Title of each class | Name of each exchange on which registered |
Common Shares Without Par Value | NASDAQ Global Select Market |
Registrant: | TRANSGLOBE ENERGY CORPORATION | |
By: | /s/ Ross G. Clarkson | |
Ross G. Clarkson | ||
Chief Executive Officer | ||
Date: | March 15, 2018 | |
99.1* | Annual Information Form for the year-ended December 31, 2017. |
99.2* | Consolidated Audited Financial Statements for the year ended December 31, 2017. |
99.3* | Management’s Discussion and Analysis for the year ended December 31, 2017. |
99.4* | Certification by the Chief Executive Officer of the Registrant pursuant to Rule 13a-14(a) of the Exchange Act, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002. |
99.5* | Certification by the Chief Financial Officer of the Registrant pursuant to Rule 13a-14(a) of the Exchange Act, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002. |
99.6* | Certification by the Chief Executive Officer of the Registrant pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002. |
99.7* | Certification by the Chief Financial Officer of the Registrant pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002. |
99.8* | Consent of Independent Registered Public Accounting Firm, Deloitte LLP. |
99.9* | Consent of Independent Engineers: GLJ Petroleum Consultants. |
[101 | Interactive Data File] |
Document and Entity Information Document |
12 Months Ended |
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Dec. 31, 2017
shares
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| Document And Entity Information [Abstract] | |
| Entity Registrant Name | TRANSGLOBE ENERGY CORP |
| Entity Central Index Key | 0000736744 |
| Document Type | 40-F/A |
| Document Period End Date | Dec. 31, 2017 |
| Amendment Flag | false |
| Current Fiscal Year End Date | --12-31 |
| Entity Current Reporting Status | Yes |
| Entity Common Stock, Shares Outstanding | 72,205,369 |
| Document Fiscal Year Focus | 2017 |
| Document Fiscal Period Focus | FY |
Consolidated Statements of Changes in Shareholders' Equity - USD ($) $ in Thousands |
Total |
Share Capital [member] |
Accumulated Other Comprehensive Income [member] |
Contributed Surplus [member] |
Retained Earnings [member] |
|---|---|---|---|---|---|
| Balance, beginning of year at Dec. 31, 2015 | $ 152,084 | $ 0 | $ 21,398 | $ 198,202 | |
| Currency translation adjustment - gain | $ 0 | 0 | |||
| Share-based compensation expense | 1,297 | ||||
| Net loss | (87,665) | (87,665) | |||
| Balance, end of year at Dec. 31, 2016 | 285,316 | 152,084 | 0 | 22,695 | 110,537 |
| Currency translation adjustment - gain | 2,793 | 2,793 | |||
| Share-based compensation expense | 634 | ||||
| Net loss | (78,736) | (78,736) | |||
| Balance, end of year at Dec. 31, 2017 | $ 210,007 | $ 152,084 | $ 2,793 | $ 23,329 | $ 31,801 |
Corporate Information |
12 Months Ended |
|---|---|
Dec. 31, 2017 | |
| Corporate Information And Statement Of IFRS Compliance [Abstract] | |
| Corporate Information | CORPORATE INFORMATION TransGlobe Energy Corporation (the "Company "or" TransGlobe") is a publicly listed company incorporated in Alberta, Canada and its shares are listed on the Toronto Stock Exchange (“TSX”) and the Global Select Market of the NASDAQ Stock Market (“NASDAQ”). The address of its registered office is 2300, 250 – 5th Street SW, Calgary, Alberta, Canada, T2P 0R4. TransGlobe together with its subsidiaries is engaged primarily in oil and gas exploration, development and production and the acquisition of oil and gas properties. |
Basis of Preparation |
12 Months Ended |
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Dec. 31, 2017 | |
| Corporate Information And Statement Of IFRS Compliance [Abstract] | |
| Basis of Preparation | BASIS OF PREPARATION Statement of compliance These Consolidated Financial Statements have been prepared in accordance with International Financial Reporting Standards ("IFRS") as issued by the International Accounting Standards Board effective as of December 31, 2017. These Consolidated Financial Statements were authorized for issue by the Board of Directors on March 5, 2018. Basis of measurement The accounting policies used in the preparation of these Consolidated Financial Statements are described in Note 3, Significant Accounting Policies. The Company prepared these Consolidated Financial Statements on a going concern basis, which contemplates the realization of assets and liabilities in the normal course of business as they become due. Accordingly, these Consolidated Financial Statements have been prepared on a historical cost basis, except for cash and cash equivalents, derivative commodity contracts and former convertible debentures that have been measured at fair value. The method used to measure fair value is discussed further in Notes 3 and 7. Presentation currency In these Consolidated Financial Statements, unless otherwise indicated, all dollar amounts are presented and expressed in United States (U.S.) dollars. All references to $ are to United States dollars and references to C$ are to Canadian dollars and all values are rounded to the nearest thousand except when otherwise indicated. |
Significant Accounting Policies |
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| Accounting Policies, Changes In Accounting Estimates And Errors [Abstract] | |||||||||||||||||||||||||||||||||||||
| Significant Accounting Policies | SIGNIFICANT ACCOUNTING POLICIES The accounting policies set out below have been applied consistently to all periods presented in these Consolidated Financial Statements. Basis of consolidation Subsidiaries are entities controlled by the Company. Control exists when the Company has the power to govern the financial and operating policies of an entity, it is exposed to or has rights to variable returns associated with its involvement in the entity, and it has the ability to use that power to influence the amount of returns it is exposed to or has rights to. In assessing control, potential voting rights need to be considered. All of the subsidiaries of the Company are wholly-owned by the parent company, TransGlobe Energy Corporation. The Consolidated Financial Statements include the financial statements of the Company and its wholly-owned, controlled subsidiaries. The financial statements of the subsidiaries are prepared for the same reporting period as the parent company, using consistent accounting policies. All intra-company transactions, balances, income and expenses, unrealized gains and losses are eliminated on consolidation. Joint operations The Company conducts many of its oil and gas production activities through joint operations and the Consolidated Financial Statements reflect only the Company's share in such activities. Foreign currency translation The Consolidated Financial Statements are presented in U.S. dollars. Effective January 1, 2017, TransGlobe Energy Corporation's functional currency is the Canadian dollar, and the functional currency of all subsidiaries is the U.S. dollar. It was determined that TransGlobe Energy Corporation's functional currency is now the Canadian dollar because the parent company now owns Canadian producing assets, and therefore generates revenues and incurs costs that are largely denominated in Canadian dollars. Foreign currency translations include the translation of foreign currency transactions and the translation of the Canadian operations functional currency, which is Canadian dollars. Foreign currency translations occur when translating transactions in foreign currencies to the applicable functional currency of TransGlobe Energy Corporation and its subsidiaries. Gains and losses from foreign currency transactions are recorded as foreign exchange gains or losses. Translations occur as follows: • Income and expenses are translated at the prevailing rates on the date of the transaction • Non-monetary assets or liabilities are carried at the prevailing rates on the date of the transaction • Monetary items are translated at the prevailing rates at the balance sheet date Translation gains and losses from Canadian operations occur when translating the financial statements of TransGlobe Energy Corporation (non-U.S. functional currency) to the U.S. dollar. These translation gains and losses are recorded as currency translation adjustments and presented as other comprehensive income on the Consolidated Statements of Loss and Comprehensive Loss. Translations occur as follows: • Income and expenses are translated at the average exchange rates for the period • Assets and liabilities are translated at the prevailing rates on the balance sheet date Cash and cash equivalents Cash and cash equivalents includes cash and short-term, highly liquid investments that mature within three months of the date of their purchase. Restricted cash Restricted cash represents a cash collateralized letter of credit facility that is used to guarantee the Company's commitments on its Egyptian exploration concessions. Financial instruments Non-derivative financial instruments Non-derivative financial instruments comprise cash and cash equivalents, accounts receivable, restricted cash, accounts payable and accrued liabilities, long-term debt, the former note payable and previous convertible debentures. Non-derivative financial instruments are recognized initially at fair value plus, for instruments not at fair value through profit or loss, any directly attributable transaction costs. Subsequent to initial recognition non-derivative financial instruments are measured as described below. Financial assets and liabilities at fair value through profit or loss An instrument is classified at fair value through profit or loss if it is held for trading or is designated as such upon initial recognition, such as cash and cash equivalents, derivative commodity contracts and the former convertible debentures. Financial instruments are designated at fair value through profit or loss if the Company makes purchase and sale decisions based on their fair value in accordance with the Company's documented risk management strategy. Upon initial recognition, any transaction costs attributable to the financial instruments are recognized through earnings when incurred. Financial instruments at fair value through profit or loss are measured at fair value, and changes therein are recognized in earnings. Other Other non-derivative financial instruments, such as accounts receivable, accounts payable and accrued liabilities, long-term debt, the prior note payable and restricted cash are measured initially at fair value, then at amortized cost using the effective interest method, less any impairment losses. Derivative financial instruments The Company enters into certain financial derivative contracts from time to time in order to reduce its exposure to market risks from fluctuations in commodity prices. These instruments are not used for trading or speculative purposes. The Company does not designate financial derivative contracts as effective accounting hedges, and thus does not apply hedge accounting, even though the Company considers all commodity contracts to be economic hedges. As a result, the Company's policy is to classify all financial derivative contracts at fair value through profit or loss and to record them on the Consolidated Balance Sheet at fair value. Attributable transaction costs are recognized in earnings when incurred. The estimated fair value of all derivative instruments is based on quoted market prices and/or third party market indications and forecasts. Embedded derivatives are derivatives embedded in a host contract. They are recorded separately from the host contract when their economic characteristics and risks are not closely related to those of the host contract; when the terms of the embedded derivatives are the same as those of a freestanding derivative; and when the combined contract is not measured at fair value through profit or loss. Changes in the fair value of separable embedded derivatives are recognized immediately in profit or loss. Share capital Common shares are classified as equity. Incremental costs directly attributable to the issue of common shares are recognized as a deduction from equity. When the Company acquires and cancels its own common shares, share capital is reduced by the cost of shares repurchased, including transaction costs. Property and equipment and intangible exploration and evaluation assets Exploration and evaluation assets Exploration and evaluation ("E&E") costs related to each license/prospect are initially capitalized within "intangible exploration and evaluation assets." Such E&E costs may include costs of license acquisition, technical services and studies, seismic acquisition, exploration drilling and testing, directly attributable expenses, including remuneration of production personnel and supervisory management, and the projected costs of retiring the assets (if any), but do not include pre-licensing costs incurred prior to having obtained the legal rights to explore an area, which are expensed directly to earnings as they are incurred and presented as exploration expenses on the Consolidated Statements of Loss and Comprehensive Loss. Intangible exploration and evaluation assets are not depleted. They are carried forward until technical feasibility and commercial viability of extracting a mineral resource is determined. The technical feasibility and commercial viability is considered to be determined when proved and/or probable reserves are determined to exist or they can be empirically supported with actual production data or conclusive formation tests. Intangible exploration and evaluation assets are transferred to petroleum properties as development and production ("D&P") assets upon determination of technical feasibility and commercial viability. The intangible E&E assets being transferred to D&P assets are subject to impairment testing upon transfer. Petroleum and natural gas assets Petroleum and natural gas ("PNG") assets and other assets are recognized at cost less accumulated depletion, depreciation, and amortization, and accumulated impairment losses. The initial cost of an asset comprises its purchase price or construction cost, any costs directly attributable to bringing the asset into operation, including qualifying E&E costs on reclassification from intangible exploration and evaluation assets, and for qualifying assets, where applicable, borrowing costs. When significant parts of an item of property and equipment have different useful lives, they are accounted for as separate items. Gains and losses on disposal of items of property and equipment, including oil and natural gas interests, are determined by comparing the proceeds from disposal with the carrying amount of property and equipment and are recognized in net earnings (loss) immediately. Subsequent costs Costs incurred subsequent to the determination of technical feasibility and commercial viability and the costs of replacing parts of property and equipment are recognized as petroleum properties or other assets only when they increase the future economic benefits embodied in the specific asset to which they relate. All other expenditures are recognized in profit or loss as incurred. Such capitalized property and equipment generally represent costs incurred in developing Proved and/or Probable reserves and bringing in or enhancing production from such reserves, and are accumulated on a well, field or geotechnical area basis, together with the discounted value of estimated future costs of asset retirement obligations. When components of PNG assets are replaced, disposed of, or no longer in use, the carrying amount is derecognized. The costs of the day-to-day servicing of property, plant and equipment are recognized in profit or loss as incurred. Depletion, depreciation and amortization The depletion, depreciation and amortization of PNG assets and other assets are recognized in earnings (loss). The net carrying value of the PNG assets included in petroleum properties is depleted using the unit of production method by reference to the ratio of production in the year to the related proved and probable reserves using estimated future prices and costs. Costs subject to depletion include estimated future development costs necessary to bring those reserves into production. These estimates are reviewed by independent reserve engineers at least annually and determined in accordance with National Instrument 51-101 Standards of Disclosure of Oil and Gas Activities. Natural gas reserves and production are converted at the energy equivalent of six thousand cubic feet to one barrel of oil. Proved and probable reserves are estimated using independent reserve evaluator reports and represent the estimated quantities of crude oil, natural gas and natural gas liquids which geological, geophysical and engineering data demonstrate with a specified degree of certainty to be recoverable in future years from known reservoirs and which are considered commercially viable. The specified degree of certainty must be a minimum 90% statistical probability that the actual quantity of recoverable reserves will be more than the amount estimated as proved and a minimum 50% statistical probability for proved and probable reserves to be considered commercially viable. Furniture and fixtures are depreciated at declining balance rates of 20% to 30%, whereas vehicles and leasehold improvements are depreciated on a straight-line basis over their estimated useful lives. Depreciation methods, useful lives and residual values are reviewed at each reporting date. Product inventory Product inventory consists of the Company's unsold Egypt entitlement crude oil barrels, which is valued at the lower of cost, using the first-in, first-out method, and net realizable value. Cost includes operating expenses and depletion associated with the entitlement crude oil barrels as determined on a concession by concession basis. Impairment Financial assets carried at amortized cost A financial asset is assessed at each reporting date to determine whether there is any objective evidence that it is impaired. A financial asset is considered to be impaired if objective evidence indicates that one or more events has had a negative effect on the estimated future cash flows of the asset. An impairment loss in respect of a financial asset measured at amortized cost is calculated as the difference between its carrying amount, and the present value of the estimated future cash flows discounted at the original effective interest rate. Individually significant financial assets are tested for impairment on an individual basis. The remaining financial assets are assessed collectively in groups that share similar credit risk characteristics. All impairment losses are recognized in profit or loss. An impairment loss may be reversed if the reversal can be related objectively to an event occurring after the impairment loss was recognized. Any such reversal is recognized in profit or loss. Non-financial assets The carrying amounts of the Company’s non-financial assets are reviewed at each reporting date to determine whether there is any indication of impairment, except for E&E assets, which are reviewed when circumstances indicate impairment may exist and at least annually, as discussed in more detail below. If any such indication exists, then the asset’s recoverable amount is estimated. For the purpose of impairment testing, assets are grouped together into the smallest group of assets that generate cash inflows from continuing use that are largely independent of the cash inflows of other assets or groups of assets (the cash-generating unit). The recoverable amount of an asset or a cash-generating unit ("CGU") is the greater of its value in use and its fair value less costs to sell. The Company’s CGUs are not larger than a segment. In assessing both fair value less costs to sell and value in use, the estimated future cash flows are discounted to their present value using a pre-tax discount rate that reflects current market assessments of the time value of money and the risks specific to the asset. For D&P assets, fair value less costs to sell and value in use is generally computed by reference to the present value of the future cash flows expected to be derived from production of proved and probable reserves. E&E assets are tested for impairment when they are reclassified to petroleum properties and also if facts and circumstances suggest that the carrying amount of E&E assets may exceed their recoverable amount. Impairment indicators are evaluated at a CGU level. Indications of impairment include:
An impairment loss is recognized if the carrying amount of an asset or its CGU exceeds its estimated recoverable amount. Impairment losses are recognized in profit or loss. Impairment losses recognized in prior years are assessed at each reporting date for any indications that the loss has decreased or no longer exists. An impairment loss may be reversed if there has been a change in the estimates used to determine the recoverable amount. An impairment loss is reversed only to the extent that the asset’s carrying amount does not exceed the carrying amount that would have been determined, net of depletion and depreciation or amortization, if no impairment loss had been recognized. Share-based payment transactions Equity-settled transactions The cost of equity-settled transactions with employees is measured by reference to the fair value at the date at which equity instruments are granted and is recognized as an expense over the vesting period, which ends on the date on which the relevant employees become fully entitled to the award. Fair value is determined by using the lattice-based trinomial option pricing model. An estimated forfeiture rate is taken into consideration when assigning a fair value to options granted such that no expense is recognized for awards that do not ultimately vest. At each financial reporting date before vesting, the cumulative expense is calculated, which represents the extent to which the vesting period has expired and management’s best estimate of the number of equity instruments that will ultimately vest. The movement in cumulative expense since the previous financial reporting date is recognized in earnings, with a corresponding entry in equity. When the terms of an equity-settled award are modified or a new award is designated as replacing a cancelled or settled award, the cost based on the original award terms continues to be recognized over the remainder of the new vesting period for the incremental fair value of any modification, based on the difference between the fair value of the original award and the fair value of the modified award, both as measured on the date of the modification. No reduction is recognized if this difference is negative. Cash-settled transactions The cost of cash-settled transactions is measured at fair value using the lattice-based trinomial pricing model and recognized as an expense over the vesting period, with a corresponding liability recognized on the balance sheet. The grant date fair value of cash-settled units granted to employees is recognized as compensation expense; within general and administrative expenses, with a corresponding increase in accounts payable and accrued liabilities over the period that the employees become unconditionally entitled to the units. The amount recognized as an expense is adjusted to reflect the actual number of units for which the related service and non-market vesting conditions are met. The liability is measured at each reporting date with changes to fair value recognized through profit or loss until it is ultimately settled. Provisions and asset retirement obligations A provision is recognized if, as a result of a past event, the Company has a present legal or constructive obligation that can be estimated reliably, and it is probable that an outflow of economic benefits will be required to settle the obligation. Provisions are determined by discounting the expected future cash flows at a pre-tax rate that reflects current market assessments of the time value of money and the risks specific to the liability. Provisions are not recognized for future operating losses. The Company provides for asset retirement obligations on all of its Canadian property, plant and equipment based on current legislation and industry operating practices. The estimated present value of the asset retirement obligation is recorded as a long-term liability, with a corresponding increase in the carrying amount of the related asset. This increase is depleted with the related depletion unit and is allocated to a CGU for impairment testing. The liability recorded is increased each reporting period due to the passage of time and this change is charged to net earnings (loss) in the period as accretion expense. The asset retirement obligation can also increase or decrease due to changes in the estimated timing of cash flows, changes in the discount rate and/or changes in the original estimated undiscounted costs. Increases or decreases in the obligation will result in a corresponding change in the carrying amount of the related asset. Actual costs incurred upon settlement of the asset retirement obligation are charged against the asset retirement obligation to the extent of the liability recorded. The Company discounts the costs related to asset retirement obligations using the discount rate that reflects the current market assessment of the time value of money and risks specific to the liabilities that have not been reflected in the cash flow estimates. The Company applies discount rates applicable to each of the jurisdictions in which it has future asset retirement obligations. Asset retirement obligations are remeasured at each reporting period in order to reflect the discount rates in effect at that time. Future abandonment and reclamation costs have been assessed at zero value in Egypt. In accordance with all of the Company's Production Sharing Agreements and Production Sharing Concessions (collectively defined as "PSCs"), the Company does not at any time hold title to the lands on which it operates, and title to fixed and movable assets is transferred to the respective government when its total cost has been recovered through cost recovery, or at the time of termination of the PSC. Since the Company will not hold title to the land or the assets at the termination of the PSC, the Company does not have a legal obligation, nor the legal ability to decommission the Egypt assets. Furthermore, there is no explicit contractual obligation under the Company's PSCs for abandonment of assets or reclamation of lands upon termination of the PSCs. Revenue recognition Canada Revenues from the sale of petroleum and natural gas are recorded when title to the products transfers to the purchasers based on volumes delivered and contracted delivery points and prices. Revenue is measured at the fair value of the consideration received or receivable. Revenue from the sale of crude oil, natural gas, condensate and natural gas liquids ("NGLs") (prior to deduction of transportation costs) is recognized when all of the following conditions have been satisfied:
Capital processing charges to other entities for use of facilities owned by TransGlobe are recognized as revenue as they accrue in accordance with the terms of the service agreements and are presented as other income. Egypt Revenues associated with the sales of the Company's crude oil are recognized by reference to actual volumes produced and quoted market prices in active markets for identical assets, adjusted according to specific terms and conditions as applicable, when the significant risks and rewards of ownership have been transferred, which is when title passes from the Company to its customer. Crude oil produced and sold by the Company below or above its working interest share in the related resource properties results in production under-liftings or over-liftings. Under-liftings are recorded as inventory and over-liftings are recorded as deferred revenue or used to offset receivables. Pursuant to the PSCs associated with the Company's operations, the Company and other non-governmental partners (if applicable) pay all operating and capital costs for exploration and development. Each PSC establishes specific terms for the Company to recover these costs (Cost Recovery Oil) and to share in the production sharing oil. Cost Recovery Oil is determined in accordance with a formula that is generally limited to a specified percentage of production during each fiscal year. Production sharing oil is that portion of production remaining after Cost Recovery Oil and is shared between the joint interest partners and the government of Egypt, varying with the level of production. Production sharing oil that is attributable to the government includes an amount in respect of all income taxes payable by the Company under the laws of the respective country. Revenue represents the Company's share and is recorded net of royalty payments to the respective government. For the Company's international operations, all government interests, except for income taxes, are considered royalty payments. The Company's revenue also includes the recovery of costs paid on behalf of foreign governments in international locations. Transportation Costs paid by TransGlobe for the transportation of crude oil, natural gas, condensate and NGLs to the point of title transfer are recognized when the transportation is provided. Finance revenue and costs Finance revenue comprises interest income on funds invested. Interest income is recognized as it accrues in earnings, using the effective interest method. Finance costs comprises interest expense on borrowings. Borrowing costs incurred for qualifying assets are capitalized during the period of time that is required to complete and prepare the assets for their intended use or sale. Qualifying assets are those that necessarily take a substantial period of time to get ready for their intended use or sale. All other borrowing costs are recognized in earnings using the effective interest method. Royalties Canada Royalties are recorded at the time the product is produced and sold. Royalties are calculated in accordance with the applicable regulations and/or the terms of individual royalty agreements. Crown royalties for natural gas, condensate and other associated liquids are based on Alberta Government posted reference prices as all of the Company's producing assets are in Alberta. Egypt For the Company’s international operations, all government interests, except for income taxes, are considered royalty payments. Government interests are determined in accordance with the respective PSCs. Income tax Income tax expense is comprised of current and deferred tax. TransGlobe is subject to income taxes based on the tax legislation of each respective country in which TransGlobe conducts business. Current tax Current tax assets and liabilities for the current and prior periods are measured at the amount expected to be recovered from or paid to the taxation authorities. The tax rates and tax laws used to compute the amount are those that are enacted or substantively enacted by the date of the Consolidated Financial Statements. The Company's contractual arrangements in Egypt stipulate that income taxes are paid by the government out of its entitlement share of production sharing oil. Such amounts are included in current income tax expense at the statutory rate in effect at the time of production. Deferred tax The Company determines the amount of deferred income tax assets and liabilities based on the difference between the carrying amounts of the assets and liabilities reported for financial accounting purposes from those reported for tax. Deferred income tax assets and liabilities are measured using the substantively enacted tax rates expected to apply to taxable income in the years in which the temporary differences are expected to be recovered or settled. Deferred income tax assets associated with unused tax losses are recognized to the extent it is probable the Company will have sufficient future taxable earnings available against which the unused tax losses can be utilized. Joint arrangements A joint arrangement involves joint control and offers joint ownership by the Company and other joint interest partners of the financial and operating policies, and of the assets associated with the arrangement. Joint arrangements are classified into one of two categories: joint operations or joint ventures. A joint operation is a joint arrangement whereby the Company and the other parties that have joint control of the arrangement have rights to the assets and obligations for the liabilities relating to the arrangement. Parties involved in joint operations must recognize in relation to their interests in the joint operation their proportionate share of the revenues, expenses, assets and liabilities. A joint venture is a joint arrangement whereby the Company and the other parties that have joint control of the arrangement have rights to the net assets of the arrangement. Parties involved in joint ventures must recognize their interests in joint ventures as investments and must account for that investment using the equity method. In Canada, the Company conducts many of its oil and gas production activities through jointly controlled operations and the financial statements reflect only the Company's proportionate interest in such activities. Joint control exists for contractual agreements governing TransGlobe's assets whereby TransGlobe has less than 100% working interest, all of the partners have control of the arrangement collectively, and spending on the project requires unanimous consent of all parties that collectively control the arrangement and share the associated risks. TransGlobe does not have any joint arrangements that are individually material to the Company or that are structured through joint venture arrangements. In Egypt, joint arrangements in which the Company is involved are conducted pursuant to PSCs. Given the nature and contractual terms associated with the PSCs, the Company has determined that it has rights to the assets and obligations for the liabilities in all of its joint arrangements, and that there are no currently existing joint arrangements where the Company has rights to net assets. Accordingly, all joint arrangements have been classified as joint operations, and the Company has recognized in the Consolidated Financial Statements its share of all revenues, expenses, assets and liabilities in accordance with the PSCs. Business combinations Business combinations are accounted for using the acquisition method. The identifiable assets acquired and liabilities and contingent liabilities assumed are measured at their fair values at the acquisition date. The cost of an acquisition is measured as the aggregate consideration transferred, measured at the acquisition date fair value. If the cost of the acquisition is less than the fair value of the net assets acquired, the difference is recognized immediately in net earnings. If the cost of the acquisition is more than the fair value of the net assets acquired, the difference is recognized on the balance sheet as goodwill. Acquisition costs incurred are expensed. |
Critical Judgments and Accounting Estimates |
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| Corporate Information And Statement Of IFRS Compliance [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Critical Judgments and Accounting Estimates | CRITICAL JUDGMENTS AND ACCOUNTING ESTIMATES Timely preparation of the financial statements in conformity with IFRS as issued by the International Accounting Standards Board requires that management make estimates and assumptions and use judgments that affect the application of accounting policies and the reported amounts of assets, liabilities, revenues and expenses. Such estimates primarily relate to unsettled transactions and events as of the date of the financial statements. Accordingly, actual results may differ from estimated amounts as future confirming events occur. The effect of these estimates, assumptions and the use of judgments are explained throughout the notes to the Consolidated Financial Statements. Estimates and underlying assumptions are reviewed on an ongoing basis. Revisions to accounting estimates are recognized in the year in which the estimates are revised and in any future years affected. The key sources of estimation uncertainty that have a significant risk of causing material adjustment to the carrying amounts of assets and liabilities are discussed below. Recoverability of asset carrying values The recoverability of development and production asset carrying values are assessed at the CGU level. Determination of what constitutes a CGU is subject to management judgment of the lowest level at which there are identifiable cash inflows that are largely independent of the cash inflows of other groups of assets or properties. The factors used by TransGlobe to determine CGUs may vary by country due to unique operating and geographic circumstances in each country. In general, TransGlobe assesses the following factors in determining whether a group of assets generate largely independent cash inflows:
In Egypt, each production sharing concession ("PSC") is considered a separate CGU. In Canada, CGUs are determined by regional geography. The asset composition of a CGU can directly impact the recoverability of the assets included therein. In assessing the recoverability of the Company's petroleum properties, each CGU's carrying value is compared to its recoverable amount, defined as the greater of its fair value less costs to sell and value-in-use. As at December 31, 2017 and December 31, 2016, the recoverable amounts of the Company's CGUs were estimated as their fair value less costs to sell based on the net present value of the after-tax cash flows from the oil and natural gas reserves of each CGU based on reserves estimated by the Company's independent reserve evaluator. Key input estimates used in the determination of cash flows from oil and natural gas reserves include the following:
Impairment tests were carried out at December 31, 2017 and were based on fair value less costs to sell calculations, using a discount rate of 10% for Canada and 15% for Egypt on future after-tax cash flows and the following forward commodity price estimates:
Depletion of petroleum properties Reserves and resources are used in the units of production calculation for depletion, depreciation and amortization. Depletion of petroleum properties is calculated based on total Proved plus Probable reserves as well as estimated future development costs associated with these reserves as determined by the Company's independent reserve evaluator. See above for discussion of estimates and judgments involved in reserve estimation. Income taxes Related assets and liabilities are recognized for the estimated tax consequences between amounts included in the financial statements and their tax base using substantively enacted future income tax rates. Timing of future revenue streams and future capital spending changes can affect the timing of any temporary differences, and accordingly affect the amount of the deferred tax asset or liability calculated at a point in time. Tax interpretations, regulations, and legislation in the various jurisdictions in which TransGlobe and its subsidiaries operate are subject to change and interpretation. Such changes can affect the timing of the reversal of temporary tax differences, the tax rates in effect when such differences reverse and TransGlobe's ability to use tax losses and other tax pools in the future. The Company’s income tax filings are subject to audit by taxation authorities in different jurisdictions and the results of such audits may increase or decrease the tax liability. The determination of current and deferred tax amounts recognized in the consolidated financial statements are based on management’s assessment of the tax positions, which includes consideration of their technical merits, communications with tax authorities and management’s view of the most likely outcome. These differences could materially impact earnings. Business combinations Business combinations are accounted for using the acquisition method of accounting. The determination of fair value often requires management to make assumptions and estimates about future events. The assumptions and estimates with respect to determining the fair value of property, plant, and equipment, and exploration and evaluation assets acquired generally require the most judgment and include estimates of reserves acquired, forecast benchmark commodity prices, and discount rates. Changes in any of the assumptions or estimates used in determining the fair value of acquired assets and liabilities could impact the amounts assigned to assets, liabilities in the purchase price allocation, and any resulting gain or goodwill. Future net earnings can be affected as a result of changes in future depletion, depreciation and accretion, and asset impairments. Financial instruments The fair values of financial instruments are estimated based upon market and third party inputs. These estimates are subject to change with fluctuations in commodity prices, interest rates, foreign currency exchange rates and estimates of non-performance risk. Share-based payments The fair value estimates of equity-settled and cash-settled share-based payment awards depend on certain assumptions including share price volatility, risk free interest rate, the term of the awards, and the forfeiture rate which, by their nature, are subject to measurement uncertainty. Asset retirement obligations The provision for site restoration and abandonment in Canada is based on current legal and constructive requirements, technology, price levels and expected plans for remediation. Actual costs and cash outflows can differ from estimates because of changes in laws and regulations, public expectations, market conditions, discovery and analysis of site conditions and changes in technology. Recoverability of accounts receivable The recoverability of accounts receivable due from the Egyptian General Petroleum Company ("EGPC") is assessed to determine the carrying value of accounts receivable on the Company's Consolidated Balance Sheets. Management judgment is required in performing the recoverability assessment. No material credit losses have been experienced to date, and the Company expects to collect the accounts receivable balance in full. |
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New Standards and Interpretations Not yet Adopted |
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Dec. 31, 2017 | |
| Accounting Policies, Accounting Estimates And Errors [Abstract] | |
| New Standards and Interpretations Not Yet Adopted | NEW STANDARDS AND INTERPRETATIONS NOT YET ADOPTED Future changes to accounting policies As at the date of authorization of the Consolidated Financial Statements the following pronouncements from the International Accounting Standards Board ("IASB") are applicable to TransGlobe and will become effective for future reporting periods, but have not yet been adopted: IFRS 9 (revised) "Financial Instruments: Classification and Measurement" In July 2014, the IASB issued the final version of IFRS 9 Financial Instruments to replace IAS 39 Financial Instruments: Recognition and Measurement. IFRS 9 introduces a single approach to determine whether a financial asset is measured at amortized cost or fair value and replaces the multiple rules in IAS 39. The approach is based on how an entity manages its financial instruments in the context of its business model and the contractual cash flow characteristics of the financial assets. For financial liabilities, IFRS 9 retains most of the IAS 39 requirements; however, where the fair value option is applied to financial liabilities, the change in fair value resulting from an entity’s own credit risk is recorded in other comprehensive income rather than net earnings, unless this creates an accounting mismatch. In addition, a new expected credit loss model for calculating impairment on financial assets replaces the incurred loss impairment model used in IAS 39. The new model will result in more timely recognition of expected credit losses. IFRS 9 also includes a simplified hedge accounting model, aligning hedge accounting more closely with risk management. The Company does not currently apply hedge accounting. IFRS 9 is effective for years beginning on or after January 1, 2018. This amendment will be adopted by the Company on January 1, 2018 and the Company does not expect the adoption of IFRS 9 amendments to have a material effect on its Consolidated Financial Statements. IFRS 15 "Revenue from Contracts with Customers" IFRS 15 was issued in May 2014 and replaces IAS 18 Revenue, IAS 11 Construction Contracts and related interpretations. The standard is required to be adopted either retrospectively or using a modified transaction approach. IFRS 15 will be adopted by the Company on January 1, 2018. The Company is finalizing the review of its sales contracts with customers and does not expect IFRS 15 will have a material impact on the consolidated financial statements. Upon adoption, the Company will expand its disclosures in the notes to the consolidated financial statements including disaggregated revenue streams by product type and any impairment losses recognized on receivables arising from contracts with customers. IFRS 16 "Leases" In January 2016, the IASB issued IFRS 16 Leases, replacing IAS 17 Leases. IFRS 16 establishes a set of principles that both parties to a contract apply to provide relevant information about leases in a manner that faithfully represents those transactions. The current standard (IAS 17) requires lessees and lessors to classify their leases as either finance leases or operating leases, with separate accounting treatment depending on the classification of the lease. Under the new standard, the accounting treatment associated with an operating lease will no longer exist, and lessees will be required to recognize assets and liabilities associated with all leased items. The standard is effective for fiscal years beginning on or after January 1, 2019 with early adoption permitted if the Company is also applying IFRS 15 Revenue from Contracts with Customers. IFRS 16 will be adopted by the Company on January 1, 2019 and the Company is currently reviewing contracts that are identified as leases. |
Business Combination |
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Dec. 31, 2017 | |||||||||||||||||||||||||||||||||||||||||||||||||
| Business Combination1 [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||
| Business Combination | BUSINESS COMBINATION In a transaction that closed on December 20, 2016 (effective date of December 1, 2016), TransGlobe completed the acquisition of production and working interests in certain facilities in the Cardium light oil and Mannville liquids rich gas assets in the Harmattan area of west central Alberta for total consideration of $59.5 million after adjustments. The acquisition was funded by $48.3 million cash from the balance sheet and a 10%, 24-month vendor take back loan of $11.2 million. In accordance with IFRS, a transaction is accounted for as a business combination when certain criteria are met, such as the acquisition of inputs and processes to convert those inputs into beneficial outputs. TransGlobe assessed the property acquisition and determined that it constitutes a business combination under IFRS. In a business combination, acquired assets and liabilities are recognized by the acquirer at their fair market value at the time of purchase. Any variance between the determined fair value of the assets and liabilities and the purchase price is recognized as either goodwill or a gain in the statement of comprehensive income in the period of acquisition. The estimated fair value of the property, plant and equipment acquired through the transaction was determined based on the present value of the expected future cash flows associated with the acquired property using both internal estimates and an independent reserve evaluation. The decommissioning liabilities assumed were determined using the timing and estimated costs associated with the abandonment, restoration and reclamation of the wells and facilities acquired. The total net fair value of the acquired property was equal to the consideration paid by the Company. As a result, no bargain purchase gain or goodwill was recognized for the year ended December 31, 2016 relating to the acquisition. The consideration paid and fair values of the identifiable assets acquired and liabilities assumed by the Company are as follows:
For the year ended December 31, 2016, if the acquisition had been effective January 1, 2016, the Company would have realized an estimated additional $17.2 million (unaudited) of production revenue and an estimated additional $7.9 million (unaudited) of net operating income before tax. Between the acquisition date of December 20, 2016 and December 31, 2016, approximately $0.6 million of production revenue and $0.2 million of net operating income before tax was recognized relating to the acquired properties. |
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Financial Instruments and Risk Management |
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| Financial Instruments [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Financial Instruments and Risk Management | FINANCIAL INSTRUMENTS AND RISK MANAGEMENT Fair Values of Financial Instruments The Company has classified its cash and cash equivalents as assets at fair value through profit or loss, its derivative commodity contracts and former convertible debentures as financial liabilities at fair value through profit or loss, which are both measured at fair value with changes being recognized through earnings. Accounts receivable and restricted cash are classified as loans and receivables; accounts payable and accrued liabilities, long-term debt and the previous note payable are classified as other liabilities, all of which are measured initially at fair value, then at amortized cost after initial recognition. Transaction costs attributable to financial instruments classified as fair value through profit or loss are included in the recognized amount of the related financial instrument and recognized over the life of the resulting financial instrument using the effective interest method. Carrying value and fair value of financial assets and liabilities are summarized as follows:
Assets and liabilities at December 31, 2017 that are measured at fair value are classified into levels reflecting the method used to make the measurements. Fair values of assets and liabilities included in Level 1 are determined by reference to quoted prices in active markets for identical assets and liabilities. Assets and liabilities in Level 2 include valuations using inputs other than quoted prices for which all significant inputs are observable, either directly or indirectly. Level 3 valuations are based on inputs that are unobservable and significant to the overall fair value measurement. The Company’s cash and cash equivalents, derivative commodity contracts and prior convertible debentures are assessed on the fair value hierarchy described above. TransGlobe’s cash and cash equivalents and former convertible debentures are classified as Level 1. Derivative commodity contracts are classified as Level 2. Assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the placement within the fair value hierarchy level. There were no transfers between levels in the fair value hierarchy in the period. Derivative commodity contracts In conjunction with the prepayment agreement (Note 20), TPI has also entered into a marketing contract with Mercuria Energy Trading S.A. ("Mercuria") to market nine million barrels of TPI’s Egypt entitlement production. The pricing of the crude oil sales will be based on market prices at the time of sale. The nature of TransGlobe’s operations exposes it to fluctuations in commodity prices, interest rates and foreign currency exchange rates. TransGlobe monitors and, when appropriate, uses derivative financial instruments to manage its exposure to these fluctuations. All transactions of this nature entered into by TransGlobe are related to an underlying financial position or to future crude oil and natural gas production. TransGlobe does not use derivative financial instruments for speculative purposes. TransGlobe has elected not to designate any of its derivative financial instruments as accounting hedges and thus accounts for changes in fair value in net earnings at each reporting period. TransGlobe has not obtained collateral or other security to support its financial derivatives as management reviews the creditworthiness of its counterparties prior to entering into derivative contracts. The derivative financial instruments are initiated within the guidelines of the Company's corporate hedging policy. This includes linking all derivatives to specific assets and liabilities on the balance sheet or to specific firm commitments or forecasted transactions. There were eleven outstanding derivative commodity contracts as at December 31, 2017 (December 31, 2016 - nil), the fair values of which have been presented as liabilities on the Consolidated Balance Sheet. The following table summarizes TransGlobe’s outstanding derivative commodity contract positions as at December 31, 2017:
The loss on financial instruments for 2017 and 2016 was comprised of the following:
Overview of Risk Management The Company’s activities expose it to a variety of financial risks that arise as a result of its exploration, development, production and financing activities: • Credit risk • Market risk • Liquidity risk This note presents information about the Company’s exposure to each of the above risks, the Company’s objectives, policies and processes for measuring and managing risk, and the Company’s management of capital. Further quantitative disclosures are included throughout these Consolidated Financial Statements. The Board of Directors and Audit Committee oversee management’s establishment and execution of the Company’s risk management framework. Management has implemented and monitors compliance with risk management policies. The Company’s risk management policies are established to identify and analyze the risks faced by the Company, to set appropriate risk limits and controls, and to monitor risks and adherence to market conditions and the Company’s activities. Credit risk Credit risk is the risk of financial loss if a customer or counterparty to a financial instrument fails to fulfill their contractual obligations. The Company’s exposure to credit risk primarily relates to cash equivalents and accounts receivable, the majority of which are in respect of oil and natural gas operations. The Company generally extends unsecured credit to these parties and therefore the collection of these amounts may be affected by changes in economic or other conditions. The Company has not experienced any material credit losses in the collection of accounts receivable to date. TransGlobe's accounts receivable related to the Canadian operations are with customers and joint interest partners in the petroleum and natural gas industry and are subject to normal industry credit risks. Receivables from petroleum and natural gas marketers are normally collected on the 25th day of the month following production. The Company currently sells its production to several purchasers under standard industry sale and payment terms. Purchasers of TransGlobe's natural gas, crude oil and natural gas liquids are subject to a periodic internal credit review to minimize the risk of non-payment. The Company has continued to closely monitor and reassess the creditworthiness of its counterparties, including financial institutions. Trade and other receivables are analyzed in the table below. The majority of the overdue receivables are due from the Egyptian General Petroleum Company ("EGPC"). The political transition and resultant economic malaise in the country that began in 2011 resulted in irregular collection of accounts receivable from EGPC and generally a larger receivable balance, which increased TransGlobe's credit risk. Despite these factors, the Company expects to collect in full all receivables outstanding from EGPC. In January 2015, TransGlobe began direct sales of Eastern Desert entitlement production to international buyers. The Company completed three separate direct crude sale shipments to third party buyers in 2017. Depending on the Company's assessment of the credit of crude cargo buyers, buyers may be required to post irrevocable letters of credit to support the sales prior to the cargo liftings. During 2017, the Company sold an additional 1,121,391 barrels of inventoried entitlement crude oil to EGPC for $48.5 million to cover in-country expenditures. The Company collected $47.8 million of accounts receivable from EGPC during 2017. As at December 31, 2017, $14.2 million of the total accounts receivable balance of $18.1 million is due from EGPC. The Company anticipates that direct sales will continue to reduce outstanding accounts receivable and credit risk in future periods.
The Company manages its credit risk on cash equivalents by investing only in term deposits with reputable banking institutions. Market risk Market risk is the risk or uncertainty arising from possible market price movements and their impact on the future performance of a business. The market price movements that the Company is exposed to include commodity prices, foreign currency exchange rates and interest rates, all of which could adversely affect the value of the Company’s financial assets, liabilities and financial results. The objective of market risk management is to manage and control market risk exposures within acceptable parameters, while optimizing the return. Commodity price risk The Company’s operational results and financial condition are partially dependent on the commodity prices received for its production of oil, natural gas and NGLs. The Company is exposed to commodity price risk on its derivative assets and liabilities which are used as part of the Company's risk management program to mitigate the effects of changes in commodity prices on future cash flows. While transactions of this nature relate to forecasted future petroleum and natural gas production, TransGlobe does not designate these derivative assets and liabilities as accounting hedges. As such, changes in commodity prices impact the fair value of derivative instruments and the corresponding gains or losses on derivative instruments. The estimated fair value of unrealized commodity contracts is reported on the Consolidated Balance Sheets, with any change in the unrealized positions recorded to earnings. The Company assesses these instruments on the fair value hierarchy and has classified the determination of fair value of these instruments as Level 2, as the fair values of these transactions are based on an approximation of the amounts that would have been received from counter-parties to settle the transactions outstanding as at the date of the Consolidated Balance Sheets with reference to forward prices and market values provided by independent sources. The actual amounts realized may differ from these estimates. Foreign currency exchange risk As the Company’s business is conducted primarily in U.S. dollars and its financial instruments are primarily denominated in U.S. dollars, the Company’s exposure to foreign currency exchange risk relates primarily to certain cash and cash equivalents, accounts receivable, long-term debt, former convertible debentures, accounts payable and accrued liabilities denominated in Canadian dollars. When assessing the potential impact of foreign currency exchange risk, the Company believes that 10% volatility is a reasonable measure. The Company estimates that a 10% increase in the value of the Canadian dollar against the U.S. dollar would increase the net loss for the year ended December 31, 2017 by approximately $0.5 million and conversely a 10% decrease in the value of the Canadian dollar against the U.S. dollar would decrease the net loss by $0.4 million for the same period. The Company does not utilize derivative instruments to manage this risk. The Company is also exposed to foreign currency exchange risk on cash balances denominated in Egyptian pounds. Some collections of accounts receivable from the Egyptian Government are received in Egyptian pounds, and while the Company is generally able to spend the Egyptian pounds received on accounts payable denominated in Egyptian pounds, there remains foreign currency exchange risk exposure on Egyptian pound cash balances. Using month-end cash balances converted at month-end foreign exchange rates, the average Egyptian pound cash balance for 2017 was $0.8 million (2016 - $3.9 million) in equivalent U.S. dollars. The Company estimates that a 10% increase in the value of the Egyptian pound against the U.S. dollar would increase the net loss for the year ended December 31, 2017 by approximately $0.1 million and conversely a 10% decrease in the value of the Egyptian pound against the U.S. dollar would decrease the net loss by $0.1 million for the same period. The Company does not currently utilize derivative instruments to manage foreign currency exchange risk. Interest rate risk Fluctuations in interest rates could result in a significant change in the amount the Company pays to service variable interest debt. No derivative contracts were entered into during 2017 to mitigate interest rate risk. When assessing interest rate risk applicable to the Company’s variable interest, U.S. dollar-denominated debt the Company believes 1% volatility is a reasonable measure. The effect of interest rates increasing by 1% would decrease the Company’s net earnings, for the year ended December 31, 2017, by $0.5 million and conversely the effect of interest rates decreasing by 1% would increase the Company’s net earnings, for the year ended December 31, 2017, by $0.5 million. Liquidity risk Liquidity risk is the risk that the Company will not be able to meet its financial obligations as they become due. Liquidity describes a company’s ability to access cash. Companies operating in the upstream oil and gas industry require sufficient cash in order to fund capital programs necessary to maintain and increase production and proved reserves, to acquire strategic oil and gas assets and to repay debt. The Company actively maintains credit facilities to ensure it has sufficient available funds to meet current and foreseeable financial requirements at a reasonable cost. The following are the contractual maturities of financial liabilities at December 31, 2017:
The Company actively monitors its liquidity to ensure that its cash flows, credit facilities and working capital are adequate to support these financial liabilities, as well as the Company’s capital programs. On February 10, 2017, the Company completed a $75 million crude oil prepayment agreement between its wholly owned subsidiary, TransGlobe Petroleum International Inc. ("TPI") and Mercuria Energy Trading SA ("Mercuria") of Geneva, Switzerland. The initial advance under the prepayment agreement was used to repay the 6.0% convertible debentures of the Company which matured on March 31, 2017 and thereafter for working capital purposes of the Company and its subsidiaries (Note 20). The Company entered into a credit agreement for a revolving reserves-based lending facility with Alberta Treasury Branches ("ATB") totaling C$30.0 million, of which C$13.6 million was drawn on May 16, 2017 to repay the remaining outstanding vendor take-back note balance in full (Note 20). The Company terminated its Borrowing Base Facility in December 2016. There were no amounts drawn on the Borrowing Base Facility at any time in 2016. To date, the Company has experienced no difficulties with transferring funds abroad. Capital disclosures The Company’s objective when managing capital is to ensure the Company will have the financial capacity, liquidity and flexibility to fund the ongoing exploration and development of its petroleum assets. The Company relies on cash flow to fund its capital investments. However, due to long lead cycles of some of its developments and corporate acquisitions, the Company’s capital requirements may exceed its cash flow generated in any one period. This requires the Company to maintain financial flexibility and liquidity. The Company sets the amount of capital in proportion to risk and has historically managed to ensure that the total of the long-term debt is not greater than two times the Company’s funds flow from operations for the trailing twelve months. For the purposes of measuring the Company’s ability to meet the above stated criteria, funds flow from operations is defined as cash generated from operating activities before changes in non-cash working capital. TransGlobe’s net debt to funds flow from operations ratio continued to improve throughout the year and was positive 0.3 at December 31, 2017 (December 31, 2016 - negative 12.0) as a result of positive funds flow from operations for the year. The Company remains in a strong financial position due to prudent capital resource management. The Company's capital programs are funded by its existing working capital and cash provided from operating activities. TransGlobe considers funds flow from operations to be a key measure of operating performance as it demonstrates the Company's ability to generate the necessary funds for sustaining capital, future growth through capital investment, and to repay debt. Management believes that such a measure provides an insightful assessment of TransGlobe's operations on a continuing basis by eliminating certain non-cash charges and actual settlements of ARO, the extent and timing of which, in the opinion of Management, is discretionary. Funds flow from operations is not a standardized measure and therefore may not be comparable with the calculation of similar measures by other entities. The Company defines and computes its capital as follows:
The Company’s net debt-to-funds flow ratio is computed as follows:
The Company’s financial objectives and strategy as described above have remained substantially unchanged over the last two completed fiscal years. These objectives and strategy are reviewed on an annual basis. The Company's debt to funds flow from operations ratio continued to improve from the prior year. TransGlobe remains in a relatively strong financial position, and will continue to focus on cost reductions and prudent stewardship of capital with the objective of maintaining a strong balance sheet. The Company was subject to financial covenants with the prepayment agreement and the RBL as at December 31, 2017. The Company was in compliance with all financial covenants at December 31, 2017 (Note 20). |
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Petroleum and Natural Gas Sales |
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Dec. 31, 2017 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Revenue [abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Petroleum and Natural Gas Sales | PETROLEUM AND NATURAL GAS SALES
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Finance Revenue and Costs |
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| Analysis of income and expense [abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Finance Revenue and Costs | FINANCE REVENUE AND COSTS Finance revenue relates to interest earned on the Company’s bank account balances and term deposits. Finance costs recognized in earnings were as follows:
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Selling Costs |
12 Months Ended |
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Dec. 31, 2017 | |
| Analysis of income and expense [abstract] | |
| Selling Costs | SELLING COSTS Selling costs include transportation and marketing costs associated with the sale of the Company's Egyptian crude oil production to third party buyers and EGPC. The Company completed three direct crude sales to third party buyers, which were marketed by Mercuria during the year ended December 31, 2017; and three direct crude sales to third party buyers during the year ended December 31, 2016. |
Cash and Cash Equivalents |
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| Subclassifications of assets, liabilities and equities [abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Cash and Cash Equivalents | CASH AND CASH EQUIVALENTS
As at December 31, 2017 the Company's cash equivalents balance consisted of short-term deposits with an original term to maturity (at purchase) of three months or less. All of the Company's cash and cash equivalents are on deposit with high credit-quality financial institutions. |
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Accounts Receivable |
12 Months Ended |
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Dec. 31, 2017 | |
| Subclassifications of assets, liabilities and equities [abstract] | |
| Accounts Receivable | ACCOUNTS RECEIVABLE Accounts receivable are comprised principally of amounts owed from EGPC. There were no amounts due from related parties and no loans to management or employees as at December 31, 2017 or December 31, 2016. As at December 31, 2017, the Company was utilizing $5.1 million of its accounts receivable from EGPC as a guarantee to support work commitments on the North West Sitra concession (see Note 22). The Company’s exposure to credit, currency and interest rate risks related to trade and other receivables is disclosed in Note 7, Financial Instruments and Risk. |
Restricted Cash |
12 Months Ended |
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Dec. 31, 2017 | |
| Subclassifications of assets, liabilities and equities [abstract] | |
| Restricted Cash | RESTRICTED CASH As at December 31, 2017, the Company had no restricted cash (December 31, 2016 - $18.3 million). The exploration commitments associated with the restricted cash were fulfilled in 2017. In 2016, restricted cash represented a cash collateralized letter of credit facility used to guarantee the Company's commitments on its Egyptian exploration concessions. |
Product Inventory |
12 Months Ended |
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Dec. 31, 2017 | |
| Inventories [Abstract] | |
| Product Inventory | PRODUCT INVENTORY Product inventory consists of the Company's Egypt entitlement crude oil barrels, which is valued at the lower of cost or net realizable value. Cost includes operating expenses and depletion associated with the unsold crude oil entitlement barrels and is determined on a concession by concession basis. As at December 31, 2017, the Company held 776,754 barrels of entitlement oil in inventory valued at $14.77 per barrel (December 31, 2016 - 1,265,080 barrels valued at $15.49 per barrel). During 2017, product inventory of $8.1 million (2016 - $2.3 million capitalized) was recorded as an expense. |
Income Taxes |
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| Income Taxes [Abstract] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Income Taxes | INCOME TAXES The Company’s deferred income tax assets and liabilities are as follows:
The Company has non-capital losses of $81.5 million (2016 - $70.8 million) that expire between 2027 and 2037. No deferred tax assets have been recognized in respect of these unused tax losses. The Company has an additional $19.4 million (2016 - $18.3 million) in unrecognized tax benefits arising in foreign jurisdictions. Current income taxes represent income taxes incurred and paid under the laws of Egypt pursuant to the PSCs on the West Gharib, West Bakr and NW Gharib concessions. Income taxes vary from the amount that would be computed by applying the average Canadian statutory income tax rate of 27.0% (2016 – 27.0%) to income before taxes as follows:
The Company's consolidated effective income tax rate for 2017 was 38.3% (2016 - 16.7%). |
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Intangible Exploration and Evaluation Assets |
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| Disclosure of detailed information about intangible assets [abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||
| Intangible Exploration and Evaluation Assets | INTANGIBLE EXPLORATION AND EVALUATION ASSETS
For the year ended December 31, 2017 the Company recorded an impairment loss of $79.0 million on its exploration and evaluation assets. The impairment loss was split between the South West Gharib concession ($1.2 million), the North West Gharib concession ($67.5 million) and the South Alamein concession ($10.3 million). At South West Gharib, it was determined during Q1-2017 that an impairment loss was necessary as no commercial quantities of oil were discovered, and no further drilling activities were planned. The South West Gharib exploration lands have been fully evaluated and all commitments had been met at the end of the first exploration phase. The Company elected to not enter the second exploration period and relinquished the concession in 2017. At North West Gharib, the recoverable amount of the North West Gharib CGU was $4.4 million. The remaining North West Gharib exploration and evaluation assets were written down to nil during the second quarter. The North West Gharib exploration lands have been fully evaluated and all commitments had been met at the end of the first exploration phase. The Company elected to not enter the second exploration period. The Company filed for and received four development leases in the North West Gharib concession, all remaining exploration lands not covered by development leases were relinquished. At South Alamein, it was determined during Q3-2017 that an impairment loss was necessary, due to the results of the Boraq 5 well and the uncertainty of an economic development of Boraq in the future. The Company completed testing two zones in the Boraq 5 appraisal well. The Boraq 5 well failed to produce any hydrocarbons from the two zones and was plugged and abandoned. In 2016, the Company recorded an impairment loss of $33.4 million on its exploration and evaluation assets. The impairment loss was related principally to the South East Gharib and South West Gharib concessions in Egypt. The impairment loss recognized on these two concessions represented the entire intangible exploration and evaluation asset balances on the concessions, as the recoverable amounts of the concessions were determined to be nil. The Company relinquished its interest in South East Gharib in November 2016, and relinquished its interest in South West Gharib in the first half of 2017 as no commercially viable quantities of oil had been discovered on either concession. The Company's policy regarding the assessment of impairment for exploration and evaluation assets is disclosed in Note 3, Significant Accounting Policies. |
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Property and Equipment |
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| Property, plant and equipment [abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Property and Equipment | PROPERTY AND EQUIPMENT The following table reconciles the change in TransGlobe's property and equipment assets:
At December 31, 2017, the Company's market capitalization was less than its net asset value, which was identified as an indicator of impairment of all assets. In addition, the decreased natural gas benchmark prices as compared to December 31, 2016 was a potential indicator of impairment for the Canadian assets. As a result, the Company completed impairment tests on all of its CGU's in accordance with IAS 36 and determined that the carrying amounts of the CGUs did not exceed their fair value less costs of sale. Neither a five percent increase in the discount rate nor a five percent decrease in the forward price estimates used in the impairment assessments would result in an impairment loss on the West Gharib, West Bakr, North West Gharib or Canada CGUs. |
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Asset Retirement Obligation |
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| Other Provisions, Contingent Liabilities And Contingent Assets [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||
| Asset Retirement Obligation | ASSET RETIREMENT OBLIGATION
TransGlobe has estimated the net present value of its asset retirement obligation to be $12.3 million as at December 31, 2017 (2016 - $12.1 million) based on a total undiscounted future liability, after inflation adjustment, of $19.6 million (2016 - $19.0 million). These payments are expected to be made between 2019 and 2066. TransGlobe calculated the present value of the obligations using discount rates between 1.68% and 2.26% to reflect the market assessment of the time value of money as well as risks specific to the liabilities that have not been included in the cash flow estimates. The inflation rate used in determining the cash flow estimate was 2% per annum. The Company reviews annually its estimates of the expected costs to reclaim the net interest in its wells and facilities. The resulting changes are categorized as changes in estimates for existing obligations in the preceding table. As at December 31, 2017, the entire asset retirement obligation balance related to the Company's Canadian operations. |
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Accounts Payable and Accrued Liabilities |
12 Months Ended |
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Dec. 31, 2017 | |
| Subclassifications of assets, liabilities and equities [abstract] | |
| Accounts Payable and Accrued Liabilities | ACCOUNTS PAYABLE AND ACCRUED LIABILITIES Accounts payable and accrued liabilities are comprised of current trade payables and accrued expenses due to third parties. There were no amounts due to related parties as at December 31, 2017 or December 31, 2016. The Company’s exposure to currency and liquidity risk related to trade and other payables is disclosed in Note 7, Financial Instruments and Risk. |
Long-term Debt |
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| Financial Instruments [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Long-term Debt | LONG-TERM DEBT The Company's interest-bearing loans and borrowings are measured at amortized cost. As at December 31, 2017, the only significant interest-bearing loans and borrowings are related to the Prepayment Agreement and the Reserves Based Lending Facility as described below. The following table summarizes TransGlobe's outstanding long-term debt:
The following table reconciles the changes in TransGlobe's long-term debt:
Prepayment Agreement
On February 10, 2017, the Company completed a $75 million crude oil prepayment agreement between its wholly owned subsidiary, TransGlobe Petroleum International Inc. ("TPI") and Mercuria. The initial advance under the prepayment agreement was used to repay the 6.0% convertible debentures of the Company, which matured on March 31, 2017 (Note 21). TPI's obligations under the prepayment agreement are guaranteed by the Company and the subsidiaries of TPI (the "Guarantors"). The obligations of TPI and the Guarantors will be supported by, among other things, a pledge of equity held by the Company in TPI and a pledge of equity held by TPI in its subsidiaries. The funding arrangement has a term of four years, maturing March 31, 2021 and advances bear interest at a rate of LIBOR plus 6.0%. The funding arrangement is revolving with each advance to be satisfied through the delivery of crude oil to Mercuria. Further advances become available upon delivery of crude oil to Mercuria up to a maximum of $75.0 million and subject to compliance with the other terms and conditions of the prepayment agreement. The prepayment agreement was initially recognized at fair value, net of financing costs, and has subsequently been measured at amortized cost. Financing costs of $1.5 million will be amortized over the term of the prepayment agreement using the effective interest rate method. The Company is subject to certain financial covenants in accordance with the terms of the prepayment agreement. These covenants are tested on June 30 and December 31 of each year for the life of the prepayment agreement. The financial covenants include financial measures defined within the prepayment agreement that are not defined under IFRS. These financial measures are defined by the prepayment agreement as follows:
As at December 31, 2017, the Company was in compliance with all the financial covenants. The Company is also subject to a cover ratio provision. The cover ratio, defined as the value of the Company's Egyptian forecasted entitlement crude oil production on a forward 12 month basis to the prepayment service obligations, must not be less than 1.25:1.0. Prepayment service obligations includes the principal outstanding of the advances at the time and any costs, fees, expenses, interest and other amounts outstanding or forecasted to be due during the applicable prepayment period. In the event the cover ratio falls below 1.25:1.00, TransGlobe must:
The cover ratio as at December 31, 2017 is 1.49:1.00, the Company is in compliance with the ratio. Based on the Company's current forecast of future production and current Brent Crude prices the estimated future debt payments on long-term debt as of December 31, 2017 are as follows:
Reserves Based Lending Facility As at December 31, 2017, the Company had in place a revolving Canadian reserves-based lending facility with Alberta Treasury Branches ("ATB") totaling C$30.0 million ($24.0 million), of which C$14.0 million ($11.2 million) was drawn. The facility borrowing base is re-calculated no less frequently than on a semi-annual basis of May 31 and November 30 of each year, or as requested by the lender. Lender shall notify the Company of each change in the amount of the borrowing base. In the event that lender re-calculates the borrowing base to be an amount that is less than the borrowings outstanding under the facility, the Company shall repay the difference between such borrowings outstanding and the new borrowing base within 45 days of receiving notice of the new borrowing base. The Company may request an extension of the term date by no later than 90 days prior to the then current term date, and lender may in its sole discretion agree to extend the term date for a further period of 364 days. Unless extended, before May 11, 2018, any unutilized amount of the facility will be cancelled, and the amount of the facility will be reduced to the aggregate borrowings outstanding on that date. The balance of all amounts owing under the facility are due and payable in full on the date falling one year after the term date. If no extension is granted by the lender, the amounts owing pursuant to the facility are due at the maturity date. The facility bears interest at a rate of either ATB Prime or CDOR (Canadian Dollar Offered Rate) plus applicable margins that vary from 1.25% to 3.25% depending on the Company's net debt to trailing cash flow ratio. The revolving reserve-based lending facility was initially recognized at fair value, net of financing costs, and has subsequently been measured at amortized cost. Financing costs of $0.1 million will be amortized over the term of the agreement using the effective interest rate method. The Company is subject to certain financial covenants in accordance with the terms of the agreement. These financial measures are defined by the agreement as follows:
Note Payable On December 20, 2016, the Company closed the acquisition of certain petroleum properties in west central Alberta, Canada (Note 6). The acquisition was partially funded by a vendor take-back note of C$15.0 million ($11.2 million). The note payable had a 24-month term and bore interest at a rate of 10% per annum. The Company repaid the outstanding vendor take-back note balance of C$13.6 million ($10.0 million) on May 16, 2017. Repayment was made using the revolving reserves-based lending facility. Borrowing Base Facility In December 2016 the Company terminated its Borrowing Base Facility. There were no amounts outstanding under the Borrowing Base Facility at the time of termination; however, the Company was utilizing approximately $16.0 million in the form of letters of credit to support its exploration commitments in Egypt. The letters of credit outstanding under the borrowing base facility were transferred to a bilateral letter of credit facility with Sumitomo Mitsui Banking Corporation ("SMBC"). The issued letters of credit under the bilateral letter of credit facility were secured by cash collateral which was on deposit with SMBC (Note 13). The exploration commitments associated with the cash collateralized letter of credit facility were fulfilled in 2017. All remaining deferred financing costs related to the Borrowing Base Facility were expensed at the time of termination of the facility. CONVERTIBLE DEBENTURES
The convertible debentures matured on March 31, 2017 and were repaid in full on that date for their aggregate face value of C$97.8 million ($73.4 million). Repayment was made using the proceeds from the prepayment agreement (Note 20). |
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Convertible Debentures |
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| Financial Instruments [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Convertible Debentures | LONG-TERM DEBT The Company's interest-bearing loans and borrowings are measured at amortized cost. As at December 31, 2017, the only significant interest-bearing loans and borrowings are related to the Prepayment Agreement and the Reserves Based Lending Facility as described below. The following table summarizes TransGlobe's outstanding long-term debt:
The following table reconciles the changes in TransGlobe's long-term debt:
Prepayment Agreement
On February 10, 2017, the Company completed a $75 million crude oil prepayment agreement between its wholly owned subsidiary, TransGlobe Petroleum International Inc. ("TPI") and Mercuria. The initial advance under the prepayment agreement was used to repay the 6.0% convertible debentures of the Company, which matured on March 31, 2017 (Note 21). TPI's obligations under the prepayment agreement are guaranteed by the Company and the subsidiaries of TPI (the "Guarantors"). The obligations of TPI and the Guarantors will be supported by, among other things, a pledge of equity held by the Company in TPI and a pledge of equity held by TPI in its subsidiaries. The funding arrangement has a term of four years, maturing March 31, 2021 and advances bear interest at a rate of LIBOR plus 6.0%. The funding arrangement is revolving with each advance to be satisfied through the delivery of crude oil to Mercuria. Further advances become available upon delivery of crude oil to Mercuria up to a maximum of $75.0 million and subject to compliance with the other terms and conditions of the prepayment agreement. The prepayment agreement was initially recognized at fair value, net of financing costs, and has subsequently been measured at amortized cost. Financing costs of $1.5 million will be amortized over the term of the prepayment agreement using the effective interest rate method. The Company is subject to certain financial covenants in accordance with the terms of the prepayment agreement. These covenants are tested on June 30 and December 31 of each year for the life of the prepayment agreement. The financial covenants include financial measures defined within the prepayment agreement that are not defined under IFRS. These financial measures are defined by the prepayment agreement as follows:
As at December 31, 2017, the Company was in compliance with all the financial covenants. The Company is also subject to a cover ratio provision. The cover ratio, defined as the value of the Company's Egyptian forecasted entitlement crude oil production on a forward 12 month basis to the prepayment service obligations, must not be less than 1.25:1.0. Prepayment service obligations includes the principal outstanding of the advances at the time and any costs, fees, expenses, interest and other amounts outstanding or forecasted to be due during the applicable prepayment period. In the event the cover ratio falls below 1.25:1.00, TransGlobe must:
The cover ratio as at December 31, 2017 is 1.49:1.00, the Company is in compliance with the ratio. Based on the Company's current forecast of future production and current Brent Crude prices the estimated future debt payments on long-term debt as of December 31, 2017 are as follows:
Reserves Based Lending Facility As at December 31, 2017, the Company had in place a revolving Canadian reserves-based lending facility with Alberta Treasury Branches ("ATB") totaling C$30.0 million ($24.0 million), of which C$14.0 million ($11.2 million) was drawn. The facility borrowing base is re-calculated no less frequently than on a semi-annual basis of May 31 and November 30 of each year, or as requested by the lender. Lender shall notify the Company of each change in the amount of the borrowing base. In the event that lender re-calculates the borrowing base to be an amount that is less than the borrowings outstanding under the facility, the Company shall repay the difference between such borrowings outstanding and the new borrowing base within 45 days of receiving notice of the new borrowing base. The Company may request an extension of the term date by no later than 90 days prior to the then current term date, and lender may in its sole discretion agree to extend the term date for a further period of 364 days. Unless extended, before May 11, 2018, any unutilized amount of the facility will be cancelled, and the amount of the facility will be reduced to the aggregate borrowings outstanding on that date. The balance of all amounts owing under the facility are due and payable in full on the date falling one year after the term date. If no extension is granted by the lender, the amounts owing pursuant to the facility are due at the maturity date. The facility bears interest at a rate of either ATB Prime or CDOR (Canadian Dollar Offered Rate) plus applicable margins that vary from 1.25% to 3.25% depending on the Company's net debt to trailing cash flow ratio. The revolving reserve-based lending facility was initially recognized at fair value, net of financing costs, and has subsequently been measured at amortized cost. Financing costs of $0.1 million will be amortized over the term of the agreement using the effective interest rate method. The Company is subject to certain financial covenants in accordance with the terms of the agreement. These financial measures are defined by the agreement as follows:
Note Payable On December 20, 2016, the Company closed the acquisition of certain petroleum properties in west central Alberta, Canada (Note 6). The acquisition was partially funded by a vendor take-back note of C$15.0 million ($11.2 million). The note payable had a 24-month term and bore interest at a rate of 10% per annum. The Company repaid the outstanding vendor take-back note balance of C$13.6 million ($10.0 million) on May 16, 2017. Repayment was made using the revolving reserves-based lending facility. Borrowing Base Facility In December 2016 the Company terminated its Borrowing Base Facility. There were no amounts outstanding under the Borrowing Base Facility at the time of termination; however, the Company was utilizing approximately $16.0 million in the form of letters of credit to support its exploration commitments in Egypt. The letters of credit outstanding under the borrowing base facility were transferred to a bilateral letter of credit facility with Sumitomo Mitsui Banking Corporation ("SMBC"). The issued letters of credit under the bilateral letter of credit facility were secured by cash collateral which was on deposit with SMBC (Note 13). The exploration commitments associated with the cash collateralized letter of credit facility were fulfilled in 2017. All remaining deferred financing costs related to the Borrowing Base Facility were expensed at the time of termination of the facility. CONVERTIBLE DEBENTURES
The convertible debentures matured on March 31, 2017 and were repaid in full on that date for their aggregate face value of C$97.8 million ($73.4 million). Repayment was made using the proceeds from the prepayment agreement (Note 20). |
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Commitments and Contingencies |
12 Months Ended |
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Dec. 31, 2017 | |
| Other Provisions, Contingent Liabilities And Contingent Assets [Abstract] | |
| Commitments and Contingencies | COMMITMENTS AND CONTINGENCIES The Company is subject to certain office and equipment leases. Pursuant to the PSC for North West Gharib in Egypt, the Company had a minimum financial commitment of $35.0 million and a work commitment for 30 wells and 200 square kilometers of 3-D seismic during the initial three year exploration period, which commenced on November 7, 2013. The Company received a six month extension to the initial exploration period, which extended to May 7, 2017. The Company completed the initial exploration period work program and met all financial commitments during the second quarter of 2017. The Company elected not to enter the second exploration period and has relinquished the remaining exploration lands not covered by the four development leases. Pursuant to the PSC for South West Gharib in Egypt, the Company had a minimum financial commitment of $10.0 million and a work commitment for four wells and 200 square kilometers of 3-D seismic during the initial three year exploration period, which commenced on November 7, 2013. The Company received a six month extension to the initial exploration period, which extended to May 7, 2017. As no commercially viable quantities of oil were discovered at South West Gharib, the Company relinquished its interest in the concession on May 7, 2017. The Company met its financial commitment during the first quarter of 2017. Pursuant to the PSC for South Ghazalat in Egypt, the Company had a minimum financial commitment of $8.0 million and a work commitment for two wells and 400 square kilometers of 3-D seismic during the initial three-year exploration period, which commenced on November 7, 2013 and reached its primary term on November 7, 2016. Prior to expiry, the Company elected to enter the first two-year extension period (expiry November 7, 2018). The Company had met its financial commitment for the first phase ($8.0 million) and the first extension ($4.0 million), however the Company had not completed the first phase work program. Prior to entering the first extension the Company posted a $4.0 million performance bond with EGPC to carry forward two exploration commitment wells into the first extension period. The $4.0 million performance bond is supported by a production guarantee from the Company's producing concessions which will be released when the commitment wells have been drilled. In accordance with the concession agreement the Company relinquished 25% of the original exploration acreage prior to entering the first extension period. In addition, the first extension period has an additional financial commitment of $4.0 million, which has been met, and two additional exploration wells. Pursuant to the PSC for North West Sitra in Egypt, the Company has a minimum financial commitment of $10.0 million ($5.1 million remaining) and a work commitment for two wells and 300 square kilometers of 3-D seismic during the initial three and a half year exploration period, which commenced on January 8, 2015. As at December 31, 2017, the Company had expended $4.9 million towards meeting the financial and operating commitment, with the acquisition of 600 square kilometers of 3-D seismic in 2017. In the normal course of its operations, the Company may be subject to litigation and claims. Although it is not possible to estimate the extent of potential costs, if any, management believes that the ultimate resolution of such contingencies would not have a material adverse impact on the results of operations, financial position or liquidity of the Company. The Company is not aware of any material provisions or other contingent liabilities as at December 31, 2017. |
Share Capital |
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| Share Capital, Reserves And Other Equity Interest [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Share Capital | SHARE CAPITAL Authorized The Company is authorized to issue an unlimited number of common shares with no par value. Issued
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Share-based Payments |
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| Share-Based Payment Arrangements [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Share-based Payments | SHARE-BASED PAYMENTS The Company operates a stock option plan (the "Plan") to provide equity-settled share-based remuneration to directors, officers and employees. The number of common shares that may be issued pursuant to the exercise of options awarded under the Plan and all other Security Based Compensation Arrangements of the Company is 10% of the common shares outstanding from time to time. All incentive stock options granted under the Plan have a per-share exercise price equal to the weighted average trading price of the common shares for the five trading days prior to the date of grant. Each tranche of an award with different vesting dates is considered a separate grant for the calculation of fair value and the resulting fair value is amortized over the vesting period of the respective tranches. The following tables summarize information about the stock options outstanding and exercisable at the dates indicated:
Share–based compensation Compensation expense of $0.6 million was recorded in general and administrative expenses in the Consolidated Statements of Loss and Comprehensive Loss and Changes in Shareholders’ Equity during year ended December 31, 2017 (2016 - $1.3 million) in respect of equity-settled share-based payment transactions. The fair value of all common stock options granted is estimated on the date of grant using the lattice-based trinomial option pricing model. The weighted average fair value of options granted during the period and the assumptions used in their determination are as noted below:
All options granted vest annually over a three-year period and expire five years after the grant date. During the year ended December 31, 2017, no employee stock options were exercised (2016 – nil). As at December 31, 2017 and December 31, 2016, the entire balance in contributed surplus was related to previously recognized stock-based compensation expense on equity-settled stock options. Restricted share unit, performance share unit and deferred share unit plans In May 2014, the Company implemented a restricted share unit ("RSU") plan, a performance share unit ("PSU") plan and a deferred share unit ("DSU") plan. RSUs may be issued to directors, officers and employees of the Company, and each RSU entitles the holder to a cash payment equal to the fair market value of a TransGlobe common share on the vesting date of the RSU. All RSUs granted vest annually over a three-year period, and all must be settled within 30 days of their respective vesting dates. PSUs are similar to RSUs, except that the number of PSUs that ultimately vest is dependent on achieving certain performance targets and objectives as set by the board of directors. Depending on performance, vested PSUs granted prior to 2017 can range between 50% and 150% of the original PSU grant, and 0% to 200% for PSU's granted in 2017. All PSUs granted vest on the third anniversary of their grant date, and all must be settled within 60 days of their vesting dates. DSUs are similar to RSUs, except that they become fully vested on the date of grant and are only issued to directors of the Company. Distributions under the DSU plan do not occur until the retirement of the DSU holder from the Company's board of directors. The number of RSUs, PSUs and DSUs outstanding as at December 31, 2017:
Compensation expense of $0.8 million was recorded in general and administrative expenses in the Consolidated Statement of Loss and Comprehensive Loss during the year ended December 31, 2017 in respect of share units granted under the three plans described above (2016 - $1.1 million). The expense related to the share units granted under these plans is measured at fair value using the lattice-based trinomial pricing model and is recognized over the vesting period, with a corresponding liability recognized on the Consolidated Balance Sheet. Until the liability is ultimately settled, it is re-measured at each reporting date with changes to fair value recognized in earnings. |
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Per Share Amounts |
12 Months Ended |
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Dec. 31, 2017 | |
| Earnings per share [abstract] | |
| Per Share Amounts | PER SHARE AMOUNTS The weighted-average number of common shares outstanding (basic and diluted) for the year ended December 31, 2017 was 72,205,369 (2016 - 72,205,369). These outstanding share amounts were used to calculate loss per share in the respective periods. In determining diluted loss per share, the Company assumes that the proceeds received from the exercise of “in-the-money” stock options are used to repurchase common shares at the average market price. In calculating the weighted-average number of diluted common shares outstanding for the year ended December 31, 2017, the Company excluded 4,958,553 stock options (2016 – 4,576,100) as their exercise price was greater than the average common share market price in the year. The convertible debentures were considered dilutive in any period in which earnings per share were reduced by the effect of adjusting net earnings for the impact of the convertible debentures, and adjusting the weighted-average number of shares outstanding for the potential shares issuable on conversion of the convertible debentures. |
Related Party Disclosures |
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| Related Party [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Related Party Disclosures | RELATED PARTY DISCLOSURES Details of controlled entities are as follows*:
* Includes only entities that were active as at December 31, 2017. |
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Compensation of Key Management Personnel |
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| Related Party [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Compensation of Key Management Personnel | COMPENSATION OF KEY MANAGEMENT PERSONNEL Key management personnel have been identified as the board of directors and the four executive officers of the Company. Key management personnel remuneration consisted of the following:
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Segmented Information |
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| Operating Segments [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Segmented Information | SEGMENTED INFORMATION The Company has two reportable operating segments for the year-ended December 31, 2017: the Arab Republic of Egypt and Canada. The Company, through its operating segments, is engaged primarily in oil exploration, development and production and the acquisition of oil and gas properties. In presenting information on the basis of operating segments, segment revenue is based on the geographical location of assets which is also consistent with the location of the segment customers. Segmented assets are also based on the geographical location of the assets. There are no inter-segment sales. TransGlobe's management regularly reviews funds flow from operations generated by each of TransGlobe's operating segments. Funds flow from operations is a measure of profit or loss that provides the management with the ability to assess the operating segments’ profitability and, correspondingly, the ability of each operating segment to sustaining capital, future growth through capital investment, and to repay debt. The accounting policies of the operating segments are the same as the Company’s accounting policies.
Reconciliation of funds flow from operations to net loss:
The carrying amounts of reportable segment assets and liabilities are as follows:
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Supplemental Cash flow Information |
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| Cash Flow Statement [Abstract] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Supplemental Cash flow Information | SUPPLEMENTAL CASH FLOW INFORMATION Changes in non-cash working capital consisted of the following:
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Significant Accounting Policies (Policies) |
12 Months Ended | ||||||||||||||||||||
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Dec. 31, 2017 | |||||||||||||||||||||
| Accounting Policies, Changes In Accounting Estimates And Errors [Abstract] | |||||||||||||||||||||
| Statement of compliance | Statement of compliance These Consolidated Financial Statements have been prepared in accordance with International Financial Reporting Standards ("IFRS") as issued by the International Accounting Standards Board effective as of December 31, 2017. These Consolidated Financial Statements were authorized for issue by the Board of Directors on March 5, 2018. |
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| Basis of measurement | Basis of measurement The accounting policies used in the preparation of these Consolidated Financial Statements are described in Note 3, Significant Accounting Policies. The Company prepared these Consolidated Financial Statements on a going concern basis, which contemplates the realization of assets and liabilities in the normal course of business as they become due. Accordingly, these Consolidated Financial Statements have been prepared on a historical cost basis, except for cash and cash equivalents, derivative commodity contracts and former convertible debentures that have been measured at fair value. The method used to measure fair value is discussed further in Notes 3 and 7. |
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| Presentation currency | Presentation currency In these Consolidated Financial Statements, unless otherwise indicated, all dollar amounts are presented and expressed in United States (U.S.) dollars. All references to $ are to United States dollars and references to C$ are to Canadian dollars and all values are rounded to the nearest thousand except when otherwise indicated. |
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| Basis of consolidation | Basis of consolidation Subsidiaries are entities controlled by the Company. Control exists when the Company has the power to govern the financial and operating policies of an entity, it is exposed to or has rights to variable returns associated with its involvement in the entity, and it has the ability to use that power to influence the amount of returns it is exposed to or has rights to. In assessing control, potential voting rights need to be considered. All of the subsidiaries of the Company are wholly-owned by the parent company, TransGlobe Energy Corporation. The Consolidated Financial Statements include the financial statements of the Company and its wholly-owned, controlled subsidiaries. The financial statements of the subsidiaries are prepared for the same reporting period as the parent company, using consistent accounting policies. All intra-company transactions, balances, income and expenses, unrealized gains and losses are eliminated on consolidation. |
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| Joint operations | Joint operations The Company conducts many of its oil and gas production activities through joint operations and the Consolidated Financial Statements reflect only the Company's share in such activities. |
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| Foreign currency translation | Foreign currency translation The Consolidated Financial Statements are presented in U.S. dollars. Effective January 1, 2017, TransGlobe Energy Corporation's functional currency is the Canadian dollar, and the functional currency of all subsidiaries is the U.S. dollar. It was determined that TransGlobe Energy Corporation's functional currency is now the Canadian dollar because the parent company now owns Canadian producing assets, and therefore generates revenues and incurs costs that are largely denominated in Canadian dollars. Foreign currency translations include the translation of foreign currency transactions and the translation of the Canadian operations functional currency, which is Canadian dollars. Foreign currency translations occur when translating transactions in foreign currencies to the applicable functional currency of TransGlobe Energy Corporation and its subsidiaries. Gains and losses from foreign currency transactions are recorded as foreign exchange gains or losses. Translations occur as follows: • Income and expenses are translated at the prevailing rates on the date of the transaction • Non-monetary assets or liabilities are carried at the prevailing rates on the date of the transaction • Monetary items are translated at the prevailing rates at the balance sheet date Translation gains and losses from Canadian operations occur when translating the financial statements of TransGlobe Energy Corporation (non-U.S. functional currency) to the U.S. dollar. These translation gains and losses are recorded as currency translation adjustments and presented as other comprehensive income on the Consolidated Statements of Loss and Comprehensive Loss. Translations occur as follows: • Income and expenses are translated at the average exchange rates for the period • Assets and liabilities are translated at the prevailing rates on the balance sheet date |
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| Cash and cash equivalents | Cash and cash equivalents Cash and cash equivalents includes cash and short-term, highly liquid investments that mature within three months of the date of their purchase. |
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| Restricted cash | Restricted cash Restricted cash represents a cash collateralized letter of credit facility that is used to guarantee the Company's commitments on its Egyptian exploration concessions. |
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| Financial instruments | Financial instruments Non-derivative financial instruments Non-derivative financial instruments comprise cash and cash equivalents, accounts receivable, restricted cash, accounts payable and accrued liabilities, long-term debt, the former note payable and previous convertible debentures. Non-derivative financial instruments are recognized initially at fair value plus, for instruments not at fair value through profit or loss, any directly attributable transaction costs. Subsequent to initial recognition non-derivative financial instruments are measured as described below. Financial assets and liabilities at fair value through profit or loss An instrument is classified at fair value through profit or loss if it is held for trading or is designated as such upon initial recognition, such as cash and cash equivalents, derivative commodity contracts and the former convertible debentures. Financial instruments are designated at fair value through profit or loss if the Company makes purchase and sale decisions based on their fair value in accordance with the Company's documented risk management strategy. Upon initial recognition, any transaction costs attributable to the financial instruments are recognized through earnings when incurred. Financial instruments at fair value through profit or loss are measured at fair value, and changes therein are recognized in earnings. Other Other non-derivative financial instruments, such as accounts receivable, accounts payable and accrued liabilities, long-term debt, the prior note payable and restricted cash are measured initially at fair value, then at amortized cost using the effective interest method, less any impairment losses. Derivative financial instruments The Company enters into certain financial derivative contracts from time to time in order to reduce its exposure to market risks from fluctuations in commodity prices. These instruments are not used for trading or speculative purposes. The Company does not designate financial derivative contracts as effective accounting hedges, and thus does not apply hedge accounting, even though the Company considers all commodity contracts to be economic hedges. As a result, the Company's policy is to classify all financial derivative contracts at fair value through profit or loss and to record them on the Consolidated Balance Sheet at fair value. Attributable transaction costs are recognized in earnings when incurred. The estimated fair value of all derivative instruments is based on quoted market prices and/or third party market indications and forecasts. Embedded derivatives are derivatives embedded in a host contract. They are recorded separately from the host contract when their economic characteristics and risks are not closely related to those of the host contract; when the terms of the embedded derivatives are the same as those of a freestanding derivative; and when the combined contract is not measured at fair value through profit or loss. Changes in the fair value of separable embedded derivatives are recognized immediately in profit or loss. |
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| Share capital | Share capital Common shares are classified as equity. Incremental costs directly attributable to the issue of common shares are recognized as a deduction from equity. When the Company acquires and cancels its own common shares, share capital is reduced by the cost of shares repurchased, including transaction costs. |
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| Property and equipment | Property and equipment and intangible exploration and evaluation assets Exploration and evaluation assets Exploration and evaluation ("E&E") costs related to each license/prospect are initially capitalized within "intangible exploration and evaluation assets." Such E&E costs may include costs of license acquisition, technical services and studies, seismic acquisition, exploration drilling and testing, directly attributable expenses, including remuneration of production personnel and supervisory management, and the projected costs of retiring the assets (if any), but do not include pre-licensing costs incurred prior to having obtained the legal rights to explore an area, which are expensed directly to earnings as they are incurred and presented as exploration expenses on the Consolidated Statements of Loss and Comprehensive Loss. Intangible exploration and evaluation assets are not depleted. They are carried forward until technical feasibility and commercial viability of extracting a mineral resource is determined. The technical feasibility and commercial viability is considered to be determined when proved and/or probable reserves are determined to exist or they can be empirically supported with actual production data or conclusive formation tests. Intangible exploration and evaluation assets are transferred to petroleum properties as development and production ("D&P") assets upon determination of technical feasibility and commercial viability. The intangible E&E assets being transferred to D&P assets are subject to impairment testing upon transfer. Petroleum and natural gas assets Petroleum and natural gas ("PNG") assets and other assets are recognized at cost less accumulated depletion, depreciation, and amortization, and accumulated impairment losses. The initial cost of an asset comprises its purchase price or construction cost, any costs directly attributable to bringing the asset into operation, including qualifying E&E costs on reclassification from intangible exploration and evaluation assets, and for qualifying assets, where applicable, borrowing costs. When significant parts of an item of property and equipment have different useful lives, they are accounted for as separate items. Gains and losses on disposal of items of property and equipment, including oil and natural gas interests, are determined by comparing the proceeds from disposal with the carrying amount of property and equipment and are recognized in net earnings (loss) immediately. Subsequent costs Costs incurred subsequent to the determination of technical feasibility and commercial viability and the costs of replacing parts of property and equipment are recognized as petroleum properties or other assets only when they increase the future economic benefits embodied in the specific asset to which they relate. All other expenditures are recognized in profit or loss as incurred. Such capitalized property and equipment generally represent costs incurred in developing Proved and/or Probable reserves and bringing in or enhancing production from such reserves, and are accumulated on a well, field or geotechnical area basis, together with the discounted value of estimated future costs of asset retirement obligations. When components of PNG assets are replaced, disposed of, or no longer in use, the carrying amount is derecognized. The costs of the day-to-day servicing of property, plant and equipment are recognized in profit or loss as incurred. Depletion, depreciation and amortization The depletion, depreciation and amortization of PNG assets and other assets are recognized in earnings (loss). The net carrying value of the PNG assets included in petroleum properties is depleted using the unit of production method by reference to the ratio of production in the year to the related proved and probable reserves using estimated future prices and costs. Costs subject to depletion include estimated future development costs necessary to bring those reserves into production. These estimates are reviewed by independent reserve engineers at least annually and determined in accordance with National Instrument 51-101 Standards of Disclosure of Oil and Gas Activities. Natural gas reserves and production are converted at the energy equivalent of six thousand cubic feet to one barrel of oil. Proved and probable reserves are estimated using independent reserve evaluator reports and represent the estimated quantities of crude oil, natural gas and natural gas liquids which geological, geophysical and engineering data demonstrate with a specified degree of certainty to be recoverable in future years from known reservoirs and which are considered commercially viable. The specified degree of certainty must be a minimum 90% statistical probability that the actual quantity of recoverable reserves will be more than the amount estimated as proved and a minimum 50% statistical probability for proved and probable reserves to be considered commercially viable. Furniture and fixtures are depreciated at declining balance rates of 20% to 30%, whereas vehicles and leasehold improvements are depreciated on a straight-line basis over their estimated useful lives. Depreciation methods, useful lives and residual values are reviewed at each reporting date. |
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| Intangible exploration and evaluation assets | Property and equipment and intangible exploration and evaluation assets Exploration and evaluation assets Exploration and evaluation ("E&E") costs related to each license/prospect are initially capitalized within "intangible exploration and evaluation assets." Such E&E costs may include costs of license acquisition, technical services and studies, seismic acquisition, exploration drilling and testing, directly attributable expenses, including remuneration of production personnel and supervisory management, and the projected costs of retiring the assets (if any), but do not include pre-licensing costs incurred prior to having obtained the legal rights to explore an area, which are expensed directly to earnings as they are incurred and presented as exploration expenses on the Consolidated Statements of Loss and Comprehensive Loss. Intangible exploration and evaluation assets are not depleted. They are carried forward until technical feasibility and commercial viability of extracting a mineral resource is determined. The technical feasibility and commercial viability is considered to be determined when proved and/or probable reserves are determined to exist or they can be empirically supported with actual production data or conclusive formation tests. Intangible exploration and evaluation assets are transferred to petroleum properties as development and production ("D&P") assets upon determination of technical feasibility and commercial viability. The intangible E&E assets being transferred to D&P assets are subject to impairment testing upon transfer. Petroleum and natural gas assets Petroleum and natural gas ("PNG") assets and other assets are recognized at cost less accumulated depletion, depreciation, and amortization, and accumulated impairment losses. The initial cost of an asset comprises its purchase price or construction cost, any costs directly attributable to bringing the asset into operation, including qualifying E&E costs on reclassification from intangible exploration and evaluation assets, and for qualifying assets, where applicable, borrowing costs. When significant parts of an item of property and equipment have different useful lives, they are accounted for as separate items. Gains and losses on disposal of items of property and equipment, including oil and natural gas interests, are determined by comparing the proceeds from disposal with the carrying amount of property and equipment and are recognized in net earnings (loss) immediately. Subsequent costs Costs incurred subsequent to the determination of technical feasibility and commercial viability and the costs of replacing parts of property and equipment are recognized as petroleum properties or other assets only when they increase the future economic benefits embodied in the specific asset to which they relate. All other expenditures are recognized in profit or loss as incurred. Such capitalized property and equipment generally represent costs incurred in developing Proved and/or Probable reserves and bringing in or enhancing production from such reserves, and are accumulated on a well, field or geotechnical area basis, together with the discounted value of estimated future costs of asset retirement obligations. When components of PNG assets are replaced, disposed of, or no longer in use, the carrying amount is derecognized. The costs of the day-to-day servicing of property, plant and equipment are recognized in profit or loss as incurred. Depletion, depreciation and amortization The depletion, depreciation and amortization of PNG assets and other assets are recognized in earnings (loss). The net carrying value of the PNG assets included in petroleum properties is depleted using the unit of production method by reference to the ratio of production in the year to the related proved and probable reserves using estimated future prices and costs. Costs subject to depletion include estimated future development costs necessary to bring those reserves into production. These estimates are reviewed by independent reserve engineers at least annually and determined in accordance with National Instrument 51-101 Standards of Disclosure of Oil and Gas Activities. Natural gas reserves and production are converted at the energy equivalent of six thousand cubic feet to one barrel of oil. Proved and probable reserves are estimated using independent reserve evaluator reports and represent the estimated quantities of crude oil, natural gas and natural gas liquids which geological, geophysical and engineering data demonstrate with a specified degree of certainty to be recoverable in future years from known reservoirs and which are considered commercially viable. The specified degree of certainty must be a minimum 90% statistical probability that the actual quantity of recoverable reserves will be more than the amount estimated as proved and a minimum 50% statistical probability for proved and probable reserves to be considered commercially viable. Furniture and fixtures are depreciated at declining balance rates of 20% to 30%, whereas vehicles and leasehold improvements are depreciated on a straight-line basis over their estimated useful lives. Depreciation methods, useful lives and residual values are reviewed at each reporting date. |
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| Product inventory | Product inventory Product inventory consists of the Company's unsold Egypt entitlement crude oil barrels, which is valued at the lower of cost, using the first-in, first-out method, and net realizable value. Cost includes operating expenses and depletion associated with the entitlement crude oil barrels as determined on a concession by concession basis. |
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| Impairment | Impairment Financial assets carried at amortized cost A financial asset is assessed at each reporting date to determine whether there is any objective evidence that it is impaired. A financial asset is considered to be impaired if objective evidence indicates that one or more events has had a negative effect on the estimated future cash flows of the asset. An impairment loss in respect of a financial asset measured at amortized cost is calculated as the difference between its carrying amount, and the present value of the estimated future cash flows discounted at the original effective interest rate. Individually significant financial assets are tested for impairment on an individual basis. The remaining financial assets are assessed collectively in groups that share similar credit risk characteristics. All impairment losses are recognized in profit or loss. An impairment loss may be reversed if the reversal can be related objectively to an event occurring after the impairment loss was recognized. Any such reversal is recognized in profit or loss. Non-financial assets The carrying amounts of the Company’s non-financial assets are reviewed at each reporting date to determine whether there is any indication of impairment, except for E&E assets, which are reviewed when circumstances indicate impairment may exist and at least annually, as discussed in more detail below. If any such indication exists, then the asset’s recoverable amount is estimated. For the purpose of impairment testing, assets are grouped together into the smallest group of assets that generate cash inflows from continuing use that are largely independent of the cash inflows of other assets or groups of assets (the cash-generating unit). The recoverable amount of an asset or a cash-generating unit ("CGU") is the greater of its value in use and its fair value less costs to sell. The Company’s CGUs are not larger than a segment. In assessing both fair value less costs to sell and value in use, the estimated future cash flows are discounted to their present value using a pre-tax discount rate that reflects current market assessments of the time value of money and the risks specific to the asset. For D&P assets, fair value less costs to sell and value in use is generally computed by reference to the present value of the future cash flows expected to be derived from production of proved and probable reserves. E&E assets are tested for impairment when they are reclassified to petroleum properties and also if facts and circumstances suggest that the carrying amount of E&E assets may exceed their recoverable amount. Impairment indicators are evaluated at a CGU level. Indications of impairment include:
An impairment loss is recognized if the carrying amount of an asset or its CGU exceeds its estimated recoverable amount. Impairment losses are recognized in profit or loss. Impairment losses recognized in prior years are assessed at each reporting date for any indications that the loss has decreased or no longer exists. An impairment loss may be reversed if there has been a change in the estimates used to determine the recoverable amount. An impairment loss is reversed only to the extent that the asset’s carrying amount does not exceed the carrying amount that would have been determined, net of depletion and depreciation or amortization, if no impairment loss had been recognized. |
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| Share-based payment transactions | Share-based payment transactions Equity-settled transactions The cost of equity-settled transactions with employees is measured by reference to the fair value at the date at which equity instruments are granted and is recognized as an expense over the vesting period, which ends on the date on which the relevant employees become fully entitled to the award. Fair value is determined by using the lattice-based trinomial option pricing model. An estimated forfeiture rate is taken into consideration when assigning a fair value to options granted such that no expense is recognized for awards that do not ultimately vest. At each financial reporting date before vesting, the cumulative expense is calculated, which represents the extent to which the vesting period has expired and management’s best estimate of the number of equity instruments that will ultimately vest. The movement in cumulative expense since the previous financial reporting date is recognized in earnings, with a corresponding entry in equity. When the terms of an equity-settled award are modified or a new award is designated as replacing a cancelled or settled award, the cost based on the original award terms continues to be recognized over the remainder of the new vesting period for the incremental fair value of any modification, based on the difference between the fair value of the original award and the fair value of the modified award, both as measured on the date of the modification. No reduction is recognized if this difference is negative. Cash-settled transactions The cost of cash-settled transactions is measured at fair value using the lattice-based trinomial pricing model and recognized as an expense over the vesting period, with a corresponding liability recognized on the balance sheet. The grant date fair value of cash-settled units granted to employees is recognized as compensation expense; within general and administrative expenses, with a corresponding increase in accounts payable and accrued liabilities over the period that the employees become unconditionally entitled to the units. The amount recognized as an expense is adjusted to reflect the actual number of units for which the related service and non-market vesting conditions are met. The liability is measured at each reporting date with changes to fair value recognized through profit or loss until it is ultimately settled. |
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| Provisions and asset retirement obligations | Provisions and asset retirement obligations A provision is recognized if, as a result of a past event, the Company has a present legal or constructive obligation that can be estimated reliably, and it is probable that an outflow of economic benefits will be required to settle the obligation. Provisions are determined by discounting the expected future cash flows at a pre-tax rate that reflects current market assessments of the time value of money and the risks specific to the liability. Provisions are not recognized for future operating losses. The Company provides for asset retirement obligations on all of its Canadian property, plant and equipment based on current legislation and industry operating practices. The estimated present value of the asset retirement obligation is recorded as a long-term liability, with a corresponding increase in the carrying amount of the related asset. This increase is depleted with the related depletion unit and is allocated to a CGU for impairment testing. The liability recorded is increased each reporting period due to the passage of time and this change is charged to net earnings (loss) in the period as accretion expense. The asset retirement obligation can also increase or decrease due to changes in the estimated timing of cash flows, changes in the discount rate and/or changes in the original estimated undiscounted costs. Increases or decreases in the obligation will result in a corresponding change in the carrying amount of the related asset. Actual costs incurred upon settlement of the asset retirement obligation are charged against the asset retirement obligation to the extent of the liability recorded. The Company discounts the costs related to asset retirement obligations using the discount rate that reflects the current market assessment of the time value of money and risks specific to the liabilities that have not been reflected in the cash flow estimates. The Company applies discount rates applicable to each of the jurisdictions in which it has future asset retirement obligations. Asset retirement obligations are remeasured at each reporting period in order to reflect the discount rates in effect at that time. Future abandonment and reclamation costs have been assessed at zero value in Egypt. In accordance with all of the Company's Production Sharing Agreements and Production Sharing Concessions (collectively defined as "PSCs"), the Company does not at any time hold title to the lands on which it operates, and title to fixed and movable assets is transferred to the respective government when its total cost has been recovered through cost recovery, or at the time of termination of the PSC. Since the Company will not hold title to the land or the assets at the termination of the PSC, the Company does not have a legal obligation, nor the legal ability to decommission the Egypt assets. Furthermore, there is no explicit contractual obligation under the Company's PSCs for abandonment of assets or reclamation of lands upon termination of the PSCs. |
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| Revenue recognition | Revenue recognition Canada Revenues from the sale of petroleum and natural gas are recorded when title to the products transfers to the purchasers based on volumes delivered and contracted delivery points and prices. Revenue is measured at the fair value of the consideration received or receivable. Revenue from the sale of crude oil, natural gas, condensate and natural gas liquids ("NGLs") (prior to deduction of transportation costs) is recognized when all of the following conditions have been satisfied:
Capital processing charges to other entities for use of facilities owned by TransGlobe are recognized as revenue as they accrue in accordance with the terms of the service agreements and are presented as other income. Egypt Revenues associated with the sales of the Company's crude oil are recognized by reference to actual volumes produced and quoted market prices in active markets for identical assets, adjusted according to specific terms and conditions as applicable, when the significant risks and rewards of ownership have been transferred, which is when title passes from the Company to its customer. Crude oil produced and sold by the Company below or above its working interest share in the related resource properties results in production under-liftings or over-liftings. Under-liftings are recorded as inventory and over-liftings are recorded as deferred revenue or used to offset receivables. Pursuant to the PSCs associated with the Company's operations, the Company and other non-governmental partners (if applicable) pay all operating and capital costs for exploration and development. Each PSC establishes specific terms for the Company to recover these costs (Cost Recovery Oil) and to share in the production sharing oil. Cost Recovery Oil is determined in accordance with a formula that is generally limited to a specified percentage of production during each fiscal year. Production sharing oil is that portion of production remaining after Cost Recovery Oil and is shared between the joint interest partners and the government of Egypt, varying with the level of production. Production sharing oil that is attributable to the government includes an amount in respect of all income taxes payable by the Company under the laws of the respective country. Revenue represents the Company's share and is recorded net of royalty payments to the respective government. For the Company's international operations, all government interests, except for income taxes, are considered royalty payments. The Company's revenue also includes the recovery of costs paid on behalf of foreign governments in international locations. |
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| Transportation | Transportation Costs paid by TransGlobe for the transportation of crude oil, natural gas, condensate and NGLs to the point of title transfer are recognized when the transportation is provided. |
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| Finance revenue and costs | Finance revenue and costs Finance revenue comprises interest income on funds invested. Interest income is recognized as it accrues in earnings, using the effective interest method. Finance costs comprises interest expense on borrowings. Borrowing costs incurred for qualifying assets are capitalized during the period of time that is required to complete and prepare the assets for their intended use or sale. Qualifying assets are those that necessarily take a substantial period of time to get ready for their intended use or sale. All other borrowing costs are recognized in earnings using the effective interest method. |
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| Royalties | Royalties Canada Royalties are recorded at the time the product is produced and sold. Royalties are calculated in accordance with the applicable regulations and/or the terms of individual royalty agreements. Crown royalties for natural gas, condensate and other associated liquids are based on Alberta Government posted reference prices as all of the Company's producing assets are in Alberta. Egypt For the Company’s international operations, all government interests, except for income taxes, are considered royalty payments. Government interests are determined in accordance with the respective PSCs. |
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| Income tax | Income tax Income tax expense is comprised of current and deferred tax. TransGlobe is subject to income taxes based on the tax legislation of each respective country in which TransGlobe conducts business. Current tax Current tax assets and liabilities for the current and prior periods are measured at the amount expected to be recovered from or paid to the taxation authorities. The tax rates and tax laws used to compute the amount are those that are enacted or substantively enacted by the date of the Consolidated Financial Statements. The Company's contractual arrangements in Egypt stipulate that income taxes are paid by the government out of its entitlement share of production sharing oil. Such amounts are included in current income tax expense at the statutory rate in effect at the time of production. Deferred tax The Company determines the amount of deferred income tax assets and liabilities based on the difference between the carrying amounts of the assets and liabilities reported for financial accounting purposes from those reported for tax. Deferred income tax assets and liabilities are measured using the substantively enacted tax rates expected to apply to taxable income in the years in which the temporary differences are expected to be recovered or settled. Deferred income tax assets associated with unused tax losses are recognized to the extent it is probable the Company will have sufficient future taxable earnings available against which the unused tax losses can be utilized. |
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| Joint arrangements | Joint arrangements A joint arrangement involves joint control and offers joint ownership by the Company and other joint interest partners of the financial and operating policies, and of the assets associated with the arrangement. Joint arrangements are classified into one of two categories: joint operations or joint ventures. A joint operation is a joint arrangement whereby the Company and the other parties that have joint control of the arrangement have rights to the assets and obligations for the liabilities relating to the arrangement. Parties involved in joint operations must recognize in relation to their interests in the joint operation their proportionate share of the revenues, expenses, assets and liabilities. A joint venture is a joint arrangement whereby the Company and the other parties that have joint control of the arrangement have rights to the net assets of the arrangement. Parties involved in joint ventures must recognize their interests in joint ventures as investments and must account for that investment using the equity method. In Canada, the Company conducts many of its oil and gas production activities through jointly controlled operations and the financial statements reflect only the Company's proportionate interest in such activities. Joint control exists for contractual agreements governing TransGlobe's assets whereby TransGlobe has less than 100% working interest, all of the partners have control of the arrangement collectively, and spending on the project requires unanimous consent of all parties that collectively control the arrangement and share the associated risks. TransGlobe does not have any joint arrangements that are individually material to the Company or that are structured through joint venture arrangements. In Egypt, joint arrangements in which the Company is involved are conducted pursuant to PSCs. Given the nature and contractual terms associated with the PSCs, the Company has determined that it has rights to the assets and obligations for the liabilities in all of its joint arrangements, and that there are no currently existing joint arrangements where the Company has rights to net assets. Accordingly, all joint arrangements have been classified as joint operations, and the Company has recognized in the Consolidated Financial Statements its share of all revenues, expenses, assets and liabilities in accordance with the PSCs. |
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| Business combinations | Business combinations Business combinations are accounted for using the acquisition method. The identifiable assets acquired and liabilities and contingent liabilities assumed are measured at their fair values at the acquisition date. The cost of an acquisition is measured as the aggregate consideration transferred, measured at the acquisition date fair value. If the cost of the acquisition is less than the fair value of the net assets acquired, the difference is recognized immediately in net earnings. If the cost of the acquisition is more than the fair value of the net assets acquired, the difference is recognized on the balance sheet as goodwill. Acquisition costs incurred are expensed. |
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| New standards and interpretations not yet adopted | NEW STANDARDS AND INTERPRETATIONS NOT YET ADOPTED Future changes to accounting policies As at the date of authorization of the Consolidated Financial Statements the following pronouncements from the International Accounting Standards Board ("IASB") are applicable to TransGlobe and will become effective for future reporting periods, but have not yet been adopted: IFRS 9 (revised) "Financial Instruments: Classification and Measurement" In July 2014, the IASB issued the final version of IFRS 9 Financial Instruments to replace IAS 39 Financial Instruments: Recognition and Measurement. IFRS 9 introduces a single approach to determine whether a financial asset is measured at amortized cost or fair value and replaces the multiple rules in IAS 39. The approach is based on how an entity manages its financial instruments in the context of its business model and the contractual cash flow characteristics of the financial assets. For financial liabilities, IFRS 9 retains most of the IAS 39 requirements; however, where the fair value option is applied to financial liabilities, the change in fair value resulting from an entity’s own credit risk is recorded in other comprehensive income rather than net earnings, unless this creates an accounting mismatch. In addition, a new expected credit loss model for calculating impairment on financial assets replaces the incurred loss impairment model used in IAS 39. The new model will result in more timely recognition of expected credit losses. IFRS 9 also includes a simplified hedge accounting model, aligning hedge accounting more closely with risk management. The Company does not currently apply hedge accounting. IFRS 9 is effective for years beginning on or after January 1, 2018. This amendment will be adopted by the Company on January 1, 2018 and the Company does not expect the adoption of IFRS 9 amendments to have a material effect on its Consolidated Financial Statements. IFRS 15 "Revenue from Contracts with Customers" IFRS 15 was issued in May 2014 and replaces IAS 18 Revenue, IAS 11 Construction Contracts and related interpretations. The standard is required to be adopted either retrospectively or using a modified transaction approach. IFRS 15 will be adopted by the Company on January 1, 2018. The Company is finalizing the review of its sales contracts with customers and does not expect IFRS 15 will have a material impact on the consolidated financial statements. Upon adoption, the Company will expand its disclosures in the notes to the consolidated financial statements including disaggregated revenue streams by product type and any impairment losses recognized on receivables arising from contracts with customers. IFRS 16 "Leases" In January 2016, the IASB issued IFRS 16 Leases, replacing IAS 17 Leases. IFRS 16 establishes a set of principles that both parties to a contract apply to provide relevant information about leases in a manner that faithfully represents those transactions. The current standard (IAS 17) requires lessees and lessors to classify their leases as either finance leases or operating leases, with separate accounting treatment depending on the classification of the lease. Under the new standard, the accounting treatment associated with an operating lease will no longer exist, and lessees will be required to recognize assets and liabilities associated with all leased items. The standard is effective for fiscal years beginning on or after January 1, 2019 with early adoption permitted if the Company is also applying IFRS 15 Revenue from Contracts with Customers. IFRS 16 will be adopted by the Company on January 1, 2019 and the Company is currently reviewing contracts that are identified as leases. |
Critical Judgments and Accounting Estimates (Tables) |
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| Corporate Information And Statement Of IFRS Compliance [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Forward commodity price estimates | Impairment tests were carried out at December 31, 2017 and were based on fair value less costs to sell calculations, using a discount rate of 10% for Canada and 15% for Egypt on future after-tax cash flows and the following forward commodity price estimates:
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Business Combination (Tables) |
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| Business Combination1 [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||
| Consideration paid and fair values of the identifiable assets acquired and liabilities assumed | The consideration paid and fair values of the identifiable assets acquired and liabilities assumed by the Company are as follows:
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Financial Instruments and Risk Management (Tables) |
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| Financial Instruments [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Carrying value and fair value of financial assets | Carrying value and fair value of financial assets and liabilities are summarized as follows:
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| Carrying value and fair value of financial liabilities | Carrying value and fair value of financial assets and liabilities are summarized as follows:
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| Schedule of outstanding derivative commodity contract positions | The following table summarizes TransGlobe’s outstanding derivative commodity contract positions as at December 31, 2017:
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| Schedule of loss on financial instruments | The loss on financial instruments for 2017 and 2016 was comprised of the following:
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| Credit risk related to trade receivables |
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| Contractual maturities of financial liabilities | The following are the contractual maturities of financial liabilities at December 31, 2017:
Based on the Company's current forecast of future production and current Brent Crude prices the estimated future debt payments on long-term debt as of December 31, 2017 are as follows:
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| Disclosure of objectives, policies and processes for managing capital | The Company defines and computes its capital as follows:
The Company’s net debt-to-funds flow ratio is computed as follows:
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Petroleum and Natural Gas Sales (Tables) |
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| Schedule of petroleum and natural gas sales |
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Finance Revenue and Costs (Tables) |
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| Schedule of finance costs recognized in earnings | Finance costs recognized in earnings were as follows:
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||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Cash and Cash Equivalents (Tables) |
12 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Dec. 31, 2017 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Subclassifications of assets, liabilities and equities [abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Schedule of cash and cash equivalents |
|
||||||||||||||||||||||||||||||||||||||||||||||||||||||
Income Taxes (Tables) |
12 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Dec. 31, 2017 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Income Taxes [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Disclosure of deferred income tax assets and liabilities | The Company’s deferred income tax assets and liabilities are as follows:
|
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Reconciliation of income tax expense | Income taxes vary from the amount that would be computed by applying the average Canadian statutory income tax rate of 27.0% (2016 – 27.0%) to income before taxes as follows:
|
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Intangible Exploration and Evaluation Assets (Tables) |
12 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Dec. 31, 2017 | |||||||||||||||||||||||||||||||||||||||||||||||||
| Disclosure of detailed information about intangible assets [abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||
| Schedule of intangible exploration and evaluation assets |
|
||||||||||||||||||||||||||||||||||||||||||||||||
Property and Equipment (Tables) |
12 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Dec. 31, 2017 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Property, plant and equipment [abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Reconciliation of the changes in property and equipment assets | The following table reconciles the change in TransGlobe's property and equipment assets:
|
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Asset Retirement Obligation (Tables) |
12 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Dec. 31, 2017 | |||||||||||||||||||||||||||||||||||||||||||||||||
| Other Provisions, Contingent Liabilities And Contingent Assets [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||
| Asset retirement obligation rollforward |
|
||||||||||||||||||||||||||||||||||||||||||||||||
Long-term Debt (Tables) |
12 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Dec. 31, 2017 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Financial Instruments [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Schedule of long-term debt | The following table summarizes TransGlobe's outstanding long-term debt:
The following table reconciles the changes in TransGlobe's long-term debt:
Prepayment Agreement
|
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Contractual maturities of financial liabilities | The following are the contractual maturities of financial liabilities at December 31, 2017:
Based on the Company's current forecast of future production and current Brent Crude prices the estimated future debt payments on long-term debt as of December 31, 2017 are as follows:
|
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Convertible Debentures (Tables) |
12 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Dec. 31, 2017 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Financial Instruments [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Schedule of convertible debentures | The following table summarizes TransGlobe's outstanding long-term debt:
The following table reconciles the changes in TransGlobe's long-term debt:
Prepayment Agreement
|
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Share Capital (Tables) |
12 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Dec. 31, 2017 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Share Capital, Reserves And Other Equity Interest [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Reconciliation of number of shares Issued | Issued
|
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Share-based Payments (Tables) |
12 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Dec. 31, 2017 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Share-Based Payment Arrangements [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Stock options outstanding and exercisable | The following tables summarize information about the stock options outstanding and exercisable at the dates indicated:
|
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| Range of exercise prices of outstanding share options |
|
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| Measurement of fair value of share options granted | The weighted average fair value of options granted during the period and the assumptions used in their determination are as noted below:
|
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| Number of RSUs, PSUs and DSUs outstanding | The number of RSUs, PSUs and DSUs outstanding as at December 31, 2017:
|
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Related Party Disclosures (Tables) |
12 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Dec. 31, 2017 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Related Party [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Disclosure of controlled entities | Details of controlled entities are as follows*:
* Includes only entities that were active as at December 31, 2017. |
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Compensation of Key Management Personnel (Tables) |
12 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Dec. 31, 2017 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Related Party [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Schedule of key management personnel remuneration | Key management personnel remuneration consisted of the following:
|
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Segmented Information (Tables) |
12 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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| Operating Segments [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Disclosure of operating segments |
Reconciliation of funds flow from operations to net loss:
The carrying amounts of reportable segment assets and liabilities are as follows:
|
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Supplemental Cash flow Information (Tables) |
12 Months Ended | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Dec. 31, 2017 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Cash Flow Statement [Abstract] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Changes in non-cash working capital | Changes in non-cash working capital consisted of the following:
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Significant Accounting Policies (Details) - Furniture and fixtures [member] |
12 Months Ended |
|---|---|
Dec. 31, 2017 | |
| Bottom of range [member] | |
| Disclosure of detailed information about property, plant and equipment [line items] | |
| Depreciation at declining balance rates | 20.00% |
| Top of range [member] | |
| Disclosure of detailed information about property, plant and equipment [line items] | |
| Depreciation at declining balance rates | 30.00% |
Business Combination - Narrative (Details) - Cardium light oil and Mannville liquid-rich gas assets [member] - USD ($) |
12 Months Ended | ||
|---|---|---|---|
Dec. 31, 2016 |
Dec. 20, 2016 |
Dec. 31, 2016 |
|
| Disclosure of detailed information about borrowings [line items] | |||
| Consideration paid | $ 59,475,000 | ||
| Cash paid to vendor | 48,313,000 | ||
| Vendor take back loan | $ 11,162,000 | ||
| Gain recognised in bargain purchase transaction | $ 0 | ||
| Goodwill | $ 0 | 0 | |
| Revenue of combined entity as if combination occurred at beginning of period | 17,200,000 | ||
| Net operating income before tax would have been if combination occurred at beginning of period | $ 7,900,000 | ||
| Revenue of acquiree since acquisition date | 600,000 | ||
| Net operating income before tax of acquiree since acquisition date | $ 200,000 | ||
| Vendor take back loan [member] | |||
| Disclosure of detailed information about borrowings [line items] | |||
| Interest rate on borrowings | 10.00% | ||
| Maturity period on borrowings | 24 months | ||
| Vendor take back loan | $ 11,200,000 |
Business Combination - Consideration Paid and FV of Identifiable Assets and Liabilities Acquired (Details) - Cardium light oil and Mannville liquid-rich gas assets [member] $ in Thousands |
Dec. 20, 2016
USD ($)
|
|---|---|
| Consideration paid | |
| Cash paid to vendor | $ 48,313 |
| Vendor take back loan | 11,162 |
| Consideration paid | 59,475 |
| Net assets acquired | |
| Petroleum and natural gas assets | 71,564 |
| Asset retirement obligations assumed | (12,089) |
| Identifiable assets acquired | $ 59,475 |
Financial Instruments and Risk Management - Schedule of Loss on Financial Instruments (Details) - USD ($) $ in Thousands |
12 Months Ended | |
|---|---|---|
Dec. 31, 2017 |
Dec. 31, 2016 |
|
| Disclosure of financial liabilities [line items] | ||
| Realized derivative loss on commodity contracts settled during the year | $ 2,871 | $ 956 |
| Loss on financial instruments | 10,992 | 7,983 |
| Derivatives [member] | ||
| Disclosure of financial liabilities [line items] | ||
| Realized derivative loss on commodity contracts settled during the year | 2,871 | 956 |
| Unrealized gain (loss) on fair value adjustments | 7,970 | 0 |
| Convertible Debt [member] | ||
| Disclosure of financial liabilities [line items] | ||
| Loss on financial instruments | $ 151 | $ 7,027 |
Financial Instruments and Risk Management - Credit Risk Relates to Trade Receivables (Details) - USD ($) $ in Thousands |
Dec. 31, 2017 |
Dec. 31, 2016 |
|---|---|---|
| Disclosure of credit risk exposure [line items] | ||
| Accounts receivable | $ 18,090 | $ 14,836 |
| Neither impaired nor past due [member] | ||
| Disclosure of credit risk exposure [line items] | ||
| Accounts receivable | 10,534 | 620 |
| Not impaired and past due [member] | Within 30 days [member] | ||
| Disclosure of credit risk exposure [line items] | ||
| Accounts receivable | 3,804 | 0 |
| Not impaired and past due [member] | Past due 31-60 days [member] | ||
| Disclosure of credit risk exposure [line items] | ||
| Accounts receivable | 2,575 | 0 |
| Not impaired and past due [member] | Past due 61-90 days [member] | ||
| Disclosure of credit risk exposure [line items] | ||
| Accounts receivable | 0 | 0 |
| Not impaired and past due [member] | Past due over 90 days [member] | ||
| Disclosure of credit risk exposure [line items] | ||
| Accounts receivable | $ 1,177 | $ 14,216 |
Financial Instruments and Risk Management - Capital Computation and Debt-to-Funds Flow Ratio (Details) $ in Thousands |
12 Months Ended | |
|---|---|---|
|
Dec. 31, 2017
USD ($)
|
Dec. 31, 2016
USD ($)
|
|
| Total Capital [Abstract] | ||
| Long-term debt, including the current portion (net of unamortized transaction costs) | $ 69,999 | $ 0 |
| Long-term note payable, including the current portion | 0 | 11,162 |
| Convertible debentures | 0 | 72,655 |
| Working capital | (50,639) | 16,764 |
| Net debt obligations | 19,360 | 100,581 |
| Shareholders’ equity | 210,007 | 285,316 |
| Total capital | 229,367 | 385,897 |
| Total Debt [abstract] | ||
| Long-term debt, including the current portion (net of unamortized transaction costs) | 69,999 | 0 |
| Long-term note payable, including the current portion | 0 | 11,162 |
| Convertible debentures | 0 | 72,655 |
| Working capital | (50,639) | 16,764 |
| Funds Flow From Operations [Abstract] | ||
| Cash flow from operating activities | 59,450 | (1,065) |
| Changes in non-cash working capital | (3,858) | (7,296) |
| Segmented funds flow from operations | $ 55,592 | $ (8,361) |
| Ratio | 0.3 | (12.0) |
Petroleum and Natural Gas Sales (Details) - USD ($) $ in Thousands |
12 Months Ended | |
|---|---|---|
Dec. 31, 2017 |
Dec. 31, 2016 |
|
| Revenue [abstract] | ||
| Petroleum and natural gas sales | $ 252,591 | $ 122,360 |
| Less: Royalties | 104,127 | 59,226 |
| Petroleum and natural gas sales, net of royalties | $ 148,464 | $ 63,134 |
Selling Costs (Details) - sale |
12 Months Ended | |
|---|---|---|
Dec. 31, 2017 |
Dec. 31, 2016 |
|
| Analysis of income and expense [abstract] | ||
| Number of direct crude sales during period | 3 | 3 |
Cash and Cash Equivalents (Details) - USD ($) $ in Thousands |
Dec. 31, 2017 |
Dec. 31, 2016 |
Dec. 31, 2015 |
|---|---|---|---|
| Subclassifications of assets, liabilities and equities [abstract] | |||
| Cash | $ 46,051 | $ 31,392 | |
| Cash equivalents | 1,398 | 76 | |
| Cash and cash equivalents | $ 47,449 | $ 31,468 | $ 126,910 |
Accounts Receivable (Details) - USD ($) |
Dec. 31, 2017 |
Dec. 31, 2016 |
|---|---|---|
| Subclassifications of assets, liabilities and equities [abstract] | ||
| Receivables due from related parties | $ 0 | $ 0 |
| Receivable due from management or employees | 0 | $ 0 |
| Accounts receivable balance as a guarantee to support work commitments | $ 5,100,000 |
Restricted Cash (Details) - USD ($) |
Dec. 31, 2017 |
Dec. 31, 2016 |
|---|---|---|
| Subclassifications of assets, liabilities and equities [abstract] | ||
| Restricted cash and cash equivalents | $ 0 | $ 18,300,000 |
Product Inventory (Details) $ in Millions |
12 Months Ended | |
|---|---|---|
|
Dec. 31, 2017
USD ($)
$ / bbl
bbl
|
Dec. 31, 2016
USD ($)
$ / bbl
bbl
|
|
| Proved Developed and Undeveloped Oil and Gas Reserve Quantities [Line Items] | ||
| Product inventory recorded as an expense | $ 8.1 | |
| Cost of inventories capitalized | $ 2.3 | |
| Oil [member] | ||
| Proved Developed and Undeveloped Oil and Gas Reserve Quantities [Line Items] | ||
| Number of barrels of oil in inventory | bbl | 776,754 | 1,265,080 |
| Inventories valuation rate (in dollars per barrel) | $ / bbl | 14.77 | 15.49 |
Income Taxes - Narrative (Details) - USD ($) $ in Millions |
12 Months Ended | |
|---|---|---|
Dec. 31, 2017 |
Dec. 31, 2016 |
|
| Disclosure of temporary difference, unused tax losses and unused tax credits [line items] | ||
| Non-capital losses with no deferred tax asset recognized | $ 81.5 | $ 70.8 |
| Applicable tax rate | 27.00% | 27.00% |
| Average effective tax rate | 38.30% | 16.70% |
| Egypt [member] | ||
| Disclosure of temporary difference, unused tax losses and unused tax credits [line items] | ||
| Applicable tax rate | 40.55% | 40.55% |
| Foreign countries [member] | ||
| Disclosure of temporary difference, unused tax losses and unused tax credits [line items] | ||
| Unrecognized tax benefits | $ 19.4 | $ 18.3 |
Income Taxes - Reconciliation of Income Tax Expense (Details) - USD ($) $ in Thousands |
12 Months Ended | |
|---|---|---|
Dec. 31, 2017 |
Dec. 31, 2016 |
|
| Reconciliation of accounting profit multiplied by applicable tax rates [abstract] | ||
| Income taxes calculated at the Canadian statutory rate | $ (15,368) | $ (20,175) |
| Non-deductible expenses | 2,023 | 3,641 |
| Changes in unrecognized tax benefits | 1,243 | 15,261 |
| Effect of tax rates in foreign jurisdictions | 31,728 | 18,635 |
| Changes in tax rates and other | 2,193 | (4,916) |
| Income tax expense | $ 21,819 | $ 12,446 |
Intangible Exploration and Evaluation Assets - Detailed Information About Intangible Assets (Details) - USD ($) $ in Thousands |
12 Months Ended | |
|---|---|---|
Dec. 31, 2017 |
Dec. 31, 2016 |
|
| Reconciliation of changes in intangible assets other than goodwill [abstract] | ||
| Intangible assets other than goodwill, beginning balance | $ 105,869 | |
| Intangible assets other than goodwill, ending balance | 41,478 | $ 105,869 |
| Intangible exploration and evaluation assets [member] | ||
| Reconciliation of changes in intangible assets other than goodwill [abstract] | ||
| Intangible assets other than goodwill, beginning balance | 105,869 | 122,020 |
| Additions | 16,905 | 19,425 |
| Transfer to petroleum and natural gas assets | (2,271) | (2,150) |
| Impairment loss | (79,025) | (33,426) |
| Intangible assets other than goodwill, ending balance | $ 41,478 | $ 105,869 |
Property and Equipment - Narrative (Details) |
12 Months Ended |
|---|---|
Dec. 31, 2017 | |
| Property, plant and equipment [abstract] | |
| Percentage increase in discount rate used in impairment assessments | 5.00% |
| Percentage decrease in discount rate used in impairment assessments | 5.00% |
Asset Retirement Obligation - Asset Retirement Obligation Rollforward (Details) - USD ($) $ in Thousands |
12 Months Ended | |
|---|---|---|
Dec. 31, 2017 |
Dec. 31, 2016 |
|
| Asset Retirement Obligation, Roll Forward Analysis1 [Roll Forward] | ||
| Obligations settled | $ (695) | $ 0 |
| Asset retirement obligation [member] | ||
| Asset Retirement Obligation, Roll Forward Analysis1 [Roll Forward] | ||
| Balance at beginning of period | 12,099 | 0 |
| Acquisitions through business combination | 12,089 | |
| Changes in estimates for asset retirement obligations | (236) | |
| Obligations settled | (695) | |
| Accretion expense | 256 | |
| Effect of movements in foreign exchange rates | 908 | 10 |
| Balance at end of period | $ 12,332 | $ 12,099 |
Asset Retirement Obligation - Narrative (Details) - Asset retirement obligation [member] - USD ($) $ in Thousands |
Dec. 31, 2017 |
Dec. 31, 2016 |
Dec. 31, 2015 |
|---|---|---|---|
| Disclosure of contingent liabilities [line items] | |||
| Provisions | $ 12,332 | $ 12,099 | $ 0 |
| Undiscounted balance of asset retirement obligation | $ 19,600 | $ 19,000 | |
| Per annum inflation rate used to determine the cash flow estimate | 2.00% | ||
| Bottom of range [member] | |||
| Disclosure of contingent liabilities [line items] | |||
| Discount rate used in the assessment of the time value of money | 1.68% | ||
| Top of range [member] | |||
| Disclosure of contingent liabilities [line items] | |||
| Discount rate used in the assessment of the time value of money | 2.26% |
Accounts Payable and Accrued Liabilities (Details) - USD ($) |
Dec. 31, 2017 |
Dec. 31, 2016 |
|---|---|---|
| Subclassifications of assets, liabilities and equities [abstract] | ||
| Current payables due to related parties | $ 0 | $ 0 |
Long-term Debt - Schedule of Outstanding Long-term Debt (Details) $ in Thousands, $ in Millions |
Dec. 31, 2017
USD ($)
|
Dec. 31, 2017
CAD ($)
|
Dec. 31, 2016
USD ($)
|
Dec. 20, 2016
USD ($)
|
Dec. 20, 2016
CAD ($)
|
|---|---|---|---|---|---|
| Prepayment agreement [member] | |||||
| Disclosure of detailed information about borrowings [line items] | |||||
| Long-term debt | $ 58,792 | $ 0 | |||
| Current portion of long-term debt | 0 | ||||
| Borrowings | 58,792 | ||||
| Reserves based lending facility [member] | |||||
| Disclosure of detailed information about borrowings [line items] | |||||
| Long-term debt | 11,207 | $ 14.0 | 0 | ||
| Note payable [member] | |||||
| Disclosure of detailed information about borrowings [line items] | |||||
| Long-term debt | 0 | 5,581 | |||
| Borrowings | $ 11,200 | $ 15.0 | |||
| Long-term debt [member] | |||||
| Disclosure of detailed information about borrowings [line items] | |||||
| Long-term debt | 69,999 | 5,581 | |||
| Current portion of long-term debt | 0 | 5,581 | |||
| Borrowings | $ 69,999 | $ 11,162 |
Long-term Debt - Long-term Debt Rollforward (Details) - USD ($) $ in Thousands |
12 Months Ended | |
|---|---|---|
Dec. 31, 2017 |
Dec. 31, 2016 |
|
| Long-term debt [member] | ||
| Disclosure of detailed information about borrowings [line items] | ||
| Beginning balance | $ 11,162 | |
| Repayments of long-term debt | (26,162) | |
| Amortization of deferred financing costs | 329 | $ 724 |
| Effect of movements in foreign exchange rates | 897 | |
| Ending balance | 69,999 | $ 11,162 |
| Prepayment agreement [member] | ||
| Disclosure of detailed information about borrowings [line items] | ||
| Increase in long-term debt | 73,500 | |
| Ending balance | 58,792 | |
| Reserves based lending facility [member] | ||
| Disclosure of detailed information about borrowings [line items] | ||
| Increase in long-term debt | 10,209 | |
| Revolving Credit Facility1 [Member] | ||
| Disclosure of detailed information about borrowings [line items] | ||
| Increase in long-term debt | $ 64 | |
Long-term Debt - Prepayment Agreement (Details) - Prepayment agreement [member] - USD ($) $ in Thousands |
Dec. 31, 2017 |
Feb. 10, 2017 |
Dec. 31, 2016 |
|---|---|---|---|
| Disclosure of detailed information about borrowings [line items] | |||
| Borrowings | $ 58,792 | ||
| Current portion of long-term debt | 0 | ||
| Long-term debt | 58,792 | $ 0 | |
| Gross carrying amount [member] | |||
| Disclosure of detailed information about borrowings [line items] | |||
| Borrowings | 75,000 | $ 75,000 | |
| Repayment [member] | |||
| Disclosure of detailed information about borrowings [line items] | |||
| Borrowings | (15,000) | ||
| Deferred financing costs [member] | |||
| Disclosure of detailed information about borrowings [line items] | |||
| Borrowings | $ (1,208) |
Long-term Debt - Estimate Future Debt Payments on Long-term Debt (Details) - Prepayment agreement [member] $ in Thousands |
Dec. 31, 2017
USD ($)
|
|---|---|
| Disclosure of detailed information about borrowings [line items] | |
| Borrowings | $ 58,792 |
| Gross carrying amount [member] | |
| Disclosure of detailed information about borrowings [line items] | |
| Borrowings | 58,792 |
| 2018 [member] | Gross carrying amount [member] | |
| Disclosure of detailed information about borrowings [line items] | |
| Borrowings | 0 |
| 2019 [member] | Gross carrying amount [member] | |
| Disclosure of detailed information about borrowings [line items] | |
| Borrowings | 0 |
| 2020 [member] | Gross carrying amount [member] | |
| Disclosure of detailed information about borrowings [line items] | |
| Borrowings | 0 |
| 2021 [member] | Gross carrying amount [member] | |
| Disclosure of detailed information about borrowings [line items] | |
| Borrowings | $ 58,792 |
Convertible Debentures - Schedule of Convertible Debentures (Details) $ in Thousands, $ in Millions |
3 Months Ended | 12 Months Ended | ||
|---|---|---|---|---|
|
Mar. 31, 2017
USD ($)
|
Mar. 31, 2017
CAD ($)
|
Dec. 31, 2017
USD ($)
|
Dec. 31, 2016
USD ($)
|
|
| Disclosure of detailed information about borrowings [line items] | ||||
| Repayment of convertible debentures | $ (73,375) | $ 0 | ||
| Fair value adjustment | 8,121 | 7,027 | ||
| Foreign exchange adjustment | (194) | (3,607) | ||
| Convertible Debt [member] | ||||
| Disclosure of detailed information about borrowings [line items] | ||||
| Beginning balance | $ 72,655 | 72,655 | 63,848 | |
| Repayment of convertible debentures | $ (73,400) | $ (97.8) | (73,375) | |
| Fair value adjustment | 151 | 7,027 | ||
| Foreign exchange adjustment | 569 | 1,780 | ||
| Ending balance | $ 0 | $ 72,655 | ||
Convertible Debentures - Narrative (Details) $ in Thousands, $ in Millions |
3 Months Ended | 12 Months Ended | ||
|---|---|---|---|---|
|
Mar. 31, 2017
USD ($)
|
Mar. 31, 2017
CAD ($)
|
Dec. 31, 2017
USD ($)
|
Dec. 31, 2016
USD ($)
|
|
| Disclosure of detailed information about borrowings [line items] | ||||
| Repayments of bonds, notes and debentures | $ 73,375 | $ 0 | ||
| Convertible Debt [member] | ||||
| Disclosure of detailed information about borrowings [line items] | ||||
| Repayments of bonds, notes and debentures | $ 73,400 | $ 97.8 | $ 73,375 | |
Share Capital - Reconciliation of Number of Shares Issued (Details) - USD ($) shares in Thousands, $ in Thousands |
Dec. 31, 2017 |
Dec. 31, 2016 |
|---|---|---|
| Shares | ||
| Balance, beginning of year (in shares) | 72,206 | 72,206 |
| Balance, end of year (in shares) | 72,206 | 72,206 |
| Amount | ||
| Balance, beginning of year | $ 152,084 | $ 152,084 |
| Balance, end of year | $ 152,084 | $ 152,084 |
Share-based Payments - Measurement of Fair Value of Share Options Granted (Details) - CAD ($) |
12 Months Ended | |
|---|---|---|
Dec. 31, 2017 |
Dec. 31, 2016 |
|
| Share-Based Payment Arrangements [Abstract] | ||
| Weighted average fair market value per option (C$) | $ 0.70 | $ 0.72 |
| Risk free interest rate (%) | 0.74% | 0.54% |
| Expected volatility (based on actual historical volatility) (%) | 48.67% | 49.76% |
| Dividend rate | 0.00% | 0.00% |
| Expected forfeiture rate (non-executive employees) (%) | 0.00% | 0.00% |
| Suboptimal exercise factor | 1.25 | 1.25 |
Per Share Amounts (Details) - shares |
12 Months Ended | |
|---|---|---|
Dec. 31, 2017 |
Dec. 31, 2016 |
|
| Earnings per share [abstract] | ||
| Weighted-average number of shares outstanding (in shares) | 72,205,369 | 72,205,369 |
| Diluted weighted-average number of shares outstanding (in shares) | 72,205,369 | 72,205,369 |
| Antidilutive securities excluded from EPS calculation (in shares) | 4,958,553 | 4,576,100 |
Compensation of Key Management Personnel (Details) - USD ($) $ in Thousands |
12 Months Ended | |
|---|---|---|
Dec. 31, 2017 |
Dec. 31, 2016 |
|
| Related Party [Abstract] | ||
| Salaries, incentives and short-term benefits | $ 2,615 | $ 3,237 |
| Share-based compensation | 898 | 1,775 |
| Key management personnel compensation | $ 3,513 | $ 5,012 |
Segmented Information - Narrative (Details) |
12 Months Ended |
|---|---|
|
Dec. 31, 2017
segment
| |
| Operating Segments [Abstract] | |
| Number of reportable segment | 2 |
| Number of operating segments | 2 |
Segmented Information - Reconciliation of Fund Flows from Operations to Net Loss (Details) - USD ($) $ in Thousands |
12 Months Ended | |
|---|---|---|
Dec. 31, 2017 |
Dec. 31, 2016 |
|
| Operating Segments [Abstract] | ||
| Funds flow from operations | $ 55,592 | $ (8,361) |
| Depletion, depreciation and amortization | (40,036) | (29,177) |
| Accretion | (256) | 0 |
| Deferred lease inducement | 91 | 95 |
| Impairment of exploration and evaluation assets | (79,025) | (33,426) |
| Stock-based compensation | (1,478) | (2,418) |
| Finance costs | (6,233) | (6,068) |
| Income tax expense | (21,819) | (12,446) |
| Loss on financial instruments | (8,121) | (7,027) |
| Unrealized (gain) loss on foreign currency translation | 35 | (4,292) |
| Asset retirement obligations settled | 695 | 0 |
| Income taxes paid | 21,819 | 15,455 |
| NET LOSS FOR THE YEAR | $ (78,736) | $ (87,665) |
Supplemental Cash flow Information (Details) - USD ($) $ in Thousands |
12 Months Ended | |
|---|---|---|
Dec. 31, 2017 |
Dec. 31, 2016 |
|
| (Increase) decrease in current assets | ||
| Accounts receivable | $ (3,254) | $ 8,093 |
| Prepaids and other | (3,044) | 1,159 |
| Product inventory | 5,789 | (3,242) |
| Increase (decrease) in current liabilities | ||
| Increase (decrease) in accounts payable and accrued liabilities | 4,367 | 1,286 |
| Change in non-cash working capital | 3,858 | 7,296 |
| Accounts receivable | (3,254) | 8,093 |
| Prepaids and other | (3,044) | 1,159 |
| Product inventory | 5,789 | (3,242) |
| Investing Activities | ||
| Accounts payable and accrued liabilities | (1,587) | 5,556 |
| Changes in non-cash working capital, net of effect of corporate disposals | $ (1,587) | $ 5,556 |