2. Summary of Significant Accounting Policies
Basis of Presentation
The Group maintains its books and records in accordance with accounting and taxation principles and practices mandated by legislation in the countries in which it operates (primarily the Russian Federation). The accompanying Consolidated Financial Statements were primarily derived from the Group’s statutory books and records with adjustments and reclassifications made to present them in accordance with International Financial Reporting Standards (“IFRS”).
Subsequent events occurring after December 31, 2014 were evaluated through February 27, 2015 the date these Consolidated Financial Statements were authorised for issue.
Basis of Measurement
The Consolidated Financial Statements are prepared on the historical cost basis except that derivative financial instruments, financial investments classified as available-for-sale, and obligations under the Stock Appreciation Rights plan (SARs) are stated at fair value.
Foreign Currency Translation
The functional currency of each of the Group’s consolidated entities is the currency of the primary economic environment in which the entity operates. In accordance with IAS 21 the Group has analysed several factors that influence the choice of functional currency and, based on this analysis, has determined the functional currency for each entity of the Group. For the majority of the entities the functional currency is the local currency of the entity.
Monetary assets and liabilities have been translated into the functional currency at the exchange rate as of reporting date. Non-monetary assets and liabilities have been translated at historical rates. Revenues, expenses and cash flows are translated into functional currency at average rates for the period or exchange rates prevailing on the transaction dates where practicable. Gains and losses resulting from the re-measurement into functional currency are included in profit and loss, except when deferred in other comprehensive income as qualifying cash flow hedges.
The presentation currency for the Group is the Russian Ruble. Gains and losses resulting from the re-measurement into presentation currency are included in a separate line of equity in the Consolidated Statement of Financial Position.
The translation of local currency denominated assets and liabilities into functional currency for the purpose of these Consolidated Financial Statements does not indicate that the Group could realise or settle, in functional currency, the reported values of these assets and liabilities. Likewise, it does not indicate that the Group could return or distribute the reported functional currency value of capital to its shareholders.
Principles of Consolidation
The consolidated financial statements include the accounts of subsidiaries in which the Group has control. Control implies rights or exposure to variable returns from the involvement with the investee and the ability to affect those returns through the power over the investee. An investor has power over an investee when the investor has existing rights that give it the current ability to direct the relevant activities, i.e. the activities that significantly affect the investee’s returns. An investor is exposed, or has the rights to variable returns from its involvement with investee when the investor’s return from its involvement have the potential to vary as a result of the investee’s performance. The financial statements of subsidiaries are included in the Consolidated Financial Statements of the Group from the date when control commences until the date when control ceases.
In assessing control, the Group takes into consideration potential voting rights that are substantive. Investments in entities that the Group does not control, but where it has the ability to exercise significant influence over operating and financial policies, are accounted for under the equity method except for investments that meet criteria of joint operations, which are accounted for on the basis of the Group’s interest in the assets, liabilities, expenses and revenues of the joint operation. All other investments are classified either as held-to-maturity or as available for sale.
The Group accounts for its business combinations according to IFRS 3 Business Combinations. The Group applies the acquisition method of accounting and recognises assets acquired and liabilities assumed in the acquiree at the acquisition date, measured at their fair values as of that date. Determining the fair value of assets acquired and liabilities assumed requires Management’s judgment and often involves the use of significant estimates and assumptions. Non-controlling interest is measured at fair value (if shares of acquired company have public market price) or at the non-controlling interest’s proportionate share of the acquiree’s net identifiable assets (if shares of acquired company do not have public market price).
Goodwill is measured by deducting the net assets of the acquiree from the aggregate of the consideration transferred for the acquiree, the amount of non-controlling interest in the acquiree and fair value of an interest in the acquiree held immediately before the acquisition date. Any negative amount (“bargain purchase”) is recognised in profit or loss, after Management identified all assets acquired and all liabilities and contingent liabilities assumed and reviewed the appropriateness of their measurement.
The consideration transferred does not include amounts related to the settlement of pre-existing relationships. Such amounts are generally recognised in profit or loss. Transaction costs, other than those associated with the issue of debt or equity securities, that the Group incurs in connection with a business combination are expensed as incurred.
Ownership interests in the Group’s subsidiaries held by parties other than the Group entities are presented separately in equity in the Consolidated Statement of Financial Position. The amount of consolidated net income attributable to the parent and the non-controlling interest are both presented on the face of the Consolidated Statement of Profit and Loss and Other Comprehensive Income.
Changes in Ownership Interests in Subsidiaries without Change of control
Transactions with non-controlling interests that do not result in loss of control are accounted for as equity transactions — that is, as transactions with the owners in their capacity as owners. The difference between fair value of any consideration paid and the relevant share acquired of the carrying value of net assets of the subsidiary is recorded in equity. Gains or losses on disposals to non-controlling interests are also recorded in equity.
Disposal of Subsidiaries
When the Group ceases to have control any retained interest in the entity is remeasured to its fair value at the date when control is lost, with the change in carrying amount of the investment to the entity recognised in profit or loss. The fair value is the initial carrying amount for the purposes of subsequently accounting for the retained interest as an associate, joint venture or financial asset. In addition, any amounts previously recognised in other comprehensive income in respect of that entity are accounted for as if the group had directly disposed of the related assets or liabilities. This may mean that amounts previously recognised in other comprehensive income are reclassified to profit or loss.
Acquisitions from Entities under Common Control
Business combinations involving entities under common control are accounted for by the Group using the predecessor accounting approach from the acquisition date. The Group uses predecessor carrying values for assets and liabilities, which are generally the carrying amounts of the assets and liabilities of the acquired entity from the consolidated financial statements of the highest entity that has common control for which consolidated financial statements are prepared. These amounts include any goodwill recorded at the consolidated level in respect of the acquired entity.
Investments in Associates
An associate is an entity over which the investor has significant influence. Investments in associates are accounted for using the equity method and are recognised initially at cost. The consolidated financial statements include the Group’s share of the profit or loss and other comprehensive income of equity accounted investees, after adjustments to align accounting policies with those of the Group, from the date that significant influence commences until the date that significant influence ceases.
Joint Operations and Joint Ventures
A joint operation 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.
A joint venture is a joint arrangement whereby the parties that have joint control of the arrangement have rights to the net assets of the arrangement.
Where the Group acts as a joint operator, the Group recognises in relation to its interest in a joint operation:
- Its assets, including its share of any assets held jointly;
- Its liabilities, including its share of any liabilities incurred jointly;
- Its revenue from the sale of its share of the output arising from the joint operation;
- Its share of the revenue from the sale of the output by the joint operation; and
- Its expenses, including its share of any expenses incurred jointly.
With regards to joint arrangements, where the Group acts as a joint venturer, the Group recognises its interest in a joint venture as an investment and accounts for that investment using the equity method.
Transactions Eliminated on Consolidation
Intra-group balances and transactions, and any unrealised income and expenses arising from intra-group transactions, are eliminated in preparing the consolidated financial statements. Unrealised gains arising from transactions with equity accounted investees are eliminated against the investment to the extent of the Group’s interest in the investee. Unrealised losses are eliminated in the same way as unrealised gains, but only to the extent that there is no evidence of impairment.
Cash and Cash Equivalents
Cash represents cash on hand and in bank accounts, that can be effectively withdrawn at any time without prior notice. Cash equivalents include all highly liquid short-term investments that can be converted to a certain cash amount and mature within three months or less from the date of purchase. They are initially recognised based on the cost of acquisition which approximates fair value.
Non-Derivative Financial Assets
The Group has the following non-derivative financial assets: financial assets at fair value through profit or loss, held-to-maturity financial assets, loans and receivables and available-for-sale financial assets.
The Group initially recognises loans and receivables on the date that they are originated. All other financial assets (including assets designated as at fair value through profit or loss) are recognised initially on the trade date, which is the date that the Group becomes a party to the contractual provisions of the instrument.
The Group derecognises a financial asset when the contractual rights to the cash flows from the asset expire, or it transfers the rights to receive the contractual cash flows in a transaction in which substantially all the risks and rewards of ownership of the financial asset are transferred. Any interest in such transferred financial assets that is created or retained by the Group is recognised as a separate asset or liability.
Financial assets and liabilities are offset and the net amount presented in the statement of financial position when, and only when, the Group has a legal right to offset the amounts and intends either to settle them on a net basis or to realise the asset and settle the liability simultaneously.
Financial Assets at Fair Value through Profit or Loss
A financial asset is classified at fair value through profit or loss category if it is classified as held for trading or is designated as such upon initial recognition. Financial assets are designated at fair value through profit or loss if the Group manages such investments and makes purchase and sale decisions based on their fair value in accordance with the Group’s documented risk management or investment strategy. Financial assets at fair value through profit or loss are measured at fair value, and changes therein are recognised in profit and loss.
Held-to-maturity Financial Assets
If the Group has the positive intent and ability to hold to maturity debt securities that are quoted in an active market, then such financial assets are classified to held-to-maturity category. Held-to-maturity financial assets are recognised initially at fair value. Subsequent to initial recognition held-to-maturity financial assets are measured at amortised cost using the effective interest method, less any impairment losses. Any sale or reclassification of a more than insignificant amount of held-to-maturity investments not close to their maturity would result in the reclassification of all held-to-maturity investments as available-for-sale, and prevent the Group from classifying investment securities as held-to-maturity for the current and the following two financial years.
Loans and Receivables
Loans and receivables is a category of financial assets with fixed or determinable payments that are not quoted in an active market. Such assets are recognised initially at fair value. Subsequent to initial recognition loans and receivables are measured at amortised cost using the effective interest method, less any impairment losses. Allowances are provided for estimated losses and for doubtful debts based on estimates of uncollectible amounts. These estimates are based on the aging of the receivable, the past history of settlements with the debtor and current economic conditions. Estimates of allowances require the exercise of judgment and the use of assumptions.
Available-for-sale Financial Assets
Available-for-sale financial assets are non-derivative financial assets that are designated as available-for-sale or are not classified in any of the above categories of financial assets. Such assets are recognised initially at fair value. Subsequent to initial recognition, they are measured at fair value and changes therein, other than impairment losses and foreign currency differences on available-for-sale debt instruments, are recognised in other comprehensive income and presented within equity in the other reserves line. When an investment is derecognised or impaired, the cumulative gain or loss in equity is reclassified to profit and loss. Unquoted equity instruments fair value of which cannot be measured reliably are carried at cost less any impairment losses.
Non-Derivative Financial Liabilities
The Group initially recognises debt securities issued and liabilities on the date that they are originated. All other financial liabilities (including liabilities designated at fair value through profit or loss) are recognised initially on the trade date on which the Group becomes a party to the contractual provisions of the instrument. The Group derecognises a financial liability when its contractual obligations are discharged, cancelled or expire. The Group classifies non-derivative financial liabilities into the other financial liabilities category. Such financial liabilities are recognised initially at fair value. Subsequent to initial recognition, these financial liabilities are measured at amortised cost using the effective interest method. Other financial liabilities comprise loans and borrowings, bank overdrafts, and trade and other payables.
Derivative Financial Instruments
A substantial portion of the Group’s revenues are received in US Dollars. Additionally, a significant portion of the Group’s financing activities is also undertaken in US Dollars. However, the Group has also significant long-term debt in Russian Ruble. Accordingly, a change in the value of the US Dollar against the Russian Ruble will impact the Group’s operating results and cash flows. The Group’s policy is to hedge anticipated cash flows from revenues received in USD up to the amount of expected redemption of loans denominated in Russian Roubles. These anticipated cash flows represent highly probable forecast transactions. For the purpose of managing its USD/Rouble foreign currency exposure, the Group enters into deliverable forward contracts to sell the notional amount of US Dollar matching the amount of loans due for redemption.
Derivative instruments are recorded at fair value on the Consolidated Statement of Financial Position in either financial assets or liabilities. Realised and unrealised gains and losses are presented in profit and loss on a net basis, except for those derivatives, where hedge accounting is applied.
The estimated fair values of derivative financial instruments are determined with reference to various market information and other valuation methodologies as considered appropriate, however considerable judgment is required in interpreting market data to develop these estimates. Accordingly, the estimates are not necessarily indicative of the amounts that the Group could realise in a current market situation.
The Group applies hedge accounting policy for those derivatives that are designated as a hedging instrument.
The Group has designated only cash flow hedges — hedges against the exposure to the variability of cash flow currency exchange rates on a highly probable forecast transaction. The effective portion of changes in the fair value of derivatives that are designated and qualify as cash flow hedges is recognised in other comprehensive income. Changes in the fair value of certain derivative instruments that do not qualify for hedge accounting are recognised immediately in profit and loss.
When a hedging instrument expires or is sold, or when a hedge no longer meets the criteria for hedge accounting, any cumulative gain or loss existing in equity at that time remains in equity until the forecast transaction occurs. Any ineffective portion is directly recognised in profit and loss. When a forecast transaction is no longer expected to occur, the cumulative gain or loss on any associated hedging instrument that was reported in equity is immediately transferred to profit and loss.
The fair value of the hedge item is determined at the end of each reporting period with reference to the market value, which is typically determined by the credit institutions.
Inventories, consisting primarily of crude oil, refined oil products and materials and supplies are stated at the lower of cost and net realisable value. The cost of inventories is calculated on a weighted average basis, and includes expenditure incurred in acquiring the inventories, production or conversion costs, and other costs incurred in bringing them to their existing location and condition. Net realisable value is the estimated selling price in the ordinary course of business, less the estimated costs of completion and selling expenses.
Assets Classified as Held for Sale
Assets are classified in the Consolidated Statement of Financial Position as ‘assets held for sale’ if their carrying amount will be recovered principally through a sale transaction (including loss of control of a subsidiary holding the assets) within twelve months after the reporting period in which they were reclassified. These assets are measured at the lower of the carrying amounts and fair value less costs to sell. Assets classified as held for sale in the current period’s statement of financial position are not reclassified or re-presented in the comparative statement of financial position to reflect the classification at the end of the current period.
Goodwill that arises on the acquisition of subsidiaries is included in intangible assets. Subsequently goodwill is measured at cost less accumulated impairment losses.
Goodwill is tested annually for impairment as well as when there are indicators of impairment. For the purpose of impairment testing goodwill is allocated to the cash generating units that are expected to benefit from synergies from the combination.
Other intangible assets that are acquired by the Group, which have finite useful lives, are measured at cost less accumulated amortisation and accumulated impairment loss.
Intangible assets that have limited useful lives are amortised on a straight-line basis over their useful lives. Useful lives with respect to intangible assets are determined as follows:
|Intangible Asset Grou||Average Life|
|Licenses and software||1–5 years|
|Land rights||25 years|
Property, Plant and Equipment
Property, plant and equipment is stated at historical cost, net of accumulated depreciation and any impairment. The cost of maintenance, repairs and replacement of minor items of property, plant are expensed when incurred; renewals and improvements of assets are capitalised. Costs of turnarounds and preventive maintenance performed with respect to oil refining assets are expensed when incurred if turnaround do not involve replacement of assets or installation of new assets. Upon sale or retirement of property, plant and equipment, the cost and related accumulated depreciation and impairment losses are eliminated from the accounts. Any resulting gains or losses are recorded in profit and loss.
Advances made on property, plant and equipment and construction in progress are accounted for within other non-current assets as a part of non-current non-financial accounts receivable.
Oil and Gas Properties
Exploration and Evaluation assets
Acquisition costs include amounts paid for the acquisition of exploration and development licenses.
Exploration and evaluation assets include:
- Costs of topographical, geological, and geophysical studies and rights of access to properties to conduct those studies, that are directly attributable to exploration activity;
- Costs of carrying and retaining undeveloped properties;
- Bottom hole contribution;
- Dry hole contribution; and
- Costs of drilling and equipping exploratory wells.
The costs incurred in finding, acquiring, and developing reserves are capitalised on a ‘field by field’ basis. On discovery of a commercially-viable mineral reserve, the capitalised costs are allocated to the discovery. If a discovery is not made, the expenditure is charged as an expense. Exploratory drilling costs and dry and bottom hole contributions are temporarily capitalised and treated as oil and gas assets within property, plant and equipment.
Costs of topographical, geological, and geophysical studies, rights of access to properties to conduct those studies are considered as part of oil and gas assets until it is determined that the reserves are proved and are commercially viable.
If no reserves are found, the exploration asset is tested for impairment. If extractable hydrocarbons are found and, subject to further appraisal activity, that may include drilling of further wells, are likely to be developed commercially; then the costs continue to be carried as oil and gas asset as long as some sufficient/continued progress is being made in assessing the commerciality of the hydrocarbons. All such carried costs are subject to technical, commercial and Management review as well as review for impairment at least once a year to confirm the continued intent to develop or otherwise extract value from the discovery. When this is no longer the case, the costs are written off.
Other exploration costs are charged to expense when incurred.
An exploration and evaluation asset is no longer classified as such when the technical feasibility and commercial viability of extracting a mineral resource are demonstrable. Exploration and evaluation assets are assessed for impairment, and any impairment loss is recognised, before reclassification.
Development costs are incurred to obtain access to proved reserves and to provide facilities for extracting, treating, gathering and storing oil and gas. They include the costs of development wells to produce proved reserves as well as costs of production facilities such as lease flow lines, separators, treaters, heaters, storage tanks, improved recovery systems, and nearby gas processing facilities.
Expenditures for the construction, installation, or completion of infrastructure facilities such as platforms, pipelines and the drilling of development wells are capitalised within oil and gas assets.
Depreciation, Depletion and Amortisation
Depletion of acquisition and development costs of proved oil and gas properties is calculated using the unit-of-production method based on proved reserves and proved developed reserves, respectively. These costs are reclassified as proved properties when the relevant reserve reclassification is made. Acquisition costs of unproved properties are not amortised.
Depreciation and amortisation with respect to operations other than oil and gas producing activities is calculated using the straight-line method based on estimated economic lives. Depreciation rates are applied to similar types of buildings and equipment having similar economic characteristics, as shown below:
|Asset Group||Average Life|
|Buildings and constructions||8–35 years|
|Machinery and equipment||8–20 years|
|Vehicles and other equipment||3–10 years|
Catalysts and reagents mainly used in the refining operations are treated as other equipment. The assets are depreciated based on the straight-line method.
Capitalisation of Borrowing Costs
Borrowing costs directly attributable to the acquisition, construction or production of assets (including oil and gas properties) that necessarily take a substantial time to get ready for intended use or sale (qualifying assets) are capitalised as part of the costs of those assets. Exchange differences arising from foreign currency borrowings to the extent that they are regarded as an adjustment to interest costs are included in the borrowing costs eligible for capitalisation.
Impairment of Long-Lived Assets
The carrying amounts of the Group’s long-lived assets, other than goodwill, inventories, long-term financial assets and deferred tax assets are reviewed at each reporting date to determine whether there is any indication of impairment. If any such indication exists, then the asset’s recoverable amount is estimated. An impairment loss is recognised if the carrying amount of an asset or its related cash-generating unit (CGU) exceeds its estimated recoverable amount. Impairment losses are recognised in profit or loss.
Impairment of Non-Derivative Financial Assets
Financial assets are assessed at each reporting date to determine whether there is any objective evidence of impairment. A financial asset is impaired if objective evidence indicates that a loss event has occurred after the initial recognition of the asset, and that the loss event had a negative effect on the estimated future cash flows of that asset that can be estimated reliably.
The Group considers evidence of impairment for loans and receivables and held-to-maturity investments at both a specific asset and collective level. All individually significant loans and receivables and held-to-maturity investments are assessed for specific impairment. Loans and receivables and held-to-maturity investments that are not individually significant are collectively assessed for impairment by grouping together loans and receivables and held-to-maturity investments with similar risk characteristics.
An impairment loss in respect of a financial asset measured at amortised cost is calculated as the difference between its carrying amount, and the present value of the estimated future cash flows discounted at the asset’s original effective interest rate. Losses are recognised in profit or loss and reflected in an allowance account against loans and receivables or held-to-maturity investments.
The Group has decommissioning obligations associated with its core activities. The nature of the assets and potential obligations is as follows:
Exploration and Production: the Group’s activities in exploration, development and production of oil and gas in the deposits are related to the use of such assets as wells, well equipment, oil gathering and processing equipment, oil storage tanks and infield pipelines. Generally, licenses and other permissions for mineral resources extraction require certain actions to be taken by the Group in respect of liquidation of these assets after oil field closure. Such actions include well plugging and abandonment, dismantling equipment, soil recultivation, and other remediation measures. When an oil field is fully depleted, the Group will incur costs related to well retirement and associated environmental protection measures.
Refining, Marketing and Distribution: the Group’s oil refining operations are carried out at large manufacturing facilities that have been operated for several decades. The nature of these operations is such that the ultimate date of decommissioning of any sites or facilities is unclear. Current regulatory and licensing rules do not provide for liabilities related to the liquidation of such manufacturing facilities or of retail fuel outlets. Management therefore believes that there are no legal or contractual obligations related to decommissioning or other disposal of these assets.
Management makes provision for the future costs of decommissioning oil and gas production facilities, wells, pipelines, and related support equipment and for site restoration based on the best estimates of future costs and economic lives of the oil and gas assets. Estimating future asset retirement obligations is complex and requires Management to make estimates and judgments with respect to removal obligations that will occur many years in the future.
Changes in the measurement of existing obligations can result from changes in estimated timing, future costs or discount rates used in valuation.
The amount recognised as a provision is the best estimate of the expenditures required to settle the present obligation at the reporting date based on current legislation in each jurisdiction where the Group’s operating assets are located, and is also subject to change because of revisions and changes in laws and regulations and their interpretation. As a result of the subjectivity of these provisions there is uncertainty regarding both the amount and estimated timing of such costs.
The estimated costs of dismantling and removing an item of property, plant and equipment are added to the cost of the item either when an item is acquired or as the item is used during a particular period for the purposes other than to produce inventories during that period. Changes in the measurement of an existing decommissioning obligation that result from changes in the estimated timing or amount of any cash outflows, or from changes in the discount rate are reflected in the cost of the related asset in the current period.
Currently eight Group companies including JSC Gazprom neft exercise the option to pay taxes as a consolidated tax-payer and are subject to taxation on a consolidated basis. The majority of the Group companies do not exercise such an option and current income taxes are provided on the taxable profit of each subsidiary. Most subsidiaries are subject to the Russian Federation Tax Code, under which income taxes are payable at a rate of 20% after adjustments for certain items, that are either not deductible or not taxable for tax purposes. In some cases income tax rate could be set at lower level as a tax concession stipulated by regional legislation. Subsidiaries operating in countries other than the Russian Federation are subject to income tax at the applicable statutory rate in the country in which these entities operate.
Deferred income tax assets and liabilities are recognised in the accompanying Consolidated Financial Statements in the amounts determined by the Group using the balance sheet liability method in accordance with IAS 12 Income Taxes. This method takes into account future tax consequences attributable to temporary differences between the carrying amounts of existing assets and liabilities for the purpose of the Consolidated Financial Statements and their respective tax bases and in respect of operating loss and tax credit carry-forwards. Deferred income tax assets and liabilities are measured using the enacted tax rates that are expected to apply to taxable income in the years in which those temporary differences are expected to reverse and the assets recovered and liabilities settled. Deferred tax assets for deductible temporary differences and tax loss carry forwards are recorded only to the extent that it is probable that future taxable profit will be available against which the deductions can be utilised.
The Group controls the reversal of temporary differences on dividends from subsidiaries or on gains upon their disposal. The Group does not recognise deferred tax liabilities on such temporary differences except to the extent that Management expects the temporary differences to reverse in the foreseeable future.
Mineral Extraction Tax and Excise Duties
Mineral extraction tax and excise duties, which are charged by the government on the volumes of oil and gas extracted or refined by the Group, are included in operating expenses. Taxes charged on volumes of goods sold are recognised as a deduction from sales.
Common stock represents the authorised capital of the Group, as stated in its charter document. The common shareholders are allowed one vote per share. Dividends paid to shareholders are determined by the Board of Directors and approved at the annual shareholders’ meeting.
Common shares of the Company owned by the Group as of the reporting date are designated as treasury shares and are recorded at cost using the weighted-average method. Gains on resale of treasury shares are credited to additional paid-in capital whereas losses are charged to additional paid-in capital to the extent that previous net gains from resale are included therein or otherwise to retained earnings.
Earnings per Share
Basic and diluted earnings per common share are determined by dividing the available income to common shareholders by the weighted average number of shares outstanding during the period. There are no potentially dilutive securities.
The Group accounts for its best estimate of the obligation under cash-settled stock-appreciation rights (“SARs”) granted to employees at fair value on the date of grant. The estimate of the final liability is re-measured to fair value at each reporting date and the compensation charge recognised in respect of SARs in profit and loss is adjusted accordingly. Expenses are recognised over the vesting period.
Retirement and Other Benefit Obligations
The Group and its subsidiaries do not have any substantial pension arrangements separate from the State pension scheme of the Russian Federation, which requires current contributions by the employer calculated as a percentage of current gross salary payments; such contributions are charged to expense as incurred. The Group has no significant post-retirement benefits or other significant compensated benefits requiring accrual.
Leases under the terms of which the Group assumes substantially all the risks and rewards of ownership are classified as finance leases. Upon initial recognition the leased asset is measured at an amount equal to the lower of its fair value and the present value of the minimum lease payments. Subsequent to initial recognition, the asset is accounted for in accordance with the accounting policy applicable to that asset.
Other leases are operating leases and the leased assets are not recognised on the Group’s statement of financial position. The total lease payments are charged to profit or loss for the year on a straight-line basis over the lease term.
Recognition of Revenues
Revenues from the sales of crude oil, petroleum products, gas and all other products are recognised when deliveries are made to final customers, title passes to the customer, collection is reasonably assured, and the sales price to final customers is fixed or determinable. Specifically, domestic crude oil sales and petroleum product and materials sales are recognised when they are shipped to customers, which is generally when title passes. For export sales, title generally passes at the border of the Russian Federation and the Group is responsible for transportation, duties and taxes on those sales.
Revenue is recognised net of value added tax (VAT), excise taxes calculated on revenues based on the volumes of goods sold, customs duties and other similar compulsory payments.
Sales include revenue, export duties and sales related excise tax.
Purchases and sales under the same contract with a specific counterparty (buy-sell transaction) are eliminated under IFRS. The purpose of the buy-sell operation, i.e. purchase and sale of same type of products in different locations during the same reporting period from / to the same counterparty, is to optimise production capacities of the Group rather than generate profit. After elimination, any positive difference is treated as a decrease in crude oil transportation to the refinery costs and any negative difference is treated as an increase in crude oil transportation costs to the refinery.
Transportation expenses recognised in profit and loss represent expenses incurred to transport crude oil and oil products through the Transneft pipeline network, costs incurred to transport crude oil and oil products by maritime vessel and railway and all other shipping and handling costs.
Other comprehensive Income/Loss
All other comprehensive Income/Loss is presented by the items that are or may be reclassified subsequently to profit or loss, net of related deferred tax.