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Notes for this page
Refers to US dollars unless specified otherwise
- <1 year
Less than 1 year
- >1 year
Greater than 1 year
Proven and probable
An entity in which the Group has an equity interest and over which it has the ability to exercise significant influence
Certified emissions reduction (carbon emissions certificate)
Carbon emissions reduction target
Cash generating unit
Consumer Price Index
Earnings before interest, tax, depreciation and amortisation
European Union allowance (carbon emissions certificate)
Financial Services Authority
- FTSE 100
Financial Times Stock Exchange 100 share index, an average of share prices in the 100 largest, most actively traded companies on the London Stock Exchange
Fair value less costs to sell
- g CO2/kWh
Grammes of carbon dioxide per kilowatt hour
Group Financial Risk Management Committee
- IAS 19
The International Accounting Standard related to Employee Benefits. These financial reporting rules include requirements related to pension accounting
- IAS 39
The International Accounting Standard related to financial instruments (recognition & measurement)
International Financial Reporting Standard
- Jointly controlled entity
A joint venture which involves the establishment of an entity to engage in economic activity, which the Group controls jointly with its fellow venturers
- Level 1
Fair value is determined using observable inputs that reflect unadjusted quoted market prices for identical assets and liabilities, for example exchange-traded commodity contracts valued using close-of-day settlement prices. The adjusted market price used for financial assets held by the Group is the current bid price
- Level 2
Fair value is determined using significant inputs that may be either directly observable inputs or unobservable inputs that are corroborated by market data, for example over-the-counter energy contracts within the active period valued using broker-quotes or third-party pricing services and foreign exchange or interest rate derivatives valued using market-based data
- Level 3
Fair value is determined using significant unobservable inputs that are not corroborated by market data and may be used with internally developed methodologies that result in management's best estimate of fair value, for example energy contracts within the inactive period valued using in-house valuation techniques
Liquefied natural gas
Comprised of Treasury gilts designated at fair value through profit or loss on initial recognition and available-for-sale financial assets. The fair values of securities are based on quoted market prices, when available. If quoted market prices are not available, fair values are estimated using observable market data
Supplementary charge associated with UK Corporation Tax
- Spark spread
The difference between the price of a unit of electricity and the cost of the gas used to generate it
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Notes to the Financial Statements
S1. General information
Centrica plc is a Company domiciled and incorporated in the UK. The address of the registered office is given in the Corporate Governance Report. The nature of the Group's operations and principal activities are set out in note S5 and in the Directors' Report – Business Review.
The consolidated Financial Statements of Centrica plc are presented in pounds sterling. Operations and transactions conducted in currencies other than pounds sterling are included in the consolidated Financial Statements in accordance with the foreign currencies accounting policy set out in note S2.
S2. Summary of significant accounting policies
Income Statement presentation
The Group's Income Statement and segmental note separately identify the effects of re-measurement of certain financial instruments, and items which are exceptional, in order to provide readers with a clear and consistent presentation of the Group's underlying performance, as described below.
(i) Certain re-measurements
As part of its energy procurement activities, the Group enters into a range of commodity contracts designed to achieve security of energy supply. These contracts comprise both purchases and sales and cover a wide range of volumes, prices and timescales. The majority of the underlying supply comes from high-volume, long-term contracts which are complemented by short-term arrangements. These short-term contracts are entered into for the purpose of balancing energy supplies and customer demand and to optimise the price paid by the Group. Short-term demand can vary significantly as a result of factors such as weather, power generation profiles and short-term movements in market prices.
Many of the energy procurement contracts are held for the purpose of receipt or delivery of commodities in accordance with the Group's purchase, sale or usage requirements and are therefore out of scope of IAS 39. However, a number of contracts are considered to be derivative financial instruments and are required to be fair valued under IAS 39, primarily because their terms include the ability to trade elements of the contracted volumes on a net-settled basis.
The Group has shown the fair value adjustments arising on these contracts separately in the certain re-measurements column. This is because the intention of management is, subject to short-term demand balancing, to use these energy supplies to meet customer demand. Accordingly, management believes the ultimate net charge to cost of sales will be consistent with the price of energy agreed in these contracts and that the fair value adjustments will reverse as the energy is supplied over the life of the contract. This makes the fair value re-measurements very different in nature from costs arising from the physical delivery of energy in the year.
At the balance sheet date the fair value represents the difference between the prices agreed in the respective contracts and the actual or anticipated market price of acquiring the same amount of energy on the open market. The movement in the fair value taken to certain re-measurements in the Income Statement represents the unwinding of the contracted volume delivered or consumed during the year, combined with the change in fair value of future contracted energy as a result of movements in forward energy prices during the year.
As an integrated energy business, the Group also enter into a range of commodity contracts designed to secure the value of its underlying production, generation, storage and transportation assets. The fair value movements on these contracts are also shown separately in the certain re-measurements column. This is because the fair value movements on these contracts are not matched with fair value movements of the underlying assets, since not all the underlying assets are fair valued.
These adjustments represent the significant majority of the items included in certain re-measurements.
In addition to these, however, the Group has identified a number of comparable contractual arrangements where the difference between the price which the Group expects to pay or receive under a contract and the market price is required to be fair valued by IAS 39. These additional items relate to cross-border transportation or transmission capacity, storage capacity and contracts relating to the sale of energy by-products, on which economic value has been created which is not wholly recognised under the requirements of IAS 39. For these arrangements the related fair value adjustments are also included under certain re-measurements.
These arrangements are managed separately from proprietary energy trading activities where trades are entered into speculatively for the purpose of making profits in their own right. These proprietary trades are included in the results before certain re-measurements.
In addition, certain re-measurements include the effects of unwinding the acquisition-date fair values attributable to forward energy procurement and energy sales contracts arising on the acquisition of Strategic Investments, as described in note 2. The Group has shown the effect of unwinding the acquisition-date fair values attributable to forward energy procurement and energy sales contracts for these investments separately as a certain re-measurement as the intention is to use these energy supplies in the normal course of business and management believes the ultimate net charge reflected before the unwind of acquisition-date fair values will be consistent with the price of energy agreed within these contracts. Such presentation is consistent with the internal performance measures used by the Group.
(ii) Exceptional items
As permitted by IAS 1 (Revised), Presentation of Financial Statements, certain items are presented separately. The items that the Group separately presents as exceptional are items which are of a non-recurring nature and, in the judgement of the Directors, need to be disclosed separately by virtue of their nature, size or incidence in order to obtain a clear and consistent presentation of the Group's underlying business performance.
Basis of consolidation
The Group Financial Statements consolidate the Financial Statements of the Company and entities controlled by the Company (its subsidiaries) up to 31 December each year, and incorporate the results of its share of jointly controlled entities and associates using the equity method of accounting.
Control is achieved where the Company has the power to govern the financial and operating policies of an investee entity so as to obtain benefits from its activities.
The results of subsidiaries acquired or disposed of during the year are consolidated from the effective date of acquisition or up to the effective date of disposal, as appropriate. Where necessary, adjustments are made to the Financial Statements of subsidiaries, associates and jointly-controlled entities to bring the accounting policies used into line with those used by the Group.
When the Group ceases to have control or significant influence, any retained interest in the entity is re-measured to its fair value with the change in carrying amount recognised in profit or loss. This fair value becomes the initial carrying amount for the purposes of subsequently accounting for the retained interest as a joint venture, associate or financial asset.
The Group's operating segments are reported in a manner consistent with the internal reporting provided to and regularly reviewed by the Group's Executive Committee for the purposes of evaluating segment performance and allocating resources.
Revenue is recognised to the extent that it is probable that the economic benefits will flow to the Group and the revenue can be measured reliably. Revenue includes amounts receivable for goods and services provided in the normal course of business, net of discounts, rebates, VAT and other sales-related taxes.
Energy supply: Revenue is recognised on the basis of energy supplied during the year. Revenue for energy supply activities includes an assessment of energy supplied to customers between the date of the last meter reading and the year end (unread). Unread gas and electricity is estimated using historical consumption patterns, taking into account the industry reconciliation process for total gas and total electricity usage by supplier, and is included in accrued energy income within trade and other receivables.
Proprietary energy trading: Revenue comprises both realised (settled) and unrealised (fair value changes) net gains and losses from trading in physical and financial energy contracts.
Fixed-fee service and insurance contracts: Revenue from these contracts is recognised in the Income Statement with regard to the incidence of risk over the life of the contract, reflecting the seasonal propensity of claims to be made under the contracts and the benefits receivable by the customer, which span the life of the contract as a result of emergency maintenance being available throughout the contract term.
Amounts paid in advance greater than recognised revenue are treated as deferred income, with any paid in arrears recognised as accrued income. For one-off services, such as installations, revenue is recognised at the date of service provision.
Storage services: Storage capacity revenues are recognised evenly over the contract period, whilst commodity revenues for the injection and withdrawal of gas are recognised at the point of gas flowing into or out of the storage facilities. Gas purchases and gas sales transactions entered into to optimise the performance of the gas storage facilities are presented net within revenue.
Upstream production: Revenue associated with exploration and production sales (of natural gas, crude oil and condensates) is recognised when title passes to the customer. Revenue from the production of natural gas, oil and condensates in which the Group has an interest with other producers is recognised based on the Group's working interest and the terms of the relevant production sharing arrangements (the entitlement method). Where differences arise between production sold and the Group's share of production, this is accounted for as an overlift or underlift (see separate accounting policy). Purchases and sales entered into to optimise the performance of production facilities are presented net within revenue.
Power generation: Revenue is recognised on the basis of power supplied during the period. Power purchases and sales entered into to optimise the performance of power generation facilities are presented net within revenue.
Interest income: Interest income is accrued on a time basis, by reference to the principal outstanding and at the effective interest rate applicable, which is the rate that exactly discounts estimated future cash receipts through the expected life of the financial asset to that asset's net carrying value.
Cost of sales
Energy supply includes the cost of gas and electricity produced and purchased during the year taking into account the industry reconciliation process for total gas and total electricity usage by supplier, and related transportation, distribution, royalty costs and bought-in materials and services.
Fixed-fee service and insurance contracts' cost of sales includes direct labour and related overheads on installation work, repairs and service contracts in the year.
Borrowing costs that arise in connection with the acquisition, construction or production of a qualifying asset are capitalised and subsequently amortised in line with the depreciation of the related asset. Borrowing costs are capitalised from the time of acquisition or from the beginning of construction or production until the point at which the qualifying asset is ready for use. Where a specific financing arrangement is in place, the specific borrowing rate for that arrangement is applied. For non-specific financing arrangements, a Group financing rate representative of the weighted average borrowing rate of the Group is used. Borrowing costs not arising in connection with the acquisition, construction or production of a qualifying asset are expensed.
Carbon Emissions Reduction Target programme and Communities Energy Savings Programme
UK-licensed energy suppliers are set a Carbon Emission Reduction Target ('CERT') by the Government which is proportional to the size of their customer base. The current CERT programme runs from April 2008 to December 2012. The CERT targets have been amended from April 2011, to include individual sub-targets related to insulation and non-insulation based carbon reductions. UK licensed energy suppliers and electricity generators are also required to contribute to the Communities Energy Saving Programme ('CESP') by the Government in proportion to the size of their customer base and also the amount of electricity they generate. The current CESP programme runs from October 2009 to December 2012.
The targets and contributions are subject to an annual adjustment throughout the programme period to take account of changes in their energy supplier's customer base and amount of electricity generated. Energy suppliers and generators can meet the target through expenditure on qualifying projects which give rise to carbon savings. The carbon savings can be transferred between suppliers and generators.
The Group charges the cost of the programmes to cost of sales with a provision recognised where there is a deficit of relevant credits held compared to the sub-target obligations accrued and capitalises the costs incurred in deriving carbon savings in excess of the annual targets or contribution as inventory. The inventory balance is valued at the lower of cost and net realisable value and may be used to meet the sub-target obligations in subsequent periods or sold to third parties. The inventory is carried on a first-in, first-out basis. The obligation for the programme period is allocated to reporting periods on a straight-line basis as adjusted by the annual determination process.
Employee share schemes
The Group operates a number of employee share schemes, detailed in the Remuneration Report and in notes 32 and S7, under which it makes equity-settled share-based payments to certain employees. Equity-settled share-based payments are measured at fair value at the date of grant (excluding the effect of non-market-based vesting conditions). The fair value determined at the grant date is expensed on a straight-line basis together with a corresponding increase in equity over the vesting period, based on the Group's estimate of the number of awards that will vest, and adjusted for the effect of non-market-based vesting conditions.
Fair value is measured using methods appropriate to each of the different schemes as follows:
|LTIS: EPS awards after 2005||Market value on the date of grant|
|LTIS: TSR awards after 2005||A Monte Carlo simulation to predict the total shareholder return performance|
|SAS and DMSS||Market value on the date of grant|
The consolidated Financial Statements are presented in pounds sterling, which is the functional currency of the Company and the Group's presentation currency. Each entity in the Group determines its own functional currency and items included in the Financial Statements of each entity are measured using that functional currency. Transactions in foreign currencies are, on initial recognition, recorded at the functional currency rate ruling at the date of the transaction. Monetary assets and liabilities denominated in foreign currencies are retranslated at the functional currency rate of exchange ruling at the balance sheet date. All differences are included in the Income Statement for the period with the exception of exchange differences on foreign currency borrowings that provide a hedge against a net investment in a foreign entity. These are taken directly to equity until the disposal or partial disposal of the net investment, at which time they are recognised in the Income Statement.
Non-monetary items that are measured in terms of historical cost in a currency other than the functional currency of the entity concerned are translated using the exchange rates as at the dates of the initial transactions.
For the purpose of presenting consolidated Financial Statements, the assets and liabilities of the Group's foreign subsidiary undertakings, jointly controlled entities and associates are translated into pounds sterling at exchange rates prevailing on the balance sheet date. The results of foreign subsidiary undertakings, jointly controlled entities and associates are translated into pounds sterling at average rates of exchange for the relevant period.
Exchange differences arising from the retranslation of the opening net assets and the results are transferred to the Group's foreign currency translation reserve, a separate component of equity, and are reported in the Statement of Comprehensive Income. In the event of the disposal of an undertaking with assets and liabilities denominated in a foreign currency, the cumulative translation difference arising in the foreign currency translation reserve is charged or credited to the Income Statement on disposal.
Exchange differences on foreign currency borrowings, foreign currency swaps and forward exchange contracts used to hedge foreign currency net investments in foreign subsidiary undertakings, jointly controlled entities and associates are taken directly to reserves and are reported in the Statement of Comprehensive Income. All other exchange movements are recognised in the Income Statement for the year.
Business combinations and goodwill
The acquisition of subsidiaries is accounted for using the purchase method. The cost of the acquisition is measured as the cash paid and the aggregate of the fair values, at the date of exchange, of other assets transferred, liabilities incurred or assumed, and equity instruments issued by the Group in exchange for control of the acquiree. The acquiree's identifiable assets, liabilities and contingent liabilities that meet the conditions for recognition under IFRS 3 (Revised), Business Combinations, are recognised at their fair value at the acquisition date, except for non-current assets (or disposal groups) that are classified as held for resale in accordance with IFRS 5, Non-Current Assets Held for Sale and Discontinued Operations, which are recognised and measured at fair value less costs to sell.
Goodwill arising on a business combination represents the excess of the cost of acquisition over the Group's interest in the fair value of the identifiable assets and liabilities of a subsidiary, jointly controlled entity or associate at the date of acquisition. Goodwill is initially recognised as an asset at cost and is subsequently measured at cost less any accumulated impairment losses. If, after reassessment, the Group's interest in the net fair value of the acquiree's identifiable assets, liabilities and contingent liabilities exceeds the cost of the business combination, the excess is recognised immediately in the Income Statement.
On disposal of a subsidiary, associate or joint venture entity, any amounts of goodwill attributed to that entity is included in the determination of the profit or loss on disposal.
Other intangible assets
Intangible assets acquired separately are measured on initial recognition at cost. Intangible assets include emissions trading schemes, renewable obligation certificates, certain exploration and evaluation expenditures, brands and application software, the accounting policies for which are dealt with separately below. For purchased application software, for example investments in customer relationship management and billing systems, cost includes contractors' charges, materials, directly-attributable labour and directly-attributable overheads.
Capitalisation begins when expenditure for the asset is being incurred and activities necessary to prepare the asset for use are in progress. Capitalisation ceases when substantially all the activities that are necessary to prepare the asset for use are complete. Amortisation commences at the point of commercial deployment. The cost of intangible assets acquired in a business combination is their fair value as at the date of acquisition.
Following initial recognition, intangible assets are carried at cost less any accumulated amortisation and any accumulated impairment losses. The useful lives of intangible assets are assessed to be either finite or indefinite. Intangible assets with finite lives are amortised over their useful economic life and assessed for impairment whenever there is an indication that the intangible asset could be impaired. The amortisation period and the amortisation method for an intangible asset are reviewed at least at each financial year end. Changes in the expected useful life or the expected pattern of consumption of future economic benefits embodied in the asset are accounted for on a prospective basis by changing the amortisation period or method, as appropriate, and treated as changes in accounting estimates.
Intangible assets are derecognised on disposal, or when no future economic benefits are expected from their use.
Intangible assets with indefinite useful lives are tested for impairment annually, and whenever there is an indication that the intangible asset could be impaired, either individually or at the CGU level. Such intangibles are not amortised. The useful life of an intangible asset with an indefinite useful life is reviewed annually to determine whether the indefinite life assessment continues to be supportable. If not, the change in the useful life assessment from indefinite to finite is made on a prospective basis.
The amortisation period for the principal categories of intangible assets are as follows:
|Application software||up to 10 years|
|Licences||up to 20 years|
|Contractual customer relationships||up to 20 years|
|Strategic identifiable acquired brand||Indefinite|
EU Emissions Trading Scheme and renewable obligations certificates
Granted carbon dioxide emissions allowances received in a period are recognised initially at nominal value (nil value). Purchased carbon dioxide emissions allowances are recognised initially at cost (purchase price) within intangible assets. A liability is recognised when the level of emissions exceeds the level of allowances granted. The liability is measured at the cost of purchased allowances up to the level of purchased allowances held, and then at the market price of allowances ruling at the balance sheet date, with movements in the liability recognised in operating profit.
Forward contracts for the purchase or sale of carbon dioxide emissions allowances are measured at fair value with gains and losses arising from changes in fair value recognised in the Income Statement. The intangible asset is surrendered and the liability is utilised at the end of the compliance period to reflect the consumption of economic benefits.
Purchased renewable obligation certificates are recognised initially at cost within intangible assets. A liability for the renewables obligation is recognised based on the level of electricity supplied to customers, and is calculated in accordance with percentages set by the UK Government and the renewable obligation certificate buyout price for that period.
The intangible asset is surrendered and the liability is utilised at the end of the compliance period to reflect the consumption of economic benefits. Any recycling benefit related to the submission of renewable obligation certificates is recognised in the Income Statement when received.
Exploration, evaluation and production assets
Centrica uses the successful efforts method of accounting for exploration and evaluation expenditure. Exploration and evaluation expenditure associated with an exploration well, including acquisition costs related to exploration and evaluation activities, are capitalised initially as intangible assets. Certain expenditures such as geological and geophysical exploration costs are expensed. If the prospects are subsequently determined to be successful on completion of evaluation, the relevant expenditure including licence acquisition costs is transferred to PP&E and are subsequently depreciated on a unit of production basis. If the prospects are subsequently determined to be unsuccessful on completion of evaluation, the associated costs are expensed in the period in which that determination is made.
All field development costs are capitalised as PP&E. Such costs relate to the acquisition and installation of production facilities and include development drilling costs, project-related engineering and other technical services costs. PP&E, including rights and concessions related to production activities, are depreciated from the commencement of production in the fields concerned, using the unit of production method, based on all of the 2P reserves of those fields. Changes in these estimates are dealt with prospectively.
The net carrying value of fields in production and development is compared on a field-by-field basis with the likely discounted future net revenues to be derived from the remaining commercial reserves. An impairment loss is recognised where it is considered that recorded amounts are unlikely to be fully recovered from the net present value of future net revenues. Exploration and production assets are reviewed annually for indicators of impairment.
Interests in joint ventures
Under the equity method, investments in jointly controlled entities are carried at cost plus post-acquisition changes in the Group's share of net assets of the jointly controlled entity, less any impairment in value in individual investments. The Income Statement reflects the Group's share of the results of operations after tax of the jointly controlled entity.
Certain exploration and production activity is conducted through joint ventures, where the venturers have a direct interest in and jointly control the assets of the venture. The results, assets, liabilities and cash flows of these jointly controlled assets are included in the consolidated Financial Statements in proportion to the Group's interest.
Interests in associates
Under the equity method, investments in associates are carried at cost plus post-acquisition changes in the Group's share of the net assets of the associate, less any impairment in value in individual investments. The Income Statement reflects the Group's share of the results of the associate, which is net of interest and taxation and presents this as a single line item in arriving at Group operating profit on the face of the Income Statement.
Property, plant and equipment
PP&E is included in the Balance Sheet at cost, less accumulated depreciation and any provisions for impairment.
The initial cost of an asset comprises its purchase price or construction cost and any costs directly attributable to bringing the asset into operation. The purchase price or construction cost is the aggregate amount paid and the fair value of any other consideration given to acquire the asset.
Subsequent expenditure in respect of items of PP&E such as the replacement of major parts, major inspections or overhauls, are capitalised as part of the cost of the related asset where it is probable that future economic benefits will arise as a result of the expenditure and the cost can be reliably measured. All other subsequent expenditure, including the costs of day-to-day servicing, repairs and maintenance, is expensed as incurred.
Freehold land is not depreciated. Other PP&E, with the exception of upstream production assets (see below), are depreciated on a straight-line basis at rates sufficient to write off the cost, less estimated residual values, of individual assets over their estimated useful lives. The depreciation periods for the principal categories of assets are as follows:
|Freehold and leasehold buildings||up to 50 years|
|Plant||5 to 20 years|
|Power stations and wind farms||up to 30 years|
|Equipment and vehicles||3 to 10 years|
|Storage||up to 40 years|
Assets held under finance leases are depreciated over their expected useful economic lives on the same basis as for owned assets, or where shorter, the lease term.
The carrying values of PP&E are reviewed for impairment when events or changes in circumstances indicate that the carrying value may not be recoverable. Residual values and useful lives are reassessed annually and if necessary changes are accounted for prospectively.
Impairment of property, plant and equipment, intangible assets, investments in joint ventures and associates and goodwill
The Group reviews the carrying amounts of PP&E, intangible assets, interests in joint ventures and associates and goodwill annually, or more frequently if events or changes in circumstances indicate that the recoverable amounts may be lower than their carrying amounts. Where an asset does not generate cash flows that are independent from other assets, the Group estimates the recoverable amount of the CGU to which the asset belongs. The recoverable amount is the higher of value in use and fair value less costs to sell. At inception, goodwill is allocated to each of the Group's CGUs or groups of CGUs that expect to benefit from the business combination in which the goodwill arose. If the recoverable amount of an asset (or CGU) is estimated to be less than its carrying amount, the carrying amount of the asset (or CGU) is reduced to its recoverable amount. Any impairment is expensed immediately in the Income Statement. Any goodwill impairment loss is allocated first to reduce the carrying amount of any goodwill allocated to the CGU and then to the other assets of the unit pro rata on the basis of the carrying amount of each asset in the unit.
An impairment loss is reversed only if there has been a change in the estimate used to determine the asset's recoverable amount since the last impairment loss was recognised, with the exception of goodwill impairment which is never reversed. Where an impairment loss subsequently reverses, the carrying amount of the asset (or CGU) is increased to the revised estimate of its recoverable amount, but so that the increased carrying amount does not exceed the carrying amount that would have been determined had no impairment loss been recognised for the asset (or CGU) in prior years. A reversal of an impairment loss is recognised in the Income Statement immediately. After such a reversal the depreciation or amortisation charge, where relevant, is adjusted in future periods to allocate the asset's revised carrying amount, less any residual value, on a systematic basis over its remaining useful life.
Overlift and underlift
Offtake arrangements for oil and gas produced from jointly owned operations are often such that it is not practical for each participant to receive or sell its precise share of the overall production during the period. This results in short-term imbalances between cumulative production entitlement and cumulative sales, referred to as overlift and underlift.
An overlift payable, or underlift receivable, is recognised at the balance sheet date within Trade and other payables, or Trade and other receivables, respectively and measured at market value, with movements in the period recognised within cost of sales.
The determination of whether an arrangement is, or contains, a lease is based on the substance of the arrangement and requires an assessment of whether the fulfilment of the arrangement is dependent on the use of a specific asset or assets and whether the arrangement conveys a right to use the asset. Leases are classified as finance leases whenever the terms of the lease transfer substantially all the risks and rewards of ownership to the lessee. All other leases are classified as operating leases. Assets held under finance leases are capitalised and included in PP&E at their fair value, or if lower, at the present value of the minimum lease payments, each determined at the inception of the lease. The obligations relating to finance leases, net of finance charges in respect of future periods, are included within bank loans and other borrowings, with the amount payable within 12 months included in bank overdrafts and loans within current liabilities.
Lease payments are apportioned between finance charges and reduction of the finance lease obligation so as to achieve a constant rate of interest on the remaining balance of the liability. Finance charges are charged directly against income.
Payments under operating leases are charged to the Income Statement on a straight-line basis over the term of the relevant lease.
Inventories are valued on a weighted-average cost basis, with the exception of CERT inventory, and at the lower of cost and estimated net realisable value after allowance for redundant and slow-moving items.
Provision is made for the net present value of the estimated cost of decommissioning gas production facilities at the end of the producing lives of fields, and storage facilities and power stations at the end of the useful life of the facilities, based on price levels and technology at the balance sheet date.
When this provision gives access to future economic benefits, a decommissioning asset is recognised and included as part of the associated PP&E and depreciated accordingly. Changes in these estimates and changes to the discount rates are dealt with prospectively and reflected as an adjustment to the provision and corresponding decommissioning asset included within PP&E. The unwinding of the discount on the provision is included in the Income Statement within interest expense.
Non-current assets and disposal groups held for sale and discontinued operations
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. No depreciation is charged in respect of non-current assets classified as held for sale.
Non-current assets and disposal groups are classified as held for sale if their carrying amount will be recovered through a sale transaction rather than through continuing use. This condition is regarded as met only when the sale is highly probable and the asset (or disposal group) is available for immediate sale in its present condition. Management must be committed to the sale which should be expected to qualify for recognition as a completed sale within one year from the date of classification.
The profits or losses and cash flows that relate to a major component of the Group or geographical region that has been sold or is classified as held for sale are presented separately from continuing operations as discontinued operations within the Income Statement and Cash Flow Statement.
Pensions and other post-employment benefits
The Group operates a number of defined benefit pension schemes. The cost of providing benefits under the defined benefit schemes is determined separately for each scheme using the projected unit credit actuarial valuation method. Actuarial gains and losses are recognised in full in the period in which they occur. They are recognised in the Statement of Comprehensive Income.
The cost of providing retirement pensions and other benefits is charged to the Income Statement over the periods benefiting from employees' service. Past service cost is recognised immediately to the extent that the benefits are already vested, and otherwise is amortised on a straight-line basis over the average period until the benefits become vested. The difference between the expected return on scheme assets and the change in present value of scheme obligations resulting from the passage of time is recognised in the Income Statement within interest income or interest expense.
The retirement benefit obligation or asset recognised in the Balance Sheet represents the present value of the defined benefit obligation of the schemes as adjusted for unrecognised past service cost, and the fair value of the schemes' assets. The present value of the defined benefit obligation or asset is determined by discounting the estimated future cash outflows using interest rates of high-quality corporate bonds that are denominated in the currency in which the benefits are paid, and that have terms of maturity approximating to the terms of the related pension liability.
Payments to defined contribution retirement benefit schemes are charged as an operating expense as they fall due.
Provisions are recognised when the Group has a present obligation (legal or constructive) as a result of a past event, that can be measured reliably, and it is probable that the Group will be required to settle that obligation. Provisions are measured at the Directors' best estimate of the expenditure required to settle the obligation at the balance sheet date, and are discounted to present value where the effect is material. Where discounting is used, the increase in the provision due to the passage of time is recognised in the Income Statement within interest expense. Onerous contract provisions are recognised where the unavoidable costs of meeting the obligations under a contract exceed the economic benefits expected to be received under it. Contracts to purchase or sell energy are reviewed on a portfolio basis given the fungible nature of energy, whereby it is assumed that the highest priced purchase contract supplies the highest priced sales contract and the lowest priced sales contract is supplied by the lowest priced purchase contract.
Current tax, including UK corporation tax, UK petroleum revenue tax and foreign tax is provided at amounts expected to be paid (or recovered) using the tax rates and laws that have been enacted or substantively enacted by the balance sheet date.
Deferred tax is recognised in respect of all temporary differences identified at the balance sheet date, except to the extent that the deferred tax arises from the initial recognition of goodwill (if amortisation of goodwill is not deductible for tax purposes) or the initial recognition of an asset or liability in a transaction which is not a business combination and at the time of the transaction affects neither accounting profit nor taxable profit and loss. Temporary differences are differences between the carrying amount of the Group's assets and liabilities and their tax base.
Deferred tax liabilities may be offset against deferred tax assets within the same taxable entity or qualifying local tax group. Any remaining deferred tax asset is recognised only when, on the basis of all available evidence, it can be regarded as probable that there will be suitable taxable profits, within the same jurisdiction, in the foreseeable future, against which the deductible temporary difference can be utilised.
Deferred tax is provided on temporary differences arising on subsidiaries, jointly controlled entities and associates, except where the timing of the reversal of the temporary difference can be controlled and it is probable that the temporary difference will not reverse in the foreseeable future.
Deferred tax is measured at the average tax rates that are expected to apply in the periods in which the asset is realised or liability settled, based on tax rates and laws that have been enacted or substantively enacted by the balance sheet date. Measurement of deferred tax liabilities and assets reflects the tax consequences expected from the manner in which the asset or liability is recovered or settled.
Financial assets and financial liabilities are recognised in the Group Balance Sheet when the Group becomes a party to the contractual provisions of the instrument. Financial assets are de-recognised when the Group no longer has the rights to cash flows, the risks and rewards of ownership or control of the asset. Financial liabilities are de-recognised when the obligation under the liability is discharged, cancelled or expires.
(a) Trade receivables
Trade receivables are recognised and carried at original invoice amount less an allowance for any uncollectible amounts. Provision is made when there is objective evidence that the Group may not be able to collect the trade receivable. Balances are written off when recoverability is assessed as being remote. If collection is due in one year or less they are classified as current assets. If not they are presented as non-current assets.
(b) Trade payables
Trade payables are recognised at original invoice amount. If payment is due within one year or less they are classified as current liabilities. If not, they are presented as non-current liabilities.
(c) Share capital
Ordinary shares are classified as equity. Incremental costs directly attributable to the issue of new shares are shown in equity as a deduction from the proceeds received. Own equity instruments that are reacquired (treasury shares) are deducted from equity. No gain or loss is recognised in the Income Statement on the purchase, sale, issue or cancellation of the Group's own equity instruments.
(d) Cash and cash equivalents
Cash and cash equivalents comprise cash in hand and current balances with banks and similar institutions, which are readily convertible to known amounts of cash and which are subject to insignificant risk of changes in value and have an original maturity of three months or less.
For the purpose of the Group Cash Flow Statement, cash and cash equivalents consist of cash and cash equivalents as defined above, net of outstanding bank overdrafts.
(e) Interest-bearing loans and other borrowings
All interest-bearing loans and other borrowings are initially recognised at fair value net of directly attributable transaction costs. After initial recognition, interest-bearing loans and other borrowings are subsequently measured at amortised cost using the effective interest method, except when they are the hedged item in an effective fair value hedge relationship where the carrying value is also adjusted to reflect the fair value movements associated with the hedged risks. Such fair value movements are recognised in the Income Statement. Amortised cost is calculated by taking into account any issue costs, discount or premium.
(f) Available-for-sale financial assets
Available-for-sale financial assets are those non-derivative financial assets that are designated as available-for-sale, which are recognised initially at fair value within the Balance Sheet. Available-for-sale financial assets are re-measured subsequently at fair value with gains and losses arising from changes in fair value recognised directly in equity and presented in the Statement of Comprehensive Income, until the asset is disposed of or is determined to be impaired, at which time the cumulative gain or loss previously recognised in equity is included in the Income Statement for the period. Accrued interest or dividends arising on available-for-sale financial assets are recognised in the Income Statement.
At each balance sheet date the Group assesses whether there is objective evidence that available-for-sale financial assets are impaired. If any such evidence exists, cumulative losses recognised in equity are removed from equity and recognised in the Income Statement. The cumulative loss removed from equity represents the difference between the acquisition cost and current fair value, less any impairment loss on that financial asset previously recognised in the Income Statement.
Impairment losses recognised in the Income Statement for equity investments classified as available-for-sale are not subsequently reversed through the Income Statement. Impairment losses recognised in the Income Statement for debt instruments classified as available-for-sale are subsequently reversed if an increase in the fair value of the instrument can be objectively related to an event occurring after the recognition of the impairment loss.
(g) Financial assets at fair value through profit or loss
The Group holds investments in gilts which it designates as fair value through profit or loss. Investments are measured at fair value on initial recognition and are re-measured to fair value in each subsequent reporting period. Gains and losses arising from changes in fair value are recognised in the Income Statement within interest income or interest expense.
(h) Derivative financial instruments
The Group routinely enters into sale and purchase transactions for physical delivery of gas, power and oil. A portion of these transactions take the form of contracts that were entered into and continue to be held for the purpose of receipt or delivery of the physical commodity in accordance with the Group's expected sale, purchase or usage requirements, and are not within the scope of IAS 39.
Certain purchase and sales contracts for the physical delivery of gas, power and oil are within the scope of IAS 39 due to the fact that they net settle or contain written options. Such contracts are accounted for as derivatives under IAS 39 and are recognised in the Balance Sheet at fair value. Gains and losses arising from changes in fair value on derivatives that do not qualify for hedge accounting are taken directly to the Income Statement for the year.
The Group uses a range of derivatives for both trading and to hedge exposures to financial risks, such as interest rate, foreign exchange and energy price risks, arising in the normal course of business. The use of derivative financial instruments is governed by the Group's policies approved by the Board of Directors. Further detail on the Group's risk management policies is included within the Directors' Report – Governance and in note S3.
The accounting treatment for derivatives is dependent on whether they are entered into for trading or hedging purposes. A derivative instrument is considered to be used for hedging purposes when it alters the risk profile of an underlying exposure of the Group in line with the Group's risk management policies and is in accordance with established guidelines, which require the hedging relationship to be documented at its inception, ensure that the derivative is highly effective in achieving its objective, and require that its effectiveness can be reliably measured. The Group also holds derivatives which are not designated as hedges and are held for trading.
All derivatives are recognised at fair value on the date on which the derivative is entered into and are re-measured to fair value at each reporting date. Derivatives are carried as assets when the fair value is positive and as liabilities when the fair value is negative. Derivative assets and derivative liabilities are offset and presented on a net basis only when both a legal right of set-off exists and the intention to net settle the derivative contracts is present.
The Group enters into certain energy derivative contracts covering periods for which observable market data does not exist. The fair value of such derivatives is estimated by reference in part to published price quotations from active markets, to the extent that such observable market data exists, and in part by using valuation techniques, whose inputs include data which is not based on or derived from observable markets. Where the fair value at initial recognition for such contracts differs from the transaction price, a fair value gain or fair value loss will arise. This is referred to as a day-one gain or day-one loss. Such gains and losses are deferred and amortised to the Income Statement based on volumes purchased or delivered over the contractual period until such time observable market data becomes available. When observable market data becomes available, any remaining deferred day-one gains or losses are recognised within the Income Statement. Recognition of the gains or losses resulting from changes in fair value depends on the purpose for issuing or holding the derivative. For derivatives that do not qualify for hedge accounting, any gains or losses arising from changes in fair value are taken directly to the Income Statement and are included within gross profit or interest income and interest expense. Gains and losses arising on derivatives entered into for speculative energy trading purposes are presented on a net basis within revenue.
Embedded derivatives: Derivatives embedded in other financial instruments or other host contracts are treated as separate derivatives when their risks and characteristics are not closely related to those of the host contracts and the host contracts are not carried at fair value, with gains or losses reported in the Income Statement. The closely-related nature of embedded derivatives is reassessed when there is a change in the terms of the contract which significantly modifies the future cash flows under the contract. Where a contract contains one or more embedded derivatives, and providing that the embedded derivative significantly modifies the cash flows under the contract, the option to fair value the entire contract may be taken and the contract will be recognised at fair value with changes in fair value recognised in the Income Statement.
(i) Hedge accounting
For the purposes of hedge accounting, hedges are classified either as fair value hedges, cash flow hedges or hedges of net investments in foreign operations.
Fair value hedges: A derivative is classified as a fair value hedge when it hedges the exposure to changes in the fair value of a recognised asset or liability. Any gain or loss from re-measuring the hedging instrument to fair value is recognised immediately in the Income Statement. Any gain or loss on the hedged item attributable to the hedged risk is adjusted against the carrying amount of the hedged item and recognised in the Income Statement. The Group discontinues fair value hedge accounting if the hedging instrument expires or is sold, terminated or exercised, the hedge no longer qualifies for hedge accounting or the Group revokes the designation. Any adjustment to the carrying amount of a hedged financial instrument for which the effective interest method is used is amortised to the Income Statement. Amortisation may begin as soon as an adjustment exists and shall begin no later than when the hedged item ceases to be adjusted for changes in its fair value attributable to the risk being hedged.
Cash flow hedges: A derivative is classified as a cash flow hedge when it hedges exposure to variability in cash flows that is attributable to a particular risk either associated with a recognised asset, liability or a highly probable forecast transaction. The portion of the gain or loss on the hedging instrument which is effective is recognised directly in equity while any ineffectiveness is recognised in the Income Statement. The gains or losses that are recognised directly in equity are transferred to the Income Statement in the same period in which the highly probable forecast transaction affects income, for example when the future sale of physical gas or physical power actually occurs. Where the hedged item is the cost of a non-financial asset or liability, the amounts taken to equity are transferred to the initial carrying amount of the non-financial asset or liability on its recognition. Hedge accounting is discontinued when the hedging instrument expires or is sold, terminated or exercised without replacement or rollover, no longer qualifies for hedge accounting or the Group revokes the designation.
At that point in time, any cumulative gain or loss on the hedging instrument recognised in equity remains in equity until the highly probable forecast transaction occurs. If the transaction is no longer expected to occur, the cumulative gain or loss recognised in equity is recognised in the Income Statement.
Net investment hedges: Hedges of net investments in foreign operations are accounted for similarly to cash flow hedges. Any gain or loss on the effective portion of the hedge is recognised in equity, any gain or loss on the ineffective portion of the hedge is recognised in the Income Statement. On disposal of the foreign operation, the cumulative value of any gains or losses recognised directly in equity is transferred to the Income Statement.
The Group's investments in Lake Acquisitions Limited and NNB Holding Company Limited are accounted for as associates. The following accounting policies are specific to the accounting for the nuclear activity of these associates.
(a) Fuel costs – nuclear front end
Front end fuel costs consist of the costs of procurement of uranium, conversion and enrichment services and fuel element fabrication. All costs are capitalised into inventory and charged to the Income Statement in proportion to the amount of fuel burnt.
(b) Fuel costs – nuclear back end
Advanced Gas-cooled Reactors (AGR)
Spent fuel extracted from the reactors is sent for reprocessing and/or long-term storage and eventual disposal of resulting waste products. Back end fuel costs comprise a loading related cost per tonne of uranium and a rebate/surcharge to this cost dependent on the out-turn market electricity price in the year and are capitalised into inventory and charged to the Income Statement in proportion to the amount of fuel burnt.
Pressurised Water Reactor (PWR)
Back end fuel costs are based on wet storage in station ponds followed by dry storage and subsequent direct disposal of fuel. Back end fuel costs are capitalised into inventory on loading and charged to the Income Statement in proportion to the amount of fuel burnt.
(c) Nuclear property, plant and equipment and depreciation
The depreciation period for the nuclear fleet, which are depreciated on a straight-line basis from the date of the Group acquiring its share in British Energy, are as follows:
|Hinkley Point and Hunterston||2016|
|Heysham 1 and Hartlepool||2019|
|Heysham 2 and Torness||2023|
Expenditure on major inspection and overhauls of production plant is depreciated over the period until the next outage which for AGR power stations is two to three years and for the PWR power station is 18 months.
(d) Nuclear Liabilities Fund (NLF) funding arrangements
Under the arrangements in place with the Secretary of State, the NLF will fund, subject to certain exceptions, British Energy's qualifying uncontracted nuclear liabilities and qualifying decommissioning costs.
In part consideration for the assumption of these liabilities by the Secretary of State and the NLF, British Energy agreed to pay fixed decommissioning contributions each year and £150,000 (indexed to RPI) for every tonne of uranium in PWR fuel loaded into the Sizewell B reactor after the date of these arrangements.
(e) NLF and nuclear liabilities receivables
The Government indemnity is provided to indemnify any future shortfall on NLF funding of qualifying uncontracted nuclear liabilities (including PWR back end fuel services) and qualifying nuclear decommissioning costs such that the receivable equals the present value of the associated qualifying nuclear liabilities.
(f) Nuclear liabilities
Nuclear liabilities represent provision for British Energy's liabilities in respect of the costs of waste management of spent fuel and nuclear decommissioning.
(g) Unburnt fuels at shutdown
Due to the nature of the nuclear fuel process there will be quantities of unburnt fuel in the reactors at station closure. The costs relating to this unburnt fuel (final core) are estimated by applying a long-term inflation index to the projected costs, which are then discounted.
S3. Financial risk management
The Group's normal operating, investing and financing activities expose it to a variety of financial risks: market risk (including commodity price risk, volumetric risk, currency risk, interest rate risk and equity price risk), credit risk and liquidity risk. The Group's overall risk management process is designed to identify, manage and mitigate business risk, which includes, among others, financial risk. Further detail on the Group's overall risk management process is included within the Directors' Report – Governance.
Financial risk management is overseen by the Group Financial Risk Management Committee (GFRMC) according to objectives, targets and policies set by the Board. Commodity price risk management is carried out in accordance with individual business unit Financial Risk Management Committees and their respective financial risk management policies, as approved by the GFRMC under delegated authority from the Board. Treasury risk management, including management of currency risk, interest rate risk, equity price risk and liquidity risk is carried out by a central Group Treasury function in accordance with the Group's financing and treasury policy and collateral risk policy, as approved by the Board.
The wholesale credit risks associated with commodity trading and treasury positions are managed in accordance with the Group's credit risk policy. Downstream credit risk management is carried out in accordance with individual business unit credit policies.
Market risk management
Market risk is the risk of loss that results from changes in market prices (commodity prices, foreign exchange rates, interest rates and equity prices). The level of market risk to which the Group is exposed at a point in time varies depending on market conditions, expectations of future price or market rate movements and the composition of the Group's physical asset and contract portfolios.
(a) Commodity price risk management
The Group is exposed to commodity price risk in its upstream assets, energy procurement contracts, downstream and proprietary energy trading activities and uses specific limits to manage the exposure to commodity prices associated with the Group's activities to an acceptable level. Volumetric limits are supported by Profit at Risk (PaR) and Value at Risk (VaR) metrics in the UK and in North America to measure the Group's exposure to commodity price risk. Limits are also set on PaR and VaR measurements as a further control over exposure to market prices.
(i) Energy procurement, upstream and downstream activities
The Group's energy procurement, upstream and downstream activities consist of equity gas and liquids production, equity power generation, bilateral procurement and sales contracts, market-traded purchase and sales contracts and derivative positions taken on with the intent of securing gas and power for the Group's downstream customers in the UK and North America from a variety of sources at an optimal cost. The Group actively manages commodity price risk by optimising its asset and contract portfolios and making use of volume flexibility.
The Group is exposed to commodity price risk in its energy procurement, upstream and downstream activities because the cost of procuring gas and electricity to serve its downstream customers varies with wholesale commodity prices. The risk is primarily that market prices for commodities will fluctuate between the time that sales prices are fixed or tariffs are set and the time at which the corresponding procurement cost is fixed, thereby potentially reducing expected margins or making sales unprofitable.
The Group is also exposed to volumetric risk in the form of an uncertain consumption profile arising from a range of factors, including weather, energy consumption changes, customer attrition and economic climate.
In order to manage the exposure to market prices associated with the Group's energy procurement, upstream and downstream activities the Group uses a specific set of limits (including position, volumetric, VaR/PaR) established by the Executive Committee and governed by GFRMC oversight along with business unit market risk policies.
Volumetric limits are supported by PaR and VaR metrics in the UK and in North America to measure the Group's exposure to commodity price risk. Limits are also set on PaR and VaR measurements as a further control over exposure to market prices. PaR measures the estimated potential loss in a position or portfolio of positions associated with the movement of a commodity price for a given confidence level, over the remaining term of the position or contract portfolio. VaR measures the estimated potential loss for a given confidence level over a predetermined holding period. The standard confidence level used is 95%. In addition, stress tests are regularly performed to evaluate the impact of substantial movements in commodity prices.
The Group measures and manages the commodity price risk associated with the Group's entire energy procurement, upstream and downstream portfolio. Only certain of the Group's energy procurement, upstream and downstream contracts constitute financial instruments under IAS 39 (note 24).
As a result, while the Group manages the commodity price risk associated with both financial and non-financial energy procurement, upstream and downstream contracts, it is the notional value of energy contracts being carried at fair value that represents the exposure of the Group's energy procurement, upstream and downstream activities to commodity price risk according to IFRS 7, Financial Instruments: Disclosures. This is because energy contracts that are financial instruments under IAS 39 are accounted for on a fair value basis and changes in fair value immediately impact profit or equity. Conversely, energy contracts that are not financial instruments under IAS 39 are accounted for as executory contracts and changes in fair value do not immediately impact profit or equity, and as such, are not exposed to commodity price risk as defined by IFRS 7. So whilst the PaR or VaR associated with energy procurement and downstream contracts outside the scope of IAS 39 is monitored for internal risk management purposes, only those energy contracts within the scope of IAS 39 are within the scope of the IFRS 7 disclosure requirements.
(ii) Proprietary energy trading
The Group's proprietary energy trading activities consist of physical and financial commodity purchases and sales contracts taken on with the intent of benefiting in the short term from changes in market prices or differences between buying and selling prices. The Group conducts its trading activities in the over-the-counter market and through exchanges in the UK, North America and continental Europe. The Group is exposed to commodity price risk as a result of its proprietary energy trading activities because the value of its trading assets and liabilities will fluctuate with changes in market prices for commodities.
The Group sets volumetric and VaR limits to manage the commodity price risk exposure associated with the Group's proprietary energy trading activities. The VaR used measures the estimated potential loss for a 95% confidence level over a one-day holding period. The holding period used is based on market liquidity and the number of days the Group would expect it to take to close out a trading position. The VaR limits set for proprietary trading activities are relatively small compared to the Group's overall operations and are less than £5 million. The carrying value of energy contracts used in proprietary energy trading activities at 31 December 2011 is disclosed in note 24.
As with any modelled risk measure, there are certain limitations that arise from the assumptions used in the VaR analysis. VaR assumes that the future will behave like the past and that the Group's trading positions can be unwound or hedged within the predetermined holding period. Furthermore, the use of a 95% confidence level, by definition, does not take into account changes in value that might occur beyond this confidence level.
(b) Currency risk management
The Group is exposed to currency risk on foreign currency denominated forecast transactions, firm commitments, monetary assets and liabilities (transactional exposure) and on its net investments in foreign operations (translational exposure).
(i) Transactional currency risk
The Group is exposed to transactional currency risk on transactions denominated in currencies other than the underlying functional currency of the commercial operation transacting. The Group's primary functional currencies are pounds sterling in the UK, Canadian dollars in Canada, US dollars in the US, Norwegian kroner in Norway and euros in the Netherlands. The risk is that the functional currency value of cash flows will vary as a result of movements in exchange rates. Transactional exposure arises from the Group's energy procurement activities in the UK and in Canada, where a proportion of transactions are denominated in euros or US dollars and on certain capital commitments denominated in foreign currencies. In addition, in order to optimise the cost of funding, the Group has, in certain cases, issued foreign currency denominated debt, primarily in US dollars, New Zealand dollars, euros or Japanese yen.
(ii) Translational currency risk
The Group is exposed to translational currency risk as a result of its net investments in North America and Europe. The risk is that the pounds sterling value of the net assets of foreign operations will decrease with changes in foreign exchange rates. The Group's policy is to protect the pounds sterling book value of its net investments in foreign operations, subject to certain parameters monitored by the GFRMC, by holding foreign currency debt, entering into foreign currency derivatives, or a mixture of both.
The Group measures and manages the currency risk associated with all transactional and translational exposures. In contrast, IFRS 7 only requires disclosure of currency risk arising on financial instruments denominated in a currency other than the functional currency of the commercial operation transacting. As a result, for the purposes of IFRS 7, currency risk excludes the Group's net investments in North America and Europe as well as foreign currency denominated forecast transactions and firm commitments. A sensitivity analysis that is intended to illustrate the sensitivity of the Group's financial position and performance to changes in the fair value or future cash flows of foreign currency denominated financial instruments as a result of changes in foreign exchange rates is provided in note 25.
(c) Interest rate risk management
In the normal course of business the Group borrows to finance its operations. The Group is exposed to interest rate risk because the fair value of fixed rate borrowings and the cash flows associated with floating rate borrowings will fluctuate with changes in interest rates. The Group's policy is to manage the interest rate risk on long-term borrowings by ensuring the exposure to floating interest rates remains within a 30% to 70% range, including the impact of interest rate derivatives. A sensitivity analysis that is intended to illustrate the sensitivity of the Group's financial position and performance to changes in interest rates is provided in note 25.
(d) Equity price risk management
The Group is exposed to equity price risk because certain available-for-sale financial assets, held by the Law Debenture Trust on behalf of the Company as security in respect of the Centrica Unapproved Pension Scheme, are linked to equity indices (note 29). Investments in equity indices are inherently exposed to less risk than individual equity investments because they represent a naturally diverse portfolio. Note 29 details the Group's other retirement benefit assets and liabilities.
(e) Sensitivity analysis
IFRS 7 requires disclosure of a sensitivity analysis that is intended to illustrate the sensitivity of the Group's financial position and performance to changes in market variables (commodity prices, foreign exchange rates and interest rates) as a result of changes in the fair value or cash flows associated with the Group's financial instruments. The sensitivity analysis provided discloses the effect on profit or loss and equity at 31 December 2011 assuming that a reasonably possible change in the relevant risk variable had occurred at 31 December 2011 and been applied to the risk exposures in existence at that date to show the effects of reasonably possible changes in price on profit or loss and equity to the next annual reporting date. Reasonably possible changes in market variables used in the sensitivity analysis are based on implied volatilities, where available, or historical data for energy prices and foreign exchange rates. Reasonably possible changes in interest rates are based on management judgement and historical experience.
The sensitivity analysis has been prepared based on 31 December 2011 balances and on the basis that the balances, the ratio of fixed to floating rates of debt and derivatives, the proportion of energy contracts that are financial instruments, the proportion of financial instruments in foreign currencies and the hedge designations in place at 31 December 2011 are all constant. Excluded from this analysis are all non-financial assets and liabilities and energy contracts that are not financial instruments under IAS 39. The sensitivity to foreign exchange rates relates only to monetary assets and liabilities denominated in a currency other than the functional currency of the commercial operation transacting, and excludes the translation of the net assets of foreign operations to pounds sterling, but includes the corresponding impact of financial instruments used in net investment hedges.
The sensitivity analysis provided is hypothetical only and should be used with caution as the impacts provided are not necessarily indicative of the actual impacts that would be experienced because the Group's actual exposure to market rates is changing constantly as the Group's portfolio of commodity, debt and foreign currency contracts changes. Changes in fair values or cash flows based on a variation in a market variable cannot be extrapolated because the relationship between the change in market variable and the change in fair value or cash flows may not be linear. In addition, the effect of a change in a particular market variable on fair values or cash flows is calculated without considering inter-relationships between the various market rates or mitigating actions that would be taken by the Group. The sensitivity analysis provided in note 25 excludes the impact of proprietary energy trading assets and liabilities because the VaR associated with the Group's proprietary energy trading activities is less than £5 million.
Credit risk management
Credit risk is the risk of loss associated with a counterparty's inability or failure to discharge its obligations under a contract. The Group is exposed to credit risk in its treasury, trading, energy procurement and downstream activities. The Group continues to take steps to tighten downstream credit policies, including the tightening of credit scores in customer management processes, whilst continuing to manage credit risk in accordance with financial risk management processes.
Note 25 provides further detail of the Group's exposure to credit risk on its financial assets.
(a) Treasury, trading and energy procurement activities
Wholesale counterparty credit exposures are monitored by individual counterparty and by category of credit rating, and are subject to approved limits. The majority of significant exposures are with counterparties rated A–/A3 or better. The Group uses master netting agreements to reduce credit risk and net settles payments with counterparties where net settlement provisions exist. In addition, the Group employs a variety of other methods to mitigate credit risk: margining, various forms of bank and parent company guarantees and letters of credit.
100% of the Group's credit risk associated with its treasury, trading and energy procurement activities is with counterparties in related energy industries or with financial institutions.
IFRS 7 requires disclosure of information about the exposure to credit risk arising from financial instruments only. Only certain of the Group's energy procurement contracts constitute financial instruments under IAS 39 (note 24). As a result, whilst the Group manages the credit risk associated with both financial and non-financial energy procurement contracts, it is the carrying value of financial assets within the scope of IAS 39 (note 24) that represents the maximum exposure to credit risk in accordance with IFRS 7.
(b) Downstream activities
In the case of business customers, credit risk is managed by checking a company's creditworthiness and financial strength both before commencing trade and during the business relationship. For residential customers, creditworthiness is ascertained normally before commencing trade to determine the payment mechanism required to reduce credit risk to an acceptable level. Certain customers will only be accepted on a prepayment basis or with a security deposit. In some cases, an ageing of receivables is monitored and used to manage the exposure to credit risk associated with both business and residential customers. In other cases, credit risk is monitored and managed by grouping customers according to method of payment or profile.
Liquidity risk management and going concern
Liquidity risk is the risk that the Group is unable to meet its financial obligations as they fall due. The Group experiences significant movements in its liquidity position due primarily to the seasonal nature of its business and margin cash arrangements associated with certain wholesale commodity contracts. To mitigate this risk the Group maintains significant committed facilities and holds cash on deposit. The Group's liquidity position has remained strong throughout 2011.
S4. Other equity
During February 1997, BG plc (formerly British Gas plc) demerged certain businesses (grouped together under GB Gas Holdings Limited (GBGH)) to form Centrica plc. Upon demerger, the share capital of GBGH was transferred to Centrica plc and was recorded at the nominal value of shares issued to BG plc shareholders. In accordance with the Companies Act 1985, no premium was recorded on the shares issued. On consolidation, the difference between the nominal value of the Company's shares issued and the amount of share capital and share premium of GBGH at the date of demerger was credited to a merger reserve.
Capital redemption reserve
In accordance with the Companies Act 1985, the Company transferred to the capital redemption reserve an amount equal to the nominal value of shares repurchased and subsequently cancelled (£16 million).
During 2005, the revaluation of the Group's existing interest in Centrica SHB Limited to fair value, following the acquisition by the Group of the remaining 40% stake in the company, was recorded as a revaluation reserve adjustment. The remainder of the revaluation reserve relates to a 2009 revaluation of producing gas and oil assets located in Alberta, Canada, following the acquisition by the Group of additional interests.
Treasury shares reserve
Treasury shares reserve reflects the cost of shares in the Company held in share-based payment plans to meet future obligations to deliver shares to employees on vesting.
Share-based payments reserve
The share-based payments reserve reflects the obligation to deliver shares to employees under the Group's share schemes in return for services provided.
S5. Segmental analysis
The measure of profit used by the Centrica Executive Committee is adjusted operating profit. Adjusted operating profit is operating profit before exceptional items and certain re-measurements (refer to note 7), before additional depreciation resulting from any fair value uplifts on Strategic Investments (refer to notes 2 and 11) and including the results from joint ventures and associates which are included before interest and tax. All transactions between segments are on an arm's length basis.
Centrica's operating segments are those used internally by management to run the business and make decisions. Centrica's operating segments are based on products and services provided in each geographical area. The operating segments are also the Group's reportable segments. The types of products and services from which each reportable segment derives its revenues are:
|Residential energy supply||The supply of gas and electricity to residential customers in the UK|
|Residential services||Installation, repair and maintenance of domestic central heating, plumbing and drains, gas appliances and kitchen appliances, including the provision of fixed-fee maintenance/breakdown service and insurance contracts in the UK|
|Business energy supply and services||The supply of gas and electricity and provision of energy-related services to business customers in the UK|
|Gas||Production, processing, trading and optimisation of gas and oil and the development of new fields to grow reserves|
|Power||Generation, trading and optimisation of power from thermal, nuclear and wind sources|
|Storage UK||Gas storage in the UK|
|Residential energy supply||The supply of gas and electricity to residential customers in North America|
|Business energy supply||The supply of gas, electricity and energy-related services to business customers in North America|
|Residential and business services||Installation and maintenance of Heating, Ventilation and Air Conditioning (HVAC) equipment, water heaters and the provision of breakdown services in North America|
|Upstream and wholesale energy||Gas production, power generation and procurement and trading activities in the North American wholesale energy markets|
The Registered Pensions Schemes are subject to independent valuations at least every three years, on the basis of which the qualified actuary certifies the rate of employer contributions which, together with the specified contributions payable by the employees and proceeds from the schemes' assets, are expected to be sufficient to fund the benefits payable under the schemes.
The latest full actuarial valuations were carried out at the following dates: the Registered Pensions Schemes at 31 March 2009, the Unapproved Pension Scheme at 6 April 2011 and the Direct Energy Marketing Limited pension plan at 31 December 2010. These have been updated to 31 December 2011 for the purposes of meeting the requirements of IAS 19. Investments have been valued for this purpose at market value.
The Registered Pension Schemes are managed by trustee companies whose boards consist of both company-nominated and member-nominated directors. Each scheme holds units in the Centrica Combined Common Investment Fund (CCCIF), which holds the combined assets of the participating schemes. The method of allocation of units is set out in the Trust Deed of the CCCIF. The board of CCCIF Limited is comprised of nine directors: three independent directors, three directors appointed by Centrica plc (including the chairman) and one director appointed by each of the three participating schemes. No direct investments are made in securities issued by Centrica plc or any of its subsidiaries, property leased to or owned by Centrica plc or any of its subsidiaries or securities of any fund manager or any of their associated companies.
Under the terms of the Pensions Act 2004, Centrica plc and each trustee board must agree the funding rate for its defined benefit pension scheme and a recovery plan to fund any deficit against the scheme-specific statutory funding objective. This approach was first adopted for the triennial valuations completed at 31 March 2006 and was again reflected in the 31 March 2009 valuations.
S7. Share schemes
Long Term Incentive Scheme (LTIS)
Under the LTIS, allocations of shares in Centrica plc are reserved for employees at senior management level. The number of shares to be released to participants is calculated subject to the Company's total shareholder return (TSR) and earnings per share (EPS) growth during the three years following the grant date. Shares are released to participants immediately following the end of the period in which performance is assessed, however release of shares is subject to continued employment within the Group at the date of release. The vesting of half of each award is made on the basis of TSR performance and is valued using a Monte Carlo simulation model. The vesting of the remaining half of awards is dependent on EPS growth. This is a non-market condition and therefore the fair value of these awards is considered to be the market value at the grant date. The likelihood of achieving the performance conditions is taken into account in calculating the number of awards expected to vest.
Deferred and Matching Share Scheme (DMSS)
Awards under the DMSS are reserved for employees within the senior executive group. Under normal conditions the grant date of the scheme is the first day of each bonus year. This is followed by a vesting period of four years, being the bonus year plus a three-year performance period. The fair value of the award reflects the market value of the shares at the grant date. The scheme comprises three separate elements:
(a) Deferred shares
The scheme automatically requires participants to defer between 20% and 40% of their annual pre-tax bonus into the scheme. The shares are held in trust over the three-year performance period, during which time they cannot be withdrawn. An employee who leaves prior to the vesting date will forfeit their right to the shares (except where permitted by the rules of the scheme). All shares held in trust will be eligible to receive dividends.
(b) Investment shares
The scheme allows participants to elect to invest an additional amount of their annual bonus into the scheme up to a maximum of 50% of their total potential bonus for the year. This 50% limit includes the pre-tax amount automatically deferred each year. The shares may be funded directly from the employee and thus the shares do not attract an IFRS 2 charge. An employee who leaves prior to the vesting date will retain their investment shares.
(c) Matching shares
Deferred and investment shares will be matched with conditional matching shares, which will be released upon the achievement, over a three-year performance period, of three-year Group economic profit performance targets. Group economic profit is calculated by taking adjusted group operating profit (as defined in note 4) after tax and subtracting a charge for capital employed based on the Group's weighted average cost of capital. Further information on the operation of the DMSS and related performance conditions can be found within the Remuneration Report. The likelihood of achieving the performance conditions is taken into account in calculating the number of awards expected to vest. Estimates are made in year one and revised in subsequent years. An employee who leaves prior to the vesting date will forfeit their right to the shares (except where permitted by the rules of the scheme).
S8. Fixed-fee service and insurance contracts
Fixed-fee service contracts are entered into with home services customers in the UK and home and business services customers in North America. These contracts continue until cancelled by either party to the maintenance element.
Insurance contracts are entered into with home service customers in the UK by British Gas Insurance Limited (BGIL), a fully owned subsidiary of Centrica plc, an entity regulated by the Financial Services Authority (FSA) since August 2009. Product offerings include central heating, boiler and controls, plumbing and drains and electrical appliance insurance cover. These contracts are normally for periods of 12-months with the option of renewal.
Fixed-fee service and insurance contracts protect purchasers of these contracts against the risk of breakdown of electrical, plumbing, heating, cooling and household appliances, resulting in the transfer of an element of risk from contract holders to BGIL. Benefits provided to customers vary in accordance with terms and conditions of the contracts entered into, however, generally include repair and/or replacement of the items affected.
The risk and level of service required within these contracts is dependent upon the occurrence of uncertain future events, in particular the number of call-outs, the cost per call-out and the nature of the fault. Accordingly, the timing and amount of future cash outflows related to the contracts is uncertain. The key terms and conditions that affect future cash flows are as follows:
- provision of labour and parts for repairs, dependent on the agreement and associated level of service;
- one safety and maintenance inspection either annually or in every continuous two-year period, as set out in the agreement;
- no limit to the number of call-outs to carry out repair work; and
- caps on certain maintenance and repair costs within fixed-fee service and insurance contracts.
Revenue from fixed-fee service and insurance contracts is recognised with regard to the incidence of risk over the life of the contract, reflecting the seasonal propensity of claims to be made under the contracts and the benefits receivable by the customer, which span the life of the contract as a result of emergency maintenance being available throughout the contract term. Cost of sales relates directly to the engineer workforce employed by Centrica within home services, the cost of which is accounted for over a 12-month period with adjustments made to reflect the seasonality of workload over a given year. The costs of claims under the fixed-fee service and insurance contracts will be the costs of the engineer workforce employed by Centrica within home services. These costs are accounted for over a 12-month period with adjustments made to reflect the seasonality of workload over a given year.
Weather conditions and the seasonality of maintenance can affect the number of call-outs, the cost per call-out and the nature of the fault. BGIL's obligations under the terms of home services fixed-fee service and insurance contracts are based on the number of breakdowns occurring within the contract period. BGIL actively manages the risk exposure of these uncertain events by undertaking the following risk mitigation activities:
- an initial service visit is performed for central heating care and insurance cover. If, at the initial visit, faults that cannot be rectified are identified, the fixed-fee service and insurance contract will be cancelled and no further cover provided;
- an annual or biennial safety and maintenance inspection is performed to ensure all issues are identified prior to them developing into significant maintenance or breakdown issues; and
- caps on certain maintenance and repair work are incorporated into fixed-fee service and insurance contracts to limit liability in areas considered to be higher risk in terms of prevalence and cost to repair.
S9. Principal undertakings
|31 December 2011||Country of
|Percentage holding in ordinary
shares and net assets
|Subsidiary undertakings (i)|
|Airtron Inc||USA||100||Home/commercial services|
|Bastrop Energy Partners LP||USA||100||Power generation|
|Brae Canada Ltd||Canada||100||Investment company|
|British Gas Energy Services Limited||England||100||Building services|
|British Gas Insurance Limited||England||100||Insurance provision|
|British Gas Services Limited||England||100||Residential services|
|British Gas Trading Limited||England||100||Energy supply|
|Centrica Barry Limited||England||100||Power generation|
|Centrica Brigg Limited||England||100||Power generation|
|Centrica Energy Limited (ii)||England||100||Wholesale energy trading|
|Centrica Energy (Trading) Limited (iii)||England||100||Proprietary energy trading|
|Centrica KL Limited||England||100||Power generation|
|Centrica KPS Limited||England||100||Power generation|
|Centrica Langage Limited||England||100||Power generation|
|Centrica LNG Company Limited||England||100||Energy supply|
|Centrica North Sea Gas Limited (iv)||Scotland||100||Gas and oil production|
|Centrica North Sea Oil Limited (v)||Scotland||100||Gas and oil production|
|Centrica Norway Limited||England||100||Gas and oil exploration and production|
|Centrica PB Limited||England||100||Power generation|
|Centrica Production Nederland B.V.||Netherlands||100||Gas and oil exploration and production|
|Centrica Resources Limited||England||100||Gas and oil exploration and production|
|Centrica RPS Limited||England||100||Power generation|
|Centrica SHB Limited||England||100||Power generation|
|Centrica Storage Limited||England||100||Gas storage|
|Clockwork Inc (vi)||USA||100||Home services|
|CPL Retail Energy LP||USA||100||Energy supply|
|Direct Energy LP||USA||100||Energy supply|
|Direct Energy Business LLC||USA||100||Energy supply|
|Direct Energy Marketing Inc||USA||100||Wholesale energy trading|
|Direct Energy Marketing Limited||Canada||100||Energy supply and home services|
|Direct Energy Partnership||Canada||100||Energy supply|
|Direct Energy Resources Partnership||Canada||100||Gas production|
|Direct Energy Services LLC||USA||100||Energy supply and home services|
|Direct Energy US Home Services Inc||USA||100||Home/commercial services|
|Dyno Holdings Limited||England||100||Home services|
|Energy America LLC||USA||100||Energy supply|
|FCP Enterprises Inc (vii)||USA||100||Energy supply|
|Frontera Generation LP||USA||100||Power generation|
|Gateway Energy Services Corporation (viii)||USA||100||Energy supply|
|GB Gas Holdings Limited||England||100||Holding company|
|Hydrocarbon Resources Limited||England||100||Gas production|
|Paris Generation LP||USA||100||Power generation|
|Vectren Retail LLC (viii)||USA||100||Energy supply|
|WTU Retail Energy LP||USA||100||Energy supply|
The principal joint ventures and associate investments held by the Group are disclosed in note 16.
A full list of related undertakings is included in the Company's Annual Return submitted to the Registrar of Companies.