TransAtlantic Petroleum (TAT) 10-K 22 Mar 17 2016 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Mar. 17, 2017	Jun. 30, 2016
Document And Entity Information [Abstract]
Document Type	10-K
Amendment Flag	false
Document Period End Date	Dec. 31, 2016
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	FY
Trading Symbol	TAT
Entity Registrant Name	TRANSATLANTIC PETROLEUM LTD.
Entity Central Index Key	1,092,289
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	No
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Filer Category	Smaller Reporting Company
Entity Common Stock, Shares Outstanding		47,312,231
Entity Public Float			$ 22.3

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Current assets:
Cash and cash equivalents	$ 10,034	$ 5,700
Restricted cash	2,555	3,758
Accounts receivable, net
Oil and natural gas sales	17,885	10,300
Joint interest and other	3,230	2,548
Related party	762	408
Prepaid and other current assets	4,756	2,063
Derivative asset		3,235
Inventory	3,647
Assets held for sale	25,217	61,247
Total current assets	68,086	89,259
Oil and natural gas properties (successful efforts method)
Proved	197,214	233,143
Unproved	21,109	25,630
Equipment and other property	20,273	32,173
Property and equipment, gross	238,596	290,946
Less accumulated depreciation, depletion and amortization	(120,638)	(122,533)
Property and equipment, net	117,958	168,413
Other long-term assets:
Other assets	2,725	1,455
Note receivable - related party	7,624	11,500
Derivative asset		3,370
Assets held for sale		24,192
Total other assets	10,349	40,517
Total assets	196,393	298,189
Current liabilities:
Accounts payable	7,036	6,159
Accounts payable - related party	1,844	2,553
Accrued liabilities	12,492	8,366
Derivative liability	596
Loans payable	35,000	31,874
Loan payable - related party	3,194	3,593
Liabilities held for sale - related party		3,671
Liabilities held for sale	15,938	79,514
Total current liabilities	76,100	135,730
Long-term liabilities:
Asset retirement obligations	4,833	5,521
Accrued liabilities	8,126	10,908
Deferred income taxes	18,806	22,603
Loans payable	3,750	34,400
Derivative liability	242
Loan payable - related party		20,600
Liabilities held for sale		9,505
Total long-term liabilities	35,757	103,537
Total liabilities	111,857	239,267
Commitments and contingencies
Shareholders' equity:
Common shares, $0.10 par value, 100,000,000 shares authorized; 47,220,525 shares and 41,017,777 shares issued and outstanding as of December 31, 2016 and December 31, 2015, respectively	4,722	4,102
Treasury stock	(970)	(970)
Additional paid-in-capital	573,278	569,365
Accumulated other comprehensive loss	(140,316)	(121,590)
Accumulated deficit	(398,228)	(391,985)
Total shareholders' equity	38,486	58,922
Total liabilities, Series A preferred shares and shareholders' equity	196,393	$ 298,189
Series A Preferred Shares [Member]
Long-term liabilities:
Preferred shares, value	25,500
Related Party [Member] | Series A Preferred Shares [Member]
Long-term liabilities:
Preferred shares, value	$ 20,550

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - $ / shares	Dec. 31, 2016	Dec. 31, 2015
Common shares, par value	$ 0.10	$ 0.10
Common shares, authorized	100,000,000	100,000,000
Common shares, issued	47,220,525	41,017,777
Common shares, outstanding	47,220,525	41,017,777
Series A Preferred Shares [Member]
Preferred shares, par value	$ 0.10
Preferred shares, authorized	510,000
Preferred shares, issued	510,000
Preferred shares, outstanding	510,000
Preferred shares, liquidation preference per share	$ 50
Related Party [Member] | Series A Preferred Shares [Member]
Preferred shares, par value	$ 0.10
Preferred shares, authorized	411,000
Preferred shares, issued	411,000
Preferred shares, outstanding	411,000
Preferred shares, liquidation preference per share	$ 50

Consolidated Statements of Comp

Consolidated Statements of Comprehensive Income (Loss) - USD ($) shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Revenues:
Oil and natural gas sales	$ 63,424	$ 82,716	$ 136,276
Sales of purchased natural gas	5,038	2,189	2,127
Other	133	159	427
Total revenues	68,595	85,064	138,830
Costs and expenses:
Production	12,368	12,873	18,193
Exploration, abandonment and impairment	5,963	21,544	19,864
Cost of purchased natural gas	4,418	2,082	2,055
Seismic and other exploration	104	370	4,285
Revaluation of contingent consideration			(2,500)
General and administrative	16,320	24,138	31,071
Depreciation, depletion and amortization	29,025	37,707	48,594
Accretion of asset retirement obligations	373	368	406
Total costs and expenses	68,571	99,082	121,968
Operating (loss) income	24	(14,018)	16,862
Other income (expense):
Interest and other expense	(11,841)	(13,077)	(6,044)
Interest and other income	2,546	855	1,124
(Loss) gain on commodity derivative contracts	(3,257)	27,457	37,454
Foreign exchange loss	(3,871)	(5,653)	(6,523)
Total other income (expense)	(16,423)	9,582	26,011
Income (loss) from continuing operations before income taxes	(16,399)	(4,436)	42,873
Current income tax expense	(6,071)	(3,587)	(1,784)
Deferred income tax benefit (expense)	(25)	18,642	11,875
Net (loss) income from continuing operations	(22,445)	(26,665)	29,214
Income (loss) from discontinued operations before income taxes	15,998	(97,042)	(750)
Income tax benefit	204	16,169	612
Net income (loss) from discontinued operations	16,202	(80,873)	(138)
Net (loss) income	(6,243)	(107,538)	29,076
Other comprehensive (loss) income:
Foreign currency translation adjustment	(18,726)	(42,280)	(14,325)
Comprehensive (loss) income	$ (24,969)	$ (149,818)	$ 14,751
Basic net income (loss) per common share
Continuing operations	$ (0.51)	$ (0.65)	$ 0.77
Discontinued operations	$ 0.37	$ (1.98)
Weighted average common shares outstanding	43,885	40,841	37,829
Diluted net income (loss) per common share
Continuing operations	$ (0.51)	$ (0.65)	$ 0.77
Discontinued operations	$ 0.37	$ (1.98)
Weighted average common and common equivalent shares outstanding	43,885	40,841	38,031

Consolidated Statements of Equi

Consolidated Statements of Equity - USD ($) $ in Thousands	Total	Common Shares [Member]	Treasury Stock [Member]	Warrants [Member]	Additional Paid-in Capital [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	Accumulated Deficit [Member]
Beginning balance at Dec. 31, 2013	$ 167,317	$ 3,734			$ 542,091	$ (64,985)	$ (313,523)
Beginning balance, shares at Dec. 31, 2013		37,340,000
Issuance of common shares	23,850	$ 322			23,528
Issuance of common shares (in shares)		3,219,000
Contingent payment event	4,188				4,188
Issuance of warrants				$ 233
Issuance of restricted stock units		$ 15			(15)
Issuance of restricted stock units, shares		149,000
Tax withholding on restricted stock units	(76)				(76)
Share-based compensation	1,434				1,434
Foreign currency translation adjustment	(14,325)					(14,325)
Net income (loss)	29,076						29,076
Ending balance at Dec. 31, 2014	211,464	$ 4,071		233	571,150	(79,310)	(284,447)
Ending balance, shares at Dec. 31, 2014		40,708,000
Contingent payment event	(4,188)				(4,188)
Issuance of warrants				466
Issuance of restricted stock units	1,137	$ 31			1,106
Issuance of restricted stock units, shares		310,000
Tax withholding on restricted stock units	(391)				(391)
Repurchase of treasury stock	(970)		$ (970)
Repurchase of treasury stock, shares			333,000
Share-based compensation	1,688				1,688
Foreign currency translation adjustment	(42,280)					(42,280)
Net income (loss)	(107,538)						(107,538)
Ending balance at Dec. 31, 2015	$ 58,922	$ 4,102	$ (970)	699	569,365	(121,590)	(391,985)
Ending balance, shares at Dec. 31, 2015	41,017,777	41,018,000	333,000
Issuance of common shares	$ 3,970	$ 600			3,370
Issuance of common shares (in shares)		5,998,000
Issuance of restricted stock units		$ 20			(20)
Issuance of restricted stock units, shares		204,000
Tax withholding on restricted stock units	(66)				(66)
Share-based compensation	629				629
Foreign currency translation adjustment	(18,726)					(18,726)
Net income (loss)	(6,243)						(6,243)
Ending balance at Dec. 31, 2016	$ 38,486	$ 4,722	$ (970)	$ 699	$ 573,278	$ (140,316)	$ (398,228)
Ending balance, shares at Dec. 31, 2016	47,220,525	47,220,000	333,000

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2016		Dec. 31, 2015		Dec. 31, 2014
Operating activities:
Net (loss) income		$ (6,243)		$ (107,538)		$ 29,076
Adjustment for net (income) loss from discontinued operations		(16,202)		80,873		138
Net (loss) income from continuing operations		(22,445)		(26,665)		29,214
Adjustments to reconcile net income to net cash provided by operating activities:
Share-based compensation		629		1,688		1,434
Foreign currency loss		3,091		5,910		6,448
Loss (gain) on commodity derivative contracts		3,257		(27,457)		(37,454)
Cash settlement on commodity derivative contracts		4,188		57,076		(2,100)
Amortization on loan financing costs		1,201		1,677		1,025
Bad debt expense				422		1,487
Deferred income tax (benefit) expense		(25)		18,642		11,875
Exploration, abandonment and impairment		5,963		21,544		19,864
Depreciation, depletion and amortization		29,025		37,707		48,594
Accretion of asset retirement obligations		373		368		406
Gain on sale of gas gathering facility		(620)
Derivative put costs				(4,638)
Revaluation of contingent consideration						(2,500)
Changes in operating assets and liabilities:
Accounts receivable		(8,180)		18,274		(3,326)
Prepaid expenses and other assets		(4,040)		1,341		(1,777)
Accounts payable and accrued liabilities		8,936		(19,380)		4,734
Net cash provided by operating activities from continuing operations		21,353		86,509		77,924
Net cash provided by (used in) operating activities from discontinued operations		220		(14,483)		(264)
Net cash provided by operating activities		21,573		72,026		77,660
Investing activities:
Acquisitions, net of cash						66
Additions to oil and natural gas properties		(9,512)		(22,843)		(107,353)
Additions to equipment and other properties		(1,204)		(3,572)		(6,318)
Proceeds from asset sale		1,104
Restricted cash		1,094		(5,261)		(1,917)
Net cash used in investing activities from continuing operations		(8,518)		(31,676)		(115,522)
Net cash used in investing activities from discontinued operations				(12,329)		(1,174)
Net cash used in investing activities		(8,518)		(44,005)		(116,696)
Financing activities:
Issuance of common shares		1,658
Issuance of Series A Preferred Shares		5,300
Tax withholding on restricted share units		(66)		(391)		(76)
Treasury stock purchases				(970)
Loan proceeds		33,778		12,378		73,237
Loan proceeds - related party				3,593		20,800
Loan repayment		(47,123)		(54,834)		(28,096)
Loan repayment - related party		(898)
Loan financing costs				(30)		(2,630)
Net cash (used in) provided by financing activities from continuing operations		(7,351)		(40,254)		63,235
Net cash used in financing activities from discontinued operations				(13,709)		(1,674)
Net cash (used in) provided by financing activities		(7,351)		(53,963)		61,561
Effect of exchange rate on cash flows and cash equivalents		(1,599)		(1,318)		(666)
Net increase (decrease) in cash and cash equivalents		4,105		(27,260)		21,859
Cash and cash equivalents, beginning of year		7,480	[1]	34,740	[1]	12,881
Cash and cash equivalents, end of year	[1]	11,585		7,480		34,740
Supplemental disclosures:
Cash paid for interest		6,576		9,522		3,490
Cash paid for taxes		4,842		3,044
Supplemental non-cash financing activities:
Repayment of the Prepayment Agreement				3,043
Contingent payment event				$ (4,188)		4,188
Common Shares [Member]
Supplemental non-cash financing activities:
Issuance of shares		2,312				$ 23,850
Series A Preferred Shares [Member]
Supplemental non-cash financing activities:
Issuance of shares		$ 40,750
[1]	Includes TBNG cash held for sale of $1.6 million and $1.8 million at December 31, 2016 and 2015, respectively.

Consolidated Statements of Cas7

Consolidated Statements of Cash Flows (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Thrace Basin Natural Gas (Turkiye) Corporation [Member]
Cash held for sale	$ 1.6	$ 1.8

General

General	12 Months Ended
	Dec. 31, 2016
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, have stable governments, are net importers of petroleum, have an existing petroleum transportation infrastructure and provide favorable commodity pricing, royalty rates and tax rates to exploration and production companies. We hold interests in developed and undeveloped oil and natural gas properties in Turkey and Bulgaria and an operated interest in a joint venture in Albania. As of March 17, 2017, approximately 47% 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 and an operated interest in a joint venture in Albania. Basis of presentation Our consolidated financial statements are expressed in U.S. Dollars and have been prepared by management in accordance with accounting principles generally accepted in the United States (“U.S. GAAP”). All amounts in these notes to the consolidated financial statements are in U.S. Dollars unless otherwise indicated. In preparing financial statements, management makes informed judgments and estimates that affect the reported amounts of assets and liabilities as of the date of the financial statements and affect the reported amounts of revenues and expenses during the reporting period. On an ongoing basis, management reviews estimates, including those related to fair value measurements associated with acquisitions and financial derivatives, the recoverability and impairment of long-lived assets, contingencies and income taxes. Changes in facts and circumstances may result in revised estimates and actual results may differ from these estimates.

Financial Restructuring and Eli

Financial Restructuring and Elimination of Going Concern Assumption	12 Months Ended
	Dec. 31, 2016
Financial Restructuring And Elimination Of Going Concern Assumption [Abstract]
Financial Restructuring and Elimination of Going Concern Assumption	2. Financial Restructuring and Elimination of Going Concern Assumption During 2016, we focused on several transactions to deleverage our balance sheet, repay our defaulted senior credit facility (the “Senior Credit Facility”) with BNP Paribas (Suisse) SA (“BNP”) and the International Finance Corporation (“IFC”) (see Note 9, “Loans Payable”), obtain new debt financing (see Note 9, “Loans Payable”), raise cash from asset sales (see Notes 17 & 18, “Assets and liabilities held for sale and discontinued operations” and “Subsequent events”, respectively) and refinance our 13.0% Senior Convertible Notes due 2017 (the “2017 Notes”) (see Note 5, “Series A Preferred Shares”). At December 31, 2015, we had $55.0 million in long-term debt, $35.5 million in short-term, $5.7 million in cash and a $24.5 million working capital deficit (excluding assets and liabilities held for sale). In addition, we had a $15.5 million borrowing base deficiency under the Senior Credit Facility, and we not in compliance with the current ratio financial covenant in the Senior Credit Facility. As of December 31, 2016, we had reduced our long-term debt to $3.8 million and our short-term debt to $38.2 million, increased our cash to $10.0 million and reduced our working capital deficit to $17.3 million (excluding assets and liabilities held for sale). Subsequent to year end, 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 $20.9 million, and approximate net cash proceeds of $16.3 million. The purchase price is 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 used $2.7 million of the net proceeds to repay short-term debt (see Note 18, “Subsequent events”). As a result of these transactions, we no longer believe there is substantial doubt about our ability to continue as a going concern, and we have eliminated the going concern assumption in our consolidated financial statements. Based on current forecasted oil prices for 2017 and beyond, we believe that our cash flows from operations and existing cash on hand are sufficient to conduct our planned operations and meet our contractual requirements, including license obligations through March 31, 2018.

Significant Accounting Policies

Significant Accounting Policies	12 Months Ended
	Dec. 31, 2016
Accounting Policies [Abstract]
Significant accounting policies	3. Significant accounting policies Basis of preparation Our reporting standard for the presentation of our consolidated financial statements is U.S. GAAP. The consolidated financial statements include the accounts of the Company and all majority-owned, controlled subsidiaries. All significant intercompany balances and transactions have been eliminated in consolidation. During the year ended December 31, 2016, we reclassified certain balance sheet amounts previously reported on our consolidated balance sheet at December 31, 2015 to conform to current year presentation. Cash and cash equivalents Cash and cash equivalents include term deposits and investments with original maturities of three months or less at the date of acquisition. We consider all highly liquid debt instruments purchased with an original maturity of three months or less to be cash equivalents. We determine the appropriate classification of our investments in cash and cash equivalents and marketable securities at the time of purchase and reevaluate such designation at each balance sheet date. Commodity derivative instruments Financial Accounting Standards Board (“FASB”) Accounting Standards Codification (“ASC”) 815, Derivatives and Hedging Fair value measurements We follow ASC 820, Fair Value Measurements and Disclosures ASC 820 characterizes inputs used in determining fair value according to a hierarchy that prioritizes those inputs based upon the degree to which they are observable. The three levels of the fair value measurement hierarchy are as follows: Level 1: Unadjusted quoted prices in active markets that are accessible at the measurement date for identical, unrestricted assets or liabilities. Level 2: Quoted prices in markets that are not active, or inputs which are observable, either directly or indirectly, for substantially the full term of the asset or liability. Level 3: Measured based on prices or valuation models that required inputs that are both significant to the fair value measurement and less observable for objective sources (i.e., supported by little or no market activity). As required by ASC 820, financial assets and liabilities are classified based on the lowest level of input that is significant to the fair value measurement. Our assessment of the significance of a particular input to the fair value measurement requires judgment, which may affect the valuation of the fair value of assets and liabilities and their placement within the fair value hierarchy levels. The determination of the fair values takes into account the market for our financial assets and liabilities, the associated credit risk and other factors as required by ASC 820. We consider active markets as those in which transactions for the assets or liabilities occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Foreign currency remeasurement and translation The functional currency of our subsidiaries in Turkey, Bulgaria, Romania, Morocco, and Albania is the New Turkish Lira (“TRY”), the Bulgarian Lev, the Romanian New Leu, the Moroccan Dirham, and the U.S. Dollar (“USD”) respectively. We follow ASC 830, Foreign Currency Matters For certain subsidiaries, translation adjustments result from the process of translating the functional currency of subsidiary financial statements into the U.S. Dollar reporting currency. These translation adjustments are reported separately and accumulated in the consolidated balance sheets as a component of accumulated other comprehensive loss. Oil and natural gas properties In accordance with the successful efforts method of accounting for oil and natural gas properties, costs of productive wells, developmental dry holes and productive leases are capitalized into appropriate groups of properties based on geographical and geological similarities. Acquisition costs of proved properties are amortized using the unit-of-production method based on total proved reserves, and exploration well costs and additional development costs are amortized using the unit-of-production method based on proved developed reserves. Proceeds from the sale of properties are credited to property costs, and a gain or loss is recognized when a significant portion of an amortization base is sold or abandoned. Exploration costs, such as exploratory geological and geophysical costs, delay rentals and exploration overhead, are charged to expense as incurred. Exploratory drilling costs, including the cost of stratigraphic test wells, are initially capitalized but charged to exploration expense if and when the well is determined to be non-productive. The determination of an exploratory well’s ability to produce must be made within one year from the completion of drilling activities. The acquisition costs of unproved acreage are initially capitalized and are carried at cost, net of accumulated impairment provisions, until such leases are transferred to proved properties or charged to exploration expense as impairments of unproved properties. Equipment and other property Equipment and other property are stated at cost, and inventory is stated at weighted average cost which does not exceed replacement cost. Depreciation is calculated using the straight-line method over the estimated useful lives (ranging from 3 to 7 years) of the respective assets. The costs of normal maintenance and repairs are charged to expense as incurred. Material expenditures that increase the life of an asset are capitalized and depreciated over the estimated remaining useful life of the asset. The cost of equipment sold, or otherwise disposed of, and the related accumulated depreciation, are removed from the accounts and any gain or loss is reflected in current earnings. Impairment of long-lived assets We follow the provisions of ASC 360, Property, Plant, and Equipment Unproved oil and natural gas properties do not have producing properties and are valued on acquisition by management, with the assistance of an independent expert when necessary. As reserves are proved through the successful completion of exploratory wells, the cost is transferred to proved properties. The cost of the remaining unproved basis is periodically evaluated by management to assess whether the value of a property has diminished. To do this assessment, management considers (i) estimated potential reserves and future net revenues from an independent expert, (ii) the Company’s history in exploring the area, (iii) the Company’s future drilling plans per its capital drilling program prepared by the Company’s reservoir engineers and operations management and (iv) other factors associated with the area. Impairment is taken on the unproved property value if it is determined that the costs are not likely to be recoverable. The valuation is subjective and requires management to make estimates and assumptions which, with the passage of time, may prove to be materially different from actual results. Joint interest activities Certain of our exploration, development and production activities are conducted jointly with other entities and, accordingly, the consolidated financial statements reflect only our proportionate interest in such activities. Asset retirement obligations We recognize a liability for the fair value of all legal obligations associated with the retirement of tangible, long-lived assets and capitalize an equal amount as a cost of the asset. The cost associated with the abandonment obligation is included in the computation of depreciation, depletion and amortization. The liability accretes until we settle the obligation. We use a credit-adjusted risk-free interest rate in our calculation of asset retirement obligations. Revenue recognition Revenue from the sale of crude oil and natural gas is recognized upon delivery to the purchaser when title passes. During the years ended December 31, 2016, 2015 and 2014, we sold $52.2 million, $63.0 million and $102.8 million, respectively, of oil to Türkiye Petrol Rafinerileri A.Ş. (“TUPRAS”), a privately owned oil refinery in Turkey, which represented approximately 76.1%, 74.0% and 74.1% of our total revenues, respectively. Share-based compensation We follow ASC 718, Compensation—Stock Compensation Series A Preferred Shares On November 4, 2016, we issued 921,000 shares of 12.0% Series A Convertible Redeemable Preferred Shares (the “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 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 (See Note 5, “Series A Preferred Shares”). Income taxes We follow the asset and liability method prescribed by ASC 740, Income Taxes As of December 31, 2016 and 2015, we have recorded an $8.1 million and $10.9 million liability, respectively, primarily due to uncertain tax positions related to the unwinding of all of our crude oil hedge collars and three-way contracts, which are included in long-term accrued liabilities on our consolidated balance sheet. We do not believe there will be any material changes in our unrecognized tax positions over the next twelve months. Our policy is that we recognize interest and penalties accrued on any unrecognized tax positions as a component of income tax expense. We are a Bermuda exempted company, and under current Bermuda law, we are not subject to tax on profits, income or dividends, nor is there any capital gains tax applicable to us in Bermuda. Comprehensive income ASC 220, Comprehensive Income Business combinations We follow ASC 805, Business Combinations Consolidation Per share information Basic per share amounts are calculated using the weighted average common shares outstanding during the year, excluding unvested restricted stock units. We use the treasury stock method to determine the dilutive effect of stock options and other dilutive instruments. Under the treasury stock method, only “in the money” dilutive instruments impact the diluted calculations in computing diluted earnings per share. Diluted calculations reflect the weighted average incremental common shares that would be issued upon exercise of dilutive options assuming the proceeds would be used to repurchase shares at average market prices for the period.

New Accounting Pronouncements

New Accounting Pronouncements	12 Months Ended
	Dec. 31, 2016
Accounting Changes And Error Corrections [Abstract]
New accounting pronouncements	4. New accounting pronouncements In March 2016, the 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	12 Months Ended
	Dec. 31, 2016
Temporary Equity Disclosure [Abstract]
Series A preferred shares	5. Series A Preferred Shares Series A Preferred Shares On November 4, 2016, we issued 921,000 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 the 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 sheet. As of December 31, 2016, there were $25.5 million of Series A Preferred Shares and $20.6 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 adjustment 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 June 30, September 30, December 31, and March 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 year ended December 31, 2016, we paid $0.9 million in cash dividends on the Series A Preferred Shares. 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 its most recent independent reserve report filed or furnished by us on EDGAR. In addition, until our 2017 Notes are repaid in full, we will not issue indebtedness for money borrowed (other than ordinary trade indebtedness and up to $30.0 million borrowed from DenizBank, A.S. (“DenizBank”)) unless the net proceeds thereof are used (i) to redeem, retire or repay the 2017 Notes, (ii) spud, drill or complete two designated wells, or (iii) used in connection with collateralization or guarantees with respect to our hedging efforts. 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 Securities and Exchange Commission (the “SEC”) as soon as practicable after filing.

Property and equipment

Property and equipment	12 Months Ended
	Dec. 31, 2016
Property Plant And Equipment [Abstract]
Property and equipment	6. Property and equipment Oil and natural gas properties The following table sets forth the capitalized costs under the successful efforts method for oil and natural gas properties: 2016 2015 (in thousands) Oil and natural gas properties, proved: Turkey $ 196,743 $ 232,654 Bulgaria 471 489 Total oil and natural gas properties, proved 197,214 233,143 Oil and natural gas properties, unproved: Turkey 21,109 25,630 Bulgaria - - Total oil and natural gas properties, unproved 21,109 25,630 Gross oil and natural gas properties 218,323 258,773 Accumulated depletion (115,401 ) (113,732 ) Net oil and natural gas properties $ 102,922 $ 145,041 The decline in oil and natural gas properties during the year ended December 31, 2016 was primarily driven by the devaluation of the Turkish Lira (“TRY”) versus the U.S. Dollar. For the year ended December 31, 2016 and 2015, we have recorded foreign currency translation adjustments which reduced oil and natural gas properties and increased accumulated other comprehensive loss within shareholders’ equity on our consolidated balance sheet. At December 31, 2016 and 2015, we excluded $1.9 million and $0.7 million of costs, respectively, from the depletion calculation for development wells in progress. 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. At December 31, 2015, the capitalized costs of our oil and natural gas properties included $18.0 million relating to acquisition costs of proved properties, which are being amortized by the unit-of-production method using total proved reserves, and $100.7 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. The factors used to determine fair value include (Level 3 inputs), 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 year ended December 31, 2016, we recorded $4.5 million of impairment of proved properties and exploratory well costs which are primarily measured using Level 3 inputs. Of the $4.5 million of impairment of proved properties and exploratory well costs incurred during the year ended December 31, 2016, $2.5 million primarily related to proved property impairments in our non-core Thrace region, specifically the Edirne and Redy natural gas fields and our non-core Alibey oil field due to reductions in reserve volumes. The remaining charges during the year ended December 31, 2016 were due to $1.7 million related to exploratory well impairments and $0.3 million of license impairments. Approximately $1.5 million of the amount impaired was cash spent during the period. During the year ended December 31, 2015, we recorded $16.0 million of impairment of proved properties and exploratory well costs, of which $5.8 million primarily related to proved property impairments on our Goksu, Molla and Bakuk fields in Turkey where we wrote the properties down to their estimated fair value which was primarily due to the decline in the Brent oil price and a reduction in the reserve volumes. The remaining charges during the year ended December 31, 2015 were due to $3.7 million related to exploratory well impairment on our Deventci-R2 well in Bulgaria, $3.5 million related to impairment on our Pinar-1 well and $0.7 million related to the South Goksu-1 well, which is part of our joint venture in the Arpatepe field in Turkey. During the year ended December 31, 2014, we recorded $19.9 million in impairment on our proved and unproved properties. Of the $19.9 million, approximately $13.8 million relates to unproved exploratory well impairment on the following wells: $3.5 million related to impairment on the Catak-1 well, $2.8 million related to the Kazanci-5 well, and $7.5 million related to the Bahar-2 side track well. Capitalized costs greater than one year As of December 31, 2016, we had $1.0 million and $1.8 million of exploratory well costs capitalized for the Hayrabolu-10 and Pinar-1 wells, respectively, in Turkey, which we spud in February 2013 and December 2014, respectively. The Hayrabolu-10 well was sold as part of the TBNG sale in February 2017. The Company expects to side-track the Pinar-1 well in the second quarter of 2017. Equipment and other property The historical cost of equipment and other property, presented on a gross basis with accumulated depreciation, is summarized as follows: 2016 2015 (in thousands) Other equipment $ 1,780 $ 2,148 Inventory 10,704 17,348 Gas gathering system and facilities 145 4,790 Vehicles 364 400 Leasehold improvements, office equipment and software 7,280 7,487 Gross equipment and other property 20,273 32,173 (5,237 ) (8,801 ) Net equipment and other property $ 15,036 $ 23,372 At December 31, 2016, we have classified $3.6 million of inventory as a current asset, which represents our expected inventory consumption in the next twelve months. We classify the remainder of our materials and supply inventory as a long-term asset because such materials will ultimately be classified as a long-term asset when the material is used in the drilling of a well. At December 31, 2016 and 2015, we excluded $14.4 million and $21.3 million (including TBNG), of inventory, respectively, from depreciation as the inventory had not been placed into service.

Commodity derivative instrument

Commodity derivative instruments	12 Months Ended
	Dec. 31, 2016
Derivative Instruments And Hedging Activities Disclosure [Abstract]
Commodity derivative instruments	7. Commodity derivative instruments We have used collar and put derivative contracts to economically hedge against the variability in cash flows associated with the forecasted sale of a portion of our future oil production. We have not designated the derivative contracts as hedges for accounting purposes, and accordingly, we record the derivative contracts at fair value and recognize changes in fair value in earnings as they occur. To the extent that a legal right of offset exists, we net the value of our derivative contracts with the same counterparty in our consolidated balance sheets. All of our oil derivative contracts are settled based upon Brent crude oil pricing. We recognize gains and losses related to these contracts on a fair value basis in our consolidated statements of comprehensive income (loss) under the caption “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 years ended December 31, 2016, 2015 and 2014, we recorded a net loss on commodity derivative contracts of $3.3 million, a net gain of $27.5 million and net gain of $37.5 million, respectively. On September 7, 2016 and September 9, 2016, in connection with our repayment and termination of our prior senior credit facility, we unwound all of our existing crude oil hedges for the periods September 10, 2016 through March 31, 2019 with one of the lenders. The unwinding of these hedging transactions resulted in proceeds of $2.6 million and was used for general corporate purposes. On October 6, 2016 and December 22, 2016, we entered into costless collars with DenizBank to hedge a portion of our oil production in Turkey. At December 31, 2016, we had outstanding commodity derivative contracts with respect to our future crude oil production as set forth in the tables below: Fair Value of Derivative Instruments as of December 31, 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 ) At December 31, 2015, we had outstanding commodity derivative contracts with respect to our future crude oil production as set forth in the tables below: Fair Value of Derivative Instruments as of December 31, 2015 Puts Weighted Average Minimum Estimated Fair Quantity Price Value of Type Period (Bbl/day) (per Bbl) Asset (in thousands) Put January 1, 2016— December 31, 2016 808 $ 50.00 $ 3,235 Put January 1, 2017— December 31, 2017 610 $ 50.00 1,798 Put January 1, 2018— December 31, 2018 494 $ 50.00 1,292 Put January 1, 2019— March 31, 2019 443 $ 50.00 280 Total Estimated Fair Value of Asset $ 6,605 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 December 31, 2016 and December 31, 2015, and (ii) the net recorded fair value as reflected on our consolidated balance sheets at December 31, 2016 and December 31, 2015. As of December 31, 2016 Gross Amount Net Amount of Gross Offset in the Liabilities Amount of Consolidated Presented in the Recognized Balance Consolidated Underlying Commodity Location on Balance Sheet Liabilities Sheet Balance Sheet (in thousands) Crude oil Current liabilities $ 596 $ – $ 596 Crude oil Long-term liabilities 242 – 242 As of December 31, 2015 Gross Amount Net Amount of Gross Offset in the Assets Amount of Consolidated Presented in the Recognized Balance Consolidated Underlying Commodity Location on Balance Sheet Assets Sheet Balance Sheet (in thousands) Crude oil Current assets $ 3,235 $ – $ 3,235 Crude oil Long-term assets 3,370 – 3,370

Asset Retirement obligations

Asset Retirement obligations	12 Months Ended
	Dec. 31, 2015
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement obligations	8. Asset retirement obligations As part of our development of oil and natural gas properties, we incur asset retirement obligations (“ARO”). Our ARO results from our responsibility to abandon and reclaim our net share of all working interest properties and facilities. At December 31, 2016, the net present value of our total ARO was estimated to be $8.0 million, with the undiscounted value being $12.6 million. Total ARO at December 31, 2016 shown in the table below consists of amounts for future plugging and abandonment liabilities on our wellbores and facilities based on third-party estimates of such costs, adjusted for inflation at a rate of approximately 6.75% per annum for Turkey. These values are discounted to present value using our credit-adjusted risk-free rate of 5.51% per annum for Turkey for the year ended December 31, 2016. The following table summarizes the changes in our ARO for the years ended December 31, 2016 and 2015: 2016 2015 (in thousands) Asset retirement obligations at beginning of period $ 9,237 $ 10,543 Change in estimates – 385 Liabilities settled (7 ) – Foreign exchange change effect (1,604 ) (2,137 ) Additions 16 78 Accretion expense 373 368 Asset retirement obligations at end of period 8,015 9,237 Less: TBNG asset retirement obligations held for sale 3,182 3,716 Long-term portion $ 4,833 $ 5,521 Our ARO is measured using primarily Level 3 inputs. The significant unobservable inputs to this fair value measurement include estimates of plugging costs, remediation costs, inflation rate and well life. The inputs are calculated based on historical data as well as current estimated costs.

Loans payable

Loans payable	12 Months Ended
	Dec. 31, 2016
Debt Disclosure [Abstract]
Loans payable	9. Loans payable As of the dates indicated, our third-party debt consisted of the following: December 31, December 31, 2016 2015 Fixed and floating rate loans (in thousands) Term Loan $ 25,000 $ - 2017 Notes 13,750 34,400 2017 Notes - Related Party 500 20,600 Senior Credit Facility – 32,075 Unamortized deferred financing costs - Senior Credit Facility and 2017 Notes – (1,200 ) ANBE Note 2,694 3,592 West Promissory Notes – 1,000 Loans payable 41,944 90,467 Less: current portion 38,194 35,467 Long-term portion $ 3,750 $ 55,000 Term Loan On August 23, 2016, the Turkish branch of TransAtlantic Exploration Mediterranean International Pty Ltd (“TEMI”) entered into a Credit Agreement with DenizBank. The Credit Agreement is a master agreement pursuant to which DenizBank may make loans to TEMI from time to time pursuant to additional loan agreements. 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 the Senior Credit Facility with BNP and IFC 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 and is payable in six monthly installments of $1.25 million each through February 2017 and thereafter in twelve monthly installments of $1.88 million each through February 2018. The Term Loan matures in February 2018. Amounts repaid under the Term Loan may not be re-borrowed, and early repayments under the Term Loan are subject to early repayment fees. The Term Loan is guaranteed by DMLP, Ltd. (“DMLP”), TransAtlantic Turkey, Ltd. (“TransAtlantic Turkey”), Talon Exploration, Ltd. (“Talon Exploration”) and TransAtlantic Worldwide, Ltd. (“TransAtlantic Worldwide”), (collectively, the “Guarantors”). Each of the Guarantors is a wholly-owned subsidiary of the Company. The Term Loan contains standard prohibitions on the activities of TEMI as the borrower, including prohibitions on granting of liens on its assets, incurring additional debt, dissolving, liquidating, merging, consolidating, paying dividends, making certain investments, selling assets or transferring revenue, and other similar matters. In addition, the Term Loan prohibits Amity Oil International Pty Ltd (“Amity”) and Petrogas Petrol Gaz ve Petrokimya Urunleri Insaat Sanayi ve Ticaret A.S. (“Petrogas”) from incurring additional debt. An event of default under the Term Loan includes, among other events, failure to pay principal or interest when due, breach of certain covenants, representations, warranties and obligations, bankruptcy or insolvency and the occurrence of a material adverse effect. The Term Loan is secured by a pledge of (i) the stock of TEMI, DMLP, TransAtlantic Turkey and Talon Exploration, (ii) substantially all of the assets of TEMI, (iii) certain real estate owned by Petrogas, (iv) the Gundem real estate and Muratli real estate owned by Gundem Turizm Yatirim ve Isletmeleri A.S. (“Gundem”) and (v) the Diyarbakir real estate owned 80% by N. Malone Mitchell 3 rd At December 31, 2016, we had $25.0 million outstanding under the Term Loan and no availability, and were in compliance with the covenants in the Term Loan. 2017 Notes As of December 31, 2016, we had $14.3 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 bear 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 mature on July 1, 2017, unless earlier redeemed or converted. On June 30, 2016, we issued 2,511,742 common shares to certain holders of the 2017 Notes in lieu of paying cash interest on the 2017 Notes. On November 4, 2016, we exchanged $40.75 million of 2017 Notes for 815,000 Series A Preferred Shares. In addition, in January 2017, we redeemed $4.3 million of 2017 Notes with proceeds of our offering of Series A Preferred Shares. Holders may from time to time at such holder’s option, convert, subject to certain terms and conditions, any or all of the principal of any 2017 Note into fully paid and nonassessable common shares at the conversion price. The conversion price is $6.80 per common share, subject to adjustment as described in the Indenture. Prior to or contemporaneously with the conversion of any of the principal of a 2017 Note, all accrued but unpaid interest on the principal amount being converted will be paid in cash. The 2017 Notes may not be converted into common shares on the maturity date or the redemption date. We may redeem all or part of the 2017 Notes at 100% of the principal amount thereof If we experience a fundamental change (as defined in the Indenture), we will be required to make an offer to repurchase the 2017 Notes at a price equal to 100% of the principal amount thereof, plus accrued and unpaid interest, if any, up to but excluding the date of repurchase. Additionally, if we sell certain assets for $50.0 million or more in cash consideration, in certain circumstances, we will be required to use a portion of the net cash proceeds of such sale to make an offer to repurchase 2017 Notes at a price equal to the price we would be required to pay for an optional redemption at such time, plus accrued and unpaid interest, if any, up to but excluding the date of repurchase. The Indenture provides for customary events of default. The Indenture contains limited covenants. Senior Credit Facility On May 6, 2014, certain of our wholly-owned subsidiaries entered into the Senior Credit Facility. The Senior Credit Facility was guaranteed by us and each of TransAtlantic Petroleum (USA) Corp. (“TransAtlantic USA”) and TransAtlantic Worldwide. On September 7, 2016, we repaid the Senior Credit Facility in full and terminated it. West Promissory Notes In August 2015, TransAtlantic USA entered into promissory notes (the “Promissory Notes”) with each of Mary West CRT 2 LLC and Gary West CRT 2 LLC, shareholders of the Company (collectively, the “Holders”), whereby TransAtlantic USA could borrow up to $1.5 million under each Promissory Note to fund a share repurchase program. The Holders were managed by Randy Rochman, a former observer of our board of directors at the time, who is now a director of our board. On September 9, 2016, the Promissory Notes were repaid in full with proceeds from the Term Loan and were terminated. ANBE Promissory Note On December 30, 2015, 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 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 Note bears interest at a rate of 13.0% per annum. On December 30, 2015, the Company borrowed $3.6 million under the Note (the “Initial Advance”) for general corporate purposes. On June 30, 2016, we issued 355,826 common shares in a private placement to ANBE in lieu of paying cash interest on the Note. On October 31, 2016, TransAtlantic USA entered into an amendment of the Note with ANBE (the “ANBE Amendment”). The ANBE Amendment extended the maturity date of the Note from October 31, 2016 to September 30, 2017, provided for the Note to be repaid in four quarterly installments of $0.9 million each in December 2016 and March, June and September 2017, and provided for monthly payments of interest. In addition, pursuant to the ANBE Amendment, if the sale of TBNG is completed prior to the extended maturity date of the Note, then the Company will repay the Note in full with proceeds from the sale of TBNG within five business days from the closing of the sale. As of December 31, 2016, the Company had borrowed $2.7 million under the Note and had no availability (See Note 18, “Subsequent Events”). 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 December 31, 2016, we had no outstanding borrowings under these lines of credit. Loan financing costs We capitalize certain costs in connection with obtaining our borrowings, such as lender’s fees and related attorney’s fees. These costs are amortized on a straight line basis, which approximates the effective interest method over the term of the loan as a component of interest expense. Loan financing costs, which are netted against current loans payable, totaled approximately zero and $1.2 million as of December 31, 2016 and 2015, respectively. Amortization of loan financing costs totaled approximately $1.2 million, $1.6 million and $1.0 million during 2016, 2015 and 2014, respectively.

Shareholders' equity

Shareholders' equity	12 Months Ended
	Dec. 31, 2016
Equity [Abstract]
Shareholders' equity	10. Shareholders’ equity June 2016 share issuance On June 30, 2016, we issued an aggregate of 5,773,305 common shares in private placements under the Securities Act of 1933, as amended (the “Securities Act”). Of the 5,773,305 common shares, (i) 2,905,737 common shares were issued to holders of the 2017 Notes at the election of such holders to receive common shares in lieu of cash interest on the 2017 Notes; (ii) 355,826 common shares were issued to ANBE in lieu of cash interest on the Note; and (iii) 2,511,742 common shares were issued for cash, which was used to pay cash interest to certain holders of the 2017 Notes. All of the shares were issued at a value of $0.6599 per share, which was equal to 75% of the 10-day volume weighted average price through the close of trading of the common shares on the NYSE MKT on June 29, 2016. Direct settlement On April 17, 2016, we issued 225,000 common shares to Direct Petroleum Inc. (“Direct”) pursuant to a settlement agreement for a mutual release of all current and future claims against the other party. November 2014 share issuance In November 2014, we issued 3,218,641 common shares at a deemed price of $7.41 per common share for the acquisition of Stream Oil & Gas Ltd. (“Stream”). Restricted stock units Under our 2009 Long-Term Incentive Plan (the “Incentive Plan”), we award restricted stock units (“RSUs”) and other share-based compensation to certain of our directors, officers, employees and consultants. Each RSU is equal in value to one of our common shares on the grant date. Upon vesting, an award recipient is entitled to a number of common shares equal to the number of vested RSUs. The RSU awards can only be settled in common shares. As a result, RSUs are classified as equity. At the grant date, we make an estimate of the forfeitures expected to occur during the vesting period and record compensation cost, net of the estimated forfeitures, over the requisite service period. The current forfeiture rate is estimated to be 12.5%. Under the Incentive Plan, RSUs vest over specified periods of time ranging from immediately to four years. RSUs are deemed full value awards and their value is equal to the market price of our common shares on the grant date. ASC 718 requires that the Incentive Plan be approved in order to establish a grant date. Under ASC 718, the approval date for the Incentive Plan was February 9, 2009, the date our board of directors approved the Incentive Plan. Share-based compensation of approximately $0.6 million, $1.1 million and $1.4 million with respect to awards of RSUs was recorded for the years ended December 31, 2016, 2015 and 2014, respectively. As of December 31, 2016, we had approximately $0.5 million of unrecognized compensation expense related to unvested RSUs, which is expected to be recognized over a weighted average period of 1.5 years. The following table sets forth RSU activity for the year ended December 31, 2016: Number of RSUs (in thousands) Weighted Average Grant Date Fair Value Per RSU Unvested RSUs outstanding at December 31, 2015 429 $ 5.60 Granted 698 0.81 Forfeited (103 ) 4.46 Vested (263 ) 5.16 Unvested RSUs outstanding at December 31, 2016 761 $ 1.52 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: (in thousands, except per share amounts) 2016 2015 2014 Net (loss) income from continuing operations $ (22,445 ) $ (26,665 ) $ 29,214 Net income (loss) from discontinued operations $ 16,202 $ (80,873 ) $ (138 ) Basic net (loss) income per common share: Shares: Weighted average common shares outstanding 43,885 40,841 37,829 Basic net (loss) income per common share: Continuing operations $ (0.51 ) $ (0.65 ) $ 0.77 Discontinued operations $ 0.37 $ (1.98 ) $ – Diluted net (loss) income per common share: Shares: Weighted average shares outstanding 43,885 40,841 37,829 Dilutive effect of: Restricted share units – – 152 Convertible notes – – 50 Weighted average common and common equivalent shares outstanding 43,885 40,841 38,031 Diluted net (loss) income per common share: Continuing operations $ (0.51 ) $ (0.65 ) $ 0.77 Discontinued operations $ 0.37 $ (1.98 ) $ – Warrants On December 31, 2014, we issued 134,169 common share purchase warrants (“Warrants”) to Mr. Mitchell and 23,333 common share purchase warrants to each of Mr. Mitchell’s children pursuant to warrant agreements. These Warrants were issued to Mr. Mitchell and his children as shareholders of Gundem, which agreed to pledge Turkish real estate in exchange for an extension of the maturity date of a credit agreement between us and a Turkish bank. As consideration for the pledge of Turkish real estate, the independent members of our board of directors approved the issuance of the Warrants to be allocated in accordance with each shareholder’s ownership percentage of Gundem. Pursuant to the warrant agreements, the Warrants are immediately exercisable, expire on January 6, 2018, and entitle the holder to purchase one common share for each Warrant at an exercise price of $5.99 per share. On each of April 24, 2015 and August 13, 2015, we issued 233,333 Warrants to Mr. Mitchell and certain other related parties as shareholders of Gundem, as consideration for the pledge of Turkish real estate in exchange for an extension of the maturity of a credit agreement between TBNG and a Turkish bank. As consideration for the pledge of Turkish real estate, the independent members of our board of directors approved the issuance of the Warrants to be allocated in accordance with each shareholder’s ownership percentage of Gundem. The Warrants were issued pursuant to a warrant agreement, whereby the Warrants are immediately exercisable, expire on January 6, 2018, and entitle the holder to purchase one common share for each Warrant. The Warrants were issued in April 2015 and August 2015 at an exercise price of $5.65 and $2.99 per share, respectively. For the year ended December 31, 2015, we incurred $0.5 million of compensation expense for these Warrants. The fair value of the Warrants was determined using the Black-Scholes Model.

Income taxes

Income taxes	12 Months Ended
	Dec. 31, 2016
Income Tax Disclosure [Abstract]
Income taxes	11. Income taxes The income tax provision differs from the amount that would be obtained by applying the Bermuda statutory income tax rate of 0% for 2016, 2015 and 2014 to income (loss) from continuing operations for the year as follows: 2016 2015 2014 (in thousands except rates) Statutory rate 0.00 % 0.00 % 0.00 % (Loss) income from continuing operations before income taxes $ (16,399 ) $ (4,436 ) $ 42,873 Increase (decrease) resulting from: Foreign tax rate differentials $ (1,018 ) $ 1,676 $ 9,262 Uncertain tax position (958 ) 10,066 1,260 Unremitted earnings 4,777 11,561 – Derivative contracts – (5,038 ) – Change in valuation allowance (147 ) 3,232 228 Expiration of non-capital tax loss carryovers 2,056 1,740 1,841 Other 1,336 (1,008 ) 1,068 Total $ 6,046 $ 22,229 $ 13,659 The components of the net deferred income tax liability at December 31, 2016 and 2015 were as follows: 2016 2015 (in thousands) Deferred tax assets Property and equipment $ 3,003 $ 3,749 Unrealized gains on derivative contracts 168 – Timing of accruals 162 351 Non-capital loss carryovers 22,364 24,098 Valuation allowance (25,452 ) (27,870 ) Total deferred tax assets $ 245 $ 328 Deferred tax liabilities Property and equipment $ (9,986 ) $ (15,514 ) Unremitted earnings (8,586 ) (6,981 ) Timing of accruals (479 ) (436 ) Total deferred tax liabilities (19,051 ) (22,931 ) Net deferred tax liabilities $ (18,806 ) $ (22,603 ) Components of net deferred tax liabilities Non-current assets $ 245 $ - Non-current liabilities (19,051 ) (22,603 ) Net deferred tax liabilities $ (18,806 ) $ (22,603 ) We have accumulated losses or resource-related deductions available for income tax purposes in Turkey, Romania, Bulgaria and the United States. As of December 31, 2016, we had non-capital tax losses in Turkey of approximately 63.2 million TRY (approximately $18.0 million), which will begin to expire in 2017; non-capital tax losses in Romania of approximately 8.1 million Romanian New Leu (approximately $1.9 million), which will begin to expire in 2018; non-capital losses in Bulgaria of approximately 7.1 million Bulgarian Lev (approximately $3.9 million), which will begin to expire in 2017; and non-capital tax losses in the United States of approximately $51.7 million, which will begin to expire in 2018. As of December 31, 2016 and 2015, we reflected a valuation allowance of $25.5 million and $27.9 million, respectively, as a reduction to our net operating losses and deferred tax assets. Effective October 1, 2009, we continued to the jurisdiction of Bermuda. We have determined that no taxes were payable upon the continuance. However, our tax filing positions are still subject to review by taxation authorities who may successfully challenge our interpretation of the applicable tax legislation and regulations, with the result that additional taxes could be payable by us. We file income tax returns in the United States, Turkey, Romania, Bulgaria and Cyprus, with Turkey being the only jurisdiction with significant amounts of taxes due. Except for the outstanding examination of the 2011 income tax filings for Petrogas, Turkish income tax filings before 2012 are no longer subject to examination. As the result of 2016 Turkish legislation allowing us the option to enter into an agreement to exempt corporate income tax filings from examination, we were able to close additional years from examination. During the year ended December 2016, the Turkish Ministry of Finance completed their audits of Amity for the year ended December 31, 2011, and Talon Exploration for the year ended December 31, 2014, with no significant findings. As of December 31, 2016 and 2015, we recorded an $8.1 million and $10.9 million liability, respectively, primarily due to uncertain tax positions related to the unwinding of all our crude oil hedge collars and three-way contracts, which are included in long-term accrued liabilities on our consolidated balance sheet. The unrecognized tax benefits at December 31, 2016 and 2015 were as follows: 2016 2015 (in thousands) Unrecognized tax benefits at beginning of period $ 11,014 $ 1,188 Gross increases - tax positions in prior period 910 – Gross decreases - tax positions in prior period (3,087 ) – Gross increases - tax positions in current period 1,219 10,066 Gross decreases - tax positions in current period – – Foreign exchange change effect (1,914 ) (240 ) Unrecognized tax benefits at end of period 8,142 11,014 Less: TBNG liability held for sale (63 ) (76 ) Unrecognized tax benefits at end of period $ 8,079 $ 10,938 As of December 31, 2016, there were no material uncertain tax positions for which the total amounts of unrecognized tax benefits will significantly increase or decrease within the next 12 months. Unremitted Earnings Our foreign subsidiaries generate earnings that are not subject to Turkish dividend withholding taxes so long as they are permanently reinvested in our operations in Turkey. Pursuant to ASC Topic No. 740-30 (formerly APB 23), undistributed earnings of foreign subsidiaries that are no longer permanently reinvested would become subject to Turkish dividend withholding taxes. Prior to fiscal year 2015, we asserted that the undistributed earnings of our foreign Turkish subsidiaries were permanently reinvested. Primarily due to the increase in our U.S. debt service obligations resulting from the issuance of the 2017 Notes in the aggregate principal amount of $55.0 million in 2015 (see Note 9, “Loans payable”), management concluded that the ability to access certain amounts of foreign earnings would provide greater flexibility to meet corporate cash flow needs without constraining foreign objectives. Accordingly, in the fourth quarter of fiscal year 2015, we withdrew the permanent reinvestment assertion on 135.2 million TRY of cumulative earnings generated by certain of our Turkish foreign subsidiaries through fiscal year 2015. We provided for Turkish dividend withholding taxes on the 135.2 million TRY of cumulative undistributed foreign Turkish earnings, resulting in the recognition of a deferred tax liability. As of December 31, 2016, we maintain the same position and we provided for Turkish dividend withholding taxes on 201.3 million TRY of cumulative undistributed foreign Turkish earnings, resulting in an additional increase in our deferred tax liability. There is no certainty as to the timing of when such Turkish foreign earnings will be distributed to TransAtlantic Worldwide in whole or in part.

Segment information

Segment information	12 Months Ended
	Dec. 31, 2016
Segment Reporting [Abstract]
Segment information	12. Segment information In accordance with ASC 280, Segment Reporting Corporate Turkey Bulgaria Total (in thousands) For the year ended December 31, 2016 Total revenues $ – $ 68,595 $ – $ 68,595 Production – 12,293 75 12,368 Exploration, abandonment, and impairment 1,417 4,546 – 5,963 Cost of purchased gas – 4,418 – 4,418 Seismic and other exploration – 91 13 104 General and administrative 8,170 7,948 202 16,320 Depreciation, depletion and amortization 264 28,761 – 29,025 Accretion of asset retirement obligations – 354 19 373 Total costs and expenses 9,851 58,411 309 68,571 Operating (loss) income (9,851 ) 10,184 (309 ) 24 Interest and other expense (8,633 ) (3,208 ) – (11,841 ) Interest and other income 656 1,888 2 2,546 Loss on commodity derivative contracts – (3,257 ) – (3,257 ) Foreign exchange gain (loss) 428 (4,293 ) (6 ) (3,871 ) (Loss) income from continuing operations before income taxes (17,400 ) 1,314 (313 ) (16,399 ) Income tax expense – (6,046 ) – (6,046 ) Net loss from continuing operations $ (17,400 ) $ (4,732 ) $ (313 ) $ (22,445 ) Total assets at December 31, 2016 $ 17,007 $ 153,560 $ 609 $ 171,176 (1) Capital expenditures for the year ended December 31, 2016 $ – $ 10,186 $ – $ 10,186 For the year ended December 31, 2015 Total revenues $ – $ 85,064 $ – $ 85,064 Production – 12,804 69 12,873 Exploration, abandonment, and impairment – 17,778 3,766 21,544 Cost of purchased gas – 2,082 – 2,082 Seismic and other exploration 55 264 51 370 General and administrative 12,729 11,132 277 24,138 Depreciation, depletion and amortization 306 37,401 – 37,707 Accretion of asset retirement obligations – 350 18 368 Total costs and expenses 13,090 81,811 4,181 99,082 Operating (loss) income (13,090 ) 3,253 (4,181 ) (14,018 ) Interest and other expense (7,383 ) (5,694 ) – (13,077 ) Interest and other income 354 500 1 855 Gain on commodity derivative contracts – 27,457 – 27,457 Foreign exchange loss (58 ) (5,589 ) (6 ) (5,653 ) (Loss) income from continuing operations before income taxes (20,177 ) 19,927 (4,186 ) (4,436 ) Income tax expense – (22,229 ) – (22,229 ) Net loss from continuing operations $ (20,177 ) $ (2,302 ) $ (4,186 ) $ (26,665 ) Total assets at December 31, 2015 $ 14,205 $ 197,944 $ 601 $ 212,750 (2) Capital expenditures for the year ended December 31, 2015 $ 163 $ 22,262 $ 41 $ 22,466 For the year ended December 31, 2014 Total revenues $ – $ 138,807 $ 23 $ 138,830 Production – 18,059 134 18,193 Exploration, abandonment, and impairment – 19,820 44 19,864 Cost of purchased gas – 2,055 – 2,055 Seismic and other exploration 178 4,106 1 4,285 Revaluation of contingent consideration – – (2,500 ) (2,500 ) General and administrative 14,418 14,984 1,669 31,071 Depreciation, depletion and amortization 124 48,452 18 48,594 Accretion of asset retirement obligations – 387 19 406 Total costs and expenses 14,720 107,863 (615 ) 121,968 Operating (loss) income (14,720 ) 30,944 638 16,862 Interest and other expense (36 ) (6,007 ) (1 ) (6,044 ) Interest and other income 350 770 4 1,124 Loss on commodity derivative contracts – 37,454 – 37,454 Foreign exchange loss (4 ) (6,497 ) (22 ) (6,523 ) (Loss) income loss from continuing operations before income Taxes (14,410 ) 56,664 619 42,873 Income tax expense – (13,659 ) – (13,659 ) Net (loss) income from continuing operations $ (14,410 ) $ 43,005 $ 619 $ 29,214 Total assets at December 31, 2014 $ 51,429 $ 306,578 $ 4,675 $ 362,682 (2) Goodwill at December 31, 2014 $ – $ 6,935 $ – $ 6,935 Capital expenditures for the year ended December 31, 2014 $ 545 $ 109,563 $ 1,393 $ 111,501 (1) Excludes assets of TBNG of $25.2 million. (2) Excludes assets of TBNG and our discontinued Albanian and Moroccan operations of $85.4 million and $181.0 million at December 31, 2015 and 2014, respectively.

Financial instruments

Financial instruments	12 Months Ended
	Dec. 31, 2016
Fair Value Disclosures [Abstract]
Financial instruments	13. Financial instruments Foreign currency risk We have underlying foreign currency exchange rate exposure. Our currency exposures primarily relate to transactions denominated in the Bulgarian Lev, European Union Euro, Albanian Lek, and TRY. We are also subject to foreign currency exposures resulting from translating the functional currency of our subsidiary financial statements into the U.S. Dollar reporting currency. We have not used foreign currency forward contracts to manage exchange rate fluctuations. At December 31, 2016, we had 30.6 million TRY (approximately $8.7 million) in cash and cash equivalents, which exposes us to exchange rate risk based on fluctuations in the value of the TRY. Commodity price risk We are exposed to fluctuations in commodity prices for oil and natural gas. Commodity prices are affected by many factors, including but not limited to, supply and demand. At December 31, 2016 and 2015, we were a party to commodity derivative contracts. Concentration of credit risk The majority of our receivables are within the oil and natural gas industry, primarily from our industry partners and from government agencies. Included in receivables are amounts due from Turkiye Petrolleri Anonim Ortakligi (“TPAO”), the national oil company of Turkey, Zorlu Dogal Gaz Ithalat Ihracat ve Toptan Ticaret A.S. (“Zorlu”), a privately owned natural gas distributor in Turkey, and TUPRAS, which purchase the majority of our oil and natural gas production. The receivables are not collateralized. To date, we have experienced minimal bad debts and have no allowance for doubtful accounts. The majority of our cash and cash equivalents are held by three financial institutions in the United States and Turkey. Fair value measurements Cash and cash equivalents, receivables, notes receivable, accounts payable, accrued liabilities, the Note and the Promissory Notes were each estimated to have a fair value approximating the carrying amount at December 31, 2016 and 2015 due to the short maturity of those instruments. The financial assets and liabilities measured on a recurring basis at December 31, 2016 and 2015 consisted of our commodity derivative contracts. Fair values for options are based on counterparty market prices. The counterparties use market standard valuation methodologies incorporating market inputs for volatility and risk free interest rates in arriving at a fair value for each option contract. Prices are verified by us using analytical tools. There are no performance obligations related to the collar contracts purchased to hedge our oil production. We utilize models based on a range of observable market inputs, including pricing models, quoted market prices of publicly traded securities with similar duration and yield, time value, yield curve, prepayment spreads, default rates and discounted cash flow and the values for these contracts are disclosed in Level 2 of the fair value hierarchy to determine the fair value of our commodity derivative contracts. We review prices received from our counterparty for unusual fluctuations to ensure that the prices represent a reasonable estimate of fair value. At December 31, 2016, the fair value of our Term Loan and 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. At December 31, 2016, the carrying value approximated the fair value for the Term Loan and 2017 Notes. The following table summarizes the valuation of our financial 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 ) The following table summarizes the valuation of our financial assets and liabilities as of December 31, 2015: 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 $ – $ 6,605 $ – $ 6,605 Disclosed but not carried at fair value Liabilities: Senior Credit Facility – – (30,050 ) (30,050 ) 2017 Notes – – (44,489 ) (44,489 ) Total $ – $ 6,605 $ (74,539 ) $ (67,934 )

Commitments

Commitments	12 Months Ended
	Dec. 31, 2016
Commitments And Contingencies Disclosure [Abstract]
Commitments	14. Commitments Our aggregate annual commitments, other than our loans payable, as of December 31, 2016 were as follows: Payments Due By Year Total 2017 2018 2019 2020 2021 Thereafter (in thousands) Series A Preferred Shares dividends (1) $ 43,348 $ 5,526 $ 5,526 $ 5,526 $ 5,526 $ 5,526 $ 15,718 Interest 2,962 2,874 88 - - - - Leases 1,370 698 603 69 - - - Total $ 47,680 $ 9,098 $ 6,217 $ 5,595 $ 5,526 $ 5,526 $ 15,718 (1) Dividends on the Series A Preferred Shares may be paid by the Company, in its sole discretion, in cash at a rate of 12% per annum or in common shares at a rate of 16% per annum or in a combination of cash and common shares. The amounts in the table assume that the Company pays all future dividend payments solely in cash. Normal operations purchase arrangements are excluded from the table as they are discretionary or being performed under contracts which are cancelable immediately or with a 30-day notice period. We lease office space in Dallas, Texas, Bulgaria, and Turkey. We also lease apartments in Turkey, as well as operations yards in Turkey. Rent expense for the years ended December 31, 2016, 2015 and 2014 was $1.4 million, $1.8 million and $2.2 million, respectively.

Contingencies

Contingencies	12 Months Ended
	Dec. 31, 2016
Commitments And Contingencies Disclosure [Abstract]
Contingencies	15. Contingencies 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, we recorded $5.0 million in accrued liabilities relating to our Tselfat exploration permit during 2012 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, and 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.

Related Party Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2016
Related Party Transactions [Abstract]
Related party transactions	16. Related party transactions Series A Preferred Shares transactions On November 4, 2016, we issued 921,000 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 2017 Notes, at an exchange rate of 20 Series A Preferred Shares for each $1,000 principal amount of 2017 Notes (the “Exchange Offer”), and (ii) 106,000 shares were issued and sold for $5.3 million of cash to certain holders of the 2017 Notes (the “Offering”). In the Exchange Offer, Pinon Foundation, a non-profit charitable organization directed by Mr. Mitchell’s spouse exchanged $10.0 million of the 2017 Notes for 200,000 Series A Preferred Shares; Dalea Partners, LP (“Dalea”), an affiliate of Mr. Mitchell, exchanged $2.1 million of the 2017 Notes for 41,000 Series A Preferred Shares; and trusts benefitting Mr. Mitchell’s four adult children each exchanged $2.0 million of the 2017 Notes for 40,000 Series A Preferred Shares. In the Offering, the Pinon Foundation purchased 5,000 Series A Preferred Shares for $250,000; and each of Mr. Mitchell’s four adult children purchased 1,000 Series A Preferred Shares for $50,000. For more information see Note 5, “Series A Preferred Shares”. Equity transactions On December 31, 2014, the Company issued 134,169 Warrants to Mr. Mitchell and 23,333 common share purchase warrants to each of Mr. Mitchell’s children pursuant to warrant agreements. These Warrants were issued to Mr. Mitchell and his children as shareholders of Gundem, which agreed to pledge Turkish real estate in exchange for an extension of the maturity date of a credit agreement between us and a Turkish bank. As consideration for the pledge of Turkish real estate, the independent members of our board of directors approved the issuance of the Warrants to be allocated in accordance with each shareholder’s ownership percentage of Gundem. Pursuant to the warrant agreements, the Warrants are immediately exercisable, expire on January 6, 2018, and entitle the holder to purchase one common share for each Warrant at an exercise price of $5.99 per share. On each of April 24, 2015 and August 13, 2015, we issued 233,333 Warrants to Mr. Mitchell and certain other related parties as shareholders of Gundem, as consideration for the pledge of Turkish real estate in exchange for an extension of the maturity of a credit agreement between TBNG and a Turkish bank. As consideration for the pledge of Turkish real estate, the independent members of our board of directors approved the issuance of the Warrants to be allocated in accordance with each shareholder’s ownership percentage of Gundem. The Warrants were issued pursuant to a warrant agreement, whereby the Warrants are immediately exercisable, expire on January 6, 2018, and entitle the holder to purchase one common share for each Warrant. The Warrants issued in April 2015 and August 2015 an exercise price of $5.65 and $2.99 per share, respectively. For the year ended December 31, 2015, we incurred $0.5 million of compensation expense for these Warrants. The fair value of the Warrants was determined using the Black-Scholes Model. On June 30, 2016, we issued an aggregate of 5,773,305 common shares in private placements under the Securities Act. Of the 5,773,305 common shares, (i) 1,974,452 common shares were issued to Dalea 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, 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 $11.5 million (the “Original Note”). The Note Amendment Agreement reduced the principal amount of the Original Note to $8.0 million 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 (“Viking International”) 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 our former subsidiaries, Viking International and Viking Geophysical Services Ltd., (“Viking Geophysical”) Viking Services B.V., the beneficial owner of Viking International, VOS and Viking Geophysical (“Viking Services”) master services agreement between Production Solutions International Petrol Arama Hizmetleri Anonim Sirketi (“PSIL”) and the Company (the “PSIL MSA”) 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 $2.0 million principal amount of the 2017 Notes 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 the 2017 Notes for 40,000 Series A Preferred Shares. On June 30, 2016, we entered into a waiver with Dalea, whereby we waived our right under the Pledge Agreement to receive the interest payment due July 1, 2016 under the Dalea Convertible Notes in connection with the payment of 201,459 common shares to Dalea with respect to the 2017 Note interest payment paid on June 30, 2016. As of December 31, 2016, the amount receivable under the Amended Note was $7.6 million. 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 will pay 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 will pay Messrs. Mitchell and Uras a fee of 5% per annum of the collateral value of the Diyarbakir real estate. 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 will be used to reduce the outstanding principal amount of the Amended Note. During the year ended December 31, 2016, we reduced the principal amount of the Amended Note by $0.2 million for amounts earned under the pledge fee agreements. Service transactions Effective May 1, 2008, we entered into a service agreement, as amended (the “Service Agreement”), with Longfellow Energy, LP (“Longfellow”), Viking Drilling LLC (“Viking Drilling”), MedOil Supply, LLC and Riata Management, LLC (“Riata Management”). Mr. Mitchell and his wife own 100% of Riata Management. In addition, Mr. Mitchell, his wife and his children indirectly own 100% of Longfellow. Riata Management owns 100% of MedOil Supply, LLC. Dalea owns 85% of Viking Drilling. Under the terms of the Service Agreement, we pay, or are paid, for the actual cost of the services rendered plus the actual cost of reasonable expenses on a monthly basis. Effective January 1, 2011, our wholly owned subsidiary, TEMI, entered into an accommodation agreement under which it leased rooms, flats and office space at a facility owned by Gundem. Under the accommodation agreement, TEMI leases six rooms and pays the TRY equivalent of $6,000 per month. On August 23, 2011, the Company’s wholly owned subsidiary, TransAtlantic USA, entered into an office lease with Longfellow to lease approximately 5,300 square feet of corporate office space in Addison, Texas. The initial lease term under the lease commenced on July 1, 2013, the date that TransAtlantic USA subleased a portion of its previous office space in Dallas, Texas (the “Commencement Date”). The lease expires five years after the Commencement Date, unless earlier terminated in accordance with the lease. During the initial lease term, TransAtlantic USA will pay monthly rent of $6,625 to Longfellow, plus utilities, real property taxes and liability insurance. On June 13, 2012, we entered into separate master services agreements with each of Viking International, Viking Petrol Sahasi Hizmetleri AS (“VOS”) and Viking Geophysical in connection with the sale of our oilfield services business to a joint venture owned by Dalea and funds managed by Abraaj Investment Management Limited. Pursuant to the master services agreements with Viking International and VOS, we are entitled to receive certain oilfield services and materials, including, but not limited to, drilling rigs and fracture stimulation that are needed for our operations in Bulgaria and Turkey. Pursuant to the master services agreement with Viking Geophysical, we are also entitled to receive geophysical services and materials that are needed for our operations in those countries. Each master services agreement is for a five-year term. Currently, we can contract for services and materials on a firm basis and, to the extent that we do not contract for all of their services or materials, Viking International, VOS and Viking Geophysical are allowed to contract with third parties for any remaining capacity. On March 3, 2016, Mr. Mitchell closed a transaction whereby he sold his interest in Viking Services 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, which equipment is owned and operated by PSIL. PSIL is beneficially owned by Dalea Investment Group, LLC, which is controlled by Mr. Mitchell. Consequently, on March 3, 2016, we entered into the PSIL MSA on substantially similar terms to our prior master services agreements with Viking International, VOS and VGS. Pursuant to the PSIL MSA, PSIL will perform services on behalf of TEMI and its affiliates. The master services agreements with each of Viking International, VOS and Viking Geophysical will remain in effect through the remainder of the five-year term of the agreements. On April 5, 2013 (the “First Floor Commencement Date”), TransAtlantic USA entered into an office lease with Longfellow to lease approximately 4,700 square feet of additional corporate office space in Addison, Texas. The initial lease term commenced on the First Floor Commencement Date and expires five years after the First Floor Commencement Date, unless earlier terminated in accordance with the lease. TransAtlantic USA pays monthly rent of $8,120 to Longfellow plus utilities, real property taxes and liability insurance. For the years ended December 31, 2016 and 2015, we incurred capital and operating expenditures of $7.0 million and $20.0 million, respectively, related to our various related party agreements. Debt transactions Between December 2014 and February 2015, we sold $55.0 million of convertible notes in a non-brokered private placement, which were exchanged for the 2017 Notes on February 20, 2015. Dalea purchased $2.0 million of the notes; trusts benefitting Mr. Mitchell’s four children each purchased $2.0 million of the notes; Pinon Foundation, purchased $10.0 million of the notes; the three children of Brian Bailey, a director of the Company, each purchased $100,000 of the notes; and a trust benefitting Barbara and Terry Pope, Mr. Mitchell’s sister-in-law and brother-in-law, purchased $200,000 of the notes. ANBE Promissory Note On December 30, 2015, TransAtlantic USA entered into the $5.0 million Note with ANBE, an entity owned by the 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 Note bears interest at a rate of 13.0% per annum. On December 30, 2015, the Company borrowed the Initial Advance of $3.6 million for general corporate purposes. On June 30, 2016, the Company issued 355,826 common shares in a private placement to ANBE in lieu of paying cash interest on the Note. On October 31, 2016, TransAtlantic USA entered into an amendment of the Note with ANBE (the “ANBE Amendment”). The ANBE Amendment extended the maturity date of the Note from October 31, 2016 to September 30, 2017, provided for the Note to be repaid in four quarterly installments of $0.9 million each in December 2016 and March, June and September 2017, and provided for monthly payments of interest. In addition, pursuant to the ANBE Amendment, if the sale of TBNG is completed prior to the extended maturity date of the Note, then the Company will repay the Note in full with proceeds from the sale of TBNG within five business days from the closing of the sale. As of December 31, 2016, the Company had borrowed $2.7 million under the Note and had no availability (See Note 18, “Subsequent Events”). The following table summarizes related party accounts receivable and accounts payable as of December 31, 2016 and December 31, 2015: 2016 2015 (in thousands) Related party accounts receivable: Riata Management Service Agreement $ 528 $ 194 PSIL MSA 234 – Viking International master services agreement – 214 Total related party accounts receivable $ 762 $ 408 Related party accounts payable: Riata Management Service Agreement $ 346 $ 384 PSIL MSA 1,315 – Interest payable on 2017 Notes 183 – Viking International master services agreement – 2,169 Total related party accounts payable $ 1,844 $ 2,553

Assets and Liabilities Held for

Assets and Liabilities Held for Sale and Discontinued Operations	12 Months Ended
	Dec. 31, 2016
Discontinued Operations And Disposal Groups [Abstract]
Assets and liabilities held for sale and discontinued operations	17. 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. The sale of TBNG resulted in the classification of the assets and liabilities of TBNG to the caption “Assets held for sale” and “Liabilities held for sale” for the periods ending December 31, 2016 and 2015. Although the sale of TBNG met the threshold to classify its assets and liabilities as held for sale, it didn’t meet the requirements to classify its operations as discontinued as the sale wasn’t 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 18, “Subsequent Events”). Discontinued operations in Albania As of December 31, 2015 we classified our Albania segment as assets and liabilities held for sale and presented the operating results within discontinued operations for all periods presented. In February 2016, we sold all of the outstanding equity in Stream to GBC Oil Company Ltd. (“GBC Oil”) in exchange for (i) the future payment of $2.3 million to Raiffeisen Bank Sh.A. (“Raiffeisen”) to pay down a Term Loan Facility dated as of September 17, 2014 (the “Term Loan Facility”) between TransAtlantic Albania and Raiffeisen, and (ii) the assumption of $29.2 million of liabilities owed by Stream, consisting of $23.1 million of accounts payable and accrued liabilities and $6.1 million of debt. We believe that GBC Oil has failed to pay the amounts required under the purchase agreement, and we are evaluating our legal remedies to enforce the provisions of the purchase agreement. TransAtlantic Albania owns all of our former Albanian assets and operations. In addition, GBC Oil issued us a warrant pursuant to which we have the option to acquire up to 25% of the fully diluted equity interests in TransAtlantic Albania for nominal consideration at any time on or before March 1, 2019. In February 2016, we valued the warrant from GBC Oil at approximately $1.6 million. At December 31, 2016, we reduced the value of the warrant to zero due to GBC Oil’s failure to comply with its obligations under the purchase agreement. We recognized this loss under the caption “Exploration, abandonment and impairment” on our consolidated statement of comprehensive (loss) income for the year ended December 31, 2016. On September 1, 2016, the Company completed a joint venture transaction with respect to the assets in the Delvina gas field in Albania (the “Delvina Assets”). The Company 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. These payments will be made each quarter over an 18-month period, with the first payment of $1.0 million to be completed by November 2016. As a result of this transaction, we have recorded a gain on disposal of discontinued operations of $9.4 million during the year ended December 31, 2016. After the Transfer, the Company retained a 25% equity interest in DelvinaCo and has agreed to pay 25% of the operating costs of DelvinaCo, subject to a three-year deferral of capital expenditures. For the next three years, Ionian will be responsible for all agreed upon capital expenditures with respect to the Delvina Assets. At the end of the three-year period, the Company will be required to either reimburse Ionian for its 25% share of such capital expenditures or face dilution in its ownership of DelvinaCo. As of December 31, 2016, we no longer hold our 25% interest in DelvinaCo as assets held for sale, and have consolidated our interest using proportionate consolidation. An impairment charge of $73.0 million was recorded to write down the net book value of the assets held for sale to their fair value as of December 31, 2015. The assumptions used in our assessment of fair value included the transaction discussed above with GBC Oil. Discontinued operations in Morocco On June 27, 2011, we decided to discontinue our operations in Morocco. We have substantially completed the process of winding down our operations in Morocco. We have presented the Moroccan segment operating results as discontinued operations for all periods presented. Assets and liabilities held for sale The assets and liabilities held for sale at December 31, 2016 and 2015 are as shown below. As a result of the joint venture transaction related to the Delvina Assets and the reassessment of the Moroccan contingent liabilities, there were no remaining assets or liabilities held for sale at December 31, 2016 for Albania or Morocco. TBNG Albania Morocco Total Held for Sale (in thousands) For the year ended December 31, 2016 Assets Cash $ 1,551 $ – $ – $ 1,551 Other current assets 7,511 – – 7,511 Property and equipment, net 16,155 – – 16,155 Total current assets held for sale $ 25,217 $ – $ – $ 25,217 Liabilities Accounts payable and other accrued liabilities $ 11,240 $ – $ – $ 11,240 Deferred tax liability 4,698 – – 4,698 Total current liabilities held for sale $ 15,938 $ – $ – $ 15,938 For the year ended December 31, 2015 Assets Cash $ 1,780 $ 1,201 $ 16 $ 2,997 Other current assets 7,956 1,853 11 9,820 Property and equipment, net – 48,430 – 48,430 Total current assets held for sale 9,736 51,484 27 61,247 Property and equipment, net 22,292 – – 22,292 Other long-term assets 1,900 – – 1,900 Total assets held for sale $ 33,928 $ 51,484 $ 27 $ 85,439 Liabilities Accounts payable and other accrued liabilities $ 8,733 $ 37,888 $ 6,352 $ 52,973 Accounts payable - related party 131 3,540 – 3,671 Loan payable 5,132 6,123 – 11,255 Deferred tax liability – 15,286 – 15,286 Total current liabilities held for sale $ 13,996 $ 62,837 $ 6,352 $ 83,185 Deferred tax liability 4,757 – – 4,757 Other long-term liabilities 4,748 – – 4,748 Total liabilities held for sale $ 23,501 $ 62,837 $ 6,352 $ 92,690 As of December 31, 2015, our third-party debt held for sale consisted of the following: December 31, 2015 (in thousands) Fixed and floating rate loans Term Loan Facility $ 6,123 TBNG credit facility 5,192 Unamortized deferred financing costs - TBNG credit facility (60 ) Loan payable $ 11,255 TransAtlantic Albania was a party to the Term Loan Facility with Raiffeisen. The loan was scheduled to mature on December 31, 2016 and bore interest at the rate of LIBOR plus 5.5%, with a minimum interest rate of 7.0%. TransAtlantic Albania was required to pay 1/16th of the total commitment each quarter on the last business day of each of March, June, September and December each year. The loan was guaranteed by TransAtlantic Albania’s parent company, Stream. TransAtlantic Albania could prepay the loan at its option in whole or in part, subject to a 3.0% penalty plus breakage costs. The Term Loan Facility was secured by substantially all of the assets of TransAtlantic Albania. As of December 31, 2015, TransAtlantic Albania had $6.1 million outstanding under the Term Loan Facility and no availability. As of December 31, 2015, TransAtlantic Albania was in default under the Term Loan Facility for failure to repay $1.1 million due on December 31, 2015. On February 29, 2016, we sold all the equity interest in Stream, the parent company of TransAtlantic Albania, to GBC Oil, who assumed the Term Loan Facility. TBNG had a fully-drawn credit facility with a Turkish bank. The facility was secured by a lien on a Turkish real estate property owned by Gundem, which is 97.5% beneficially owned by Mr. Mitchell and his children. At December 31, 2015, TBNG had a balance of $5.2 million under the credit facility and no availability. In August 2016, TBNG repaid the credit facility in full and terminated it. Our operating results from discontinued operations for the years ended December 31, 2016, 2015 and 2014 are summarized as follows: Albania Morocco Total (in thousands) For the year ended December 31, 2016 Total revenues $ 626 $ - $ 626 Production and transportation expense 1,138 - 1,138 Total other costs and expenses 561 - 561 Total other income 10,168 6,903 17,071 Income before income taxes $ 9,095 $ 6,903 $ 15,998 Income tax benefit 204 - 204 Income from discontinued operations $ 9,299 $ 6,903 $ 16,202 For the year ended December 31, 2015 Total revenues $ 8,565 $ - $ 8,565 Production and transportation expense 11,615 - 11,615 Exploration, abandonment and impairment 86,577 - 86,577 Total other costs and expenses 9,229 5 9,234 Total other income 1,819 - 1,819 Loss before income taxes $ (97,037 ) $ (5 ) $ (97,042 ) Income tax benefit 16,169 - 16,169 Loss from discontinued operations $ (80,868 ) $ (5 ) $ (80,873 ) For the year ended December 31, 2014 Total revenues $ 1,898 $ - $ 1,898 Total costs and expenses 2,984 20 3,004 Total other income 356 - 356 Loss before income taxes $ (730 ) $ (20 ) $ (750 ) Income tax benefit 612 - 612 Loss from discontinued operations $ (118 ) $ (20 ) $ (138 )

Subsequent Events

Subsequent Events	12 Months Ended
	Dec. 31, 2016
Subsequent Events [Abstract]
Subsequent Events	18. Subsequent events Optional redemption of 2017 Notes On January 1, 2017 (the “Redemption Date”), we redeemed $4.3 million in aggregate principal amount of 2017 Notes at a cash redemption price equal to 100% of the principal amount thereof plus accrued and unpaid interest thereon to the Redemption Date. After the optional redemption, we had $10.0 million of 2017 Notes outstanding. TBNG Sale On February 24, 2017, we sold TBNG for gross proceeds of $20.9 million, and approximate net cash proceeds of $16.3 million, effective as of March 31, 2016. The purchase price is 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 used $2.7 million of the net proceeds from the sale to pay off our Note with ANBE pursuant to the terms of the ANBE Amendment. Amendment to Master Services Agreement On March 20, 2017, the Company entered into a second amendment to the Master Services Agreement among the Company and Longfellow Energy, LP, a Texas limited partnership, 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. As this agreement is a related party transaction, the independent members of the Board of Directors reviewed and approved this amendment.

General (Policies)

General (Policies)	12 Months Ended
	Dec. 31, 2016
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, have stable governments, are net importers of petroleum, have an existing petroleum transportation infrastructure and provide favorable commodity pricing, royalty rates and tax rates to exploration and production companies. We hold interests in developed and undeveloped oil and natural gas properties in Turkey and Bulgaria and an operated interest in a joint venture in Albania. As of March 17, 2017, approximately 47% 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 and an operated interest in a joint venture in Albania.
Basis of presentation	Basis of presentation Our consolidated financial statements are expressed in U.S. Dollars and have been prepared by management in accordance with accounting principles generally accepted in the United States (“U.S. GAAP”). All amounts in these notes to the consolidated financial statements are in U.S. Dollars unless otherwise indicated. In preparing financial statements, management makes informed judgments and estimates that affect the reported amounts of assets and liabilities as of the date of the financial statements and affect the reported amounts of revenues and expenses during the reporting period. On an ongoing basis, management reviews estimates, including those related to fair value measurements associated with acquisitions and financial derivatives, the recoverability and impairment of long-lived assets, contingencies and income taxes. Changes in facts and circumstances may result in revised estimates and actual results may differ from these estimates.
Basis of preparation	Basis of preparation Our reporting standard for the presentation of our consolidated financial statements is U.S. GAAP. The consolidated financial statements include the accounts of the Company and all majority-owned, controlled subsidiaries. All significant intercompany balances and transactions have been eliminated in consolidation. During the year ended December 31, 2016, we reclassified certain balance sheet amounts previously reported on our consolidated balance sheet at December 31, 2015 to conform to current year presentation.
Cash and cash equivalents	Cash and cash equivalents Cash and cash equivalents include term deposits and investments with original maturities of three months or less at the date of acquisition. We consider all highly liquid debt instruments purchased with an original maturity of three months or less to be cash equivalents. We determine the appropriate classification of our investments in cash and cash equivalents and marketable securities at the time of purchase and reevaluate such designation at each balance sheet date.
Commodity derivative instruments	Commodity derivative instruments Financial Accounting Standards Board (“FASB”) Accounting Standards Codification (“ASC”) 815, Derivatives and Hedging
Fair value measurements	Fair value measurements We follow ASC 820, Fair Value Measurements and Disclosures ASC 820 characterizes inputs used in determining fair value according to a hierarchy that prioritizes those inputs based upon the degree to which they are observable. The three levels of the fair value measurement hierarchy are as follows: Level 1: Unadjusted quoted prices in active markets that are accessible at the measurement date for identical, unrestricted assets or liabilities. Level 2: Quoted prices in markets that are not active, or inputs which are observable, either directly or indirectly, for substantially the full term of the asset or liability. Level 3: Measured based on prices or valuation models that required inputs that are both significant to the fair value measurement and less observable for objective sources (i.e., supported by little or no market activity). As required by ASC 820, financial assets and liabilities are classified based on the lowest level of input that is significant to the fair value measurement. Our assessment of the significance of a particular input to the fair value measurement requires judgment, which may affect the valuation of the fair value of assets and liabilities and their placement within the fair value hierarchy levels. The determination of the fair values takes into account the market for our financial assets and liabilities, the associated credit risk and other factors as required by ASC 820. We consider active markets as those in which transactions for the assets or liabilities occur in sufficient frequency and volume to provide pricing information on an ongoing basis.
Foreign currency remeasurement and translation	Foreign currency remeasurement and translation The functional currency of our subsidiaries in Turkey, Bulgaria, Romania, Morocco, and Albania is the New Turkish Lira (“TRY”), the Bulgarian Lev, the Romanian New Leu, the Moroccan Dirham, and the U.S. Dollar (“USD”) respectively. We follow ASC 830, Foreign Currency Matters For certain subsidiaries, translation adjustments result from the process of translating the functional currency of subsidiary financial statements into the U.S. Dollar reporting currency. These translation adjustments are reported separately and accumulated in the consolidated balance sheets as a component of accumulated other comprehensive loss.
Oil and natural gas properties	Oil and natural gas properties In accordance with the successful efforts method of accounting for oil and natural gas properties, costs of productive wells, developmental dry holes and productive leases are capitalized into appropriate groups of properties based on geographical and geological similarities. Acquisition costs of proved properties are amortized using the unit-of-production method based on total proved reserves, and exploration well costs and additional development costs are amortized using the unit-of-production method based on proved developed reserves. Proceeds from the sale of properties are credited to property costs, and a gain or loss is recognized when a significant portion of an amortization base is sold or abandoned. Exploration costs, such as exploratory geological and geophysical costs, delay rentals and exploration overhead, are charged to expense as incurred. Exploratory drilling costs, including the cost of stratigraphic test wells, are initially capitalized but charged to exploration expense if and when the well is determined to be non-productive. The determination of an exploratory well’s ability to produce must be made within one year from the completion of drilling activities. The acquisition costs of unproved acreage are initially capitalized and are carried at cost, net of accumulated impairment provisions, until such leases are transferred to proved properties or charged to exploration expense as impairments of unproved properties.
Equipment and other property	Equipment and other property Equipment and other property are stated at cost, and inventory is stated at weighted average cost which does not exceed replacement cost. Depreciation is calculated using the straight-line method over the estimated useful lives (ranging from 3 to 7 years) of the respective assets. The costs of normal maintenance and repairs are charged to expense as incurred. Material expenditures that increase the life of an asset are capitalized and depreciated over the estimated remaining useful life of the asset. The cost of equipment sold, or otherwise disposed of, and the related accumulated depreciation, are removed from the accounts and any gain or loss is reflected in current earnings.
Impairment of long-lived assets	Impairment of long-lived assets We follow the provisions of ASC 360, Property, Plant, and Equipment Unproved oil and natural gas properties do not have producing properties and are valued on acquisition by management, with the assistance of an independent expert when necessary. As reserves are proved through the successful completion of exploratory wells, the cost is transferred to proved properties. The cost of the remaining unproved basis is periodically evaluated by management to assess whether the value of a property has diminished. To do this assessment, management considers (i) estimated potential reserves and future net revenues from an independent expert, (ii) the Company’s history in exploring the area, (iii) the Company’s future drilling plans per its capital drilling program prepared by the Company’s reservoir engineers and operations management and (iv) other factors associated with the area. Impairment is taken on the unproved property value if it is determined that the costs are not likely to be recoverable. The valuation is subjective and requires management to make estimates and assumptions which, with the passage of time, may prove to be materially different from actual results.
Joint interest activities	Joint interest activities Certain of our exploration, development and production activities are conducted jointly with other entities and, accordingly, the consolidated financial statements reflect only our proportionate interest in such activities.
Asset retirement obligations	Asset retirement obligations We recognize a liability for the fair value of all legal obligations associated with the retirement of tangible, long-lived assets and capitalize an equal amount as a cost of the asset. The cost associated with the abandonment obligation is included in the computation of depreciation, depletion and amortization. The liability accretes until we settle the obligation. We use a credit-adjusted risk-free interest rate in our calculation of asset retirement obligations.
Revenue recognition	Revenue recognition Revenue from the sale of crude oil and natural gas is recognized upon delivery to the purchaser when title passes. During the years ended December 31, 2016, 2015 and 2014, we sold $52.2 million, $63.0 million and $102.8 million, respectively, of oil to Türkiye Petrol Rafinerileri A.Ş. (“TUPRAS”), a privately owned oil refinery in Turkey, which represented approximately 76.1%, 74.0% and 74.1% of our total revenues, respectively.
Share-based compensation	Share-based compensation We follow ASC 718, Compensation—Stock Compensation
Series A Preferred Shares	Series A Preferred Shares On November 4, 2016, we issued 921,000 shares of 12.0% Series A Convertible Redeemable Preferred Shares (the “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 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 (See Note 5, “Series A Preferred Shares”).
Income taxes	Income taxes We follow the asset and liability method prescribed by ASC 740, Income Taxes As of December 31, 2016 and 2015, we have recorded an $8.1 million and $10.9 million liability, respectively, primarily due to uncertain tax positions related to the unwinding of all of our crude oil hedge collars and three-way contracts, which are included in long-term accrued liabilities on our consolidated balance sheet. We do not believe there will be any material changes in our unrecognized tax positions over the next twelve months. Our policy is that we recognize interest and penalties accrued on any unrecognized tax positions as a component of income tax expense. We are a Bermuda exempted company, and under current Bermuda law, we are not subject to tax on profits, income or dividends, nor is there any capital gains tax applicable to us in Bermuda.
Comprehensive income	Comprehensive income ASC 220, Comprehensive Income
Business combinations	Business combinations We follow ASC 805, Business Combinations Consolidation
Per share information	Per share information Basic per share amounts are calculated using the weighted average common shares outstanding during the year, excluding unvested restricted stock units. We use the treasury stock method to determine the dilutive effect of stock options and other dilutive instruments. Under the treasury stock method, only “in the money” dilutive instruments impact the diluted calculations in computing diluted earnings per share. Diluted calculations reflect the weighted average incremental common shares that would be issued upon exercise of dilutive options assuming the proceeds would be used to repurchase shares at average market prices for the period.
New Accounting Pronouncements	In March 2016, the 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)	12 Months Ended
	Dec. 31, 2016
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)	12 Months Ended
	Dec. 31, 2016
Property Plant And Equipment [Abstract]
Capitalized Costs under Successful Efforts Method for Oil and Natural Gas Properties	The following table sets forth the capitalized costs under the successful efforts method for oil and natural gas properties: 2016 2015 (in thousands) Oil and natural gas properties, proved: Turkey $ 196,743 $ 232,654 Bulgaria 471 489 Total oil and natural gas properties, proved 197,214 233,143 Oil and natural gas properties, unproved: Turkey 21,109 25,630 Bulgaria - - Total oil and natural gas properties, unproved 21,109 25,630 Gross oil and natural gas properties 218,323 258,773 Accumulated depletion (115,401 ) (113,732 ) Net oil and natural gas properties $ 102,922 $ 145,041
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: 2016 2015 (in thousands) Other equipment $ 1,780 $ 2,148 Inventory 10,704 17,348 Gas gathering system and facilities 145 4,790 Vehicles 364 400 Leasehold improvements, office equipment and software 7,280 7,487 Gross equipment and other property 20,273 32,173 (5,237 ) (8,801 ) Net equipment and other property $ 15,036 $ 23,372

Commodity derivative instrume29

Commodity derivative instruments (Tables)	12 Months Ended
	Dec. 31, 2016
Derivative Instruments And Hedging Activities Disclosure [Abstract]
Fair Value of Derivative Instruments of Future Crude Oil Production	At December 31, 2016, we had outstanding commodity derivative contracts with respect to our future crude oil production as set forth in the tables below: Fair Value of Derivative Instruments as of December 31, 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 ) At December 31, 2015, we had outstanding commodity derivative contracts with respect to our future crude oil production as set forth in the tables below: Fair Value of Derivative Instruments as of December 31, 2015 Puts Weighted Average Minimum Estimated Fair Quantity Price Value of Type Period (Bbl/day) (per Bbl) Asset (in thousands) Put January 1, 2016— December 31, 2016 808 $ 50.00 $ 3,235 Put January 1, 2017— December 31, 2017 610 $ 50.00 1,798 Put January 1, 2018— December 31, 2018 494 $ 50.00 1,292 Put January 1, 2019— March 31, 2019 443 $ 50.00 280 Total Estimated Fair Value of Asset $ 6,605
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 December 31, 2016 and December 31, 2015, and (ii) the net recorded fair value as reflected on our consolidated balance sheets at December 31, 2016 and December 31, 2015. As of December 31, 2016 Gross Amount Net Amount of Gross Offset in the Liabilities Amount of Consolidated Presented in the Recognized Balance Consolidated Underlying Commodity Location on Balance Sheet Liabilities Sheet Balance Sheet (in thousands) Crude oil Current liabilities $ 596 $ – $ 596 Crude oil Long-term liabilities 242 – 242 As of December 31, 2015 Gross Amount Net Amount of Gross Offset in the Assets Amount of Consolidated Presented in the Recognized Balance Consolidated Underlying Commodity Location on Balance Sheet Assets Sheet Balance Sheet (in thousands) Crude oil Current assets $ 3,235 $ – $ 3,235 Crude oil Long-term assets 3,370 – 3,370

Asset Retirement obligations (T

Asset Retirement obligations (Tables)	12 Months Ended
	Dec. 31, 2015
Asset Retirement Obligation Disclosure [Abstract]
Changes in Asset Retirement Obligations	The following table summarizes the changes in our ARO for the years ended December 31, 2016 and 2015: 2016 2015 (in thousands) Asset retirement obligations at beginning of period $ 9,237 $ 10,543 Change in estimates – 385 Liabilities settled (7 ) – Foreign exchange change effect (1,604 ) (2,137 ) Additions 16 78 Accretion expense 373 368 Asset retirement obligations at end of period 8,015 9,237 Less: TBNG asset retirement obligations held for sale 3,182 3,716 Long-term portion $ 4,833 $ 5,521

Loans payable (Tables)

Loans payable (Tables)	12 Months Ended
	Dec. 31, 2016
Debt Disclosure [Abstract]
Debt	As of the dates indicated, our third-party debt consisted of the following: December 31, December 31, 2016 2015 Fixed and floating rate loans (in thousands) Term Loan $ 25,000 $ - 2017 Notes 13,750 34,400 2017 Notes - Related Party 500 20,600 Senior Credit Facility – 32,075 Unamortized deferred financing costs - Senior Credit Facility and 2017 Notes – (1,200 ) ANBE Note 2,694 3,592 West Promissory Notes – 1,000 Loans payable 41,944 90,467 Less: current portion 38,194 35,467 Long-term portion $ 3,750 $ 55,000

Shareholders' equity (Tables)

Shareholders' equity (Tables)	12 Months Ended
	Dec. 31, 2016
Equity [Abstract]
Restricted Stock Units Activity	Share-based compensation of approximately $0.6 million, $1.1 million and $1.4 million with respect to awards of RSUs was recorded for the years ended December 31, 2016, 2015 and 2014, respectively. As of December 31, 2016, we had approximately $0.5 million of unrecognized compensation expense related to unvested RSUs, which is expected to be recognized over a weighted average period of 1.5 years. The following table sets forth RSU activity for the year ended December 31, 2016: Number of RSUs (in thousands) Weighted Average Grant Date Fair Value Per RSU Unvested RSUs outstanding at December 31, 2015 429 $ 5.60 Granted 698 0.81 Forfeited (103 ) 4.46 Vested (263 ) 5.16 Unvested RSUs outstanding at December 31, 2016 761 $ 1.52
Basic and Diluted Earnings Per Common Share Computations	The following table presents the basic and diluted earnings per common share computations: (in thousands, except per share amounts) 2016 2015 2014 Net (loss) income from continuing operations $ (22,445 ) $ (26,665 ) $ 29,214 Net income (loss) from discontinued operations $ 16,202 $ (80,873 ) $ (138 ) Basic net (loss) income per common share: Shares: Weighted average common shares outstanding 43,885 40,841 37,829 Basic net (loss) income per common share: Continuing operations $ (0.51 ) $ (0.65 ) $ 0.77 Discontinued operations $ 0.37 $ (1.98 ) $ – Diluted net (loss) income per common share: Shares: Weighted average shares outstanding 43,885 40,841 37,829 Dilutive effect of: Restricted share units – – 152 Convertible notes – – 50 Weighted average common and common equivalent shares outstanding 43,885 40,841 38,031 Diluted net (loss) income per common share: Continuing operations $ (0.51 ) $ (0.65 ) $ 0.77 Discontinued operations $ 0.37 $ (1.98 ) $ –

Income taxes (Tables)

Income taxes (Tables)	12 Months Ended
	Dec. 31, 2016
Income Tax Disclosure [Abstract]
Reconciliation of Bermuda Income Tax Expense to Actual Income Tax Expense	The income tax provision differs from the amount that would be obtained by applying the Bermuda statutory income tax rate of 0% for 2016, 2015 and 2014 to income (loss) from continuing operations for the year as follows: 2016 2015 2014 (in thousands except rates) Statutory rate 0.00 % 0.00 % 0.00 % (Loss) income from continuing operations before income taxes $ (16,399 ) $ (4,436 ) $ 42,873 Increase (decrease) resulting from: Foreign tax rate differentials $ (1,018 ) $ 1,676 $ 9,262 Uncertain tax position (958 ) 10,066 1,260 Unremitted earnings 4,777 11,561 – Derivative contracts – (5,038 ) – Change in valuation allowance (147 ) 3,232 228 Expiration of non-capital tax loss carryovers 2,056 1,740 1,841 Other 1,336 (1,008 ) 1,068 Total $ 6,046 $ 22,229 $ 13,659
Components of Net Deferred Income Tax Liability	The components of the net deferred income tax liability at December 31, 2016 and 2015 were as follows: 2016 2015 (in thousands) Deferred tax assets Property and equipment $ 3,003 $ 3,749 Unrealized gains on derivative contracts 168 – Timing of accruals 162 351 Non-capital loss carryovers 22,364 24,098 Valuation allowance (25,452 ) (27,870 ) Total deferred tax assets $ 245 $ 328 Deferred tax liabilities Property and equipment $ (9,986 ) $ (15,514 ) Unremitted earnings (8,586 ) (6,981 ) Timing of accruals (479 ) (436 ) Total deferred tax liabilities (19,051 ) (22,931 ) Net deferred tax liabilities $ (18,806 ) $ (22,603 ) Components of net deferred tax liabilities Non-current assets $ 245 $ - Non-current liabilities (19,051 ) (22,603 ) Net deferred tax liabilities $ (18,806 ) $ (22,603 )
Schedule of Unrecognized Tax Benefits	The unrecognized tax benefits at December 31, 2016 and 2015 were as follows: 2016 2015 (in thousands) Unrecognized tax benefits at beginning of period $ 11,014 $ 1,188 Gross increases - tax positions in prior period 910 – Gross decreases - tax positions in prior period (3,087 ) – Gross increases - tax positions in current period 1,219 10,066 Gross decreases - tax positions in current period – – Foreign exchange change effect (1,914 ) (240 ) Unrecognized tax benefits at end of period 8,142 11,014 Less: TBNG liability held for sale (63 ) (76 ) Unrecognized tax benefits at end of period $ 8,079 $ 10,938

Segment information (Tables)

Segment information (Tables)	12 Months Ended
	Dec. 31, 2016
Segment Reporting [Abstract]
Financial Information of Geographic Segments	In accordance with ASC 280, Segment Reporting Corporate Turkey Bulgaria Total (in thousands) For the year ended December 31, 2016 Total revenues $ – $ 68,595 $ – $ 68,595 Production – 12,293 75 12,368 Exploration, abandonment, and impairment 1,417 4,546 – 5,963 Cost of purchased gas – 4,418 – 4,418 Seismic and other exploration – 91 13 104 General and administrative 8,170 7,948 202 16,320 Depreciation, depletion and amortization 264 28,761 – 29,025 Accretion of asset retirement obligations – 354 19 373 Total costs and expenses 9,851 58,411 309 68,571 Operating (loss) income (9,851 ) 10,184 (309 ) 24 Interest and other expense (8,633 ) (3,208 ) – (11,841 ) Interest and other income 656 1,888 2 2,546 Loss on commodity derivative contracts – (3,257 ) – (3,257 ) Foreign exchange gain (loss) 428 (4,293 ) (6 ) (3,871 ) (Loss) income from continuing operations before income taxes (17,400 ) 1,314 (313 ) (16,399 ) Income tax expense – (6,046 ) – (6,046 ) Net loss from continuing operations $ (17,400 ) $ (4,732 ) $ (313 ) $ (22,445 ) Total assets at December 31, 2016 $ 17,007 $ 153,560 $ 609 $ 171,176 (1) Capital expenditures for the year ended December 31, 2016 $ – $ 10,186 $ – $ 10,186 For the year ended December 31, 2015 Total revenues $ – $ 85,064 $ – $ 85,064 Production – 12,804 69 12,873 Exploration, abandonment, and impairment – 17,778 3,766 21,544 Cost of purchased gas – 2,082 – 2,082 Seismic and other exploration 55 264 51 370 General and administrative 12,729 11,132 277 24,138 Depreciation, depletion and amortization 306 37,401 – 37,707 Accretion of asset retirement obligations – 350 18 368 Total costs and expenses 13,090 81,811 4,181 99,082 Operating (loss) income (13,090 ) 3,253 (4,181 ) (14,018 ) Interest and other expense (7,383 ) (5,694 ) – (13,077 ) Interest and other income 354 500 1 855 Gain on commodity derivative contracts – 27,457 – 27,457 Foreign exchange loss (58 ) (5,589 ) (6 ) (5,653 ) (Loss) income from continuing operations before income taxes (20,177 ) 19,927 (4,186 ) (4,436 ) Income tax expense – (22,229 ) – (22,229 ) Net loss from continuing operations $ (20,177 ) $ (2,302 ) $ (4,186 ) $ (26,665 ) Total assets at December 31, 2015 $ 14,205 $ 197,944 $ 601 $ 212,750 (2) Capital expenditures for the year ended December 31, 2015 $ 163 $ 22,262 $ 41 $ 22,466 For the year ended December 31, 2014 Total revenues $ – $ 138,807 $ 23 $ 138,830 Production – 18,059 134 18,193 Exploration, abandonment, and impairment – 19,820 44 19,864 Cost of purchased gas – 2,055 – 2,055 Seismic and other exploration 178 4,106 1 4,285 Revaluation of contingent consideration – – (2,500 ) (2,500 ) General and administrative 14,418 14,984 1,669 31,071 Depreciation, depletion and amortization 124 48,452 18 48,594 Accretion of asset retirement obligations – 387 19 406 Total costs and expenses 14,720 107,863 (615 ) 121,968 Operating (loss) income (14,720 ) 30,944 638 16,862 Interest and other expense (36 ) (6,007 ) (1 ) (6,044 ) Interest and other income 350 770 4 1,124 Loss on commodity derivative contracts – 37,454 – 37,454 Foreign exchange loss (4 ) (6,497 ) (22 ) (6,523 ) (Loss) income loss from continuing operations before income Taxes (14,410 ) 56,664 619 42,873 Income tax expense – (13,659 ) – (13,659 ) Net (loss) income from continuing operations $ (14,410 ) $ 43,005 $ 619 $ 29,214 Total assets at December 31, 2014 $ 51,429 $ 306,578 $ 4,675 $ 362,682 (2) Goodwill at December 31, 2014 $ – $ 6,935 $ – $ 6,935 Capital expenditures for the year ended December 31, 2014 $ 545 $ 109,563 $ 1,393 $ 111,501 (1) Excludes assets of TBNG of $25.2 million. (2) Excludes assets of TBNG and our discontinued Albanian and Moroccan operations of $85.4 million and $181.0 million at December 31, 2015 and 2014, respectively.

Financial instruments (Tables)

Financial instruments (Tables)	12 Months Ended
	Dec. 31, 2016
Fair Value Disclosures [Abstract]
Valuation of Financial Assets and Liabilities	The following table summarizes the valuation of our financial 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 ) The following table summarizes the valuation of our financial assets and liabilities as of December 31, 2015: 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 $ – $ 6,605 $ – $ 6,605 Disclosed but not carried at fair value Liabilities: Senior Credit Facility – – (30,050 ) (30,050 ) 2017 Notes – – (44,489 ) (44,489 ) Total $ – $ 6,605 $ (74,539 ) $ (67,934 )

Commitments (Tables)

Commitments (Tables)	12 Months Ended
	Dec. 31, 2016
Commitments And Contingencies Disclosure [Abstract]
Aggregate Annual Commitments Other Than Debt	Our aggregate annual commitments, other than our loans payable, as of December 31, 2016 were as follows: Payments Due By Year Total 2017 2018 2019 2020 2021 Thereafter (in thousands) Series A Preferred Shares dividends (1) $ 43,348 $ 5,526 $ 5,526 $ 5,526 $ 5,526 $ 5,526 $ 15,718 Interest 2,962 2,874 88 - - - - Leases 1,370 698 603 69 - - - Total $ 47,680 $ 9,098 $ 6,217 $ 5,595 $ 5,526 $ 5,526 $ 15,718 (1) Dividends on the Series A Preferred Shares may be paid by the Company, in its sole discretion, in cash at a rate of 12% per annum or in common shares at a rate of 16% per annum or in a combination of cash and common shares. The amounts in the table assume that the Company pays all future dividend payments solely in cash.

Related Party Transactions (Tab

Related Party Transactions (Tables)	12 Months Ended
	Dec. 31, 2016
Related Party Transactions [Abstract]
Related Party Accounts Receivable and Accounts Payable	The following table summarizes related party accounts receivable and accounts payable as of December 31, 2016 and December 31, 2015: 2016 2015 (in thousands) Related party accounts receivable: Riata Management Service Agreement $ 528 $ 194 PSIL MSA 234 – Viking International master services agreement – 214 Total related party accounts receivable $ 762 $ 408 Related party accounts payable: Riata Management Service Agreement $ 346 $ 384 PSIL MSA 1,315 – Interest payable on 2017 Notes 183 – Viking International master services agreement – 2,169 Total related party accounts payable $ 1,844 $ 2,553

Assets and Liabilities Held f38

Assets and Liabilities Held for Sale and Discontinued Operations (Tables)	12 Months Ended
	Dec. 31, 2016
Summary of Assets and Liabilities Held for Sale and Operating Results from Discontinued Operations	The assets and liabilities held for sale at December 31, 2016 and 2015 are as shown below. As a result of the joint venture transaction related to the Delvina Assets and the reassessment of the Moroccan contingent liabilities, there were no remaining assets or liabilities held for sale at December 31, 2016 for Albania or Morocco. TBNG Albania Morocco Total Held for Sale (in thousands) For the year ended December 31, 2016 Assets Cash $ 1,551 $ – $ – $ 1,551 Other current assets 7,511 – – 7,511 Property and equipment, net 16,155 – – 16,155 Total current assets held for sale $ 25,217 $ – $ – $ 25,217 Liabilities Accounts payable and other accrued liabilities $ 11,240 $ – $ – $ 11,240 Deferred tax liability 4,698 – – 4,698 Total current liabilities held for sale $ 15,938 $ – $ – $ 15,938 For the year ended December 31, 2015 Assets Cash $ 1,780 $ 1,201 $ 16 $ 2,997 Other current assets 7,956 1,853 11 9,820 Property and equipment, net – 48,430 – 48,430 Total current assets held for sale 9,736 51,484 27 61,247 Property and equipment, net 22,292 – – 22,292 Other long-term assets 1,900 – – 1,900 Total assets held for sale $ 33,928 $ 51,484 $ 27 $ 85,439 Liabilities Accounts payable and other accrued liabilities $ 8,733 $ 37,888 $ 6,352 $ 52,973 Accounts payable - related party 131 3,540 – 3,671 Loan payable 5,132 6,123 – 11,255 Deferred tax liability – 15,286 – 15,286 Total current liabilities held for sale $ 13,996 $ 62,837 $ 6,352 $ 83,185 Deferred tax liability 4,757 – – 4,757 Other long-term liabilities 4,748 – – 4,748 Total liabilities held for sale $ 23,501 $ 62,837 $ 6,352 $ 92,690 Our operating results from discontinued operations for the years ended December 31, 2016, 2015 and 2014 are summarized as follows: Albania Morocco Total (in thousands) For the year ended December 31, 2016 Total revenues $ 626 $ - $ 626 Production and transportation expense 1,138 - 1,138 Total other costs and expenses 561 - 561 Total other income 10,168 6,903 17,071 Income before income taxes $ 9,095 $ 6,903 $ 15,998 Income tax benefit 204 - 204 Income from discontinued operations $ 9,299 $ 6,903 $ 16,202 For the year ended December 31, 2015 Total revenues $ 8,565 $ - $ 8,565 Production and transportation expense 11,615 - 11,615 Exploration, abandonment and impairment 86,577 - 86,577 Total other costs and expenses 9,229 5 9,234 Total other income 1,819 - 1,819 Loss before income taxes $ (97,037 ) $ (5 ) $ (97,042 ) Income tax benefit 16,169 - 16,169 Loss from discontinued operations $ (80,868 ) $ (5 ) $ (80,873 ) For the year ended December 31, 2014 Total revenues $ 1,898 $ - $ 1,898 Total costs and expenses 2,984 20 3,004 Total other income 356 - 356 Loss before income taxes $ (730 ) $ (20 ) $ (750 ) Income tax benefit 612 - 612 Loss from discontinued operations $ (118 ) $ (20 ) $ (138 )
Debt	As of the dates indicated, our third-party debt consisted of the following: December 31, December 31, 2016 2015 Fixed and floating rate loans (in thousands) Term Loan $ 25,000 $ - 2017 Notes 13,750 34,400 2017 Notes - Related Party 500 20,600 Senior Credit Facility – 32,075 Unamortized deferred financing costs - Senior Credit Facility and 2017 Notes – (1,200 ) ANBE Note 2,694 3,592 West Promissory Notes – 1,000 Loans payable 41,944 90,467 Less: current portion 38,194 35,467 Long-term portion $ 3,750 $ 55,000
Discontinued Operations, Held-for-sale [Member]
Debt	As of December 31, 2015, our third-party debt held for sale consisted of the following: December 31, 2015 (in thousands) Fixed and floating rate loans Term Loan Facility $ 6,123 TBNG credit facility 5,192 Unamortized deferred financing costs - TBNG credit facility (60 ) Loan payable $ 11,255

General - Additional Informatio

General - Additional Information (Detail) - Segment	12 Months Ended
	Dec. 31, 2016	Mar. 17, 2017
Nature Of Business [Line Items]
Number of operating segments	2
Subsequent Event [Member]
Nature Of Business [Line Items]
Percentage of common shares owned		47.00%

Financial Restructuring and E40

Financial Restructuring and Elimination of Going Concern Assumption - Additional Information (Detail) - USD ($) $ in Millions	Feb. 24, 2017	Dec. 31, 2016	Dec. 31, 2015
Financial Restructuring And Elimination Of Going Concern Assumption [Line Items]
Long-term debt		$ 3.8	$ 55
Short-term debt		38.2	35.5
Cash		10	5.7
Working capital deficit		$ 17.3	24.5
Subsequent Event [Member]
Financial Restructuring And Elimination Of Going Concern Assumption [Line Items]
Repayments of short-term debt	$ 2.7
Subsequent Event [Member] | Thrace Basin Natural Gas (Turkiye) Corporation [Member]
Financial Restructuring And Elimination Of Going Concern Assumption [Line Items]
Gross proceeds on sale of ownership interests	20.9
Net cash proceeds on sale of ownership interests	16.3
Escrow deposit	$ 3.1
13.0% Convertible Notes Due in 2017 [Member] | Convertible Debt [Member]
Financial Restructuring And Elimination Of Going Concern Assumption [Line Items]
Debt instrument interest rate stated percentage		13.00%
Senior Credit Facility [Member]
Financial Restructuring And Elimination Of Going Concern Assumption [Line Items]
Borrowing base deficiency			$ 15.5

Significant Accounting Polici41

Significant Accounting Policies - Additional information (Detail) - USD ($)	Nov. 04, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Significant Accounting Policies [Line Items]
Determination of exploratory well's ability to produce, term		1 year
Sales revenue, crude oil and natural gas		$ 52,200,000	$ 63,000,000	$ 102,800,000
Liability for Uncertain Tax Positions, Current		$ 8,100,000	$ 10,900,000
Series A Preferred Shares [Member]
Significant Accounting Policies [Line Items]
Preferred shares, issued	921,000	510,000
Preferred stock, dividend rate, percentage	12.00%
Preferred stock, shares issued value per share	$ 50	$ 50
Series A Preferred Shares [Member] | 2017 Notes [Member]
Significant Accounting Policies [Line Items]
Preferred shares, issued	815,000
Proceeds from issuance of preferred stock	$ 40,750,000
Convertible preferred shares issued upon conversion	20
Value of principal amount on conversion	$ 1,000,000
Series A Preferred Shares [Member] | 2017 Notes [Member] | Certain Holders [Member]
Significant Accounting Policies [Line Items]
Preferred shares, issued	106,000
Proceeds from issuance of preferred stock	$ 5,300,000
Sales Revenue, Goods, Net [Member] | Revenue from Rights Concentration Risk [Member]
Significant Accounting Policies [Line Items]
Concentration Risk, Percentage		76.10%	74.00%	74.10%
Minimum [Member]
Significant Accounting Policies [Line Items]
Equipment and other property, estimated useful lives		3 years
Maximum [Member]
Significant Accounting Policies [Line Items]
Equipment and other property, estimated useful lives		7 years

Series A Preferred Shares - Add

Series A Preferred Shares - Additional Information (Detail)	Jan. 02, 2017USD ($)	Nov. 04, 2016USD ($)Director$ / sharesshares	Dec. 31, 2016USD ($)shares	Aug. 31, 2016USD ($)
TEMI Term Loan [Member] | DenizBank [Member] | Credit Agreement [Member]
Redeemable Noncontrolling Interest [Line Items]
Line Of Credit Facility Maximum Borrowing Capacity | $		$ 30,000,000		$ 30,000,000
Series A Preferred Shares [Member]
Redeemable Noncontrolling Interest [Line Items]
Preferred shares, issued		921,000	510,000
Convertible preferred shares issued upon conversion		45.754
Preferred stock, shares issued value per share | $ / shares		$ 50
Preferred shares, value | $			$ 25,500,000
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 adjustment 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%.
Preferred stock, dividend rate, percentage		12.00%
Dividend payment description			Dividends are payable quarterly, on June 30, September 30, December 31, and March 31 of each year.
Cash dividend paid | $		$ 900,000
Preferred stock voting rights			no voting rights
Preferred shares, outstanding			510,000
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 its most recent independent reserve report filed or furnished by us on EDGAR. In addition, until our 2017 Notes are repaid in full, we will not issue indebtedness for money borrowed (other than ordinary trade indebtedness and up to $30.0 million borrowed from DenizBank, A.S. (“DenizBank”)) unless the net proceeds thereof are used (i) to redeem, retire or repay the 2017 Notes, (ii) spud, drill or complete two designated wells, or (iii) used in connection with collateralization or guarantees with respect to our hedging efforts.
Maximum amount of indebtedness for borrowed money allowed under certificate of designation | $		$ 100,000,000
PV10 reserve value percentage		35.00%
Series A Preferred Shares [Member] | Maximum [Member]
Redeemable Noncontrolling Interest [Line Items]
Right to elect number of directors | Director		2
Series A Preferred Shares [Member] | Minimum [Member]
Redeemable Noncontrolling Interest [Line Items]
Right to elect number of directors | Director		1
Series A Preferred Shares [Member] | Dividend Paid in Cash [Member]
Redeemable Noncontrolling Interest [Line Items]
Preferred stock, dividend rate, percentage		12.00%
Series A Preferred Shares [Member] | Dividend Paid in Common Shares [Member]
Redeemable Noncontrolling Interest [Line Items]
Preferred stock, dividend rate, percentage		16.00%
Series A Preferred Shares [Member] | 2017 Notes [Member]
Redeemable Noncontrolling Interest [Line Items]
Preferred shares, issued		815,000
Amount of notes exchanged | $		$ 40,750,000
Convertible preferred shares issued upon conversion		20
Value of principal amount on conversion | $		$ 1,000,000
Series A Preferred Shares [Member] | Certain Holders [Member] | 2017 Notes [Member]
Redeemable Noncontrolling Interest [Line Items]
Preferred shares, issued		106,000
Proceeds from issuance of preferred stocks | $		$ 5,300,000
Series A Preferred Shares [Member] | Two Director [Member]
Redeemable Noncontrolling Interest [Line Items]
Preferred shares, outstanding		400,000
Series A Preferred Shares [Member] | One Director [Member] | Maximum [Member]
Redeemable Noncontrolling Interest [Line Items]
Preferred shares, outstanding		80,000
Series A Preferred Shares [Member] | One Director [Member] | Minimum [Member]
Redeemable Noncontrolling Interest [Line Items]
Preferred shares, outstanding		399,999
Subsequent Event [Member] | 2017 Notes [Member]
Redeemable Noncontrolling Interest [Line Items]
Redemption of notes | $	$ 4,300,000
Subsequent Event [Member] | Series A Preferred Shares [Member] | 2017 Notes [Member]
Redeemable Noncontrolling Interest [Line Items]
Redemption of notes | $	$ 4,300,000
Related Party [Member] | Series A Preferred Shares [Member]
Redeemable Noncontrolling Interest [Line Items]
Preferred shares, issued			411,000
Preferred shares, value | $			$ 20,550,000
Preferred shares, outstanding			411,000

Series A Preferred Shares - Sch

Series A Preferred Shares - Schedule of Redemption Prices (Detail) - Series A 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	Dec. 31, 2016	Dec. 31, 2015
Property Plant And Equipment [Line Items]
Oil and natural gas properties, proved	$ 197,214	$ 233,143
Oil and natural gas properties, unproved	21,109	25,630
Gross oil and natural gas properties	218,323	258,773
Accumulated depletion	(115,401)	(113,732)
Net oil and natural gas properties	102,922	145,041
Turkey [Member]
Property Plant And Equipment [Line Items]
Oil and natural gas properties, proved	196,743	232,654
Oil and natural gas properties, unproved	21,109	25,630
Bulgaria [Member]
Property Plant And Equipment [Line Items]
Oil and natural gas properties, proved	$ 471	$ 489

Property and Equipment - Additi

Property and Equipment - Additional Information (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 30, 2015
Property Plant And Equipment [Line Items]
Proved development wells excluded from depletion	$ 1,900	$ 700
Acquisition costs of proved properties	13,200	18,000
Well costs and additional development costs	66,700	100,700
Exploratory dry hole costs	4,500
Impairment charge on well		16,000	$ 19,900
Cash spent for the amount impaired	1,500
Inventory	3,647
Inventory [Member]
Property Plant And Equipment [Line Items]
Property plant and equipment excluded from depreciation	14,400			$ 21,300
Unproved Properties [Member]
Property Plant And Equipment [Line Items]
Impairment charge on well			13,800
Exploratory Well Impairments [Member]
Property Plant And Equipment [Line Items]
Impairment charge on well	1,700
License Impairments [Member]
Property Plant And Equipment [Line Items]
Impairment charge on well	300
Molla And Bakuk Field | Turkey [Member]
Property Plant And Equipment [Line Items]
Impairment charge on well		5,800
Deventci-R2 well [Member] | Bulgaria [Member]
Property Plant And Equipment [Line Items]
Impairment charge on well		3,700
Pinar - 1 well [Member] | Turkey [Member]
Property Plant And Equipment [Line Items]
Impairment charge on well		3,500
Exploratory drilling costs capitalized	1,800
South Goksu-1 well | Turkey [Member]
Property Plant And Equipment [Line Items]
Impairment charge on well		$ 700
Catak-1 Well [Member] | Unproved Properties [Member]
Property Plant And Equipment [Line Items]
Impairment charge on well			3,500
Kazanci-5 Well [Member] | Unproved Properties [Member]
Property Plant And Equipment [Line Items]
Impairment charge on well			2,800
Bahar-2 Side Track Well [Member] | Unproved Properties [Member]
Property Plant And Equipment [Line Items]
Impairment charge on well			$ 7,500
Hayrabolu-10 well [Member] | Turkey [Member]
Property Plant And Equipment [Line Items]
Exploratory drilling costs capitalized	1,000
TNBG [Member]
Property Plant And Equipment [Line Items]
Impairment charge on well	$ 2,500

Property and Equipment - Histor

Property and Equipment - Historical Cost of Equipment and Other Property on Gross Basis with Accumulated Depreciation (Detail) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Property Plant And Equipment [Line Items]
Gross equipment and other property	$ 20,273	$ 32,173
Accumulated depreciation	(5,237)	(8,801)
Net equipment and other property	15,036	23,372
Other equipment [Member]
Property Plant And Equipment [Line Items]
Gross equipment and other property	1,780	2,148
Inventory [Member]
Property Plant And Equipment [Line Items]
Gross equipment and other property	10,704	17,348
Gas gathering system and facilities [Member]
Property Plant And Equipment [Line Items]
Gross equipment and other property	145	4,790
Vehicles [Member]
Property Plant And Equipment [Line Items]
Gross equipment and other property	364	400
Leasehold improvements, office equipment and software [Member]
Property Plant And Equipment [Line Items]
Gross equipment and other property	$ 7,280	$ 7,487

Commodity Derivative Instrume47

Commodity Derivative Instruments - Additional Information (Detail) - USD ($) $ in Thousands	Sep. 09, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Derivatives Fair Value [Line Items]
(Loss) gain on commodity derivative contracts		$ (3,257)	$ 27,457	$ 37,454
Crude Oil [Member]
Derivatives Fair Value [Line Items]
Proceeds from hedging transactions	$ 2,600

Commodity Derivative Instrume48

Commodity Derivative Instruments - Fair Value of Derivative Instruments of Future Crude Oil Production (Detail) $ in Thousands	12 Months Ended
	Dec. 31, 2016USD ($)$ / bblbbl	Dec. 31, 2015USD ($)$ / bblbbl
Derivatives Fair Value [Line Items]
Estimated Fair Value of Liability | $	$ (838)
Estimated Fair Value of Asset | $		$ 6,605
Collar - January 1, 2017 - December 31, 2017 [Member]
Derivatives Fair Value [Line Items]
Quantity (Bbl/day) | bbl	296
Collars Weighted Average Minimum Price (per Bbl)	47.50
Weighted Average Maximum Price (per Bbl)	61
Estimated Fair Value of Liability | $	$ (289)
Collar - January 2, 2017 - December 31, 2017 [Member]
Derivatives Fair Value [Line Items]
Quantity (Bbl/day) | bbl	445
Collars Weighted Average Minimum Price (per Bbl)	50
Weighted Average Maximum Price (per Bbl)	61.50
Estimated Fair Value of Liability | $	$ (307)
Collar - January 1, 2018 - February 28, 2018 [Member]
Derivatives Fair Value [Line Items]
Quantity (Bbl/day) | bbl	458
Collars Weighted Average Minimum Price (per Bbl)	50
Weighted Average Maximum Price (per Bbl)	61.50
Estimated Fair Value of Liability | $	$ (74)
Collar - January 1, 2018 - May 31, 2018 [Member]
Derivatives Fair Value [Line Items]
Quantity (Bbl/day) | bbl	298
Collars Weighted Average Minimum Price (per Bbl)	47.50
Weighted Average Maximum Price (per Bbl)	61
Estimated Fair Value of Liability | $	$ (168)
Put - January 1, 2016 - December 31, 2016 [Member]
Derivatives Fair Value [Line Items]
Quantity (Bbl/day) | bbl		808
Collars Weighted Average Minimum Price (per Bbl)		50
Estimated Fair Value of Asset | $		$ 3,235
Put - January 1, 2017 - December 31, 2017 [Member]
Derivatives Fair Value [Line Items]
Quantity (Bbl/day) | bbl		610
Collars Weighted Average Minimum Price (per Bbl)		50
Estimated Fair Value of Asset | $		$ 1,798
Put - January 1, 2018 - December 31, 2018 [Member]
Derivatives Fair Value [Line Items]
Quantity (Bbl/day) | bbl		494
Collars Weighted Average Minimum Price (per Bbl)		50
Estimated Fair Value of Asset | $		$ 1,292
Put - January 1, 2019 - March 31, 2019 [Member]
Derivatives Fair Value [Line Items]
Quantity (Bbl/day) | bbl		443
Collars Weighted Average Minimum Price (per Bbl)		50
Estimated Fair Value of Asset | $		$ 280

Commodity Derivative Instrume49

Commodity Derivative Instruments - Summary of Gross Fair Value of Commodity Derivative Instruments by Balance Sheet Classification (Detail) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Derivatives Fair Value [Line Items]
Gross Amount of Recognized Liabilities	$ 838
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
Gross Amount of Recognized Assets		$ 6,605
Net Amount of Assets Presented in the Consolidated Balance Sheet, Current assets		3,235
Net Amount of Assets Presented in the Consolidated Balance Sheet, Long-term assets		3,370
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
Crude Oil [Member] | Current Assets [Member]
Derivatives Fair Value [Line Items]
Gross Amount of Recognized Assets		3,235
Crude Oil [Member] | Long Term Assets [Member]
Derivatives Fair Value [Line Items]
Gross Amount of Recognized Assets		$ 3,370

Asset Retirement Obligations -

Asset Retirement Obligations - Additional Information (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Asset Retirement Obligations [Line Items]
Asset retirement obligation, net present value	$ 8,015	$ 9,237	$ 10,543
Asset retirement obligation, undiscounted value	$ 12,600
Turkey [Member]
Asset Retirement Obligations [Line Items]
Inflation rate per annum used to adjust asset retirement obligation	6.75%
Credit-adjusted risk-free rate used to discount asset retirement obligation	5.51%

Asset Retirement Obligations 51

Asset Retirement Obligations - Changes in Asset Retirement Obligations (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Asset Retirement Obligation Disclosure [Abstract]
Asset retirement obligations at beginning of period	$ 9,237	$ 10,543
Change in estimates		385
Liabilities settled	(7)
Foreign exchange change effect	(1,604)	(2,137)
Additions	16	78
Accretion expense	373	368	$ 406
Asset retirement obligations at end of period	8,015	9,237	$ 10,543
Less: TBNG asset retirement obligations held for sale	3,182	3,716
Long-term portion	$ 4,833	$ 5,521

Loans Payable - Debt (Detail)

Loans Payable - Debt (Detail) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Loans payable	$ 41,944	$ 90,467
Less: current portion	38,194	35,467
Long-term portion	3,750	55,000
Senior Credit Facility [Member]
Debt Instrument [Line Items]
Loans payable		32,075
Term Loan [Member]
Debt Instrument [Line Items]
Loans payable	25,000
13.0% convertible notes due in 2017 [Member] | Convertible Debt [Member]
Debt Instrument [Line Items]
Loans payable	13,750	34,400
13.0% Convertible Notes due in 2017 and Senior Credit Facility [Member]
Debt Instrument [Line Items]
Unamortized deferred financing costs		(1,200)
ANBE Note [Member]
Debt Instrument [Line Items]
Loans payable	2,694	3,592
West Promissory Notes [Member]
Debt Instrument [Line Items]
Loans payable		1,000
Related Party [Member] | 13.0% convertible notes due in 2017 [Member] | Convertible Debt [Member]
Debt Instrument [Line Items]
Loans payable	$ 500	$ 20,600

Loans Payable - Additional Info

Loans Payable - Additional Information (Detail)

Nov. 04, 2016USD ($)shares

Sep. 07, 2016USD ($)

Jan. 31, 2017USD ($)

Oct. 31, 2016Installment

Sep. 30, 2017USD ($)

Jun. 30, 2017USD ($)

Mar. 31, 2017USD ($)

Dec. 31, 2016USD ($)$ / sharesshares

Dec. 31, 2016USD ($)$ / sharesshares

Dec. 31, 2015USD ($)

Dec. 31, 2014USD ($)

Aug. 31, 2016USD ($)

Jun. 30, 2016shares

Dec. 30, 2015USD ($)

Aug. 31, 2015USD ($)

Line Of Credit Facility [Line Items]

Loans payable

$ 41,944,000

$ 41,944,000

$ 90,467,000

Private Placement [Member]

Line Of Credit Facility [Line Items]

Common stock, shares issued for cash interest | shares

355,826

Non-cash Facilities [Member] | DenizBank [Member]

Line Of Credit Facility [Line Items]

Line Of Credit Facility Maximum Borrowing Capacity

$ 20,000,000

Loan Financing Costs [Member]

Line Of Credit Facility [Line Items]

Deferred Finance Costs, Current, Net

$ 0

0

1,200,000

Amortization of Deferred Loan Origination Fees, Net

$ 1,200,000

1,600,000

$ 1,000,000

TEMI Term Loan [Member]

Line Of Credit Facility [Line Items]

Debt instrument interest rate stated percentage

5.25%

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)

Debt instrument payment terms

Payable in six monthly installments of $1.25 million each through February 2017 and thereafter in twelve monthly installments of $1.88 million each through February 2018

Amount of each installment payable through February 2017

$ 1,250,000

Amount of each installment payable through February 2018

$ 1,880,000

Line of credit facility, expiration date

Feb. 28, 2018

Loans payable

$ 25,000,000

$ 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

$ 30,000,000

TEMI Term Loan [Member] | Line of Credit [Member]

Line Of Credit Facility [Line Items]

Loans payable

$ 25,000,000

$ 25,000,000

TEMI Term Loan [Member] | Line of Credit [Member] | N. Malone Mitchell 3rd [Member]

Line Of Credit Facility [Line Items]

Line of credit facility ownership percentage

80.00%

TEMI Term Loan [Member] | Line of Credit [Member] | Selami Erdem Uras [Member]

Line Of Credit Facility [Line Items]

Line of credit facility ownership percentage

20.00%

Senior Credit Facility [Member] | BNP Paribas and IFC [Member]

Line Of Credit Facility [Line Items]

Line of credit facility, repayment

$ 22,900,000

Senior Credit Facility [Member] | Line of Credit [Member]

Line Of Credit Facility [Line Items]

Line of credit facility, initiation date

May 6, 2014

13.0% Convertible Notes Due in 2017 [Member] | Series A Preferred Stock [Member]

Line Of Credit Facility [Line Items]

Value of principal amount on conversion

$ 40,750,000

Convertible preferred shares issued upon conversion | shares

815,000

13.0% Convertible Notes Due in 2017 [Member] | Series A Preferred Stock [Member] | Subsequent Event [Member]

Line Of Credit Facility [Line Items]

Redemption of notes

$ 4,300,000

13.0% Convertible Notes Due in 2017 [Member] | Private Placement [Member]

Line Of Credit Facility [Line Items]

Common stock, shares issued for cash interest | shares

2,511,742

2,511,742

13.0% Convertible Notes Due in 2017 [Member] | Convertible Debt [Member]

Line Of Credit Facility [Line Items]

Debt instrument interest rate stated percentage

13.00%

13.00%

Loans payable

$ 13,750,000

$ 13,750,000

34,400,000

Notes payable

$ 14,300,000

$ 14,300,000

55,000,000

Frequency of payments

semi-annually

Debt instrument, maturity date

Jul. 1, 2017

Debt Instrument, Convertible, Conversion Ratio | $ / shares

$ 6.80

$ 6.80

Debt instrument redemption price percentage

100.00%

Sale of assets required to use a portion of the net proceeds to make an offer to repurchase

$ 50,000,000

West Promissory Notes [Member]

Line Of Credit Facility [Line Items]

Loans payable

1,000,000

West Promissory Notes [Member] | TransAtlantic USA [Member]

Line Of Credit Facility [Line Items]

Line Of Credit Facility Maximum Borrowing Capacity

$ 1,500,000

ANBE Promissory Note [Member] | TransAtlantic USA [Member]

Line Of Credit Facility [Line Items]

Loans payable

$ 2,700,000

2,700,000

Number of installments | Installment

4

Debt instrument, principal installments

900,000

ANBE Promissory 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

$ 5,000,000

Debt instrument interest rate stated percentage

13.00%

13.00%

Line of credit facility borrowing capacity

2,700,000

2,700,000

$ 3,600,000

$ 3,600,000

ANBE Promissory Note [Member] | Subsequent Event [Member] | TransAtlantic USA [Member]

Line Of Credit Facility [Line Items]

Debt instrument, principal installments

$ 900,000

$ 900,000

$ 900,000

Extender ANBE Note [Member] | TransAtlantic USA [Member]

Line Of Credit Facility [Line Items]

Debt instrument, maturity date

Sep. 30, 2017

Unsecured lines of credit [Member]

Line Of Credit Facility [Line Items]

Loans payable

$ 0

$ 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

Shareholders' Equity - Addition

Shareholders' Equity - Additional Information (Detail) - USD ($) $ / shares in Units, $ in Millions	Jun. 30, 2016	Apr. 17, 2016	Aug. 13, 2015	Apr. 24, 2015	Nov. 30, 2014	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Employee Service Share Based Compensation Allocation Of Recognized Period Costs [Line Items]
Issuance of common shares					3,218,641
Issuance of common shares, price per share					$ 7.41
Antidilutive securities excluded from computation of earnings per share amount						17,300,000	8,900,000	0
Common share purchase warrants issued			233,333	233,333
Common share purchase			1
Common share purchase warrants, exercise price			$ 2.99	$ 5.65				$ 5.99
Warrants [Member]
Employee Service Share Based Compensation Allocation Of Recognized Period Costs [Line Items]
Share-based compensation expense							$ 0.5
Common share purchase								1
Restricted Stock Units [Member]
Employee Service Share Based Compensation Allocation Of Recognized Period Costs [Line Items]
Estimated forfeiture rate of RSUs						12.50%
Share-based compensation expense						$ 0.6	1.1	$ 1.4
Unrecognized compensation expense						$ 0.5
Unrecognized compensation expense recognition period						1 year 6 months
Restricted Stock Units [Member] | Maximum [Member]
Employee Service Share Based Compensation Allocation Of Recognized Period Costs [Line Items]
Restricted stock unit, vesting period						4 years
Direct [Member]
Employee Service Share Based Compensation Allocation Of Recognized Period Costs [Line Items]
Issuance of common shares		225,000
Mr. Mitchell [Member]
Employee Service Share Based Compensation Allocation Of Recognized Period Costs [Line Items]
Common share purchase warrants issued								134,169
Mitchell, and his Children [Member]
Employee Service Share Based Compensation Allocation Of Recognized Period Costs [Line Items]
Common share purchase warrants issued								23,333
Mitchell And Other Related Parties [Member]
Employee Service Share Based Compensation Allocation Of Recognized Period Costs [Line Items]
Share-based compensation expense							$ 0.5
Common share purchase warrants issued			233,333	233,333
Common share purchase warrants, exercise price			$ 2.99	$ 5.65
Private Placement [Member]
Employee Service Share Based Compensation Allocation Of Recognized Period Costs [Line Items]
Issuance of common shares	5,773,305
Issuance of common shares, price per share	$ 0.6599
Threshold percentage of common share weighted average price	75.00%
Threshold trading period of common share weighted average price	10 days
Private Placement [Member] | 2017 Notes [Member]
Employee Service Share Based Compensation Allocation Of Recognized Period Costs [Line Items]
Issuance of common shares	2,511,742
Common shares issued for debt conversion	2,905,737
Private Placement [Member] | ANBE Note [Member]
Employee Service Share Based Compensation Allocation Of Recognized Period Costs [Line Items]
Common shares issued for debt conversion	355,826

Shareholders' Equity - Restrict

Shareholders' Equity - Restricted Stock Unit Activity (Detail) - Restricted Stock Units [Member] shares in Thousands	12 Months Ended
	Dec. 31, 2016$ / sharesshares
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Unvested RSUs outstanding, beginning balance | shares	429
Granted | shares	698
Forfeited | shares	(103)
Vested | shares	(263)
Unvested RSUs outstanding, ending balance | shares	761
Unvested RSUs, weighted average grant date fair value Per RSU, beginning balance | $ / shares	$ 5.60
Granted, weighted average grant date fair value Per RSU | $ / shares	0.81
Forfeited, weighted average grant date fair value Per RSU | $ / shares	4.46
Vested, weighted average grant date fair value Per RSU | $ / shares	5.16
Unvested RSUs weighted average grant date fair value Per RSU, ending balance | $ / shares	$ 1.52

Shareholders' Equity - Basic an

Shareholders' Equity - Basic and Diluted Earnings Per Common Share Computations (Detail) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Equity [Abstract]
Net (loss) income from continuing operations	$ (22,445)	$ (26,665)	$ 29,214
Net income (loss) from discontinued operations	$ 16,202	$ (80,873)	$ (138)
Weighted average common shares outstanding	43,885	40,841	37,829
Continuing operations	$ (0.51)	$ (0.65)	$ 0.77
Discontinued operations	$ 0.37	$ (1.98)
Restricted share units			152
Convertible notes			50
Weighted average common and common equivalent shares outstanding	43,885	40,841	38,031
Continuing operations	$ (0.51)	$ (0.65)	$ 0.77
Discontinued operations	$ 0.37	$ (1.98)

Income Taxes - Reconciliation o

Income Taxes - Reconciliation of Bermuda Income Tax Expense to Actual Income Tax Expense (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Income Tax Disclosure [Abstract]
Statutory rate	0.00%	0.00%	0.00%
(Loss) income from continuing operations before income taxes	$ (16,399)	$ (4,436)	$ 42,873
Increase (decrease) resulting from:
Foreign tax rate differentials	(1,018)	1,676	9,262
Uncertain tax position	(958)	10,066	1,260
Unremitted earnings	4,777	11,561
Derivative contracts		(5,038)
Change in valuation allowance	(147)	3,232	228
Expiration of non-capital tax loss carryovers	2,056	1,740	1,841
Other	1,336	(1,008)	1,068
Total	$ 6,046	$ 22,229	$ 13,659

Income Taxes - Components of Ne

Income Taxes - Components of Net Deferred Income Tax Liability (Detail) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Deferred tax assets
Property and equipment	$ 3,003	$ 3,749
Unrealized gains on derivative contracts	168
Timing of accruals	162	351
Non-capital loss carryovers	22,364	24,098
Valuation allowance	(25,452)	(27,870)
Total deferred tax assets	245	328
Deferred tax liabilities
Property and equipment	(9,986)	(15,514)
Unremitted earnings	(8,586)	(6,981)
Timing of accruals	(479)	(436)
Total deferred tax liabilities	(19,051)	(22,931)
Net deferred tax liabilities	(18,806)	(22,603)
Components of net deferred tax liabilities
Non-current assets	245
Non-current liabilities	(19,051)	(22,603)
Net deferred tax liabilities	$ (18,806)	$ (22,603)

Income Taxes - Additional Infor

Income Taxes - Additional Information (Detail) TRY in Millions, RON in Millions, BGN in Millions	12 Months Ended
	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2016TRY	Dec. 31, 2016RON	Dec. 31, 2016BGN
Income Tax [Line Items]
Valuation allowance	$ 25,452,000	$ 27,870,000
Liability for Uncertain Tax Positions, Current	8,100,000	10,900,000
Unrecognized Tax Benefits, Period Increase (Decrease)	0
13.0% convertible notes due in 2017 [Member] | 2017 Notes [Member]
Income Tax [Line Items]
Notes Payable	14,300,000	55,000,000
Turkish Foreign Subsidiaries [Member]
Income Tax [Line Items]
Withdrew reinvestment assertion		135,200,000
Dividend withholding taxes	201,300,000	$ 135,200,000
Turkey [Member]
Income Tax [Line Items]
Non-capital tax losses	$ 18,000,000		TRY 63.2
Non-capital tax losses, expiration date	2,017
Romania [Member]
Income Tax [Line Items]
Non-capital tax losses	$ 1,900,000			RON 8.1
Non-capital tax losses, expiration date	2,018
Bulgaria [Member]
Income Tax [Line Items]
Non-capital tax losses	$ 3,900,000				BGN 7.1
Non-capital tax losses, expiration date	2,017
U.S [Member]
Income Tax [Line Items]
Non-capital tax losses	$ 51,700,000
Non-capital tax losses, expiration date	2,018

Income Taxes - Schedule of Unre

Income Taxes - Schedule of Unrecognized Tax Benefits (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Income Tax Disclosure [Abstract]
Unrecognized tax benefits at beginning of period	$ 11,014	$ 1,188
Gross increases - tax positions in prior period	910
Gross decreases - tax positions in prior period	(3,087)
Gross increases - tax positions in current period	1,219	10,066
Foreign exchange change effect	(1,914)	(240)
Unrecognized tax benefits at end of period	8,142	11,014
Less: TBNG liability held for sale	(63)	(76)
Unrecognized tax benefits at end of period	$ 8,079	$ 10,938

Segment Information - Additiona

Segment Information - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2016Segment
Segment Reporting [Abstract]
Number of reportable geographic segments	2

Segment Information - Financial

Segment Information - Financial Information of Geographic Segments (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016		Dec. 31, 2015		Dec. 31, 2014
Segment Reporting Information [Line Items]
Total revenues	$ 68,595		$ 85,064		$ 138,830
Production	12,368		12,873		18,193
Exploration, abandonment and impairment	5,963		21,544		19,864
Cost of purchased gas	4,418		2,082		2,055
Seismic and other exploration	104		370		4,285
Revaluation of contingent consideration					(2,500)
General and administrative	16,320		24,138		31,071
Depreciation, depletion and amortization	29,025		37,707		48,594
Accretion of asset retirement obligations	373		368		406
Total costs and expenses	68,571		99,082		121,968
Operating (loss) income	24		(14,018)		16,862
Interest and other expense	(11,841)		(13,077)		(6,044)
Interest and other income	2,546		855		1,124
Gain (loss) on commodity derivative contracts	(3,257)		27,457		37,454
Foreign exchange gain (loss)	(3,871)		(5,653)		(6,523)
Income (loss) from continuing operations before income taxes	(16,399)		(4,436)		42,873
Income tax expense	(6,046)		(22,229)		(13,659)
Net (loss) income from continuing operations	(22,445)		(26,665)		29,214
Total assets	171,176	[1]	212,750	[2]	362,682	[2]
Goodwill					6,935
Capital expenditures	10,186		22,466		111,501
Corporate, Non-Segment [Member]
Segment Reporting Information [Line Items]
Exploration, abandonment and impairment	1,417
Seismic and other exploration			55		178
General and administrative	8,170		12,729		14,418
Depreciation, depletion and amortization	264		306		124
Total costs and expenses	9,851		13,090		14,720
Operating (loss) income	(9,851)		(13,090)		(14,720)
Interest and other expense	(8,633)		(7,383)		(36)
Interest and other income	656		354		350
Foreign exchange gain (loss)	428		(58)		(4)
Income (loss) from continuing operations before income taxes	(17,400)		(20,177)		(14,410)
Net (loss) income from continuing operations	(17,400)		(20,177)		(14,410)
Total assets	17,007		14,205		51,429
Capital expenditures			163		545
Operating Segments [Member] | Turkey [Member]
Segment Reporting Information [Line Items]
Total revenues	68,595		85,064		138,807
Production	12,293		12,804		18,059
Exploration, abandonment and impairment	4,546		17,778		19,820
Cost of purchased gas	4,418		2,082		2,055
Seismic and other exploration	91		264		4,106
General and administrative	7,948		11,132		14,984
Depreciation, depletion and amortization	28,761		37,401		48,452
Accretion of asset retirement obligations	354		350		387
Total costs and expenses	58,411		81,811		107,863
Operating (loss) income	10,184		3,253		30,944
Interest and other expense	(3,208)		(5,694)		(6,007)
Interest and other income	1,888		500		770
Gain (loss) on commodity derivative contracts	(3,257)		27,457		37,454
Foreign exchange gain (loss)	(4,293)		(5,589)		(6,497)
Income (loss) from continuing operations before income taxes	1,314		19,927		56,664
Income tax expense	(6,046)		(22,229)		(13,659)
Net (loss) income from continuing operations	(4,732)		(2,302)		43,005
Total assets	153,560		197,944		306,578
Goodwill					6,935
Capital expenditures	10,186		22,262		109,563
Operating Segments [Member] | Bulgaria [Member]
Segment Reporting Information [Line Items]
Total revenues					23
Production	75		69		134
Exploration, abandonment and impairment			3,766		44
Seismic and other exploration	13		51		1
Revaluation of contingent consideration					(2,500)
General and administrative	202		277		1,669
Depreciation, depletion and amortization					18
Accretion of asset retirement obligations	19		18		19
Total costs and expenses	309		4,181		(615)
Operating (loss) income	(309)		(4,181)		638
Interest and other expense					(1)
Interest and other income	2		1		4
Foreign exchange gain (loss)	(6)		(6)		(22)
Income (loss) from continuing operations before income taxes	(313)		(4,186)		619
Net (loss) income from continuing operations	(313)		(4,186)		619
Total assets	$ 609		601		4,675
Capital expenditures			$ 41		$ 1,393
[1]	Excludes assets of TBNG of $25.2 million
[2]	Excludes assets of TBNG and our discontinued Albanian and Moroccan operations of $85.4 million and $181.0 million at December 31, 2015 and 2014, respectively.

Segment Information - Financi63

Segment Information - Financial Information of Geographic Segments (Parenthetical) (Detail) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Segment Reporting [Abstract]
Assets from discontinued operations and services	$ 25,200	$ 85,439	$ 181,000

Financial Instruments - Additio

Financial Instruments - Additional Information (Detail) - 12 months ended Dec. 31, 2016 TRY 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 primarily relate to transactions denominated in the Bulgarian Lev, European Union Euro, Albanian Lek, and TRY. We are also subject to foreign currency exposures resulting from translating the functional currency of our subsidiary financial statements into the U.S. Dollar reporting currency. We have not used foreign currency forward contracts to manage exchange rate fluctuations. At December 31, 2016, we had 30.6 million TRY (approximately $8.7 million) in cash and cash equivalents, which exposes us to exchange rate risk based on fluctuations in the value of the TRY.
Allowance for doubtful accounts | $	$ 0
Number of financial institutions | Institution	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	$ 8,700,000	TRY 30.6

Financial Instruments - Valuati

Financial Instruments - Valuation of Financial Assets and Liabilities (Detail) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Assets (liabilities), fair value	$ (36,892)	$ (67,934)
Disclosed but not carried at fair value [Member] | Term Loan [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Liabilities, fair value	(22,500)
Disclosed but not carried at fair value [Member] | Senior Credit Facility [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Liabilities, fair value		(30,050)
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	(13,554)	(44,489)
Measured on a recurring basis [Member] | Derivative Financial Instruments (commodity) [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Liabilities, fair value	(838)
Assets, fair value		6,605
Significant Other Observable Inputs (Level 2) [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Assets (liabilities), fair value	(838)	6,605
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]
Liabilities, fair value	(838)
Assets, fair value		6,605
Significant Unobservable Inputs (Level 3) [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Assets (liabilities), fair value	(36,054)	(74,539)
Significant Unobservable Inputs (Level 3) [Member] | Disclosed but not carried at fair value [Member] | Term Loan [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Liabilities, fair value	(22,500)
Significant Unobservable Inputs (Level 3) [Member] | Disclosed but not carried at fair value [Member] | Senior Credit Facility [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Liabilities, fair value		(30,050)
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	$ (13,554)	$ (44,489)

Commitments - Aggregate Annual

Commitments - Aggregate Annual Commitments Other Than Debt (Detail) $ in Thousands	Dec. 31, 2016USD ($)
Other Commitments [Line Items]
Total	$ 47,680
2,017	9,098
2,018	6,217
2,019	5,595
2,020	5,526
2,021	5,526
Thereafter	15,718
Series A Preferred Shares Dividends [Member]
Other Commitments [Line Items]
Total	43,348	[1]
2,017	5,526	[1]
2,018	5,526	[1]
2,019	5,526	[1]
2,020	5,526	[1]
2,021	5,526	[1]
Thereafter	15,718	[1]
Interest [Member]
Other Commitments [Line Items]
Total	2,962
2,017	2,874
2,018	88
Leases [Member]
Other Commitments [Line Items]
Total	1,370
2,017	698
2,018	603
2,019	$ 69
[1]	Dividends on the Series A Preferred Shares may be paid by the Company, in its sole discretion, in cash at a rate of 12% per annum or in common shares at a rate of 16% per annum or in a combination of cash and common shares. The amounts in the table assume that the Company pays all future dividend payments solely in cash.

Commitments - Aggregate Annua67

Commitments - Aggregate Annual Commitments Other Than Debt (Parenthetical) (Detail) - Series A Preferred Shares [Member]	Dec. 31, 2016
Other Commitments [Line Items]
Cash dividend rate, percentage	12.00%
Common share dividend rate, percentage	16.00%

Commitments - Additional Inform

Commitments - Additional Information (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Commitments And Contingencies Disclosure [Abstract]
Normal operations purchase arrangements, notice period	30 days
Rent expense	$ 1.4	$ 1.8	$ 2.2

Contingencies - Additional Info

Contingencies - Additional Information (Detail) - USD ($)	1 Months Ended	12 Months Ended
	Feb. 28, 2013	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2012	Sep. 30, 2016	Oct. 31, 2015
Loss Contingencies [Line Items]
General and administrative		$ 16,320,000	$ 24,138,000	$ 31,071,000
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

Related Party Transactions - Ad

Related Party Transactions - Additional Information (Detail)

Nov. 04, 2016USD ($)shares

Jun. 30, 2016shares

Apr. 19, 2016USD ($)

Aug. 13, 2015$ / sharesshares

Apr. 24, 2015$ / sharesshares

Apr. 05, 2013USD ($)ft²

Aug. 23, 2011USD ($)ft²

Nov. 30, 2014shares

Sep. 30, 2017USD ($)

Jun. 30, 2017USD ($)

Mar. 31, 2017USD ($)

Dec. 31, 2016USD ($)InstallmentRoomshares

Dec. 31, 2016USD ($)InstallmentRoomshares

Dec. 31, 2015USD ($)

Dec. 31, 2014$ / sharesshares

Aug. 31, 2016USD ($)

Dec. 30, 2015USD ($)

Feb. 20, 2015USD ($)

Jun. 13, 2012USD ($)

Related Party Transaction [Line Items]

Common share purchase warrants issued | shares

233,333

233,333

Common share purchase warrants issued, expiration period

Jan. 6, 2018

Jan. 6, 2018

Common share purchase | shares

1

Common share purchase warrants, exercise price | $ / shares

$ 2.99

$ 5.65

$ 5.99

Issuance of common shares | shares

3,218,641

Note receivable - related party

$ 7,624,000

$ 7,624,000

$ 11,500,000

$ 11,500,000

Amount due to related party

$ 6,000

6,000

Capital and operating expenditures

$ 7,000,000

20,000,000

Notes sold

$ 55,000,000

Number of installments | Installment

4

4

Repayments of notes Payable

$ 900,000

Loans payable

41,944,000

$ 41,944,000

90,467,000

Line of Credit Facility, Remaining Borrowing Capacity

$ 0

$ 0

Scenario Forecast [Member]

Related Party Transaction [Line Items]

Repayments of notes Payable

$ 900,000

$ 900,000

$ 900,000

Lease Agreement With Gundem [Member]

Related Party Transaction [Line Items]

Number of rooms leased | Room

6

6

Longfellow [Member]

Related Party Transaction [Line Items]

Lease agreement area, additional office space leased | ft²

5,300

Lease expiration period

5 years

Lease rent payable

$ 6,625

Longfellow [Member] | First Floor Commencement Date [Member]

Related Party Transaction [Line Items]

Lease agreement area, additional office space leased | ft²

4,700

Lease expiration period

5 years

Lease rent payable

$ 8,120

Warrants [Member]

Related Party Transaction [Line Items]

Common share purchase | shares

1

Share-based compensation expense

500,000

Pinon Foundation [Member]

Related Party Transaction [Line Items]

Purchase of notes

10,000,000

Dalea [Member]

Related Party Transaction [Line Items]

Purchase of notes

2,000,000

Dalea [Member] | Viking Drilling [Member]

Related Party Transaction [Line Items]

Percentage of ownership interest owned by related party

85.00%

85.00%

Mitchell, and his Children [Member]

Related Party Transaction [Line Items]

Common share purchase warrants issued | shares

23,333

Purchase of notes

2,000,000

Mr. Mitchell [Member]

Related Party Transaction [Line Items]

Common share purchase warrants issued | shares

134,169

Joint Venture [Member] | Dalea and Funds [Member]

Related Party Transaction [Line Items]

Conversion of Stock, Shares Converted | shares

40,000

Joint Venture [Member] | Dalea and Funds [Member] | Promissory Note [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

$ 2,000,000

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]

Promissory note, collateral amount

$ 200,000

$ 200,000

Mitchell, his wife and his children [Member] | Riata Management [Member]

Related Party Transaction [Line Items]

Percentage of ownership interest owned by related party

100.00%

100.00%

Mitchell, his wife and his children [Member] | Longfellow [Member]

Related Party Transaction [Line Items]

Percentage of ownership interest owned by related party

100.00%

100.00%

MedOil Supply, LLC [Member] | Riata Management [Member]

Related Party Transaction [Line Items]

Percentage of ownership interest owned by related party

100.00%

100.00%

Viking International Master Service Agreement [Member]

Related Party Transaction [Line Items]

Service agreement term

5 years

Brian Bailey and his children [Member]

Related Party Transaction [Line Items]

Purchase of notes

100,000

Barbara And Terry Pope [Member]

Related Party Transaction [Line Items]

Purchase of notes

$ 200,000

Private Placement [Member]

Related Party Transaction [Line Items]

Issuance of common shares | shares

5,773,305

Private Placement [Member] | Cash [Member] | Dalea and Funds [Member]

Related Party Transaction [Line Items]

Issuance of common shares | shares

814,627

2017 Notes [Member] | Dalea and Funds [Member]

Related Party Transaction [Line Items]

Payment of common shares | shares

201,459

Interest receivable

$ 7,600,000

$ 7,600,000

2017 Notes [Member] | Joint Venture [Member] | Dalea and Funds [Member]

Related Party Transaction [Line Items]

Conversion of Stock, Amount Converted

$ 2,000,000

2017 Notes [Member] | Private Placement [Member] | Dalea and Funds [Member]

Related Party Transaction [Line Items]

Issuance of common shares | shares

1,974,452

ANBE Note [Member]

Related Party Transaction [Line Items]

Issuance of common shares | shares

355,826

Loans payable

2,694,000

2,694,000

$ 3,592,000

ANBE Note [Member] | Private Placement [Member]

Related Party Transaction [Line Items]

Issuance of common shares | shares

355,826

ANBE Promissory Note [Member] | TransAtlantic USA [Member]

Related Party Transaction [Line Items]

Loans payable

2,700,000

2,700,000

ANBE Promissory Note [Member] | TransAtlantic USA [Member] | Convertible Promissory Note [Member]

Related Party Transaction [Line Items]

Debt instrument interest rate stated percentage

13.00%

13.00%

Line Of Credit Facility Maximum Borrowing Capacity

$ 5,000,000

$ 5,000,000

Line of credit facility borrowing capacity

$ 2,700,000

$ 2,700,000

$ 3,600,000

$ 3,600,000

Series A Preferred Shares [Member]

Related Party Transaction [Line Items]

Preferred shares, issued | shares

921,000

510,000

510,000

Convertible preferred shares issued upon conversion | shares

45.754

Series A Preferred Shares [Member] | 2017 Notes [Member]

Related Party Transaction [Line Items]

Preferred shares, issued | shares

815,000

Amount of notes exchanged

$ 40,750,000

Convertible preferred shares issued upon conversion | shares

20

Value of principal amount on conversion

$ 1,000,000

Series A Preferred Shares [Member] | 2017 Notes [Member] | Certain Holders [Member]

Related Party Transaction [Line Items]

Preferred shares, issued | shares

106,000

Proceeds from issuance of preferred stocks

$ 5,300,000

Series A Preferred Shares [Member] | 2017 Notes [Member] | Private Placement Exchange Offer [Member]

Related Party Transaction [Line Items]

Preferred shares, issued | shares

815,000

Amount of notes exchanged

$ 40,750,000

Convertible preferred shares issued upon conversion | shares

20

Value of principal amount on conversion

$ 1,000,000

Series A Preferred Shares [Member] | 2017 Notes [Member] | Private Placement Exchange Offer [Member] | Pinon Foundation [Member]

Related Party Transaction [Line Items]

Preferred shares, issued | shares

200,000

Amount of notes exchanged

$ 10,000,000

Series A Preferred Shares [Member] | 2017 Notes [Member] | Private Placement Exchange Offer [Member] | Dalea [Member]

Related Party Transaction [Line Items]

Preferred shares, issued | shares

41,000

Amount of notes exchanged

$ 2,100,000

Series A Preferred Shares [Member] | 2017 Notes [Member] | Private Placement Exchange Offer [Member] | Mitchell, and his Children [Member]

Related Party Transaction [Line Items]

Preferred shares, issued | shares

40,000

Amount of notes exchanged

$ 2,000,000

Series A Preferred Shares [Member] | 2017 Notes [Member] | Private Placement [Member] | Pinon Foundation [Member]

Related Party Transaction [Line Items]

Preferred shares, issued | shares

5,000

Proceeds from issuance of preferred stocks

$ 250,000

Series A Preferred Shares [Member] | 2017 Notes [Member] | Private Placement [Member] | Mitchell, and his Children [Member]

Related Party Transaction [Line Items]

Preferred shares, issued | shares

1,000

Proceeds from issuance of preferred stocks

$ 50,000

Series A Preferred Shares [Member] | 2017 Notes [Member] | Private Placement [Member] | Certain Holders [Member]

Related Party Transaction [Line Items]

Preferred shares, issued | shares

106,000

Proceeds from issuance of preferred stocks

$ 5,300,000

Related Party Transactions - Re

Related Party Transactions - Related Party Accounts Receivable and Accounts Payable (Detail) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Related Party Transaction [Line Items]
Total related party accounts receivable	$ 762	$ 408
Total related party accounts payable	1,844	2,553
Viking International Master Service Agreement [Member]
Related Party Transaction [Line Items]
Total related party accounts receivable		214
Total related party accounts payable		2,169
Riata Management Service Agreement [Member]
Related Party Transaction [Line Items]
Total related party accounts receivable	528	194
Total related party accounts payable	346	$ 384
PSIL MSA [Member]
Related Party Transaction [Line Items]
Total related party accounts receivable	234
Total related party accounts payable	1,315
Interest Payable on 2017 Notes [Member]
Related Party Transaction [Line Items]
Total related party accounts payable	$ 183

Assets and Liabilities Held f72

Assets and Liabilities Held for Sale and Discontinued Operations - Additional Information (Detail) - USD ($) $ in Thousands	Sep. 01, 2016	Feb. 29, 2016	Dec. 31, 2016	Dec. 31, 2015	Nov. 30, 2016
Discontinued Operations And Disposal Groups [Line Items]
Disposal group, liabilities				$ 92,690
Disposal group, accounts payable and accrued liabilities			$ 11,240	52,973
Disposal group, debt				11,255
Loans payable			$ 41,944	90,467
Term Loan Facility [Member] | TransAtlantic Albania [Member]
Discontinued Operations And Disposal Groups [Line Items]
Loans payable				6,100
Debt failure to paid, amount				1,100
TBNG Credit Facility [Member]
Discontinued Operations And Disposal Groups [Line Items]
Loans payable				5,200
Line of Credit [Member] | Term Loan Facility [Member] | Raiffeisen Bank Sh A | TransAtlantic Albania [Member]
Discontinued Operations And Disposal Groups [Line Items]
Line of credit facility expiration date			Dec. 31, 2016
Line of Credit Facility, Frequency of Payments			TransAtlantic Albania was a party to the Term Loan Facility with Raiffeisen. The loan was scheduled to mature on December 31, 2016 and bore interest at the rate of LIBOR plus 5.5%, with a minimum interest rate of 7.0%. TransAtlantic Albania was required to pay 1/16th of the total commitment each quarter on the last business day of each of March, June, September and December each year.
Penalty Plus Breakage Costs			3.00%
Line of Credit [Member] | TBNG Credit Facility [Member] | Turkish Bank [Member] | Mitchell, and his Children [Member]
Discontinued Operations And Disposal Groups [Line Items]
Line of credit facility ownership percentage			97.50%
LIBOR [Member] | Line of Credit [Member] | Term Loan Facility [Member] | Raiffeisen Bank Sh A | TransAtlantic Albania [Member]
Discontinued Operations And Disposal Groups [Line Items]
Debt instrument basis spread on variable rate			5.50%
Minimum [Member] | LIBOR [Member] | Line of Credit [Member] | Term Loan Facility [Member] | Raiffeisen Bank Sh A | TransAtlantic Albania [Member]
Discontinued Operations And Disposal Groups [Line Items]
Revolving Credit Facility With Company Libor Minimum Rate			7.00%
Albania [Member]
Discontinued Operations And Disposal Groups [Line Items]
Disposal group, liabilities				62,837
Disposal group, accounts payable and accrued liabilities				37,888
Disposal group, debt				6,123
Albania [Member] | Stream Oil and Gas Ltd [Member]
Discontinued Operations And Disposal Groups [Line Items]
Receivable from sale of outstanding equities		$ 2,300
Disposal group, liabilities		29,200
Disposal group, accounts payable and accrued liabilities		23,100
Disposal group, debt		6,100
Warrants stock		$ 1,600	$ 0
Net book value of the assets held for sale to their fair value				$ 73,000
Albania [Member] | Stream Oil and Gas Ltd [Member] | Maximum [Member]
Discontinued Operations And Disposal Groups [Line Items]
Option to acquire ownership interest, percentage		25.00%
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
Disposal group, frequency of periodic payment receivable			each quarter
Disposal group, payment receivable term	18 months
Disposal group, outstanding shares transferred first payment to be received					$ 1,000
Gain on disposal of discontinued operations			$ 9,400
Disposal group discontinued operation percentage of operating costs payment			25.00%
Disposal group discontinued operation number of years deferral capital expenditures payment			3 years
Percentage of ownership interest in assets held for sale, no longer hold			25.00%

Assets and Liabilities Held f73

Assets and Liabilities Held for Sale and Discontinued Operations - Assets and Liabilities Held for Sale (Detail) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Assets
Cash	$ 1,551	$ 2,997
Other current assets	7,511	9,820
Property and equipment, net	16,155	48,430
Total current assets held for sale	25,217	61,247
Property and equipment, net		22,292
Other long-term assets		1,900
Total assets held for sale	25,200	85,439	$ 181,000
Liabilities
Accounts payable and other accrued liabilities	11,240	52,973
Accounts payable - related party		3,671
Loan payable		11,255
Deferred tax liability	4,698	15,286
Total current liabilities held for sale	15,938	83,185
Deferred tax liability		4,757
Other long-term liabilities		4,748
Total liabilities held for sale		92,690
TNBG [Member]
Assets
Cash	1,551	1,780
Other current assets	7,511	7,956
Property and equipment, net	16,155
Total current assets held for sale	25,217	9,736
Property and equipment, net		22,292
Other long-term assets		1,900
Total assets held for sale		33,928
Liabilities
Accounts payable and other accrued liabilities	11,240	8,733
Accounts payable - related party		131
Loan payable		5,132
Deferred tax liability	4,698
Total current liabilities held for sale	$ 15,938	13,996
Deferred tax liability		4,757
Other long-term liabilities		4,748
Total liabilities held for sale		23,501
Albania [Member]
Assets
Cash		1,201
Other current assets		1,853
Property and equipment, net		48,430
Total current assets held for sale		51,484
Total assets held for sale		51,484
Liabilities
Accounts payable and other accrued liabilities		37,888
Accounts payable - related party		3,540
Loan payable		6,123
Deferred tax liability		15,286
Total current liabilities held for sale		62,837
Total liabilities held for sale		62,837
Morocco [Member]
Assets
Cash		16
Other current assets		11
Total current assets held for sale		27
Total assets held for sale		27
Liabilities
Accounts payable and other accrued liabilities		6,352
Total current liabilities held for sale		6,352
Total liabilities held for sale		$ 6,352

Assets and Liabilities Held f74

Assets and Liabilities Held for Sale and Discontinued Operations - Summary of Third Party Debt Held for sale (Detail) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Loan payable	$ 41,944	$ 90,467
Discontinued Operations, Held-for-sale [Member]
Debt Instrument [Line Items]
Loan payable		11,255
Discontinued Operations, Held-for-sale [Member] | Term Loan Facility [Member]
Debt Instrument [Line Items]
Loan payable		6,123
Discontinued Operations, Held-for-sale [Member] | TBNG Credit Facility [Member]
Debt Instrument [Line Items]
Loan payable		5,192
Unamortized deferred financing costs		$ (60)

Assets and Liabilities Held f75

Assets and Liabilities Held for Sale and Discontinued Operations - Operating Results from Discontinued Operations (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Discontinued Operations And Disposal Groups [Line Items]
Total revenues	$ 626	$ 8,565	$ 1,898
Production and transportation expense	1,138	11,615
Exploration, abandonment and impairment		86,577
Total other costs and expenses	561	9,234	3,004
Total other income	17,071	1,819	356
Income (Loss) before income taxes	15,998	(97,042)	(750)
Income tax benefit	204	16,169	612
Net income (loss) from discontinued operations	16,202	(80,873)	(138)
Albania [Member]
Discontinued Operations And Disposal Groups [Line Items]
Total revenues	626	8,565	1,898
Production and transportation expense	1,138	11,615
Exploration, abandonment and impairment		86,577
Total other costs and expenses	561	9,229	2,984
Total other income	10,168	1,819	356
Income (Loss) before income taxes	9,095	(97,037)	(730)
Income tax benefit	204	16,169	612
Net income (loss) from discontinued operations	9,299	(80,868)	(118)
Morocco [Member]
Discontinued Operations And Disposal Groups [Line Items]
Total other costs and expenses		5	20
Total other income	6,903
Income (Loss) before income taxes	6,903	(5)	(20)
Net income (loss) from discontinued operations	$ 6,903	$ (5)	$ (20)

Subsequent Events - Additional

Subsequent Events - Additional Information (Detail) - Subsequent Event [Member] - USD ($) $ in Millions	Feb. 24, 2017	Jan. 02, 2017
Subsequent Event [Line Items]
Repayments of short-term debt	$ 2.7
Thrace Basin Natural Gas (Turkiye) Corporation [Member]
Subsequent Event [Line Items]
Gross proceeds on sale of ownership interests	20.9
Net cash proceeds on sale of ownership interests	16.3
Escrow deposit	3.1
2017 Notes [Member]
Subsequent Event [Line Items]
Debt instrument redemption date		Jan. 1, 2017
Redemption of notes		$ 4.3
Debt instrument redemption price percentage		100.00%
Notes payable		$ 10
ANBE Note [Member]
Subsequent Event [Line Items]
Repayments of short-term debt	$ 2.7