| Basis of Presentation and Significant Accounting Policies | BASIS OF PRESENTATION AND SIGNIFICANT ACCOUNTING POLICIES Basis of Presentation The accompanying consolidated financial statements include the accounts of the Company and its wholly-owned and majority-owned direct and indirect subsidiaries, and have been prepared in accordance with generally accepted accounting principles in the United States (“U.S. GAAP”) pursuant to the rules and regulations of the Securities and Exchange Commission (the “SEC”). All significant intercompany transactions and balances have been eliminated in consolidation. The consolidated financial statements reflect all adjustments that are, in the opinion of management, necessary for a fair presentation of the consolidated financial position and results of operations for the indicated periods. All such adjustments are of a normal recurring nature. Significant Accounting Policies Principles of Consolidation The consolidated financial statements include the accounts and activities of the Company, subsidiaries in which the Company has a controlling financial interest, and entities for which the Company is the primary beneficiary. All material intercompany accounts and transactions have been eliminated in consolidation. Use of Estimates The preparation of consolidated financial statements in conformity with U.S. GAAP requires management to make estimates based on assumptions. Estimates affect the reported amounts of assets and liabilities, disclosure of contingent liabilities, and the reported amounts of revenues and expenses during the reporting periods. Accordingly, accounting estimates require the exercise of judgment. While management believes that the estimates and assumptions used in the preparation of the Company’s consolidated financial statements are appropriate, actual results could differ from those estimates. Estimates that may have a significant effect on the Company’s financial position and results from operations include share-based compensation assumptions, oil and natural gas reserve quantities, impairment of oil and gas properties, depletion and amortization relating to oil and gas properties, asset retirement obligation assumptions, calculations related to derivative liabilities, and income taxes. The accounting estimates used in the preparation of the consolidated financial statements may change as new events occur, more experience is acquired, additional information is obtained and our operating environment changes. Cash and Cash Equivalents Cash and cash equivalents include cash on hand, demand deposits and short-term investments with initial maturities of three months or less. Restricted Cash Restricted cash consists of cash deposits that are contractually restricted for withdrawal or required to be maintained in a reserve bank account for a specific period of time, as provided for under certain agreements with third parties. Restricted cash as of December 31, 2017 totaling $11.7 million consists of $2.6 million held in a debt service reserve account to secure certain interest and principal repayments pursuant to the Term Loan Facility in Nigeria and $9.1 million held in a debt service account as required under the MCB Finance Facility (see Note 8 - Debt - Long-Term Debt) for further information and definitions of the Term Loan Facility and MCB Finance Facility). Restricted cash as of December 31, 2016 consists of $2.6 million held in a debt service reserve account to secure certain interest and principal repayments pursuant to the Term Loan Facility in Nigeria. Accounts Receivable and Allowance for Doubtful Accounts Accounts receivable are accounted for at cost less allowance for doubtful accounts. The Company establishes provisions for losses on accounts receivable if it is determined that collection of all or a part of an outstanding balance is not probable. Collectability is reviewed regularly and an allowance is established or adjusted, as necessary, using the specific identification method. As of December 31, 2017 and 2016 , no allowance for doubtful accounts was necessary. As of December 31, 2017 and 2016, the Company had a trade receivable balance of $6.7 million and nil , respectively. Partner accounts receivable consist of balances owed from joint venture (“JV”) partners. As of December 31, 2017 and 2016 , the Company was owed $1.8 million and $0.7 million , respectively, from its Ghana JV partners for their share of the expenditures incurred in the Shallow Water Tano block, pursuant to the Ghana JV Joint Operating Agreement. Crude Oil Inventory Inventories of crude oil are valued at the lower of cost or net realized value using the first-in, first-out method and include certain costs directly related to the production process and depletion, depreciation and amortization attributable to the underlying oil and gas properties. The Company had crude oil inventory of $3.6 million and $9.4 million as of December 31, 2017 and 2016 , respectively. Successful Efforts Method of Accounting for Oil and Gas Activities The Company follows the successful efforts method of accounting for its costs of acquisition, exploration and development of oil and gas properties. Under this method, oil and gas lease acquisition costs and intangible drilling costs associated with exploration efforts that result in the discovery of proved reserves and costs associated with development drilling, whether or not successful, are capitalized when incurred. Drilling costs of exploratory wells are capitalized pending determination that proved reserves have been found. If the determination is dependent upon the results of planned additional wells and require additional capital expenditures to develop the reserves, the drilling costs will be capitalized as long as sufficient reserves have been found to justify completion of the exploratory well as a producing well, and additional wells are underway or firmly planned to complete the evaluation of the well. Exploratory wells not meeting the criteria for continued capitalization are expensed when such a determination is made. Other exploration costs are expensed as incurred. A portion of the Company’s oil and gas properties include oilfield materials and supplies inventory to be used in connection with the Company’s drilling program. These inventories are stated at the lower of cost or net realized value, which approximates fair value, and they are regularly assessed for obsolescence. Oilfield materials and supplies inventory balances were $36.7 million and $34.7 million at December 31, 2017 and 2016 , respectively. Depreciation, depletion and amortization costs for productive oil and gas properties are recorded on a unit-of-production basis. For other depreciable property, depreciation is recorded on a straight-line basis over the estimated useful life of the assets, which range between three to five years , or the lease term if shorter. Repairs and maintenance charges, including workover costs, are charged to expense as incurred. Impairment of Long-Lived Assets The Company reviews its long-lived assets in property, plant and equipment for impairment each reporting period, or whenever changes in circumstances indicate that the carrying amount of assets may not be fully recoverable. Possible indicators of impairment include lower expected future oil and gas prices, actual or expected future development or operating costs significantly higher than previously anticipated, significant downward oil and gas reserve revisions, or when changes in other circumstances indicate the carrying amount of an asset may not be recoverable. An impairment loss is recognized for proved properties when the estimated undiscounted future cash flows expected to result from the asset are less than its carrying amount. The Company estimates the future undiscounted cash flows of the affected properties to judge the recoverability of carrying amounts. Cash flows are determined on the basis of reasonable and documented assumptions that represent the best estimate of the future economic conditions during the remaining useful life of the asset. The Company’s cash flow projections into the future include assumptions on variables, such as future sales, sales prices, operating costs, economic conditions, market competition and inflation. Prices used to quantify the expected future cash flows are estimated based on forward prices prevailing in the marketplace and management’s long-term planning assumptions. Impairment is measured by the excess of carrying amount over the fair value of the assets. Unevaluated leasehold costs are assessed for impairment at the end of each reporting period and transferred to proved oil and gas properties to the extent they are associated with successful exploration activities. Significant unevaluated leasehold costs are assessed individually for impairment, based on the Company’s current exploration plans, and any indicated impairment is charged to expense. Asset Retirement Obligations The Company accounts for asset retirement obligations in accordance with applicable accounting guidelines , which require that the fair value of a liability for an asset retirement obligation be recognized in the period in which it is incurred. Specifically, the Company records a liability for the present value, using a credit-adjusted risk free interest rate, of the estimated site restoration costs with a corresponding increase to the carrying amount of the related long-lived asset. Revenues Revenues are recognized when crude oil is delivered to a buyer. The recognition criteria are satisfied when there exists a signed contract with defined pricing, delivery, and acceptance, and there is no significant uncertainty of collectability. Crude oil revenues are recorded net of royalties. Income Taxes The Company accounts for income taxes using the asset and liability method of accounting for income taxes in accordance with applicable accounting rules. Under the asset and liability method, deferred tax assets and liabilities are recognized for temporary differences between the tax bases of assets and liabilities and their carrying values for financial reporting purposes and for operating loss and tax credit carry-forwards. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in income in the period that includes the enactment date. A valuation allowance is established to reduce deferred tax assets to their net realizable amounts if it is more likely than not that the related tax benefits will not be fully realized. The Company routinely evaluates any tax deduction and tax refund position in a two-step process. The first step is to determine whether it is more likely than not that a tax position will be sustained. If that test is met, the second step is to determine the amount of benefit or expense to recognize in the consolidated financial statements. See Note 12. — Income Taxes for further information. Debt Issuance Costs Debt issuance costs consist of certain costs paid to lenders in the process of securing a borrowing facility. Debt issuance costs incurred are capitalized and subsequently charged to interest expense over the term of the related debt, using the effective interest rate method. As of December 31, 2017 and 2016 , unamortized debt issuance costs were $17.3 million and $2.3 million , of which $6.5 million and $1.6 million was classified as long-term, respectively. The current portion of the debt issuance costs, which was $10.8 million and $0.8 million as of December 31, 2017 and 2016 , respectively, is presented as a reduction to the current portion of long-term debt. Capitalized Interest The Company capitalizes interest costs for qualifying oil and gas properties. The capitalization period begins when expenditures are incurred on qualified properties, activities begin which are necessary to prepare the property for production, and interest costs have been incurred. The capitalization period continues as long as these events occur. Capitalized interest is added to the cost of the underlying assets and is depleted using the unit-of-production method in the same manner as the underlying assets. During the years ended December 31, 2017 and 2016 , the Company capitalized $2.7 million and nil , in interest cost as additions to property, plant and equipment related to the Oyo field redevelopment campaign and costs related to the drilling of an exploratory well in the Miocene formation. Stock-Based Compensation The Company recognizes all stock-based payments to employees, including grants of employee stock options, in the consolidated financial statements based on their grant-date fair values. The Company values its stock options awarded using the Black-Scholes option pricing model. Restricted stock awards are valued at the grant date closing market price. Stock-based compensation costs are recognized over the vesting period, which is the period during which the employee is required to provide service in exchange for the award. Stock-based compensation paid to non-employees are valued at the fair value of the goods or services provided at the applicable measurement date and charged to expense as services are rendered. Treasury Stock Treasury stock is reported at cost and is included in the accompanying consolidated balance sheets. Pursuant to the Company’s withholding tax policy with respect to vested restricted stock awards, the Company may withhold, on a cashless basis, a number of shares needed to settle statutory withholding tax requirements. During the years ended December 31, 2017 and 2016, 207,911 shares and 99,932 shares were withheld for taxes at a total cost of $0.7 million and $0.2 million , respectively. The following table sets forth information with respect to the withholding and related repurchases of the Company's common stock during the year ended December 31, 2017 . Total Number of Average Price January 1 - January 31, 2017 12,650 $ 3.55 February 1 - February 28, 2017 158,264 $ 3.82 May 1 - May 31, 2017 33,635 $ 1.75 December 1 - December 31, 2017 3,362 $ 2.65 Total 207,911 $ 3.45 (1) All shares repurchased were surrendered by employees to settle tax withholding obligations upon the vesting of restricted stock awards and the exercise of stock options. The price paid was the closing price on the dates in which the shares of common stock vested or when the stock options were exercised. Total Number of Average Price January 1 - January 31, 2016 3,643 $ 4.02 February 1 - February 29, 2016 62,152 $ 2.16 March 1 - March 31, 2016 17,318 $ 2.31 May 1 - May 31, 2016 1,072 $ 2.48 September 1 - September 30, 2016 6,162 $ 2.29 November 1 - November 30, 2016 6,175 $ 2.35 December 1 - December 31, 2016 3,410 $ 2.10 Total 99,932 $ 2.28 (1) All shares repurchased were surrendered by employees to settle tax withholding obligations upon the vesting of restricted stock awards. Reporting and Functional Currency The Company has adopted the U.S. dollar as the functional currency for all of its foreign subsidiaries. Gains and losses on foreign currency transactions and remeasurements are included in results of operations. Net Earnings (Loss) Per Common Share Basic net earnings or loss per common share is computed by dividing net earnings or loss by the weighted average number of shares of common stock outstanding at the end of the reporting period. Diluted net earnings or loss per share is computed by dividing net earnings or loss by the fully dilutive common stock equivalent, which consists of shares outstanding, augmented by potentially dilutive shares issuable upon the exercise of the Company’s stock options, stock warrants, non-vested restricted stock awards, and the conversions of the 2011 Promissory Note, 2014 Convertible Subordinated Note and the 2016 Promissory Note (collectively, the "Convertible Notes"), described and defined below under Note 8. - Debt - Long-Term Debt - Related Party ), calculated using the treasury stock method. The table below sets forth the number of stock options, warrants, non-vested restricted stock, and shares issuable upon conversion of Convertibles Notes that were excluded from dilutive shares outstanding during the years ended December 31, 2017 , 2016 and 2015 , as these securities are anti-dilutive because the Company was in a loss position each year. Years Ended December 31, (In thousands) 2017 2016 2015 Stock options 141 230 1,101 Stock warrants 39 3 541 Unvested restricted stock awards 1,660 1,942 1,275 Convertible Notes — — 12,379 1,840 2,175 15,296 Upon the occurrence of certain events, the Company is also contingently liable to make additional payments to Allied, under the November 2013 Transfer Agreement by the Company and its affiliates, and Allied (the “Transfer Agreement”), up to an additional amount totaling $50.0 million in cash, or the equivalent in shares of the Company’s common stock, at Allied’s option. See Note 10. — Commitments and Contingencies for further information. Non-Controlling Interests The Company reports its non-controlling interests as a separate component of equity. The Company also presents the consolidated net loss and the portion of the consolidated net loss allocable to the non-controlling interests and to the shareholders of the Company separately in its consolidated statements of operations. Losses attributable to the non-controlling interests are allocated to the non-controlling interests even when those losses are in excess of the non-controlling interests’ investment basis. As of December 31, 2017 and 2016 , the non-controlling interest recorded in equity was $1.0 million and $0.8 million , respectively, attributable to the joint ownership of an affiliate in our Erin Energy Ghana Limited subsidiary. Fair Value Measurements Fair value is defined as the amount at which an asset (or liability) could be bought (or incurred) or sold (or settled) in an orderly transaction between market participants at the measurement date. The established framework for measuring fair value establishes a fair value hierarchy based on the quality of inputs used to measure fair value, and includes certain disclosure requirements. Fair value estimates are based on either (i) actual market data or (ii) assumptions that other market participants would use in pricing an asset or liability, including estimates of risk. There are three levels of valuation hierarchy for disclosure of fair value measurements. The valuation hierarchy categorizes assets and liabilities measured at fair value into one of three different levels depending on the observability of the inputs employed in the measurement. The three levels are defined as follows: Level 1 - Unadjusted quoted prices in active markets that are accessible at the measurement date for identical, unrestricted assets or liabilities. The Company considers active markets as those in which transactions for the assets or liabilities occur in sufficient frequency and volume to provide pricing information on an on-going basis. Level 2 - Quoted prices in markets that are not active, or inputs which are observable, either directly or indirectly, for substantially the full term of the asset or liability. Substantially all of these inputs are observable in the marketplace throughout the term, can be derived from observable data, or supported by observable levels at which transactions are executed in the marketplace. Level 3 - Inputs that are unobservable and significant to the fair value measurement (including the Company’s own assumptions in determining fair value). The Company’s assessment of the significance of a particular input to the fair value measurement in its entirety requires judgment and considers factors specific to the asset or liability. Fair Value on a Recurring Basis As discussed under Note 8 - Debt , the Company recognized a derivative liability relating to the portion of the amount drawn from the MCB Financing Facility as of December 31, 2017 in which issuance of stock warrants is expected on the day the Company receives funds under the MCB Finance Facility. The Company utilized a combination of a lattice-binomial option-pricing model and the Black-Scholes valuation model to determine the estimated fair value of this derivative liability. The following table sets forth the Company’s oil and gas properties and derivative liability that is accounted for at fair value using Level 3 assumptions on a recurring basis as of December 31, 2017 and December 31, 2016: Level 3 As of December 31, (in thousands) 2017 Liabilities: Warrant Derivative liability $ 1,799 The fair value of the derivative liability is estimated using a combination of a lattice-binomial option-pricing model and the Black-Scholes valuation model with the following assumptions as of December 31, 2017: December 31, 2017 Estimated market value of common stock on measurement date $ 2.86 Estimated exercise price 2.86 Risk-free interest rate (1) 2.10 % Expected warrant term (years) 2.75 Expected volatilities (2) 10.0% - 35.6% Expected annual dividend yield — (1) The risk-free rate for periods within the contractual life of the warrants is based on the U.S. Treasury yield curve in effect at the time of grant. (2) Expected volatilities are based on historical volatility of the Oil & Gas Exploration & Production Select Industries Index, among other factors. The following table sets forth a reconciliation of changes in the fair value of the Company's financial liability that is accounted for at fair value using Level 3 inputs, and is classified as level 3 in the fair value hierarchy: Year ended (in thousands) December 31, 2017 Beginning balance $ — Loss (gain) on fair value of derivative liability (36 ) Additions 2,046 Revisions (211 ) Transfers — Ending balance $ 1,799 Change in unrealized loss (gain) included in earnings relating to derivatives still held as of December 31, 2017 $ (36 ) Fair Value on a Non-Recurring Basis The Company used discounted cash flow techniques to determine the estimated fair value of its oil and gas properties as part of the Company's analysis for impairment. Accordingly, the Company estimated the present value of expected future net cash flows from the Oyo field, discounted using risk-adjusted cost of capital. Significant Level 3 assumptions used in the calculation include the Company's estimate of future crude oil prices, production costs, development costs, and anticipated production of proved reserves, as well as appropriate risk-adjusted probable and possible reserves. During the year ended December 31, 2017, the Company recorded a non-cash impairment charge of $78.1 million to reduce the carrying value of its oil and gas properties to their estimated fair values. Other than the write-off of the carrying value of its offshore leases in Kenya (as discussed under Note 4 - Property, Plant and Equipment ), there was no impairment to the Company's oil and gas properties for the year ended December 31, 2016 . Fair Value of Financial Instruments The carrying amounts of the Company’s financial instruments, which include cash and cash equivalents, restricted cash, accounts receivable, inventory, deposits, accounts payable and accrued liabilities, and debts at floating interest rates, approximate their fair values at December 31, 2017 and 2016 , respectively, principally due to the short-term nature, maturities or nature of interest rates of the above listed items. Risks and Uncertainties The Company’s producing properties are located offshore Nigeria. Substantially all of the Company’s crude oil available for sale is sold under spot sales contracts and is delivered Free on Board ("FOB") at the point of transfer from the FPSO, as is customary in the industry. During the years ended December 31, 2017 and 2016 , the Company sold its crude oil under spot sales contracts with one customer. The Company believes that the potential loss of this customer would not prevent it from selling its crude oil, as it will find other buyers for its crude oil. Reclassification Certain reclassifications have been made to the 2016 and 2015 consolidated financial statements to conform to the 2017 presentation. These reclassifications were not material to the accompanying consolidated financial statements. Recently Issued Accounting Standards In May of 2014, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2014-09, Revenue form Contracts with Customers (Topic 606) . ASU 2014-09 core principal is that revenue should be recognized to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. The Company has evaluated the impact of this guidance and concluded that this standards update is not expected to have a material impact on the Company’s consolidated financial statements. In February 2016, the Financial Accounting Standards Board FASB issued ASU No. 2016-02, Leases (Topic 842) . ASU 2016-02 is aimed at making leasing activities more transparent and comparable, and requires substantially all leases be recognized by lessees on their balance sheet as a right-of-use asset and corresponding lease liability, including leases currently accounted for as operating leases. ASU 2016-02 is effective for the Company in the fiscal year beginning after December 15, 2018, and interim periods within those fiscal years with early adoption permitted. The Company is still evaluating the impact of this standard. However, due to the nature of its operations, the adoption of this standards update could have a material impact on its consolidated financial statements. In January 2017, the FASB issued ASU No. 2017-01, Business Combinations (Topic 805): Clarifying the Definition of a Business (“ASU 2017-01”). This ASU clarifies the definition of a business with the objective of adding guidance to assist entities with evaluating whether transactions should be accounted for as acquisitions (or disposals) of assets or businesses. This guidance is to be applied using a prospective method and is effective for annual periods, and interim periods within those annual periods, beginning after December 15, 2017. Early adoption is permitted. The adoption of this standard in the first quarter of 2018 did not have a material impact on the Company’s consolidated financial statements. In January 2017, the FASB issued ASU 2017-04, Simplifying the Test for Goodwill Impairment . ASU 2017-04 eliminates step 2 of the goodwill impairment test. An entity no longer will determine goodwill impairment by calculating the implied fair value of goodwill by assigning the fair value of a reporting unit to all of its assets and liabilities as if that reporting unit had been acquired in a business combination. A goodwill impairment will now be the amount by which a reporting unit’s carrying value exceeds its fair value, not to exceed the carrying amount of goodwill. ASU 2017-04 is effective for annual reporting periods and interim reporting periods within those annual reporting periods, beginning after December 15, 2019. Early adoption is permitted for interim or annual goodwill impairment tests performed on testing dates after January 1, 2017. The adoption of this standards update is not expected to have a material impact on the Company’s consolidated financial statements. In February 2017, the FASB issued ASU 2017-05, Other Income-Gains and Losses from the Derecognition of Nonfinancial Assets (Subtopic 610-20): Clarifying the Scope of Asset Derecognition Guidance and Accounting for Partial Sales of Nonfinancial Assets. This ASU clarifies the scope and application of ASC 610-20 on the sale or transfer of nonfinancial assets and in substance nonfinancial assets to noncustomers, including partial sales. The Company is required to adopt this guidance at the same time that it adopts the guidance in ASU 2014-09. The adoption of this standard in the first quarter of 2018 did not have a material impact on the Company’s consolidated financial statements. In March 2017, the FASB issued ASU 2017-08, Receivables-Nonrefundable Fees and Other Costs (Subtopic 310-20), Premium Amortization on Purchased Callable Debt Securities . This ASU shortens the amortization period for certain callable debt securities held at a premium to the earliest call date. However, the amendments do not require an accounting change for securities held at a discount; the discount continues to be amortized to maturity. ASU 2017-08 is effective for the Company in the fiscal year beginning after December 15, 2018, and interim periods within those fiscal years, with early adoption permitted. The adoption of this standards update is not expected to have a material impact on the Company’s consolidated financial statements. In May 2017, the FASB issued ASU 2017-09, Compensation - Stock Compensation (Topic 718): Scope of Modification Accounting, which provides guidance about which changes to the terms or conditions of a share-based payment award require an entity to apply modification accounting in Topic 718. This pronouncement is effective for annual reporting periods beginning after December 15, 2017. Early adoption is permitted. The adoption of this standards update did not have a material impact on the Company’s consolidated financial statements. In May 2017, the FASB issued ASU No. 2017-10, Service Concession Arrangements (Topic 853): Determining the Customer of the Operation Services . ASU No. 2017-10 provides clarity on determining the customer in a service concession arrangement. ASU No. 2017-10 is effective for interim and annual periods beginning after December 15, 2017, and the Company will adopt this standards update, as required, beginning with the first quarter of 2018. The adoption of this standard did not have a material impact on the Company’s consolidated financial statements. In July 2017, the FASB issued ASU No. 2017-11, Earnings Per Share (Topic 260); Distinguishing Liabilities from Equity (Topic 480); Derivatives and Hedging (Topic 815): (Part I) Accounting for Certain Financial Instruments with Down Round Features . ASU No. 2017-11 amendments simplify the accounting for certain financial instruments with down round features. The amendments require companies to disregard the down round feature when assessing whether the instrument is indexed to its own stock, for purposes of determining liability or equity classification. Companies that provide earnings per share (EPS) data will adjust their basic EPS calculation for the effect of the feature when triggered (i.e., when the exercise price of the related equity-linked financial instrument is adjusted downward because of the down round feature) and will also recognize the effect of the trigger within equity. ASU No. 2017-11 is effective for interim and annual periods beginning after December 15, 2018, and the Company will adopt this standards update, as required, beginning with the first quarter of 2019. The adoption of this standard update is not expected to have a material impact on the Company’s consolidated financial statements. In August 2017, the FASB issued ASU No. 2017-12, Derivatives and Hedging (Topic 815): Improvements to Accounting for Hedging Activities . ASU No. 2017-12 amends and better aligns an entity’s risk management activities and financial reporting for hedging relationships through changes to both the designation and measurement guidance for qualifying hedging relationships and the presentation of hedge results. To meet that objective, the amendments expand and refine hedge accounting for both non-financial and financial risk components and align the recognition and presentation of the effects of the hedging instrument and the hedged item in the financial statements. ASU No. 2017-12 is effective for interim and annual periods beginning after December 15, 2018, and the Company will adopt this standards update, as required, beginning with the first quarter of 2019. The adoption of this standard update is not expected to have a material impact on the Company’s consolidated financial statements. In January 2018, the FASB issued ASU No. 2018-01, Leases (Topic 842): Land Easement Practical Expedient for Transition to Topic 842. The amendments in ASU 2018-01 provide an optional transition practical expedient for the adoption of ASU 2016-02 that would not require an organization to reconsider their accounting for existing land easements that are not currently accounted for under the old leases standards |
