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Significant accounting policies | 12 Months Ended
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Dec. 31, 2019
Significant accounting policies |
Significant accounting policies | Note 2 – Significant accounting policies (a)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 (“IASB”) under the historical cost convention, except for equity investments, warrants and receivables from provisionally priced concentrate sales which are measured at fair value. These consolidated financial statements were authorized for issuance by the Board of Directors on March 9, 2020. (b)Principles of consolidation The consolidated financial statements include the accounts of the Company and its wholly-owned subsidiaries (its “subsidiaries”) (together the “Company”).
| (i) |  | Subsidiaries
These consolidated financial statements include the accounts of Franco-Nevada and its subsidiaries. All intercompany accounts, transactions, income and expenses, and profits or losses have been eliminated on consolidation. The Company consolidates subsidiaries where it has the ability to exercise control. Control of an investee is defined to exist when the Company is exposed to variable returns from its involvement in the investee and has the ability to affect those returns through its power over the investee. Specifically, the Company controls an investee if, and only if, it has all of the following: power over the investee (i.e. existing rights that give the Company the current ability to direct the relevant activities of the investee); exposure, or rights, to variable returns from its involvement with the investee; and the ability to use its power over the investee to affect its returns. Control is presumed to exist where the Company owns more than one half of the voting rights unless it can be demonstrated that ownership does not constitute control. The existence and effect of potential voting rights that are currently exercisable or convertible are considered when assessing whether the Company controls another entity. Subsidiaries are fully consolidated from the date on which control is transferred to the Company. They are de-consolidated from the date that control ceases. The financial statements of the subsidiaries are prepared for the same reporting period as the parent company, using consistent accounting policies. The consolidated financial statements include all assets, liabilities, revenues, expenses and cash flows of the Company and its subsidiaries after eliminating intercompany transactions. Material subsidiaries of the Company and their geographic locations at December 31, 2019 were as follows:
Entity | Jurisdiction | Economic Interest
Franco-Nevada U.S. Corporation | Delaware | 100%
Franco-Nevada GLW Holdings Corp. | British Columbia | 100%
Franco-Nevada Canada Holdings Corp. | Canada | 100%
Franco-Nevada (Barbados) Corporation | Barbados | 100%
Franco-Nevada Australia Pty Ltd. | Australia | 100%
Franco-Nevada Delaware LLC | Delaware | 100%
Franco-Nevada Texas LP | Texas | 100%
Minera Global Copper Chile S.A. | Chile | 100%
FN Subco Inc. | British Columbia | 100%
FN Holdings ULC | Alberta | 100%
All the above entities are classified as subsidiaries of the Company. There are no significant restrictions on the Company’s ability to access or use assets or settle liabilities of its subsidiaries.
| (ii) |  | Joint arrangements
A joint arrangement is defined as an arrangement over which two or more parties have joint control, which is the contractually agreed sharing of control over an arrangement. This exists only when the decisions about relevant activities (being those that significantly affect the returns of the arrangement) require unanimous consent of the parties sharing control. There are two types of joint arrangement, joint operations (“JO”) and joint ventures (“JV”). A JO is a joint arrangement whereby the parties that have joint control of the arrangement have rights to the assets and obligations for the liabilities, relating to the arrangement. In relation to the Company’s interest in any JO, the Company would recognize its share of any assets, liabilities, revenues and expenses of the JO. The Company participates in a strategic relationship with Continental Resources, Inc. (“Continental”), to jointly acquire mineral rights in the South Central Oklahoma Oil Province (“SCOOP”) and Sooner Trend Anadarko Basin Canadian and Kingfisher Counties (“STACK”) plays of Oklahoma. The mineral interests are acquired through a royalty acquisition entity, The Mineral Resource Company II, LLC (“TMRC II”), in which the Company holds an economic interest of 49.9%. The Company funds 80% of the contributions to TMRC II, with the remainder funded by Continental. The Company determined that it has joint control over TMRC II given that decisions about relevant activities require unanimous consent of the parties to the joint arrangement. The Company further determined that the joint arrangement is a JO, based on the terms of the contractual agreement which specify how revenues and expenses are shared between the parties. The Company also participates in joint operations with respect to energy working interests but does not have joint control. A working interest is an ownership position in the energy property and related operating assets, whereby the Company is liable for its proportionate share of gross costs of capital and operations based on information received from the operator. The Company’s share of the assets, liabilities, revenues and expenses of each joint operation are recognized in the statements of financial position and statements of income and comprehensive income. (c)Business combinations On the acquisition of a business, the acquisition method of accounting is used whereby the purchase consideration is allocated to the identifiable assets, liabilities and contingent liabilities (identifiable net assets) of the business on the basis of the fair value at the date of acquisition. Provisional fair values allocated at a reporting date are finalized as soon as the relevant information is available, which period shall not exceed twelve months from the acquisition date and are adjusted to reflect the transaction as of the acquisition date. The results of businesses acquired during the period are consolidated into the consolidated financial statements from the date on which control commences at the date of acquisition and taken out of the consolidated financial statements from the date on which control ceases. When all or part of the purchase consideration is contingent on future events, the cost of the acquisition initially recorded includes an estimate of the fair value of the contingent liability amounts expected to be payable in the future. The cost of acquisition is adjusted when revised estimates are made, with corresponding adjustments made to the consolidated statement of income and comprehensive income. When a business is acquired in a number of stages, the cost of each stage is compared with the fair value of the identifiable net assets at the date of that purchase. When the cost of the acquisition exceeds the fair values of the identifiable net assets acquired, the difference is recorded as goodwill. If the fair value attributable to the Company’s share of the identifiable net assets exceeds the cost of acquisition, the difference is recognized as a gain in the consolidated statement of income and comprehensive income. Acquisition costs are expensed. (d)Currency translation
| (i) |  | Functional and presentation currency
The functional currency for each entity within the Franco-Nevada group is the currency of the primary economic environment in which it operates. These consolidated financial statements are expressed in United States dollars, which is the functional currency of the majority of the subsidiaries. The parent Company’s functional currency is the Canadian dollar. The U.S. dollar is used as the presentation currency of the Company to ensure comparability with the Company’s peers. References herein to C$ are to Canadian dollars.
| (ii) |  | Foreign currency transactions and balances
Foreign currency transactions are translated into the functional currency of the respective subsidiary, using the exchange rate prevailing at the dates of the transaction (spot exchange rates). Foreign exchange gains and losses resulting from the settlement of such transactions and the re-measurement of monetary items and available-for-sale securities at the date of the consolidated statements of financial position are recognized in net income. Non-monetary items measured at historical cost are translated into the functional currency using the exchange rate at the date of the transaction. The results and financial position of the subsidiaries that have a functional currency different from the presentation currency are translated into U.S. dollars, the group’s presentation currency, as follows:
| · |  | assets and liabilities for each subsidiary are translated at the closing exchange rate at the date of the balance sheet;
| · |  | income and expenses for each subsidiary are translated at the average exchange rates during the period; and
| · |  | all resulting exchange differences are charged/credited to the currency translation adjustment in other comprehensive income.
(e)Royalty, stream and working interests Royalty, stream and working interests consist of acquired royalty interests, stream metal purchase agreements, and working interests in producing, advanced/development and exploration stage properties. Royalty, stream and working interests are recorded at cost and capitalized as tangible assets with finite lives. They are subsequently measured at cost less accumulated depletion and accumulated impairment losses. The cost of royalty, stream and working interests is determined by reference to the cost model under IAS 16. The major categories of the Company’s interests are producing, advanced and exploration. Producing assets are those that have generated revenue from steady-state operations for the Company or are expected to in the next year. Advanced assets are interests on projects which are not yet producing, but where in management’s view, the technical feasibility and commercial viability of extracting a mineral resource are demonstrable. Exploration assets represent interests on projects where technical feasibility and commercial viability of extracting a mineral resource are not demonstrable. Royalty, stream and working interests for producing and advanced assets are recorded at cost and capitalized in accordance with IAS 16, while exploration assets are recorded and capitalized in accordance with IFRS 6 Exploration for and Evaluation of Mineral Resources (“IFRS 6”). Management uses the following criteria in its assessment of technical feasibility and commercial viability:
| (i) |  | Geology: there is a known mineral deposit which contains mineral reserves or resources; or the project is adjacent to a mineral deposit that is already being mined or developed and there is sufficient geologic certainty of converting the deposit into mineral reserves or resources.
| (ii) |  | Accessibility and authorization: there are no significant unresolved issues impacting the accessibility and authorization to develop or mine the mineral deposit, and social, environmental and governmental permits and approvals to develop or mine the mineral deposit appear obtainable.
Producing mineral royalty and stream interests are depleted using the units-of-production method over the life of the property to which the interest relates. The life of the property is estimated using life of mine models specifically associated with the mineral royalty or stream properties which include proven and probable reserves and may include a portion of resources expected to be converted into reserves. Where life of mine models are not available, the Company uses publicly available statements of reserves and resources for the mineral royalty or stream properties to estimate the life of the property and portion of resources that the Company expects to be converted into reserves. Where life of mine models and publicly available reserve and resource statements are not available, depletion is based on the Company’s best estimate of the volumes to be produced and delivered under the contract. The Company relies on information available to it under contracts with operators and/or public disclosures for information on reserves and resources from the operators of the producing mineral and stream interests. Producing energy interests are depleted using the units-of-production method over the life of the property to which the interest relates, which is estimated using available estimated proved and probable reserves specifically associated with the energy properties. For energy interests, management uses reserve reports prepared by independent petroleum consultants or other qualified parties engaged by the Company. On acquisition of a producing royalty, stream or working interest, an allocation of its fair value is attributed to the exploration potential of the interest. The estimated fair value of this acquired exploration potential is recorded as an asset (non-depletable interest) on the acquisition date. Updated reserve and resource information obtained from the operators of the royalty, stream or working interest properties is used to determine the amount to be converted from non-depletable interest to depletable interest. If the cost of a royalty, stream or working interest includes contingent consideration, the contingent consideration is measured at fair value on the date of acquisition and included in the cost of the interest. Any changes in the fair value of the contingent consideration subsequent to the acquisition date are recorded against the cost of the interest acquired. Acquisition costs of advanced and exploration stage royalty, stream and working interests are capitalized and are not depleted until such time as revenue-generating activities begin. The Company may receive advance minimum payments prior to the commencement of production on some of its interests. In these circumstances, the Company would record depletion expense as described above, up to a maximum of the total of the advance minimum payment received.
| (f) |  | Working interests in energy properties
Acquired energy working interests are accounted for at cost and capitalized as tangible assets of developing or operating properties, or in accordance with IFRS 6 for exploration properties. For each energy property on which the Company has a working interest, the Company bears its proportionate share of the gross costs of capital and operations based on information received from the operator. Such capital costs are capitalized to energy well equipment which is a component of other assets on the statement of financial position. Capitalized costs, other than those related to energy well equipment, are depreciated when the asset is available for its intended use on a units-of-production basis, whereby the denominator is the proved and probable reserves associated with the energy properties. For energy well equipment, capitalized costs are depreciated by application of a 25% declining balance method.
| (g) |  | Impairment of non-financial assets
Producing and advanced mineral, stream and working interests are reviewed for impairment if there is any indication that the carrying amount may not be recoverable. Impairment is assessed at the level of cash-generating units (“CGUs”) which, in accordance with IAS 36 Impairment of Assets (“IAS 36”) are identified as the smallest identifiable group of assets that generates cash inflows, which are largely independent of the cash inflows from other assets. This is usually at the individual royalty, stream, or working interest level for each property from which cash inflows are generated. An impairment loss is recognized for the amount by which the asset’s carrying value exceeds its recoverable amount, which is the higher of fair value less costs of disposal (“FVLCD”) and value-in-use (“VIU”). The future cash flow expected is derived using estimates of proven and probable reserves, a portion of resources that is expected to be converted into reserves and information regarding the mineral, stream and energy properties, respectively, that could affect the future recoverability of the Company’s interests. Discount factors are determined individually for each asset and reflect their respective risk profiles. In certain circumstances, the Company may use a market approach in determining the recoverable amount which may include an estimate of (i) net present value of estimated future cash flows; (ii) dollar value per ounce or pound of reserve/resource; (iii) cash-flow multiples; and/or (iv) market capitalization of comparable assets. Impairment losses are charged to the royalty, stream or working interest and any associated energy well equipment in the case of working interests. Assets are subsequently reassessed for indications that an impairment loss previously recognized may no longer exist. An impairment charge is reversed if the conditions that gave rise to the recognition of an impairment loss are subsequently reversed and the asset’s recoverable amount exceeds its carrying amount. Impairment losses can be reversed only to the extent that the recoverable amount does not exceed the carrying value that would have been determined had no impairment been recognized previously. Gold bullion and prepaid expenses are similarly assessed for impairment whenever indicators of impairment exist in accordance with IAS 36. An impairment loss is recognized for the amount by which the asset’s carrying value exceeds its recoverable amount, which is the higher of FVLCD and VIU. Interests classified as exploration are assessed for impairment whenever indicators of impairment exist in accordance with IFRS 6. An impairment loss is recognized for the amount by which the asset’s carrying value exceeds its recoverable amount, which is the higher of FVLCD and VIU. An interest that has previously been classified as exploration is also assessed for impairment before reclassification to either advanced or producing, and the impairment loss, if any, is recognized in net income.
| (h) |  | Financial instruments
Financial assets and financial liabilities are recognized on the Company’s statement of financial position when the Company has become a party to the contractual provisions of the instrument. Financial assets are derecognized when the rights to receive cash flows from the assets have expired or have been transferred and the Company has transferred substantially all risks and rewards of ownership. The Company’s financial instruments consist of cash and cash equivalents, receivables, accounts payable, accrued liabilities, debt, and investments, including equity investments, loans receivable, and warrants. Financial instruments are recognized initially at fair value. Under the IFRS 9 model for classification the Company has classified its financial assets as described below.
| (i) |  | Cash and cash equivalents
Cash and cash equivalents comprise cash on hand, deposits held with banks and other short-term highly liquid investments with original maturities of three months or less. Cash and cash equivalents are recorded at amortized cost using the effective interest method.
| (ii) |  | Receivables
Receivables, other than those related to stream agreements with provisional pricing mechanisms, are classified as financial assets at amortized cost and measured using the effective interest method less any impairment loss allowance. The loss allowance for receivables is measured based on lifetime expected credit losses.
| (iii) |  | Investments
Investments comprise equity interests in publicly-traded and privately-held entities, warrants, marketable securities with original maturities at the date of the purchase of more than three months and a loan receivable. The Company’s equity investments are held for strategic purposes and not for trading. The Company made an irrevocable election to designate these investments in common shares at FVTOCI. FVTOCI investments are recognized initially at fair value plus transaction costs. Subsequent to initial recognition, FVTOCI investments are measured at fair value and changes in the fair value are recognized directly in other comprehensive income (loss). When an equity investment at FVTOCI is sold, the accumulated gains or losses are reclassified from accumulated other comprehensive income (loss) directly to deficit. Translation differences on equity securities classified as FVTOCI are included in other comprehensive income (loss). Derivative instruments, such as warrants and receivables related to stream agreements with provisional pricing mechanisms, are classified as fair value through profit and loss (“FVTPL”) and are recognized initially at fair value. Subsequent to initial recognition, derivatives are measured at fair value. In the case of receivables related to stream agreements with provisional pricing, once the final settlement price is determined the financial instrument is no longer a derivative and is classified as a financial asset at amortized cost. Changes in the fair value of receivables related to stream agreements with provisional pricing mechanisms are recognized in revenue in the statement of income and other comprehensive income. Changes in fair value of warrants are recognized as other income (expenses) in the statement of income and comprehensive income. Loans receivable are classified as financial assets at amortized cost because these instruments are held for collection of contractual cash flows and those cash flows represent solely payments of principal and interest. Loans are measured at amortized cost using the effective interest method, less any impairment loss allowance. The impairment loss allowance for the loan receivable is measured based on expected credit losses under the general approach. Interest income is recognized by applying the effective interest rate method and presented as finance income in the statement of income and comprehensive income.
| (iv) |  | Financial liabilities
Financial liabilities, including accounts payable, accrued liabilities and debt, are classified as financial liabilities to be subsequently measured at amortized cost using the effective interest method.
| (i) |  | Revenue recognition
The Company generates revenue from contracts with customers under each of its royalty, stream and working interests. The Company has determined that each unit of a commodity that is delivered to a customer under a royalty, stream, or working interest arrangement is a performance obligation for the delivery of a good that is separate from each other unit of the commodity to be delivered under the same arrangement.
| (i) |  | Stream arrangements
Under its stream arrangements, the Company acquires commodities from operators of mining properties on which the Company has stream interests. The Company sells the commodities received under these arrangements to its customers under separate sales contracts. For those stream arrangements where the Company acquires refined metal from the operator, the Company sells the refined metal to third party financial institutions or brokers. The Company transfers control over the commodity on the date the commodity is delivered to the customer’s metal account, which is the date that title to the commodity and the risks and rewards of ownership transfer to the customer and the customer is able to direct the use of and obtain substantially all of the benefits from the commodity. The transaction price for these sales is fixed at the delivery date based on the spot price for the commodity and payment of the transaction price is generally due immediately when control has been transferred. For those stream arrangements where the Company acquires the commodities in concentrate form from the operator, the Company sells the concentrate under sales contracts with independent smelting companies. The Company transfers control over the concentrate at the time of shipment, which is when the risks and rewards of ownership and title pass to the independent smelting company. The final prices for metals contained in the concentrate are determined based on the market price for the metals on a specified future date after shipment. Upon transfer of control at shipment, the Company records revenue and a corresponding receivable from these sales based on forward commodity prices at the time of shipment. Variations between the price recorded at the transfer of control and the actual final price set under the contracts with the smelting companies are caused by changes in market commodity prices, and result in an embedded derivative in the receivable. The embedded derivative is recorded at fair value each period until final settlement occurs, with changes in fair value classified as provisional price adjustments and included as a component of stream revenue. These provisional price adjustments associated with concentrate sales are not considered to be revenue from contracts with customers as they arise from changes in market commodity prices.
| (ii) |  | Royalty arrangements
For royalty interests, the Company sells commodities to customers under contracts that are established by the operator of each mining or energy property on which the royalty interest is held. The Company recognizes revenue from these sales when control over the commodity transfers to the customer. This transfer of control generally occurs when the operator of the mining or energy property on which the royalty interest is held physically delivers the commodity to the customer. At this point in time, the risks and rewards of ownership have transferred to the customer and the Company has an unconditional right to payment. Revenue from royalty arrangements is measured at the transaction price agreed in the royalty arrangement with the operator of each mining or energy property. The transaction price will reflect the gross value of the commodity sold less deductions that vary based on the terms of the royalty arrangement.
| (iii) |  | Working interest arrangements
The Company sells its proportionate share of the crude oil, natural gas and natural gas liquids to third-party customers using the services of a third-party marketing agent. The Company transfers control over the oil and gas at the time it enters the pipeline system, which is when title and the risks and rewards of ownership are transferred to customers and the Company has an unconditional right to payment. Revenue is measured at the transaction price set by reference to monthly market commodity prices plus certain price adjustments. Price adjustments include product quality and transportation adjustments and market differentials.
| (j) |  | Costs of sales
Costs of sales includes various production taxes that are recognized with the related revenues and the Company’s share of the gross operating costs for the working interests in the energy properties. For stream agreements, the Company purchases gold, silver or platinum group metals for a cash payment of the lesser of a set contractual price, subject to annual inflationary adjustments, and the prevailing market price per ounce of gold and/or silver when purchased. Under certain stream agreements, the Company purchases gold and/or silver for a cash payment that is a fixed percentage of the prevailing market price per ounce of gold and/or silver when purchased. In certain instances, the Company purchases a fixed amount of gold by providing an initial deposit. The initial deposit is recorded as a prepaid gold asset and classified within current prepaid expenses and other assets or non-current other assets dependent on whether delivery will occur within 12 months of the reporting date. When gold is delivered to the Company it is recorded as inventory until such time as it is sold and the cost of the gold is recorded as a cost of sale.
| (k) |  | Income taxes
The income tax expense or recovery represents the sum of current and deferred income taxes. Current income tax payable is based on taxable profit for the year. Taxable profit differs from net income as reported in the consolidated statement of income and other comprehensive income because it excludes items of income or expense that are taxable or deductible in other years and it further excludes items that are never taxable or deductible. The Company’s liability for current tax is calculated by using tax rates and laws that have been enacted or substantively enacted at the statement of financial position date. Deferred tax is the tax expected to be payable or recoverable on differences between the carrying amount of assets and liabilities in the consolidated financial statements and the corresponding tax bases used in the computation of taxable profit, and is accounted for using the statement of financial position liability method. Deferred tax liabilities are recognized for all taxable temporary differences and deferred tax assets are recognized to the extent that it is probable that taxable profits will be available against which deductible temporary differences can be utilized. Such assets and liabilities are not recognized if the temporary differences arise from initial recognition of an asset or liability in a transaction that is not a business combination and, at the time of the transaction, affects neither the accounting profit nor taxable profit. Deferred tax liabilities are recognized for taxable temporary differences arising on investments in subsidiaries, except where the Company is able to control the reversal of the temporary difference and it is probable that the temporary difference will not reverse in the foreseeable future. Deferred tax is calculated at the tax rates that are enacted or substantively enacted at the statement of financial position date and are expected to apply to the period when the deferred tax asset is realized or the liability is settled. Deferred tax is charged or credited in the consolidated statement of income and other comprehensive income, except when it relates to items credited or charged directly to equity, in which case the deferred tax is also accounted for within equity.
| (l) |  | Stock options
The Company may issue equity-settled share-based payments to directors, officers, employees and consultants under the terms of its share compensation plan. Equity-settled share-based payments are measured at fair value at the date of grant. The fair value determined at the date of grant of equity-settled share-based payments is expensed over the expected service period with a corresponding change to contributed surplus and is based on the Company’s estimate of shares that will ultimately vest. Fair value is measured by use of the Black-Scholes option pricing valuation model. The expected life used in the model is adjusted, based on management’s best estimate, for the effect of non-transferability, exercise restrictions and behavioural considerations. Expected volatility is estimated by considering historic average share price volatility. Any consideration paid or received upon the exercise of the stock options or purchase of shares is credited to share capital.
| (m) |  | Restricted share units
The Company may grant performance-based or time-based restricted share units (“RSUs”) to officers and employees under the terms of its share compensation plan. When each RSU vests, the Company plans to settle every RSU with one common share of the parent company. The Company recognizes the fair value of the RSUs as share-based compensation expense which is determined with reference to the weighted average trading price of the Company’s common shares over the five trading days immediately preceding the date of issuance. The amount recognized reflects the number of awards for which the related service and non-market performance conditions associated with these awards are expected to be met. The Company expenses the fair value of the RSUs over the applicable service period, with a corresponding change in contributed surplus. Time-based RSUs vest over a three year period on the anniversary of the date of grant. For performance vesting conditions, the grant date fair value of the restricted share unit is measured to reflect such conditions and this estimate is not updated between expected and actual outcomes. Performance-based RSUs vest at the end of a three year period following the achievement of certain performance criteria and target settlement will range from 0% to 100% of the value.
| (n) |  | Deferred share units
Non-executive directors may choose to convert their directors’ fees into deferred share units (“DSUs”) under the terms of the Company’s deferred share unit plan (the “DSU Plan”). Directors must elect to convert their fees prior to January 1 in each year. The Company may also award DSUs to non-executive directors under the DSU Plan as compensation. When dividends are declared by the Company, directors are also credited with dividend equivalents in the form of additional DSUs based on the number of vested DSUs each director holds on the record date for the payment of a dividend. Retainer, conversion and dividend equivalent DSUs vest immediately. The fair value of DSUs at the time of conversion or award, as applicable, is determined with reference to the weighted average trading price of the Company’s common shares over the five trading days immediately preceding the date of conversion or award, as applicable. The fair value of the DSUs, which are settled in cash, is recognized as a share-based compensation expense with a corresponding increase in liabilities, over the service period. The fair value of the DSUs is marked to the quoted market price of the Company’s common shares at each reporting date with a corresponding change in the consolidated statement of income and comprehensive income. Participants are not allowed to redeem their DSUs until retirement or termination of directorship. The cash value of the DSUs at the time of redemption is equivalent to the market value of the Company’s common shares when redemption takes place.
| (o) |  | Segment reporting
The Company is engaged in the management and acquisition of royalties, streams and working interests in the mining and energy sectors. Operating segments are reported in a manner consistent with the internal reporting provided to the Chief Executive Officer (“CEO”) who fulfills the role of the chief operating decision-maker. The CEO is responsible for allocating resources and assessing performance of the Company’s operating segments.
| (p) |  | Earnings per share
Basic earnings per share is computed by dividing the net income or loss by the weighted average number of common shares outstanding during each period. Diluted earnings per share reflects the effect of all potentially dilutive common share equivalents, which includes dilutive share options and restricted share units granted to employees and warrants computed using the treasury stock method. New and Amended Standards Adopted by the Company The following standard was effective and implemented for the annual period as of January 1, 2019. IFRS 16 Leases Effective January 1, 2019, the Company has adopted IFRS 16 Leases (“IFRS 16”). IFRS 16 requires lessees to recognize assets and liabilities for most leases. The new standard was applied using a modified retrospective approach whereby the effects of the change in accounting policies for leases as at January 1, 2019 are presented together as a single adjustment to the opening balance of deficit. Therefore, the comparative information has not been restated and continues to be reported under IAS 17 Leases. As permitted under transitional provisions, the Company has elected to use the following practical expedients:
| · |  | Not to separate non-lease from lease components, and instead account for each lease component and any associated non-lease components as a single lease component.
| · |  | Not to recognize right-of-use assets and associated liabilities for low value assets or lease terms of 12 months or less.
| · |  | Measure its right-of-use assets at amounts equal to the associated lease liabilities; as such, the adjustment to deficit on transition is nil.
The Company’s significant lease arrangements relate to its office premises. Adoption of the new standard resulted in the recognition of right-of-use assets of $2.8 million within other assets on the statement of financial position, measured at an amount equal to the related lease liability. IFRIC 23 Uncertainty over Income Tax Treatments Effective January 1, 2019, the Company has adopted IFRIC 23 Uncertainty over Income Tax Treatments (“IFRIC 23”). IFRIC 23 clarifies how to apply the recognition and measurement requirements of IAS 12 Income Taxes when there is uncertainty over income tax treatments. The application of IFRIC 23 did not have a significant impact on the Company’s consolidated financial statements. New Accounting Standards Issued But Not Yet Effective Amendments to IFRS 3 Business Combinations In October 2018, the IASB issued amendments to the definition of a business in IFRS 3 Business Combinations (“IFRS 3”). The amendments are intended to assist entities to determine whether a transaction should be accounted for as a business combination or as an asset acquisition. The amendments clarify the minimum requirements for a business, remove the assessment of whether market participants are capable of replacing any missing elements, add guidance to help entities assess whether an acquired process is substantive, narrow the definitions of a business and of outputs, and introduce an optional fair value concentration test. The amendments to IFRS 3 are effective for annual reporting periods beginning on or after January 1, 2020 and apply prospectively. Earlier application is permitted. While it is generally expected that the application of the amendments will result in more acquisitions being accounted for as asset acquisitions, the Company will evaluate the impact of the amendments based on the nature and terms of acquisitions the Company may complete in future periods.

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