GAZ.L Regulatory News (GAZ)

Gazprom Neft Group

Consolidated Financial Statements

As of and for the year ended 31 December 2017

Gazprom Neft Group

Consolidated Statement of Financial Position

Currency - RUB millions

The accompanying notes are an integral part of these Consolidated Financial Statements

Gazprom Neft Group

Consolidated Statement of Profit and Loss and Other Comprehensive Income

Currency - RUB millions (except per share data)

The accompanying notes are an integral part of these Consolidated Financial Statements

Gazprom Neft Group

Consolidated Statement of Changes in Shareholders' Equity

Currency - RUB millions

The accompanying notes are an integral part of these Consolidated Financial Statements

Gazprom Neft Group

Consolidated Statement of Cash Flows

Currency - RUB millions

The accompanying notes are an integral part of these Consolidated Financial Statements

Gazprom Neft Group

Supplementary Information on Oil and Gas Activities (Unaudited)

For the year ended 31 December 2017

Currency - RUB millions

1. General

Description of business

PJSC Gazprom Neft (the "Company") and its subsidiaries (together referred to as the "Group") is a vertically integrated oil company operating in the Russian Federation, CIS and internationally. The Group's principal activities include exploration, production and development of crude oil and gas, production of refined petroleum products and distribution and marketing operations through its retail outlets.

The Company was incorporated in 1995 and is domiciled in the Russian Federation. The Company is a public joint stock company and was set up in accordance with Russian regulations. PJSC Gazprom ("Gazprom", a state controlled entity), the Group's ultimate parent company, owns 95.7% of the shares in the Company.

2. Summary of significant accounting policies

Basis of preparation

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 31 December 2017 were evaluated through 26 February 2018, 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 (SAR) 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 Rouble. 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 has 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.

Business combinations

The Group accounts for its business combinations according to IFRS 3 Business Combinations. The Group applies the acquisition method of accounting and recognises identifiable assets acquired and liabilities and contingent 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

Goodwill is measured by deducting the fair value 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 the 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.

Non-controlling interest

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.

Disposals 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 subsequent 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. When these transactions represent transactions with owners in their capacity as owners, the effect on such transactions is included in Additional paid-in capital in Equity.

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 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 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.

Non-derivative financial liabilities

The Group initially recognises debt securities issued and liabilities on the date that they are originated. All other financial liabilities 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 expired. The Group classifies non-derivative financial liabilities into the other financial liabilities category. 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, trade and other payables and finance lease liabilities.

Derivative financial instruments

Derivative instruments are recorded at fair value in 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 significant 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.

Hedge accounting

The Group applies hedge accounting policy for those derivatives that are designated as a hedging instrument (currency exchange forwards and interest-rate swaps).

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 instrument is determined at the end of each reporting period with reference to the market value, which is typically determined by the credit institutions.

Inventories

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 assigned 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.

Intangible assets

Goodwill that arises on the acquisition of subsidiaries is included in intangible assets. Subsequently goodwill is measured at cost less accumulated impairment losses.

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:

Property, plant and equipment

Property, plant and equipment is stated at cost, net of accumulated depreciation and any impairment. The cost of maintenance, repairs and replacement of minor items of property, plant and equipment 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 does 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.

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;

- Costs of drilling and equipping exploratory wells.

The costs incurred in finding, acquiring, and developing reserves are capitalised on a 'field by field' basis.

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. On discovery of a commercially-viable mineral reserve, the capitalised costs are allocated to the discovery.

If no reserves are found, the exploration asset is tested for impairment. If extractable hydrocarbons are found then it should be subject to further appraisal activity, which may include drilling of further wells. If they are likely to be developed commercially (including dry holes), 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 reclassified to property, plant and equipment and intangible assets 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. Exploration and development licenses are classified as property, plant and equipment after transfer from exploration and evaluation assets.

Development costs

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. 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:

Catalysts and reagents mainly used in the refining operations are treated as other assets. 

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 non-current assets

The carrying amounts of the Group's non-current assets, other than assets arising from 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.

Goodwill is tested for impairment annually or more frequently if impairment indicators arise. An impairment loss recognised for goodwill is not reversed in a subsequent period. 

If any indication of impairment exists, the group makes an estimate of the asset's recoverable amount. Individual assets are grouped for impairment assessment purposes at the lowest level at which there are identifiable cash flows that are largely independent of the cash flows of other groups of assets (cash-generated units - CGUs). The carrying amount of the CGUs (including goodwill) is compared with their recoverable amount. The recoverable amount of CGUs to which goodwill is allocated is the higher of value in use and fair value less costs of disposal. Where the recoverable amount of the CGUs to which goodwill has been allocated is less than the carrying amount, an impairment loss is recognised.

An impairment loss is recognised in profit and loss. Prior impairments of non-financial assets (other than goodwill) are reviewed for possible reversal at each reporting date.

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 and loss and reflected in an allowance account against loans and receivables or held-to-maturity investments.

Decommissioning obligations

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. The Group applies risk-free rate adjusted for specific risks of the liability for the purpose of estimating asset retirement obligations.

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. 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.

Income taxes

Currently some Group companies including PJSC 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 sufficient future taxable profit will be available against which the deductions can be utilised.

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.

Share capital

Share capital represents the authorised capital of the Company, 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.

Treasury stock

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.

Dividends

Dividends are recorded as a liability and deducted from equity in the period in which they are declared and approved. Any dividends declared after the reporting period and before the Consolidated Financial Statements are authorised for issue are disclosed in the subsequent events note.

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.

Stock-based compensation

The Group accounts for its best estimate of the obligation under cash-settled stock-appreciation rights ("SAR") 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 SAR 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 employee-benefit programs requiring accrual.

Leases

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 in the Group's consolidated statement of financial position. The total lease payments are charged to profit and 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.

Buy / sell transactions

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 transportation costs and any negative difference is treated as an increase in transportation costs.

Transportation costs

Transportation expenses recognised in profit and loss represent expenses incurred to transport crude oil and oil products through the PJSC "AK "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 income tax.

3. Critical accounting estimates, assumptions and judgments

Preparing these Consolidated Financial Statements in accordance with IFRS requires Management to make judgements on the basis of estimates and assumptions. These judgements affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the reporting date, and the reported amounts of revenues and expenses during the reporting period.

Management reviews the estimates and assumptions on a continuous basis, by reference to past experiences and other factors that can reasonably be used to assess the book values of assets and liabilities. Adjustments to accounting estimates are recognised in the period in which the estimate is revised if the change affects only that period or in the period of the revision and subsequent periods, if both periods are affected.

Actual results may differ from the judgements, estimates made by the Management if different assumptions or circumstances apply.

Judgments and estimates that have the most significant effect on the amounts reported in these Consolidated Financial Statements and have a risk of causing a material adjustment to the carrying amount of assets and liabilities are described below.

Impairment of non-current assets

The following are examples of impairment indicators, which are reviewed by the Management: changes in the Group's business plans, changes in oil and commodity prices leading to sustained unprofitable performance, low plant utilisation, evidence of physical damage or, for oil and gas assets, significant downward revisions of estimated reserves or increases in estimated future development expenditure or decommissioning costs. In case any of such indicators exist the Group makes an assessment of recoverable amount.

The long-term business plans (models), which are approved by the Management, are the primary source of information for the determination of value in use. They contain forecasts for oil and gas production, refinery throughputs, sales volumes for various types of refined products, revenues, costs and capital expenditure.

As an initial step in the preparation of these plans, various market assumptions, such as oil prices, refining margins, refined product margins and inflation rates, are set by the Management. These market assumptions take into account long-term oil price forecasts by the research institutions, macroeconomic factors such as inflation rate and historical trends.

In assessing value in use, the estimated future cash flows are adjusted for the risks specific to the asset group or CGU and are discounted to their present value using a pre-tax discount rate that reflects current market assessments of the time value of money.

Estimation of oil and gas reserves

Engineering estimates of oil and gas reserves are inherently uncertain and are subject to future revisions on annual basis. The Group estimates its oil and gas reserves in accordance with rules promulgated by the US Securities and Exchange Commission (SEC) for proved reserves. Oil and gas reserves are determined with use of certain assumptions made by the Group, for future capital and operational expenditure, estimates of oil in place, recovery factors, number of wells and cost of drilling. Accounting measures such as depreciation, depletion and amortisation charges that are based on the estimates of proved reserves are subject to change based on future changes to estimates of oil and gas reserves.

Proved reserves are defined as the estimated quantities of oil and gas which geological and engineering data demonstrate recoverability in future years from known reservoirs under existing economic conditions with reasonable certainty. In some cases, substantial new investment in additional wells and related support facilities and equipment will be required to recover such proved reserves. Due to the inherent uncertainties and the limited nature of reservoir data, estimates of underground reserves are subject to change over time as additional information becomes available.

Oil and gas reserves have a direct impact on certain amounts reported in the consolidated financial statements, most notably depreciation, depletion and amortisation as well as impairment expenses. Depreciation rates on oil and gas assets using the units-of-production method for each field are based on proved developed reserves for development costs, and total proved reserves for costs associated with the acquisition of proved properties. Moreover, estimated proved reserves are used to calculate future cash flows from oil and gas properties, which serve as an indicator in determining whether or not property impairment is present.

Useful lives of property, plant and equipment

Management assesses the useful life of an asset by considering the expected usage, estimated technical obsolescence, residual value, physical wear and tear and the operating environment in which the asset is located. Differences between such estimates and actual results may have a material impact on the amount of the carrying values of the property, plant and equipment and may result in adjustments to future depreciation rates and expenses for the period.

Contingencies

Certain conditions may exist as of the date of these Consolidated Financial Statements are issued that may result in a loss to the Group, but one that will only be realised when one or more future events occur or fail to occur. Management makes an assessment of such contingent liabilities that is based on assumptions and is a matter of judgement. In assessing loss contingencies relating to legal or tax proceedings that involve the Group or unasserted claims that may result in such proceedings, the Group, after consultation with legal and tax advisors, evaluates the perceived merits of any legal or tax proceedings or unasserted claims as well as the perceived merits of the amount of relief sought or expected to be sought therein.

If the assessment of a contingency indicates that it is probable that a loss will be incurred and the amount of the liability can be estimated, then the estimated liability is accrued in the Group's Consolidated Financial Statements. If the assessment indicates that a potentially material loss contingency is not probable, but is reasonably possible, or is probable but cannot be estimated, then the nature of the contingent liability, together with an estimate of the range of possible loss if determinable and material, is disclosed. If loss contingencies can not be reasonably estimated, Management recognises the loss when information becomes available that allows a reasonable estimation to be made. Loss contingencies considered remote are generally not disclosed unless they involve guarantees, in which case the nature of the guarantee is disclosed. However, in some instances in which disclosure is not otherwise required, the Group may disclose contingent liabilities of an unusual nature which, in the judgment of Management and its legal counsel, may be of interest to shareholders or others.

Joint arrangements

Upon adopting of IFRS 11 the Group applied judgement when assessing whether its joint arrangements represent a joint operation or a joint venture. The Group determined the type of joint arrangement in which it is involved by considering its rights and obligations arising from the arrangement including the assessment of the structure and legal form of the arrangement, the terms agreed by the parties in the contractual arrangement and, when relevant, other facts and circumstances.

Leases

Leases under the terms of which the Group assumes substantially all the risks and rewards of ownership are classified as finance leases. Risks include the possibilities of losses from idle capacities or technological obsolence and of variations in return because of changing economic conditions. Rewards may be represented by the expectation of profitable operation over the assets's economic life and of gain from appreciation in value or realization of a residual value.

Other leases are classified as operating leases. In most cases leasing of vessels under time-charter agreements are accounted for as operating leases under IAS 17 Leases.

4. Application of new IFRS

The following standards or amended standards became effective for the Group from 1 January 2017, but did not have any material impact on the Group:

· Disclosure Initiative - Amendments to IAS 7 (issued on 29 January 2016 and effective for annual periods beginning on or after 1 January 2017). The new disclosures are included in Note 35.

· Recognition of Deferred Tax Assets for Unrealised Losses - Amendment to IAS 12 (issued on 19 January 2016 and effective for annual periods beginning on or after 1 January 2017).

· Amendments to IFRS 12 included in Annual Improvements to IFRSs 2014-2016 Cycle (issued on 8 December 2016 and effective for annual periods beginning on or after 1 January 2017).

5. New accounting standards

Certain new standards and interpretations have been issued that are mandatory for the annual periods beginning on or after 1 January 2018 or later, and that the Group has not early adopted.

IFRS 9 - Financial Instruments (amended in July 2014 and effective for annual periods beginning on or after 1 January 2018). Key features of the new standard are:

· Financial assets are required to be classified into three measurement categories: those to be measured subsequently at amortised cost, those to be measured subsequently at fair value through other comprehensive income (FVOCI) and those to be measured subsequently at fair value through profit or loss (FVPL). The decision is to be made at initial recognition.

· An instrument is subsequently measured at amortised cost only if it is a debt instrument and both (i) the objective of the entity's business model is to hold the asset to collect the contractual cash flows, and (ii) the asset's contractual cash flows represent solely payments of principal and interest only. All other debt instruments are to be measured at fair value through profit or loss.

· All equity instruments are to be measured subsequently at fair value. Equity instruments that are held for trading will be measured at fair value through profit or loss. For all other equity investments, an irrevocable election can be made at initial recognition, to recognise unrealised and realised fair value gains and losses through other comprehensive income rather than profit or loss. There is no recycling of fair value gains and losses to profit or loss.

Based on an analysis of the Group's financial assets and financial liabilities as at 31 December 2017 and on the basis of the facts and circumstances those exist at that date, the main changes expected from adoption of IFRS 9 since 1 January 2018 are the following:

· Current classification of the Group's financial assets will be changed into three measurement categories: those to be measured subsequently at fair value (either through profit and loss or other comprehensive income), and at amortised cost. For the debt instruments the decision is to be made depending on (i) the objective of the entity's business model and (ii) either the asset's contractual cash flows represent solely payments of principal and interest.

· Current model for recognition of impairment losses will be changed into the expected credit losses (ECL) model. However, the Group does not expect any significant changes in impairment amount as current model is based on expert opinion which covers all possible data.

· The new standard also introduces expanded disclosure requirements and changes in presentation. These are expected to change the nature and extent of the Group's disclosures about its financial instruments particularly in the year of the adoption of the new standard.

· Changes in the fair value of financial liabilities designated at FVTPL that are attributable to changes in the instrument's credit risk, which will be presented in other comprehensive income rather than profit or loss.

The Group continues to apply IAS 39 for hedge accounting. The management of the Group is not expecting a significant impact on its Consolidated Financial Statements from the adoption of the new standard on 1 January 2018.

IFRS 15 - Revenue from Contracts with Customers (issued on 28 May 2014 and effective for annual periods beginning on or after 1 January 2018). The new standard introduces the core principle that revenue must be recognised when the goods or services are transferred to the customer, at the transaction price. Any bundled goods or services that are distinct must be separately recognized, and any discounts or rebates on the contract price must generally be allocated to the separate elements. When the consideration varies for any reason, minimum amounts must be recognized if they are not at significant risk of reversal. Costs incurred to secure contracts with customers have to be capitalized and amortized over the period when the benefits of the contract are consumed.

Amendments to IFRS 15, Revenue from Contracts with Customers (issued on 12 April 2016 and effective for annual periods beginning on or after 1 January 2018). The amendments do not change the underlying principles of the Standard but clarify how those principles should be applied. The amendments clarify how to identify a performance obligation (the promise to transfer a good or a service to a customer) in a contract; how to determine whether a company is a principal (the provider of a good or service) or an agent (responsible for arranging for the good or service to be provided); and how to determine whether the revenue from granting a licence should be recognised at a point in time or over time. In addition to the clarifications, the amendments include two additional reliefs to reduce cost and complexity for a company when it first applies the new Standard.

The Group plans to apply the practical expedient available for simplified transition method: IFRS 15 is retrospectively applied only to the contracts that are not completed at the date of initial application (1 January 2018).

Based on the analysis of the Group's revenue streams for the year ended 31 December 2017 and individual contracts' terms and on the basis of the facts and circumstances that exist at that date, an impact on the Consolidated Financial Statements from the adoption of the new standard on 1 January 2018 is not significant.

IFRIC 22 "Foreign currency transactions and advance consideration" (issued on 8 December 2016 and effective for annual periods beginning on or after 1 January 2018). This interpretation considers how to determine the date of the transaction when applying the standard on foreign currency transactions, IAS 21. The interpretation applies where an entity either pays or received consideration in advance for foreign currency-denominated contracts. The interpretation specifies that the date of transaction is the date on which the entity initially recognizes the non-monetary asset or non-monetary liability arising from the payment or receipt of advance consideration. If there are multiple payments or receipts in advance, the Interpretation requires an entity to determine the date of transaction for each payment or receipt of advance consideration. This interpretation will not have any material impact on the Group.

IFRS 16, Leases (issued on 13 January 2016 and effective for annual periods beginning on or after 1 January 2019). The new standard sets out the principles for the recognition, measurement, presentation and disclosure of leases. All leases result in the lessee obtaining the right to use an asset at the start of the lease and, if lease payments are made over time, also obtaining financing. Accordingly, IFRS 16 eliminates the classification of leases as either operating leases or finance leases as is required by IAS 17 and, instead, introduces a single lessee accounting model. Lessees will be required to recognise: (a) assets and liabilities for all leases with a term of more than 12 months, unless the underlying asset is of low value; and (b) depreciation of lease assets separately from interest on lease liabilities in the statement of profit and loss and other comprehensive income. IFRS 16 substantially carries forward the lessor accounting requirements in IAS 17. Accordingly, a lessor continues to classify its leases as operating leases or finance leases, and to account for those two types of leases differently. The Group is currently assessing the impact of the new standard on its Consolidated Financial Statements.

IFRS 17 "Insurance Contracts" (issued on 18 May 2017 and effective for annual periods beginning on or after 1 January 2021). IFRS 17 replaces IFRS 4, which has given companies dispensation to carry on accounting for insurance contracts using existing practices. IFRS 17 is a single principle-based standard to account for all types of insurance contracts, including reinsurance contracts that an insurer holds. New standard will not have any material impact on the Group. 

IFRIC 23 "Uncertainty over Income Tax Treatments" (issued on 7 June 2017 and effective for annual periods beginning on or after 1 January 2019). IAS 12 specifies how to account for current and deferred tax, but not how to reflect the effects of uncertainty. The interpretation clarifies how to apply the recognition and measurement requirements in IAS 12 when there is uncertainty over income tax treatments. An entity should determine whether to consider each uncertain tax treatment separately or together with one or more other uncertain tax treatments based on which approach better predicts the resolution of the uncertainty. An entity should assume that a taxation authority will examine amounts it has a right to examine and have full knowledge of all related information when making those examinations. If an entity concludes it is not probable that the taxation authority will accept an uncertain tax treatment, the effect of uncertainty will be reflected in determining the related taxable profit or loss, tax bases, unused tax losses, unused tax credits or tax rates, by using either the most likely amount or the expected value, depending on which method the entity expects to better predict the resolution of the uncertainty. An entity will reflect the effect of a change in facts and circumstances or of new information that affects the judgments or estimates required by the interpretation as a change in accounting estimate. The Group is currently assessing the impact of the interpretation on its Consolidated Financial Statements.

The following other new pronouncements are not expected to have any material impact on the Group when adopted:

· Sale or Contribution of Assets between an Investor and its Associate or Joint Venture - Amendments to IFRS 10 and IAS 28 (issued on 11 September 2014 and effective for annual periods beginning on or after a date to be determined by the IASB).

· Amendments to IFRS 2, Share-based Payment (issued on 20 June 2016 and effective for annual periods beginning on or after 1 January 2018).

· Applying IFRS 9 Financial Instruments with IFRS 4 Insurance Contracts - Amendments to IFRS 4 (issued on 12 September 2016 and effective, depending on the approach, for annual periods beginning on or after 1 January 2018 for entities that choose to apply temporary exemption option, or when the entity first applies IFRS 9 for entities that choose to apply the overlay approach).

· Transfers of Investment Property - Amendments to IAS 40 (issued on 8 December 2016 and effective for annual periods beginning on or after 1 January 2018).

· Annual Improvements to IFRSs 2014-2016 cycle ‒ Amendments to IFRS 1 an IAS 28 (issued on 8 December 2016 and effective for annual periods beginning on or after 1 January 2018).

· Prepayment Features with Negative Compensation - Amendments to IFRS 9 (issued on 12 October 2017 and effective for annual periods beginning on or after 1 January 2019).

· Long-term Interests in Associates and Joint Ventures - Amendments to IAS 28 (issued on 12 October 2017 and effective for annual periods beginning on or after 1 January 2019).

· Annual Improvements to IFRSs 2015-2017 cycle - Amendments to IFRS 3, IFRS 11, IAS 12 and IAS 23 (issued on 12 December 2017 and effective for annual periods beginning on or after 1 January 2019).

6. Cash and cash equivalents

Cash and cash equivalents as of 31 December 2017 and 2016 comprise the following:

7. Short-term financial assets

Short-term financial assets as of 31 December 2017 and 2016 comprise the following:

The loans issued as of 31 December 2017 and 2016 mainly comprise loans issued to a joint venture.

8. Trade and other receivables

Trade and other receivables as of 31 December 2017 and 2016 comprise the following:

Trade receivables represent amounts due from customers in the ordinary course of business and are short-term by nature. 

9. Inventories

Inventories as of 31 December 2017 and 2016 consist of the following:

10. Other taxes receivable

Other taxes receivable as of 31 December 2017 and 2016 comprise the following:

11. Other current assets

Other current assets as of 31 December 2017 and 2016 comprise the following:

The movement in impairment provision in respect of other current assets is presented in Note 35.

12. Property, plant and equipment

Movement in property, plant and equipment for the years ended 31 December 2017 and 2016 is presented below:

Capitalised borrowing costs for the year ended 31 December 2017 include interest expense in the amount of RUB 25.0 billion and exchange losses arising from foreign currency borrowings in the amount of RUB 4.6 billion.

Capitalisation rate for the borrowing costs related to the acquisition of property, plant and equipment equals to 7% for the year ended 31 December 2017 (6% for the year ended 31 December 2016).

The information regarding Group's exploration and evaluation assets (part of O&G properties) is presented below: 

During 2017 the Group performed impairment testing and recognised net reversal of impairment in relation to upstream oil and gas assets located in Iraq region in the amount of RUB 0.3 billion (an impairment in relation to upstream oil and gas assets and exploration and evaluation assets in the amount of RUB 14.4 billion was recognised for the year ended 31 December 2016). Net reversal of impairment consists of an impairment loss in the amount of RUB 2.0 billion and reversal of impairment in the amount of RUB 2.3 billion. The impairment reversal is included in Depreciation, depletion and amortisation line item in the Consolidated Statement of Profit and Loss and Other Comprehensive Income. The accumulated impairment as at 31 December 2017 in the amount of RUB 13.9 billion is presented within net book value of property, plant and equipment (RUB 14.8 billion as at 31 December 2016).

The Group recognized the net reversal of impairment for the amount by which recoverable amount of these assets of RUB 81.7 billion (translated into Roubles at the exchange rate as of date of impairment testing) exceeded its book value. Revision of the expected economic and technical performance of the assets in result of changes in exploration information, development programs, investment plans and international oil prices affected estimated value in use of Iraq assets.

The recoverable amount was determined as the present value of estimated future cash flows using available forecasts of oil prices from globally recognised research institutions and production quantities based on reserve reports and long-term strategic plans. The pre-tax discount rate reflects current market assessments of the time value of money and the risks specific to the asset and amounts to 11% per annum in real terms (similar to prior year).

13. Goodwill and other intangible assets

The information regarding movements in Group's intangible assets is presented below:

Goodwill acquired through business combination has been allocated to Upstream and Downstream in the amounts of RUB 27.0 billion and RUB 6.9 billion as of 31 December 2017 (RUB 25.1 billion and RUB 6.8 billion as of 31 December 2016). Goodwill was tested for impairment and no impairment was identified.

14. Investments in associates and joint ventures

The carrying values of the investments in associates and joint ventures as of 31 December 2017 and 2016 are summarised below:

The principal place of business of the most significant joint ventures and associates disclosed above is the Russian Federation.

The total amount of dividends received from joint ventures in 2017 amounts to RUB 5,531 million (RUB 3,144 million in 2016).

Slavneft

OAO NGK Slavneft and it's subsidiaries (Slavneft) are engaged in exploration, production and development of crude oil and gas and production of refined petroleum products. The control over Slavneft is divided equally between the Group and PJSC NK Rosneft.

SeverEnergy

The Group's investment in SeverEnergy LLC (SeverEnergy) is held through Yamal Razvitie LLC (Yamal Razvitie, an entity jointly controlled by the Group and PJSC NOVATEK). SeverEnergy, through its subsidiary JSC Arctic Gas Company (Arcticgas), is developing the Samburgskoye, Urengoiskoe and Yaro-Yakhinskoye oil and gas condensate fields and some other small oil and gas condensate fields located in the Yamalo-Nenetskiy autonomous region of the Russian Federation.

The carrying amount of the Group's investment exceeds the Group's share in the underlying net assets of SeverEnergy by RUB 17.0 billion as of 31 December 2017 due to complex holding structure, current financing scheme and goodwill arising on acquisition (RUB 18.2 billion as of 31 December 2016).

Northgas

The Group's investment in CJSC Northgas (Northgas) is held through Gazprom Resource Northgas LLC which is controlled by the Group based on signed Management agreement and charter documents. Gazprom Resource Northgas LLC owns a 50% share in Northgas. Northgas is engaged in development of natural gas and oil field.

Messoyakha

JSC Messoyakhaneftegas (Messoyakha) is developing the Vostochno-Messoyakhskoe and Zapadno-Messoyakhskoe oil and gas condensate fields. The control over Messoyakha is divided equally between the Group and PJSC NK Rosneft. During the year ended 31 December 2017 the Group performed additional contribution to share capital in the amount of RUB 7.6 billion.

The summarised financial information for the significant associates and joint ventures as of 31 December 2017 and 2016 and for the years ended 31 December 2017 and 2016 is presented in the table below.

Others

The aggregate carrying amount of all individually immaterial joint ventures and associates as well as the Group's share of those joint ventures' and associates' profit or loss and other comprehensive income is not significant.

15. Joint operations

Under IFRS 11 Joint Arrangements the Group assessed the nature of its 50% share in joint arrangements and determined investments in Tomskneft and Salym Petroleum Development as Joint operations. Tomskneft and Salym Petroleum Development are engaged in production of oil and gas in the Russian Federation and all of the production is required to be sold to the parties of the joint arrangement (that is, the Group and its partners).

16. Long-term financial assets

Long-term financial assets as of 31 December 2017 and 2016 comprise the following:

17. Deferred income tax assets and liabilities

Recognised deferred tax assets and liabilities are attributable to the following:

Movement in temporary differences during the period:

18. Other non-current assets

Other non-current assets are primarily comprised of advances provided on capital expenditures (RUB 69.3 billion and RUB 97.2 billion as of 31 December 2017 and 2016, respectively).

19. Short-term debt and current portion of long-term debt

As of 31 December 2017 and 2016 the Group has short-term loans and current portion of long-term debt outstanding as follows:

Short-term bank loans and other borrowings include interest payable on short-term debt. Current portion of long-term debt includes interest payable on long-term borrowings.

20. Trade and other payables

Accounts payable as of 31 December 2017 and 2016 comprise the following: