2 – Accounting policies, judgements and estimates

The accounting policies adopted are consistent with those of the previous financial year, except for the changes as described below.

First-time adoption of amended standards

The Group has adopted the following amended standards with a date of initial application of January 1, 2020:

• Amendments to IFRS 3 Business Combinations: Definition of a Business
• Amendments to IFRS 9, IAS 39 and IFRS 7: Interest Rate Benchmark Reform
• Amendments to IAS 1 and IAS 8: Definition of Material
• Amendments to References to the Conceptual Framework in IFRS Standards

The amendments did not have any material impact on OMV’s group financial statements.

Amendments to IFRS 9, IAS 39 and IFRS 7: Interest Rate Benchmark Reform

The Group has adopted the amendments to IFRS 9 and IFRS 7 retrospectively to hedging relationships that existed at the start of the reporting period or were designated thereafter, and that are directly affected by the interest rate benchmark reform. These amendments also apply to the gain or loss accumulated in the cash flow hedge reserve that existed at 1 January, 2020.

The amendments provide temporary relief from applying specific hedge accounting requirements to hedging relationships directly affected by interbank offered rate (IBOR) reform. For the purpose of evaluating whether there is an economic relationship between the hedged items and the hedging instruments, the Group assumes that the benchmark interest rate is not altered as a result of interest rate benchmark reform. Any hedge ineffectiveness continues to be recorded in the income statement. The Group will cease to apply this relief when the uncertainty arising from interest rate benchmark reform is no longer present.

Note 28 – Risk Management – provides information about the uncertainty arising from IBOR reform for hedging relationships for which the Group has applied the reliefs. No changes were required to any of the amounts recognized in the current or prior period as a result of these amendments.

Change in income statement presentation

Starting with 2020, reversals of impairments on tangible and intangible assets are reported within the line “Depreciation, amortization, impairments and write-ups” in order to improve the international comparability of the income statement presentation. The prior year figures have been adjusted accordingly. The change in presentation has no effect on the operating result.

OMV has not applied the following new or revised IFRSs that have been issued but are not yet effective. They are not expected to have any material effects on the Group’s financial statements. EU endorsement is still pending in some cases.

a) Business combinations and goodwill

Business combinations are accounted for using the acquisition method. Assets and liabilities of subsidiaries acquired are included at their fair value at the time of acquisition. For each business combination, the Group elects whether it measures the non-controlling interest in the acquiree either at fair value or at the proportionate share of the acquiree’s identifiable net assets.

Any contingent consideration is measured at fair value at the date of acquisition. Contingent consideration classified as financial asset or liability is subsequently measured at fair value with the changes in fair value recognized in profit or loss.

Goodwill is calculated as the excess of the aggregate of the consideration transferred, the amount recognized for non-controlling interest and the fair value of the equity previously held by OMV in the acquired entity over the net identifiable assets acquired and liabilities assumed. Goodwill is recorded as an asset and tested for impairment at least yearly. Impairments are recorded immediately through profit or loss, subsequent write-ups are not possible. Any gain on a bargain purchase is recognized in profit or loss immediately.

b) Sales revenue

Revenue is generally recognized when control over a product or a service is transferred to a customer. It is measured based on the consideration specified in a contract with a customer and excludes amounts collected on behalf of third parties.

When goods such as crude oil, LNG, oil and petrochemical products and similar goods are sold, the delivery of each quantity unit normally represents a single performance obligation. Revenue is recognized when control of the goods has transferred to the customer, which is the point in time when legal ownership as well as the risk of loss has passed to the customer and is determined on the basis of the Incoterm agreed in the contract with the customer. These sales are done with normal credit terms according to the industry standard.

Revenue from the production of crude oil, in which OMV has an interest with other producers, is recognized according to the sales method. This means that revenue is recognized based on the actual sales to third parties, regardless of the Group’s percentage interest or entitlement. An adjustment of production costs is recognized at average cost for the difference between the costs associated with the output sold and the costs incurred based on entitlement to output, with a counter entry in the other assets or liabilities.

In the Downstream retail business, revenues from the sale of fuels are recognized when products are supplied to the customers. Depending on whether OMV is principal or agent in the sale of shop merchandise, revenue and costs related to such sales are presented gross or net in the income statement. OMV is principal if it controls the goods before they are transferred to the customer, which is mainly indicated by OMV having the inventory risk. At filling stations, payments are due immediately at the time of purchase.

OMV’s gas and power supply contracts include a single performance obligation which is satisfied over the agreed delivery period. Revenue is recognized according to the consumption by the customer and in line with the amount to which OMV has a right to invoice. Only in exceptional cases long-term gas supply contracts contain stepped prices in different periods where the rates do not reflect the value of the goods at the time of delivery. In these cases revenue is recognized based on the average contractual price.

In some customer contracts for the delivery of natural gas, the fees charged to the customer comprise a fixed charge as well as a variable fee depending on the volumes delivered. These contracts contain only one performance obligation which is to stand-ready for the delivery of gas over a certain period. The revenue from the fixed charges and the variable fees is recognized in line with the amount chargeable to the customer. Gas and power deliveries are billed and paid on a monthly basis.

Gas storage and gas transportation contracts contain a stand-ready obligation for providing storage or transportation services over an agreed period of time. Revenue is recognized according to the amount to which OMV has a right to invoice. These services are billed and paid on a monthly basis.

There are some customer contracts in OMV for the delivery of oil and gas as well as for the provision of gas storage and transportation services which have a term of more than one year. In principle, IFRS 15 requires the disclosure of the total amount of transaction prices allocated to unperformed performance obligations for such contracts. Contracts for the delivery of oil contain variable prices based on market prices as at delivery date, as it is common in the oil industry. For these contracts it is, therefore, not possible to allocate the transaction price to unsatisfied performance obligations. For gas delivery and gas storage and transportation contracts OMV applies the practical expedient according to IFRS 15.121 (b) according to which this information need not be disclosed for contracts where revenue is recognized in the amount to which the entity has a right to invoice. OMV, therefore, does not disclose this information.

c) Other revenues

Other revenues include revenues from commodity contracts which are in the scope of IFRS 9. Sales and purchases of commodities are reported net within other revenues when the forward sales and purchase contracts are determined to be for trading purposes and not for the final physical delivery.

In addition, other revenues include an adjustment of revenues from considering the national oil company’s profit share as income tax in certain production sharing agreements in the Upstream segment (see 2.3f), realized and unrealized results from hedging of sales transactions as well as lease and rental income.

d) Exploration expenses

Exploration expenses relate exclusively to the business segment Upstream and comprise the costs associated with unproved reserves. These include geological and geophysical costs for the identification and investigation of areas with possible oil and gas reserves and administrative, legal and consulting costs in connection with exploration. They also include all impairments on exploration wells where no proved reserves could be demonstrated. Depreciation of economically successful exploration wells is reported as depreciation, amortization, impairment charges and write-ups.

e) Research and development

Expenditure related to research activities is recognized as expense in the period in which it is incurred. Research and development (R&D) expenses, which are presented in the income statement within other operating expenses, include all direct and indirect materials, personnel and external services costs incurred in connection with the focused search for new insights related to the development and significant improvement of products, services and processes and in connection with research activities. Development costs are capitalized if the recognition criteria according to IAS 38 are fulfilled.

f) Exploration and production sharing agreements

Exploration and production sharing agreements (EPSAs) are contracts for oil and gas licenses in which the oil or gas production is shared between one or more oil companies and the host country/national oil company in defined proportions. Exploration expenditures are carried by the oil companies as a rule and recovered from the state or the national oil company through so called “cost oil” in a successful case only. Under certain EPSA contracts the host country’s/national oil company’s profit share represents imposed income taxes and is treated as such for purposes of the income statement presentation.

g) Intangible assets and property, plant and equipment

Intangible assets and property, plant and equipment are recognized at costs of acquisition or construction (including costs of major inspection and general overhauls). The present value of the expected cost for the decommissioning of an asset after its use is included in the cost of the respective asset when a decommissioning provision is recognized (see 2.3s). Costs for replacements of components are capitalized and carrying values of the replaced parts are derecognized. Costs relating to minor maintenance and repairs are treated as expenses in the year in which they are incurred.

Intangible assets and depreciable property, plant and equipment (except for oil and gas assets and a contract-related intangible asset in Upstream, see 2.3h) are amortized or depreciated on a straight-line basis over the useful economic life.

h) Oil and gas assets

Upstream activities are recorded using the successful efforts method. The acquisition costs of geological and geophysical studies before the discovery of proved reserves form part of expenses for the period. The costs of wells are capitalized and reported as intangible assets until the existence or absence of potentially commercially viable oil or gas reserves is determined. Wells which are not commercially viable are expensed. The costs of exploration wells whose commercial viability has not yet been determined continue to be capitalized as long as the following conditions are satisfied:

• Sufficient oil and gas reserves have been discovered that would justify completion as a production well.
• Sufficient progress is being made in assessing the economic and technical feasibility to justify beginning field development in the near future.

Exploratory wells in progress at year end which are determined to be unsuccessful subsequent to the statement of financial position date are treated as non-adjusting events, meaning that the costs incurred for such exploratory wells remain capitalized in the financial statements of the reporting period under review and will be expensed in the subsequent period.

License acquisition costs and capitalized exploration and appraisal activities are not amortized as long as they are related to unproved reserves, but tested for impairment when there is an indicator for a potential impairment. Once the reserves are proved and commercial viability is established, the related assets are reclassified into tangible assets. Development expenditure on the construction, installation or completion of infrastructure facilities such as platforms and pipelines and drilling development wells is capitalized within tangible assets. Once production starts, depreciation commences. Capitalized exploration and development costs and support equipment are generally depreciated based on proved developed reserves by applying the unit-of-production method; only capitalized exploration rights and acquired reserves are amortized on the basis of total proved reserves, unless a different reserves basis is more adequate.

i) Associated companies and joint arrangements

Associated companies are those entities in which the Group has significant influence, but not control nor joint control over the financial and operating policies. Joint arrangements, which are arrangements of which the Group has joint control together with one or more parties, are classified into joint ventures or joint operations. Joint ventures are joint arrangements in which the parties that share control have rights to the net assets of the arrangement. Joint operations are joint arrangements in which the parties that share joint control have rights to the assets, and obligations for the liabilities, relating to the arrangement.

Investments in associated companies and joint ventures are accounted for using the equity method, under which the investment is initially recognized at cost and subsequently adjusted for the Group’s share of the profit or loss less dividends received and the Group’s share of other comprehensive income and other movements in equity.

Significant joint exploration and production activities in the Upstream segment are conducted through joint operations which are not structured through a separate vehicle. For these joint operations, OMV recognizes in the consolidated financial statements its share of the assets held and liabilities and expenses incurred jointly with the other partners, as well as the group’s income from the sale of its share of the output and any liabilities and expenses that the group has incurred in relation to the joint operation. Acquisitions of interests in a joint operation, in which the activity of the joint operation constitutes a business, are accounted for according to the relevant IFRS 3 principles for business combination accounting (see 2.3a).

In addition, there are contractual arrangements similar to joint operations in the Group which are not jointly controlled and therefore do not meet the definition of a joint operation according to IFRS 11. This is the case when the main decisions can be taken by more than one combination of affirmative votes of the involved parties or where one other party has control. OMV assesses whether such arrangements are within or out of scope of IFRS 11 on the basis of the relevant legal arrangements such as concession, license or joint operating agreements which define how and by whom the relevant decisions for these activities are taken. The accounting treatment for these arrangements is basically the same as for joint operations. As acquisitions of interests in such arrangements are not within the scope of IFRS 3, OMV’s accounting policy is to treat such transactions as asset acquisitions.

j) Impairment of assets

Intangible assets, property, plant and equipment (including oil and gas assets) and investments in associated companies and joint ventures are tested for impairment whenever events or changes in circumstances indicate that an asset may be impaired. Impairment tests are performed on the level of the asset or the smallest group of assets that generates cash inflows that are largely independent of those from other assets or groups of assets, called cash-generating units (CGUs).

If assets are determined to be impaired, the carrying amounts are written down to their recoverable amount, which is the higher of fair value less costs of disposal or value in use.

In assessing value in use, the estimated future cash flows are discounted to their present value using a post-tax discount rate that reflects current market assessments of the time value of money and the risks specific to the asset or CGU. The pre-tax discount rate is determined by way of iteration. The cash flows are generally derived from the recent budgets and planning calculations, which are prepared separately for each of the Group’s CGUs to which the individual assets are allocated.

The fair value less costs of disposal is determined on the basis of the recent market transactions, if available. If no such transactions can be identified, an appropriate valuation model is used.

If the reasons for impairment no longer apply in a subsequent period, a reversal is recognized in profit or loss. The increased carrying amount related to the reversal of an impairment loss shall not exceed the carrying amount that would have been determined (net of amortization and depreciation) had no impairment loss been recognized in prior years.

k) Assets held for sale

Non-current assets and disposal groups are classified as held for sale if their carrying amounts are to be realized by sale rather than through continued use. This is the case when the sale is highly probable, and the asset or disposal group is available for immediate sale in its present condition. Non-current assets and disposal groups classified as held for sale are measured at the lower of carrying amount and fair value less costs to sell. Property, plant and equipment and intangible assets once classified as held for sale are no longer amortized or depreciated.

l) Leases

OMV as a lessee recognizes lease liabilities and right-of-use assets for lease contracts according to IFRS 16. It applies the recognition exemption for short-term leases and leases in which the underlying asset is of low value and therefore does not recognize right-of-use assets and lease liabilities for such leases. Leases to explore for and use oil and natural gas, which comprise mainly land leases used for such activities, are not in the scope of IFRS 16. The rent for these contracts is recognized as expense on a straight-line basis over the lease term.

Non-lease components are separated from the lease components for the measurement of right-of-use assets and lease liabilities. Lease liabilities are recognized at the present value of fixed lease payments and lease payments which depend on an index or rate over the determined lease term with the applicable discount rate. Right-of-use assets are recognized at the value of the lease liability plus prepayments and initial direct costs and presented within property, plant and equipment.

OMV as a lessor entered into contracts which were assessed as operating leases, for which fixed and variable rent is recognized as revenue from rents and leases over the period of the lease.

m) Non-derivative financial assets

At initial recognition, OMV classifies its financial assets as subsequently measured at amortized cost, fair value through other comprehensive income (OCI) or fair value through profit or loss. The classification depends both on the Group’s business model for managing the financial assets and the contractual cash flow characteristics of the financial assets. All regular way trades are recognized and derecognized on the trade date, i.e., the date that the Group commits to purchase or sell the asset.

Debt instruments are measured at amortized cost if both of the following conditions are met:

• the asset is held within the business model whose objective is to hold assets in order to collect contractual cash flows; and
• the contractual terms of the financial asset give rise on specific dates to cash flows that are solely payments of principal and interest on the principal amount outstanding.

These assets are subsequently measured at amortized cost using the effective interest method less any impairment losses. Interest income, impairment losses and gains or losses on derecognition are recognized in profit or loss.

OMV recognizes allowances for expected credit losses (ECLs) for all financial assets measured at amortized costs. The ECL calculation is based on external or internal credit ratings of the counterparty and associated probabilities of default. Available forward-looking information is taken into account, if it has a material impact on the amount of valuation allowance recognized.

ECLs are recognized in two stages. Where there has not been a significant increase in the credit risk since initial recognition, credit losses are measured at 12 month ECLs. The 12 month ECL is the credit loss which results from default events that are possible within the next 12 months. The Group considers a financial asset to have low credit risk when its credit risk rating is equivalent to the definition of ‘investment grade’.

Where there has been a significant increase in the credit risk since initial recognition, a loss allowance is required for the lifetime ECL, i.e. the expected credit losses resulting from possible default events over the expected life of a financial asset. For this assessment, OMV considers all reasonable and supportable information that is available without undue cost or effort. Furthermore, OMV assumes that the credit risk on a financial asset has significantly increased if it is more than 30 days past due. If the credit quality improves for a lifetime ECL asset, OMV reverts to recognizing allowances on a 12 month ECL basis. A financial asset is considered to be in default when the financial asset is 90 days past due unless there is reasonable and supportable information that demonstrates that a more lagging default criterion is appropriate. A financial asset is written off when there is no reasonable expectation that the contractual cash flows will be recovered.

For trade receivables and contract assets from contracts with customers a simplified approach is adopted, where the impairment losses are recognized at an amount equal to lifetime expected credit losses. In case there are credit insurances or securities held against the balances outstanding, the ECL calculation is based on the probability of default of the insurer/securer for the insured/secured element of the outstanding balance and the remaining amount will take the probability of default of the counterparty.

Non-derivative financial assets classified as at fair value through profit or loss include trade receivables from sales contracts with provisional pricing and investment funds because the contractual cash flows do not represent solely payments of principal and interest on the principal amount outstanding. Furthermore, this measurement category includes portfolios of trade receivables held with an intention to sell them. These assets are measured at fair value, with any gains or losses arising on remeasurement recognized in profit or loss.

Equity instruments are either measured at fair value through profit or loss (FVPL) or at fair value through OCI (FVOCI). OMV elected irrevocably to classify as investments at FVOCI the majority of its non-listed equity investments which are held for strategic purposes and not trading. Gains and losses on equity investments measured at FVOCI are never recycled to profit or loss and they are not subject to impairment assessment. Dividends are recognized in profit or loss unless they represent a recovery of part of the cost of an investment.

OMV derecognizes a financial asset when the contractual rights to the cash flows from the asset expire, or when it transfers the financial asset and substantially all the risks and rewards of ownership of the asset to another party.

n) Derivative financial instruments and hedge accounting

Derivative instruments are used to hedge risks resulting from changes in currency exchange rates, commodity prices and interest rates. Derivative instruments are recognized at fair value. Unrealized gains and losses are recognized as income or expense, except where hedge accounting according to IFRS 9 is applied.

Those derivatives qualifying and designated as hedges are either

• a fair value hedge when hedging exposure to changes in the fair value of a recognized asset or liability,
• a cash flow hedge when hedging exposure to variability in cash flows that is attributable to a particular risk associated with a recognized asset or liability or a highly probable forecast transaction, or
• a net investment hedge when hedging the foreign exchange risk in a net investment in a foreign operation.

For cash flow hedges, the effective part of the changes in fair value is recognized in other comprehensive income, while the ineffective part is recognized immediately in the income statement. Where the hedging of cash flows results in the recognition of a non-financial asset or liability, the carrying value of that item will be adjusted for the accumulated gains or losses recognized directly in OCI.

Hedges of net investments in foreign operations are accounted for similarly to cash flow hedges. Any gain or loss on the hedging instrument relating to the effective portion of the hedge is recognised in OCI and accumulated in the reserve for currency translation differences. The gain or loss relating to the ineffective portion is recognised immediately in profit or loss. Gains and losses accumulated in equity are reclassified to profit or loss when the foreign operation is disposed of or sold.

The Group applies hedge accounting to hedges which are affected by the interest rate benchmark reform. For the purpose of evaluating whether there is an economic relationship between the hedged items and the hedging instruments, the Group assumes that the benchmark interest rate is not altered as a result of interest rate benchmark reform (see Note 2.1a).

Contracts to buy or sell a non-financial item that can be settled net in cash or another financial instrument are accounted for as financial instruments and measured at fair value. Associated gains or losses are recognized in profit or loss. However, contracts that are entered into and continue to be held for the purpose of the receipt or delivery of a non-financial item in accordance with the Group’s expected purchase, sale or usage requirements are not accounted for as derivative financial instruments, but as executory contracts.

o) Borrowing costs

Borrowing costs directly attributable to the acquisition, construction or production of qualified assets are capitalized until these assets are substantially ready for their intended use or sale. All other costs of borrowing are expensed in the period in which they are incurred.

p) Government grants

Government grants are recognized as income or deducted from the related asset where it is reasonable to expect that the granting conditions will be met and that the grants will be received.

q) Inventories

Inventories are recognized at the lower of cost and net realizable value. Costs incurred are generally determined based on the individual costs for not interchangeable goods, the average price method for oil and gas inventories or the FIFO method for petrochemical products. Costs of production comprise directly attributable costs as well as fixed and variable indirect material and production overhead costs. Production-related administrative costs, the costs of company pension schemes and voluntary employee benefits are also included. In refineries, a carrying capacity approach is applied according to which the production costs are allocated to product groups on the basis of their relative market values at the end of the period.

r) Cash and cash equivalents

Cash and cash equivalents include cash balances, bank accounts and highly liquid short-term investments with low realization risk, i.e. negligible short-term exchange and interest risks. The maximum maturity at the time of acquisition for such investments is three months.

s) Provisions

A provision is recorded for present obligations against third parties when it is probable that an obligation will occur and the settlement amount can be estimated reliably. Provisions for individual obligations are based on the best estimate of the amount necessary to settle the obligation, discounted to the present value in the case of long-term obligations.

Decommissioning and environmental obligations: The Group’s core activities regularly lead to obligations related to dismantling and removal, asset retirement and soil remediation activities. These decommissioning and restoration obligations are principally of material importance in the Upstream segment (oil and gas wells, surface facilities) and in connection with filling stations on third-party property. At the time the obligation arises, it is provided for in full by recognizing the present value of future decommissioning and restoration expenses as a liability. An equivalent amount is capitalized as part of the carrying amount of long-lived assets. Any such obligation is calculated on the basis of best estimates. The unwinding of discounting leads to interest expense or income (in case of a negative discount rate) and accordingly to increased or decreased obligations at each statement of financial position date until decommissioning or restoration. For other environmental risks and measures, provisions are recognized if such obligations are probable and the amount of the obligation can be estimated reliably.

Pensions and similar obligations: OMV has both defined contribution and defined benefit pension plans. In the case of defined contribution plans, OMV has no obligations beyond payment of the agreed premiums, and no provision is therefore recognized. The reported expense corresponds to the contributions payable for the period.

In contrast, participants in defined benefit plans are entitled to pensions at certain levels and are generally based on years of service and the employee’s average compensation. These defined benefit plans expose the Group to actuarial risks, such as longevity risk, interest rate risk, inflation risk (as a result of indexation of pension) and market risk. Defined benefit pension obligations are accounted for by recognizing provisions for pensions.

Employees of Austrian Group companies whose service began before December 31, 2002 are entitled to receive severance payments upon termination of employment or on reaching normal retirement age. The entitlements depend on years of service and final compensation levels. Entitlements to severance payments for employees whose service began after December 31, 2002 are covered by defined contribution plans. Similar obligations as entitlement to severance payments also exist in other countries, where the Group provides employment.

Employees in Austria and Germany are entitled to jubilee payments after completion of a given number of years of service. These plans are non-contributory and unfunded.

Provisions for pensions, severance payments and jubilee payments are calculated using the projected unit credit method, which divides the costs of the estimated benefit entitlements over the whole period of employment and thus takes future increases in remuneration into account. Actuarial gains and losses for defined benefit pension and severance payment obligations are recognized in full in the period in which they occur in other comprehensive income. Such actuarial gains and losses are not reclassified to profit or loss in subsequent periods. Actuarial gains and losses on obligations for jubilee payments are recognized in profit or loss. Net interest expense is calculated on the basis of the net defined benefit obligation and disclosed as part of the financial result. Differences between the return on plan assets and interest income on plan assets included in the net interest expense is recognized in other comprehensive income.

Provisions for voluntary and mandatory separations under restructuring programs are recognized if a detailed plan has been approved by management and communicated to those affected prior to the statement of financial position date and an irrevocable commitment is thereby established. Voluntary modifications to employees’ remuneration arrangements are recognized on the basis of the expected number of employees accepting the employing company’s offer. Provisions for obligations related to individual separation agreements which lead to fixed payments over a defined period of time are recognized at the present value of the obligation.

Provision for onerous contracts are recognized for contracts in which the unavoidable costs of meeting a contractual obligation exceed the economic benefits expected to be received under the contract. These provisions are measured at the lower amount of the cost of fulfilling the contract and any potential penalties or compensation arising in the event of non-performance.

Emission allowances received free of cost from governmental authorities (EU Emissions Trading Scheme for greenhouse gas emissions allowances) reduce financial obligations related to CO₂ emissions; provisions are recognized only for shortfalls (see Note 23 – Provisions).

t) Non-derivative financial liabilities

Liabilities are carried at amortized cost, with the exception of derivative financial instruments, which are recognized at fair value. Long-term liabilities are discounted using the effective interest rate method.

u) Taxes on income and deferred taxes

In addition to corporate income taxes and trade earnings taxes, typical upstream taxes from oil and gas production like the country’s/national oil company’s profit share for certain EPSAs (see 2.3f) are disclosed as income taxes. Deferred taxes are recognized for temporary differences.

Deferred tax assets are recognized to the extent that it is probable that taxable profit will be available against which the unused tax losses, unused tax credits and deductible temporary differences can be utilized.

Deferred tax assets and liabilities at Group level are shown net where there is a right of set-off and the taxes relate to matters subject to the same tax jurisdiction.

v) Long Term Incentive (LTI) Plans and Equity Deferral

The fair value of share-based compensation expense arising from the Long-term Incentive Plan (LTIP) – OMV’s main equity settled plan – is estimated using a model which is based on the expected target achievements and the expected share prices. For cash-settled awards, a provision based on the fair value of the amount payable is built up over the vesting period, so that by the end of the vesting period the fair value of the bonus shares to be granted is fully provided for. The provision is remeasured at the end of each reporting period up to the date of settlement, with any changes in fair value recognized in profit or loss. For share settled awards, the grant date fair value is recognized as an expense (including income tax), with a corresponding increase in equity, over the vesting period of the awards. The amount recognized as expense is adjusted to subsequent changes in parameters other than market parameters. In addition, the Equity Deferral part of the annual bonus is settled in shares. Accordingly, the related expense is recognized against equity. For share-based awards, the award is settled net of tax to the participants.

w) Fair value measurement

The fair value is the amount for which an asset or liability could be transferred at the measurement date, based on the assumption that such transfers take place between participants in principal markets and, where applicable, taking highest and best use into account.

Fair values are determined according to the following hierarchy:

• Level 1: Quoted prices in active markets for identical assets or liabilities. For OMV Group this category will, in most cases, only be relevant for securities, bonds, investment funds and futures contracts.
• Level 2: Valuation technique using directly or indirectly observables inputs. In order to determine the fair value for financial instruments within Level 2, usually forward prices of crude oil or natural gas, interest rates and foreign exchange rates are used as inputs to the valuation model. In addition counterparty credit risk as well as volatility indicators, if applicable, are taken into account.
• Level 3: Valuation techniques such as discounted cash flow models using significant unobservable inputs (e.g. long-term price assumptions and reserves estimates).

Monetary foreign currency balances are measured at closing rates, and exchange gains and losses accrued at statement of financial position date are recognized in the income statement.

The financial statements of Group companies with functional currencies different from the Group’s presentation currency are translated using the closing rate method. Differences arising from statement of financial position items translated at closing rates are disclosed in other comprehensive income. Income statement items are translated at average rates for the period. The use of average rates for the income statement creates additional differences compared to the application of the closing rates in the statement of financial position which are directly adjusted in other comprehensive income.

The main rates applied in translating currencies to EUR were as follows:

The items in the income statement related to Borealis Group were converted by using the monthly average rates instead of the annual average rate for the period after the acquisition on October 29, 2020.