31, 2016, we excluded $0.2 million and $1.9 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, 2017, the capitalized costs of our oil and natural gas properties, net of accumulated depletion, included $12.7 million relating to acquisition costs of proved properties, which are being depleted by the unit-of-production method using total proved reserves, and $63.3 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, 2016, the capitalized costs of our oil and natural gas properties included $13.2 million relating to acquisition costs of proved properties, which are being amortized by the unit-of-production method using total proved reserves, and $66.7 million relating to well costs and additional development costs, which are being amortized by the unit-of-production method using proved developed reserves. Impairments of proved properties and impairment of exploratory well costs Proved oil and natural gas properties are reviewed for impairment when events and circumstances indicate the carrying value of such properties may not be recoverable. We primarily use Level 3 inputs to determine fair value, including but are not limited to, estimates of proved reserves, future commodity prices, the timing and amount of future production and capital expenditures and discount rates commensurate with the risk reflective of the lives remaining for the respective oil and natural gas properties. During the six months ended June 30, 2017, we recorded $0.1 million of impairment of proved properties and exploratory well costs which are primarily measured using Level 3 inputs. Capitalized cost greater than one year As of June 30, 2017, we had $3.9 million of exploratory well costs capitalized for the Pinar-1 well in Turkey, which we spud in March 2014. We are currently sidetracking the Pinar-1 well. 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, 2017 December 31, 2016 (in thousands) Inventory $ 9,270 $ 10,704 Leasehold improvements, office equipment and software 7,603 7,280 Vehicles 365 364 Other equipment 2,026 1,925 Gross equipment and other property 19,264 20,273 Accumulated depreciation (5,771 ) (5,237 ) Net equipment and other property $ 13,493 $ 15,036 At June 30, 2017, we classified $3.7 million of inventory as a current asset, which represents our expected inventory consumption in the next twelve months. We classify our materials and supply inventory 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, 2017 and December 31, 2016, we excluded $12.9 million and $14.4 million of inventory, respectively, from depreciation as the inventory had not been placed into service.

Asset Retirement obligations

Asset Retirement obligations	6 Months Ended
	Jun. 30, 2017
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement obligations	5. Asset retirement obligations The following table summarizes the changes in our asset retirement obligations (“ARO”) for the six months ended June 30, 2017 and for the year ended December 31, 2016: June 30, 2017 December 31, 2016 (in thousands) Asset retirement obligations at beginning of period $ 4,833 $ 9,237 Change in estimates – (7 ) Liabilities settled (37 ) – Foreign exchange change effect 46 (1,604 ) Additions – 16 Accretion expense 95 373 Asset retirement obligations at end of period 4,937 8,015 Less: TBNG - 3,182 Long-term portion $ 4,937 $ 4,833 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 instrument

Commodity derivative instruments	6 Months Ended
	Jun. 30, 2017
Derivative Instruments And Hedging Activities Disclosure [Abstract]
Commodity derivative instruments	6. 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 (loss) income under the caption “Gain (loss) on commodity derivative contracts.” Settlements of derivative contracts are included in operating activities on our consolidated statements of cash flows under the caption “Cash settlement on commodity derivative contracts.” During the three months ended June 30, 2017 and 2016, we recorded a net gain on commodity derivative contracts of $0.7 million and a net loss of $3.0 million, respectively. During the six months ended June 30, 2017 and 2016, we recorded a net gain on commodity derivative contracts of $1.7 million and a net loss of $2.2 million, respectively. At June 30, 2017 and December 31, 2016, we had outstanding derivative 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, 2017 Average Average Quantity Minimum Maximum Price Estimated Fair Type Period (Bbl/day) Price (per Bbl) (per Bbl) Value of Asset (in thousands) Collar July 1, 2017 — December 31, 2017 293 $ 47.50 $ 61.00 $ 116 Collar July 1, 2017 — December 31, 2017 440 $ 50.00 $ 61.50 288 Collar July 1, 2017 — December 31, 2017 489 $ 47.00 $ 59.65 161 Collar January 1, 2018 — February 28, 2018 458 $ 50.00 $ 61.50 82 Collar January 1, 2018 — March 31, 2018 500 $ 47.00 $ 59.65 60 Collar January 1, 2018 — May 31, 2018 298 $ 47.50 $ 61.00 87 Total estimated fair value of asset $ 794 Fair Value of Derivative Instruments as of December 31, 2016 Weighted Weighted Average Average Quantity Minimum Maximum Price Estimated Fair Type Period (Bbl/day) Price (per Bbl) (per Bbl) Value of Liability (in thousands) Collar January 1, 2017 — December 31, 2017 296 $ 47.50 $ 61.00 $ (289 ) Collar January 2, 2017 — December 31, 2017 445 $ 50.00 $ 61.50 (307 ) Collar January 1, 2018 — February 28, 2018 458 $ 50.00 $ 61.50 (74 ) Collar January 1, 2018 — May 31, 2018 298 $ 47.50 $ 61.00 (168 ) Total estimated fair value of liability $ (838 ) 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, 2017 and December 31, 2016, and (ii) the net recorded fair value as reflected on our consolidated balance sheets at June 30, 2017 and December 31, 2016. As of June 30, 2017 Gross Amount Net Amount of Gross Offset in the Assets Amount of Consolidated Presented in the Location on Consolidated Recognized Balance Consolidated Underlying Commodity Balance Sheets Assets Sheet s Balance Sheets (in thousands) Crude oil Current assets $ 794 $ - $ 794 As of December 31, 2016 Gross Amount Net Amount of Gross Offset in the Liabilities Amount of Consolidated Presented in the Location on Consolidated Recognized Balance Consolidated Underlying Commodity Balance Sheets Liabilities Sheets Balance Sheets (in thousands) Crude oil Current liabilities $ 596 $ - $ 596 Crude oil Long-term liabilities $ 242 $ - $ 242

Loans payable

Loans payable	6 Months Ended
	Jun. 30, 2017
Debt Disclosure [Abstract]
Loans payable	7. Loans payable As of the dates indicated, our third-party debt consisted of the following: June 30, December 31, 2017 2016 Fixed and floating rate loans (in thousands) Term Loan $ 16,500 $ 25,000 2017 Notes (1) 9,450 13,500 2017 Notes - Related Party (1) 525 750 ANBE Note - 2,694 Loans payable 26,475 41,944 Less: current portion 26,475 38,194 Long-term portion $ - $ 3,750 (1) The 2017 Notes matured on July 1, 2017, and on July 3, 2017, we paid off and retired all remaining outstanding 2017 Notes. Term Loan On August 23, 2016, the Turkish branch of TransAtlantic Exploration Mediterranean International Pty Ltd (“TEMI”) entered into a Credit Agreement with DenizBank, A.S. (“DenizBank”). On August 31, 2016, DenizBank entered into a $30.0 million term loan with TEMI under the Credit Agreement (the “Term Loan”). In addition, we and DenizBank entered into additional agreements with respect to up to $20.0 million of non-cash facilities, including guarantee letters and treasury instruments for future hedging transactions. On September 7, 2016, TEMI used approximately $22.9 million of the proceeds from the Term Loan to repay our prior senior credit facility in full. The Term Loan bears interest at a fixed rate of 5.25% (plus 0.2625% for Banking and Insurance Transactions Tax per the Turkish government) per annum. Amounts repaid under the Term Loan may not be re-borrowed, and early repayments under the Term Loan are subject to early repayment fees. On April 27, 2017, TEMI and DenizBank approved a revised amortization schedule for the Term Loan. Pursuant to the revised amortization schedule, the maturity date of the Term Loan was extended from February 2018 to June 2018, and the monthly principal payments were reduced from $1.88 million to $1.38 million. The other terms of the Term Loan remain unchanged. At June 30, 2017, we had $16.5 million outstanding under the Term Loan and no availability, and were in compliance with the covenants in the Term Loan . 2017 Notes As of June 30, 2017, we had $10.0 million aggregate principal amount of outstanding 2017 Notes. The 2017 Notes were issued pursuant to an indenture, dated as of February 20, 2015 (the “Indenture”), between us and U.S. Bank National Association, as trustee (the “Trustee”). The 2017 Notes bore interest at an annual rate of 13.0%, payable semi-annually, in arrears, on January 1 and July 1 of each year. The 2017 Notes matured on July 1, 2017, and on July 3, 2017, we paid off and retired all remaining outstanding 2017 Notes. ANBE Note On December 30, 2015, TransAtlantic Petroleum (USA) Corp (“TransAtlantic USA”) entered into a $5.0 million draw down convertible promissory note (the “Note”) with ANBE Holdings, L.P. (“ANBE”), an entity owned by the adult children of the Company’s chairman and chief executive officer, N. Malone Mitchell 3rd, and controlled by an entity managed by Mr. Mitchell and his wife. The ANBE Note bore interest at a rate of 13.0% per annum. 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, 2017, we had no outstanding borrowings under these lines of credit.

Contingencies relating to produ

Contingencies relating to production leases and exploration permits	6 Months Ended
	Jun. 30, 2017
Commitments And Contingencies Disclosure [Abstract]
Contingencies relating to production leases and exploration permits	8. 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 During 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, during 2012, we recorded $5.0 million in accrued liabilities relating to our Tselfat exploration permit for this contingency. In September 2016, management determined that, because it had received no communication from the Moroccan government since early 2013, the probability of payment of this contingency is remote. Therefore, the Company reversed the $6.0 million in contingent liabilities previously classified as liabilities held for sale . Bulgaria During 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. In October 2015, the Bulgarian Ministry of Energy and Economy filed a suit against our subsidiary, Direct Petroleum Bulgaria EOOD (“Direct Bulgaria”), claiming a $200,000 penalty for Direct Bulgaria’s alleged failure to fulfill the work program associated with the Aglen exploration permit. Direct Bulgaria received a force majeure recognition in 2012 from the Bulgarian Ministry of Energy and Economy, and the force majeure event has not been rectified. We believe that Direct Bulgaria is not under any obligation to fulfill the work program until the force majeure event is rectified, and continue to vigorously defend this claim.

Shareholders' equity

Shareholders' equity	6 Months Ended
	Jun. 30, 2017
Equity [Abstract]
Shareholders' equity	9. Shareholders’ equity Restricted stock units We recorded share-based compensation expense of $0.3 million and $0.2 million for awards of restricted stock units (“RSUs”) for the three months ended June 30, 2017 and 2016, respectively. We recorded share-based compensation expense $0.4 million for awards of RSUs for each of the six months ended June 30, 2017 and 2016. As of June 30, 2017, we had approximately $0.6 million of unrecognized compensation expense related to unvested RSUs, which is expected to be recognized over a weighted average period of 1 year. Earnings per share We account for earnings per share in accordance with ASC Subtopic 260-10, 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) 2017 2016 2017 2016 Net income (loss) from continuing operations $ 566 $ (6,544 ) $ (15,483 ) $ (12,110 ) Net loss from discontinued operations $ - $ (118 ) $ - $ (103 ) Basic net income (loss) per common share: Shares: Weighted average common shares outstanding 47,412 41,001 47,355 40,870 Basic net income (loss) per common share: Continuing operations $ 0.01 $ (0.16 ) $ (0.33 ) $ (0.30 ) Discontinued operations $ (0.00 ) $ (0.00 ) $ (0.00 ) $ (0.00 ) Diluted net income (loss) per common share: Shares: Weighted average common shares outstanding 47,412 41,001 47,355 40,870 Dilutive effect of: Restricted stock units 414 - - - Weighted average common shares outstanding 47,826 41,001 47,355 40,870 Diluted net (income) loss per common share: Continuing operations $ 0.01 $ (0.16 ) $ (0.33 ) $ (0.30 ) Discontinued operations $ (0.00 ) $ (0.00 ) $ (0.00 ) $ (0.00 )

Segment information

Segment information	6 Months Ended
	Jun. 30, 2017
Segment Reporting [Abstract]
Segment information	10. Segment information In accordance with ASC 280, Segment Reporting Corporate Turkey Bulgaria Total (in thousands) For the three months ended June 30, 2017 Total revenues $ - $ 12,341 $ - $ 12,341 (Loss) income from continuing operations before income taxes (4,315 ) 6,163 (79 ) 1,769 Capital expenditures $ - $ 4,893 $ - $ 4,893 For the three months ended June 30, 2016 Total revenues $ - $ 17,698 $ - $ 17,698 Loss from continuing operations before income taxes (3,990 ) (567 ) (138 ) (4,695 ) Capital expenditures $ - $ 911 $ - $ 911 For the six months ended June 30, 2017 Total revenues $ - $ 28,777 $ - $ 28,777 (Loss) income from continuing operations before income taxes (23,236 ) 11,240 (149 ) (12,145 ) Capital expenditures $ - $ 11,331 $ - $ 11,331 For the six months ended June 30, 2016 Total revenues $ 33,264 $ 33,264 (Loss) income from continuing operations before income taxes (8,990 ) 679 (203 ) (8,514 ) Capital expenditures $ - $ 3,191 $ - $ 3,191 Segment assets June 30, 2017 $ 21,837 $ 146,372 $ 595 $ 168,804 December 31, 2016 (1) $ 17,007 $ 153,560 $ 609 $ 171,176 (1) Excludes assets of TBNG of $25.2 million at December 31, 2016.

Financial instruments

Financial instruments	6 Months Ended
	Jun. 30, 2017
Fair Value Disclosures [Abstract]
Financial instruments	11. Financial instruments Cash and cash equivalents, restricted cash, accounts receivable, accounts payable, accrued liabilities and our loans payable were each estimated to have a fair value approximating the carrying amount at June 30, 2017 and December 31, 2016, 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. Foreign currency risk We have underlying foreign currency exchange rate exposure. Our currency exposures relate to transactions denominated in the Bulgarian Lev, European Union Euro, and Turkish Lira (“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, 2017, we had 9.9 million TRY (approximately $2.8 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, 2017 and December 31, 2016, we were a party to commodity derivative contracts (See Note 6, “Commodity derivative instruments”). 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 purchases all of our oil production. The receivables are not collateralized. To date, we have experienced minimal bad debts from customers in Turkey. 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, 2017: Fair Value Measurement Classification Quoted Prices in Active Markets for Identical Assets or Significant Other Significant Liabilities Observable Inputs Unobservable Inputs (Level 1) (Level 2) (Level 3) Total (in thousands) Measured on a recurring basis Assets: Commodity derivative contracts $ – $ 794 $ – $ 794 Disclosed but not carried at fair value Liabilities: Term Loan - - (16,500 ) (16,500 ) 2017 Notes - - (9,975 ) (9,975 ) Total $ – $ 794 $ (26,475 ) $ (25,681 ) The following table summarizes the valuation of our financial assets and liabilities as of December 31, 2016: Fair Value Measurement Classification Quoted Prices in Active Markets for Identical Assets or Significant Other Significant Liabilities Observable Inputs Unobservable Inputs (Level 1) (Level 2) (Level 3) Total (in thousands) Measured on a recurring basis Liabilities: Commodity derivative contracts $ – $ (838 ) $ – $ (838 ) Disclosed but not carried at fair value Liabilities: Term Loan - - (22,500 ) (22,500 ) 2017 Notes - - (13,554 ) (13,554 ) Total $ – $ (838 ) $ (36,054 ) $ (36,892 ) We remeasure our derivative contracts on a recurring basis, with changes flowing through earnings. At June 30, 2017 and December 31, 2016, the fair values of our Term Loan and the 2017 Notes were estimated using a discounted cash flow analysis based on unobservable Level 3 inputs, including our own credit risk associated with the loans payable.

Related Party Transactions

Related Party Transactions	6 Months Ended
	Jun. 30, 2017
Related Party Transactions [Abstract]
Related party transactions	12. Related party transactions The following table summarizes related party accounts receivable and accounts payable as of the dates indicated: June 30, December 31, 2017 2016 (in thousands) Related party accounts receivable: Riata Management Service Agreement $ 456 $ 528 PSIL MSA 334 234 Total related party accounts receivable 790 762 Related party accounts payable: Riata Management Service Agreement $ 433 $ 346 PSIL MSA 1,671 1,315 Interest payable on 2017 Notes 34 183 Total related party accounts payable $ 2,138 $ 1,844 Services transactions On March 20, 2017, the Company entered into a second amendment to the Service Agreement among the Company and Longfellow Energy, LP, a Texas limited partnership (“Longfellow”), Viking Drilling, LLC, a Nevada limited liability company, RIATA Management LLC, an Oklahoma limited liability company, Longfellow Nemaha, LLC, a Texas limited liability company, Red Rock Minerals, LP, a Delaware limited partnership, Red Rock Advisors, LLC, a Texas limited liability company, Production Solutions International Limited, a Bermuda exempted company, and Nexlube Operating, LLC, a Delaware limited liability company, and their subsidiaries (collectively, the "Riata Entities"), adding and removing certain of the Riata Entities and expanding the scope of services. Because this agreement is a related party transaction, the independent members of the Board of Directors reviewed and approved this amendment. As of June 30, 2017, the Company had $0.5 million of outstanding receivables and $0.4 million of outstanding payables pursuant to this Service Agreement. On March 3, 2016, Mr. Mitchell sold his interests in Viking Services B.V. (“Viking Services”), the beneficial owner of Viking International Limited (“Viking International”), Viking Petrol Sahasi Hizmetleri A.S. (“VOS”) and Viking Geophysical Services Ltd. (“Viking Geophysical”), to a third party. As part of the transaction, Mr. Mitchell acquired certain equipment used in the performance of stimulation, wireline, workover and similar services (the “Services”), which equipment is owned and operated by Production Solutions International Petrol Arama Hizmetleri Anonim Sirketi (“PSIL”). PSIL is beneficially owned by Dalea Investment Group, LLC, which is controlled by Mr. Mitchell. Consequently, on March 3, 2016, TEMI entered into a master services agreement (the “PSIL MSA”) with PSIL on substantially similar terms to our current master services agreements with Viking International, VOS and Viking Geophysical. Pursuant to the PSIL MSA, PSIL performs the Services on behalf of TEMI and its affiliates. The master services agreements with each of Viking International, VOS and Viking Geophysical remain in effect in accordance with the terms of the agreements. As of June 30, 2017, the Company had $0.3 million of outstanding receivables and $1.7 million of outstanding payables pursuant to the PSIL MSA. Debt transactions On February 27, 2017, we repaid the ANBE Note in full with proceeds from the sale of TBNG and terminated it. Dalea Amended Note and Pledge Agreement On April 19, 2016, we entered into a note amendment agreement (the “Note Amendment Agreement”) with Mr. Mitchell and Dalea Partners, LP (“Dalea”), pursuant to which Dalea agreed to deliver an amended and restated promissory note (the “Amended Note”) in favor of us, in the principal sum of $7,964,053, which Amended Note would amend and restate that certain Promissory Note, dated June 13, 2012, made by Dalea in favor of us in the principal amount of $11,500,000 (the “Original Note”). The Note Amendment Agreement reduced the principal amount of the Original Note to $7,964,053 in exchange for the cancellation of an account payable of approximately $3.5 million (the “Account Payable”) owed by TransAtlantic Albania Ltd. (“TransAtlantic Albania”), a former subsidiary of the Company, to Viking International Limited. We have indemnified a third party for any liability relating to the payment of the Account Payable. Pursuant to the Note Amendment Agreement, on April 19, 2016, we entered into the Amended Note, which amended and restated the Original Note that was issued in connection with our sale of its subsidiaries, Viking International and Viking Geophysical Services, to a joint venture owned by Dalea and Abraaj Investment Management Limited in June 2012. In the Amended Note, we and Dalea acknowledged that (i) while the sale of Dalea’s interest in Viking Services enabled us to take the position that the Original Note was accelerated in accordance with its terms, the principal purpose of including the acceleration events in the Original Note was to ensure that certain oilfield services provided by Viking Services to us would continue to be available to us, and (ii) such services will now be provided pursuant to the PSIL MSA. PSIL is beneficially owned by Dalea Investment Group, LLC, which is controlled by Mr. Mitchell. As a result, the Amended Note revised the events triggering acceleration of the repayment of the Original Note to the following: (i) a reduction of ownership by Dalea (and other controlled affiliates of Mr. Mitchell) of equity interest in PSIL to less than 50%; (ii) the sale or transfer by Dalea or PSIL of all or substantially all of its assets to any person (a “Transferee”) that does not own a controlling interest in Dalea or PSIL and is not controlled by Mr. Mitchell (an “Unrelated Person”), or the subsequent transfer by any Transferee that is not an Unrelated Person of all or substantially all of its assets to an Unrelated Person; (iii) the acquisition by an Unrelated Person of more than 50% of the voting interests of Dalea or PSIL; (iv) termination of the PSIL MSA other than as a result of an uncured default thereunder by TEMI; (v) default by PSIL under the PSIL MSA, which default is not remedied within a period of 30 days after notice thereof to PSIL; and (vi) insolvency or bankruptcy of PSIL. The maturity date of the Amended Note was extended to June 13, 2019. The interest rate on the Amended Note remains at 3.0% per annum and continues to be guaranteed by Mr. Mitchell. The Amended Note contains customary events of default. In addition, pursuant to the Note Amendment Agreement, on April 19, 2016, we entered into a pledge agreement (the “Pledge Agreement”) with Dalea, whereby Dalea pledged the $2.1 million principal amount of the 2017 Notes issued by us and owned by Dalea (the “Dalea Convertible Notes”), including any future securities for which the Dalea Convertible Notes are converted or exchanged, as security for the performance of Dalea’s obligations under the Amended Note. The Pledge Agreement provides that interest payable to Dalea under the Dalea Convertible Notes (or any future securities for which the Dalea Convertible Notes are converted or exchanged) will be credited first against the outstanding principal balance of the Amended Note and, upon full repayment of the outstanding principal balance of the Amended Note, any accrued and unpaid interest on the Amended Note. The Pledge Agreement contains customary events of default. On November 4, 2016, Dalea exchanged $2.0 million of 2017 Notes for 40,000 Series A Preferred Shares, which were pledged as security for the performance of Dalea’s obligations under the Amended Note pursuant to the terms of the Pledge Agreement. During the three and six months ended June 30, 2017, we reduced the principal amount of the Amended Note by $0.1 million and $0.2 million, respectively, for cash dividends on the Series A Preferred Shares. Pledge fee agreements In connection with the pledge of the Gundem real estate and Muratli real estate to DenizBank as collateral for the Term Loan, on August 31, 2016, the Company entered into a pledge fee agreement with Gundem (the “Gundem Fee Agreement”) pursuant to which the Company pays Gundem a fee equal to 5% per annum of the collateral value of the Gundem real estate and Muratli real estate. Pursuant to the Gundem Fee Agreement, the Gundem real estate has a deemed collateral value of $10.0 million and the Muratli real estate has a deemed collateral value of $5.0 million. In connection with the pledge of the Diyarbakir real estate to DenizBank as collateral for the Term Loan, on August 31, 2016, the Company entered into a pledge fee agreement with Messrs. Mitchell and Uras (the “Diyarbakir Fee Agreement”) pursuant to which the Company pays Mr. Mitchell and Selami Erdem Uras a fee of 5% per annum of the collateral value of the Diyarbakir real estate. Mr. Uras is our vice president, Turkey. Pursuant to the Diyarbakir Fee Agreement, the Diyarbakir real estate has a deemed collateral value of $5.0 million. Amounts payable to Mr. Mitchell under the Gundem Fee Agreement and the Diyarbakir Fee Agreement are used to reduce the outstanding principal amount of the Amended Note. During the three and six months ended June 30, 2017, we reduced the principal amount of the Amended Note by $0.2 million and $0.3 million, respectively, for amounts payable under the pledge fee agreements. Office lease On June 26, 2017, and effective as of January 1, 2017, the Company’s wholly owned subsidiary, TransAtlantic USA entered into an Amended and Restated Office Lease (the “Office Lease”) with Longfellow to lease approximately 10,000 square feet of corporate office space in Addison, Texas. The initial lease term under the Office Lease commenced on January 1, 2017 (the “Commencement Date”), and expires five years after the Commencement Date, unless earlier terminated in accordance with the Office Lease. TransAtlantic USA has the option to extend the lease term for two additional periods of five years each. If TransAtlantic USA exercises its option to extend the lease term, the monthly rent payable during such extended term shall be at a mutually agreed upon amount for monthly rent during the renewal term. During the first five months of the initial lease term, TransAtlantic USA is required to pay monthly rent of $14,745.16 to Longfellow, plus utilities, real property taxes, and liability insurance (to the extent that TransAtlantic does not obtain its own liability insurance). Monthly rent increases by $2,754.84 the sixth month of the initial lease term, by $833.33 the second year of the initial lease term, and by approximately $417 each year thereafter during the initial lease term.

Assets and Liabilities Held for

Assets and Liabilities Held for Sale and Discontinued Operations	6 Months Ended
	Jun. 30, 2017
Discontinued Operations And Disposal Groups [Abstract]
Assets and liabilities held for sale and discontinued operations	13. Assets and liabilities held for sale and discontinued operations TBNG assets and liabilities held for sale On October 13, 2016, we entered into a share purchase agreement (the “Purchase Agreement”) with Valeura Energy Netherlands B.V. (“Valeura”) for the sale of all of the equity interests in TBNG, our wholly-owned subsidiary. TBNG owns a portion of the Company’s interests in the Thrace Basin area in Turkey. We classified the assets and liabilities of TBNG within the captions “Assets held for sale” and “Liabilities held for sale” on our consolidated balance sheets as of December 31, 2016. Although the sale of TBNG met the threshold to classify its assets and liabilities as held for sale, it did not meet the requirements to classify its operations as discontinued as the sale was not considered a strategic shift in the Company’s operations. As such, TBNG’s results of operations are classified as continuing operations for all periods presented. On February 24, 2017, we closed on the sale of TBNG for gross proceeds of $20.7 million, and approximate net cash proceeds of $16.1 million, effective as of March 31, 2016. The purchase price was subject to post-closing adjustments, and we agreed to escrow $3.1 million of the purchase price for 30 days to satisfy any agreed upon purchase price adjustments. We agreed to a $0.2 million reduction to the purchase price and, on April 10, 2017, we collected the $2.9 million of escrowed funds. For the six months ended June 30, 2017, we recorded a net loss of $15.2 million on the sale of TBNG. The loss related to the reclassification of the TBNG accumulated foreign currency translation adjustment that was realized into earnings from accumulated other comprehensive loss within shareholders’ equity. The calculation of the loss on sale is presented below: Loss on Sale (in thousands) Total cash proceeds for TBNG $ 20,707 Less: TBNG net assets 12,869 Gain on sale before accumulated foreign currency translation adjustment 7,838 Less: TBNG accumulated foreign currency translation adjustment (23,064 ) Net loss on sale of TBNG $ (15,226 ) Our assets and liabilities held for sale at December 31, 2016 were as follows: Held for Sale (in thousands) For the year ended December 31, 2016 Assets Cash $ 1,551 Other current assets 7,511 Property and equipment, net 16,155 Total current assets held for sale $ 25,217 Liabilities Accounts payable and other accrued liabilities $ 11,240 Deferred tax liability 4,698 Total current liabilities held for sale $ 15,938 We had no assets or liabilities held for sale at June 30, 2017. Discontinued operations in Albania In February 2016, we sold all of the outstanding equity in our wholly-owned subsidiary, Stream Oil & Gas Ltd. (“Stream”), to GBC Oil Company (“GBC Oil”). We have presented the Albanian segment operating results as discontinued operations for the three and six months ended June 30, 2016. On September 1, 2016, we completed a joint venture transaction with respect to the assets in the Delvina gas field in Albania (the “Delvina Assets”). We transferred (the “Transfer”) 75% of the outstanding shares of Delvina Gas Company Ltd. (“DelvinaCo”), which owns the Delvina Assets, to Ionian Gas Company Ltd. (“Ionian”) in exchange for Ionian’s agreement to pay $12.0 million to DelvinaCo, which will be used primarily to repay debt and for general corporate purposes with respect to the Delvina Assets. After the Transfer, we retained a 25% equity interest in DelvinaCo and agreed to pay 25% of the operating costs of DelvinaCo, subject to a three-year deferral of capital expenditures. As of June 30, 2017, we no longer hold our 25% interest in DelvinaCo as assets held for sale, and have consolidated our interest using proportionate consolidation. On August 9, 2017, due to continued failures by our joint venture partners Our operating results from discontinued operations for the three and six months ended June 30, 2016 are summarized as follows: Discontinued Operations (in thousands) For the three months ended June, 2016 Total revenues $ - Production and transportation expense - Total other costs and expenses 118 Loss before income taxes $ (118 ) Gain on disposal of discontinued operations - Income tax benefit - Loss from discontinued operations $ (118 ) For the six months ended June, 2016 Total revenues $ 626 Production and transportation expense 1,155 Total other costs and expenses 527 Loss before income taxes $ (1,056 ) Gain on disposal of discontinued operations 749 Income tax benefit 204 Loss from discontinued operations $ (103 ) For the three and six months ended June 30, 2017, we did not have any discontinued operations.

Subsequent Events

Subsequent Events	6 Months Ended
	Jun. 30, 2017
Subsequent Events [Abstract]
Subsequent Events	14. Subsequent Events On July 3, 2017, we paid off and retired all remaining 2017 Notes. On August 9, 2017, due to continued failures by our joint venture partners

General (Policies)

General (Policies)	6 Months Ended
	Jun. 30, 2017
Accounting Policies [Abstract]
Nature of operations	Nature of operations TransAtlantic Petroleum Ltd. (together with its subsidiaries, “we,” “us,” “our,” the “Company” or “TransAtlantic”) is an international oil and natural gas company engaged in acquisition, exploration, development and production. We have focused our operations in countries that have established, yet underexplored petroleum systems, are net importers of petroleum, have an existing petroleum transportation infrastructure and provide favorable commodity pricing, royalty rates and tax rates to exploration and production companies. We hold interests in developed and undeveloped oil and natural gas properties in Turkey and Bulgaria. As of August 7, 2017, approximately 47.9% of our outstanding common shares were beneficially owned by N. Malone Mitchell 3rd, our chief executive officer and chairman of our board of directors. TransAtlantic is a holding company with two operating segments – Turkey and Bulgaria. Its assets consist of its ownership interests in subsidiaries that primarily own assets in Turkey and Bulgaria.
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 the 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, contingencies and income taxes. Changes in facts and circumstances may result in revised estimates and actual results may differ from these estimates. During the six months ended June 30, 2017, we reclassified certain balance sheet amounts previously reported on our consolidated balance sheet at December 31, 2016 to conform to current year presentation. 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, 2016. On February 24, 2017, we closed the sale of our ownership interests in our subsidiary Thrace Basin Natural Gas (Turkiye) Corporation (“TBNG”) for gross proceeds of $20.7 million, and approximate net cash proceeds of $16.1 million, effective as of March 31, 2016. We classified the assets and liabilities of TBNG within the captions “Assets held for sale” and “Liabilities held for sale” on our consolidated balance sheets as of December 31, 2016. Although the sale of TBNG met the threshold to classify its assets and liabilities as held for sale, it did not meet the requirements to classify its operations as discontinued as the sale was not considered a strategic shift in the Company’s operations. As such, TBNG’s results of operations are classified as continuing operations for all periods presented (See Note 13, “Assets and liabilities held for sale and discontinued operations”).
Recent accounting pronouncements	In March 2016, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2016-08, Revenue from Contracts with Customers (Topic 606): Principal versus Agent Considerations (Reporting Revenue Gross versus Net) In April 2016, the FASB issued ASU 2016-10, Revenue from Contracts with Customers (Topic 606): Identifying Performance Obligations and Licensing In June 2016, the FASB issued ASU 2016-13, Financial Instruments - Credit Losses In August 2016, the FASB issued ASU 2016-15, Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments In November 2016, the FASB issued ASU 2016-18, Statement of Cash Flows (Topic 230): Restricted Cash 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.

Series A Preferred Shares (Tabl

Series A Preferred Shares (Tables)	6 Months Ended
	Jun. 30, 2017
Temporary Equity Disclosure [Abstract]
Schedule of Redemption Prices	The redemption prices for the 12-month period starting on the date below are: Period Commencing Redemption Price November 4, 2020 105.000% November 4, 2021 103.000% November 4, 2022 101.000% November 4, 2023 and thereafter 100.000%

Property and Equipment (Tables)

Property and Equipment (Tables)	6 Months Ended
	Jun. 30, 2017
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, 2017 December 31, 2016 (in thousands) Oil and natural gas properties, proved: Turkey $ 200,176 $ 196,743 Bulgaria 510 471 Total oil and natural gas properties, proved 200,686 197,214 Oil and natural gas properties, unproved: Turkey 30,033 21,109 Total oil and natural gas properties, unproved 30,033 21,109 Gross oil and natural gas properties 230,719 218,323 Accumulated depletion (124,460 ) (115,401 ) Net oil and natural gas properties $ 106,259 $ 102,922
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, 2017 December 31, 2016 (in thousands) Inventory $ 9,270 $ 10,704 Leasehold improvements, office equipment and software 7,603 7,280 Vehicles 365 364 Other equipment 2,026 1,925 Gross equipment and other property 19,264 20,273 Accumulated depreciation (5,771 ) (5,237 ) Net equipment and other property $ 13,493 $ 15,036

Asset Retirement obligations (T

Asset Retirement obligations (Tables)	6 Months Ended
	Jun. 30, 2017
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, 2017 and for the year ended December 31, 2016: June 30, 2017 December 31, 2016 (in thousands) Asset retirement obligations at beginning of period $ 4,833 $ 9,237 Change in estimates – (7 ) Liabilities settled (37 ) – Foreign exchange change effect 46 (1,604 ) Additions – 16 Accretion expense 95 373 Asset retirement obligations at end of period 4,937 8,015 Less: TBNG - 3,182 Long-term portion $ 4,937 $ 4,833

Commodity derivative instrume26

Commodity derivative instruments (Tables)	6 Months Ended
	Jun. 30, 2017
Derivative Instruments And Hedging Activities Disclosure [Abstract]
Fair Value of Derivative Instruments of Future Crude Oil Production	At June 30, 2017 and December 31, 2016, we had outstanding derivative 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, 2017 Average Average Quantity Minimum Maximum Price Estimated Fair Type Period (Bbl/day) Price (per Bbl) (per Bbl) Value of Asset (in thousands) Collar July 1, 2017 — December 31, 2017 293 $ 47.50 $ 61.00 $ 116 Collar July 1, 2017 — December 31, 2017 440 $ 50.00 $ 61.50 288 Collar July 1, 2017 — December 31, 2017 489 $ 47.00 $ 59.65 161 Collar January 1, 2018 — February 28, 2018 458 $ 50.00 $ 61.50 82 Collar January 1, 2018 — March 31, 2018 500 $ 47.00 $ 59.65 60 Collar January 1, 2018 — May 31, 2018 298 $ 47.50 $ 61.00 87 Total estimated fair value of asset $ 794 Fair Value of Derivative Instruments as of December 31, 2016 Weighted Weighted Average Average Quantity Minimum Maximum Price Estimated Fair Type Period (Bbl/day) Price (per Bbl) (per Bbl) Value of Liability (in thousands) Collar January 1, 2017 — December 31, 2017 296 $ 47.50 $ 61.00 $ (289 ) Collar January 2, 2017 — December 31, 2017 445 $ 50.00 $ 61.50 (307 ) Collar January 1, 2018 — February 28, 2018 458 $ 50.00 $ 61.50 (74 ) Collar January 1, 2018 — May 31, 2018 298 $ 47.50 $ 61.00 (168 ) Total estimated fair value of liability $ (838 )
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, 2017 and December 31, 2016, and (ii) the net recorded fair value as reflected on our consolidated balance sheets at June 30, 2017 and December 31, 2016. As of June 30, 2017 Gross Amount Net Amount of Gross Offset in the Assets Amount of Consolidated Presented in the Location on Consolidated Recognized Balance Consolidated Underlying Commodity Balance Sheets Assets Sheet s Balance Sheets (in thousands) Crude oil Current assets $ 794 $ - $ 794 As of December 31, 2016 Gross Amount Net Amount of Gross Offset in the Liabilities Amount of Consolidated Presented in the Location on Consolidated Recognized Balance Consolidated Underlying Commodity Balance Sheets Liabilities Sheets Balance Sheets (in thousands) Crude oil Current liabilities $ 596 $ - $ 596 Crude oil Long-term liabilities $ 242 $ - $ 242

Loans payable (Tables)

Loans payable (Tables)	6 Months Ended
	Jun. 30, 2017
Debt Disclosure [Abstract]
Debt	As of the dates indicated, our third-party debt consisted of the following: June 30, December 31, 2017 2016 Fixed and floating rate loans (in thousands) Term Loan $ 16,500 $ 25,000 2017 Notes (1) 9,450 13,500 2017 Notes - Related Party (1) 525 750 ANBE Note - 2,694 Loans payable 26,475 41,944 Less: current portion 26,475 38,194 Long-term portion $ - $ 3,750

Shareholders' equity (Tables)

Shareholders' equity (Tables)	6 Months Ended
	Jun. 30, 2017
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) 2017 2016 2017 2016 Net income (loss) from continuing operations $ 566 $ (6,544 ) $ (15,483 ) $ (12,110 ) Net loss from discontinued operations $ - $ (118 ) $ - $ (103 ) Basic net income (loss) per common share: Shares: Weighted average common shares outstanding 47,412 41,001 47,355 40,870 Basic net income (loss) per common share: Continuing operations $ 0.01 $ (0.16 ) $ (0.33 ) $ (0.30 ) Discontinued operations $ (0.00 ) $ (0.00 ) $ (0.00 ) $ (0.00 ) Diluted net income (loss) per common share: Shares: Weighted average common shares outstanding 47,412 41,001 47,355 40,870 Dilutive effect of: Restricted stock units 414 - - - Weighted average common shares outstanding 47,826 41,001 47,355 40,870 Diluted net (income) loss per common share: Continuing operations $ 0.01 $ (0.16 ) $ (0.33 ) $ (0.30 ) Discontinued operations $ (0.00 ) $ (0.00 ) $ (0.00 ) $ (0.00 )

Segment information (Tables)

Segment information (Tables)	6 Months Ended
	Jun. 30, 2017
Segment Reporting [Abstract]
Financial Information of Geographic Segments	In accordance with ASC 280, Segment Reporting Corporate Turkey Bulgaria Total (in thousands) For the three months ended June 30, 2017 Total revenues $ - $ 12,341 $ - $ 12,341 (Loss) income from continuing operations before income taxes (4,315 ) 6,163 (79 ) 1,769 Capital expenditures $ - $ 4,893 $ - $ 4,893 For the three months ended June 30, 2016 Total revenues $ - $ 17,698 $ - $ 17,698 Loss from continuing operations before income taxes (3,990 ) (567 ) (138 ) (4,695 ) Capital expenditures $ - $ 911 $ - $ 911 For the six months ended June 30, 2017 Total revenues $ - $ 28,777 $ - $ 28,777 (Loss) income from continuing operations before income taxes (23,236 ) 11,240 (149 ) (12,145 ) Capital expenditures $ - $ 11,331 $ - $ 11,331 For the six months ended June 30, 2016 Total revenues $ 33,264 $ 33,264 (Loss) income from continuing operations before income taxes (8,990 ) 679 (203 ) (8,514 ) Capital expenditures $ - $ 3,191 $ - $ 3,191 Segment assets June 30, 2017 $ 21,837 $ 146,372 $ 595 $ 168,804 December 31, 2016 (1) $ 17,007 $ 153,560 $ 609 $ 171,176 (1) Excludes assets of TBNG of $25.2 million at December 31, 2016.

Financial instruments (Tables)

Financial instruments (Tables)	6 Months Ended
	Jun. 30, 2017
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, 2017: Fair Value Measurement Classification Quoted Prices in Active Markets for Identical Assets or Significant Other Significant Liabilities Observable Inputs Unobservable Inputs (Level 1) (Level 2) (Level 3) Total (in thousands) Measured on a recurring basis Assets: Commodity derivative contracts $ – $ 794 $ – $ 794 Disclosed but not carried at fair value Liabilities: Term Loan - - (16,500 ) (16,500 ) 2017 Notes - - (9,975 ) (9,975 ) Total $ – $ 794 $ (26,475 ) $ (25,681 ) The following table summarizes the valuation of our financial assets and liabilities as of December 31, 2016: Fair Value Measurement Classification Quoted Prices in Active Markets for Identical Assets or Significant Other Significant Liabilities Observable Inputs Unobservable Inputs (Level 1) (Level 2) (Level 3) Total (in thousands) Measured on a recurring basis Liabilities: Commodity derivative contracts $ – $ (838 ) $ – $ (838 ) Disclosed but not carried at fair value Liabilities: Term Loan - - (22,500 ) (22,500 ) 2017 Notes - - (13,554 ) (13,554 ) Total $ – $ (838 ) $ (36,054 ) $ (36,892 )

Related Party Transactions (Tab

Related Party Transactions (Tables)	6 Months Ended
	Jun. 30, 2017
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, 2017 2016 (in thousands) Related party accounts receivable: Riata Management Service Agreement $ 456 $ 528 PSIL MSA 334 234 Total related party accounts receivable 790 762 Related party accounts payable: Riata Management Service Agreement $ 433 $ 346 PSIL MSA 1,671 1,315 Interest payable on 2017 Notes 34 183 Total related party accounts payable $ 2,138 $ 1,844

Assets and Liabilities Held f32

Assets and Liabilities Held for Sale and Discontinued Operations (Tables)	6 Months Ended
	Jun. 30, 2017
Discontinued Operations And Disposal Groups [Abstract]
Reclassification of Accumulated Foreign Currency Translation Adjustment Realized Into Earnings from Accumulated Other Comprehensive Loss	The loss related to the reclassification of the TBNG accumulated foreign currency translation adjustment that was realized into earnings from accumulated other comprehensive loss within shareholders’ equity. The calculation of the loss on sale is presented below: Loss on Sale (in thousands) Total cash proceeds for TBNG $ 20,707 Less: TBNG net assets 12,869 Gain on sale before accumulated foreign currency translation adjustment 7,838 Less: TBNG accumulated foreign currency translation adjustment (23,064 ) Net loss on sale of TBNG $ (15,226 )
Summary of Assets and Liabilities Held for Sale and Operating Results from Discontinued Operations	Our assets and liabilities held for sale at December 31, 2016 were as follows: Held for Sale (in thousands) For the year ended December 31, 2016 Assets Cash $ 1,551 Other current assets 7,511 Property and equipment, net 16,155 Total current assets held for sale $ 25,217 Liabilities Accounts payable and other accrued liabilities $ 11,240 Deferred tax liability 4,698 Total current liabilities held for sale $ 15,938 Our operating results from discontinued operations for the three and six months ended June 30, 2016 are summarized as follows:

General - Additional Informatio

General - Additional Information (Detail) $ in Millions	Feb. 24, 2017USD ($)	Jun. 30, 2017Segment	Aug. 07, 2017
Nature Of Business [Line Items]
Number of operating segments | Segment		2
Thrace Basin Natural Gas (Turkiye) Corporation [Member]
Nature Of Business [Line Items]
Gross proceeds on sale of ownership interests	$ 20.7
Net cash proceeds on sale of ownership interests	$ 16.1
Subsequent Event [Member]
Nature Of Business [Line Items]
Percentage of common shares owned			47.90%

Series A Preferred Shares - Add

Series A Preferred Shares - Additional Information (Detail) - 12.0% Series A Convertible Redeemable Preferred Shares [Member]	Jan. 02, 2017USD ($)	Nov. 04, 2016USD ($)Director$ / sharesshares	Jun. 30, 2017USD ($)shares	Jun. 30, 2017USD ($)shares	Dec. 31, 2016USD ($)shares
Redeemable Noncontrolling Interest [Line Items]
Preferred shares, issued		921,000	426,000	426,000	426,000
Preferred stock, dividend rate, percentage		12.00%
Convertible preferred shares issued upon conversion		45.754
Preferred stock, shares issued value per share | $ / shares		$ 50
Preferred shares, value | $			$ 21,300,000	$ 21,300,000	$ 21,300,000
Convertible preferred stock, terms of conversion				each Series A Preferred Share may be converted at any time, at the option of the holder, into 45.754 common shares of the Company (which is equal to an initial conversion price of approximately $1.0928 per common share and is subject to customary adjustments for stock splits, stock dividends, recapitalizations or other fundamental changes).
Conversion of stock, per share | $ / shares		$ 1.0928
Preferred stock redemption period end date		Nov. 4, 2024
Preferred stock redemption period start date		Nov. 4, 2020
Maximum closing sale price of common shares on conversion price		150.00%
Preferred stock, redemption description				At any time on or after November 4, 2020, we may redeem all or a portion of the Series A Preferred Shares at the redemption prices listed below (expressed as a percentage of the liquidation preference amount per share) plus accrued and unpaid dividends to the date of redemption, if the closing sale price of the common shares equals or exceeds 150% of the conversion price then in effect for at least 10 trading days (whether or not consecutive) in a period of 20 consecutive trading days, including the last trading day of such 20 trading day period, ending on, and including, the trading day immediately preceding the business day on which we issue a notice of optional redemption.
Change in control, offering redemption period		120 days
Preferred stock, dividend payment terms				Dividends on the Series A Preferred Shares are payable quarterly at our election in cash, common shares or a combination of cash and common shares at an annual dividend rate of 12.0% of the liquidation preference if paid all in cash or 16.0% of the liquidation preference if paid in common shares. If paid partially in cash and partially in common shares, the dividend rate on the cash portion is 12.0%, and the dividend rate on the common share portion is 16.0%.
Dividend payment description				Dividends are payable quarterly, on March 31, June 30, September 30, and December 31 of each year.
Cash dividend paid | $			$ 1,400,000	$ 2,800,000
Preferred stock voting rights				no voting rights
Preferred shares, outstanding			426,000	426,000	426,000
Certificate of designation description				The Certificate of Designation also provides that without the approval of the holders of a majority of the outstanding Series A Preferred Shares, we will not issue indebtedness for money borrowed or other securities which are senior to the Series A Preferred Shares in excess of the greater of (i) $100 million or (ii) 35% of our PV-10 of proved reserves as disclosed in our most recent independent reserve report filed or furnished by us on EDGAR.
Maximum amount of indebtedness for borrowed money allowed under certificate of designation | $		$ 100,000,000
PV10 reserve value percentage		35.00%
Maximum [Member]
Redeemable Noncontrolling Interest [Line Items]
Right to elect number of directors | Director		2
Minimum [Member]
Redeemable Noncontrolling Interest [Line Items]
Right to elect number of directors | Director		1
Dividend Paid in Cash [Member]
Redeemable Noncontrolling Interest [Line Items]
Preferred stock, dividend rate, percentage		12.00%
Dividend Paid in Common Shares [Member]
Redeemable Noncontrolling Interest [Line Items]
Preferred stock, dividend rate, percentage		16.00%
13.0% Convertible Notes Due 2017 [Member]
Redeemable Noncontrolling Interest [Line Items]
Preferred shares, issued		815,000
Amount of notes exchanged | $		$ 40,750,000
Debt instrument interest rate stated percentage		13.00%
Convertible preferred shares issued upon conversion		20
Value of principal amount on conversion | $		$ 1,000
Redemption of notes | $	$ 4,300,000
Certain Holders [Member] | 13.0% Convertible Notes Due 2017 [Member]
Redeemable Noncontrolling Interest [Line Items]
Preferred shares, issued		106,000
Proceeds from issuance of preferred stocks | $		$ 5,300,000
Two Director [Member]
Redeemable Noncontrolling Interest [Line Items]
Preferred shares, outstanding		400,000
One Director [Member] | Maximum [Member]
Redeemable Noncontrolling Interest [Line Items]
Preferred shares, outstanding		80,000
One Director [Member] | Minimum [Member]
Redeemable Noncontrolling Interest [Line Items]
Preferred shares, outstanding		399,999
Related Party [Member]
Redeemable Noncontrolling Interest [Line Items]
Preferred shares, issued			495,000	495,000	495,000
Preferred shares, value | $			$ 24,750,000	$ 24,750,000	$ 24,750,000
Preferred shares, outstanding			495,000	495,000	495,000

Series A Preferred Shares - Sch

Series A Preferred Shares - Schedule of Redemption Prices (Detail) - 12.0% Series A Convertible Redeemable Preferred Shares [Member]	Nov. 04, 2016
Redeemable Noncontrolling Interest [Line Items]
November 4, 2020	105.00%
November 4, 2021	103.00%
November 4, 2022	101.00%
November 4, 2023 and thereafter	100.00%

Property and Equipment - Capita

Property and Equipment - Capitalized Costs under Successful Efforts Method for Oil and Natural Gas Properties (Detail) - USD ($) $ in Thousands	Jun. 30, 2017	Dec. 31, 2016
Property Plant And Equipment [Line Items]
Oil and natural gas properties, proved	$ 200,686	$ 197,214
Oil and natural gas properties, unproved	30,033	21,109
Gross oil and natural gas properties	230,719	218,323
Accumulated depletion	(124,460)	(115,401)
Net oil and natural gas properties	106,259	102,922
Turkey [Member]
Property Plant And Equipment [Line Items]
Oil and natural gas properties, proved	200,176	196,743
Oil and natural gas properties, unproved	30,033	21,109
Bulgaria [Member]
Property Plant And Equipment [Line Items]
Oil and natural gas properties, proved	$ 510	$ 471

Property and Equipment - Additi

Property and Equipment - Additional Information (Detail) - USD ($) $ in Thousands	6 Months Ended	12 Months Ended
	Jun. 30, 2017	Dec. 31, 2016
Property Plant And Equipment [Line Items]
Proved development wells excluded from depletion	$ 200	$ 1,900
Acquisition costs of proved properties	12,700	13,200
Well costs and additional development costs	63,300	66,700
Exploratory dry hole costs	100
Inventory	3,659	3,647
Inventory [Member]
Property Plant And Equipment [Line Items]
Property plant and equipment excluded from depreciation	12,900	$ 14,400
Pinar - 1 well [Member] | Turkey [Member]
Property Plant And Equipment [Line Items]
Exploratory drilling costs capitalized	$ 3,900

Property and Equipment - Histor

Property and Equipment - Historical Cost of Equipment and Other Property on Gross Basis with Accumulated Depreciation (Detail) - USD ($) $ in Thousands	Jun. 30, 2017	Dec. 31, 2016
Property Plant And Equipment [Line Items]
Gross equipment and other property	$ 19,264	$ 20,273
Accumulated depreciation	(5,771)	(5,237)
Net equipment and other property	13,493	15,036
Inventory [Member]
Property Plant And Equipment [Line Items]
Gross equipment and other property	9,270	10,704
Leasehold improvements, office equipment and software [Member]
Property Plant And Equipment [Line Items]
Gross equipment and other property	7,603	7,280
Vehicles [Member]
Property Plant And Equipment [Line Items]
Gross equipment and other property	365	364
Other equipment [Member]
Property Plant And Equipment [Line Items]
Gross equipment and other property	$ 2,026	$ 1,925

Asset Retirement Obligations -

Asset Retirement Obligations - Changes in Asset Retirement Obligations (Detail) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016	Dec. 31, 2016
Asset Retirement Obligation Disclosure [Abstract]
Asset retirement obligations at beginning of period			$ 4,833	$ 9,237	$ 9,237
Change in estimates					(7)
Liabilities settled			(37)
Foreign exchange change effect			46		(1,604)
Additions					16
Accretion expense	$ 47	$ 96	95	$ 188	373
Asset retirement obligations at end of period	4,937		4,937		8,015
Less: TBNG					3,182
Long-term portion	$ 4,937		$ 4,937		$ 4,833

Commodity Derivative Instrume40

Commodity Derivative Instruments - Additional Information (Detail) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Derivative Instruments And Hedging Activities Disclosure [Abstract]
Gain (loss) on commodity derivative contracts	$ 676	$ (3,003)	$ 1,664	$ (2,232)

Commodity Derivative Instrume41

Commodity Derivative Instruments - Fair Value of Derivative Instruments of Future Crude Oil Production (Detail) $ in Thousands	6 Months Ended	12 Months Ended
	Jun. 30, 2017USD ($)$ / bblbbl	Dec. 31, 2016USD ($)$ / bblbbl
Derivatives Fair Value [Line Items]
Estimated Fair Value of Asset	$ 794	$ 838
Estimated Fair Value of Asset	$ (794)	$ (838)
Collar - July 1, 2017 - December 31, 2017 [Member]
Derivatives Fair Value [Line Items]
Quantity (Bbl/day) | bbl	293	296
Collars Average Minimum Price (per Bbl) | $ / bbl	47.50	47.50
Average Maximum Price (per Bbl) | $ / bbl	61	61
Estimated Fair Value of Asset	$ 116	$ 289
Estimated Fair Value of Asset	$ (116)	$ (289)
Collar - July 1, 2017 - December 31, 2017 [Member]
Derivatives Fair Value [Line Items]
Quantity (Bbl/day) | bbl	440
Collars Average Minimum Price (per Bbl) | $ / bbl	50
Average Maximum Price (per Bbl) | $ / bbl	61.50
Estimated Fair Value of Asset	$ 288
Estimated Fair Value of Asset	$ (288)
Collar - July 1, 2017 - December 31, 2017 [Member]
Derivatives Fair Value [Line Items]
Quantity (Bbl/day) | bbl	489
Collars Average Minimum Price (per Bbl) | $ / bbl	47
Average Maximum Price (per Bbl) | $ / bbl	59.65
Estimated Fair Value of Asset	$ 161
Estimated Fair Value of Asset	$ (161)
Collar - January 1, 2018 - February 28, 2018 [Member]
Derivatives Fair Value [Line Items]
Quantity (Bbl/day) | bbl	458	458
Collars Average Minimum Price (per Bbl) | $ / bbl	50	50
Average Maximum Price (per Bbl) | $ / bbl	61.50	61.50
Estimated Fair Value of Asset	$ 82	$ 74
Estimated Fair Value of Asset	$ (82)	$ (74)
Collar - January 1, 2018 - March 31, 2018 [Member]
Derivatives Fair Value [Line Items]
Quantity (Bbl/day) | bbl	500
Collars Average Minimum Price (per Bbl) | $ / bbl	47
Average Maximum Price (per Bbl) | $ / bbl	59.65
Estimated Fair Value of Asset	$ 60
Estimated Fair Value of Asset	$ (60)
Collar - January 1, 2018 - May 31, 2018 [Member]
Derivatives Fair Value [Line Items]
Quantity (Bbl/day) | bbl	298	298
Collars Average Minimum Price (per Bbl) | $ / bbl	47.50	47.50
Average Maximum Price (per Bbl) | $ / bbl	61	61
Estimated Fair Value of Asset	$ 87	$ 168
Estimated Fair Value of Asset	$ (87)	$ (168)
Collar - January 2, 2017 - December 31, 2017 [Member]
Derivatives Fair Value [Line Items]
Quantity (Bbl/day) | bbl		445
Collars Average Minimum Price (per Bbl) | $ / bbl		50
Average Maximum Price (per Bbl) | $ / bbl		61.50
Estimated Fair Value of Asset		$ 307
Estimated Fair Value of Asset		$ (307)

Commodity Derivative Instrume42

Commodity Derivative Instruments - Summary of Gross Fair Value of Commodity Derivative Instruments by Balance Sheet Classification (Detail) - USD ($) $ in Thousands	Jun. 30, 2017	Dec. 31, 2016
Derivatives Fair Value [Line Items]
Gross Amount of Recognized Assets	$ 794	$ 838
Net Amount of Assets Presented in the Consolidated Balance Sheet, Current assets	794
Net Amount of Liabilities Presented in the Consolidated Balance Sheet, Current liabilities		596
Net Amount of Liabilities Presented in the Consolidated Balance Sheet, Long-term liabilities		242
Crude Oil [Member] | Current Assets [Member]
Derivatives Fair Value [Line Items]
Gross Amount of Recognized Assets	$ 794
Crude Oil [Member] | Current Liabilities [Member]
Derivatives Fair Value [Line Items]
Gross Amount of Recognized Liabilities		596
Crude Oil [Member] | Long Term Liabilities [Member]
Derivatives Fair Value [Line Items]
Gross Amount of Recognized Liabilities		$ 242

Loans Payable - Debt (Detail)

Loans Payable - Debt (Detail) - USD ($) $ in Thousands		Jun. 30, 2017	Dec. 31, 2016
Debt Instrument [Line Items]
Loans payable		$ 26,475	$ 41,944
Less: current portion		26,475	38,194
Long-term portion			3,750
Term Loan [Member]
Debt Instrument [Line Items]
Loans payable		16,500	25,000
13.0% Convertible Notes Due 2017 [Member] | Convertible Debt [Member]
Debt Instrument [Line Items]
Loans payable	[1]	9,450	13,500
ANBE Note [Member]
Debt Instrument [Line Items]
Loans payable			2,694
Related Party [Member] | 13.0% Convertible Notes Due 2017 [Member] | Convertible Debt [Member]
Debt Instrument [Line Items]
Loans payable	[1]	$ 525	$ 750
[1]	The 2017 Notes matured on July 1, 2017, and on July 3, 2017, we paid off and retired all remaining outstanding 2017 Notes.

Loans Payable - Additional Info

Loans Payable - Additional Information (Detail) - USD ($)		Apr. 27, 2017	Sep. 07, 2016	Jun. 30, 2017	Dec. 31, 2016	Aug. 31, 2016	Dec. 30, 2015
Line Of Credit Facility [Line Items]
Loans payable				$ 26,475,000	$ 41,944,000
Debt instrument, paid off and retired date				Jul. 3, 2017
Convertible Debt [Member]
Line Of Credit Facility [Line Items]
Notes payable				$ 10,000,000
Non-cash Facilities [Member] | DenizBank [Member]
Line Of Credit Facility [Line Items]
Line Of Credit Facility Maximum Borrowing Capacity						$ 20,000,000
TEMI Term Loan [Member]
Line Of Credit Facility [Line Items]
Debt instrument interest rate stated percentage				5.25%
Debt instrument interest rate basis for effective rate				The Term Loan bears interest at a fixed rate of 5.25% (plus 0.2625% for Banking and Insurance Transactions Tax per the Turkish government)
Loans payable				$ 16,500,000	25,000,000
TEMI Term Loan [Member] | Turkish Banking and Insurance Transactions Tax Rate [Member]
Line Of Credit Facility [Line Items]
Debt instrument basis spread on variable rate				0.2625%
TEMI Term Loan [Member] | Credit Agreement [Member] | DenizBank [Member]
Line Of Credit Facility [Line Items]
Line of credit facility, initiation date				Aug. 31, 2016
Line Of Credit Facility Maximum Borrowing Capacity						$ 30,000,000
Line of credit facility, expiration date		Jun. 30, 2018
Debt instrument, monthly payments		$ 1,380,000		$ 1,880,000
TEMI Term Loan [Member] | Line of Credit [Member]
Line Of Credit Facility [Line Items]
Loans payable				$ 16,500,000
Senior Credit Facility [Member] | BNP Paribas and IFC [Member]
Line Of Credit Facility [Line Items]
Line of credit facility, repayment			$ 22,900,000
13.0% Convertible Notes Due 2017 [Member] | Convertible Debt [Member]
Line Of Credit Facility [Line Items]
Debt instrument interest rate stated percentage				13.00%
Loans payable	[1]			$ 9,450,000	13,500,000
Frequency of payments				semi-annually
Debt instrument, maturity date				Jul. 1, 2017
ANBE Note [Member]
Line Of Credit Facility [Line Items]
Loans payable					$ 2,694,000
ANBE Note [Member] | TransAtlantic USA [Member] | Convertible Promissory Note [Member]
Line Of Credit Facility [Line Items]
Line Of Credit Facility Maximum Borrowing Capacity							$ 5,000,000
Debt instrument interest rate stated percentage							13.00%
Line of credit facility borrowing capacity							$ 3,600,000
Unsecured lines of credit [Member]
Line Of Credit Facility [Line Items]
Loans payable				$ 0
Turkey [Member] | TEMI Term Loan [Member] | Credit Agreement [Member] | DenizBank [Member]
Line Of Credit Facility [Line Items]
Line of credit facility, initiation date				Aug. 23, 2016
[1]	The 2017 Notes matured on July 1, 2017, and on July 3, 2017, we paid off and retired all remaining outstanding 2017 Notes.

Contingencies Relating to Pro45

Contingencies Relating to Production Leases and Exploration Permits - Additional Information (Detail) - USD ($)	1 Months Ended	3 Months Ended		6 Months Ended		12 Months Ended
	Feb. 28, 2013	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016	Dec. 31, 2012	Sep. 30, 2016	Oct. 31, 2015
Loss Contingencies [Line Items]
General and administrative		$ 3,181,000	$ 3,899,000	$ 6,771,000	$ 8,742,000
Morocco [Member] | Government [Member]
Loss Contingencies [Line Items]
Recovery of contractual obligations						$ 5,500,000
Bank guarantee	$ 1,000,000
Accrued liabilities relating to our Tselfat exploration permit						5,000,000
Reversed amount in contingent liabilities previously classified as liabilities held for sale							$ 6,000,000
Bulgaria [Member]
Loss Contingencies [Line Items]
Recovery of contractual obligations						2,000,000
Estimated Litigation Liability								$ 200,000
Bulgaria [Member] | Aglen Exploration Permit Work Program [Member]
Loss Contingencies [Line Items]
General and administrative						$ 2,000,000

Shareholders' Equity - Addition

Shareholders' Equity - Additional Information (Detail) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Employee Service Share Based Compensation Allocation Of Recognized Period Costs [Line Items]
Dilutive securities included in the calculation of diluted earnings per share	414,000
Restricted Stock Units [Member]
Employee Service Share Based Compensation Allocation Of Recognized Period Costs [Line Items]
Share-based compensation expense	$ 0.3	$ 0.2	$ 0.4	$ 0.4
Unrecognized compensation expense	$ 0.6		$ 0.6
Unrecognized compensation expense recognition period			1 year
Dilutive securities included in the calculation of diluted earnings per share	413,997

Shareholders' Equity - Basic an

Shareholders' Equity - Basic and Diluted Earnings Per Common Share Computations (Detail) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Equity [Abstract]
Net loss from continuing operations	$ 566	$ (6,544)	$ (15,483)	$ (12,110)
Net loss from discontinued operations		$ (118)		$ (103)
Weighted average common shares outstanding	47,412	41,001	47,355	40,870
Continuing operations	$ 0.01	$ (0.16)	$ (0.33)	$ (0.30)
Discontinued operations	$ 0	$ 0	$ 0	$ 0
Dilutive securities included in the calculation of diluted earnings per share	414
Weighted average common shares outstanding	47,826	41,001	47,355	40,870
Continuing operations	$ 0.01	$ (0.16)	$ (0.33)	$ (0.30)
Discontinued operations	$ 0	$ 0	$ 0	$ 0

Segment Information - Additiona

Segment Information - Additional Information (Detail)	6 Months Ended
	Jun. 30, 2017Segment
Segment Reporting [Abstract]
Number of reportable geographic segments	2

Segment Information - Financial

Segment Information - Financial Information of Geographic Segments (Detail) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016	Dec. 31, 2016	[1]
Segment Reporting Information [Line Items]
Total revenues	$ 12,341	$ 17,698	$ 28,777	$ 33,264
(Loss) income from continuing operations before income taxes	1,769	(4,695)	(12,145)	(8,514)
Capital expenditures	4,893	911	11,331	3,191
Segment assets	168,804		168,804		$ 171,176
Corporate, Non-Segment [Member]
Segment Reporting Information [Line Items]
(Loss) income from continuing operations before income taxes	(4,315)	(3,990)	(23,236)	(8,990)
Segment assets	21,837		21,837		17,007
Operating Segments [Member] | Turkey [Member]
Segment Reporting Information [Line Items]
Total revenues	12,341	17,698	28,777	33,264
(Loss) income from continuing operations before income taxes	6,163	(567)	11,240	679
Capital expenditures	4,893	911	11,331	3,191
Segment assets	146,372		146,372		153,560
Operating Segments [Member] | Bulgaria [Member]
Segment Reporting Information [Line Items]
(Loss) income from continuing operations before income taxes	(79)	$ (138)	(149)	$ (203)
Segment assets	$ 595		$ 595		$ 609
[1]	Excludes assets of TBNG of $25.2 million at December 31, 2016.

Segment Information - Financi50

Segment Information - Financial Information of Geographic Segments (Parenthetical) (Detail) - USD ($)	Jun. 30, 2017	Dec. 31, 2016
Segment Reporting [Abstract]
Assets from discontinued operations and services	$ 0	$ 25,200,000

Financial Instruments - Additio

Financial Instruments - Additional Information (Detail) - 6 months ended Jun. 30, 2017 TRY in Millions, $ in Millions	USD ($)Institution	TRY
Financial Statement Line Items With Differences In Reported Amount And Reporting Currency Denominated Amounts [Line Items]
Currency risk descriptions	We have underlying foreign currency exchange rate exposure. Our currency exposures relate to transactions denominated in the Bulgarian Lev, European Union Euro, and Turkish Lira (“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, 2017, we had 9.9 million TRY (approximately $2.8 million) in cash and cash equivalents, which exposes us to exchange rate risk based on fluctuations in the value of the TRY.
Number of financial institutions	3
Cash and cash equivalents [Member]
Financial Statement Line Items With Differences In Reported Amount And Reporting Currency Denominated Amounts [Line Items]
Cash and cash equivalents	$ 2.8	TRY 9.9

Financial Instruments - Valuati

Financial Instruments - Valuation of Financial Assets and Liabilities (Detail) - USD ($) $ in Thousands	Jun. 30, 2017	Dec. 31, 2016
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Assets (liabilities), fair value	$ (25,681)	$ (36,892)
Disclosed but not carried at fair value [Member] | TEMI Term Loan [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Liabilities, fair value	(16,500)	(22,500)
Disclosed but not carried at fair value [Member] | 2017 Notes [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Liabilities, fair value	(9,975)	(13,554)
Measured on a recurring basis [Member] | Derivative Financial Instruments (commodity) [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Assets, fair value	794
Liabilities, fair value		(838)
Significant Other Observable Inputs (Level 2) [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Assets (liabilities), fair value	794	(838)
Significant Other Observable Inputs (Level 2) [Member] | Measured on a recurring basis [Member] | Derivative Financial Instruments (commodity) [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Assets, fair value	794
Liabilities, fair value		(838)
Significant Unobservable Inputs (Level 3) [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Assets (liabilities), fair value	(26,475)	(36,054)
Significant Unobservable Inputs (Level 3) [Member] | Disclosed but not carried at fair value [Member] | TEMI Term Loan [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Liabilities, fair value	(16,500)	(22,500)
Significant Unobservable Inputs (Level 3) [Member] | Disclosed but not carried at fair value [Member] | 2017 Notes [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Liabilities, fair value	$ (9,975)	$ (13,554)

Related Party Transactions - Re

Related Party Transactions - Related Party Accounts Receivable and Accounts Payable (Detail) - USD ($) $ in Thousands	Jun. 30, 2017	Dec. 31, 2016
Related Party Transaction [Line Items]
Total related party accounts receivable	$ 790	$ 762
Total related party accounts payable	2,138	1,844
Riata Management Service Agreement [Member]
Related Party Transaction [Line Items]
Total related party accounts receivable	456	528
Total related party accounts payable	433	346
PSIL MSA [Member]
Related Party Transaction [Line Items]
Total related party accounts receivable	334	234
Total related party accounts payable	1,671	1,315
Interest Payable on 2017 Notes [Member]
Related Party Transaction [Line Items]
Total related party accounts payable	$ 34	$ 183

Related Party Transactions - Ad

Related Party Transactions - Additional Information (Detail)	Jun. 26, 2017ft²Period	Nov. 04, 2016USD ($)shares	Apr. 19, 2016USD ($)	Jun. 30, 2017USD ($)	Jun. 30, 2017USD ($)	Dec. 31, 2016USD ($)	Aug. 31, 2016USD ($)	Jun. 13, 2012USD ($)
Related Party Transaction [Line Items]
Related parties outstanding receivables				$ 790,000	$ 790,000	$ 762,000
Related parties outstanding payables				2,138,000	2,138,000	1,844,000
Note receivable - related party				7,185,000	7,185,000	7,624,000		$ 11,500,000
Dalea and Funds [Member] | 13.0% Convertible Notes Due 2017 [Member] | Series A Preferred Stock [Member]
Related Party Transaction [Line Items]
Value of principal amount on conversion		$ 2,000,000
Convertible preferred shares issued upon conversion | shares		40,000
Repayments of debt				100,000	200,000
Riata Management Service Agreement [Member]
Related Party Transaction [Line Items]
Related parties outstanding receivables				456,000	456,000	528,000
Related parties outstanding payables				433,000	433,000	346,000
PSIL MSA [Member]
Related Party Transaction [Line Items]
Related parties outstanding receivables				334,000	334,000	234,000
Related parties outstanding payables				1,671,000	1,671,000	$ 1,315,000
Joint Venture [Member] | Promissory Note [Member] | Dalea and Funds [Member]
Related Party Transaction [Line Items]
Note receivable - related party			$ 7,964,053
Cancellation of purchase price in promissory note			$ 3,500,000
Debt instrument, maturity date			Jun. 13, 2019
Debt instrument interest rate stated percentage			3.00%
Promissory note, collateral amount			$ 2,100,000
Dalea Promissory Note [Member]
Related Party Transaction [Line Items]
Promissory notes default remedy period			30 days
Dalea Promissory Note [Member] | Maximum [Member]
Related Party Transaction [Line Items]
Noncontrolling equity voting interest percentage			50.00%
Gundem Fee Agreement [Member] | Gundem Real Estate [Member]
Related Party Transaction [Line Items]
Debt instrument interest rate stated percentage							5.00%
Promissory note, collateral amount							$ 10,000,000
Gundem Fee Agreement [Member] | Muratli Real Estate [Member]
Related Party Transaction [Line Items]
Debt instrument interest rate stated percentage							5.00%
Promissory note, collateral amount							$ 5,000,000
Diyarbakir Fee Agreement [Member] | Diyarbakir Real Estate [Member]
Related Party Transaction [Line Items]
Debt instrument interest rate stated percentage							5.00%
Promissory note, collateral amount							$ 5,000,000
Gundem Fee Agreement and the Diyarbakir Fee Agreement [Member]
Related Party Transaction [Line Items]
Decrease in principal amount of Amended Note				200,000	$ 300,000
Longfellow [Member] | TransAtlantic USA [Member]
Related Party Transaction [Line Items]
Office lease space | ft²	10,000
Office lease commencement date					Jan. 1, 2017
Office lease expiration period from commencement date	5 years
Office lease number of extendable period | Period	2
Office lease each extendable period	5 years
Office lease monthly rent payable during first five months				14,745.16	$ 14,745.16
Office lease monthly rent payable increase from sixth month.				2,754.84	2,754.84
Office lease monthly rent payable increase from second year				833.33	833.33
Office lease monthly rent payable increase from year three and thereafter				$ 417	$ 417

Assets and Liabilities Held f55

Assets and Liabilities Held for Sale and Discontinued Operations - Additional Information (Detail) - USD ($)	Apr. 10, 2017	Feb. 24, 2017	Jun. 30, 2017	Aug. 09, 2017	Dec. 31, 2016	Sep. 01, 2016
Discontinued Operations And Disposal Groups [Line Items]
Gross proceeds on sale of ownership interests			$ 17,779,000
Purchase price reduction amount		$ 200,000
Proceeds from escrow funds	$ 2,900,000
Loss on sale of TBNG			15,226,000
Assets held for sale			0		$ 25,200,000
Liabilities held for sale			$ 0
Delvina Gas Company Ltd [Member] | Subsequent Event [Member]
Discontinued Operations And Disposal Groups [Line Items]
Percentage of outstanding shares transferred				25.00%
Payment receivable in exchange for transfer of outstanding shares				$ 300,000
Albania [Member] | Delvina Gas Company Ltd [Member]
Discontinued Operations And Disposal Groups [Line Items]
Percentage of outstanding shares transferred						75.00%
Payment receivable in exchange for transfer of outstanding shares						$ 12,000,000
Disposal group discontinued operation percentage of operating costs payment			25.00%
Percentage of ownership interest in assets held for sale, no longer hold			25.00%
Thrace Basin Natural Gas (Turkiye) Corporation [Member]
Discontinued Operations And Disposal Groups [Line Items]
Gross proceeds on sale of ownership interests		20,700,000
Net cash proceeds on sale of ownership interests		16,100,000
Escrow deposit		$ 3,100,000

Assets and Liabilities Held f56

Assets and Liabilities Held for Sale and Discontinued Operations - Reclassification of Accumulated Foreign Currency Translation Adjustment Realized Into Earnings from Accumulated Other Comprehensive Loss (Detail) $ in Thousands	6 Months Ended
	Jun. 30, 2017USD ($)
Discontinued Operations And Disposal Groups [Line Items]
Total cash proceeds for TBNG	$ 17,779
Thrace Basin Natural Gas (Turkiye) Corporation [Member]
Discontinued Operations And Disposal Groups [Line Items]
Total cash proceeds for TBNG	20,707
Less: TBNG net assets	12,869
Gain on sale before accumulated foreign currency translation adjustment	7,838
Less: TBNG accumulated foreign currency translation adjustment	(23,064)
Net loss on sale of TBNG	$ (15,226)

Assets and Liabilities Held f57

Assets and Liabilities Held for Sale and Discontinued Operations - Assets and Liabilities Held for Sale (Detail) $ in Thousands	Dec. 31, 2016USD ($)
Assets
Total current assets held for sale	$ 25,217
TBNG [Member]
Assets
Cash	1,551
Other current assets	7,511
Property and equipment, net	16,155
Total current assets held for sale	25,217
Liabilities
Accounts payable and other accrued liabilities	11,240
Deferred tax liability	4,698
Total current liabilities held for sale	$ 15,938

Assets and Liabilities Held f58

Assets and Liabilities Held for Sale and Discontinued Operations - Operating Results from Discontinued Operations (Detail) - USD ($) $ in Thousands	3 Months Ended	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2016
Discontinued Operations And Disposal Groups [Abstract]
Total revenues		$ 626
Production and transportation expense		1,155
Total other costs and expenses	$ 118	527
Loss before income taxes	(118)	(1,056)
Gain on disposal of discontinued operations		749
Income tax benefit		204
Net loss from discontinued operations	$ (118)	$ (103)

Subsequent Events - Additional

Subsequent Events - Additional Information (Detail) - USD ($)	6 Months Ended
	Jun. 30, 2017	Aug. 09, 2017
Subsequent Event [Line Items]
Debt instrument, paid off and retired date	Jul. 3, 2017
Delvina Gas Company Ltd [Member] | Subsequent Event [Member]
Subsequent Event [Line Items]
Percentage of outstanding shares transferred		25.00%
Payment receivable in exchange for transfer of outstanding shares		$ 300,000