SDFI and Petoro annual report 2023
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Note information for accounts based on the Accounting Act


As of 31 December 2023, Petoro AS acted as licensee on behalf of the SDFI for interests in 175 production licences and 16 joint ventures for pipelines and terminals, including the company's management of commercial interests in Mongstad Terminal DA and Vestprosess DA, and the shares in Norsea Gas AS and Norpipe Oil AS. The SDFI is also entitled to potential profits in production licences with net profit agreements. Petoro has the same rights and obligations as other licensees, and manages the SDFI on the Norwegian shelf on the basis of sound business principles.
Petoro's administration of the portfolio is subject to the Regulations on Financial Management in Central Government and instructions for financial management of the SDFI. Accounts for the portfolio are presented both on the cash basis used by the government and in accordance with the (Norwegian) Accounting Act. The company maintains separate accounts for all transactions relating to its participating interests, so that revenue and costs from production licences and joint ventures are kept separate from operation of the company. Cash flow from the portfolio is transferred to the central government's own accounts with Norges Bank. Petoro prepares separate annual accounts for the SDFI, with an overview of the participating interests managed by the company and associated resource accounting.

Accounting principles for the company accounts

The principal difference between the profit based on the Accounting Act and on a cash basis is that the latter includes cash payment for investments and operating expenses. Adjustments are also made for accruals of income and expenses on a cash basis, with a corresponding adjustment of debtors and creditors in the balance sheet. Realised currency loss/gain related to operating expenses and income is classified on the cash basis as operating expenses and income. The accounts based on the Accounting Act present realised currency loss/gain as financial expenses/income, and these items are accordingly not included in the operating profit. Differences between the accounts prepared in accordance with the Accounting Act (NGAAP) and on a cash basis are indicated in the notes below.
The SDFI's interests in partnerships with shared liability relating to the production of petroleum are included under the respective items in the income statement and recorded in the balance sheet based on relative ownership interest for the SDFI's share of income, expenses, assets and liabilities. The same applies to licence interests in oil and gas activities, including pipeline transport, which are not organised as companies.
SDFI's participation in Equinor's investments that fall under the marketing and sale instruction, are assessed as investments in associated companies or jointly controlled enterprises and are recorded pursuant to the equity method. The SDFI's share of the equity is recorded in the balance sheet under financial fixed assets and its share of the profit/loss is recorded as operating revenue in the income statement.
SDFI's ownership interests in limited companies are recorded in the balance sheet in accordance with the cost method and any dividend is recorded as a financial item. In addition, revenue from production licences with net profit agreements (concerns licences awarded in the second licensing round) is recorded as other income.
The functional currency is the Norwegian krone.
Revenue recognition principles
The SDFI records revenue from the production of oil, NGL and gas using the sales method. This means that sales are recorded in the period when the volumes are lifted and sold to the customer.
Revenue from ownership in transport and process facilities is recorded when the service is rendered.
Gas swap and borrowing agreements where settlement takes the form of returning volumes are, as a general rule, accrued using the sales method. At the same time, a provision is made for the associated production costs in the event that the SDFI has lent/swapped gas. When lending gas from the SDFI, the lower of production expense and estimated net present value of the future sales price is capitalised as a pre-paid expense at the date of the loan. The SDFI's share of location swaps associated with the purchase or sale of third-party gas is recorded net as operating revenue. The SDFI's share of timeswaps is recorded gross.
Liabilities arising because too much crude oil has been lifted in relation to the SDFI's share of the production partnership are valued at production cost, while receivables from the other partners in the production partnerships are valued at the lower of production cost and the estimated present value of the future sales price.
Purchases of third-party gas for resale and gas for inventory are recorded gross as operating expenses. The corresponding revenue is included in sales income.
Purchases and sales between fields and/or transport systems
Internal expenses and revenues are eliminated in purchases and sales between fields and/or transport systems in which the SDFI is both owner and shipper, so that only costs paid to third parties appear as net transport costs.
Foreign currencies
Transactions in foreign currencies are recorded at the transaction rate. Monetary items in foreign currencies are valued at the exchange rate prevailing on the balance sheet date. Unrealised currency losses and realised currency losses/gains are recorded as financial income or financial expenses. 
Classification of assets and liabilities
Assets intended for ownership or use over a longer period are classified as fixed assets. Other assets are classified as current assets. Debts due within one year are classified as current assets. Equivalent criteria are applied for classification of current and long-term liabilities.
Research and development
Research and development costs are expensed on a continuous basis. In addition to expenses for direct research and development in each joint venture, the operator also charges expenses for general research and development to the partnership in accordance with the extent of exploration, development and operating expenses in the joint venture.
Exploration and development costs
Petoro employs the successful efforts method to record exploration costs for SDFI oil and gas operations. This means that costs related to geological and geophysical surveys are expensed. However, expenses linked to the drilling of exploration wells are recognised in the balance sheet in anticipation of evaluation. Such costs are expensed if the evaluation determines that the discovery is not  commercially viable. Considerable time can elapse between the drilling of a well and a final development decision. Capitalised exploration well expenses are accordingly assessed quarterly to determine whether sufficient progress is being made in the projects so that the criteria for capitalisation continue to be met. Dry wells or those where progress is insufficient are expensed.
Expenses linked to development, including wells, platforms and equipment, are capitalised. Costs for operational preparations are expensed on a continuous basis.
Tangible fixed assets
Tangible fixed assets and investments are carried at acquisition cost with deduction for planned and contingent depreciation. Fixed assets under construction are carried at historical cost.
Fixed assets leased on terms which largely transfer the financial risk and control to the SDFI (financial leasing) are capitalised under tangible fixed assets and the associated lease obligation is recognised as an obligation under long-term interest-bearing debt at the net present value of the lease charges. The fixed asset is subject to planned depreciation, and the obligation is reduced by the lease payment after deduction of calculated interest costs.
The SDFI does not take up loans, and incurs no interest expenses associated with the financing of development projects.
Ordinary depreciation of oil and gas production facilities is calculated for each field and field-dedicated transport system using the unit of production method. This means that the acquisition cost is depreciated in line with the ratio between volume sold during the period and reserves at the start of the period. Investments in wells are depreciated in line with the reserves made available by the wells drilled.
Petoro determines the reserve base for depreciation purposes on the basis of estimated remaining reserves per field, which are adjusted by a factor calculated as the ratio between the Norwegian Petroleum Directorate's total of low reserves in production and the sum of expected reserves in production. This is done for both oil and gas reserves. This reserve adjustment factor amounted to 76 per cent of expected remaining oil reserves in 2023, while the corresponding figure for gas reserves was 89 per cent. The reserve estimates are revised annually, and any changes affect only future depreciation expenses.
Ordinary depreciation for onshore facilities and transport systems as well as riser platforms used by multiple fields, is calculated on a straight-line basis over the remaining licence period at 31 December.
Other tangible fixed assets are depreciated on a straight-line basis over their expected economic lifetime.
Intangible fixed assets
Intangible fixed assets are carried at their fair value at the time of acquisition. They are depreciated over the expected contract period or their expected economic lifetime, and any impairment charges are deducted.
When the accounts are prepared, tangible fixed assets and intangible assets are reviewed for indications of a decline in value. Producing fields or installations are normally treated as separate entities for the purposes of assessing impairment. Should the recoverable value be lower than the book value, and this decline is not expected to be temporary, the asset is written down to its recoverable value, which is the higher of the asset's fair value less sales costs and its utility value. The utility value is calculated using expected future cash flows, which are discounted using a discount rate based on the weighted average cost of capital (WACC) calculated for the company.
The impairment charge will be reversed if the conditions for writing down the asset no longer apply, limited to what the value would have been if no impairment was undertaken.
Maintenance expenses
Expenses related to repair and maintenance are expensed on a continuous basis. Expenses for major replacements and renovations that significantly extend the economic life of the tangible fixed assets are capitalised.
Abandonment and decommissioning expenses
Under the terms of a licence, the authorities can require the licensees to remove offshore installations when their production life comes to an end. The estimated fair value of obligations for decommissioning and removal is recorded in the accounts in the period when the liability arises, normally when wells are drilled and installations are built and ready for use. The obligation is capitalised as part of the acquisition cost of wells and installations, and depreciated therewith. Changes to estimated cessation and decommissioning costs are recorded and capitalised in the same manner and depreciated over the remaining economic life of the assets. The discount rate is based on the discount rate for corporate bonds (OMF) as stated in NRS 6.
A change in the liability relating to its time value — the effect of the decommissioning date having come one year closer — is recorded as a financial expense.
Inventories of spare parts and operating materials are valued at the lower of acquisition cost according to the FIFO principle, or net realisable value. Spare parts of insignificant value for use in connection with operating oil or gas fields are expensed at the time of acquisition. Spare parts of significant value are recorded as inventory at the time of acquisition and expensed when they are used in operations. Petoro takes a point of departure in the operators' assessments in monthly settlements (billings) as regards which materials should be capitalised and which expensed.
Accounts receivable
Accounts receivable are recognised at face value in the balance sheet less a provision for expected loss. This provision is based on an individual assessment of each debtor. 
Bank deposits
Bank deposits include cash, bank deposits and other monetary instruments with a maturity of less than three months at the date of purchase. Cash flows from oil and gas sales are transferred to the state on a daily basis. Booked bank deposits thus include the SDFI's share of bank deposits in companies with apportioned liability in which the SDFI has an interest, and in which the proportionate consolidation method is used.
Current liabilities
Current liabilities are recognised at face value.
Taxes and fees
The SDFI is exempt from income tax in Norway. The SDFI is registered for value-added tax (VAT) in Norway. Virtually all the SDFI's sales of oil and gas products from its activity take place outside the geographic scope of Norway's VAT legislation (continental shelf and exports). The SDFI invoices these sales to the buyer free of tax. At the same time, the SDFI can deduct any VAT incurred on invoiced costs relevant to its activity.
Financial instruments
The SDFI is covered by the state's overall risk management. Financial instruments are used as part of Equinor's optimisation of gas sales.
Financial instruments are valued according to the lowest value principle, unless stated criteria have been met. Unrealised losses relating to financial instruments are recorded as expenses. Portfolio valuations are used as a basis where this, based on the financial instruments, is considered to be the most sensible approach, and where the portfolio is balanced in volume and time. Eliminations are carried out where legal rights exist to offset unrealised losses and gains, or where deposits/margins that correspond with the market value of the derivatives have been paid and capitalised. Gains are otherwise recognised upon realisation.
Financial instruments that are not current assets follow the valuation rules for fixed assets. 
Uncertain obligations and contingent assets
Probable and quantifiable losses are expensed. Contingent assets are not included unless the asset is reasonably certain to be settled.  Liabilities related to legal disputes are reflected when there is a preponderance of evidence indicating that the SDFI is on the losing side or when a judgement is pronounced, regardless of whether the judgement is appealed and the dispute is still making its way through the legal system.