NOTE 2: -     Basis of preparation and presentation of financial information 

The following accounting policies have been applied consistently in the consolidated financial statements for all periods presented, unless otherwise stated.

a.      Basis of presentation of the financial statements:

These consolidated financial statements have been prepared in accordance with International Financial Reporting Standards (IFRS) as adopted by the European Union (EU).

These consolidated financial statements have not been prepared in accordance with the requirements of the Cyprus Companies Law, Cap.113 and are not intended for statutory filing in Cyprus.

The consolidated financial statements have been prepared on the historical cost basis.

The consolidated financial statements have been prepared on a going concern basis. The principal accounting policies adopted by the Group are set out below.

 b.     The financial statements are presented in U.S. Dollars and all values are rounded to the nearest thousand

dollars except where otherwise indicated.

c.      Going Concern:

The Group carefully manages the risk of a shortage of funds by closely monitoring its funding position and its liquidity risk. The going concern assessment covers the period from the date of approval of the Group Financial Statements on 20 March 2024 to 30 June 2025 ('the Assessment Period'). Cash forecasts are regularly produced based on, inter alia, the Group's latest life of field production, budgeted expenditure forecasts, price estimates based on signed GSPAs and oil price forward curves. In addition, on a regular basis, the Group performs sensitivity tests of its liquidity position to evaluate adverse impacts that may result from changes to the macro economic environment and downside scenarios to budgeted production forecasts. The Group does this to identify risks to liquidity to formulate appropriate and timely mitigation strategies in order to manage the risk of funds shortfalls and to ensure the Group's ability to continue as a going concern.

On 11 July 2023, Energean Israel Finance Ltd. completed the offering of US$750 million aggregate principal amount of senior secured notes with a fixed annual interest rate of 8.500%. The proceeds from the Offering, were released from escrow in September 2023 and were used to a) refinance the $625 million notes due in 2024 (redemption date on 30 September 2023), b) pay fees and expenses associated with this refinancing, c) contribute towards funding the interest payment reserve account and d) contribute towards the payment of the final deferred consideration to Kerogen.

The going concern assessment is founded on a cashflow forecast prepared by management, which is based on a number of assumptions, most notably the Group's latest life of field production forecasts, budgeted expenditure forecasts, estimated of future commodity prices (based on recent published forward curves). The going concern assessment contains a 'Base Case' and a 'Reasonable Worst Case' ('RWC') scenario.

The Base Case scenario assumes Brent at $80/bbl in 2024 and $75/bbl in 2025. A reasonable production from the Karish field is assumed throughout the going concern assessment period, with prices for gas sold assumed at contractually agreed prices. Under the Base Case, sufficient liquidity is maintained throughout the going concern period.

The Group also routinely performs sensitivity tests of its liquidity position to evaluate adverse impacts that may result from changes to the macro-economic environment, such as a reduction in commodity prices. These downsides are considered in the RWC going concern assessment scenario. The Group is not exposed to floating interest rate risk since its borrowings are fixed-rate. The Group also looks at the impact of changes or deferral of key projects and downside scenarios to budgeted production forecasts in the RWC.

The two primary downside sensitivities considered in the RWC are: (i) reduced commodity prices; (ii) reduced production - these downsides are applied to assess the robustness of the Group's liquidity position over the Assessment Period. The conditions necessary for liquidity headroom to be eliminated are judged to have a remote possibility of occurring, given the 'natural hedge' provided by virtue of the Group's fixed-price gas contracts.

Under the RWC scenario, liquidity is maintained throughout the going concern period.

 

NOTE 2: -       Basis of preparation and presentation of financial information (Cont.)

In forming its assessment of the Group's ability to continue as a going concern, including its review of the forecasted cashflow of the Group over the Forecast Period, the Board has made judgements about:

• reasonable sensitivities appropriate for the current status of the business and the wider macro environment; and

• the Group's ability to implement the mitigating actions within the Group's control, in the event these actions were required.

After careful consideration, the Directors are satisfied that the Group has sufficient financial resources to continue in operation for the foreseeable future, for the Assessment Period from the date of approval of the Group Financial Statements on 20 March 2024 to 30 June 2025. For this reason, they continue to adopt the going concern basis in preparing the Group financial statements.

Israel-Hamas conflict- The Group continues to monitor the ongoing conflict between the State of Israel and Hamas. While the situation has not impacted the Company's production from the FPSO, it is not possible to predict whether the conflict will have a material adverse effect on our future earnings, cash flows and financial conditions.

 

d.      New and amended accounting standards and interpretations:

The following amendments became effective as at 1 January 2023:

·      Disclosure of Accounting Policies (Amendments to IAS 1 and IFRS Practice Statement 2)

·      Definition of Accounting Estimates (Amendments to IAS 8)

·      Deferred Tax related to Assets and Liabilities arising from a Single Transaction (Amendments to IAS 12)

·      International Tax Reform - Pillar Two Model Rules (Amendments to IAS 12)

None of the above amendments had a significant impact on the Group's consolidated financial statements. The amendments on International Tax Reform - Pillar Two Model Rules introduce a mandatory exception in IAS 12 'Income Taxes' to recognising and disclosing information about deferred tax assets and liabilities related to Pillar Two income taxes.

New and amended standards and interpretations in issue but not yet effective for the 2023 year end:

·      Amendments to IAS 1 - Classification of Liabilities as Current or Non-current and Non-current Liabilities with Covenants - 1 January 2024

The adoption of the above standard and interpretations is not expected to lead to any material changes to the Group's accounting policies or have any other material impact on the financial position or performance of the Group.

e.      Basis of consolidation:

The consolidated financial statements incorporate the financial statements of the Company and entities controlled by the Company (its subsidiaries) as detailed in Note 1 above.

 

 NOTE 3: -    Material accounting policies

Accounting Policies:

The principal accounting policies and measurement bases used in the preparation of the consolidated financial statements are set out below. These policies have been consistently applied to all periods presented in the consolidated financial statements unless otherwise stated.

a)      Functional and presentation currency and foreign currency:

1.      Functional and presentation currency:

Items included in the financial statements of the Group are measured using the currency of the primary economic environment in which the Group operates (''the functional currency'').

The functional currency of the Company is U.S. Dollars (US$). The U.S. Dollar is the currency that influences future sales prices, revenue estimates and also highly affect the Group's operations.

The presentation currency of the Group's consolidated financial statements is U.S. Dollar.

NOTE 3: -        Material accounting policies (Cont.)

2.      Transactions and balances:

Foreign currency transactions are translated into the functional currency using the exchange rates prevailing at the dates of the transactions. Foreign exchange gains and losses resulting from monetary assets and liabilities denominated in foreign currencies are recognised in the profit or loss. Such monetary assets and liabilities are translated using the functional currency exchange rates at the reporting date. Non-monetary items that are measured in terms of historical cost denominated in a foreign currency are translated at the exchange rates prevailing at the date of the transaction and are not subsequently remeasured.

b)      Intangible assets - Exploration and evaluation expenditures:

The Group adopts the successful efforts method of accounting for exploration and evaluation costs. Pre-licence costs are expensed in the period in which they are incurred. All licence acquisition, exploration and evaluation costs and directly attributable administration costs are initially capitalised as intangible assets by field or exploration area, as appropriate. All such capitalised costs are subject to technical, commercial and management review, as well as review for indicators of impairment at least once a year. This is 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 through the statement of comprehensive income (loss). When proved reserves of oil and gas are identified and development is sanctioned by management, the relevant capitalised expenditure is first assessed for impairment and (if required) any impairment loss is recognised, then the remaining balance is transferred to oil and gas properties.

c)      Commercial reserves:

Commercial reserves are proven and probable oil and gas reserves, which are defined as the estimated quantities of crude oil, natural gas and natural gas liquids which geological, geophysical and engineering data demonstrate with a specified degree of certainty to be recoverable in future years from known reservoirs and which are considered commercially producible. There should be a 50 per cent statistical probability that the actual quantity of recoverable reserves will be more than the amount estimated as proven and probable reserves and a 50 per cent statistical probability that it will be less.

d)      Oil and gas properties - assets in development:

Expenditure is transferred from 'Exploration and evaluation assets' to 'Assets in development' which is a subcategory of 'Oil and gas properties' once the work completed to date supports the future development of the asset and such development receives appropriate approvals. After transfer of the exploration and evaluation assets, all subsequent expenditure on the construction, installation or completion of infrastructure facilities such as platforms, pipelines and the drilling of development wells, including unsuccessful development or delineation wells, is capitalised within 'Assets in development'.

Proceeds from any oil and gas produced while bringing an item of property, plant and equipment to the location and condition necessary for it to be capable of operating in the manner intended by management (such as samples produced when testing whether the asset is functioning properly) has been recognised in profit or loss in accordance with IFRS 15 Revenue Recognition. The Group measures the cost of those items applying the measurement requirements of IAS 2 Inventories. When a development project moves into the production stage, all assets included in 'Assets in development' are then transferred to 'Producing assets' which is also a sub-category of 'Oil and gas properties. The capitalisation of certain construction/development costs ceases, and costs are either regarded as part of the cost of inventory or expensed, except for costs which qualify for capitalisation relating to 'Oil and gas properties' asset additions, improvements or new developments.

e)      Depletion and amortisation:

All expenditure carried within each field will be amortised from the commencement of production on a unit of production basis, which is the ratio of oil and gas production in the period to the estimated quantities of commercial reserves at the end of the period plus the production in the period, generally on a field-by-field basis or by a group of fields which are reliant on common infrastructure.

NOTE 3: -        Material accounting policies (Cont.)

f)       Impairments of oil & gas properties:

Where there is evidence of economic interdependency between fields, such as common infrastructure, the fields are grouped as a single CGU for impairment purposes. A CGU's recoverable amount is the higher of its fair value less costs of disposal and its value in use. Where the carrying amount of a CGU exceeds its recoverable amount, the CGU is considered impaired and is written down to its recoverable amount.

Fair value less costs of disposal is the price that would be received to sell the asset in an orderly transaction between market participants and does not reflect the effects of factors that may be specific to the Group and not applicable to entities in general.

For discount of the future cash flows the Group calculates CGU-specific discount rate. The discount rate is based on an assessment of a relevant peer group's pre-tax Weighted Average Cost of Capital (WACC). The Group then adds any exploration risk premium which is implicit within a peer group's WACC and subsequently applies additional country risk premium for Israel.

g)      Impairment of non-financial assets:

At each reporting date, the Group reviews the carrying amounts of its depreciable property, plant and equipment and intangible assets to determine whether there is any indication that those assets have suffered an impairment loss. Impairment is assessed at the level of cash-generating units (CGUs) which, in accordance with IAS 36 'Impairment of Assets', are identified as the smallest identifiable group of assets that generates cash inflows, which are largely independent of the cash inflows from other assets. This is usually at the individual royalty, stream, oil and gas or working interest level for each property from which cash inflows are generated.

An impairment loss is recognised for the amount by which the asset's carrying value exceeds its recoverable amount, which is the higher of fair value less costs of disposal (FVLCD) and value-in-use (VIU). The future cash flow expected is derived using estimates of proven and probable reserves, a portion of resources that is expected to be converted into reserves and information regarding the mineral, stream and oil & gas properties, respectively, that could affect the future recoverability of the Group's interests. Discount factors are determined individually for each asset and reflect their respective risk profiles.

In addition, exploration and evaluation assets are assessed for impairment upon their reclassification to producing assets (oil and gas interest in property, plant and equipment).

In assessing the impairment of exploration and evaluation assets, the carrying value of the asset would be compared to the estimated recoverable amount and any impairment loss is recognised immediately in profit or loss.

h)      Leases:

The Group assesses at contract inception whether a contract is, or contains, a lease. That is, if the contract conveys the right to control the use of an identified asset for a period of time in exchange for consideration.

The determination of whether an arrangement is, or contains, a lease is based on the substance of the arrangement at the date of inception. The arrangement is assessed to determine whether fulfilment is dependent on the use of a specific asset (or assets) and the arrangement conveys a right to use the asset (or assets), even if that asset is (or those assets are) not explicitly specified in an arrangement. The Group is not a lessor in any transactions, it is only a lessee.

The Group applies a single recognition and measurement approach for all leases, except for short-term leases and leases of low-value assets. The Group recognises lease liabilities to make lease payments and right-of-use assets representing the right to use the underlying assets.

 

 

 

 

NOTE 3: -        Material accounting policies (Cont.)

i)       Right-of-use assets:

The Group recognises right-of-use assets at the commencement date of the lease (i.e., the date the underlying asset is available for use). Right-of-use assets are measured at cost, less any accumulated depreciation and impairment losses, and adjusted for any remeasurement of lease liabilities. The cost of right-of-use assets includes the amount of lease liabilities recognised, initial direct costs incurred, and lease payments made at or before the commencement date less any lease incentives received.

Right-of-use assets are depreciated on a straight-line basis over the shorter of the lease term and the estimated useful lives of the assets, as follows:

-        Property leases 2 to 5 years

-        Motor vehicles and other equipment 1 to 3 years

-         Fiber Optic 14 years

 Lease liabilities:

At the commencement date of the lease, the Group recognises lease liabilities measured at the present value of lease payments to be made over the lease term. The lease payments include fixed payments (including in substance fixed payments) less any lease incentives receivable, variable lease payments that depend on an index or a rate, and amounts expected to be paid under residual value guarantees. The lease payments also include the exercise price of a purchase option reasonably certain to be exercised by the Group and payments of penalties for terminating the lease, if the lease term reflects the Group exercising the option to terminate.

In calculating the present value of lease payments, the Group uses its incremental borrowing rate at the lease commencement date if the interest rate implicit in the lease is not readily determinable. After the commencement date, the amount of lease liabilities is increased to reflect the accretion of interest and reduced for the lease payments made.

 

Other leases outside the scope of IFRS 16:

Leases to explore for or use minerals, oil, natural gas and similar non-regenerative resources are outside the scope of IFRS 16 and are recognised as exploration and  evaluation costs or as oil and gas assets, as appropriate. Please refer to notes c and e above.

j)       Financial instruments - initial recognition and subsequent measurement:

A financial instrument is any contract that gives rise to a financial asset of one entity and a financial liability or equity instrument of another entity.

1.         Financial assets:

Initial recognition and measurement:

Financial assets are classified, at initial recognition, as subsequently measured at amortised cost. The classification of financial assets at initial recognition depends on the financial asset's contractual cash flow characteristics and the Group's business model for managing them. With the exception of trade receivables that do not contain a significant financing component or for which the Group has applied the practical expedient, the Group initially measures a financial asset at its fair value plus, in the case of a financial asset not at fair value through profit or loss, transaction costs. Trade receivables that do not contain a significant financing component or for which the Group has applied the practical expedient are measured at the transaction price determined under IFRS 15.

In order for a financial asset to be classified and measured at amortised cost, it needs to give rise to cash flows that are 'solely payments of principal and interest (SPPI)' on the principal amount outstanding. This assessment is referred to as the SPPI test and is performed at an instrument level.

 

NOTE 3: -        Material accounting policies (Cont.)

The Group's business model for managing financial assets refers to how it manages its financial assets in order

to generate cash flows. The business model determines whether cash flows will result from collecting contractual cash flows, selling the financial assets, or both.

Subsequent measurement- Financial assets at amortised cost:

The Group measures financial assets at amortised cost if both of the following conditions are met:

-           The financial asset is held within a business model with the objective to hold financial assets in order to collect contractual cash flows; and

-           The contractual terms of the financial asset give rise on specified dates to cash flows that are solely payments of principal and interest on the principal amount outstanding.

Financial assets at amortised cost are subsequently measured using the effective interest (EIR) method and are subject to impairment under the expected credit loss model. Gains and losses are recognised in profit or loss when the asset is derecognised, modified or impaired.

The Group's financial assets at amortised cost includes trade receivables.

Impairment of financial assets:

For trade receivables and contract assets, the Group applies a simplified approach in calculating allowance for expected credit losses (ECLs). Therefore, the Group does not track changes in credit risk, but instead recognises a loss allowance based on lifetime ECLs at each reporting date.

2.         Financial liabilities:

Initial recognition and measurement:

The Group's financial liabilities include trade and other payables and senior secured notes.

Subsequent measurement:

Loans and borrowings:

After initial recognition, interest-bearing liabilities such as senior secured notes are subsequently measured at amortised cost using the EIR method. Gains and losses are recognised in profit or loss when the liabilities are derecognised, modified and through the EIR amortisation process.

Amortised cost is calculated by taking into account any discount or premium on acquisition and fees or costs that are an integral part of the EIR. The EIR amortisation is included as finance costs in the statement of profit or loss.

 Derecognition:

A financial liability is derecognised when the obligation under the liability is discharged or cancelled or expires. When an existing financial liability is replaced by another from the same lender on substantially different terms, or the terms of an existing liability are substantially modified, such an exchange or modification is treated as the derecognition of the original liability and the recognition of a new liability. The difference in the respective carrying amounts is recognised in the statement of profit or loss.

3.         Offsetting of financial instruments:

Financial assets and financial liabilities are offset and the net amount is reported in the consolidated statement of financial position if there is a currently enforceable legal right to offset the recognised amounts and there is an intention to settle on a net basis, to realise the assets and settle the liabilities simultaneously.

k)      Equity instruments:

Equity instruments issued by the Group are recorded at the proceeds received, net of direct issue costs.

Ordinary shares

Ordinary shares are classified as equity and measured at their nominal value that have been issued.

NOTE 3: -        Material accounting policies (Cont.)

Any premiums received on issue of share capital above its nominal value, are recognised as share premium within equity. Associated issue costs are deducted from share premium.

Other components of equity include the following:

Retained earnings (losses) includes all current and prior period retained earning (losses).

l)       Dividend payments

Dividend distributions payable to equity shareholders are included in other liabilities when the dividends have been approved in a general meeting prior to the balance sheet date.

m)     Share-based payments:

Employees (including senior executives) of the Group receive remuneration in the form of share-based payments, whereby employees render services as consideration for equity instruments issued and charge upon vesting by the Ultimate Parent Company (Energean plc).

n)      Fair value measurement:

The Group uses valuation techniques that are appropriate in the circumstances and for which sufficient data are available to measure fair value, maximising the use of relevant observable inputs and minimising the use of unobservable inputs.

All assets and liabilities, for which fair value is measured or disclosed in the financial statements, are categorised within the fair value hierarchy, described as follows, based on the lowest-level input that is significant to the fair value measurement as a whole:

-       Level 1 - Quoted (unadjusted) market prices in active markets for identical assets or liabilities.

-    Level 2 - Valuation techniques for which the lowest-level input that is significant to the fair value measurement is directly or indirectly observable.

-    Level 3 - Valuation techniques for which the lowest-level input that is significant to the fair value measurement is unobservable.

For assets and liabilities that are recognised in the financial statements on a recurring basis, the Group determines whether transfers have occurred between levels in the hierarchy by reassessing categorisation (based on the lowest-level input that is significant to the fair value measurement as a whole) at the end of each reporting period.

o)      Cash and cash equivalents and restricted cash:

Cash and cash equivalents comprise of cash in hand and time deposits, with a maturity of three months or less, that are subject to an insignificant risk of changes in their fair value.

Restricted cash comprises balances retained in respect of the Group's Senior Secured Notes and cash collateral provided under a letter of credit facility for issuing bank guarantees for Group's activities in Israel (see Note 16A). The nature of the restrictions on these balances mean that they do not qualify for classification as cash equivalents.

p)      Inventories:

Inventories comprise hydrocarbon liquids and natural gas, consumables and other spare parts. Inventories are stated at the lower of cost and net realisable value. Cost is determined using the weighted average cost method. The cost of finished goods and work in progress comprises raw materials, direct labour, other direct costs and related production overheads. It does not include borrowing costs. Net realisable value is the estimated selling price in the ordinary course of business, less estimated costs of completion and estimated costs necessary to make the sale. Spare parts consumed within a year are carried as inventory and recognised in profit or loss when consumed.

 

 

 

NOTE 3: -        Material accounting policies (Cont.)

q)      Decommissioning provision:

Provision for decommissioning is recognised in full when the related facilities are installed. A corresponding amount equivalent to the provision is also recognised as part of the cost of the related property, plant and equipment. The amount recognised is the estimated cost of decommissioning, discounted to its net present value at a risk-free discount rate, and is reassessed each year in accordance with relevant conditions and requirements. Changes in the estimated timing of decommissioning or decommissioning cost estimates are dealt with prospectively by recording an adjustment to the provision, and a corresponding adjustment to property, plant and equipment. The unwinding of the discount on the decommissioning provision is included as a finance cost.

r)      Revenue

Revenue from contracts with customers is recognised when control of the gas/ hydrocarbon liquids are transferred to the customer at an amount that reflects the consideration to which the Group expects to be entitled in exchange for those goods or services. The Group has concluded that it is the principal in its revenue arrangements because it typically controls the goods or services before transferring them to the customer.

In Israel royalties are levied by the government. The government can request that these royalty payments be made in cash or in kind. In the current year and in prior year the government has requested cash payments be made and therefore the Group has not made any royalty payments in kind. As such the Group obtains control of all the underlying reserves once extracted, sells the production to its customers and then remits the proceeds to the royalty holder and is therefore considered to be acting as the Principal.

Sale of natural gas and hydrocarbon liquids

Sales revenue represents the sales value, net of VAT, of actual sales volumes to customers in the year.

The Group's accounting policy under IFRS 15 is that revenue is recognised when the Group satisfies a performance obligation by transferring hydrocarbon liquids or gas to its customer. The title to hydrocarbon liquids and gas typically transfers to a customer at the same time as the customer takes physical possession of the hydrocarbon liquids or gas. Typically, at this point in time, the performance obligations of the Group are fully satisfied. The revenue is recorded when the hydrocarbon liquids or gas has been physically delivered to a vessel or pipeline.

s)      Retirement benefit costs regarding the employees by the directly owned Branch in Israel:

The Israeli Branch has defined contribution plans pursuant to section 14 to the Severance Pay in Israel Law under which the Israeli Branch pays fixed contributions and will have no legal or constructive obligation to pay further contributions if the fund does not hold sufficient amounts to pay all employee benefits relating to employee service in the current and prior periods. Contributions to the defined contribution plan in respect of severance or retirement pay are recognised as an expense when contributed concurrently with performance of the employee's services.

t)       Borrowing costs:

Borrowing costs directly attributable to the acquisition, construction or production of qualifying assets, which are assets that necessarily take a substantial period of time to get ready for their intended use or sale, are added to the cost of those assets, until such time as the assets are substantially ready for their intended use or sale. Investment income earned on the temporary investment of specific borrowings pending their expenditure on qualifying assets is deducted from the borrowing costs eligible for capitalisation.

Excluded from the above capitalisation policy are any qualifying assets that are inventories that are produced in large quantities on a repetitive basis.

 

 

 

NOTE 3: -        Material accounting policies (Cont.)

u)      Tax:

The tax currently payable is based on taxable profit for the year. Taxable profit differs from profit as reported in the financial statements because it excludes items of income or expense that are taxable or deductible in other years and it further excludes items that are never taxable or deductible. The Group's liability for current tax is calculated using tax rates that have been enacted or substantively enacted by the reporting date.

Deferred tax is recognised on temporary differences between the carrying amounts of assets and liabilities in the financial statements and the corresponding tax bases used in the computation of taxable profit, based on tax rates that have been enacted or substantively enacted by the reporting date. Deferred tax liabilities are generally recognised for all taxable temporary differences and deferred tax assets are recognised to the extent that it is probable that taxable profits will be available against which deductible temporary differences can be utilised.

The Group recognises tax provision liabilities for anticipated tax issues based on if it is probable, defined as more likely than not, that additional taxes will be due. This assessment is based on all available evidence and, where appropriate, in the light of external advice. Where the final tax outcome of these matters is different from the amounts that were initially recorded, such differences will impact the income tax liability in the period in which such determination is made.

v)      Levies:

Levies imposed on the Company by government entities through legislation, are accounted for pursuant to IFRIC 21 according to which the liability for the levy is recognized only when the activity that triggers payment occurs.

 

NOTE 4: -     Critical accounting estimates and judgments

The preparation of these consolidated financial statements in conformity with IFRS requires the use of accounting estimates and assumptions, and also requires management to exercise its judgement, in the process of applying the Group's accounting policies.

Estimates, assumptions and judgement applied are continually evaluated and are based on historical experience and other factors, including expectations of future events that are believed to be reasonable under the circumstances. Although these estimates, assumptions and judgement are based on management's best knowledge of current events and actions, actual results may ultimately differ.

1.         Critical judgements in applying the Group's accounting policies:

The following are significant management judgements in applying the accounting policies of the Group that have the most significant effect on the financial statements:

Carrying value of intangible exploration and evaluation assets:

Amounts carried under intangible exploration and evaluation assets represent active exploration projects. Capitalised costs will be written off to the income statement as exploration costs unless commercial reserves are established, or the determination process is not completed and there are no indications of impairment in accordance with the Group's accounting policy. The process of determining whether there is an indicator for impairment or calculating the impairment requires critical judgement. The key areas in which management has applied judgement are as follows: the Group's intention to proceed with a future work programme; the likelihood of licence renewal or extension; the assessment of whether sufficient data exists to indicate that, although a development in the specific area is likely to proceed, the carrying amount of the exploration and evaluation asset is unlikely to be recovered in full from successful development or by sale; and the success of a well result or geological or geophysical survey.

Identification of cash generating units (note 10):

In considering the carrying value of property, plant and equipment the Group has to make a critical judgement in relation to the identification of the smallest cash generating unit to which those assets are allocated.

The Israel development is one CGU, all the production from both the Karish Main and Karish North fields is processed through the FPSO and flows through one pipeline onto gas buyers and therefor there are no separate cash inflows.

NOTE 4: -     Critical accounting estimates and judgments (Cont.)

2.         Estimation uncertainty:

The estimates and assumptions that have a significant risk of causing a material adjustment to the carrying amounts of assets and liabilities, are discussed below:

Carrying value of property, plant and equipment (note 10):

The Group assesses impairment at each reporting date by evaluating conditions specific to the Group that may lead to impairment of assets. Where an indicator of impairment exists, the recoverable amount (which is the higher of fair value less costs to sell and value in use) of the cash-generating unit to which the assets belong is then estimated based on the present value of future discounted cash flows.

For oil and gas assets, the expected future cash flow estimation is based on a number of factors, variables and assumptions, the most important of which are estimates of reserves, future production profiles, oil prices and costs. In most cases, the present value of future cash flows is most sensitive to estimates of future oil and gas price, estimates of reserves, estimates of development costs and discount rates.

A change in the assumptions could materially change the recoverable amount. In the event that future circumstances vary from these assumptions, the recoverable amount of the Group's development and production assets could change materially and result in impairment losses or the reversal of previous impairment losses.

Hydrocarbon reserve and resource estimates (Note 10, 11, 12 and 17):

The Company's oil and gas development and production properties are depreciated on a unit of production basis at a rate calculated by reference to developed and undeveloped proved and probable commercial reserves (2P developed and undeveloped) which are estimated to be recoverable with existing and future developed facilities using current operating methods, determined in accordance with the Petroleum Resources Management System published by the Society of Petroleum Engineers, the World Petroleum Congress and the American Association of Petroleum Geologists.
Commercial reserves are determined using estimates of oil and gas in place, recovery factors and future oil prices. The level of estimated commercial reserves is also a key determinant in assessing whether the carrying value of any of the Company's oil and gas properties has been impaired. As the economic assumptions used may change and as additional geological information is produced during the operation of a field, estimates of recoverable reserves may change.

Such changes may impact the Company's reported financial position and results which include:

•      Depreciation and amortisation charges in profit or loss may change where such charges are determined using the units of production method, or where the useful life of the related assets change.

•      Impairment charges in the income statement

•      Provisions for decommissioning may change - where changes to the reserve estimates affect expectations about when such activities will occur and the associated cost of these activities.

•      The recognition and carrying value of deferred tax assets may change due to changes in the judgements regarding the existence of such assets and in estimates of the likely recovery of such assets

Decommissioning liabilities (Note 17):

There is uncertainty around the cost of decommissioning as cost estimates can vary in response to many factors, including from changes to market rates for goods and services, to the relevant legal requirements, the emergence of new technology or experience at other assets. The expected timing, work scope, amount of expenditure, discount and inflation rates may also require estimation. Therefore, significant estimates and assumptions are made in determining the provision for decommissioning. The discount rate applied to determine the carrying amount of provisions provides a source of estimation uncertainty as referred to in IAS 1.

The estimated decommissioning costs are reviewed annually by management and the results of this review are then assessed alongside estimates from operators. Provision for environmental cleanup and remediation costs is based on current legal and contractual requirements, technology and price levels. Discount rate applied is reviewed regularly and adjusted following the changes in market rates.

 

NOTE 4: -     Critical accounting estimates and judgments (Cont.)

The Group considers the impact of climate change on environmental restoration and decommissioning provisions, specifically the timing of future cash flows, and has concluded that it does not currently represent a key source of estimation uncertainty. Changes to legislation, including in relation to climate change, are factored into the provisions when the legislation becomes enacted.

 

Deferred taxes (Note 12):

The Group has recognised deferred tax assets in respect of losses and other temporary differences to the extent that it is probable that there will be future taxable profits against which the losses and other temporary differences can be utilised. The Group has considered their carrying value at each balance sheet date and concluded that based on management's estimates, sufficient taxable profits will be generated in future years to recover such recognised deferred tax assets. These estimates are based on forecast performance. The management regards the deferred tax asset in relation to tax losses and other temporary differences as recoverable, despite the loss-making situation that currently exists, based on its best estimate of future sources of taxable income.

 

NOTE 5: -     Revenues

		2023 $'000		2022 $'000
Revenue from gas sales (1)		679,410		45,153
Revenue from hydrocarbon liquids sales (2)		265,355		-
Compensation to customers (3)		(4,929)		(18,031)
Total revenue		939,836		27,122

⁽¹) Sales gas for 2023 totaled approximately (4.4 bcm) and between 26 October 2022 and 31 December 2022 totaled approximately   0.28 bcm.

⁽²⁾ Sales from hydrocarbon liquids for 2023 totaled approximately 3.492 mmbbl (the Company did not sell hydrocarbon liquids during 2022).

⁽³⁾ During 2021 and in accordance with the GSPAs signed with a group of gas buyers, the Company paid compensation to these counterparties following delays to the supply of gas from the Karish project. The compensation is deducted from revenue, as variable consideration, as the gas is delivered to the gas buyers, in accordance with IFRS 15 Revenue Recognition.

 

 

 

 

NOTE 6: -     Operating profit (loss) before taxation

		2023 $'000		2022 $'000
(a)   Cost of sales
Staff costs (Note 7)		9,766		1,174
Energy cost		3,652		1,030
Royalty payable (Note 21 (e))		167,179		8,128
Depreciation (Note 10)		185,884		10,976
Other operating costs (4)		76,997		12,440
Oil stock movement (Note 14)		576		(2,731)
Total cost of sales		444,054		31,017
(b)   General & administration expenses
Staff costs (Note 7)		3,163		2,121
Share-based payment charge (note 20)		730		214
Depreciation and amortisation  (Note  10, 11)		1,837		459
Auditor fees (3)		356		254
Other general & administration expenses (2)		8,253		9,204
Total administrative expenses		14,339		12,252
(c)    Exploration and evaluation expenses
Exploration costs written off (1)		-		1,518
Other exploration and evaluation expenses		50		301
Total exploration and evaluation expenses		50		1,819
(d)   Other expenses
Loss from disposal of property, plant and equipment		190		1,102
Total other expenses		190		1,102
(e)   Other income
Other income		37		54
Total other income		37		54

⁽¹⁾ Zone D: On 27 July 2022, the Company sent a formal notice to the Ministry of Energy notifying relinquishment of Zone D and discontinuation of related work. As such, the licences subsequently expired on 27 October 2022. Capitalised costs associated with Zone D were written off during 2022 (Note 11).

⁽²⁾ The Other general & administration expenses mainly consists of legal expenses, intercompany management fees and external advisors fees.

⁽³⁾ In addition to the services outlined in the preceding table, the Company's auditor also rendered services related to the senior secured notes issuance in 2023. These services were capitalized as transaction costs.

⁽⁴⁾ Other operating costs comprise of insurance costs and planned maintenance costs.

 

 

 

 

 

 

NOTE 7: -     Staff costs

The average monthly number of employees employed by the Group was:

				2023 $'000			2022 $'000
Average number of employees		98				70

 

					2023 $'000					2022 $'000
Wages and salaries			9,500				6,961
Bonuses		963							538
Expenses related to pension plans		2,699							1.396
Social insurance costs and other funds			906				575
Other staff costs		908							455
Share-based payments			730				410
Payroll Cost capitalised in oil & gas assets		(1,809)							(6,826)
Payroll Cost capitalised in intangible assets			(238)				-
			13,659				3,509
Total payroll cost in cost of sales			9,766				1,174
Total payroll cost in administration expenses			3,893				2,335
Total payroll cost			13,659				3,509

 

NOTE 8: -     Net finance income/(expenses)

		2023 $'000		2022 $'000
Interest on Senior Secured Notes (Note 16)		161,918		136,412
Interest expense on long terms payables (Note 18(2))		7,159		14,660
Less amounts included in the cost of qualifying assets (Note 10(A))		(17,415)		(123,634)
		151,662		27,438
Finance and arrangement fees		3,855		4,713
Other finance costs and bank charges		1,403		1,118
Unwinding of discount on trade payable (Note 18(3))		8,753		-
Unwinding of discount on provision for decommissioning (Note 17)		3,401		1,230
Unwinding of discount on right of use asset (1)		636		1,035
Less amounts included in the cost of qualifying assets (Note 10(A))		(243)		(5,723)
		17,805		2,373
Total finance costs		169,467		29,811
Interest income from time deposits		11,319		3,165
Interest income from loans to related parties (Note 22(E)(3))		-		3,214
Total finance income		11,319		6,379
Net foreign exchange losses		(8,483)		(3,087)
Net finance costs		(166,631)		(26,519)

 

NOTE 9: -     Taxation

1.      Corporate Tax rates applicable to the Company:

Israel:

The Israeli corporate tax rate is 23% in 2023 and 2022.

Cyprus:

For its activity in Cyprus, the Company is subject to corporation tax on its taxable profits at the rate of 12.5%.

Starting from 1 January 2024, the company's control and management shall be transferred from the Republic of Cyprus ("Cyprus") to the United Kingdom ("UK") and as such the company's tax residency will be migrated from Cyprus to UK. See Note 24.

2.      The Income and Natural Resources Taxation Law, 5771-2011 - Israel- the main provisions of the law are as follows:

In April 2011, the Knesset passed the Income and Natural Resources Tax Law, 5771-2011 ("the Law"). The imposition of an oil and gas profits levy at a rate to be set as set out below. The rate of the levy will be calculated according to a proposed R factor mechanism, according to the ratio between the net accrued revenues from the project and the cumulative investments as defined in the law. A minimum levy of 20% will be levied at the stage where the R factor ratio reaches 1.5, and when the ratio increases, the levy will increase gradually until the maximum rate of 50% until the ratio reaches 2.3. In addition, it was determined that the rate of the levy as stated will be reduced starting in 2017 by multiplying 0.64 by the difference between the corporate tax rate prescribed in section 126 of the Income Tax Ordinance for each tax year and the tax rate of 18%. In accordance with the corporate tax rate from 2018 onwards, the maximum rate will be 46.8%.

In addition, additional provisions were prescribed regarding the levy, inter alia, the levy will be recognised as an expense for the purpose of calculating income tax; The limits of the levy shall not include export facilities; The levy will be calculated and imposed for each reservoir separately (Ring Fencing); Payment by the owner of an oil right calculated as a percentage of the oil produced, the recipient of the payment will be liable to pay a levy according to the amount of the payment received, and this amount will be subtracted from the amount of the levy owed by the holder of the oil right. The law also sets rules for the unification or separation or consolidation of oil projects for the purposes of the Law. In accordance with the provisions of the Law, the Group is not yet required to pay any payment in respect of the said levy, and therefore no liability has been recognised in the financial statements in respect of this payment.

 

3.      Taxation charge:

		2023 $'000	2022 $'000
Current income tax charge		(1,929)	(360)
Deferred tax relating to origination and reversal of temporary differences (Note 12)		(69,871)	11,311
Total taxation income (expense)		(71,800)	10,951

 

 

 

NOTE 9: -       Taxation (Cont.)

4.      Reconciliation of the total tax charge:

The reconciliation between the tax expense, assuming that all the income, expenses, gains and losses in profit or loss were taxed at the statutory tax rate of Israel and the taxes on income recorded in profit or loss is as follows:

		2023 $'000			2022 $'000
Profit (loss) before tax		314,609			(45,533)
Tax credit at the applicable tax rates of 23% (1)		(72,360)			10,473
Impact of different tax rates (2)		8			331
Temporary differences in respect of different tax recognition, resulting in timing differences		764			-
Permanent differences - non deductible (3)		(174)			(137)
Permanent differences additional expenses for Cyprus tax (4)		-			314
Other adjustments		(38)			(19)
Taxation income		(71,800)			10,962
Effective tax rate		23%			24%

¹⁾      For the reconciliation of the effective tax rate, the statutory tax rate of the Israeli Branch of 23% has been used.

²⁾      Energean Israel Limited (Cyprus) is subject to corporation tax rate of 12.5%.

³⁾      Permanent differences consisted of non-deductible expenses with the majority derived from the Israeli Branch and, inter alia, related to refreshments, accommodation, donations and travelling.

⁴⁾      The Cypriot Income Tax Law (ITL) provides for a notional interest deduction (NID) from the taxable profits of entities financing their operations through new equity. In view of this, the Company proceeded with the relevant calculation regarding the new equity used to finance asset.

 

 

NOTE 10: -   Property, Plant and Equipment  

a.          Composition:

		Oil and gas Assets $'000		Leased assets $'000		Furniture, fixtures and equipment $'000		Total $'000
Cost:
At 1 January 2022		2,241,783		4,009		829		2,246,621
Additions		514,373		731		1,165		516,269
Disposals		(900)		-		-		(900)
Capitalised borrowing cost		129,357		-		-		129,357
Capitalised depreciation		632		-		-		632
Change in decommissioning provision		47,544		-		-		47,544
Total cost at 31 December 2022		2,932,789		4,740		1,994		2,939,523
Additions		135,126		12,246		396		147,768
Handover to INGL(1)		(111,448)		-		-		(111,448)
Capitalised borrowing cost		17,658		-		-		17,658
Change in decommissioning provision		4,913		-		-		4,913
Total cost at 31 December 2023		2,979,038		16,986		2,390		2,998,414
Depreciation:
At 1 January 2022		433		693		228		1,354
Charge for the year		10,976		134		297		11,407
Capitalised to petroleum and gas assets		-		632		-		632
Disposals		(433)		-		-		(433)
Write down of the assets		250		-		-		250
Total Depreciation at 31 December 2022		11,226		1,459		525		13,210
Charge for the year		183,898		2,966		509		187,373
Total Depreciation at 31 December 2023		195,124		4,425		1,034		200,583
At 31 December 2022		2,921,563		3,281		1,469		2,926,313
At 31 December 2023		2,783,914		12,561		1,356		2,797,831

The additions to oil & gas assets in 2023 are primarily due to development costs for the FPSO, Karish North and 2^nd Oil Train. The additions in 2022 are primarily due to development costs for the Karish field, incurred under the EPCIC contract, FPSO, subsea and onshore construction.

⁽¹⁾ Handover to INGL took place on 22 March 2023, please refer to Note 18(4).

b.         Depreciation expense for the year has been recognised as follows:

	2023 $'000		2022 $'000
Cost of sales	185,884		10,976
Administration expenses	1,489		431
Capitalised depreciation in oil & gas assets	-		632
Total	187,373		12,039

NOTE 10: -   Property, Plant and Equipment  (Cont.)

c.          Cash flow statement reconciliations:

				2023 $'000		2022 $'000
Additions and disposals to property, plant and equipment, net			58,891		692,902
Associated cash flows
Payments and receipts for additions to property, plant and equipment, net			(156,414)		(278,396)
Non-cash movements/presented in other cash flow lines
Capitalised borrowing costs			(17,658)		(129,357)
Right-of-use asset additions			(12,246)		(731)
INGL hand over			111,448		-
Capitalised share-based payment charge			-		(196)
Capitalised depreciation			-		(632)
Change in decommissioning provision			(4,913)		(47,544)
Lease payments related to capital activities			3,321		1,085
Movement in working capital			17,571		(237,131)

d.         Details of the Group's rights in petroleum and gas assets are presented in note 1.

NOTE 11: -   Intangible Assets

a.          Composition:

		Exploration and evaluation assets $'000		Software licences $'000		Total $'000
Cost:
At 1 January 2022		20,141		255		20,396
Additions		123,005		1,713		124,718
Write off of exploration and evaluation costs (1)		(1,277)		-		(1,277)
At 1 January 2023		141,869		1,968		143,837
Additions		24,597		362		24,959
At 31 December 2023		166,466		2,330		168,796
Amortisation:
At 1 January 2022		-		255		255
Charge for the year		-		28		28
Total Amortisation at 31 December 2022		-		283		283
Charge for the year		-		348		348
Total Amortisation at 31 December 2023		-		631		631
At 31 December 2022		141,869		1,685		143,554
At 31 December 2023		166,466		1,699		168,165

Additions to exploration and evaluation assets are primarily related to the growth drilling programme undertaken offshore Israel and related to Katlan.

NOTE 11: -   Intangible Assets (Cont.)

Block 12 ("Katlan") offshore Israel - Gas Discovery:

During 2022 the Company's growth drilling programme discovered gas in Block 12, offshore Israel.  Successful exploration wells were drilled into the Athena and Zeus prospects, resulting in the award of 2P reserves by Energean's reserve auditor, D&M. The Hera prospect shared sufficient geological and seismic attributes to also be classified as 2P reserves. As a result, and in accordance with the Company's Competent Person's Report ("CPR") as of 31 December 2023, Block 12 is estimated to contain 2P reserves of 31.9 bcm and 5.4 mmboe of hydrocarbon liquids. Energean expects to take FID upon the finalisation of EPC ("Engineering, Procurement and Construction") terms, which are currently under negotiation.

⁽¹⁾  Zone D: On 27 July 2022, the Company sent a formal notice to the Ministry of Energy notifying the relinquishment of Zone D and discontinuation of related work. As such, the licences subsequently expired on 27 October 2022.

 

b.         Cash flow statement reconciliations:

		2023 $'000		2022 $'000
Additions to intangible assets		24,959		123,441
Associated cash flows
Payment for additions to intangible assets		(98,909)		(50,332)
Non-cash movements/presented in other cash flow lines
Write off of exploration and evaluation costs		-		1,277
Movement in working capital		73,950		(74,386)

 

c.          Details on the Group's rights in the intangible assets:

Right	Type of right	Valid date of the right	Group's interest as at 31 December 2023
Block 12	Licence	13 January 2025	100%
Block 21	Licence	13 January 2025	100%
Block 23	Licence	13 January 2025	100%
Block 31	Licence	13 January 2025	100%

d.         Additional information regarding the Exploration and Evaluation assets:

As of 31 December 2023, the Group held four licences to explore for gas and oil in Block 12, Block 21, Block 23 and Block 31, which are located in the economic waters of the State of Israel. On January 2024 the licences were extended until 13 January 2025, and they may be extended for a further one year.

NOTE 12: -   Deferred taxes

The Group is subject to corporation tax on its taxable profits in Israel at the rate of 23%. The Capital Gain Tax rates depends on the purchase date and the nature of asset. The general capital tax rate for a corporation is the standard corporate tax rate.

Tax losses can be utilised for an unlimited period, and tax losses may not be carried back.

According to Income Tax (Deductions from Income of Oil Rights Holders) Regulations, 5716-1956, the exploration and evaluation expenses of oil and gas assets are deductible in the year in which they are incurred.

The Group expects that there will be sufficient taxable profit in the following years and that deferred tax assets, recognised in the consolidated financial statements of the Group, will be recovered.