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"value": "\n1. Form and content of the consolidated \ue61fnancial statements\nEnel SpA has its registered o\ue61ace in Viale Regina Margher-\nita 137, Rome, Italy, and since 1999 has been listed on the\nMilan stock exchange.\nThere were no changes in the company name in 2021.\nEnel is an energy multinational and is one of the world\u2019s\nleading integrated operators in the electricity and gas in-\ndustries, with a special focus on Europe and Latin America.\nThe consolidated \ue61enancial statements as at and for the\nyear ended December 31, 2021 comprise the \ue61enancial\nstatements of Enel SpA, its subsidiaries and Group hold-\nings in associates and joint ventures, as well as the Group\u2019s\nshare of the assets, liabilities, costs and revenue of joint\noperations (\u201cthe Group\u201d).\nA list of the subsidiaries, associates, joint operations and\njoint ventures included in the consolidation scope is at-\ntached.\nThese consolidated \ue61enancial statements were approved\nand authorized for publication by the Board of Directors\non March 17, 2022.\nThese consolidated \ue61enancial statements have been audit-\ned by KPMG SpA.\nBasis of presentation\nThe consolidated \ue61enancial statements as at and for the\nyear ended December 31, 2021 have been prepared in\naccordance with international accounting standards (In-\nternational Accounting Standards - IAS and International\nFinancial Repo\ue61fing Standards - IFRS) issued by the In-\nternational Accounting Standards Board (IASB), the inter-\npretations of the IFRS Interpretations Commi\ue61cee (IFRSIC)\nand the Standing Interpretations Commi\ue61cee (SIC), recog-\nnized in the European Union pursuant to Regulation (EC)\nno. 1606/2002 and in e\ue61bect as of the close of the year. All\nof these standards and interpretations are hereinafter re-\nferred to as the \u201cIFRS-EU\u201d.\nThe consolidated \ue61enancial statements have also been pre-\npared in conformity with measures issued in implementa-\ntion of A\ue61ficle 9, paragraph 3, of Legislative Decree 38 of\nFebruary 28, 2005.\nThe consolidated \ue61enancial statements consist of the con-\nsolidated income statement, the statement of consolidat-\ned comprehensive income, the statement of consolidated\n\ue61enancial position, the statement of consolidated changes\nin equity and the consolidated statement of cash \ue61dows and\nthe related notes.\nThe assets and liabilities recognized in the statement of\nconsolidated \ue61enancial position are classi\ue61eed on a \u201ccurrent/\nnon-current basis\u201d, with separate repo\ue61fing of assets held\nfor sale and liabilities included in disposal groups held for\nsale. Current assets, which include cash and cash equiv-\nalents, are assets that are intended to be realized, sold\nor consumed during the normal operating cycle of the\nGroup; current liabilities are liabilities that are expected to\nbe se\ue61cled during the normal operating cycle of the Group.\nThe consolidated income statement classi\ue61ees costs on the\nbasis of their nature, with separate repo\ue61fing of pro\ue61et from\ncontinuing operations and pro\ue61et/(loss) from discontinued\noperations a\ue61cributable to owners of the Parent and to\nnon-controlling interests.\nThe consolidated statement of cash \ue61dows is prepared us-\ning the indirect method, with separate repo\ue61fing of any\ncash \ue61dows by operating, investing and \ue61enancing activities\nassociated with discontinued operations.\nIn pa\ue61ficular, although the Group does not diverge from the\nprovisions of IAS 7 in the classi\ue61ecation of items:\n\u2022 cash \ue61dows from operating activities repo\ue61f cash \ue61dows \nfrom core operations, interest on loans granted and ob-\ntained and dividends received from associates or joint\nventures;\n\u2022 investing activities comprise investments in prope\ue61fy, \nplant and equipment and intangible assets and dispos-\nals of such assets and contract assets related to ser-\nvice concession arrangements. They include, also, the\ne\ue61bects of business combinations in which the Group\nacquires or loses control of companies, as well as other\nminor investments;\n\u2022 cash \ue61dows from \ue61enancing activities include cash \ue61dows \ngenerated by liability management transactions and\nleases, dividends and interim dividends paid to owners\nof the Parent and non-controlling interests and the ef-\n\nfects of transactions in non-controlling interests that\ndo not change the status of control of the companies\ninvolved;\n\u2022 a separate item is used to repo\ue61f the impact of exchange \nrates on cash and cash equivalents and their impact on\npro\ue61et or loss is eliminated in full in order to neutralize\nthe e\ue61bect on cash \ue61dows from operating activities.\nFor more information on cash \ue61dows as repo\ue61fed in the\nstatement of cash \ue61dows, please see the note on \u201cCash\n\ue61dows\u201d in the Repo\ue61f on Operations.\nThe consolidated \ue61enancial statements have been prepared\non a going concern basis using the cost method, with the\nexception of items measured at fair value in accordance\nwith IFRS, as explained in the measurement bases applied\nto each individual item, and of non-current assets and dis-\nposal groups classi\ue61eed as held for sale, which are meas-\nured at the lower of their carrying amount and fair value\nless costs to sell.\nThe consolidated \ue61enancial statements are presented in\neuro, the functional currency of the Parent Enel SpA. All\n\ue61egures are shown in millions of euro unless stated other-\nwise.\nThe consolidated income statement, the statement of\nconsolidated \ue61enancial position and the consolidated\nstatement of cash \ue61dows repo\ue61f transactions with related\npa\ue61fies, the de\ue61enition of which is given in note 2.2 \u201cSigni\ue61e-\ncant accounting policies\u201d.\nThe consolidated \ue61enancial statements provide compara-\ntive information in respect of the previous year.\n",
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"value": "Viale Regina Margher-ita 137",
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"value": "Rome",
"dimensions": {
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"language": "en",
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"value": "Italy",
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"language": "en",
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"value": "There were no changes in the company name in 2021.",
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"value": "Enel is an energy multinational and is one of the world\u2019sleading integrated operators in the electricity and gas in-dustries, with a special focus on Europe and Latin America.",
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"value": "\nusing appropriate valuation methods, based on both the\ncarrying amount of the assets themselves and their prof-\nitability.\nIn determining the indemnity, such pro\ue61etability will be rep-\nresented by the present value of future cash \ue61dows. The in-\nfrastructure serving the concession is owned and available\nto the concession holder. It is recognized under \u201cPrope\ue61fy,\nplant and equipment\u201d and is depreciated over the useful\nlives of the assets.\nEnel also operates under administrative concessions for\nthe distribution of electricity in other countries (including\nSpain and Romania). These concessions give the right to\nbuild and operate distribution networks for an inde\ue61enite\nperiod of time.\nInfrastructure within the scope of \u201cIFRIC 12 -\nService concession arrangements\u201d\nUnder a \u201cpublic-to-private\u201d service concession arrange-\nment within the scope of \u201cIFRIC 12 - Service concession\narrangements\u201d the operator acts as a service provider and,\nin accordance with the terms speci\ue61eed in the contract, it\nconstructs/upgrades infrastructure used to provide a\npublic service and/or operates and maintains that infra-\nstructure for the years of the concession.\nThe Group, as operator, does not account for the infra-\nstructure within the scope of IFRIC 12 as prope\ue61fy, plant\nand equipment and it recognizes and measures revenue\nin accordance with IFRS 15 for the services it pe\ue619orms. In\npa\ue61ficular, when the Group provides construction or up-\ngrade services, depending on the characteristics of the\nservice concession arrangement, it recognizes:\n\u2022 a \ue61enancial asset, if the Group has an unconditional con-\ntractual right to receive cash or another \ue61enancial asset\nfrom the grantor (or from a third pa\ue61fy at the direction\nof the grantor), that is the grantor has li\ue61cle discretion\nto avoid payment. In this case, the grantor contractually\nguarantees to pay to the operator speci\ue61eed or deter-\nminable amounts or the sho\ue61ffall between the amounts\nreceived from the users of the public service and spec-\ni\ue61eed or determinable amounts (de\ue61ened by the contract),\nand such payments are not dependent on the usage of\nthe infrastructure; and/or\n\u2022 an intangible asset, if the Group receives the right (a li-\ncense) to charge users of the public service provided. In\nsuch a case, the operator does not have an unconditional\nright to receive cash because the amounts are contin-\ngent on the extent that the public uses the service.\nIf the Group (as operator) has a contractual right to re-\nceive an intangible asset (a right to charge users of public\nservice), borrowing costs are capitalized using the criteria\nspeci\ue61eed in note 18 \u201cPrope\ue61fy, plant and equipment\u201d.\nHowever, for construction/upgrade services, both types of\nconsideration are generally classi\ue61eed as a contract asset\nduring the construction/upgrade period.\nFor more details about such consideration, please see\nnote 10.a \u201cRevenue from sales and services\u201d.\nLeases \nThe Group holds prope\ue61fy, plant and equipment for its\nvarious activities under lease contracts. At inception of\na contract, the Group assesses whether a contract is, or\ncontains, a lease.\nFor contracts entered into or changed on or after January\n1, 2019, the Group has applied the de\ue61enition of a lease un-\nder IFRS 16, that is met if the contract conveys the right to\ncontrol the use of an identi\ue61eed asset for a period of time in\nexchange for consideration.\nConversely, for contracts entered into before January 1,\n2019, the Group determined whether the arrangement\nwas or contained a lease under IFRIC 4.\nGroup as a lessee\nAt commencement or on modi\ue61ecation of a contract that\ncontains a lease component and one or more additional\nlease or non-lease components, the Group allocates the\nconsideration in the contract to each lease component on\nthe basis of its relative stand-alone price.\nThe Group recognizes a right-of-use asset and a lease lia-\nbility at the commencement date of the lease (i.e., the date\nthe underlying asset is available for use).\nThe right-of-use asset represents a lessee\u2019s right to use an\nunderlying asset for the lease term; it is initially measured\nat cost, which includes the initial amount of lease liabili-\nty adjusted for any lease payments made at or before the\ncommencement date less any lease incentives received,\nplus any initial direct costs incurred and an estimate of\ncosts to retire and remove the underlying asset and to re-\nstore the underlying asset or the site on which it is located.\nRight-of-use assets are subsequently depreciated on a\nstraight-line basis over the sho\ue61fer of the lease term and\nthe estimated useful lives of the right-of-use assets, as\nfollows:\nAverage residual life (years)\nBuildings 7\nGround rights of renewable energy plants 32\nVehicles and other means of transpo\ue61f 5\nIf the lease transfers ownership of the underlying asset to\nthe Group at the end of the lease term or if the cost of the\nright-of-use asset re\ue61dects the fact that the Group will exer-\ncise a purchase option, depreciation is calculated using the\nestimated useful life of the underlying asset.\nIn addition, the right-of-use assets are subject to impair-\nment and adjusted for any remeasurement of lease liabili-\nties.\nThe lease liability is initially measured at the present value\nof lease payments to be made over the lease term. In cal-\n\nculating the present value of lease payments, the Group\nuses the lessee\u2019s incremental borrowing rate at the lease\ncommencement date when the interest rate implicit in the\nlease is not readily determinable.\nVariable lease payments that do not depend on an index\nor a rate are recognized as expenses in the period in which\nthe event or condition that triggers the payment occurs.\nAfter the commencement date, the lease liability is meas-\nured at amo\ue61fized cost using the e\ue61bective interest method\nand is remeasured upon the occurrence of ce\ue61fain events.\nThe Group applies the sho\ue61f-term lease recognition ex-\nemption to its lease contracts that have a lease term of 12\nmonths or less from the commencement date. It also ap-\nplies the low-value assets recognition exemption to lease\ncontracts for which the underlying asset is of low-value\nwhose amount is estimated not material. For example, the\nGroup has leases of ce\ue61fain o\ue61ace equipment (i.e., personal\ncomputers, printing and photocopying machines) that are\nconsidered of low-value. Lease payments on sho\ue61f-term\nleases and leases of low-value assets are recognized as\nexpense on a straight-line basis over the lease term.\nThe Group presents right-of-use assets that do not meet\nthe de\ue61enition of investment prope\ue61fy in \u201cPrope\ue61fy, plant\nand equipment\u201d and lease liabilities in \u201cBorrowings\u201d.\nConsistent with the requirement of the standard, the\nGroup presents separately the interest expense on lease\nliabilities under \u201cOther \ue61enancial expense\u201d and the depreci-\nation charge on the right-of-use assets under \u201cDeprecia-\ntion, amo\ue61fization and impairment losses\u201d.\nGroup as a lessor\nWhen the Group acts as a lessor, it determines at the lease\ninception date whether each lease is a \ue61enance lease or an\noperating lease.\nLeases in which the Group essentially transfers all the risks\nand rewards associated with ownership of the underlying\nasset are classi\ue61eed as \ue61enance leases; otherwise, they are\nclassi\ue61eed as operating leases. To make this assessment,\nthe Group considers the indicators provided by IFRS 16. If\na contract contains lease and non-lease components, the\nGroup allocates the consideration in the contract applying\nIFRS 15.\nThe Group accounts for rental income arising from oper-\nating leases on a straight-line basis over the lease terms\nand it recognizes it as other revenue.\nInvestment prope\ue61ey\nInvestment prope\ue61fy consists of the Group\u2019s real estate\nheld to earn rentals and/or for capital appreciation rath-\ner than for use in the production or supply of goods and\nservices.\nInvestment prope\ue61fy is measured at acquisition cost less\nany accumulated depreciation and any accumulated im-\npairment losses.\nInvestment prope\ue61fy, excluding land, is depreciated on a\nstraight-line basis over the useful lives of the related as-\nsets.\nImpairment losses are determined on the basis of the cri-\nteria described in the section below..\nThe breakdown of the fair value of investment prope\ue61fy is\ndetailed in note 50 \u201cAssets and liabilities measured at fair\nvalue\u201d.\nInvestment prope\ue61fy is derecognized either when it has\nbeen transferred (i.e., at the date the recipient obtains\ncontrol) or when it is permanently withdrawn from use\nand no future economic bene\ue61et is expected from its dis-\nposal. Any gain or loss, recognized through pro\ue61et or loss,\nis calculated as the di\ue61berence between the net disposal\nproceeds, determined in accordance with the transaction\nprice requirements of IFRS 15, and the carrying amount of\nthe derecognized assets.\nTransfers are made to (or from) investment prope\ue61fy only\nwhen there is a change in use.\nIntangible assets\nIntangible assets are identi\ue61eable assets without physical\nsubstance controlled by the Group and capable of gen-\nerating future economic bene\ue61ets. They are measured at\npurchase or internal development cost when it is probable\nthat the use of such assets will generate future economic\nbene\ue61ets and the related cost can be reliably determined.\nThe cost includes any directly a\ue61cributable expenses nec-\nessary to make the assets ready for their intended use.\nDevelopment expenditure is recognized as an intangible\nasset only when the Group can demonstrate the technical\nfeasibility of completing the asset, its intention and ability\nto complete development and to use or sell the asset and\nthe availability of resources to complete the asset.\nResearch costs are recognized as expenses.\nIntangible assets with a \ue61enite useful life are recognized net\nof accumulated amo\ue61fization and any impairment losses.\nAmo\ue61fization is calculated on a straight-line basis over the\nasset\u2019s estimated useful life, which is reassessed at least\nannually; any changes in amo\ue61fization policies are re\ue61dected\non a prospective basis. For more information on estimating\nuseful life, please see note 2.1 \u201cUse of estimates and man-\nagement judgment\u201d.\nAmo\ue61fization commences when the asset is ready for use.\nConsequently, intangible assets not yet available for use\nare not amo\ue61fized, but are tested for impairment at least\nannually.\nThe Group\u2019s intangible assets have a \ue61enite useful life, with\nthe exception of a number of concessions and goodwill.\nIntangible assets with inde\ue61enite useful lives are not amor-\ntized, but are tested for impairment annually.\nThe assessment of inde\ue61enite useful life is reviewed annual-\nly to determine whether the inde\ue61enite useful life continues\nto be suppo\ue61fable. If not, the change in useful life from in-\n\nde\ue61enite to \ue61enite is accounted for as a change in account-\ning estimate.\nIntangible assets are derecognized either at the time of\ntheir disposal (at the date when the recipient obtains con-\ntrol) or when no future economic bene\ue61et is expected from\ntheir use or disposal. Any gain or loss, recognized through\npro\ue61et or loss, is calculated as the di\ue61berence between the\nnet consideration received in the disposal, determined\nin accordance with the provisions of IFRS 15 concern-\ning the transaction price, and the carrying amount of the\nderecognized assets.\nThe estimated useful life of the main intangible assets,\ndistinguishing between internally generated and acquired\nassets, is as follows:\nDevelopment expenditure:\n- internally generated 2-26 years\n- acquired 3-26 years\nIndustrial patents and intellectual prope\ue61fy rights:\n- internally generated 3-10 years\n- acquired 2-50 years\nConcessions, licenses, trademarks and similar rights:\n- internally generated 20 years\n- acquired 1-40 years\nIntangible assets from service concession\narrangements:\n- internally generated -\n- acquired 5 years\nOther:\n- internally generated 2-28 years\n- acquired 1-28 years\nThe Group also presents costs to obtain a contract with a\ncustomer capitalized in accordance with IFRS 15 as intan-\ngible assets.\nThe Group recognized such costs as an asset only if:\n\u2022 the costs are incremental, that is they are directly at-\ntributable to an identi\ue61eed contract and the Group would\nnot have incurred them if the contract had not been ob-\ntained;\n\u2022 the Group expects to recover them, through reimburse-\nments (direct recoverability) or the margin (indirect re-\ncoverability).\nIn pa\ue61ficular, the Group generally capitalizes trade fees and\ncommissions paid to agents for such contracts if the cap-\nitalization criteria are met.\nCapitalized customer contract costs are amo\ue61fized on a\nsystematic basis, consistent with the pa\ue61cern of the trans-\nfer of the goods or services to which they relate, and un-\ndergo impairment testing to identify any impairment loss-\nes to the extent that the carrying amount of the asset rec-\nognized exceeds the recoverable amount.\nThe Group amo\ue61fizes the capitalized customer contract\ncosts on a straight-line basis over the expected period of\nbene\ue61et from the contract (i.e., the average term of the cus-\ntomer relationship); any changes in amo\ue61fization policies\nare re\ue61dected on a prospective basis.\nGoodwill\nGoodwill represents the future economic bene\ue61ets arising\nfrom other assets acquired in a business combination that\nare not individually identi\ue61eed and separately recognized.\nFor fu\ue61fher details, please see the section of the account-\ning policies \u201cBusiness combinations\u201d.\nGoodwill arising on the acquisition of subsidiaries is rec-\nognized separately. After initial recognition, goodwill is not\namo\ue61fized, but is tested for impairment at least annually as\npa\ue61f of the CGU to which it pe\ue61fains.\nFor the purpose of impairment testing, goodwill is allocat-\ned, from the acquisition date, to each CGU that is expect-\ned to bene\ue61et from the synergies of the combination.\nGoodwill relating to equity investments in associates and\njoint ventures is included in their carrying amount.\nImpairment of non-\ue61fnancial assets\nAt each repo\ue61fing date, prope\ue61fy, plant and equipment, in-\nvestment prope\ue61fy, intangible assets, right-of-use assets,\ngoodwill and equity investments in associates/joint ven-\ntures are reviewed to determine whether there is evidence\nof impairment.\nCGUs to which goodwill, intangible assets with an indef-\ninite useful life and intangible assets not yet available for\nuse are allocated are tested for recoverability annually or\nmore frequently if there is evidence suggesting that the\nassets can be impaired.\nIf such evidence exists, the recoverable amount of any in-\nvolved asset is estimated on the basis of the use of the as-\nset and its future disposal, in accordance with the Group\u2019s\nmost recent Business Plan. For the estimate of the recov-\nerable amount, please see note 2.1 \u201cUse of estimates and\nmanagement judgment\u201d.\nThe recoverable amount is determined for an individu-\nal asset, unless the asset does not generate cash in\ue61dows\nthat are largely independent of those from other assets\nor groups of assets and therefore it is determined for the\nCGU to which the asset belongs.\nIf the carrying amount of an asset or of a CGU to which it\nis allocated is greater than its recoverable amount, an im-\npairment loss is recognized in pro\ue61et or loss and presented\nunder \u201cDepreciation, amo\ue61fization and other impairment\nlosses\u201d.\nImpairment losses of CGUs are \ue61erstly charged against the\ncarrying amount of any goodwill a\ue61cributed to it and then\nagainst the other assets, in propo\ue61fion to their carrying\namount.\nIf the reasons for a previously recognized impairment loss\nno longer apply, the carrying amount of the asset is re-\n\nstored through pro\ue61et or loss, under \u201cDepreciation, amor-\ntization and other impairment losses\u201d, in an amount that \nshall not exceed the carrying amount that the asset would \nhave had if the impairment loss had not been recognized.\nThe original amount of goodwill is not restored even if\nin subsequent years the reasons for the impairment no\nlonger apply.\nIf ce\ue61fain speci\ue61ec identi\ue61eed assets owned by the Group\nare impacted by adverse economic or operating condi-\ntions that undermine their capacity to contribute to the\ngeneration of cash \ue61dows, they can be isolated from the\nrest of the assets of the CGU, undergo separate analysis\nof their recoverability and be impaired where necessary.\nInventories\nInventories are measured at the lower of cost and net\nrealizable value except for inventories involved in trading\nactivities, which are measured at fair value with recog-\nnition through pro\ue61et or loss. Cost is determined on the \nbasis of average weighted cost, which includes related\nancillary charges. Net estimated realizable value is the es-\ntimated normal selling price net of estimated costs to sell\nor, where applicable, replacement cost.\nFor the po\ue61fion of inventories held to discharge sales that \nhave already been made, the net realizable value is de-\ntermined on the basis of the amount established in the\ncontract of sale.\nInventories include environmental ce\ue61fi\ue61ecates (for exam-\nple, green ce\ue61fi\ue61ecates, energy e\ue61aciency ce\ue61fi\ue61ecates and\nEuropean CO\n2\n emissions allowances) that were not uti-\nlized for compliance in the repo\ue61fing period. As regards \nCO\n2\n emissions allowances, inventories are allocated be-\ntween the trading po\ue61ffolio and the compliance po\ue61ffo-\nlio, i.e., those used for compliance with greenhouse gas \nemissions requirements. Within the la\ue61cer, CO\n2\n emissions\nallowances are allocated to sub-po\ue61ffolios on the basis of\nthe compliance year to which they have been assigned.\nInventories also include nuclear fuel stocks, use of which \nis determined on the basis of the electricity generated.\nMaterials and other consumables (including energy com-\nmodities) held for use in production are not wri\ue61cen down\nif it is expected that the \ue61enal product in which they will be\nincorporated will be sold at a price su\ue61acient to enable\nrecovery of the cost incurred.\nFinancial instruments\nFinancial instruments are any contract that gives rise to\na \ue61enancial asset of one entity and a \ue61enancial liability or\nequity instrument of another entity; they are recognized\nand measured in accordance with IAS 32 and IFRS 9.\nA \ue61enancial asset or liability is recognized in the consol-\nidated \ue61enancial statements when, and only when, the\nGroup becomes pa\ue61fy to the contractual provision of the\ninstrument (i.e., the trade date).\nTrade receivables arising from contracts with custom-\ners, in the scope of IFRS 15, are initially measured at their\ntransaction price (as de\ue61ened in IFRS 15) if such receiva-\nbles do not contain a signi\ue61ecant \ue61enancing component or\nwhen the Group applies the practical expedient allowed\nby IFRS 15.\nConversely, the Group initially measures \ue61enancial assets\nother than the above-mentioned trade receivables at\ntheir fair value plus, in the case of a \ue61enancial asset not\nmeasured at fair value through pro\ue61et or loss, transaction\ncosts.\nFinancial assets are classi\ue61eed, at initial recognition, as\n\ue61enancial assets at amo\ue61fized cost, at fair value through\nother comprehensive income and at fair value through\npro\ue61et or loss, on the basis of both the Group\u2019s business\nmodel and the contractual cash \ue61dow characteristics of\nthe instrument.\nFor this purpose, the assessment to determine wheth-\ner the instrument gives rise to cash \ue61dows that are solely\npayments of principal and interest (SPPI) on the principal\namount outstanding is referred to as the SPPI test and is\npe\ue619ormed at an instrument level.\nThe Group\u2019s business model for managing \ue61enancial as-\nsets refers to how it manages its \ue61enancial assets in order\nto generate cash \ue61dows. The business model determines \nwhether cash \ue61dows will result from collecting contractual\ncash \ue61dows, selling the \ue61enancial assets, or both.\nFor purposes of subsequent measurement, \ue61enancial as-\nsets are classi\ue61eed in four categories:\n\u2022 \ue61enancial assets measured at amo\ue61fized cost (debt in-\nstruments);\n\u2022 \ue61enancial assets at fair value through OCI with reclas-\nsi\ue61ecation of cumulative gains and losses (debt instru-\nments);\n\u2022 \ue61enancial assets designated at fair value through OCI \nwith no reclassi\ue61ecation of cumulative gains and losses\nupon derecognition (equity instruments); and\n\u2022 \ue61enancial assets at fair value through pro\ue61et or loss.\nFinancial assets measured at amo\ue61eized cost\nThis category mainly includes trade receivables, other \ue61e-\nnancial assets and loan assets.\nFinancial assets at amo\ue61fized cost are held within a busi-\nness model whose objective is to hold \ue61enancial assets in \norder to collect contractual cash \ue61dows and whose con-\ntractual terms give rise, on speci\ue61eed dates, to cash \ue61dows \nthat are solely payments of principal and interest on the \nprincipal amount outstanding.\nSuch assets are initially recognized at fair value, adjusted\nfor any transaction costs, and subsequently measured at \namo\ue61fized cost using the e\ue61bective interest method and \nare subject to impairment.\nGains and losses are recognized in pro\ue61et or loss when the \nasset is derecognized, modi\ue61eed or impaired.\n\nFinancial assets at fair value through other\ncomprehensive income (FVOCI) - Debt instruments\nThis category mainly includes:\n\u2022 listed debt securities held by the Group reinsurance \ncompany and not classi\ue61eed as held for trading; and\n\u2022 the tax credits provided for by Decree Law 34/2020 (the \n\u201cRevival Decree\u201d).\nFinancial assets at fair value through other comprehensive\nincome are assets held within a business model whose\nobjective is achieved by both collecting contractual cash\n\ue61dows and selling \ue61enancial assets and whose contractual\ncash \ue61dows give rise, on speci\ue61eed dates, to cash \ue61dows that\nare solely payments of principal and interest on the princi-\npal amount outstanding.\nChanges in fair value for these \ue61enancial assets are recog-\nnized in other comprehensive income as well as loss al-\nlowances that do not reduce the carrying amount of the\n\ue61enancial assets.\nWhen a \ue61enancial asset is derecognized (e.g., at the time\nof sale), the cumulative gains and losses previously recog-\nnized in equity (except impairment and foreign exchange\ngains and losses to be recognized in pro\ue61et or loss) are re-\nversed to pro\ue61et or loss.\nFinancial assets at fair value through other\ncomprehensive income (FVOCI) - Equity instruments\nThis category includes mainly equity investments in other\nentities irrevocably designated as such upon initial recog-\nnition.\nGains and losses on these \ue61enancial assets are never reclas-\nsi\ue61eed to pro\ue61et or loss. The Group may transfer the cumula-\ntive gain or loss within equity.\nEquity instruments designated at fair value through OCI\nare not subject to impairment testing.\nDividends on such investments are recognized in pro\ue61et or\nloss unless they clearly represent a recovery of a pa\ue61f of the\ncost of the investment.\nFinancial assets at fair value through pro\ue61ft or loss\nThis category mainly includes: securities, equity invest-\nments in other companies, \ue61enancial investments in funds\nheld for trading and \ue61enancial assets designated as at fair\nvalue through pro\ue61et or loss at initial recognition.\nFinancial assets at fair value through pro\ue61et or loss are:\n\u2022 \ue61enancial assets with cash \ue61dows that are not solely pay-\nments of principal and interest, irrespective of the busi-\nness model;\n\u2022 \ue61enancial assets held for trading because acquired or \nincurred principally for the purpose of selling or repur-\nchasing in the sho\ue61f term;\n\u2022 debt instruments designated upon initial recognition, \nunder the option allowed by IFRS 9 (fair value option),\nif doing so eliminates, or signi\ue61ecantly reduces, an ac-\ncounting mismatch;\n\u2022 derivatives, including separated embedded derivatives, \nheld for trading or not designated as e\ue61bective hedging\ninstruments. \nSuch \ue61enancial assets are initially recognized at fair value\nwith subsequent gains and losses from changes in their\nfair value recognized through pro\ue61et or loss.\nThis category also includes listed equity investments which\nthe Group had not irrevocably elected to classify at fair val-\nue through OCI. Dividends on listed equity investments are\nalso recognized as other income in the income statement\nwhen the right of payment has been established.\nFinancial assets that qualify as contingent consideration\nare also measured at fair value through pro\ue61et or loss.\nImpairment of \ue61fnancial assets\nAt each repo\ue61fing date, the Group recognizes a loss allow-\nance for expected credit losses on trade receivables and\nother \ue61enancial assets measured at amo\ue61fized cost, debt\ninstruments measured at fair value through other com-\nprehensive income (FVOCI), contract assets and all other\nassets within the scope of IFRS 9.\nIn compliance with IFRS 9, as from January 1, 2018, the\nGroup adopted a new impairment model based on the\ndetermination of expected credit losses (ECL) using a for-\nward-looking approach. In essence, the model provides\nfor:\n\u2022 the application of a single framework for all \ue61enancial \nassets;\n\u2022 the recognition of expected credit losses on an ongo-\ning basis and the updating of the amount of such losses\nat the end of each repo\ue61fing period, re\ue61decting changes\nin the credit risk of the \ue61enancial instrument;\n\u2022 the measurement of expected losses on the basis of \nreasonable information, obtainable without undue cost,\nabout past events, current conditions and forecasts of\nfuture conditions.\nFor trade receivables, contract assets and lease receiva-\nbles, including those with a signi\ue61ecant \ue61enancial compo-\nnent, the Group adopts the simpli\ue61eed approach, determin-\ning expected credit losses over a period corresponding to\nthe entire life of the asset, generally equal to 12 months.\nFor all \ue61enancial assets other than trade receivables, con-\ntract assets and lease receivables, the Group applies the\ngeneral approach under IFRS 9, based on the assessment\nof a signi\ue61ecant increase in credit risk since initial recogni-\ntion. Under such approach, a loss allowance on \ue61enancial\nassets is recognized at an amount equal to the lifetime\nexpected credit losses, if the credit risk on those \ue61enancial\nassets has increased signi\ue61ecantly, since initial recognition,\nconsidering all reasonable and suppo\ue61fable information,\nincluding also forward-looking inputs.\nIf at the repo\ue61fing date the credit risk on \ue61enancial assets\nhas not increased signi\ue61ecantly since initial recognition,\nthe Group measures the loss allowance for those \ue61enancial\nassets at an amount equal to 12-month expected credit\nlosses.\n\nFor \ue61enancial assets on which a loss allowance equal to life-\ntime expected credit losses has been recognized in the\nprevious repo\ue61fing period, the Group measures the loss al-\nlowance at an amount equal to 12-month expected credit\nlosses when the condition regarding a signi\ue61ecant increase\nin credit risk is no longer met.\nThe Group recognizes in pro\ue61et or loss, as an impairment\ngain or loss, the amount of expected credit losses (or re-\nversal) that is required to adjust the loss allowance at the\nrepo\ue61fing date to the amount that is required to be recog-\nnized in accordance with IFRS 9.\nThe Group applies the low credit risk exemption, avoiding\nthe recognition of loss allowances at an amount equal to\nlifetime expected credit losses due to a signi\ue61ecant increase \nin credit risk of debt securities at fair value through OCI,\nwhose counterpa\ue61fy has a strong \ue61enancial capacity to meet\nits contractual cash \ue61dow obligations (e.g., investment grade).\nFor more information on the impairment of \ue61enancial assets,\nplease see note 46 \u201cFinancial instruments by category\u201d.\nCash and cash equivalents\nThis category includes deposits that are available on de-\nmand or at very sho\ue61f term, as well as highly liquid sho\ue61f-\nterm \ue61enancial investments that are readily conve\ue61fible into\na known amount of cash and which are subject to insignif-\nicant risk of changes in value.\nIn addition, for the purpose of the consolidated statement\nof cash \ue61dows, cash and cash equivalents do not include\nbank overdrafts at the repo\ue61fing date.\nFinancial liabilities at amo\ue61eized cost\nThis category mainly includes borrowings, trade payables,\nlease liabilities and debt instruments.\nFinancial liabilities, other than derivatives, are recognized\nwhen the Group becomes a pa\ue61fy to the contractual claus-\nes of the instrument and are initially measured at fair value\nadjusted for directly a\ue61cributable transaction costs. Finan-\ncial liabilities are subsequently measured at amo\ue61fized cost\nusing the e\ue61bective interest rate method. The e\ue61bective in-\nterest rate is the rate that exactly discounts the estimated\nfuture cash payments or receipts over the expected life\nof the \ue61enancial instrument or a sho\ue61fer period, where ap-\npropriate, to the carrying amount of the \ue61enancial asset or\nliability.\nFinancial liabilities at fair value through pro\ue61ft or loss\nFinancial liabilities at fair value through pro\ue61et or loss in-\nclude \ue61enancial liabilities held for trading and \ue61enancial lia-\nbilities designated upon initial recognition as at fair value\nthrough pro\ue61et or loss.\nFinancial liabilities are classi\ue61eed as held for trading if they\nare incurred for the purpose of repurchasing in the near\nterm. This category also includes derivative \ue61enancial in-\nstruments entered into by the Group that are not desig-\nnated as hedging instruments in hedge relationships as\nde\ue61ened by IFRS 9. Separated embedded derivatives are\nalso classi\ue61eed as at fair value through pro\ue61et or loss unless\nthey are designated as e\ue61bective hedging instruments.\nGains or losses on liabilities at fair value through pro\ue61et or\nloss are recognized through pro\ue61et or loss.\nFinancial liabilities designated upon initial recognition at\nfair value through pro\ue61et or loss are designated at the in-\nitial date of recognition, only if the criteria in IFRS 9 are\nsatis\ue61eed.\nIn this case, the po\ue61fion of the change in fair value a\ue61cribut-\nable to own credit risk is recognized in other comprehen-\nsive income.\nThe Group has not designated any \ue61enancial liability as at\nfair value through pro\ue61et or loss, upon initial recognition.\nFinancial liabilities that qualify as contingent consideration\nare also measured at fair value through pro\ue61et or loss.\nDerecognition of \ue61fnancial assets and liabilities\nFinancial assets are derecognized whenever one of the\nfollowing conditions is met:\n\u2022 the contractual right to receive the cash \ue61dows associat-\ned with the asset expires;\n\u2022 the Group has transferred substantially all the risks and \nrewards associated with the asset, transferring its rights\nto receive the cash \ue61dows of the asset or assuming a\ncontractual obligation to pay such cash \ue61dows to one or\nmore bene\ue61eciaries under a contract that meets the re-\nquirements provided by IFRS 9 (the \u201cpass through test\u201d);\n\u2022 the Group has not transferred or retained substantially \nall the risks and rewards associated with the asset but\nhas transferred control over the asset.\nFinancial liabilities are derecognized when they are extin-\nguished, i.e., when the contractual obligation has been dis-\ncharged, cancelled or expired.\nWhen an existing \ue61enancial liability is replaced by another\nfrom the same lender on substantially di\ue61berent terms, or\nthe terms of an existing liability are substantially modi-\n\ue61eed, such an exchange or modi\ue61ecation is treated as the\nderecognition of the original liability and the recognition\nof a new liability. The di\ue61berence in the respective carrying\namounts is recognized in pro\ue61et or loss.\nDerivative \ue61fnancial instruments\nA derivative is a \ue61enancial instrument or another contract:\n\u2022 whose value changes in response to the changes in an \nunderlying variable such as an interest rate, commodity\nor security price, foreign exchange rate, a price or rate\nindex, a credit rating or other variable;\n\u2022 that requires no initial net investment, or one that is \nsmaller than would be required for a contract with simi-\nlar response to changes in market factors;\n\u2022 that is se\ue61cled at a future date.\nDerivative instruments are classi\ue61eed as \ue61enancial assets or\nliabilities depending on the positive or negative fair value\nand they are classi\ue61eed as \u201cheld for trading\u201d within \u201cOther\n\nbusiness models\u201d and measured at fair value through prof-\nit or loss, except for those designated as e\ue61bective hedging\ninstruments.\nAll derivatives held for trading are classi\ue61eed as current as-\nsets or liabilities.\nDerivatives not held for trading purposes, but measured at\nfair value through pro\ue61et or loss since they do not qualify for\nhedge accounting, and derivatives designated as e\ue61bective\nhedging instruments are classi\ue61eed as current or not cur-\nrent on the basis of their maturity date and the Group in-\ntention to hold the \ue61enancial instrument till maturity or not.\nFor more details about derivatives and hedge accounting,\nplease see note 49 \u201cDerivatives and hedge accounting\u201d.\nEmbedded derivatives\nAn embedded derivative is a derivative included in a \n\u201ccombined\u201d contract (the so-called \u201chybrid instrument\u201d)\nthat contains another non-derivative contract (the so-\ncalled \u201chost contract\u201d) and gives rise to some or all of the \ncombined contract\u2019s cash \ue61dows.\nThe main Group contracts that may contain embedded\nderivatives are contracts to buy or sell non-\ue61enancial items\nwith clauses or options that a\ue61bect the contract price, vol-\nume or maturity.\nA derivative embedded in a hybrid contract containing a\n\ue61enancial asset host is not accounted for separately. The\n\ue61enancial asset host together with the embedded deriva-\ntive is required to be classi\ue61eed in its entirety as a \ue61enancial\nasset at fair value through pro\ue61et or loss.\nContracts that do not represent \ue61enancial instruments to\nbe measured at fair value are analyzed in order to iden-\ntify any embedded derivatives, which are to be separat-\ned and measured at fair value. This analysis is pe\ue619ormed\nwhen the Group becomes pa\ue61fy to the contract or when\nthe contract is renegotiated in a manner that signi\ue61ecantly\nchanges the original associated cash \ue61dows.\nEmbedded derivatives are separated from the host con-\ntract and accounted for as derivatives when:\n\u2022 the host contract is not a \ue61enancial instrument meas-\nured at fair value through pro\ue61et or loss;\n\u2022 the economic risks and characteristics of the embed-\nded derivative are not closely related to those of the\nhost contract;\n\u2022 a separate contract with the same terms as the em-\nbedded derivative would meet the de\ue61enition of a de-\nrivative.\nEmbedded derivatives that are separated from the host\ncontract are recognized in the consolidated \ue61enancial\nstatements at fair value with changes recognized in pro\ue61et\nor loss (except when the embedded derivative is pa\ue61f of a\ndesignated hedge relationship).\nContracts to buy or sell non-\ue61fnancial items\nIn general, contracts to buy or sell non-\ue61enancial items\nthat are entered into and continue to be held for receipt\nor delivery in accordance with the Group\u2019s normal ex-\npected purchase, sale or usage requirements are out of\nthe scope of IFRS 9 and then recognized as executory\ncontracts, according to the \u201cown use exemption\u201d.\nA contract to buy or sell non-\ue61enancial items is classi\ue61eed as\n\u201cnormal purchase or sale\u201d if it is entered into:\n\u2022 for the purpose of the physical se\ue61clement;\n\u2022 in accordance with the entity\u2019s expected purchase, sale \nor usage requirements.\nMoreover, contracts to buy or sell non-\ue61enancial items with\nphysical se\ue61clement (for example, \ue61exed-price forward con-\ntracts on energy commodities) do not qualify for the own\nuse exemption and are recognized as derivatives meas-\nured at fair value through pro\ue61et or loss only if:\n\u2022 they can be se\ue61cled net in cash; and\n\u2022 they are not entered into in accordance with the Group\u2019s \nexpected purchase, sale or usage requirements.\nThe Group recognizes the fair value gain or loss on con-\ntracts for the purchase or sale of energy commodities still\noutstanding at the repo\ue61fing date on a net basis under the\nitem \u201cNet results from commodity contracts\u201d.\nSubsequently, at the se\ue61clement date:\n\u2022 the fair value gain or loss on closed contracts for the \nsale of energy commodities as well as the related rev-\nenue, together with the impact on pro\ue61et or loss of the\nderecognition of the derivative, are recognized under\n\u201cOther revenue\u201d;\n\u2022 the fair value gain or loss on closed contracts for the \npurchase of energy commodities as well as the related\ncost, together with the impact on pro\ue61et or loss of the\nderecognition of the derivative, are recognized under\n\u201cElectricity, gas and fuel\u201d and \u201cServices and other ma-\nterials\u201d.\nThe Group analyzes all contracts to buy or sell non-\ue61e-\nnancial assets on an ongoing basis, with a speci\ue61ec focus\non forward purchases and sales of electricity and energy\ncommodities, in order to determine if they shall be classi-\n\ue61eed and treated in accordance with IFRS 9 or if they have\nbeen entered into for \u201cown use\u201d.\nO\ue61cse\ue61bing \ue61fnancial assets and liabilities\nThe Group o\ue61bsets \ue61enancial assets and liabilities when:\n\u2022 there is a legally enforceable right to set o\ue61b the recog-\nnized amounts; and\n\u2022 there is the intention of se\ue61cling on a net basis or real-\nizing the asset and se\ue61cling the liability simultaneously.\nHyperin\ue61dation\nIn a hyperin\ue61dationary economy, the Group adjusts\nnon-monetary items, equity and items deriving from in-\ndex-linked contracts up to the limit of recoverable amount,\nusing a price index that re\ue61dects changes in general pur-\nchasing power.\nThe e\ue61bects of initial application are recognized in equity\n\nnet of tax e\ue61bects. Conversely, during the hyperin\ue61dation-\nary period (until it ceases), the gain or loss resulting from\nadjustments is recognized in pro\ue61et or loss and disclosed \nseparately in \ue61enancial income and expense. \nSta\ue61fing from 2018, this standard applies to the Group\u2019s \ntransactions in Argentina, whose economy has been de-\nclared hyperin\ue61dationary from July 1, 2018.\nNon-current assets (or disposal groups) \nclassi\ue61fed as held for sale and discontinued\noperations\nNon-current assets (or disposal groups) are classi\ue61eed \nas held for sale if their carrying amount will be recov-\nered principally through a sale transaction, rather than\nthrough continuing use.\nThis classi\ue61ecation criterion is applicable only when\nnon-current assets (or disposal groups) are available in\ntheir present condition for immediate sale and the sale is\nhighly probable.\nIf the Group is commi\ue61ced to a sale plan involving loss of\ncontrol of a subsidiary and the requirements provided for \nunder IFRS 5 are met, all the assets and liabilities of that\nsubsidiary are classi\ue61eed as held for sale when the classi-\n\ue61ecation criteria are met, regardless of whether the Group\nwill retain a non-controlling interest in its former subsid-\niary after the sale.\nThe Group applies these classi\ue61ecation criteria as envis-\naged in IFRS 5 to an investment, or a po\ue61fion of an in-\nvestment, in an associate or a joint venture. Any retained\npo\ue61fion of an investment in an associate or a joint venture\nthat has not been classi\ue61eed as held for sale is accounted\nfor using the equity method until disposal of the po\ue61fion\nthat is classi\ue61eed as held for sale takes place.\nNon-current assets (or disposal groups) and liabilities of\ndisposal groups classi\ue61eed as held for sale are presented \nseparately from other assets and liabilities in the state-\nment of \ue61enancial position.\nThe amounts presented for non-current assets or for the\nassets and liabilities of disposal groups classi\ue61eed as held \nfor sale are not reclassi\ue61eed or re-presented for prior pe-\nriods presented.\nImmediately before the initial classi\ue61ecation of non-cur-\nrent assets (or disposal groups) as held for sale, the car-\nrying amounts of such assets (or disposal groups) are\nmeasured in accordance with the accounting standard\napplicable to those assets or liabilities. Non-current as-\nsets (or disposal groups) classi\ue61eed as held for sale are\nmeasured at the lower of their carrying amount and fair\nvalue less costs to sell. Impairment losses for any initial or\nsubsequent write-down of the assets (or disposal groups)\nto fair value less costs to sell and gains for their reversals\nare recognized in pro\ue61et or loss from continuing opera-\ntions.\nNon-current assets are not depreciated (or amo\ue61fized)\nwhile they are classi\ue61eed as held for sale or while they are\npa\ue61f of a disposal group classi\ue61eed as held for sale.\nIf the classi\ue61ecation criteria are no longer met, the Group\nceases to classify the non-current assets (or disposal\ngroups) as held for sale. In this case they are measured\nat the lower of:\n\u2022 the carrying amount before the asset (or disposal \ngroup) was classi\ue61eed as held for sale, adjusted for any\ndepreciation, amo\ue61fization or reversals of impairment\nlosses that would have been recognized if the asset \n(or disposal group) had not been classi\ue61eed as held for\nsale; and\n\u2022 the recoverable amount, which is equal to the greater \nof its fair value net of costs to sell and its value in use,\nas calculated at the date of the subsequent decision\nnot to sell.\nAny adjustment to the carrying amount of a non-current\nasset that ceases to be classi\ue61eed as held for sale is in-\ncluded in pro\ue61et or loss from continuing operations.\nA discontinued operation is a component of the Group\nthat either has been disposed of, or is classi\ue61eed as held \nfor sale, and:\n\u2022 represents a separate major business line or geo-\ngraphical segment;\n\u2022 is pa\ue61f of a single coordinated plan to dispose of a sep-\narate major business line or geographical segment; or\n\u2022 is a subsidiary acquired exclusively with a view to re-\nsale.\nThe Group presents, in a separate line item of the income\nstatement, a single amount comprising the total of:\n\u2022 the post-tax pro\ue61et or loss of discontinued operations; \nand\n\u2022 the post-tax gain or loss recognized on the measure-\nment at fair value less costs to sell or on the disposal\nof the assets or disposal groups constituting the dis-\ncontinued operation.\nThe corresponding amount is restated in the income \nstatement for prior periods presented in the \ue61enancial\nstatements, so that the disclosures relate to all operations \nthat are discontinued by the end of the current repo\ue61f-\ning period. If the Group ceases to classify a component\nas held for sale, the results of the component previously\npresented in discontinued operations are reclassi\ue61eed and\nincluded in pro\ue61et or loss from continuing operations for\nall periods presented. \nEnvironmental ce\ue61ei\ue61fcates\nSome Group companies are a\ue61bected by national regula-\ntions governing green ce\ue61fi\ue61ecates and energy e\ue61aciency\nce\ue61fi\ue61ecates (so-called \u201cwhite ce\ue61fi\ue61ecates\u201c), as well as the \nEU Emissions Trading System.\nGreen ce\ue61fi\ue61ecates accrued in propo\ue61fion to electricity\ngenerated by renewable energy plants and energy e\ue61a-\nciency ce\ue61fi\ue61ecates accrued in propo\ue61fion to energy sav-\n\nings achieved that have been ce\ue61fi\ue61eed by the compe-\ntent authority are treated as non-monetary government\ngrants related to income and are recognized at fair value,\nunder other operating pro\ue61et, with recognition of an as-\nset under other non-\ue61enancial assets, if the ce\ue61fi\ue61ecates\nare not yet credited to the ownership account, or under\ninventories, if the ce\ue61fi\ue61ecates have already been credited\nto that account.\nAt the time the ce\ue61fi\ue61ecates are credited to the ownership\naccount, they are reclassi\ue61eed from other assets to inven-\ntories.\nRevenue from the sale of such ce\ue61fi\ue61ecates is recognized\nunder revenue from contracts with customers, with a\ncorresponding decrease in inventories.\nFor the purposes of accounting for charges arising from \nregulatory requirements concerning green ce\ue61fi\ue61ecates,\nenergy e\ue61aciency ce\ue61fi\ue61ecates and CO\n2\n emissions allow-\nances, the Group uses the \u201cnet liability approach\u201d.\nUnder this accounting policy, environmental ce\ue61fi\ue61ecates\nreceived free of charge and those self-produced as a \nresult of Group\u2019s operations that will be used for com-\npliance purposes are recognized at nominal value (nil). In\naddition, charges incurred for obtaining (in the market or\nin some other transaction for consideration) any missing\nce\ue61fi\ue61ecates to ful\ue61el compliance requirements for the re-\npo\ue61fing period are recognized through pro\ue61et or loss on an\naccruals basis under other operating costs, as they rep-\nresent \u201csystem charges\u201d consequent to compliance with \na regulatory requirement.\nEmployee bene\ue61fts\nLiabilities related to employee bene\ue61ets paid upon or after\nceasing employment in connection with de\ue61ened bene-\n\ue61et plans or other long-term bene\ue61ets accrued during the \nemployment period are determined separately for each \nplan, using actuarial assumptions to estimate the amount\nof the future bene\ue61ets that employees have accrued at the \nrepo\ue61fing date (using the projected unit credit method). \nMore speci\ue61ecally, the present value of the de\ue61ened bene\ue61et\nobligation is calculated by using a discount rate deter-\nmined on the basis of market yields at the end of the re-\npo\ue61fing period on high-quality corporate bonds. If there\nis no deep market for high-quality corporate bonds in the\ncurrency in which the bonds are denominated, the corre-\nsponding yield of government securities is used.\nThe liability, net of any plan assets, is recognized on an \naccruals basis over the vesting period of the related\nrights. These appraisals are pe\ue619ormed by independent \nactuaries.\nIf the plan assets exceed the present value of the related\nde\ue61ened bene\ue61et obligation, the surplus (up to the limit of\nany cap) is recognized as an asset.\nAs regards the liabilities/(assets) of de\ue61ened bene\ue61et plans,\nthe cumulative actuarial gains and losses from the ac-\ntuarial measurement of the liabilities, the return on the\nplan assets (net of the associated interest income) and\nthe e\ue61bect of the asset ceiling (net of the associated inter-\nest) are recognized in other comprehensive income when\nthey occur. For other long-term bene\ue61ets, the related ac-\ntuarial gains and losses are recognized through pro\ue61et or\nloss. \nIn the event of a change being made to an existing de-\n\ue61ened bene\ue61et plan or the introduction of a new plan, any\npast service cost is recognized immediately in pro\ue61et or \nloss. \nIn addition, the Group is involved in de\ue61ened contribution\nplans under which it pays \ue61exed contributions to a sepa-\nrate entity (a fund) and has no legal or constructive obli-\ngation to pay fu\ue61fher contributions if the fund does not\nhold su\ue61acient assets to pay all employee bene\ue61ets relat-\ning to employee service in the current and prior periods. \nSuch plans are usually aimed to supplement pension \nbene\ue61ets due to employees post-employment. The related\ncosts are recognized through pro\ue61et or loss on the basis\nof the amount of contributions paid in the period.\nTermination bene\ue61fts\nLiabilities for bene\ue61ets due to employees for the early ter-\nmination of employee service arise out of the Group\u2019s de-\ncision to terminate an employee\u2019s employment before the\nnormal retirement date or an employee\u2019s decision to ac-\ncept an o\ue61ber of bene\ue61ets in exchange for the termination\nof employment. The event that gives rise to an obligation \nis the termination of employment rather than employee\nservice. Termination bene\ue61ets are recognized at the earlier \nof the following dates:\n\u2022 when the entity can no longer withdraw its o\ue61ber of \nbene\ue61ets; and\n\u2022 when the entity recognizes a cost for a restructuring \nthat is within the scope of IAS 37 and involves the pay-\nment of termination bene\ue61ets.\nThe liabilities are measured on the basis of the nature of\nthe employee bene\ue61ets. More speci\ue61ecally, when the ben-\ne\ue61ets represent an enhancement of other post-employ-\nment bene\ue61ets, the associated liability is measured in ac-\ncordance with the rules governing that type of bene\ue61ets.\nOtherwise, if the termination bene\ue61ets due to employees\nare expected to be fully se\ue61cled before 12 months of the\nclose of the period in which the bene\ue61ets are recognized,\nthe entity measures the liability in accordance with the\nrequirements for sho\ue61f-term employee bene\ue61ets; if they\nare not expected to be fully se\ue61cled before 12 months of\nthe close of period in which the bene\ue61ets are recognized,\nthe entity measures the liability in accordance with the\nrequirements for other long-term employee bene\ue61ets.\nShare-based payments\nThe Group unde\ue61fakes share-based payment transac-\ntions se\ue61cled with equity instruments as pa\ue61f of the remu-\n\nneration policy adopted for the Chief Executive O\ue61acer/\nGeneral Manager and for key management personnel.\nThe most recent long-term incentive plans provide for\nthe grant to recipients of an incentive represented by an \nequity component and a monetary component.\nIn order to se\ue61cle the equity component through the bo-\nnus award of Enel shares, a program for the purchase of\ntreasury shares to suppo\ue61f these plans was approved. For\nmore details on share-based incentive plans, please see \nnote 51 \u201cShare-based payments\u201d.\nThe Group recognizes the services rendered by employ-\nees as personnel expenses and indirectly estimates their\nvalue, and the corresponding increase in equity, on the\nbasis of the fair value of the equity instruments (i.e., Enel \nshares) at the grant date. This fair value is based on the\nobservable market price of Enel (on the Mercato Tele-\nmatico Azionario (electronic stock exchange) organized\nand operated by Borsa Italiana SpA), taking account of\nthe terms and conditions under which the shares were\ngranted (with the exception of vesting conditions exclud-\ned from the measurement of fair value).\nThe cost of these share-based payment transactions set-\ntled with equity instruments is recognized through pro\ue61et\nor loss, with a balancing entry in a speci\ue61ec equity item, \nover the period in which the service and return pe\ue619or-\nmance conditions are met (vesting period).\nThe overall expense recognized is adjusted at each re-\npo\ue61fing date until the vesting date to re\ue61dect the best\nestimate available to the Group of the number of equity\ninstruments for which the service and pe\ue619ormance con-\nditions other than market conditions will be satis\ue61eed, so\nthat the amount recognized at the end is based on the \ne\ue61bective number of equity instruments that satisfy the\nservice and pe\ue619ormance conditions other than market\nconditions at the vesting date.\nNo expense is recognized for awards which ultimately do\nnot vest because the pe\ue619ormance conditions other than\nmarket conditions and/or the service conditions have not\nbeen satis\ue61eed. Conversely, the transactions are consid-\nered to have vested irrespective of whether the market\nor non-vesting conditions are satis\ue61eed, provided that all\nthe other pe\ue619ormance and/or service conditions are sat-\nis\ue61eed.\nProvisions for risks and charges\nProvisions are recognized where there is a legal or con-\nstructive obligation as a result of a past event at the end\nof the repo\ue61fing period, the se\ue61clement of which is expect-\ned to result in an out\ue61dow of resources whose amount can \nbe reliably estimated. Where the impact is signi\ue61ecant, the \naccruals are determined by discounting expected future\ncash \ue61dows using a pre-tax discount rate that re\ue61dects the\ncurrent market assessment of the time value of money\nand, if applicable, the risks speci\ue61ec to the liability.\nIf the provision is discounted, the periodic adjustment of\nthe present value for the time factor is recognized as a\n\ue61enancial expense.\nWhen the Group expects some or all charges to be reim-\nbursed, the reimbursement is recognized as a separate\nasset, but only when the reimbursement is vi\ue61fually ce\ue61fain.\nWhere the liability relates to decommissioning and/or site\nrestoration in respect of prope\ue61fy, plant and equipment,\nthe initial recognition of the provision is made against the\nrelated asset and the expense is then recognized in pro\ue61et \nor loss through the depreciation of the asset involved.\nWhere the liability regards the treatment and storage of\nnuclear waste and other radioactive materials, the pro-\nvision is recognized against the related operating costs.\nA liability for restructuring refers to a program planned\nand controlled by management that materially changes\nthe scope of a business unde\ue61faken by the Group or the\nmanner in which the business is conducted. Such a lia-\nbility is recognized when a constructive obligation is es-\ntablished, i.e., when the Group has approved a detailed\nformal restructuring plan and has sta\ue61fed to implement\nthe plan or has announced its main features to those af-\nfected by it.\nProvisions do not include liabilities in respect of unce\ue61fain\nincome tax treatments that are recognized as tax liabili-\nties.\nThe Group could provide a warranty in connection with\nthe sale of a product (whether a good or service) from\ncontracts with customers in the scope of IFRS 15, in ac-\ncordance with the contract, the law or its customary busi-\nness practices. In this case, the Group assesses whether\nthe warranty provides the customer with assurance that\nthe related product will function as the pa\ue61fies intended\nbecause it complies with agreed-upon speci\ue61ecations or\nwhether the warranty provides the customer with a ser-\nvice in addition to the assurance that the product com-\nplies with agreed-upon speci\ue61ecations.\nAfter the assessment, if the Group establishes that an\nassurance warranty is provided, it recognizes a separate\nwarranty liability and corresponding expense when trans-\nferring the product to the customer, as additional costs of\nproviding goods or services, without a\ue61cributing any of the\ntransaction price (and therefore revenue) to the warranty.\nThe liability is measured and presented as a provision.\nOtherwise, if the Group determines that a service warran-\nty is provided, it accounts for the promised warranty as a\npe\ue619ormance obligation in accordance with IFRS 15, rec-\nognizing the contract liability as revenue over the period\nthe warranty service is provided and the costs associated\nas they are incurred.\nFinally, if the warranty includes both an assurance ele-\nment and a service element and the Group cannot rea-\nsonably account for them separately, then it accounts for\nboth of the warranties together as a single pe\ue619ormance\nobligation.\n\nIn the case of contracts in which the unavoidable costs of\nmeeting the obligations under the contract exceed the\neconomic bene\ue61ets expected to be received under it (on-\nerous contracts), the Group recognizes a provision as the\nlower of the excess of unavoidable costs of meeting the \nobligations under the contract over the economic bene-\n\ue61ets expected to be received under it and any compensa-\ntion or penalty arising from failure to ful\ue61el it.\nChanges in estimates of accruals to the provisions ad-\ndressed here are recognized through pro\ue61et or loss in the\nperiod in which the changes occur, with the exception of\nthose in the costs of decommissioning, retiring and/or\nrestoration resulting from changes in the timetable and\ncosts necessary to extinguish the obligation or from a\nchange in the discount rate. These changes increase or\ndecrease the carrying amount of the related assets and\nare taken to pro\ue61et or loss through depreciation. Where\nthey increase the carrying amount of the assets, it is also\ndetermined whether the new carrying amount of the as-\nsets is fully recoverable. If this is not the case, a loss equal\nto the unrecoverable amount is recognized through pro\ue61et \nor loss. \nDecreases in estimates are recognized up to the carrying \namount of the assets. Any excess is recognized immedi-\nately in pro\ue61et or loss.\nFor more information on the estimation criteria adopted\nin determining provisions for retiring and/or restoration\nof prope\ue61fy, plant and equipment, especially those asso-\nciated with decommissioning nuclear power plants and \nstorage of waste fuel and other radioactive materials,\nplease see note 2.1 \u201cUse of estimates and management\njudgment\u201d.\nRevenue from contracts with customers\nThe Group recognizes revenue from contracts with cus-\ntomers in order to represent the transfer of promised\ngoods or services to the customers at an amount that\nre\ue61dects the consideration to which the Group expects to\nbe entitled in exchange for those goods or services.\nThe Group applies this core principle using a \ue61eve-step\nmodel:\n\u2022 identify the contract with the customer (step 1).\n The Group applies IFRS 15 to contracts with customers \nin the scope of the standard when the contract is le-\ngally enforceable and all the criteria envisaged for step \n1 are met:\n If the criteria are not met, any consideration received\nfrom the customer is generally recognized as an ad-\nvance;\n\u2022 identify the pe\ue619ormance obligations in the contract \n(step 2).\n The Group identi\ue61ees all goods or services promised in\nthe contract, separating them into pe\ue619ormance obli-\ngations to account for separately if they are both: ca-\npable of being distinct and distinct within the context\nof the contract.\n As an exception, the Group accounts for as a single \npe\ue619ormance obligation a series of distinct goods or\nservices that are substantially the same and that have\nthe same pa\ue61cern of transfer to the customer over\ntime.\n In assessing the existence and the nature of the per-\nformance obligations, the Group considers all of the \ncontract\u2019s features as mentioned in step 1.\n For each distinct good or service identi\ue61eed, the Group\ndetermines whether it acts as a principal or agent,\nrespectively if it controls or not the speci\ue61eed good\nor service that is promised to the customer before\nits control is transferred to the customer. When the\nGroup acts as agent, it recognizes revenue on a net\nbasis, corresponding to any fee or commission to\nwhich it expects to be entitled;\n\u2022 determine the transaction price (step 3).\n The transaction price represents the amount of con-\nsideration to which the Group expects to be entitled in\nexchange for transferring goods or services to a cus-\ntomer, excluding amounts collected on behalf of third\npa\ue61fies (e.g., some sale taxes and value-added taxes).\n The Group determines the transaction price at incep-\ntion of the contract and updates it each repo\ue61fing pe-\nriod for any changes in circumstances.\n When the Group determines the transaction price, it\nconsiders whether the transaction price includes var-\niable consideration, non-cash consideration received\nfrom a customer, consideration payable to a customer \nand a signi\ue61ecant \ue61enancing component;\n\u2022 allocate the transaction price (step 4).\n The Group allocates the transaction price at contract\ninception to each separate pe\ue619ormance obligation \nto depict the amount of consideration to which the\nGroup expects to be entitled in exchange for transfer-\nring the promised goods or services.\n When the contract includes a customer option to\nacquire additional goods or services that represents\na material right, the Group allocates the transaction \nprice to this pe\ue619ormance obligation (i.e., the option) \nand defers the relative revenue until those future\ngoods or services are transferred or the option ex-\npires.\n The Group generally allocates the transaction price on\nthe basis of the relative stand-alone selling price of \neach distinct good or service promised in the contract\n(that is, the price at which the Group would sell that\ngood or service separately to the customer);\n\u2022 recognize revenue (step 5).\n The Group recognizes revenue when (or as) each pe\ue619or-\nmance obligation is satis\ue61eed by transferring the prom-\nised good or service to the customer, which is when the\ncustomer obtains control of the good or service.\n\n To this end, the Group \ue61erst determines if one of the\nover-time criteria is met.\n For each pe\ue619ormance obligation satis\ue61eed over time,\nthe Group recognizes revenue over time by measuring\nprogress toward the complete satisfaction of that per-\nformance obligation using an output method or an in-\nput method and applies a single method of measuring\nprogress from contract inception until full satisfaction\nand to similar pe\ue619ormance obligations and in similar\ncircumstances.\n When the Group cannot reasonably measure the pro-\ngress, it recognizes revenue only to the extent of the\ncosts incurred that are considered recoverable.\n If the pe\ue619ormance obligation is not satis\ue61eed over time,\nthe Group determines the point in time at which the \ncustomer obtains the control, considering whether the\nindicators of the transfer of control collectively indi-\ncate that the customer has obtained control.\n Depending on the type of transaction, the broad crite-\nria used under IFRS 15 are summarized below: \n \u2013 revenue from the sale of goods is recognized at \nthe point in time at which the customer obtains the\ncontrol of goods if the Group considers that the\nsale of goods is satis\ue61eed at a point in time;\n \u2013 revenue from providing services is recognized on \nthe basis of the progress towards complete sat-\nisfaction of the pe\ue619ormance obligation measured\nwith an appropriate method that be\ue61cer depicts\nthis progress if the Group considers that the per-\nformance obligation is satis\ue61eed over time. The cost\nincurred method (cost-to-cost method) is consid-\nered appropriate for measuring progress, except\nwhen speci\ue61ec contract analyses suggest the use\nof an alternative method, which be\ue61cer depicts the\nGroup\u2019s pe\ue619ormance obligation ful\ue61elled at the re-\npo\ue61fing date.\nThe Group does not disclose the information about the\nremaining pe\ue619ormance obligations in existing contracts\nif the pe\ue619ormance obligation is pa\ue61f of a contract that \nhas an original expected duration of one year or less and\nif the Group recognizes revenue in the amount to which it \nhas a right to invoice the customer.\nMore information on the application of this revenue rec-\nognition model is provided in note 2.1 \u201cUse of estimates\nand management judgment\u201d and in note 10.a \u201cRevenue\nfrom sales and services\u201d.\nIf the Group pe\ue619orms by transferring goods or services\nto a customer before the customer pays the consider-\nation or before payment is due, it recognizes a contract\nasset relating to the right to consideration in exchange \nfor goods or services transferred to the customer.\nIf a customer pays the consideration before the Group \ntransfers goods or services to the customer, the Group\nrecognizes a contract liability when the payment is made\n(or the payment is due) that is recognized as revenue \nwhen the Group pe\ue619orms under the contract.\nOther revenue\nThe Group recognizes revenue other than that deriving\nfrom contracts with customers mainly referring to:\n\u2022 revenue from the sale of energy commodities based \non contracts with physical se\ue61clement, which do not\nqualify for the own use exemption and therefore is\nrecognized at FVTPL in accordance with IFRS 9;\n\u2022 changes in the fair value of se\ue61cled contracts to sell en-\nergy commodities with physical se\ue61clement, which do\nnot qualify for the own use exemption and therefore\nare recognized at FVTPL in accordance with IFRS 9;\n\u2022 operating lease revenue accounted for on an accruals \nbasis in accordance with the substance of the relevant \nlease agreement.\nOther operating income\nOther operating income primarily includes gains on dis-\nposal of assets that are not an output of the Group\u2019s ordi-\nnary activities and government grants.\nGrants related to assets, including non-monetary grants\nat fair value, are recognized where there is reasonable\nassurance that they will be received and that the Group\nwill comply with all conditions a\ue61caching to them as set by\nthe government, government agencies and similar bodies\nwhether local, national or international.\nWhen loans are provided by governments at a below-mar-\nket rate of interest, the bene\ue61et is regarded as a govern-\nment grant. The loan is initially recognized and measured\nat fair value and the government grant is measured as the \ndi\ue61berence between the initial carrying amount of the loan\nand the funds received. The loan is subsequently meas-\nured in accordance with the requirements for \ue61enancial\nliabilities.\nGovernment grants are recognized in pro\ue61et or loss on a\nsystematic basis over the periods in which the Group rec-\nognizes as expenses the costs that the grants are intend-\ned to compensate.\nWhere the Group receives government grants in the form\nof a transfer of a non-monetary asset for the use of the\nGroup, it accounts for both the grant and the asset at the\nfair value of the non-monetary asset received at the date\nof the transfer.\nCapital grants, including non-monetary grants at fair val-\nue, i.e., those received to purchase, build or otherwise ac-\nquire non-current assets (for example, an item of prope\ue61fy,\nplant and equipment or an intangible asset), are deducted\nfrom the carrying amount of the asset and are recognized\nin pro\ue61et or loss over the depreciable/amo\ue61fizable life of\nthe asset as a reduction in the depreciation/amo\ue61fization\ncharge. If there is insu\ue61acient information to enable ade-\n\nquate a\ue61cribution to the non-current assets to which they\nrefer, grants related to assets are recognized as deferred\nincome under other liabilities, and credited to pro\ue61et or loss\non a systematic basis over the useful life of the asset.\nFinancial income and expense from\nderivatives\nFinancial income and expense from derivatives includes: \n\u2022 income and expense from derivatives measured at fair \nvalue through pro\ue61et or loss on interest rate and cur-\nrency risks;\n\u2022 income and expense from fair value hedge derivatives \non interest rate risk;\n\u2022 income and expense from cash \ue61dow hedge derivatives \non interest rate and currency risks.\nOther \ue61fnancial income and expense \nFor all \ue61enancial assets and liabilities measured at amor-\ntized cost and interest-bearing \ue61enancial assets classi\ue61eed\nas at fair value through other comprehensive income, in-\nterest income and expense are recognized using the ef-\nfective interest rate method.\nInterest income is recognized to the extent that it is prob-\nable that the economic bene\ue61ets will \ue61dow to the Group and \nthe amount can be reliably measured.\nOther \ue61enancial income and expense include also changes \nin the fair value of \ue61enancial instruments other than de-\nrivatives.\nDividends\nDividends are recognized when the unconditional right to\nreceive payment is established.\nDividends and interim dividends payable to the Parent\u2019s\nshareholders and non-controlling interests are recog-\nnized as changes in equity in the period in which they are \napproved by the Shareholders\u2019 Meeting and the Board of\nDirectors, respectively.\nIncome taxes\nCurrent income taxes\nCurrent income taxes for the year, which are recognized\nunder \u201cincome tax liabilities\u201d net of payments on account,\nor under \u201ctax assets\u201d where there is a credit balance, are\ndetermined using an estimate of taxable income and in \nconformity with the applicable regulations.\nSuch liabilities and assets are determined using the tax\nrates and tax laws that are enacted or substantively en-\nacted by the end of the repo\ue61fing period in the countries\nwhere taxable income has been generated.\nCurrent income taxes are recognized in pro\ue61et or loss with\nthe exception of current income taxes related to items\nrecognized outside pro\ue61et or loss that are recognized in\nequity.\nDeferred tax liabilities and assets\nDeferred tax liabilities and assets are calculated on the \ntemporary di\ue61berences between the carrying amounts of\nliabilities and assets in the \ue61enancial statements and their\ncorresponding amounts recognized for tax purposes on\nthe basis of tax rates in e\ue61bect on the date the temporary\ndi\ue61berence will reverse, which is determined on the basis\nof tax rates that are enacted or substantively enacted as\nat the end of the repo\ue61fing period.\nDeferred tax liabilities are recognized for all taxable tem-\nporary di\ue61berences, except when such liability arises from\nthe initial recognition of goodwill or in respect of taxa-\nble temporary di\ue61berences associated with investments\nin subsidiaries, associates and joint ventures, when the\nGroup can control the timing of the reversal of the tem-\nporary di\ue61berences and it is probable that the temporary\ndi\ue61berences will not reverse in the foreseeable future.\nDeferred tax assets are recognized for all deductible tem-\nporary di\ue61berences, the carry forward of tax losses and any\nunused tax credits. For more information concerning the\nrecoverability of such assets, please see the appropriate\nsection of the discussion of estimates.\nDeferred taxes and liabilities are recognized in pro\ue61et or\nloss, with the exception of those in respect of items rec-\nognized outside pro\ue61et or loss that are recognized in eq-\nuity.\nDeferred tax assets and deferred tax liabilities are o\ue61bset\nonly if there is a legally enforceable right to o\ue61bset current \ntax assets with current tax liabilities and when they relate \nto income taxes levied by the same taxation authority on\neither the same taxable entity or di\ue61berent taxable entities \nwhich intend either to se\ue61cle current tax liabilities and as-\nsets on a net basis, or to realize the assets and se\ue61cle the\nliabilities simultaneously, in each future period in which\nsigni\ue61ecant amounts of deferred tax liabilities or assets are\nexpected to be se\ue61cled or recovered.\nUnce\ue61eainty over income tax treatments\nIn de\ue61ening \u201cunce\ue61fainty\u201c, it shall be considered whether a \npa\ue61ficular tax treatment will be accepted by the relevant \ntaxation authority. If it is deemed probable that the tax \ntreatment will be accepted (where the term \u201cprobable\u201c is \nde\ue61ened as \u201cmore likely than not\u201c), then the Group rec-\nognizes and measures its current/deferred tax asset or\nliabilities applying the requirements in IAS 12.\nConversely, when the Group feels that it is not likely that\nthe taxation authority will accept the tax treatment for\nincome tax purposes, the Group re\ue61dects the unce\ue61fainty\nin the manner that best predicts the resolution of the un-\nce\ue61fain tax treatment. The Group determines whether to\nconsider each unce\ue61fain tax treatment separately or to-\ngether with one or more other unce\ue61fain tax treatments \n\nbased on which approach provides be\ue61cer predictions of\nthe resolution of the unce\ue61fainty. In assessing whether\nand how the unce\ue61fainty a\ue61bects the tax treatment, the\nGroup assumes that a taxation authority will accept or\nnot an unce\ue61fain tax treatment supposing that the tax-\nation authority will examine amounts it has a right to ex-\namine and have full knowledge of all related information\nwhen making those examinations. The Group re\ue61dects the\ne\ue61bect of unce\ue61fainty in accounting for current and de-\nferred tax using the expected value or the most likely\namount, whichever method be\ue61cer predicts the resolution\nof the unce\ue61fainty.\nSince unce\ue61fain income tax positions meet the de\ue61enition\nof income taxes, the Group presents unce\ue61fain tax liabili-\nties/assets as current tax liabilities/assets or deferred tax\nliabilities/assets.\n\n(22) \u201cInformation is material if omi\ue61cing, misstating or obscuring it could reasonably be expected to in\ue61duence the decisions that the primary users of general \npurpose \ue61enancial statements make on the basis of those \ue61enancial statements, which provide \ue61enancial information about a speci\ue61ec repo\ue61fing entity.\u201d\n2. Accounting policies \n2.1 Use of estimates and management\njudgment\nPreparing the consolidated \ue61enancial statements under IF-\nRS-EU requires management to take decisions and make\nestimates and assumptions that may impact the carrying\namounts of revenue, costs, assets and liabilities and the re-\nlated disclosures concerning the items involved as well as\ncontingent assets and liabilities at the repo\ue61fing date. The\nestimates and management\u2019s judgments are based on pre-\nvious experience and other factors considered reasonable\nin the circumstances. They are formulated when the carry-\ning amount of assets and liabilities is not easily determined \nfrom other sources. The actual results may therefore di\ue61ber\nfrom these estimates. The estimates and assumptions are\nperiodically revised and the e\ue61bects of any changes are re-\n\ue61dected through pro\ue61et or loss if they only involve that period.\nIf the revision involves both the current and future periods,\nthe change is recognized in the period in which the revision\nis made and in the related future periods.\nIn order to enhance understanding of the consolidated \ue61e-\nnancial statements, the following sections examine the main\nitems a\ue61bected by the use of estimates and the cases that\nre\ue61dect management judgments to a signi\ue61ecant degree, un-\nderscoring the main assumptions used by management in\nmeasuring these items in compliance with the IFRS-EU. The\ncritical element of such valuations is the use of assumptions\nand professional judgments concerning issues that are by \ntheir very nature unce\ue61fain.\nChanges in the conditions underlying the assumptions and\njudgments could have a substantial impact on future results.\nThe information included in the consolidated \ue61enancial\nstatements is selected on the basis of a materiality analysis\ncarried out in accordance with the requirements of Prac-\ntice Statement 2 \u201cMaking Materiality Judgments\u201d, issued by\nthe International Accounting Standards Board (IASB), and on\nthe basis of investor expectations.\n(22)\n In addition, as regards\nthe impact of COVID-19, the continuing instability connect-\ned with the pandemic creates unce\ue61fainty in forecasts for\nfuture developments in the macroeconomic, \ue61enancial and\nbusiness environment in which the Group operates, which\nis re\ue61dected in the assessments and the estimates produced \nby management regarding the carrying amounts of the as-\nsets and liabilities a\ue61bected by greater volatility. Please see\nnote 6 \u201cCOVID-19 disclosures\u201d for details on the areas of the\n\ue61enancial statements most a\ue61bected by the COVID-19 pan-\ndemic, drawing on the information available at December\n31, 2021 and considering the constantly evolving scenario.\nWith regard to the e\ue61bects of climate change issues, the\nGroup believes that climate change represents an implic-\nit element in the application of the methodologies and\nmodels used to pe\ue619orm estimates in the valuation and/or\nmeasurement of ce\ue61fain accounting items. Fu\ue61fhermore,\nthe Group has also taken account of the impact of climate\nchange in the signi\ue61ecant judgments made by management. \nIn this regard, the main items included in the consolidat-\ned \ue61enancial statements at December 31, 2021 a\ue61bected by\nmanagement\u2019s use of estimates and judgments refer to the\nimpairment of non-\ue61enancial assets, obligations connected\nwith the energy transition, including those for decommis-\nsioning and site restoration of ce\ue61fain generation plants,\nand the impairment of inventories of a number of coal-\ue61ered\nplants. For fu\ue61fher details on these items, see note 18 \u201cProp-\ne\ue61fy, plant and equipment\u201d, note 23 \u201cGoodwill\u201d, note 32 \u201cIn-\nventories\u201d and note 39 \u201cProvisions for risks and charges\u201d.\n\nUse of estimates\nRevenue from contracts with customers\nRevenue from supply of electricity and gas to end users is\nrecognized at the time the electricity or gas is delivered and \nincludes, in addition to amounts invoiced on the basis of pe-\nriodic (and pe\ue61faining to the year) meter readings or on the\nvolumes noti\ue61eed by distributors and transpo\ue61fers, an esti-\nmate of the electricity and gas delivered during the period\nbut not yet invoiced that is equal to the di\ue61berence between\nthe amount of electricity and gas delivered to the distribu-\ntion network and that invoiced in the period, taking account\nof any network losses. Revenue between the date of the last \nmeter reading and the year-end is based on estimates of \nthe daily consumption of individual customers, primarily de-\ntermined on their historical information, adjusted to re\ue61dect\nthe climate factors or other ma\ue61cers that may a\ue61bect the es-\ntimated consumption. \nFor more details on such revenue, see note 10.a \u201cRevenue\nfrom sales and services\u201d.\nImpairment of non-\ue61fnancial assets\nWhen the carrying amount of prope\ue61fy, plant and equip-\nment, investment prope\ue61fy, intangible assets, right-of-use \nassets, goodwill and investments in associates/joint ven-\ntures exceeds its recoverable amount, which is the higher\nof the fair value less costs to sell and the value in use, the\nassets are impaired.\nImpairment tests are carried out in accordance with the\nprovisions of IAS 36, as described in greater detail in note\n23 \u201cGoodwill\u201d.\nIn order to determine the recoverable amount, the Group\ngenerally adopts the value in use criterion. Value in use is \nbased on the estimated future cash \ue61dows generated by\nthe asset, discounted to their present value using a pre-tax\ndiscount rate that re\ue61dects the current market assessment \nof the time value of money and of the speci\ue61ec risks of the\nasset.\nFuture cash \ue61dows used to determine value in use are based\non the most recent Business Plan, approved by the manage-\nment, containing forecasts for volumes, revenue, operating \ncosts and investments. These projections cover the next\nthree years. For subsequent years, account is taken of:\n\u2022 assumptions concerning the long-term evolution of \nthe main variables considered in the calculation of cash\n\ue61dows, as well as the average residual useful life of the\nassets or the duration of the concessions, based on the\nspeci\ue61ec characteristics of the businesses;\n\u2022 a long-term growth rate equal to the long-term growth \nof electricity demand and/or in\ue61dation (depending on the\ncountry and business) that does not in any case exceed\nthe average long-term growth rate of the market in-\nvolved.\nThe recoverable amount is sensitive to the estimates and\nassumptions used in the calculation of cash \ue61dows and the\ndiscount rates applied. Neve\ue61fheless, possible changes in\nthe underlying assumptions on which the calculation of\nsuch amounts is based could generate di\ue61berent recover-\nable amounts. The analysis of each group of non-\ue61enancial \nassets is unique and requires management to use estimates\nand assumptions considered prudent and reasonable in the\nspeci\ue61ec circumstances.\nIn the current scenario, the analysis of impairment indica-\ntors has become even more impo\ue61fant as an a\ue61cempt was\nalso made to assess whether the impact of the COVID-19 \npandemic could reduce the carrying amount of ce\ue61fain\nnon-\ue61enancial assets as at December 31, 2021. For this rea-\nson, the Group has carefully considered the e\ue61bects of the\nCOVID-19 pandemic in determining the existence of impair-\nment indicators for non-\ue61enancial assets.\nFu\ue61fhermore, in line with its business model and in the con-\ntext of the acceleration of the decarbonization of the gen-\neration mix and driving the energy-transition process, the\nGroup has also carefully assessed whether climate change\nissues have a\ue61bected the reasonable and suppo\ue61fable as-\nsumption used to estimate expected cash \ue61dows. In this re-\ngard, where necessary, the Group has also taken account\nof the long-term impact of climate change, in pa\ue61ficular by\nconsidering in the estimation of the terminal value a long-\nterm growth rate in line with the change in electricity de-\nmand determined using energy models for each country.\nInformation on the main assumptions used to estimate the\nrecoverable amount of assets with reference to the impacts\nrelating to climate change, as well as information on chang-\nes in these assumptions, is provided in note 23 \u201cGoodwill\u201d.\nExpected credit losses on \ue61fnancial assets\nAt the end of each repo\ue61fing period, the Group recogniz-\nes a loss allowance for expected credit losses on trade re-\nceivables and other \ue61enancial assets measured at amo\ue61fized\ncost, debt instruments measured at fair value through other\ncomprehensive income, contract assets and all other assets\nin scope.\nLoss allowances for \ue61enancial assets are based on assump-\ntions about risk of default and on the measurement of ex-\npected credit losses. Management uses judgment in mak-\ning these assumptions and selecting the inputs for the im-\npairment calculation, based on the Group\u2019s past experience,\ncurrent market conditions as well as forward-looking esti-\nmates at the end of each repo\ue61fing period.\nThe expected credit loss (i.e., ECL) \u2013 determined consider-\ning probability of default (PD), loss given default (LGD), and\nexposure at default (EAD) \u2013 is the di\ue61berence between all\ncontractual cash \ue61dows that are due in accordance with the\ncontract and all cash \ue61dows that are expected to be received\n(including all sho\ue61ffalls) discounted at the original e\ue61bective\ninterest rate (EIR).\nIn pa\ue61ficular, for trade receivables, contract assets and\nlease receivables, including those with a signi\ue61ecant \ue61e-\nnancial component, the Group applies the simpli\ue61eed ap-\n\nproach, determining expected credit losses over a period\ncorresponding to the entire life of the asset, generally\nequal to 12 months.\nBased on the speci\ue61ec reference market and the regulatory\ncontext of the sector, as well as expectations of recovery\nafter 90 days, for such assets, the Group mainly applies a\ndefault de\ue61enition of 180 days past due to determine ex-\npected credit losses, as this is considered an e\ue61bective in-\ndication of a signi\ue61ecant increase in credit risk. Accordingly,\n\ue61enancial assets that are more than 90 days past due are\ngenerally not considered to be in default, except for some\nspeci\ue61ec regulated markets.\nFor trade receivables and contract assets the Group mainly\napplies a collective approach based on grouping trade re-\nceivables and contract assets into speci\ue61ec clusters, taking\ninto account the speci\ue61ec regulatory and business context.\nOnly if the trade receivables are deemed to be individually\nsigni\ue61ecant by management and there is speci\ue61ec informa-\ntion about any signi\ue61ecant increase in credit risk, does the\nGroup apply an analytical approach.\nIn case of individual assessment, PD is mainly obtained\nfrom an external provider.\nConversely, for collective assessment, trade receivables\nare grouped based on shared credit risk characteristics\nand past due information, considering a speci\ue61ec de\ue61enition\nof default.\nBased on each business and local regulatory framework as\nwell as di\ue61berences in customer po\ue61ffolios also in terms of\nrisk, default rates and recovery expectations, speci\ue61ec clus-\nters are de\ue61ened.\nThe contract assets are considered to have substantially\nthe same risk characteristics as the trade receivables for\nthe same types of contracts.\nIn order to measure the ECL for trade receivables on a\ncollective basis, as well as for contract assets, the Group\nconsiders the following assumptions related to ECL pa-\nrameters:\n\u2022 PD, assumed as to be the average default rate, is cal-\nculated on a cluster basis and taking into consideration\nminimum 24 month historical data;\n\u2022 LGD is a function of the default bucket\u2019s recovery rates, \ndiscounted at the EIR; and\n\u2022 EAD is estimated as the carrying exposure at the repo\ue61f-\ning date net of cash deposits, including invoices issued\nbut not expired and invoices to be issued.\nBased on speci\ue61ec management evaluations, the for-\nward-looking adjustment can be applied considering\nqualitative and quantitative information in order to re\ue61dect\npossible future events and macroeconomic scenarios,\nwhich may a\ue61bect the risk of the po\ue61ffolio or the \ue61enancial\ninstrument.\nFor additional details on the key assumptions and inputs\nused please see note 46 \u201cFinancial instruments by cate-\ngory\u201d.\nDepreciable amount of ce\ue61eain elements of Italian\nhydroelectric plants subsequent to enactment of Law\n134/2012\nLaw 134 of August 7, 2012 containing \u201curgent measures for\ngrowth\u201d (published in the Gazze\ue61ca U\ue61aciale of August 11,\n2012), introduced a sweeping overhaul of the rules gov-\nerning hydroelectric concessions. Among its various pro-\nvisions, the law establishes that \ue61eve years before the expi-\nration of a major hydroelectric water diversion concession\nand in cases of lapse, relinquishment or revocation, where\nthere is no prevailing public interest for a di\ue61berent use of\nthe water, incompatible with its use for hydroelectric gen-\neration, the competent public entity shall organize a pub-\nlic call for tenders for the award for consideration of the\nconcession for a period ranging from 20 to a maximum of\n30 years.\nIn order to ensure operational continuity, the law also gov-\nerns the methods of transferring ownership of the busi-\nness unit necessary to operate the concession, including\nall legal relationships relating to the concession, from the\noutgoing concession holder to the new concession holder,\nin exchange for payment of a price to be determined in ne-\ngotiations between the depa\ue61fing concession holder and\nthe grantor agency, taking due account of the following\nelements:\n\u2022 for intake and governing works, penstocks and out\ue61dow \nchannels, which under the consolidated law governing\nwaters and electrical plants are to be relinquished free\nof charge (A\ue61ficle 25 of Royal Decree 1775 of December\n11, 1933), the revalued cost less government grants re-\nlated to assets, also revalued, received by the conces-\nsion holder for the construction of such works, depre-\nciated for ordinary wear and tear;\n\u2022 for other prope\ue61fy, plant and equipment, the market val-\nue, meaning replacement value, reduced by estimated\ndepreciation for ordinary wear and tear.\nWhile acknowledging that the new regulations introduce\nimpo\ue61fant changes as to the transfer of ownership of the\nbusiness unit with regard to the operation of the hydroe-\nlectric concession, the practical application of these prin-\nciples faces di\ue61aculties, given the unce\ue61fainties that do not\npermit the formulation of a reliable estimate of the value\nthat can be recovered at the end of existing concessions\n(residual value).\nAccordingly, management has decided it could not pro-\nduce a reasonable and reliable estimate of residual value.\nThe fact that the legislation requires the new concession\nholder to make a payment to the depa\ue61fing concession\nholder prompted management to review the depreciation\nschedules for assets classi\ue61eed as to be relinquished free\nof charge prior to Law 134/2012 (until the year ended on\nDecember 31, 2011, given that the assets were to be relin-\n\nquished free of charge, the depreciation period was equal\nto the closest date between the term of the concession\nand the end of the useful life of the individual asset), cal-\nculating depreciation no longer over the term of the con-\ncession but, if longer, over the useful life of the individual\nassets. If additional information becomes available to ena-\nble the calculation of residual value, the carrying amounts\nof the assets involved will be adjusted prospectively.\nDetermining the fair value of \ue61fnancial instruments\nThe fair value of \ue61enancial instruments is determined on the\nbasis of prices directly observable in the market, where\navailable, or, for unlisted \ue61enancial instruments, using spe-\nci\ue61ec valuation techniques (mainly based on present val-\nue) that maximize the use of observable market inputs. In\nrare circumstances where this is not possible, the inputs\nare estimated by management taking due account of the\ncharacteristics of the instruments being measured.\nFor more information on \ue61enancial instruments measured\nat fair value, please see note 50 \u201cAssets and liabilities\nmeasured at fair value\u201d.\nIn accordance with IFRS 13, the Group includes a meas-\nurement of credit risk, both of the counterpa\ue61fy (Credit\nValuation Adjustment or CVA) and its own (Debit Valua-\ntion Adjustment or DVA), in order to adjust the fair value\nof \ue61enancial instruments for the corresponding amount of\ncounterpa\ue61fy risk, using the method discussed in note 50\n\u201cAssets and liabilities measured at fair value\u201d.\nChanges in the assumptions made in estimating the input\ndata could have an impact on the fair value recognized for\nthose instruments, especially in current conditions where\nmarkets are volatile and the economic outlook is highly un-\nce\ue61fain and subject to rapid change.\nDevelopment expenditure\nIn order to determine the recoverability of development\nexpenditure, the recoverable amount is estimated mak-\ning assumptions regarding any fu\ue61fher cash out\ue61dow that is\nexpected to be incurred before the asset is ready for use\nor sale, the discount rates to be applied and the expected\nperiod of bene\ue61ets.\nPensions and other post-employment bene\ue61fts\nSome of the Group\u2019s employees pa\ue61ficipate in pension\nplans o\ue61bering bene\ue61ets based on their wage history and\nyears of service. Ce\ue61fain employees are also eligible for\nother post-employment bene\ue61et schemes.\nThe expenses and liabilities of such plans are calculated on\nthe basis of estimates carried out by consulting actuaries,\nwho use a combination of statistical and actuarial elements\nin their calculations, including statistical data on past years\nand forecasts of future costs. Other components of the\nestimation that are considered include mo\ue61fality and re-\ntirement rates as well as assumptions concerning future\ndevelopments in discount rates, the rate of wage increas-\nes, the in\ue61dation rate and trends in healthcare cost.\nThese estimates can di\ue61ber signi\ue61ecantly from actual devel-\nopments owing to changes in economic and market con-\nditions, increases or decreases in retirement rates and the\nlifespan of pa\ue61ficipants, as well as changes in the e\ue61bective\ncost of healthcare.\nSuch di\ue61berences can have a substantial impact on the\nquanti\ue61ecation of pension costs and other related expens-\nes. \nWith regard to the COVID-19 pandemic, the Group has\ncarefully analyzed the possible impacts of the economic\ncrisis generated by the emergency on the actuarial as-\nsumptions used in the measurement of the actuarial liabil-\nities and assets serving the plans.\nFor more details on the main actuarial assumptions adopt-\ned, please see note 38.\nProvisions for risks and charges\nFor more details on provisions for risks and charges, please\nsee note 39 \u201cProvisions for risks and charges\u201d.\nNote 55 \u201cContingent assets and liabilities\u201d also provides\ninformation regarding the most signi\ue61ecant contingent as-\nsets and liabilities for the Group at year end.\nLitigation\nThe Group is involved in various civil, administrative and tax\ndisputes connected with the normal pursuit of its activi-\nties that could give rise to signi\ue61ecant liabilities. It is not al-\nways objectively possible to predict the outcome of these\ndisputes. The assessment of the risks associated with this\nlitigation is based on complex factors whose very nature\nrequires recourse to management judgments, even when\ntaking account of the contribution of external advisors as-\nsisting the Group, about whether to classify them as con-\ntingent liabilities or liabilities.\nProvisions have been recognized to cover all signi\ue61ecant li-\nabilities for cases in which legal counsel feels an adverse\noutcome is likely and a reasonable estimate of the amount\nof the expense can be made.\nObligations associated with generation plants, \nincluding decommissioning and site restoration\nGeneration activities may entail obligations for the opera-\ntor with regard to future interventions that will have to be\npe\ue619ormed following the end of the operating life of the\nplant.\nSuch interventions may involve the decommissioning of\nplants and site restoration, or other obligations linked to\nthe type of generation technology involved. The nature of\nsuch obligations may also have a major impact on the ac-\ncounting treatment used for them.\nIn the case of nuclear power plants, where the costs re-\ngard both decommissioning and the storage of waste\nfuel and other radioactive materials, the estimation of the\nfuture cost is a critical process, given that the costs will\n\nbe incurred over a very long span of time, estimated at up \nto 100 years.\nThe obligation, based on \ue61enancial and engineering as-\nsumptions, is calculated by discounting the expected fu-\nture cash \ue61dows that the Group considers it will have to\npay to meet the obligations it has assumed.\nThe discount rate used to determine the present value \nof the liability is the pre-tax risk-free rate and is based \non the economic parameters of the country in which the\nplant is located.\nThat liability is quanti\ue61eed by management on the basis of\nthe technology existing at the measurement date and is re-\nviewed each year, taking account of developments in stor-\nage, decommissioning and site restoration technology, as\nwell as the ongoing evolution of the legislative framework\ngoverning health and environmental protection.\nSubsequently, the value of the obligation is adjusted to\nre\ue61dect the passage of time and any changes in estimates.\nOnerous contracts\nIn order to identify an onerous contract, the Group esti-\nmates the non-discretionary costs necessary to ful\ue61el the\nobligations assumed (including any penalties) under the\ncontract and the economic bene\ue61ets that are presumed \nto be obtained from the contract.\nLeases\nWhen the interest rate implicit in the lease cannot be\nreadily determined, the Group uses the incremental bor-\nrowing rate (IBR) at the lease commencement date to cal-\nculate the present value of the lease payments. This is the\ninterest rate that the lessee would have to pay to borrow\nover a similar term, and with a similar security, the funds\nnecessary to obtain an asset of a similar value to the right\nof use asset in a similar economic environment. When no\nobservable inputs are available, the Group estimates the\nIBR making assumptions to re\ue61dect the terms and condi-\ntions of the lease and ce\ue61fain lessee-speci\ue61ec estimates.\nOne of the most signi\ue61ecant judgments for the Group in\nadopting IFRS 16 is determining this IBR necessary to cal-\nculate the present value of the lease payments required \nto be paid to the lessor. The Group approach to deter-\nmine an IBR is based on the assessment of the following\nthree key components:\n\u2022 the risk free rate, that consider the currency \ue61dows of \nthe lease payments, the economic environment where\nthe lease contract has been negotiated and also the\nlease term; \n\u2022 the credit spread adjustment, in order to calculate an \nIBR that is speci\ue61ec for the lessee considering any un-\nderlying Parent or other guarantee;\n\u2022 the lease related adjustments, in order to re\ue61dect into \nthe IBR calculation the fact that the discount rate is\ndirectly linked to the type of the underlying asset, rath-\ner than being a general incremental borrowing rate. In\npa\ue61ficular, the risk of default is mitigated for the lessors \nas they have the right to reclaim the underlying asset\nitself.\nFor more information on lease liabilities, please see note\n46 \u201cFinancial instruments by category\u201d.\nIncome tax\nRecovery of deferred tax assets\nAt December 31, 2021, the consolidated \ue61enancial state-\nments repo\ue61f deferred tax assets in respect of tax loss-\nes or tax credits usable in subsequent years and income \ncomponents whose deductibility is deferred in an amount\nwhose future recovery is considered by management to \nbe highly probable.\nThe recoverability of such assets is subject to the achieve-\nment of future pro\ue61ets su\ue61acient to absorb such tax losses\nand to use the bene\ue61ets of the other deferred tax assets.\nSigni\ue61ecant management judgment is required to assess\nthe probability of recovering deferred tax assets, consid-\nering all negative and positive evidence, and to determine \nthe amount that can be recognized, based upon the likely\ntiming and the level of future taxable pro\ue61ets together with\nfuture tax planning strategies and the tax rates applicable\nat the date of reversal. However, where the Group should\nbecome aware that it is unable to recover all or pa\ue61f of\nrecognized tax assets in future years, the consequent\nadjustment would be taken to pro\ue61et or loss in the year in\nwhich this circumstance arises.\nThe recoverability of deferred tax assets is reviewed at \nthe end of each period. Deferred tax assets not recog-\nnized are reassessed at each repo\ue61fing date in order to\nverify the conditions for their recognition.\nWhere required, the Group monitored the recovery times\nof deferred tax assets as well as those relating to the re-\nversal of deductible temporary di\ue61berences, if any, as a re-\nsult of the greater unce\ue61fainty caused by the COVID-19\npandemic.\nFor more detail in deferred tax assets recognized or not\nrecognized, please see note 24 \u201cDeferred tax assets and \nliabilities\u201d.\n\nManagement judgment\nIdenti\ue61fcation of cash generating units (CGUs)\nFor impairment testing, if the recoverable amount cannot\nbe determined for an individual asset, the Group identi-\n\ue61ees the smallest group of assets that generate largely in-\ndependent cash in\ue61dows. The smallest group of assets that\ngenerates cash in\ue61dows that are largely independent of the\ncash in\ue61dows from other assets or group of assets is a CGU.\nIdentifying such CGUs involves management judgments\nregarding the speci\ue61ec nature of the assets and the busi-\nness involved (geographical segment, business segment,\nregulatory framework, etc.) and the evidence that the cash\nin\ue61dows of the group of assets are largely independent of\nthose associated with other assets (or groups of assets).\nThe assets of each CGU are also identi\ue61eed on the basis of\nthe manner in which management manages and monitors\nthose assets within the business model adopted. In par-\nticular, the number and scope of the CGUs are updated\nsystematically to re\ue61dect the impact of new business com-\nbinations and reorganizations carried out by the Group,\nand to take account of external factors that could in\ue61du-\nence the ability of assets to generate independent cash\nin\ue61dows.\nIn pa\ue61ficular, if ce\ue61fain speci\ue61ec identi\ue61eed assets owned by\nthe Group are impacted by adverse economic or operating\nconditions that undermine their capacity to contribute to\nthe generation of cash \ue61dows, they can be isolated from the\nrest of the assets of the CGU, undergo separate analysis of\ntheir recoverability and be impaired where necessary.\nThe CGUs identi\ue61eed by management to which the goodwill\nrecognized in these consolidated \ue61enancial statements has\nbeen allocated and the criteria used to identify the CGUs\nare indicated in note 23 \u201cGoodwill\u201d.\nDetermining the useful life of non-\ue61fnancial assets\nIn determining the useful life of prope\ue61fy, plant and equip-\nment and intangible assets with a \ue61enite useful life, the\nGroup considers not only the future economic bene\ue61ets \u2013\ncontained in the assets \u2013 obtained through their use, but\nalso many other factors, such as physical wear and tear,\nthe technical, commercial or other obsolescence of the\nproduct or service produced with the asset, legal or similar\nlimits (e.g., safety, environmental or other restrictions) on\nthe use of the asset, if the useful life of the asset depends\non the useful life of other assets.\nFu\ue61fhermore, in estimating the useful lives of the assets\nconcerned, the Group has taken account of its commit-\nment under the Paris Agreement. For more information on\nthis issue, please see note 18 \u201cPrope\ue61fy, plant and equip-\nment\u201d.\nDetermination of the existence of control\nUnder the provisions of IFRS 10, control is achieved when\nthe Group is exposed, or has rights, to variable returns\nfrom its involvement with the investee and has the ability\nto a\ue61bect those returns through its power over the investee.\nPower is de\ue61ened as the current ability to direct the relevant\nactivities of the investee based on existing substantive\nrights.\nThe existence of control does not depend solely on owner-\nship of a majority investment, but rather it arises from sub-\nstantive rights that each investor holds over the investee.\nConsequently, management must use its judgment in as-\nsessing whether speci\ue61ec situations determine substantive\nrights that give the Group the power to direct the relevant\nactivities of the investee in order to a\ue61bect its returns.\nFor the purpose of assessing control, management analyz-\nes all facts and circumstances including any agreements\nwith other investors, rights arising from other contractu-\nal arrangements and potential voting rights (call options,\nwarrants, put options granted to non-controlling share-\nholders, etc.). These other facts and circumstances could\nbe especially signi\ue61ecant in such assessment when the\nGroup holds less than a majority of voting rights, or similar\nrights, in the investee.\nFollowing such analysis of the existence of control, in ap-\nplication of IFRS 10 the Group consolidated ce\ue61fain com-\npanies (Emgesa and Codensa) on a line-by-line basis even\nthough it did not hold more than half of the voting rights,\ndetermining that the requirements for de facto control ex-\nisted.\nFu\ue61fhermore, even if it holds more than half of the voting\nrights in another entity, the Group considers all the rele-\nvant facts and circumstances in assessing whether it con-\ntrols the investee.\nThe Group reassesses whether or not it controls an in-\nvestee if facts and circumstances indicate that there are\nchanges to one or more of the elements considered in\nverifying the existence of control.\nDetermination of the existence of joint control and of\nthe type of joint arrangement\nUnder the provisions of IFRS 11, a joint arrangement is an\nagreement where two or more pa\ue61fies have joint control.\nJoint control exists only when the decisions over the rele-\nvant activities require the unanimous consent of the par-\nties that share joint control.\nA joint arrangement can be con\ue61egured as a joint venture\nor a joint operation. Joint ventures are joint arrangements\nwhereby the pa\ue61fies that have joint control have rights to\nthe net assets of the arrangement. Conversely, joint op-\nerations are joint arrangements whereby the pa\ue61fies that\nhave joint control have rights to the assets and obligations\nfor the liabilities relating to the arrangement.\nIn order to determine the existence of the joint control and\nthe type of joint arrangement, management must apply\njudgment and assess its rights and obligations arising from\nthe arrangement. For this purpose, the management con-\nsiders the structure and legal form of the arrangement, the\n\nterms agreed by the pa\ue61fies in the contractual arrangement\nand, when relevant, other facts and circumstances.\nFollowing that analysis, the Group has considered its interest\nin Asociaci\u00f3n Nuclear Asc\u00f3-Vandell\u00f3s II as a joint operation.\nThe Group re-assesses whether or not it has joint control\nif facts and circumstances indicate that changes have oc-\ncurred in one or more of the elements considered in veri-\nfying the existence of joint control and the type of the joint\narrangement.\nFor more information on the Group\u2019s investments in joint\nventures, please see note 25 \u201cEquity-accounted invest-\nments\u201d.\nDetermination of the existence of signi\ue61fcant in\ue61duence\nover an associate\nAssociates are those in which the Group exercises signi\ue61e-\ncant in\ue61duence, i.e., the power to pa\ue61ficipate in the \ue61enancial\nand operating policy decisions of the investee but not exer-\ncise control or joint control over those policies. In general, it\nis presumed that the Group has a signi\ue61ecant in\ue61duence when\nit has an ownership interest of 20% or more.\nIn order to determine the existence of signi\ue61ecant in\ue61duence,\nmanagement must apply judgment and consider all facts\nand circumstances.\nThe Group re-assesses whether or not it has signi\ue61ecant in-\n\ue61duence if facts and circumstances indicate that there are\nchanges to one or more of the elements considered in ver-\nifying the existence of signi\ue61ecant in\ue61duence.\nFor more information on the Group\u2019s equity investments in\nassociates, please see note 25 \u201cEquity-accounted invest-\nments\u201d.\nApplication of \u201cIFRIC 12 - Service concession\narrangements\u201d to concessions\nIFRIC 12 applies to \u201cpublic-to-private\u201d service concession\narrangements, which can be de\ue61ened as contracts under\nwhich the operator is obligated to provide public services,\ni.e., give access to major economic and social services for a\nce\ue61fain period of time, on behalf of a public entity (the gran-\ntor). In these contracts, the grantor conveys to an operator\nthe right to manage the infrastructure used to provide ser-\nvices.\nMore speci\ue61ecally, IFRIC 12 gives guidance on the accounting\nby operators for \u201cpublic-to-private\u201d service concession ar-\nrangements in the event that:\n\u2022 the grantor controls or regulates what services the op-\nerator must provide with the infrastructure, to whom it\nmust provide them, and at what price; and\n\u2022 the grantor controls \u2013 through ownership, bene\ue61ecial en-\ntitlement or otherwise \u2013 any signi\ue61ecant residual interest\nin the infrastructure at the end of the term of the ar-\nrangement.\nIn assessing the applicability of these requirements for the\nGroup, as operator, management carefully analyzed existing\nconcessions.\nOn the basis of that analysis, the provisions of IFRIC 12 are\napplicable to some of the infrastructure of a number of\ncompanies that operate primarily in Brazil.\nFu\ue61fher details about the infrastructure used in the service\nconcession arrangements in the scope of IFRIC 12 are pro-\nvided in note 19 \u201cInfrastructure within the scope of \u2018IFRIC\n12 - Service concession arrangements\u2019\u201d.\nRevenue from contracts with customers\nIn the process of applying IFRS 15, the Group has made the\nfollowing judgments (fu\ue61fher details about the most signif-\nicant e\ue61bect on the Group\u2019s revenue are provided in note\n10.a \u201cRevenue from sales and services\u201d).\nFu\ue61fhermore, during the year, the Group carefully moni-\ntored the e\ue61bects of the unce\ue61fainties linked to the COV-\nID-19 pandemic on the recognition of its revenue, in par-\nticular as regards the main areas a\ue61bected by signi\ue61ecant\njudgments.\nIdenti\ue61dcation of the contract\nThe Group carefully analyzes the contractual terms and\nconditions on a jurisdictional level in order to determine\nwhen a contract exists and the terms of that contract\u2019s en-\nforceability so as to apply IFRS 15 only to such contracts.\nIdenti\ue61dcation and satisfaction of pe\ue61cormance obligations\nWhen a contract includes multiple promised goods or\nservices, in order to assess if they should be accounted\nfor separately or as a group, the Group considers both the\nindividual characteristics of goods/services and the na-\nture of the promise within the context of the contract, also\nevaluating all the facts and circumstances relating to the\nspeci\ue61ec contract under the relevant legal and regulatory\nframework.\nTo evaluate when a pe\ue619ormance obligation is satis\ue61eed, the\nGroup evaluates when the control of the goods or services\nis transferred to the customer, assessed primarily from the\nperspective of the customer.\nDetermination of the transaction price\nThe Group considers all relevant facts and circumstanc-\nes in determining whether a contract includes variable\nconsideration (i.e., consideration that may vary or de-\npends upon the occurrence or non-occurrence of a fu-\nture event). In estimating variable consideration, the Group\nuses the method that be\ue61cer predicts the consideration to\nwhich it will be entitled, applying it consistently throughout\nthe contract and for similar contracts, also considering all\navailable information, and updating such estimates until\nthe unce\ue61fainly is resolved. The Group includes the esti-\nmated variable consideration in the transaction price only\nto the extent that it is highly probable that a signi\ue61ecant re-\nversal in the cumulative revenue recognized will not occur\nwhen the unce\ue61fainty is resolved.\n\nPrincipal versus agent assessment\nThe Group considers that it is an agent in some con-\ntracts in which it is not primarily responsible for ful\ue61elling\nthe contract and therefore it does not control goods or\nservices before they are being transferred to customers.\nFor example, the Group acts as an agent in some contracts\nfor electricity/gas network connection services and other\nrelated activities depending on local legal and regulatory\nframework.\nAllocation of transaction price\nFor contracts that have more than one pe\ue619ormance obli-\ngation (e.g., \u201cbundled\u201d sale contracts), the Group generally\nallocates the transaction price to each pe\ue619ormance ob-\nligation in propo\ue61fion to its stand-alone selling price. The\nGroup determines stand-alone selling prices considering\nall information and using observable prices when they are\navailable in the market or, if not, using an estimation meth-\nod that maximizes the use of observable inputs and apply-\ning it consistently to similar arrangements.\nIf the Group evaluates that a contract includes an option\nfor additional goods or services (e.g., customer loyalty pro-\ngrams or renewal options) that represents a material right,\nit allocates the transaction price to this option since the\noption gives rise to an additional pe\ue619ormance obligation.\nContract costs\nThe Group assesses recoverability of the incremental costs\nof obtaining a contract either on a contract-by-contract\nbasis, or for a group of contracts if those costs are associ-\nated with the group of contracts.\nThe Group suppo\ue61fs the recoverability of such costs on\nthe basis of its experience with other similar transactions\nand evaluating various factors, including potential renew-\nals, amendments and follow-on contracts with the same\ncustomer.\nThe Group amo\ue61fizes such costs over the average custom-\ner term. In order to determine this expected period of ben-\ne\ue61et from the contract, the Group considers its past experi-\nence (e.g., \u201cchurn rate\u201d), the predictive evidence from sim-\nilar contracts and available information about the market.\nClassi\ue61fcation and measurement of \ue61fnancial assets\nAt initial recognition, in order to classify \ue61enancial assets\nas \ue61enancial assets at amo\ue61fized cost, at fair value through\nother comprehensive income and at fair value through\npro\ue61et or loss, management assesses both the contractual\ncash \ue61dow characteristics of the instrument and the busi-\nness model for managing \ue61enancial assets in order to gen-\nerate cash \ue61dows.\nIn order to evaluate the contractual cash \ue61dow character-\nistics of the instrument, management pe\ue619orms the SPPI\ntest at an instrument level, in order to determine if it gives\nrise to cash \ue61dows that are solely payments of principal and\ninterest (SPPI) on the principal amount outstanding, per-\nforming speci\ue61ec assessment on the contractual clauses of\nthe \ue61enancial instruments, as well as quantitative analysis,\nif required.\nThe business model determines whether cash \ue61dows will\nresult from collecting contractual cash \ue61dows, selling the\n\ue61enancial assets, or both.\nFor more details, please see note 46 \u201cFinancial instruments\nby category\u201d.\nHedge accounting\nHedge accounting is applied to derivatives in order to re-\n\ue61dect into the \ue61enancial statements the e\ue61bect of risk man-\nagement strategies.\nAccordingly, at the inception of the transaction the Group\ndocuments the hedge relationship between hedging in-\nstruments and hedged items, as well as its risk manage-\nment objectives and strategy. The Group also assesses,\nboth at hedge inception and on an ongoing basis, wheth-\ner hedging instruments are highly e\ue61bective in o\ue61bse\ue61cing\nchanges in the fair values or cash \ue61dows of hedged items.\nOn the basis of management\u2019s judgment, the e\ue61bective-\nness assessment based on the existence of an econom-\nic relationship between the hedging instruments and the\nhedged items, the dominance of credit risk in the changes\nin fair value and the hedge ratio, as well as the measure-\nment of the ine\ue61bectiveness, is evaluated through a qualita-\ntive assessment or a quantitative computation, depending\non the speci\ue61ec facts and circumstances and on the char-\nacteristics of the hedged items and the hedging instru-\nments.\nFor cash \ue61dow hedges of forecast transactions designated\nas hedged items, management assesses and documents\nthat they are highly probable and present an exposure to\nchanges in cash \ue61dows that a\ue61bect pro\ue61et or loss.\nFu\ue61fhermore, during the year, the Group carefully moni-\ntored the possible e\ue61bects of the unce\ue61fainties linked to the\nCOVID-19 pandemic on its hedge relationships.\nFor additional details on the key assumptions about e\ue61bec-\ntiveness assessment and ine\ue61bectiveness measurement,\nplease refer to note 49.1 \u201cDerivatives and hedge account-\ning\u201d.\nLeases\nThe complexity of the assessment of the lease contracts,\nand also their long-term expiring date, requires consider-\nable professional judgments for application of IFRS 16. In\npa\ue61ficular, this regards:\n\u2022 the application of the de\ue61enition of a lease to the cases \ntypical of the sectors in which the Group operates;\n\u2022 the identi\ue61ecation of the non-lease component in the \nlease;\n\u2022 the evaluation of any renewable and termination op-\ntions included in the lease in order to determine the\nterm of leases, also considering the probability of their\nexercise and any signi\ue61ecant leasehold improvements on\n\nthe underlying asset, taking due consideration of recent\ninterpretations issued by the IFRS Interpretations Com-\nmi\ue61cee;\n\u2022 the identi\ue61ecation of any variable lease payments that \ndepend on an index or a rate to determine whether the\nchanges of the la\ue61cer impact the future lease payments\nand also the amount of the right-of-use asset;\n\u2022 the estimate of the discount rate to calculate the pres-\nent value of the lease payments; fu\ue61fher details on as-\nsumptions about this rate are provided in the paragraph\n\u201cUse of estimates\u201d.\nFor more information on leases, please see note 20 \u201cLeases\u201d.\nUnce\ue61eainty over income tax treatments \nThe Group determines whether to consider each uncer-\ntain income tax treatment separately or together with one\nor more other unce\ue61fain tax treatments as well as whether\nto re\ue61dect the e\ue61bect of unce\ue61fainty by using the most like-\nly amount or the expected value method, based on which\napproach be\ue61cer predicts the resolution of the unce\ue61fainty\nfor each unce\ue61fain tax treatments, taking account of local\ntax regulations.\nThe Group makes signi\ue61ecant use of professional judgment\nin identifying unce\ue61fainties about income tax treatments\nand reviews the judgments and estimates made in the\nevent of a change in facts and circumstances that could\nchange its assessment of the acceptability of a speci\ue61ec tax\ntreatment or the estimate of the e\ue61bects of unce\ue61fainty, or\nboth.\nFor more information on income taxes, please see note 16\n\u201cIncome taxes\u201d.\n2.2 Signi\ue61fcant accounting policies \nRelated pa\ue61eies\nRelated pa\ue61fies are mainly those that share the same par-\nent with Enel SpA, the companies that directly or indirectly\nare controlled by Enel SpA, the associates or joint ventures\n(including their subsidiaries) of Enel SpA, or the associates\nor joint ventures (including their subsidiaries) of any Group\ncompany. Related pa\ue61fies also include entities that operate \npost-employment bene\ue61et plans for employees of Enel SpA\nor its associates (speci\ue61ecally, the FOPEN and FONDENEL\npension funds), as well as the members of the boards of\nstatutory auditors, and their immediate family, and the key\nmanagement personnel, and their immediate family, of Enel\nSpA and its subsidiaries. Key management personnel com-\nprises management personnel who have the power and di-\nrect or indirect responsibility for the planning, management\nand control of the activities of the Company. They include\ndirectors (whether executive or not).\nSubsidiaries\nSubsidiaries are all entities over which the Group has con-\ntrol. The Group controls an entity, regardless of the nature\nof the formal relationship between them, when it is ex-\nposed, or has rights, to variable returns deriving from its\ninvolvement and has the ability, through the exercise of its\npower over the investee, to a\ue61bect its returns.\nThe \ue61egures of the subsidiaries are consolidated on a full\nline-by-line basis as from the date control is acquired until\nsuch control ceases.\nConsolidation procedures\nThe \ue61enancial statements of subsidiaries used to prepare\nthe consolidated \ue61enancial statements were prepared at\nDecember 31, 2021 in accordance with the accounting\npolicies adopted by the Group.\nIf a subsidiary uses di\ue61berent accounting policies from\nthose adopted in preparing the consolidated \ue61enancial\nstatements for similar transactions and facts in similar cir-\ncumstances, appropriate adjustments are made to ensure\nconformity with Group accounting policies.\nAssets, liabilities, revenue and expenses of a subsidiary ac-\nquired or disposed of during the year are included in or\nexcluded from the consolidated \ue61enancial statements, re-\nspectively, from the date the Group gains control or until\nthe date the Group ceases to control the subsidiary.\nPro\ue61et or loss for the year and the other comprehensive in-\ncome are a\ue61cributed to owners of the Parent and non-con-\ntrolling interests, even if this results in a loss for non-con-\ntrolling interests.\nAll intercompany assets and liabilities, equity items, reve-\nnue, expenses and cash \ue61dows relating to transactions be-\ntween entities of the Group are eliminated in full.\nChanges in ownership interest in subsidiaries that do not\nresult in loss of control are accounted for as equity trans-\nactions, with the carrying amounts of the controlling and\nnon-controlling interests adjusted to re\ue61dect changes in\ntheir interests in the subsidiary. Any di\ue61berence between\nthe amount to which non-controlling interests are adjust-\ned and the fair value of the consideration paid or received\nis recognized in consolidated equity.\nWhen the Group ceases to have control over a subsidiary,\nany interest retained in the entity is remeasured to its fair\nvalue, recognized through pro\ue61et or loss, at the date when\ncontrol is lost, recognizing any gain or loss from the loss\nof control through pro\ue61et or loss. In addition, any amounts\npreviously recognized in other comprehensive income in\nrespect of the former subsidiary are accounted for as if\nthe Group had directly disposed of the related assets or\nliabilities.\n\nInvestments in associates and joint ventures\nAn associate is an entity over which the Group has signi\ue61e-\ncant in\ue61duence. Signi\ue61ecant in\ue61duence is the power to pa\ue61fic-\nipate in decisions concerning the \ue61enancial and operating\npolicies of the investee without having control or joint con-\ntrol over the investee.\nA joint venture is a joint arrangement over which the Group\nexercises joint control and has rights to the net assets of\nthe arrangement. Joint control is the sharing of control of\nan arrangement, whereby decisions about the relevant ac-\ntivities require unanimous consent of the pa\ue61fies sharing\ncontrol.\nThe Group\u2019s investments in associates and joint ventures\nare accounted for using the equity method.\nUnder the equity method, these investments are initially\nrecognized at cost and any goodwill arising from the di\ue61ber-\nence between the cost of the investment and the Group\u2019s\nshare of the net fair value of the investee\u2019s identi\ue61eable as-\nsets and liabilities at the acquisition date is included in the \ncarrying amount of the investment.\nAfter the acquisition date, their carrying amount is adjusted\nto recognize changes in the Group\u2019s share of pro\ue61et or loss of\nthe associate or joint venture in Group pro\ue61et or loss. Adjust-\nments to the carrying amount may also be necessary fol-\nlowing changes in the Group\u2019s share in the associate or joint\nventure as a result of changes in the other comprehensive\nincome of the investee. The Group\u2019s share of these changes\nis recognized in the Group\u2019s other comprehensive income.\nDividends received from joint ventures and associates re-\nduce the carrying amount of the investments.\nGains and losses resulting from transactions between the\nGroup and the associates or joint ventures are eliminated\nto the extent of the interest in the associate or joint venture.\nThe \ue61enancial statements of the associates or joint ventures\nare prepared for the same repo\ue61fing period as the Group.\nWhen necessary, adjustments are made to bring the ac-\ncounting policies in line with those of the Group.\nAfter application of the equity method, the Group deter-\nmines whether it is necessary to recognize an impairment\nloss on its investment in an associate or joint venture. If\nthere is objective evidence of a loss of value, the entire\ncarrying amount of the investment undergoes impairment\ntesting pursuant to IAS 36 as a single asset. For more in-\nformation on impairment, please see the section \u201cImpair-\nment of non-\ue61enancial assets\u201d in note 2.1 \u201cUse of estimates\nand management judgment\u201d.\nIf the investment ceases to be an associate or a joint ven-\nture, the Group recognizes any retained investment at its\nfair value, through pro\ue61et or loss. Any amounts previously\nrecognized in other comprehensive income in respect of\nthe former associate or joint venture are accounted for as\nif the Group had directly disposed of the related assets or\nliabilities.\nIf the ownership interest in an associate or a joint venture is\nreduced, but the Group continues to exercise a signi\ue61ecant\nin\ue61duence or joint control, the Group continues to apply\nthe equity method and the share of the gain or loss that\nhad previously been recognized in other comprehensive\nincome relating to that reduction is accounted for as if\nthe Group had directly disposed of the related assets or\nliabilities.\nWhen a po\ue61fion of an investment in an associate or joint\nventure meets the criteria to be classi\ue61eed as held for sale,\nany retained po\ue61fion of an investment in the associate or\njoint venture that has not been classi\ue61eed as held for sale\nis accounted for using the equity method until disposal of\nthe po\ue61fion classi\ue61eed as held for sale takes place.\nJoint operations are joint arrangements whereby the\nGroup, which holds joint control, has rights to the assets\nand obligations for the liabilities relating to the arrange-\nment. For each joint operation, the Group recognized as-\nsets, liabilities, costs and revenue on the basis of the pro-\nvisions of the arrangement rather than the interest held.\nWhere there is an increase in the interest in a joint ar-\nrangement that meets the de\ue61enition of a business:\n\u2022 if the Group acquires control, and had rights over the \nassets and obligations for the liabilities of the joint ar-\nrangement immediately before the acquisition date,\nthen the transaction represents a business combination\nachieved in stages. Consequently, the Group applies the\nrequirements for a business combination achieved in\nstages, including the remeasurement of the interest it\nheld previously in the joint operation at its fair value at\nthe acquisition date;\n\u2022 if the Group obtains joint control (i.e., it already had an \ninterest in a joint operation without holding joint con-\ntrol), the interest previously held in the joint operation\nshall not be remeasured.\nFor more information on the Group\u2019s investments in asso-\nciates and joint ventures, please see note 25 \u201cEquity-ac-\ncounted investments\u201d.\nTranslation of foreign currency items\nTransactions in currencies other than the functional cur-\nrency are initially recognized at the spot exchange rate\nprevailing on the date of the transaction.\nMonetary assets and liabilities denominated in a foreign\ncurrency other than the functional currency are subse-\nquently translated using the closing exchange rate (i.e., the\nspot exchange rate prevailing at the repo\ue61fing date).\nNon-monetary assets and liabilities denominated in for-\neign currency that are recognized at historical cost are\ntranslated using the exchange rate at the date of the\ntransaction. Non-monetary assets and liabilities in foreign\ncurrency measured at fair value are translated using the\nexchange rate at the date the fair value was determined.\nAny exchange di\ue61berences are recognized through pro\ue61et or\nloss.\n\nIn determining the spot exchange rate to use on initial rec-\nognition of the related asset, expense or income (or pa\ue61f \nof it) on the derecognition of a non-monetary asset or\nnon-monetary liability relating to advance consideration in\nforeign currency paid or received, the date of the transac-\ntion is the date on which the Group initially recognizes the\nnon-monetary asset or non-monetary liability associated\nwith the advance consideration.\nIf there are multiple advance payments or receipts, the\nGroup determines the transaction date for each payment\nor receipt of advance consideration.\nTranslation of \ue61fnancial statements\ndenominated in a foreign currency\nFor the purposes of the consolidated \ue61enancial statements,\nall revenue, expenses, assets and liabilities are stated in\neuro, which is the presentation currency of the Parent.\nIn order to prepare the consolidated \ue61enancial statements,\nthe \ue61enancial statements of consolidated companies with\nfunctional currencies other than the presentation curren-\ncy used in the consolidated \ue61enancial statements are trans-\nlated into euros by applying the closing exchange rate to\nthe assets and liabilities, including goodwill and consolida-\ntion adjustments, and the average exchange rate for the\nperiod to the income statement items on the condition it\napproximates the exchange rates prevailing at the date of\nthe respective transactions.\nAny resulting exchange gains or losses are recognized as\na separate component of equity in a special reserve. The\ngains and losses are recognized propo\ue61fionately in the\nincome statement on the disposal (pa\ue61fial or total) of the\nsubsidiary.\nWhen the functional currency of a consolidated company\nis the currency of a hyperin\ue61dationary economy, the Group\nrestates the \ue61enancial statements in accordance with IAS\n29 before applying the speci\ue61ec conversion method set out\nbelow.\nIn order to consider the impact of hyperin\ue61dation on the\nlocal currency exchange rate, the \ue61enancial position and\npe\ue619ormance (i.e., assets, liabilities, equity items, revenue\nand expenses) of a company whose functional currency is\nthe currency of a hyperin\ue61dationary economy are translated\ninto the Group\u2019s presentation currency (the euro) using the\nexchange rate prevailing at the repo\ue61fing date, except for\ncomparative amounts presented in the previous year\u2019s \ue61e-\nnancial statements which are not adjusted for subsequent\nchanges in the price level or subsequent changes in ex-\nchange rates.\nBusiness combinations\nBusiness combinations initiated before January 1, 2010\nand completed within that \ue61enancial year are recognized on\nthe basis of IFRS 3 (2004).\nSuch business combinations were recognized using the\npurchase method, where the purchase cost is equal to the\nfair value at the date of the exchange of the assets acquired\nand the liabilities incurred or assumed, plus costs directly\na\ue61cributable to the acquisition. This cost was allocated by\nrecognizing the assets, liabilities and identi\ue61eable contin-\ngent liabilities of the acquired company at their fair values.\nAny positive di\ue61berence between the cost of the acquisition\nand the fair value of the net assets acquired a\ue61cributable to\nowners of the Parent was recognized as goodwill. If the dif-\nference is negative, it is recognized through pro\ue61et or loss.\nThe carrying amount of non-controlling interests was de-\ntermined in propo\ue61fion to the interest held by non-con-\ntrolling shareholders in the net assets. In the case of busi-\nness combinations achieved in stages, at the acquisition\ndate, any adjustment to the fair value of the net assets ac-\nquired previously was recognized in equity; the amount of\ngoodwill was determined for each transaction separately\nbased on the fair values of the acquiree\u2019s net assets at the\ndate of each exchange transaction.\nBusiness combinations carried out as from January 1, 2010\nare recognized on the basis of IFRS 3 (2008), which is re-\nferred to as IFRS 3 (Revised) hereafter.\nMore speci\ue61ecally, business combinations are recognized\nusing the acquisition method, where the acquisition cost\n(the consideration transferred) is equal to the fair value at\nthe acquisition date of the assets acquired and the liabili-\nties incurred or assumed, as well as any equity instruments\nissued by the acquirer. The consideration transferred in-\ncludes the fair value of any asset or liability resulting from\na contingent consideration arrangement.\nCosts directly a\ue61cributable to the acquisition are recog-\nnized through pro\ue61et or loss.\nThe consideration transferred is allocated by recognizing\nthe assets, liabilities and identi\ue61eable contingent liabili-\nties of the acquired company at their fair values as at the\nacquisition date. The excess of the consideration trans-\nferred, measured at fair value as at the acquisition date,\nthe amount of any non-controlling interest in the acquiree\nplus the fair value of any equity interest in the acquiree\npreviously held by the Group (in a business combination\nachieved in stages) over the net amount of the identi\ue61ea-\nble assets acquired and the liabilities incurred or assumed\nmeasured at fair value is recognized as goodwill. If the dif-\nference is negative, the Group veri\ue61ees whether it has cor-\nrectly identi\ue61eed all the assets acquired and liabilities as-\nsumed and reviews the procedures used to determine the\namounts to recognize at the acquisition date. If after this\nassessment the fair value of the net assets acquired still\nexceeds the total consideration transferred, this excess\nrepresents a gain on a bargain purchase and is recognized\nthrough pro\ue61et or loss.\nThe carrying amount of non-controlling interests is deter-\nmined either in propo\ue61fion to the interest held by non-con-\n\ntrolling shareholders in the net identi\ue61eable assets of the\nacquiree or at their fair value as at the acquisition date.\nIn the case of business combinations achieved in stages, at\nthe date of acquisition of control the previously held equi-\nty interest in the acquiree is remeasured to fair value and\nany positive or negative di\ue61berence is recognized in pro\ue61et\nor loss.\nAny contingent consideration is recognized at fair value at\nthe acquisition date. Subsequent changes to the fair val-\nue of the contingent consideration classi\ue61eed as an asset\nor a liability, or as a \ue61enancial instrument within the scope\nof IFRS 9, are recognized in pro\ue61et or loss. If the contin-\ngent consideration is not within the scope of IFRS 9, it is\nmeasured in accordance with the appropriate IFRS-EU.\nContingent consideration that is classi\ue61eed as equity is not\nre-measured, and its subsequent se\ue61clement is accounted\nfor within equity.\nIf the fair values of the assets, liabilities and contingent li-\nabilities can only be calculated on a provisional basis, the \nbusiness combination is recognized using such provisional\nvalues. Any adjustments resulting from the completion of\nthe measurement process are recognized within 12 months\nof the acquisition date, restating comparative \ue61egures.\nFair value measurement\nFor all fair value measurements and disclosures of fair val-\nue, that are either required or permi\ue61ced by IFRS, the Group\napplies IFRS 13.\nFair value is de\ue61ened as the price that would be received\nto sell an asset or paid to transfer a liability, in an orderly\ntransaction, between market pa\ue61ficipants, at the measure-\nment date (i.e., an exit price).\nThe fair value measurement assumes that the transaction\nto sell an asset or transfer a liability takes place in the prin-\ncipal market, i.e., the market with the greatest volume and\nlevel of activity for the asset or liability. In the absence of a\nprincipal market, it is assumed that the transaction takes\nplace in the most advantageous market to which the Group\nhas access, i.e., the market that maximizes the amount\nthat would be received to sell the asset or minimizes the\namount that would be paid to transfer the liability.\nThe fair value of an asset or a liability is measured using\nthe assumptions that market pa\ue61ficipants would use when\npricing the asset or liability, assuming that market pa\ue61fic-\nipants act in their economic best interest. Market pa\ue61fici-\npants are independent, knowledgeable sellers and buyers\nwho are able to enter into a transaction for the asset or the\nliability and who are motivated but not forced or otherwise\ncompelled to do so.\nWhen measuring fair value, the Group considers the char-\nacteristics of the asset or liability, in pa\ue61ficular:\n\u2022 for a non-\ue61enancial asset, a fair value measurement takes \ninto account a market pa\ue61ficipant\u2019s ability to generate\neconomic bene\ue61ets by using the asset in its highest and\nbest use or by selling it to another market pa\ue61ficipant\nthat would use the asset in its highest and best use;\n\u2022 for liabilities and own equity instruments, the fair val-\nue re\ue61dects the e\ue61bect of non-pe\ue619ormance risk, i.e., the\nrisk that an entity will not ful\ue61ell an obligation, including\namong others the credit risk of the Group itself;\n\u2022 in the case of groups of \ue61enancial assets and \ue61enancial li-\nabilities with o\ue61bse\ue61cing positions in market risk or credit\nrisk, managed on the basis of an entity\u2019s net exposure\nto such risks, it is permi\ue61ced to measure fair value on a\nnet basis.\nIn measuring the fair value of assets and liabilities, the\nGroup uses valuation techniques that are appropriate in\nthe circumstances and for which su\ue61acient data are availa-\nble, maximizing the use of relevant observable inputs and\nminimizing the use of unobservable inputs.\nPrope\ue61ey, plant and equipment\nPrope\ue61fy, plant and equipment is stated at cost, net of\naccumulated depreciation and accumulated impairment\nlosses, if any. Such cost includes expenses directly a\ue61crib-\nutable to bringing the asset to the location and condition\nnecessary for its intended use.\nThe cost is also increased by the present value of the es-\ntimate of the costs of decommissioning and restoring the\nsite on which the asset is located where there is a legal\nor constructive obligation to do so. The corresponding lia-\nbility is recognized under provisions for risks and charges.\nThe accounting treatment of changes in the estimate of\nthese costs, the passage of time and the discount rate is\ndiscussed in note 39 \u201cProvisions for risks and charges\u201d.\nPrope\ue61fy, plant and equipment transferred from custom-\ners to connect them to the electricity distribution network\nand/or to provide them with other related services is ini-\ntially recognized at its fair value at the date on which con-\ntrol is obtained.\nBorrowing costs that are directly a\ue61cributable to the ac-\nquisition, construction or production of a qualifying asset,\ni.e., an asset that takes a substantial period of time to get\nready for its intended use or sale, are capitalized as pa\ue61f \nof the cost of the assets themselves. Borrowing costs as-\nsociated with the purchase/construction of assets that do\nnot meet such requirement are expensed in the period in\nwhich they are incurred.\nCe\ue61fain assets that were revalued at the IFRS-EU transi-\ntion date or in previous periods are recognized at their fair\nvalue, which is considered to be their deemed cost at the\nrevaluation date.\nWhere individual items of major components of prope\ue61fy,\nplant and equipment have di\ue61berent useful lives, the com-\nponents are recognized and depreciated separately.\nSubsequent costs are recognized as an increase in the\ncarrying amount of the asset when it is probable that fu-\nture economic bene\ue61ets associated with the cost incurred\nto replace a pa\ue61f of the asset will \ue61dow to the Group and the\n\ncost of the item can be measured reliably. All other costs\nare recognized in pro\ue61et or loss as incurred.\nThe cost of replacing pa\ue61f or all of an asset is recognized\nas an increase in the carrying amount of the asset and is\ndepreciated over its useful life; the carrying amount of the\nreplaced unit is derecognized through pro\ue61et or loss.\nPrope\ue61fy, plant and equipment, net of its residual value,\nis depreciated on a straight-line basis over its estimated\nuseful life, which is reviewed annually. Any changes in de-\npreciation criteria shall be applied prospectively. For more\ninformation on estimating useful life, please see note 2.1\n\u201cUse of estimates and management judgment\u201d.\nDepreciation begins when the asset is available for use.\nThe estimated useful life of the main items of prope\ue61fy,\nplant and equipment is as follows:\nCivil buildings 10-70 years\nBuildings and civil works incorporated in plants 10-100 years\nHydroelectric power plants:\n- penstock 7-85 years\n- mechanical and electrical machinery 5-60 years\n- other \ue61exed hydraulic works 5-100 years\nThermal power plants:\n- boilers and auxiliary components 3-53 years\n- gas turbine components 3-53 years\n- mechanical and electrical machinery 3-53 years\n- other \ue61exed hydraulic works 3-53 years\nNuclear power plants 50 years\nGeothermal power plants:\n- cooling towers 20-25 years\n- turbines and generators 25-30 years\n- turbine pa\ue61fs in contact with \ue61duid 10-25 years\n- mechanical and electrical machinery 20-40 years\nWind power plants:\n- towers 20-30 years\n- turbines and generators 20-30 years\n- mechanical and electrical machinery 15-30 years\nSolar power plants:\n- mechanical and electrical machinery 20-30 years\nPublic and a\ue61fistic lighting:\n- public lighting installations 10-20 years\n- a\ue61fistic lighting installations 20 years\nTranspo\ue61f lines 12-50 years\nTransformer stations 20-55 years\nDistribution plants:\n- high-voltage lines 10-60 years\n- primary transformer stations 5-55 years\n- low- and medium-voltage lines 5-50 years\nMeters:\n- electromechanical meters 3-34 years\n- electricity balance measurement equipment 3-30 years\n- electronic meters 6-35 years\nThe useful life of leasehold improvements is determined\non the basis of the term of the lease or, if sho\ue61fer, on the\nduration of the bene\ue61ets produced by the improvements\nthemselves.\nLand is not depreciated as it has an inde\ue61enite useful life.\nAssets recognized under prope\ue61fy, plant and equipment\nare derecognized either upon their disposal (i.e., at the\ndate the recipient obtains control) or when no future eco-\nnomic bene\ue61et is expected from their use or disposal. Any\ngain or loss, recognized through pro\ue61et or loss, is calculat-\ned as the di\ue61berence between the net disposal proceeds,\ndetermined in accordance with the transaction price re-\nquirements of IFRS 15, and the carrying amount of the\nderecognized assets.\nAssets to be relinquished free of charge\nThe Group\u2019s plants include assets to be relinquished free\nof charge at the end of the concessions. These mainly\nregard major water diversion works and the public lands\nused for the operation of the thermal power plants.\nWithin the Italian regulatory framework in force until 2011,\nif the concessions are not renewed, at those dates all in-\ntake and governing works, penstocks, out\ue61dow channels\nand other assets on public lands were to be relinquished\nfree of charge to the State in good operating condition.\nAccordingly, depreciation on assets to be relinquished was\ncalculated over the sho\ue61fer of the term of the concession\nand the useful life of the assets.\nIn the wake of the legislative changes introduced with Law\n134 of August 7, 2012, the assets previously classi\ue61eed as\nassets \u201cto be relinquished free of charge\u201d connected with\nthe hydroelectric water diversion concessions are now\nconsidered in the same manner as other categories of\n\u201cprope\ue61fy, plant and equipment\u201d and are therefore depre-\nciated over the useful life of the asset (where this exceeds\nthe term of the concession), as discussed in the section\nabove on the \u201cDepreciable amount of ce\ue61fain elements of\nItalian hydroelectric plants subsequent to enactment of\nLaw 134/2012\u201d, which you are invited to consult for more\ndetails.\nIn accordance with Spanish laws 29/1985 and 46/1999,\nhydroelectric power stations in Spanish territory operate\nunder administrative concessions at the end of which the\nplants will be returned to the government in good oper-\nating condition. The terms of the concessions extend up\nto 2067.\nA number of generation companies that operate in Lat-\nin America hold administrative concessions with similar\nconditions to those applied under the Spanish concession\nsystem. These concessions will expire in 2071.\nInfrastructure serving a concession not within the scope\nof \u201cIFRIC 12 - Service concession arrangements\u201d\nAs regards the distribution of electricity, the Group is a\nconcession holder in Italy for this service. The concession,\ngranted by the Ministry for Economic Development, was\nissued free of charge and terminates on December 31,\n2030. If the concession is not renewed upon expiry, the\ngrantor is required to pay an indemnity. The amount of the\nindemnity will be determined by agreement of the pa\ue61fies\n",
"dimensions": {
"concept": "ifrs-full:DisclosureOfSummaryOfSignificantAccountingPoliciesExplanatory",
"language": "en",
"entity": "scheme:WOCMU6HCI0OJWNPRZS33",
"period": "2021-01-01T00:00:00/2022-01-01T00:00:00"
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"Tag2": {
"value": "\n3. New and amended standards and interpretations\nThe Group has applied the following standards, interpre-\ntations and amendments that took e\ue61bect as from January\n1, 2021.\n\u2022 \u201cAmendments to IFRS 9, IAS 39, IFRS 7, and IFRS 16 \u2013 \nInterest Rate Benchmark Reform \u2013 Phase 2\u201d, issued in \nAugust 2020. The amendments supplement those is-\nsued in 2019 (Interest Rate Benchmark Reform - Phase\n1) and address issues that could a\ue61bect \ue61enancial repo\ue61f-\ning after a benchmark has been reformed or replaced\nwith an alternative benchmark rate. The objectives of\nthe Phase 2 amendments are to assist companies: (i) in\napplying the IFRSs when changes occur in contractual \ncash \ue61dows or hedge relationships due to the reform \nof the benchmarks for determining interest rates; and\n(ii) in providing information to users of \ue61enancial state-\nments.\n In addition, when the Phase 1 exemptions cease to ap-\nply, companies are required to amend the documen-\ntation of hedge relationship to re\ue61dect the changes re-\nquired under the IBOR reform by the end of the year\nin which the changes are made (such changes do not\nconstitute the discontinuation of the hedge relation-\nship). When the description of a hedged element in the\ndocumentation of the hedge relationship is changed,\nthe amounts accumulated in the hedging reserve shall\nbe considered to be based on the alternative bench-\nmark rate on the basis of which the future hedged\ncash \ue61dows will be determined.\n The amendments will require providing additional dis-\nclosures about the entity\u2019s exposure to the risks aris-\ning from the interest rate benchmark reform and relat-\ned risk management activities.\n\u2022 \u201cAmendment to IFRS 16: COVID 19-related rent con-\ncessions beyond 30 June 2021\u201d, issued on May 28, \n2020 in order to permit lessees to not account for rent\nconcessions (rent payment holidays, deferral of lease\npayments, reductions in rent for a period of time, pos-\nsibly followed by rent increases in future periods) as\nlease modi\ue61ecations if they are a direct consequence of\nthe COVID-19 pandemic and meet ce\ue61fain conditions.\nAccording to IFRS 16, a lease modi\ue61ecation is a change \nin the scope of a lease, or the consideration for a lease,\nthat was not pa\ue61f of the original terms and conditions\nof the lease. Accordingly, rent concessions would rep-\nresent lease modi\ue61ecations unless they were provided\nfor in the original lease agreement. The amendment \napplies only to lessees, while lessors are required to \napply the current provisions of IFRS 16. \n The amendment was to be applied until June 30, 2021\nbut, in consideration of the persistence of the impacts\nof the COVID-19 pandemic, on March 31, 2021, the\nIASB extended the period of application of the practi-\ncal expedient to June 30, 2022.\nThe application of the amendments did not have a ma-\nterial impact on these consolidated \ue61enancial statements.\n",
"dimensions": {
"concept": "ifrs-full:DisclosureOfChangesInAccountingPoliciesExplanatory",
"language": "en",
"entity": "scheme:WOCMU6HCI0OJWNPRZS33",
"period": "2021-01-01T00:00:00/2022-01-01T00:00:00"
}
},
"Tag3": {
"value": "\n4. Argentina - Hyperin\ue61dationary economy: \nimpact of the application of IAS 29\nAs from July 1, 2018, the Argentine economy has been\nconsidered hyperin\ue61dationary based on the criteria estab-\nlished by \u201cIAS 29 - Financial repo\ue61fing in hyperin\ue61dation-\nary economies\u201d. This designation is determined following\nan assessment of a series of qualitative and quantitative\ncircumstances, including the presence of a cumulative\nin\ue61dation rate of more than 100% over the previous three\nyears.\nFor the purposes of preparing the consolidated \ue61enancial\nstatements at December 31, 2021, and in accordance\nwith IAS 29, ce\ue61fain items of the statements of \ue61enancial \nposition of the investees in Argentina have been remeas-\nured by applying the general consumer price index to\nhistorical data in order to re\ue61dect changes in the purchas-\ning power of the Argentine peso at the repo\ue61fing date for\nthose companies.\n\nBearing in mind that the Enel Group acquired control of \nthe Argentine companies on June 25, 2009, the remeas-\nurement of the non-monetary \ue61enancial statement \ue61egures\nwas conducted by applying the in\ue61dation indices sta\ue61fing\nfrom that date. In addition to being already re\ue61dected in\nthe opening statement of \ue61enancial position, the account-\ning e\ue61bects of that remeasurement also include chang-\nes during the period. More speci\ue61ecally, the e\ue61bect of the\nremeasurement of non-monetary items, the equity items\nand the income statement items recognized in 2021 was\nrecognized in a speci\ue61ec line of the income statement un-\nder \ue61enancial income and expense. The associated tax ef-\nfect was recognized in taxes for the year.\nIn order to also take account of the impact of hyperin-\n\ue61dation on the exchange rate of the local currency, the\nincome statement balances expressed in the hyperin\ue61da-\ntionary currency have been translated into the Group\u2019s\npresentation currency (euro) applying, in accordance with \nIAS 21, the closing exchange rate rather than the aver-\nage rate for the year in order to adjust these amounts to\npresent values.\nThe cumulative changes in the general price indices at \nDecember 31, 2018, December 31, 2019, December 31,\n2020 and December 31, 2021 are shown in the following\ntable.\nPeriods\nCumulative change\nin general consumer\nprice index\nFrom July 1, 2009 to December 31, 2018 346.30%\nFrom January 1, 2019 to December 31, 2019 54.46%\nFrom January 1, 2020 to December 31, 2020 35.41%\nFrom January 1, 2021 to December 31, 2021 49.73%\nIn 2021, the application of IAS 29 generated net \ue61enancial\nincome (gross of tax) of \u20ac20 million.\nThe following tables repo\ue61f the e\ue61bects of IAS 29 on the\nbalance at December 31, 2021 and the impact of hyper-\nin\ue61dation on the main income statement items for 2021,\ndi\ue61berentiating between that concerning the revaluation \non the basis of the general consumer price index and that\ndue to the application of the closing exchange rate rather \nthan the average exchange rate for the period, in accord-\nance with the provisions of IAS 21 for hyperin\ue61dationary\neconomies.\nMillions of euro\nCumulative hyperin\ue61dation\ne\ue61cect at Dec. 31, 2020\nHyperin\ue61dation e\ue61cect for the\nperiod Exchange di\ue61cerences\nCumulative\nhyperin\ue61dation e\ue61cect at\nDec. 31, 2021\nTotal assets 962 594 (190) 1,366\nTotal liabilities 192 173 (19) 346\nEquity 770 421\n(1)\n(171) 1,020\n(1) The \ue61egure includes loss for the year, equal to \u20ac122 million.\nMillions of euro\nIAS 29 e\ue61cect IAS 21 e\ue61cect Total e\ue61cect at Dec. 31, 2021\nRevenue 143 (26) 117\nCosts 182\n(1)\n(25)\n(2)\n157\nOperating pro\ue61ft (39) (1) (40)\nNet \ue61enancial income/(expense) (13) - (13)\nNet income/(expense) from hyperin\ue61dation 20 - 20\nPre-tax pro\ue61ft (32) (1) (33)\nIncome taxes 90 (3) 87\nLoss for the year (owners of the Parent and non-\ncontrolling interests)\n(122) 2 (120)\nA\ue61cributable to owners of the Parent (80) 27 (53)\nA\ue61cributable to non-controlling interests (42) (25) (67)\n(1) Includes impact on depreciation, amo\ue61fization and impairment losses of \u20ac62 million.\n(2) Includes impact on depreciation, amo\ue61fization and impairment losses of \u20ac(2) million.\n",
"dimensions": {
"concept": "ifrs-full:DisclosureOfHyperinflationaryReportingExplanatory",
"language": "en",
"entity": "scheme:WOCMU6HCI0OJWNPRZS33",
"period": "2021-01-01T00:00:00/2022-01-01T00:00:00"
}
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"Tag4": {
"value": "\n5. Climate change disclosures \n(23) \u201cE\ue61bects of climate-related ma\ue61cers on \ue61enancial statements\u201d, which completes an a\ue61ficle wri\ue61cen by Nick Anderson, member of the International Accounting \nStandards Board, on this issue in November 2019.\nThe move towards \u201cnet zero\u201d is under way worldwide and\nthe processes of decarbonization and electri\ue61ecation of the\nglobal economy are crucial to avoiding the serious conse-\nquences of an increase in temperatures of over 1.5 \u00b0C.\nWith this outlook, the Group has set its strategic guide-\nlines as follows:\n\u2022 allocate capital to suppo\ue61f a decarbonized electricity \nsupply;\n\u2022 enable the electri\ue61ecation of customers\u2019 energy demand;\n\u2022 leverage the creation of value along the value chain;\n\u2022 bring forward achievement of the sustainable \u201cnet-ze-\nro\u201d goals to 2040.\nThe Group has considered the risks related to climate\nchange and the commitments established under the Paris\nAgreement in the preparation of these consolidated \ue61enan-\ncial statements at December 31, 2021, which appropriately\nre\ue61dect the e\ue61bects of achieving the carbon neutrality ob-\njectives on assets, liabilities, and pro\ue61et and loss, highlight-\ning its signi\ue61ecant and foreseeable impacts as required un-\nder the Conceptual Framework of the IFRS.\nIn this regard, in accordance with the provisions of the\ndocument published by the IFRS Foundation on November\n20, 2020,\n(23)\n the Group provides explicit information in the\nnotes to these consolidated \ue61enancial statements regard-\ning how climate change is re\ue61dected in our accounts.\nFor a more e\ue61bective and comprehensive communication\nconcerning climate change disclosures prepared as pa\ue61f \nof the notes to these consolidated \ue61enancial statements,\nwe have mapped this disclosure as shown below, providing\nreferences to the various sections where issues associated\nwith climate change are addressed.\nTopic Note Content\nEstimates and\njudgments concerning\nclimate change\nNote 2.1 \u201cUse of estimates and\nmanagement judgment\u201d\n\u2022 Reference to management\u2019s use of estimates and judgments with regard \nto climate change (taking account of their materiality within \ue61enancial\nrepo\ue61fing).\n\u2022 Focus on estimating expected cash \ue61dows from speci\ue61ec assets/CGUs \n(section: \"Impairment of non-\ue61enancial assets\u201d).\n\u2022 Focus of the e\ue61bects of the Group\u2019s commitments under the Paris \nAgreement and their impact on the estimation of the useful life of the\nassets involved (section \u201cDetermining the useful life of non-\ue61enancial\nassets\u201d).\nSustainable investment Note 18 \u201cPrope\ue61fy, plant and equipment\u201d\nNote 22 \u201cIntangible assets\u201d\n\u2022 Focus on assets involved in renewable generation, infrastructure \nconnected with the development of the grid and investment in expanding\nthe e-Mobility, e-City, e-Industries, and e-Home businesses.\n\u2022 Focus on the development of intellectual prope\ue61fy for achieving strategic \nobjectives such as decarbonization, electri\ue61ecation and the development of\nplatform models.\nMeasurement of non-\n\ue61enancial assets\nNote 11.e \u201cDepreciation, amo\ue61fization\nand other impairment losses\u201d\nNote 18 \u201cPrope\ue61fy, plant and equipment\u201d\nNote 23 \u201cGoodwill\u201d\n\u2022 Focus on the e\ue61bects related to the commitments of the Group in line with \nthe Paris Agreement with regard to the measurement of non-\ue61enancial \nassets, with pa\ue61ficular regard to the residual useful life of ce\ue61fain assets \nand impairment testing.\nProvisions Note 39 \u201cProvisions for risks and\ncharges\u201d\n\u2022 Focus on the impact of climate change on provisions for risks and charges \nconnected with generation plants, including those for decommissioning\nand restoration of sites, and provisions for restructuring plans linked to the\nenergy transition (which include decarbonization and digitization).\nSustainable \ue61enance Note 46.3 \u201cBorrowings\u201d\nNote 57 \u201cEvents after the repo\ue61fing\nperiod\u201d\nFocus on:\n\u2022 issues of sustainability-linked bonds connected with the achievement of \nsustainability objectives in line with the SDGs issued by the UN;\n\u2022 green bonds used to \ue61enance speci\ue61ec sustainable Group projects and \ninitiatives;\n\u2022 sustainable loans connected with the achievement of Sustainable \nDevelopment Goals (SDGs).\nShare-based payments Note 51 \u201cShare-based payments\u201d \u2022 Description of long-term incentive plans anchored to achievement of\nspeci\ue61ec climate-related targets.\nEnvironmental\ncompliance\nNote 11.f \u201cOther operating costs\u201d \u2022 Description of the costs connected with environmental compliance\nobligations under national and international regulations (in pa\ue61ficular\nthose concerning CO\n2\n emission allowances, green ce\ue61fi\ue61ecates and energy\ne\ue61aciency ce\ue61fi\ue61ecates).\nNote 39 \u201cProvisions for risks and\ncharges\u201d\n\u2022 Description of costs generated by not having su\ue61acient environmental \nce\ue61fi\ue61ecates to meet environmental compliance regulations.\nNote 2.2 \u201cSigni\ue61ecant accounting\npolicies\u201d\n\u2022 Description of accounting treatment of environmental ce\ue61fi\ue61ecates \n(sections: \u201cEnvironmental ce\ue61fi\ue61ecates\u201d and \u201cInventories\u201d).\n",
"dimensions": {
"concept": "enel:DisclosureOfClimateChange",
"language": "en",
"entity": "scheme:WOCMU6HCI0OJWNPRZS33",
"period": "2021-01-01T00:00:00/2022-01-01T00:00:00"
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"Tag5": {
"value": "\n6. COVID-19 disclosures\nIn view of the challenges posed by current circumstanc-\nes, the Group carefully monitors the evolution of the\nCOVID-19 pandemic with regard to the main areas and \ncountries in which it operates, in line with the recom-\nmendations of ESMA primarily contained in the public \nstatements\n(24)\n published in March, May, July and October\n2020, and of CONSOB in its warning notices nos. 6/2020\nof April 9, 2020, 8/2020 of July 16, 2020 and 1/2021 of\nFebruary 16, 2021.\nThe Group analyzed the impacts of COVID-19 on busi-\nness operations, the \ue61enancial position and pe\ue619ormance,\nalso identifying the main risks and unce\ue61fainties to which\nit is exposed.\nNote also that, due to the continuing unce\ue61fainty regard-\ning the future evolution of the macroeconomic, \ue61enancial \nand business environment in which the Group operates,\nthe impacts of the COVID-19 pandemic for the purpos-\nes of the Integrated Annual Repo\ue61f at December 31, 2021\nare re\ue61dected in the assessments and estimates made \nby management concerning the carrying amount of the\nincome statement items, assets and liabilities that expe-\nrience the greatest volatility (in pa\ue61ficular, revenue and\ncosts, prope\ue61fy, plant and equipment, goodwill, employee\nbene\ue61ets, and \ue61enancial instruments).\n",
"dimensions": {
"concept": "enel:DisclosureOfNonFinancialInformationExplanatory",
"language": "en",
"entity": "scheme:WOCMU6HCI0OJWNPRZS33",
"period": "2021-01-01T00:00:00/2022-01-01T00:00:00"
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"Tag6": {
"value": "\n7. Restatement of comparative disclosures\nReclassi\ue61fcation of commodity contracts\nwith physical se\ue61blement\nIn order to improve the representation of contracts en-\ntered into for the purchase or sale of commodities with \nphysical se\ue61clement (that do not qualify for the own use \nexemption) measured at fair value through pro\ue61et or loss\n(within the scope of IFRS 9), the Group modi\ue61eed their\npresentation in the consolidated \ue61enancial statements in\n2021.\nMore speci\ue61ecally, in 2020:\n\u2022 the unrealized fair value gain or loss on energy com-\nmodity sales contracts outstanding at the repo\ue61fing\ndate were presented under \u201cRevenue from sales and\nservices\u201d;\n\u2022 the unrealized fair value gain or loss on energy com-\nmodity purchase contracts outstanding at the repo\ue61f-\ning date were presented under \u201cElectricity, gas and\nfuel\u201d and \u201cServices and other materials\u201d.\nIn 2021, the unrealized fair value gain or loss on contracts \nfor the purchase or sale of energy commodities out-\nstanding at the repo\ue61fing date are recognized on a net\nbasis under the item \u201cNet results from commodity con-\ntracts\u201d.\nThe new presentation method constitutes a change in ac-\ncounting policy, in accordance with \u201cIAS 8 - Accounting\npolicies, changes in accounting estimates and errors\u201d.\nAccordingly, it was necessary to restate the income state-\nment balances for previous periods for comparative pur-\nposes only, with no impact on either net pro\ue61et or equity.\nReclassi\ue61fcation of the remeasurement\nat fair value of assets in respect of\nconcession arrangements (IFRIC 12) in\nBrazil\nIn order to improve the representation of the remeas-\nurement at fair value of \ue61enancial assets in respect of \nconcession arrangements within the scope of applica-\ntion of IFRIC 12 in Brazil in pro\ue61et or loss, in 2021, the gain\nwas reclassi\ue61eed from \ue61enancial income to revenue from\ncontracts with customers (IFRS 15) since it refers to the\nremeasurement at fair value of contract assets.\nThat said, the following table repo\ue61fs the reclassi\ue61ecations\nmade to costs, revenue, net results from commodity con-\ntracts and \ue61enancial income in order to restate the com-\nparative \ue61egures at December 31, 2020.\n(24) ESMA 71-99-1290 of March 11, 2020; ESMA 32-63-951 of March 25, 2020; ESMA 31-67-742 of March 27, 2020; ESMA 32-63-972 of May 20, 2020; ESMA \n32-61-417 of July 21, 2020 and ESMA 32-63-1041 of October 28, 2020.\n\nImpact on the income statement\nMillions of euro Notes\n2020\nE\ue61cect of\nreclassi\ue61fcation of \nenergy commodity\ncontracts with physical\nse\ue61element IFRS 9\nE\ue61cect of reclassi\ue61fcation of\nremeasurement at fair value\nof \ue61fnancial assets in respect\nof concession arrangements\nwithin scope of IFRIC 12 in\nBrazil\n2020\nrestated\nRevenue\nRevenue from sales and services 10.a 62,623 932 87 63,642\nOther income 10.b 2,362 2,362\n[Subtotal] 64,985 932 87 66,004\nCosts\nElectricity, gas and fuel 11.a 25,049 977 26,026\nServices and other materials 11.b 18,298 68 18,366\nPersonnel expenses 11.c 4,793 4,793\nNet impairment losses/(reversals) on trade receivables and other\nreceivables\n11.d 1,285 1,285\nDepreciation, amo\ue61fization and other impairment losses 11.e 7, 16 3 7, 16 3\nOther operating costs 11.f 2,202 2,202\nCapitalized costs 11.g (2,385) (2,385)\n[Subtotal] 56,405 1,045 57,45 0\nNet results from commodity contracts 12 (212) 113 (99)\nOperating pro\ue61ft 8,368 87 8,455\nFinancial income from derivatives 13 1,315 1,315\nOther \ue61enancial income 14 2,763 (87) 2,676\nFinancial expense from derivatives 13 2,256 2,256\nOther \ue61enancial expense 14 4,485 4,485\nNet income/(expense) from hyperin\ue61dation 57 57\nShare of pro\ue61et/(loss) of equity-accounted investments 15 (299) (299)\nPre-tax pro\ue61ft 5,463 5,463\nIncome taxes 16 1,841 1,841\nPro\ue61ft from continuing operations 3,622 3,622\nPro\ue61ft/(Loss) from discontinued operations - -\nPro\ue61ft for the year (owners of the Parent and non-controlling\ninterests)\n3,622 3,622\nA\ue61cributable to owners of the Parent 2,610 2,610\nA\ue61cributable to non-controlling interests 1,012 1,012\nEarnings per share\nBasic earnings per share\nBasic earnings per share 0.26 0.26\nBasic earnings per share from continuing operations 0.26 0.26\nBasic earnings/(loss) per share from discontinued operations - - \nDiluted earnings per share\nDiluted earnings per share 0.26 0.26\nDiluted earnings per share from continuing operations 0.26 0.26\nDiluted earnings/(loss) per share from discontinued operations - - \nThe \ue61egures presented in the comments and the tables of\nthe notes to these consolidated \ue61enancial statements at\nDecember 31, 2021 are uniform and comparable with each\nother.\n",
"dimensions": {
"concept": "ifrs-full:DisclosureOfReclassificationsOrChangesInPresentationExplanatory",
"language": "en",
"entity": "scheme:WOCMU6HCI0OJWNPRZS33",
"period": "2021-01-01T00:00:00/2022-01-01T00:00:00"
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"Tag37": {
"value": "\nChanges in the consolidation scope\n8. Main acquisitions and disposals during the year\nIn the two periods under review, the consolidation scope\nchanged as a result of a number of transactions:\n2020\n\u2022 In January 2020, the Wild Plains project company, 100% \nowned by Tradewind, was sold. The sale did not have an\nimpact on pro\ue61et or loss.\n\u2022 On May 11, 2020 Endesa Energ\u00eda sold 80% of Endesa \nSoluciones for \u20ac21 million. The interest, which had pre-\nviously been consolidated on a line-by-line basis, was\naccounted for using the equity method.\n\u2022 On July 7, 2020, Enel Green Power Espa\u00f1a acquired \n100% of Parque E\u00f3lico Tico SLU, Tico Solar 1 SLU and\nTico Solar 2 SLU for a total of \u20ac40 million.\n\u2022 On September 14, Endesa Generaci\u00f3n Po\ue61fugal ac-\nquired 100% of Suggestion Power (Unipessoal) Ltda for\na total of \u20ac6 million.\n\u2022 On September 17, 2020, Enel X International acquired \n60% of Viva Labs AS for a total of \u20ac3 million.\n\u2022 Enel Green Power Panama acquired 100% of Jaguito So-\nlar and Progreso Solar in 2020 for a total of \u20ac2 million.\nIn addition to the above changes in the consolidation\nscope, the following transactions, although they do not\nrepresent transactions involving the acquisition or loss of\ncontrol, gave rise to a change in the interest held by the\nGroup in the investees in 2020:\n\u2022 the disposal of a number of 50% owned joint ventures in \nEnel No\ue61fh America\u2019s hydroelectric po\ue61ffolio. In Decem-\nber 2019, the entire po\ue61ffolio had been classi\ue61eed as held\nfor sale in accordance with IFRS 5. The gain recognized\nin pro\ue61et or loss was \u20ac2 million;\n\u2022 Enel SpA increased its interest in Enel Am\u00e9ricas by \n5.03% under the provisions of share swaps entered\ninto with a \ue61enancial institution. The Group\u2019s total stake\ntherefore reached 65% in 2020;\n\u2022 Enel SpA increased its interest in Enel Chile by 2.89% un-\nder the provisions of two share swaps entered into with\na \ue61enancial institution. The Group\u2019s total stake therefore\nreached 64.93% in 2020.\n2021\n\u2022 On January 8, 2021, 100% of Tynemouth Energy Storage \nwas sold for \u20ac1 million. The sale did not have any signif-\nicant impact on pro\ue61et or loss.\n\u2022 On January 20, 2021 100% of Enel Green Power Bulgaria \nwas sold for a total of \u20ac35 million. The sale did not have\nany signi\ue61ecant impact on pro\ue61et or loss.\n\u2022 On March 10, 2021, Enel Green Power Italy acquired \n100% of e-Solar Srl, the owner of a photovoltaic pro-\nject with an authorized capacity of 170.11 MW, for \u20ac2.7\nmillion.\n\u2022 On March 29, 2021, Enel X Srl acquired 100% of City-\nPoste Payment SpA, an Italian company that o\ue61bers\nconsumers access to payment services through both\nphysical and digital channels, enabling them to carry\nout numerous types of transactions with private- and\npublic-sector entities.\n\u2022 In the 1st Qua\ue61fer of 2021 the consolidation scope \nchanged with the full consolidation of Australian renew-\nable energy companies previously accounted for using\nthe equity method due to a change in governance ar-\nrangements at the companies, without the acquisition\nof an additional interest. The purchase price allocation\nprocess was completed in December 2021 and essen-\ntially con\ue61ermed the carrying amount of the net assets\nacquired following an impairment loss of about \u20ac9 mil-\nlion.\n\u2022 On May 13, 2021 EGP Solar 1 LLC was sold for a total of \nabout \u20ac4 million.\n\u2022 In the \ue61erst nine months of 2021, Enel Green Power Es-\npa\u00f1a acquired 100% of 30 renewables companies for a\ntotal of \u20ac86 million.\n\u2022 On September 8, 2021, Genability was sold by Enel X \nNo\ue61fh America for about \u20ac6 million.\n\u2022 The purchase price allocation process for Viva Labs AS, \nacquired on September 17, 2020 by Enel X International,\nwas completed in September, following which the car-\nrying amounts recognized at the acquisition date were\ncon\ue61ermed.\nOther changes\nIn addition to the above changes in the consolidation\nscope, the following transactions, which although they do\nnot represent transactions involving the acquisition or loss\nof control, gave rise to a change in the interest held by the\nGroup in the investees:\n\u2022 on March 15, Enel SpA launched a pa\ue61fial voluntary ten-\nder o\ue61ber for up to a maximum of 7,608,631,104 shares of\nEnel Am\u00e9ricas, equal to 10% of the share capital at that\ndate. The o\ue61ber period began on March 15 and ended on\nApril 13, 2021.The tender o\ue61ber was subject to the merger\n\nof EGP Am\u00e9ricas SpA into Enel Am\u00e9ricas SA being com-\npleted, which took place on April 1, 2021. The total price\nwas \u20ac1,271 million. Following completion of the pa\ue61fial\nvoluntary tender o\ue61ber and the completion of the EGP\nAm\u00e9ricas merger, Enel owns about 82.3% of the out-\nstanding share capital of Enel Am\u00e9ricas;\n\u2022 on November 24, Enel Green Power RSA 2 (Pty) Ltd sold \na stake in the investments held in Oyster Bay Wind Farm,\nGarob Wind Farm, Aced Renewables Hidden Valley and\nSoetwater Wind Farm for a total of ZAR 340 million, cor-\nresponding to about \u20ac19 million. Following the transac-\ntion, the Group\u2019s interest in those companies decreased\nfrom 60% to 55%;\n\u2022 on December 3, Enel SpA \ue61enalized the sale of the entire \nstake held in Open Fiber SpA, equal to 50% of the la\ue61cer\u2019s\nshare capital, to Macquarie Asset Management and CDP\nEquity SpA for a total of about \u20ac2,733 million. The capital\ngain realized by the Group on a consolidated basis came\nto about \u20ac1,763 million.\nAcquisition of CityPoste Payment\nOn March 29, 2021, Enel X Srl acquired 100% of CityPoste\nPayment SpA, a payment institution authorized to oper-\nate by the Bank of Italy in the provision of payment servic-\nes both digitally (using a proprietary platform) and using\nphysical sites (its network of points of sale).\nIn December 2021 the identi\ue61ecation of the fair value of the\nassets acquired and liabilities assumed was completed,\nfollowing which negative goodwill of about \u20ac1 million was\nrecognized.\nMillions of euro\nCarrying amount \npre March 29, 2021\nAdjustments for purchase \nprice allocation\nAmount recognized \nat March 29, 2021\nNet assets acquired 2 20 22\nCost of the acquisition 21 21\nGoodwill/(Negative goodwill) 19 (1)\nAcquisitions of renewable energy companies in Spain\nIn the \ue61erst nine months of 2021 Enel Green Power Espa\u00f1a\nacquired 100% of 30 renewable energy companies for a\ntotal of \u20ac86 million for the development and construction\nof photovoltaic and wind plants in Spain.\nDetermination of goodwill\nMillions of euro \nNet assets acquired 86\nCost of the acquisition 86\n(of which paid in cash) 75 \nGoodwill/(Negative goodwill) -\nThe total price of the transaction amounted to \u20ac103 million\nas it includes repayment of the debt of the acquired com-\npanies due to the previous shareholders in the amount of\n\u20ac17 million.\n\nSale of Open Fiber \nOn December 3, 2021, Enel SpA \ue61enalized the sale of the\nentire stake held in Open Fiber SpA, equal to 50% of the\nla\ue61cer\u2019s share capital, to Macquarie Asset Management and\nCDP Equity SpA for a total of about \u20ac2,733 million. The\ncapital gain realized by the Group on a consolidated basis\ncame to about \u20ac1,763 million.\nThe price was collected in full.\nMillions of euro \nValue of the transaction 2,733.3\nValue of the investment at December 2, 2021 (614.5)\nEarly se\ue61clement of \ue61enancial asset with Open Fiber and related income (310.6)\nReversal of OCI reserve (45.1)\nConsolidated capital gain 1,763.1\n",
"dimensions": {
"concept": "enel:DisclosureOfChangeInOwnershipInterestsInSubsidiariesExplanatory",
"language": "en",
"entity": "scheme:WOCMU6HCI0OJWNPRZS33",
"period": "2021-01-01T00:00:00/2022-01-01T00:00:00"
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"Tag36": {
"value": "\n9. Segment repo\ue61eing\nThe representation of the \ue61enancial position and pe\ue619or-\nmance by business segment and geographical segment \npresented here is based on the approach used by man-\nagement in monitoring Group pe\ue619ormance for the two\nyears being compared.\n\nPe\ue61aormance by business segment \nResults for 2021\n(1)\nMillions of euro\nThermal\nGeneration\nand Trading\nEnel Green\nPower\nInfrastructure\nand Networks\nEnd-user\nMarkets Enel X Services\nHolding\nand\nother\nTotal\nrepo\ue61bing\nsegment\nEliminations\nand\nadjustments Total\nRevenue and other\nincome from third\npa\ue61fies\n22,883 7, 24 4 17, 16 4 37,39 6 1,513 20 1,786 88,006 - 88,006\nRevenue and other\nincome from\ntransactions with\nother segments\n10,272 2,282 3,492 1,312 28 1,977 148 19,511 (19,511) -\nTotal revenue 33,155 9,526 20,656 38,708 1,541 1,997 1,934 107,517 (19,511) 88,006\nTotal costs 32,791 4,710 13,446 37,762 1,258 2,083 422 92,472 (19,511) 72,961\nNet results from\ncommodity contracts\n535 (55) - 2,044 - - (2) 2,522 - 2,522\nDepreciation and\namo\ue61fization\n929 1,297 2,692 410 222 188 36 5,774 - 5,774\nImpairment losses 2,568 392 205 1,126 37 51 2 4,381 - 4,381\nImpairment gains (12) (10) (35) (203) (6) (2) - (268) - (268)\nOperating pro\ue61ft (2,586) 3,082 4,348 1,657 30 (323) 1,472 7,680 - 7,680\nCapital expenditure 822 5,662\n(2)\n5,296 643 367 139 68 12,997 - 12,997\n(1) Segment revenue includes both revenue from third pa\ue61fies and revenue from transactions with other segments.\n(2) Does not include \u20ac111 million regarding units classi\ue61eed as \u201cheld for sale\u201d.\nResults for 2020\n(1) (2) (3) (4)\nMillions of euro\nThermal\nGeneration\nand Trading\nEnel Green\nPower\nInfrastructure\nand Networks\nEnd-user\nMarkets Enel X Services\nHolding\nand\nother\nTotal\nrepo\ue61bing\nsegment\nEliminations\nand\nadjustments Total\nRevenue and other\nincome from third\npa\ue61fies\n14,332 5,852 15,919 28,793 1,097 2 9 66,004 - 66,004\nRevenue and other\nincome from\ntransactions with\nother segments\n7,404 1,840 3,510 715 24 1,868 145 15,506 (15,506) -\nTotal revenue 21,736 7,69 2 19,429 29,508 1,121 1,870 154 81,510 (15,506) 66,004\nTotal costs 19,615 3,113 11,909 26,651 969 1,911 340 64,508 (15,506) 49,002\nNet results from\ncommodity contracts\n(421) 68 - 264 - (6) (4) (99) - (99)\nDepreciation and\namo\ue61fization\n778 1,252 2,597 366 150 172 28 5,343 - 5,343\nImpairment losses 950 728 621 1,079 18 11 1 3,408 - 3,408\nImpairment gains (43) (67) (47) (141) - (4) (1) (303) - (303)\nOperating pro\ue61ft 15 2,734 4,349 1 ,817 (16) (226) (218) 8,455 - 8,455\nCapital expenditure 694 4,629 3,937 460 303 103 71 10,197 - 10,197\n(1) Segment revenue includes both revenue from third pa\ue61fies and revenue from transactions with other segments.\n(2) The \ue61egures for revenue from third pa\ue61fies and transactions with other segments have been calculated more accurately.\n(3) The \ue61egures for 2020 have been adjusted, for comparative purposes only, to take account of the e\ue61bects associated with the change in classi\ue61ecation connect-\ned with the fair value measurement of outstanding contracts at the end of the period for the purchase and sale of commodities with physical se\ue61clement.\nThe change in classi\ue61ecation had no impact on operating pro\ue61et. For more details, please see note 7 to these consolidated \ue61enancial statements.\n(4) For comparative purposes only, \u20ac87 million in 2020 in respect of the component recognized through pro\ue61et or loss deriving from the remeasurement at fair\nvalue of the \ue61enancial assets connected with service concession arrangements involving distribution operations in Brazil falling within the scope of IFRIC 12\nhave been reclassi\ue61eed from \ue61enancial income to revenue. The la\ue61cer classi\ue61ecation had an impact of the same amount on operating pro\ue61et. For more details,\nplease see note 7 to these consolidated \ue61enancial statements.\n\nPe\ue61aormance by geographical segment \nResults for 2021\n(1)\nMillions of euro Italy Iberia Latin America Europe No\ue61bh America\nAfrica, Asia and\nOceania\nOther,\neliminations and\nadjustments Total\nRevenue and other\nincome from third\npa\ue61fies\n44,282 20,800 16,956 2,335 1 ,479 240 1,914 88,006 \nRevenue and other\nincome from\ntransactions with other\nsegments\n1,135 252 1 13 34 1 (1,436) -\nTotal revenue 45,417 21,052 16,957 2,348 1,513 241 478 88,006 \nTotal costs 40,751 17,412 12,867 2,063 748 135 (1,015) 72,961 \nNet results from\ncommodity contracts\n1,967 543 53 38 (81) 4 (2) 2,522\nDepreciation and\namo\ue61fization\n2,107 1,754 1,177 186 356 65 129 5,774 \nImpairment losses 1 ,747 1,797 536 87 161 32 21 4,381\nImpairment gains (22) (170) (9) (65) - - (2) (268)\nOperating pro\ue61ft 2,801 802 2,439 115 167 13 1,343 7,680\nCapital expenditure 3,842 2,203 3,722 455 2,293 217\n(2)\n265 12,997 \n(1) Segment revenue includes both revenue from third pa\ue61fies and revenue from transactions with other segments.\n(2) Does not include \u20ac111 million regarding units classi\ue61eed as \u201cheld for sale\u201d.\nResults for 2020\n(1) (2) (3)\nMillions of euro Italy Iberia Latin America Europe No\ue61bh America\nAfrica, Asia and\nOceania\nOther,\neliminations and\nadjustments Total\nRevenue and other\nincome from third\npa\ue61fies\n31,418 17,006 13,897 2 ,074 1,333 152 124 66,004\nRevenue and other\nincome from\ntransactions with other\nsegments\n785 164 6 11 34 1 (1,001) -\nTotal revenue 32,203 17,170 13,903 2,085 1,367 153 (877) 66,004\nTotal costs 24,205 13,480 9,713 1,576 622 98 (692) 49,002\nNet results from\ncommodity contracts\n(174) 85 (40) - 33 - (3) (99)\nDepreciation and\namo\ue61fization\n1,835 1,640 1,230 185 306 36 111 5,343\nImpairment losses 1,209 268 1,225 136 536 31 3 3,408\nImpairment gains (10) (160) (3) (126) (3) - (1) (303)\nOperating pro\ue61ft 4,790 2,027 1,698 314 (61) (12) (301) 8,455\nCapital expenditure 2,842 1,638 2,860 411 1,816 417 213 10,197\n(1) Segment revenue includes both revenue from third pa\ue61fies and revenue from transactions with other segments.\n(2) The \ue61egures for 2020 have been adjusted, for comparative purposes only, to take account of the e\ue61bects associated with the change in classi\ue61ecation connect-\ned with the fair value measurement of outstanding contracts at the end of the period for the purchase and sale of commodities with physical se\ue61clement.\nThe change in classi\ue61ecation had no impact on operating pro\ue61et. For more details, please see note 7 to these consolidated \ue61enancial statements.\n(3) For comparative purposes only, \u20ac87 million in 2020 in respect of the component recognized through pro\ue61et or loss deriving from the remeasurement at fair\nvalue of the \ue61enancial assets connected with service concession arrangements involving distribution operations in Brazil falling within the scope of IFRIC 12\nhave been reclassi\ue61eed from \ue61enancial income to revenue. The la\ue61cer classi\ue61ecation had an impact of the same amount on operating pro\ue61et. For more details,\nplease see note 7 to these consolidated \ue61enancial statements.\n\nFinancial position by business segment\nAt December 31, 2021\nMillions of euro\nThermal\nGeneration \nand Trading\nEnel Green\nPower\nInfrastructure\nand Networks\nEnd-\nuser\nMarkets Enel X Services\nHolding\nand\nother\nTotal\nrepo\ue61bing\nsegment\nEliminations\nand\nadjustments Total\nPrope\ue61fy, plant and\nequipment\n9,384 36,205 38,635 49 600 587 12 85,472 - 85,472\nIntangible assets 216 5,016 21,473 4,030 788 370 143 32,036 - 32,036\nNon-current and\ncurrent contract\nassets\n1 1 525 - 77 4 - 608 43 651\nTrade receivables 4,814 2,601 6,731 6,533 547 882 435 22,543 (6,451) 16,092\nOther 4,319 826 2,614 3,812 383 635 1,614 14,203 (6,107) 8,096\nOperating assets 18,734\n(1)\n44,649\n(2)\n 69,978 14,424 2,395\n(3)\n2,478 2,204 154,862 (12,515) 142,347\nTrade payables 5,730 3,701 4,390 7, 12 9 726 982 169 22,827 (5,843) 16,984\nNon-current and\ncurrent contract\nliabilities\n102 216 7,316 62 13 13 - 7,722 (75) 7,6 47\nSundry provisions 4,586 936 3,810 466 58 671 620 11,147 (89) 11,058\nOther 4,125 1,901 8,104 4,575 148 1,070 2,582 22,505 (6,245) 16,260\nOperating liabilities 14,543 6,754\n(4)\n23,620 12,232 945\n(5)\n2,736 3,371 64,201 (12,252) 51,949\n(1) Of which \u20ac2 million regarding units classi\ue61eed as \u201cheld for sale\u201d.\n(2) Of which \u20ac999 million regarding units classi\ue61eed as \u201cheld for sale\u201d.\n(3) Of which \u20ac136 million regarding units classi\ue61eed as \u201cheld for sale\u201d.\n(4) Of which \u20ac28 million regarding units classi\ue61eed as \u201cheld for sale\u201d.\n(5) Of which \u20ac57 million regarding units classi\ue61eed as \u201cheld for sale\u201d.\nAt December 31, 2020\n(1)\nMillions of euro\nThermal\nGeneration \nand Trading\nEnel Green\nPower\nInfrastructure\nand Networks\nEnd-\nuser\nMarkets Enel X Services\nHolding\nand\nother\nTotal\nrepo\ue61bing\nsegment\nEliminations\nand\nadjustments Total\nPrope\ue61fy, plant and\nequipment\n10,747 30,655 36,718 154 516 699 9 79,498 1 79,499\nIntangible assets\n(1)\n184 4,883 21,490 3,775 676 383 114 31,505 - 31,505\nNon-current and\ncurrent contract\nassets\n4 1 340 - 42 14 - 401 79 480\nTrade receivables 2,670 2,053 6,493 4,034 358 755 368 16,731 (4,679) 12,052\nOther 1,433 1,095 2,674 756 297 769 1,327 8,351 (2,139) 6,212\nOperating assets\n(1)\n15,038\n(2)\n38,687\n(3)\n67,7 15 8,719 1,889\n(4)\n2,620 1,818 136,486 (6,738) 129,748\nTrade payables 2,816 2,751 5,405 4,678 426 868 99 17,043 (4,160) 12,883\nNon-current and\ncurrent contract\nliabilities\n147 152 7, 17 2 42 5 8 - 7,526 (60) 7,466\nSundry provisions 3,528 947 3,794 400 46 603 587 9,905 (108) 9,797\nOther 1,133 1,434 7,856 2,245 179 1,101 2,607 16,555 (2,323) 14,232\nOperating liabilities\n7,624 5,284\n(5)\n24,227 7, 3 6 5 656 2,580 3,293 51,029 (6,651) 44,378\n(1) The \ue61egures for 2020 have been adjusted to re\ue61dect a more accurate allocation.\n(2) Of which \u20ac3 million regarding units classi\ue61eed as \u201cheld for sale\u201d.\n(3) Of which \u20ac855 million regarding units classi\ue61eed as \u201cheld for sale\u201d.\n(4) Of which \u20ac11 million regarding units classi\ue61eed as \u201cheld for sale\u201d.\n(5) Of which \u20ac35 million regarding units classi\ue61eed as \u201cheld for sale\u201d.\n\nFinancial position by geographical segment\nAt December 31, 2021\nMillions of euro Italy Iberia\nLatin\nAmerica Europe\nNo\ue61bh\nAmerica\nAfrica, Asia\nand Oceania\nOther,\neliminations and\nadjustments Total\nPrope\ue61fy, plant and\nequipment\n27,335 23,075 18,671 3,440 10,853 1,948 150 85,472\nIntangible assets 2,313 16,071 11,414 772 557 179 730 32,036\nNon-current and\ncurrent contract assets\n94 5 517 - 18 13 4 651\nTrade receivables 7,372 3,886 4,414 583 215 51 (429) 16,092\nOther 4,555 2,474 1,398 217 259 140 (947) 8,096\nOperating assets 41,669\n(1)\n45,511 36,414 5,012 11,902 2,331\n(2)\n(492)\n(3)\n142,347\nTrade payables 9,684 2,509 4,333 481 1,208 136 (1,367) 16,984\nNon-current and\ncurrent contract\nliabilities\n4,109 3,109 30 438 - - (39) 7,647\nSundry provisions 3,395 4,211 2,426 130 120 32 744 11,058\nOther 5,749 3,945 4,509 328 1,482 64 183 16,260\nOperating liabilities 22,937\n(4)\n13,774 11,298 1,377 2,810 232\n(5)\n(479)\n(6)\n51,949\n(1) Of which \u20ac2 million regarding units classi\ue61eed as \u201cheld for sale\u201d.\n(2) Of which \u20ac999 million regarding units classi\ue61eed as \u201cheld for sale\u201d.\n(3) Of which \u20ac136 million regarding units classi\ue61eed as \u201cheld for sale\u201d.\n(4) Of which \u20ac6 million regarding units classi\ue61eed as \u201cheld for sale\u201d.\n(5) Of which \u20ac22 million regarding units classi\ue61eed as \u201cheld for sale\u201d.\n(6) Of which \u20ac57 million regarding units classi\ue61eed as \u201cheld for sale\u201d.\nAt December 31, 2020\nMillions of euro Italy Iberia\nLatin\nAmerica Europe\nNo\ue61bh\nAmerica\nAfrica, Asia\nand Oceania\nOther,\neliminations and\nadjustments Total\nPrope\ue61fy, plant and\nequipment\n26,762 23,355 16,492 3,255 8,134 1,345 156 79,499\nIntangible assets 2,047 15,919 11,612 787 483 169 488 31,505\nNon-current and\ncurrent contract assets\n105 10 297 1 16 2 49 480\nTrade receivables 5,948 2,166 3,686 436 181 48 (413) 12,052\nOther 2,624 1,804 1,368 178 253 55 (70) 6,212\nOperating assets 37,486\n(1)\n43,254 33,455\n(2)\n4,657\n(3)\n9,067 1,619\n(4)\n210 129,748\nTrade payables 6,881 2, 274 3,387 318 1,076 105 (1,158) 12,883\nNon-current and\ncurrent contract\nliabilities\n4,060 3,006 17 425 - - (42) 7,466\nSundry provisions 2,468 3,910 2,542 100 128 24 625 9,797\nOther 5,033 3,033 3,420 330 1,289 79 1,048 14,232\nOperating liabilities 18,442 12,223 9,366 1,173\n(5)\n2,493 208\n(6)\n473 44,378\n(1) Of which \u20ac5 million regarding units classi\ue61eed as \u201cheld for sale\u201d.\n(2) Of which \u20ac2 million regarding units classi\ue61eed as \u201cheld for sale\u201d.\n(3) Of which \u20ac46 million regarding units classi\ue61eed as \u201cheld for sale\u201d.\n(4) Of which \u20ac816 million regarding units classi\ue61eed as \u201cheld for sale\u201d.\n(5) Of which \u20ac2 million regarding units classi\ue61eed as \u201cheld for sale\u201d.\n(6) Of which \u20ac33 million regarding units classi\ue61eed as \u201cheld for sale\u201d.\n\nThe following table reconciles segment assets and liabilities and the consolidated \ue61egures.\nMillions of euro\nat Dec. 31, 2021 at Dec. 31, 2020\nTotal assets 206,940 163,453\nEquity-accounted investments 704 861\nNon-current \ue61enancial derivative assets 2,772 1,236\nOther non-current \ue61enancial assets 5,704 5,159\nNon-current tax assets included in \u201cOther non-current assets\u201d 2,286 1,539\nOther current \ue61enancial assets 8,645 5,113\nCurrent \ue61enancial derivative assets 22,791 3,471\nCash and cash equivalents 8,858 5,906\nDeferred tax assets 11,034 8,578\nTax assets 1,694 1,294\nFinancial and tax assets of \u201cAssets held for sale\u201d 105 548\nSegment assets 142,347 129,748\nTotal liabilities 164,598 121,096\nLong-term borrowings 54,500 49,519\nNon-current \ue61enancial derivative liabilities 3,339 3,606\nOther non-current \ue61enancial liabilities 120 -\nSho\ue61f-term borrowings 13,306 6,345\nCurrent po\ue61fion of long-term borrowings 4,031 3,168\nOther current \ue61enancial liabilities 625 622\nCurrent \ue61enancial derivative liabilities 24,607 3,531\nDeferred tax liabilities 9,259 7,797\nIncome tax liabilities 712 471\nOther tax liabilities 1,274 886\nFinancial and tax liabilities of \u201cLiabilities included in disposal groups held for sale\u201d 876 773\nSegment liabilities 51,949 44,378\n",
"dimensions": {
"concept": "ifrs-full:DisclosureOfEntitysReportableSegmentsExplanatory",
"language": "en",
"entity": "scheme:WOCMU6HCI0OJWNPRZS33",
"period": "2021-01-01T00:00:00/2022-01-01T00:00:00"
}
},
"Tag7": {
"value": "\nRevenue\n10.a Revenue from sales and services \u2013 \u20ac84,104 million\nMillions of euro\n2021 2020 Change\nSale of electricity 46,963 34,745 12,218 35.2%\nTranspo\ue61f of electricity 10,732 10,710 22 0.2%\nFees from network operators 800 932 (132) -14.2%\nTransfers from institutional market operators 833 1,395 (562) -40.3%\nSale of gas 4,823 2,718 2,105 7 7.4%\nTranspo\ue61f of gas 599 611 (12) -2.0%\nSale of fuel 1,791 602 1,189 -\nFees for connection to electricity and gas networks 787 759 28 3.7%\nConstruction contracts\n(1)\n1,268 819 449 54.8%\nSale of environmental ce\ue61fi\ue61ecates 107 35 72 -\nSale of value-added services 1,093 862 231 26.8%\nOther sales and services 855 764 91 11.9%\nTotal IFRS 15 revenue\n(1)\n70,651 54,952 15,699 28.6%\nSale of commodities under contracts with physical se\ue61clement 24,314 7, 513 16,801 -\nFair value gain/(loss) on commodity sales contracts with physical se\ue61clement\nclosed during the period\n(2)\n(10,893) 1,156 (12,049) -\nOther revenue 32 21 11 52.4%\nTotal revenue from sales and services\n(1) (2)\n84,104 63,642 20,462 32.2%\n(1) For comparative purposes only, \u20ac87 million in 2020 in respect of the component recognized through pro\ue61et or loss deriving from the remeasurement at fair\nvalue of the \ue61enancial assets connected with service concession arrangements involving distribution operations in Brazil falling within the scope of IFRIC 12\nhave been reclassi\ue61eed from \ue61enancial income to revenue. The la\ue61cer classi\ue61ecation had an impact of the same amount on operating pro\ue61et. For more details,\nplease see note 7 to the consolidated \ue61enancial statements.\n(2) The \ue61egures for 2020 have been adjusted, for comparative purposes only, to take account of the e\ue61bects associated with the change in classi\ue61ecation connect-\ned with the fair value measurement of outstanding contracts at the end of the period for the purchase and sale of commodities with physical se\ue61clement.\nFor more details, please see note 7 to these consolidated \ue61enancial statements.\nRevenue from the \u201cSale of electricity\u201d amounted to \u20ac46,963\nmillion, an increase of \u20ac12,218 million compared with the\nprevious year (+35.2%). The increase mainly re\ue61dects higher\nsales volumes and prices, mainly in Italy (\u20ac7,367 million), Brazil\n(\u20ac2,037 million) and Spain (\u20ac2,058 million), where the rise was\nalso due to the recognition of an indemnity paid to Endesa\n(\u20ac186 million) in relation to the CO\n2\n emission rights assigned\nfree of charge under the \u201cPlan Nacional de Asignaci\u00f3n de \nDerechos de Emisi\u00f3n\u201d (PNA).\n \n\u201cTransfers from institutional market operators\u201d decreased by\n\u20ac562 million compared with the previous year, mainly due to\na decline in compensation for extra-peninsular generation in\nSpain following an increase in prices.\nRevenue from the \u201cSale of gas\u201c in 2021 amounted to \u20ac4,823\nmillion (\u20ac2,718 million in 2020), an increase of \u20ac2,105 million\ncompared with the previous year. The increase is mainly at-\ntributable to an increase in quantities sold in Spain.\nRevenue from the \u201cSale of fuel\u201d increased by \u20ac1,189 million,\nespecially by Enel Global Trading due to the rise in gas prices.\nThe increase in the \u201cSale of commodities under contracts\nwith physical se\ue61clement\u201d (\u20ac16,801 million) mainly regards gas\nsales. This positive e\ue61bect was pa\ue61fially o\ue61bset by the deterio-\nration in pe\ue619ormance of the measurement of contracts set-\ntled in 2021 (-\u20ac12,049 million), mainly involving gas contracts.\nThe following table shows the net fair value gain or loss on \ncontracts for the sale or purchase of commodities with\nphysical se\ue61clement measured at fair value through pro\ue61et or\nloss within the scope of IFRS 9.\n\nMillions of euro\n2021 2020 Change\nFair value gain/(loss) on contracts for energy commodities with physical se\ue61element\n(within the scope of IFRS 9) closed in the period\nSales contracts\nSale of electricity 4,368 2,478 1,890 76.3%\nFair value gain/(loss) on closed contracts (1,705) 353 (2,058) -\nTotal electricity 2,663 2,831 (168) -5.9%\nSale of gas 19,576 4,723 14,853 -\nFair value gain/(loss) on closed contracts (9,335) 791 (10,126) -\nTotal gas 10,241 5,514 4,727 85.7%\nSale of environmental ce\ue61fi\ue61ecates 370 312 58 18.6%\nFair value gain/(loss) on closed contracts 147 12 135 -\nTotal environmental ce\ue61bi\ue61fcates 517 324 193 59.6%\nTotal revenue 13,421 8,669 4,752 54.8%\nPurchase contracts\nPurchase of electricity 3,677 2,828 849 30.0%\nFair value gain/(loss) on closed contracts (1,220) (47) (1,173) -\nTotal electricity 2,457 2,781 (324) -11.7%\nPurchase of gas 19,951 4,661 15,290 -\nFair value gain/(loss) on closed contracts (8,057) 684 (8,741) -\nTotal gas 11,894 5,345 6,549 -\nPurchase of environmental ce\ue61fi\ue61ecates 810 92 718 -\nFair value gain/(loss) on closed contracts 145 139 6 4.3%\nTotal environmental ce\ue61bi\ue61fcates 955 231 724 -\nTotal costs 15,306 8,357 6,949 83.2%\nNet revenue/(costs) on contracts for energy commodities with physical se\ue61element\n(within the scope of IFRS 9) closed in the period\n(1,885) 312 (2,197) -\nUnrealized fair value gain/(loss) on outstanding contracts for energy commodities\nwith physical se\ue61element (IFRS 9)\nSales contracts\nElectricity (1,606) (197) (1,409) -\nGas (16,285) (668) (15,617) -\nEnvironmental ce\ue61fi\ue61ecates (495) (67) (428) -\nTotal (18,386) (932) (17,454) -\nPurchase contracts\nElectricity (2,169) (108) (2,061) -\nGas (13,801) (869) (12,932) -\nEnvironmental ce\ue61fi\ue61ecates (508) (68) (440) -\nTotal (16,478) (1,045) (15,433) -\nNet unrealized fair value gain/(loss) on outstanding contracts for energy commodities\nwith physical se\ue61element (IFRS 9)\n(1,908) 113 (2,021) -\nTOTAL REVENUE/(COSTS) ON CONTRACTS WITH PHYSICAL SETTLEMENT (WITHIN\nTHE SCOPE OF IFRS 9)\n(3,793) 425 (4,218) -\n\nRevenue from contracts with customers (IFRS 15) breaks\ndown into \u201cpoint in time\u201d and \u201cover time\u201d revenue as indi-\ncated in the following tables.\nMillions of euro 2021\nItaly Iberia Latin America Europe No\ue61bh America\nAfrica, Asia\nand Oceania\nOther,\neliminations and\nadjustments Total\nOver\ntime\nPoint\nin time\nOver\ntime\nPoint\nin time\nOver\ntime\nPoint\nin time\nOver\ntime\nPoint\nin time\nOver\ntime\nPoint in\ntime\nOver\ntime\nPoint in\ntime\nOver\ntime\nPoint in\ntime\nOver\ntime\nPoint in\ntime\nTotal IFRS 15 revenue 29,187 1,178 19,707 402 16,525 245 1,598 654 805 17 194 26 - 113 68,016 2,635\n2020\nItaly Iberia Latin America Europe No\ue61bh America\nAfrica, Asia\nand Oceania\nOther,\neliminations and\nadjustments Total\nOver\ntime\nPoint\nin time\nOver\ntime\nPoint\nin time\nOver\ntime\n(1)\nPoint\nin time\nOver\ntime\nPoint\nin time\nOver\ntime\nPoint in\ntime\nOver\ntime\nPoint in\ntime\nOver\ntime\nPoint in\ntime\nOver\ntime\nPoint in\ntime\nTotal IFRS 15 revenue 21,107 441 16,355 460 13,520 200 1,418 580 586 51 67 79 16 72 53,069 1,883\n(1) For comparative purposes only, \u20ac87 million in 2020 in respect of the component recognized through pro\ue61et or loss deriving from the remeasurement at fair\nvalue of the \ue61enancial assets connected with service concession arrangements involving distribution operations in Brazil falling within the scope of IFRIC 12\nhave been reclassi\ue61eed from \ue61enancial income to revenue. The la\ue61cer classi\ue61ecation had an impact of the same amount on operating pro\ue61et. For more details,\nplease see note 7 to the consolidated \ue61enancial statements.\n\nWith regard to the release to pro\ue61et or loss by time class\nof \u201cpe\ue619ormance obligations\u201d, please see note 27 \u201cCurrent/\nNon-current contract assets/(liabilities)\u201d.\nThe table below gives a breakdown of revenue from sales\nand services by geographical segment.\nMillions of euro\n2021 2020\n (1)\nItaly 33,304 24,904\nEurope\nIberia 18,896 16,169\nFrance 970 503\nSwitzerland 2,918 99\nGermany 1,085 1,860\nAustria 245 66\nSlovenia 195 2\nRomania 1,534 1,322\nGreece 121 110\nBulgaria - 9\nBelgium 522 18\nCzech Republic 435 33\nHungary 12 165\nRussia 552 533\nNetherlands 96 2,743\nUnited Kingdom 3,736 399\nOther European countries 1,160 73\nAmericas\nUnited States 601 502\nCanada 33 25\nMexico\n(2)\n202 152\nBrazil\n(3)\n9,381 6,753\nChile 3,151 2,811\nPeru 1,111 1,118\nColombia 2,188 2,022\nArgentina 887 816\nPanama 150 136\nCosta Rica 14 22\nGuatemala 67 44\nOther\nAfrica 114 84\nAsia 371 129\nOceania 53 20\nTotal 84,104 63,642\n(1) The \ue61egures for 2020 have been adjusted, for comparative purposes only, to take account of the e\ue61bects associated with the change in classi\ue61ecation connect-\ned with the fair value measurement of outstanding contracts at the end of the period for the purchase and sale of commodities with physical se\ue61clement.\nFor more details, please see note 7 to these consolidated \ue61enancial statements.\n(2) The \ue61egures for 2020 have been reallocated more accurately among Mexico, Costa Rica and Guatemala.\n(3) For comparative purposes only, \u20ac87 million in 2020 in respect of the component recognized through pro\ue61et or loss deriving from the remeasurement at fair\nvalue of the \ue61enancial assets connected with service concession arrangements involving distribution operations in Brazil falling within the scope of IFRIC 12\nhave been reclassi\ue61eed from \ue61enancial income to revenue. The la\ue61cer classi\ue61ecation had an impact of the same amount on operating pro\ue61et. For more details,\nplease see note 7 to the consolidated \ue61enancial statements.\n\nPe\ue61aormance obligations\nThe following table provides information about the Group\u2019s\npe\ue619ormance obligations arising from contracts with cus-\ntomers with reference to the main revenue streams only,\nwith a summary of the speci\ue61ec judgments made and the\nrelated revenue recognition policies.\nFor information on the use of estimates with revenue from\ncontracts with customers, please see note 2.1 \u201cUse of esti-\nmates and management judgment\u201d.\nType of product/\nservice Nature and timing of satisfaction of pe\ue61aormance obligation Accounting policies\nSale/transpo\ue61f of\nelectricity/gas to\nend users\nAn electricity/gas supply agreement signed with an end user includes\na single pe\ue619ormance obligation (sale and transpo\ue61f of the commodity)\nbecause the Group has determined that the contract does not provide\ndistinct goods/services and the promise is satis\ue61eed by transferring\ncontrol over the commodity to the customer when it is delivered at\nthe point of delivery. In order to determine the nature of the promise\nincluded in such contracts, the Group carefully analyzes the facts and\ncircumstances applicable to each contract and commodity.\nHowever, the Group considers that the pe\ue619ormance obligation provided\nfor in a repetitive service contract, such as a supply or transpo\ue61f contract\nfor the provision of electricity/gas to end users, is typically satis\ue61eed over\ntime (because the customer simultaneously receives and consumes the\nbene\ue61ets of the commodity as it is delivered) as pa\ue61f of a series of distinct\ngoods/services (i.e., each unit of commodity) that are substantially the\nsame and have the same pa\ue61cern of transfer to the customer. In these\ncases, the Group applies an output method to recognize revenue in the\namount to which it has a right to invoice the customer if that amount\ncorresponds directly with the value to the customer of the pe\ue619ormance\ncompleted to date.\nRevenue from the sale and transpo\ue61f of\nelectricity/gas to end users is recognized\nwhen these commodities are delivered to the\ncustomer and is based on the quantities provided\nduring the period, even if these have not yet\nbeen invoiced. It is determined using estimates\nas well as periodic meter readings. Where\napplicable, this revenue is based on the rates and\nrelated restrictions established by law or by the\nRegulatory Authority for Energy, Networks and\nthe Environment (ARERA) and analogous foreign\nauthorities during the applicable period.\nNetwork\nconnection\nservices\nThe network connection fees received from customers for connecting\nthem to the electricity/gas distribution networks require a speci\ue61ec\nGroup assessment to take into consideration all terms and conditions of\nthe connection arrangements.\nThis assessment is intended to determine whether the contract includes\nother distinct goods or services, such as for example the right to obtain\nongoing access to the infrastructure in order to receive the commodity\nor, when the connection fee is a \u201cnon-refundable up-front fee\u201d paid\nat or near contract inception, a material right that gives rise to a\npe\ue619ormance obligation.\nIn pa\ue61ficular, in some countries in which the Group operates, it has\ndetermined that the nature of the consideration received represents\na \u201cnon-refundable up-front fee\u201d whose payment provides a material\nright to the customer. In order to determine if the period over which\nthis material right should be recognized extends beyond the initial\ncontractual period, the Group takes into consideration the applicable\nlocal legal and regulatory framework applicable to the contract and\na\ue61becting the pa\ue61fies. In such cases, if there is an implied assignment\nof the material right and an obligation from the initial customer to\nthe new customer, the Group recognizes the connection fee over a\nperiod beyond the relationship with the initial customer, considering\nthe concession terms as the period during which the initial customer\nand any future customer can bene\ue61et from the ongoing access without\npaying an additional connection fee. As a consequence, the fee is\nrecognized over the period for which the payment creates an obligation\nfor the Group to make the lower prices available to future customers (i.e.,\nthe period during which the customer is expected to bene\ue61et from the\nongoing access service without having to pay an \u201cup-front fee\u201d upon\nrenewal).\nRevenue from monetary and in-kind fees for\nconnection to the electricity and gas distribution\nnetwork is recognized on the basis of the\nsatisfaction of the pe\ue619ormance obligations\nincluded in the contract. The identi\ue61ecation of\ndistinct goods or services requires a careful\nanalysis of the terms and conditions of the\nconnection arrangements, which could vary\nfrom country to country based on the local\ncontext, regulations and law. In order to \ue61enalize\nthis assessment, the Group considers not\nonly the characteristics of the goods/services\nthemselves (i.e., the good or service is capable of\nbeing distinct) but also the implied promises for\nwhich the customer has a valid expectation as it\nviews those promises as pa\ue61f of the negotiated\nexchange, that is goods/services that the\ncustomer expects to receive and has paid for (i.e.,\nthe promise to transfer the good or service to\nthe customer is separately identi\ue61eable from other\npromises in the contract).\nFu\ue61fhermore, the Group acts as an agent in some\ncontracts for electricity/gas network connection\nservices and other related activities, depending\non local legal and regulatory framework. In such\ncases, it recognizes revenue on a net basis,\ncorresponding to any fee or commission to which\nit expects to be entitled.\nConstruction\ncontracts\nThe construction contracts typically include a pe\ue619ormance obligation\nsatis\ue61eed over time. For these contracts, the Group generally considers\nit appropriate to use an input method for measuring progress, except\nwhen a speci\ue61ec contract analysis suggests the use of an alternative\nmethod that be\ue61cer depicts the Group\u2019s pe\ue619ormance obligation ful\ue61elled\nat the repo\ue61fing date.\nFor construction contracts that include a\npe\ue619ormance obligation satis\ue61eed over time,\nthe Group recognizes revenue over time by\nmeasuring progress toward the complete\nsatisfaction of that pe\ue619ormance obligation. The\ncost-to-cost method is generally considered the\nbest method to depict the Group\u2019s pe\ue619ormance\nobligation ful\ue61elled at the repo\ue61fing date.\nThe amount due from customers under a\nconstruction contract is presented as a contract\nasset; the amount due to customers under a\nconstruction contract is presented as a contract\nliability.\n\n10.b Other income \u2013 \u20ac3,902 million\nMillions of euro\n2021 2020 Change\nGrants related to income 33 12 21 -\nGrants for environmental ce\ue61fi\ue61ecates 291 342 (51) -14.9%\nGrants related to assets (electricity and gas business) 26 24 2 8.3%\nSundry reimbursements 305 371 (66) -17.8%\nGains on the disposal of subsidiaries, associates, joint ventures, joint\noperations and non-current assets held for sale\n1,781 15 1,766 -\nGains on the disposal of prope\ue61fy, plant and equipment and intangible assets 66 58 8 13.8%\nService continuity bonuses 48 40 8 20.0%\nOther income 1,352 1,500 (148) -9.9%\nTotal 3,902 2,362 1,540 65.2%\n\u201cSundry reimbursements\u201d amounted to \u20ac305 million, a\ndecrease of \u20ac66 million compared with the previous year,\nwith most of the reduction coming in Italy due to a de-\ncrease in penalties and reimbursements for damages re-\ncorded at e-distribuzione and Enel Energia.\nGains on the disposal of entities amounted to \u20ac1,781 mil-\nlion in 2021, an increase of \u20ac1,766 million, mainly re\ue61decting\nthe recognition in 2021 of the capital gain on the sale of\nEnel SpA\u2019s interest in Open Fiber (\u20ac1,763 million).\n\u201cOther income\u201d decreased by \u20ac148 million, mainly due to\nthe decline registered by e-distribuzione in other income\nfrom the electricity business (\u20ac288 million), primarily re-\n\ue61decting the reimbursement of system charges and grid\nfees.\nThis negative e\ue61bect was pa\ue61fially o\ue61bset by the increase\nregistered at Enel Green Power No\ue61fh America in income\nfrom tax pa\ue61fnerships (\u20ac44 million) and an increase in in-\ncome from the eco-bonus subsidy relating to energy and\nseismic upgrading posted by Enel X Italia (\u20ac84 million).\nThe following tables show a breakdown of total revenue by\nbusiness segment based on the approach used by man-\nagement to monitor the Group\u2019s pe\ue619ormance during the\ntwo years being compared.\nMillions of euro 2021\nThermal\nGeneration\nand Trading\nEnel Green\nPower\nInfrastructure\nand Networks\nEnd-\nuser\nMarkets Enel X Services\nHolding\nand\nother\nTotal\nrepo\ue61bing\nsegment\nEliminations\nand\nadjustments Total\nTotal IFRS 15 revenue 17, 2 13 8,843 20,078 38,238 1,394 1,972 138 87,876 (17,225) 70,651\nSale of commodities\nunder contracts with\nphysical se\ue61clement\n26,691 - - 14 - - - 26,705 (2,391) 24,314\nFair value gain/(loss)\non commodity sales\ncontracts with physical\nse\ue61clement closed\nduring the period\n(10,895) - - 1 - - - (10,894) 1 (10,893)\nOther revenue 5 6 15 - 3 14 17 60 (28) 32\nTotal revenue from\nsales and services\n33,014 8,849 20,093 38,253 1,397 1,986 155 103,747 (19,643) 84,104\nOther income 141 677 563 455 144 11 1,779 3,770 132 3,902\nTOTAL REVENUE 33,155 9,526 20,656 38,708 1,541 1,997 1,934 107,517 (19,511) 88,006\n\nMillions of euro 2020\nThermal\nGeneration\nand Trading\nEnel Green\nPower\nInfrastructure\nand Networks\nEnd-\nuser\nMarkets Enel X Services\nHolding\nand\nother\nTotal\nrepo\ue61bing\nsegment\nEliminations\nand\nadjustments Total\nTotal IFRS 15 revenue\n(1)\n9,812 7, 143 18,462 29,143 1,022 1,835 136 67, 5 5 3 (12,601) 54,952\nSale of commodities\nunder contracts with\nphysical se\ue61clement\n10,192 - - 15 - - - 10,207 (2,694) 7,513\nFair value gain/(loss)\non commodity sales\ncontracts with physical\nse\ue61clement closed during\nthe period\n1,164 - - (7) - - - 1,157 (1) 1,156\nOther revenue 6 7 6 - 4 6 3 32 (11) 21\nTotal revenue from sales\nand services\n21,174 7, 15 0 18,468 29,151 1,026 1,841 139 78,949 (15,307) 63,642\nOther income 562 542 961 357 95 29 15 2,561 (199) 2,362\nTOTAL REVENUE\n(1) (2)\n21,736 7,69 2 19,429 29,508 1,121 1,870 154 81,510 (15,506) 66,004\n(1) For comparative purposes only, \u20ac87 million in 2020 in respect of the component recognized through pro\ue61et or loss deriving from the remeasurement at fair\nvalue of the \ue61enancial assets connected with service concession arrangements involving distribution operations in Brazil falling within the scope of IFRIC 12\nhave been reclassi\ue61eed from \ue61enancial income to revenue. The la\ue61cer classi\ue61ecation had an impact of the same amount on operating pro\ue61et. For more details,\nplease see note 7 to these consolidated \ue61enancial statements.\n(2) The \ue61egures for 2020 have been adjusted, for comparative purposes only, to take account of the e\ue61bects associated with the change in classi\ue61ecation connect-\ned with the fair value measurement of outstanding contracts at the end of the period for the purchase and sale of commodities with physical se\ue61clement.\nThe change in classi\ue61ecation had no impact on operating pro\ue61et. For more details, please see note 7 to these consolidated \ue61enancial statements.\n",
"dimensions": {
"concept": "ifrs-full:DisclosureOfRevenueExplanatory",
"language": "en",
"entity": "scheme:WOCMU6HCI0OJWNPRZS33",
"period": "2021-01-01T00:00:00/2022-01-01T00:00:00"
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"Tag8": {
"value": "\nCosts\n11.a Electricity, gas and fuel \u2013 \u20ac49,093 million\nMillions of euro\n2021 2020 Change\nElectricity 29,579 16,158 13,421 83.1%\nGas 27,046 7, 9 52 19,094 -\nFair value gain/(loss) on contracts for purchase of electricity and gas with\nphysical se\ue61clement closed during the period\n(1)\n(9,277) 637 (9,914) -\nNuclear fuel 107 117 (10) -8.5%\nOther fuels 1,638 1,162 476 41.0%\nTotal\n (1)\n49,093 26,026 23,067 88.6%\n(1) The \ue61egures for 2020 have been adjusted, for comparative purposes only, to take account of the e\ue61bects associated with the change in classi\ue61ecation connect-\ned with the fair value measurement of outstanding contracts at the end of the period for the purchase and sale of commodities with physical se\ue61clement.\nThe change in classi\ue61ecation had no impact on operating pro\ue61et. For more details, please see note 7 to these consolidated \ue61enancial statements. \nCosts for the purchase of \u201cElectricity\u201d mainly increased\ndue to a rise in volumes purchased in an environment of in-\ncreasing average prices compared with the previous year,\nmainly a\ue61cributable to Italy (\u20ac8,098 million), Spain (\u20ac2,564\nmillion) and Latin America (\u20ac2,428 million).\nThe increase in costs for the purchase of \u201cGas\u201d re\ue61dects the\nincrease in quantities handled, mainly due to a rise in gen-\neration, as well as the increase in the cost of purchasing\ngas from third pa\ue61fies.\nThe fair value loss on closed contracts with physical se\ue61cle-\nment changed from a fair value gain in the previous year,\nwith a di\ue61berence of \u20ac9,914 million, of which \u20ac8,741 million\na\ue61cributable to gas and \u20ac1,173 million to electricity.\nThe increase in \u201cOther fuels\u201d is mainly a\ue61cributable to the\nincrease in the volume of generation and the rise in com-\nmodity prices.\n\n11.b Services and other materials \u2013 \u20ac19,609 million \nMillions of euro\n2021 2020 Change\nWheeling 9,023 9,619 (596) -6.2%\nMaintenance and repairs 1,410 1,127 283 25.1%\nTelephone and postal costs 180 172 8 4.7%\nCommunication services 127 116 11 9.5%\nIT services 967 823 144 17.5 %\nLeases and rentals 126 396 (270) -68.2%\nOther services 4,246 3,648 598 16.4%\nPurchase of environmental ce\ue61fi\ue61ecates 1,279 673 606 90.0%\nFair value gain on contracts for purchase of environmental ce\ue61fi\ue61ecates with\nphysical se\ue61clement closed during the period\n(1)\n145 139 6 4.3%\nOther materials 2,106 1,653 453 27.4%\nTotal\n(1)\n19,609 18,366 1,243 6.8%\n(1) The \ue61egures for 2020 have been adjusted, for comparative purposes only, to take account of the e\ue61bects associated with the change in classi\ue61ecation connect-\ned with the fair value measurement of outstanding contracts at the end of the period for the purchase and sale of commodities with physical se\ue61clement.\nThe change in classi\ue61ecation had no impact on operating pro\ue61et. For more details, please see note 7 to these consolidated \ue61enancial statements.\nCosts for services and other materials amounted to\n\u20ac19,609 million in 2021, an increase of \u20ac1,243 million com-\npared with 2020. This change essentially re\ue61dected:\n\u2022 a decline in costs for wheeling, mainly in Spain, a\ue61cribut-\nable to a decline in the average price applied;\n\u2022 future costs connected with the conversion of plants \nin Italy for the purposes of the energy transition. More\nspeci\ue61ecally, these costs regard provisions associated\nwith the acceleration of the energy-transition process,\nwhich a\ue61bected almost all of Enel Produzione\u2019s plants\nwith the NextGen project (\u20ac426 million). In application\nof the Group strategy to accelerate the elimination of\nthe use of fossil fuels from the generation process and\nincreasing our green capacity, we have commi\ue61ced our-\nselves to launching a radical process to decommission\nand secure Italian generation facilities that use tradi-\ntional energy sources that are no longer in line with Eu-\nropean standards, with a view to conve\ue61fing them into\nrenewable energy facilities or installing storage systems\nand other circular economy initiatives;\n\u2022 an increase in costs for systems assistance, computer \nmaintenance and IT development, mainly in Italy;\n\u2022 a decline in costs for leases and rentals, mainly re\ue61dect-\ning the closure of a dispute in Spain, which permi\ue61ced\nthe reversal of provisions previously recognized in the\namount of about \u20ac300 million;\n\u2022 an increase in costs for the purchase of environmen-\ntal ce\ue61fi\ue61ecates, a\ue61cributable to a signi\ue61ecant increase in\nthe prices of CO\n2\n, the increase in production at thermal\ngeneration plants and an expansion of trading in emis-\nsion allowances;\n\u2022 an increase of \u20ac598 million in \u201cOther services\u201d, essen-\ntially re\ue61decting the increase in costs for services con-\nnected with the electricity and gas business (\u20ac154 mil-\nlion), those related to the value-added services busi-\nness (\u20ac150 million) and expenses for professional and\ntechnical services (\u20ac147 million).\n11.c Personnel expenses \u2013 \u20ac5,281 million\nMillions of euro\n2021 2020 Change\nWages and salaries 3,238 3,133 105 3.4%\nSocial security contributions 853 824 29 3.5%\nItalian post-employment bene\ue61ets 104 103 1 1.0%\nPost-employment and other long-term bene\ue61ets 85 (485) 570 -\nEarly retirement incentives 10 152 (142) -93.4%\nEarly retirement incentives connected with restructuring agreements 806 882 (76) -8.6%\nOther costs 185 184 1 0.5%\nTotal 5,281 4,793 488 10.2%\n\nPersonnel expenses amounted to \u20ac5,281 million in 2021,\nan increase of \u20ac488 million.\nThe Group\u2019s workforce decreased by 438 employees,\nmainly re\ue61decting the negative balance between new hires\nand terminations (-461 employees) due to early-retirement\nincentive policies and changes in the consolidation scope\n(+23 employees), essentially a\ue61cributable to:\n\u2022 the sale of Enel Green Power Bulgaria; \n\u2022 the acquisition of CityPoste Payment SpA in Italy.\nThe increase in \u201cWages and salaries\u201d substantially re\ue61dects\nthe cost incurred as a result of new hiring at companies in\nItaly, the United States and Argentina.\nThe \u20ac570 million increase in \u201cPost-employment and oth-\ner long-term bene\ue61ets\u201d is mainly a\ue61cributable to the 2020\nmodi\ue61ecation in Spain of the electricity discount bene\ue61et for\nemployees following the renewal of the 5th Endesa Collec-\ntive Bargaining Agreement, which led to the release of the\nassociated provision in the amount of \u20ac515 million.\nExpenses for early retirement incentives in 2021 amounted\nto \u20ac816 million, down \u20ac218 million, with the change largely\naccounted for by Spain (\u20ac732 million) due to the e\ue61bect of\nthe accrual in 2020 to the provision for the Plan de Salida \nprompted by elimination of the extinguishment option of\nthe individual agreement concerning the suspension of\nemployment relationships for ce\ue61fain individual contracts\nas a result of the signing of the new collective bargaining\nagreement mentioned earlier, only pa\ue61fly o\ue61bset by an in-\ncrease in costs for early retirement incentives in Italy (\u20ac480\nmillion) associated with corporate restructuring programs.\nThe table below shows the average number of employees\nby category, along with a comparison with the previous\nyear, and the headcount as of December 31, 2021.\nNo. Average\n(1)\nHeadcount\n(1)\n2021 2020 at Dec. 31, 2021\nSenior managers 1,386 1,397 1,377\nMiddle managers 11,797 11,258 12,242\nO\ue61ace sta\ue61b 35,449 36,027 35,556\nBlue collar 17,344 18,396 17, 10 4\nTotal 65,976 67, 07 8 66,279\n(1) For companies consolidated on a propo\ue61fionate basis, the headcount corresponds to Enel\u2019s percentage share of the total.\n11.d Net impairment losses/(reversals) on trade receivables and other receivables \u2013\n\u20ac1,196 million\nMillions of euro\n2021 2020 Change\nImpairment losses on trade receivables 1,361 1,505 (144) -9.6%\nImpairment losses on other receivables 94 46 48 -\nTotal impairment losses on trade receivables and other receivables 1,455 1,551 (96) -6.2%\nImpairment gains on trade receivables (258) (194) (64) -33.0%\nImpairment gains on other receivables (1) (72) 71 98.6%\nTotal impairment gains on trade receivables and other receivables (259) (266) 7 2.6%\nNET IMPAIRMENT LOSSES/(REVERSALS) ON TRADE RECEIVABLES AND\nOTHER RECEIVABLES\n1,196 1,285 (89) -6.9%\nThe item, equal to \u20ac1,196 million, includes impairment\nlosses and gains on trade receivables and other receiva-\nbles. The net impairment losses on trade receivables de-\ncreased by a total of \u20ac208 million, essentially re\ue61decting the\ne\ue61bect of the recognition in 2020 of greater impairment\nlosses on trade receivables in respect of traders.\n\n11.e Depreciation, amo\ue61eization and other impairment losses \u2013 \u20ac8,691 million\nMillions of euro\n2021 2020 Change\nPrope\ue61fy, plant and equipment 4,414 4,118 296 7. 2 %\nInvestment prope\ue61fy 3 2 1 50.0%\nIntangible assets 1,357 1,223 134 11.0%\nOther impairment losses 2,926 1,857 1,069 57.6 %\nOther reversals of impairment losses (9) (37) 28 75.7%\nTotal 8,691 7, 16 3 1,528 21.3%\nThe increase in \u201cDepreciation, amo\ue61fization and other im-\npairment losses\u201d in 2021 essentially re\ue61dected:\n\u2022 an increase in depreciation and amo\ue61fization in Italy \n(\u20ac102 million) due to an acceleration of the depreciation\nrates for \ue61erst-generation electronic meters (1G) in order\nto re\ue61dect the planned installation schedule for 2G me-\nters provided for in the Open Meter plan;\n\u2022 an increase in depreciation and amo\ue61fization in Spain \nfor new plants entering service (\u20ac72 million);\n\u2022 impairment losses recognized in 2021 on ce\ue61fain plants \nor CGUs in Italy (\u20ac989 million), Spain (\u20ac1,488 million),\nMexico (\u20ac155 million), Chile (\u20ac32 million) and Australia\n(\u20ac30 million);\n\u2022 the impairment loss recognized on Group's headquar-\nters building in Rome (\u20ac45 million);\n\u2022 the impairment losses recognized in Costa Rica (\u20ac126 \nmillion) on the hydroelectric plant operated under a\nconcession arrangement by PH Chucas.\nThese e\ue61bects were pa\ue61fially o\ue61bset by:\n\u2022 the e\ue61bect of the impairment losses recognized in 2020 \non the Bocamina II plant in Chile (\u20ac737 million);\n\u2022 the e\ue61bect of the impairment losses recognized in 2020 \non the Mexico, Argentina and Australia CGUs in the total\namount of \u20ac750 million.\n11.f Other operating costs \u2013 \u20ac2,095 million\nMillions of euro\n2021 2020 Change\nSystem charges - emissions allowances 41 90 (49) -54.4%\nCharges for energy e\ue61aciency ce\ue61fi\ue61ecates 239 277 (38) -13.7%\nCharges for purchases of green ce\ue61fi\ue61ecates 64 61 3 4.9%\nLosses on disposal of prope\ue61fy, plant and equipment and intangible assets 75 65 10 15.4%\nTaxes and duties 1,132 1,130 2 0.2%\nOther 544 579 (35) -6.0%\nTotal 2,095 2,202 (107) -4.9%\nOther operating costs decreased by \u20ac107 million com-\npared with the previous year, mainly due to a reduction in\nenvironmental compliance charges and association dues\nin Italy. \n11.g Capitalized costs \u2013 \u20ac(3,117) million\nMillions of euro\n2021 2020 Change\nPersonnel (1,022) (836) (186) -22.2%\nMaterials (1,120) (846) (274) -32.4%\nOther (975) (703) (272) -38.7%\nTotal (3,117) (2,385) (732) -30.7%\nCapitalized costs increased by \u20ac732 million, mainly due to\ngreater investment in distribution plants in Latin America\nand distribution grids associated with the development\nof the Grid Blue Sky project and to the installation of sec-\nond-generation meters in Italy in 2021.\n",
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"concept": "ifrs-full:DisclosureOfExpensesByNatureExplanatory",
"language": "en",
"entity": "scheme:WOCMU6HCI0OJWNPRZS33",
"period": "2021-01-01T00:00:00/2022-01-01T00:00:00"
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"Tag9": {
"value": "\n12. Net results from commodity contracts \u2013 \u20ac2,522 million\nMillions of euro\n2021 2020 Change\nCommodity derivatives\n- income from se\ue61cled derivatives 11,456 4,346 7, 1 10 -\n- expense from se\ue61cled derivatives 9,331 4,912 4,419 90.0%\nNet income/(expense) from se\ue61eled commodity derivatives 2,125 (566) 2,691 -\n- income from outstanding derivatives 4,572 634 3,938 -\n- expense from outstanding derivatives 2,267 280 1,987 -\nNet income from outstanding commodity derivatives 2,305 354 1,951 -\nOutstanding contracts for energy commodities with physical se\ue61element\n- results from outstanding contracts to sell energy commodities with\nphysical se\ue61clement\n (1)\n(18,386) (932) (17,454) -\n- results from outstanding contracts to purchase energy commodities with\nphysical se\ue61clement\n(1)\n16,478 1,045 15,433 -\nNet results from outstanding contracts for energy commodities with\nphysical se\ue61element\n (1)\n(1,908) 113 (2,021) -\nNET RESULTS FROM COMMODITY CONTRACTS\n(1)\n2,522 (99) 2,621 -\n(1) The \ue61egures for 2020 have been adjusted, for comparative purposes only, to take account of the e\ue61bects associated with the change in classi\ue61ecation connect-\ned with the fair value measurement of outstanding contracts at the end of the period for the purchase and sale of commodities with physical se\ue61clement.\nThe change in classi\ue61ecation had no impact on operating pro\ue61et. For more details, please see note 7 to these consolidated \ue61enancial statements.\nNet results from commodity came to \u20ac2,522 million in 2021\n(net expense of \u20ac99 million in 2020), and breaks down as\nfollows:\n\u2022 net income from commodity derivatives totaling \u20ac4,430 \nmillion (net expense of \u20ac212 million in 2020), including\nderivatives designated as cash \ue61dow hedges and de-\nrivatives measured at fair value through pro\ue61et or loss.\nMore speci\ue61ecally, net income from derivatives se\ue61cled in\nthe period amounted to \u20ac2,125 million (net expense of\n\u20ac566 million in 2020) and the net fair gain on outstand-\ning derivatives came to \u20ac2,305 million (net fair value\ngain of \u20ac354 million in 2020);\n\u2022 net fair value loss on energy commodity contracts with \nphysical se\ue61clement still outstanding at the repo\ue61fing\ndate amounting to \u20ac1,908 million (net fair value gain of\n\u20ac113 million in 2020).\nFor more information on derivatives, please see note 49\n\u201cDerivatives and hedge accounting\u201d.\n",
"dimensions": {
"concept": "enel:DisclosureOfNetResultsFromCommodityContracts",
"language": "en",
"entity": "scheme:WOCMU6HCI0OJWNPRZS33",
"period": "2021-01-01T00:00:00/2022-01-01T00:00:00"
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"Tag10": {
"value": "\n13. Net \ue61fnancial income/(expense) from derivatives \u2013 \u20ac1,461 million\nMillions of euro\n2021 2020 Change\nIncome:\n- income from derivatives designated as hedging derivatives 2,097 639 1,458 -\n- income from derivatives at fair value through pro\ue61et or loss 621 676 (55) -8.1%\nTotal income 2,718 1,315 1,403 -\nExpense:\n- expense from derivatives designated as hedging derivatives (599) (1,945) 1,346 69.2%\n- expense from derivatives at fair value through pro\ue61et or loss (658) (311) (347) -\nTotal expense (1,257) (2,256) 999 44.3%\nNET FINANCIAL INCOME/(EXPENSE) FROM DERIVATIVES 1,461 (941) 2,402 -\nIn 2021, net income from derivatives on interest and ex-\nchange rates amounted to \u20ac1,461 million (net expense of\n\u20ac941 million in 2020) and breaks down as follows:\n\u2022 net income from derivatives designated as hedging de-\nrivatives in the amount of \u20ac1,498 million (net expense\nof \u20ac1,306 million in 2020), mainly in regard of cash \ue61dow\nhedges;\n\u2022 net expense from derivatives at fair value through pro\ue61et \nor loss in the amount of \u20ac37 million (net income of \u20ac365\nmillion in 2020).\nThe net balances recognized in 2021 and 2020 on both\nhedging derivatives and those at fair value through pro\ue61et\nor loss mainly referred to the hedging of currency risk. For\nmore information on derivatives, see note 49 \u201cDerivatives\nand hedge accounting\u201d.\n\n14. Net other \ue61fnancial income/(expense) \u2013 \u20ac(4,212) million\nOther \ue61fnancial income\nMillions of euro\n2021 2020 Change\nInterest income from \ue61fnancial assets\n(current and non-current):\n- interest income at e\ue61bective rate on non-current securities and \ue61enancial\nassets\n116 110 6 5.5%\n- interest income at e\ue61bective rate on current \ue61enancial investments 89 69 20 29.0%\nTotal interest income at the e\ue61cective interest rate 205 179 26 14.5%\nExchange gains 1,219 2,182 (963) -44.1%\nIncome on equity investments 6 23 (17) -73.9%\nIncome from hyperin\ue61dation 824 529 295 55.8%\nOther income\n(1)\n452 292 160 54.8%\nTOTAL OTHER FINANCIAL INCOME 2,706 3,205 (499) -15.6%\n(1) For comparative purposes only, \u20ac87 million in 2020 in respect of the component recognized through pro\ue61et or loss deriving from the remeasurement at fair\nvalue of the \ue61enancial assets connected with service concession arrangements involving distribution operations in Brazil falling within the scope of IFRIC 12\nhave been reclassi\ue61eed from \ue61enancial income to revenue. The la\ue61cer classi\ue61ecation had an impact of the same amount on operating pro\ue61et. For more details,\nplease see note 7 to these consolidated \ue61enancial statements.\nOther \ue61enancial income amounted to \u20ac2,706 million, a de-\ncrease of \u20ac499 million compared with the previous year.\nThe decline mainly re\ue61dects a decrease in income from ex-\nchange gains of \u20ac963 million, essentially a\ue61cributable to\nthe impact of exchange rate developments on net \ue61enan-\ncial debt denominated in currencies other than the euro.\nThis e\ue61bect was pa\ue61fially o\ue61bset by the following factors:\n\u2022 an increase in income from hyperin\ue61dation (\u20ac295 mil-\nlion), recognized by the Argentine companies as a re-\nsult of the application of IAS 29 on \ue61enancial repo\ue61fing \nin hyperin\ue61dationary economies; for more information,\nsee note 4 of these consolidated \ue61enancial statements;\n\u2022 the recognition of \ue61enancial income of \u20ac73 million in \nSpain, largely connected with interest on arrears ac-\ncrued in respect of Endesa\u2019s right to be compensated\nfor the reduction in remuneration received in the past\nwith regard to the assignment of CO\n2\n emission rights \nunder the \u201cPlan Nacional de Asignaci\u00f3n de Derechos \nde Emisi\u00f3n\u201d (PNA);\n\u2022 an increase in income deriving from the impairment \nloss on hedged liabilities in fair value hedge relation-\nships (\u20ac57 million);\n\u2022 an increase in interest income at the e\ue61bective rate \n(\u20ac26 million), mainly relating to sho\ue61f-term \ue61enancial in-\nvestments.\nOther \ue61fnancial expense\nMillions of euro\n2021 2020 Change\nInterest expense on \ue61fnancial debt\n(current and non-current):\n- interest on bank borrowings 346 291 55 18.9%\n- interest expense on bonds 1,881 1,887 (6) -0.3%\n- interest expense on other borrowings 137 149 (12) -8.1%\nTotal interest expense 2,364 2,327 37 1.6%\nFinancial expense on debt management transactions 702 - 702 -\nExchange losses 2,559 1,245 1,314 -\nAdjustment to post-employment and other employee bene\ue61fts 107 109 (2) -1.8%\nAdjustment to other provisions 129 150 (21) -14.0%\nExpense from equity investments - 1 (1) -\nExpense from hyperin\ue61dation 804 472 332 70.3%\nOther expenses 253 653 (400) -61.3%\nTOTAL OTHER FINANCIAL EXPENSE 6,918 4,957 1,961 39.6%\n\n\u201cOther \ue61enancial expense\u201d amounted to \u20ac6,918 million, an\noverall increase of \u20ac1,961 million compared with 2020, es-\nsentially re\ue61decting the following factors:\n\u2022 the recognition of expense on debt management trans-\nactions, regarding:\n \u2013 Enel Finance International in the amount of \u20ac634 \nmillion for the recognition of \ue61enancial expense on the\ncash consideration paid in connection with voluntary\nnon-binding tender o\ue61ber (\u201ctender o\ue61ber\u201d) for the re-\npurchase, and subsequent cancellation, of a number\nof series of outstanding conventional bonds;\n \u2013 Enel SpA in the amount of \u20ac68 million for the recog-\nnition of \ue61enancial expense connected with the con-\nsent solicitation for non-conve\ue61fible subordinated\nhybrid bonds conve\ue61fed into perpetual hybrid bonds.\nThis expense represents the di\ue61berence between the\nfair value of the hybrid instrument and the carrying\namount of the bond.\n With regard to the tender o\ue61ber and consent solicita-\ntion, the amount of the amo\ue61fized cost adjustment for\nthe bonds involved in these transactions was released\nto pro\ue61et or loss, which produced an increase in interest\nexpense compared with 2020. However, the aforemen-\ntioned debt management transactions, together with\nthe new sustainability-linked bond issues, have reduced\nthe Group\u2019s borrowing costs, providing an impo\ue61fant\ntool for protection against potential rate increases;\n\u2022 an increase in exchange losses in the amount of \u20ac1,314 \nmillion, primarily a\ue61cributable to the impact of exchange\nrate developments on net \ue61enancial debt denominated\nin currencies other than the euro;\n\u2022 an increase in expense from hyperin\ue61dation of \u20ac332 mil-\nlion, recognized by the Argentine companies as a re-\nsult of the application of IAS 29 on \ue61enancial repo\ue61fing in\nhyperin\ue61dationary economies; for more information, see\nnote 4 of these consolidated \ue61enancial statements.\nThese e\ue61bects were substantially o\ue61bset by the reduction in\n\ue61enancial expense associated with the impairment loss on\nthe \ue61enancial asset connected with the sale of Slovak Power\nHolding (\u20ac472 million).\n",
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"Tag11": {
"value": "\n15. Share of pro\ue61ft/(loss) of equity-accounted investments \u2013 \u20ac571 million\nMillions of euro\n2021 2020 Change\nShare of pro\ue61et of associates 624 131 493 -\nShare of loss of associates (53) (430) 377 87.7%\nTotal 571 (299) 870 -\nThe share of pro\ue61et/(loss) of equity-accounted investments\nimproved by \u20ac870 million compared with the previous year.\nThe change was essentially due to the impairment loss\non the investment in Slovak Power Holding (\u20ac908 million),\npa\ue61fly o\ue61bset by the change in the share of pro\ue61et/(loss) at-\ntributable to owners of the Parent of, mainly, the Po\ue61fu-\nguese company Tejo Energia Produ\u00e7\u00e3o e Distribui\u00e7\u00e3o de\nEnergia El\u00e9ctrica (\u20ac14 million).\n",
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"language": "en",
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"period": "2021-01-01T00:00:00/2022-01-01T00:00:00"
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"Tag12": {
"value": "\n16. Income taxes \u2013 \u20ac1,643 million\nMillions of euro\n2021 2020 Change\nCurrent taxes 2,023 1,898 125 6.6%\nAdjustments for income taxes relating to prior years 145 (168) 313 -\nTotal current taxes 2,168 1,730 438 25.3%\nDeferred tax expense 313 180 133 73.9%\nDeferred tax income (838) (69) (769) -\nTOTAL 1,643 1,841 (198) -10.8%\n\nThe tax rate for 2021 came to 30%, compared with 34% in \n2020. The reduction essentially re\ue61dects the combined e\ue61bect\nof the following permanent di\ue61berences:\n\u2022 a decrease in the tax impact of extraordinary items com-\npared with the previous year (\u20ac431 million), taking account\nof the taxation associated with the revaluation of the as-\nsets of Slovensk\u00e9 elektr\u00e1rne;\n\u2022 the application of the preferential \u201cpa\ue61ficipation exemp-\ntion\u201d mechanism to the capital gain realized on the sale of \nthe investment in Open Fiber (\u20ac401 million);\n\u2022 the adjustments of deferred and current taxation following \nthe tax reforms approved by the Argentine and Colombian \ngovernments, which increased the tax rate from 25% to\n35% in Argentina and from 30% to 35% in Colombia;\n\u2022 the adjustment of the tax credit held by Enel Iberia (\u20ac211 \nmillion);\n\u2022 the tax e\ue61bect of the application of hyperin\ue61dation account-\ning in Argentina (\u20ac49 million);\n\u2022 the non-recognition of pa\ue61f of the deferred tax assets as-\nsociated with the impairment loss recognized on PH Chu-\ncas due to the unce\ue61fainty about their future recoverability\n(\u20ac27 million);\n\u2022 the reversal of the tax credit of Enel Green Power SpA (\u20ac25 \nmillion) following the reorganization of the Enel Green\nPower Business Line in Latin America, which was complet-\ned in April 2021.\nFor more information on changes in deferred tax assets and \nliabilities, see note 24.\nThe following table provides a reconciliation of the theoretical\ntax rate and the e\ue61bective tax rate.\nMillions of euro\n2021 2020\nPre-tax pro\ue61ft/(loss) 5,500 5,463\nTheoretical taxes 1,320 24% 1,311 24%\nChange in tax e\ue61bect on impairment losses, capital gains and negative\ngoodwill\n(229) 202\nNet e\ue61bect on deferred taxation recognized with timing mismatch 70 16\nTax reforms in Argentina and Colombia 166 -\nAdjustment of tax credit of Enel Iberia 211 -\nPreferential tax treatment of Open Fiber capital gain (401) -\nDeferred tax assets not recognized on tax losses 75 -\nSundry tax e\ue61bects of hyperin\ue61dation accounting in Argentina 49 -\nReversal of tax credit for Astrid operation 25 -\nIRAP 276 249\nOther di\ue61berences, e\ue61bect of di\ue61berent tax rates abroad compared with the\ntheoretical rate in Italy, and other minor items\n81 63\nTotal 1,643 1,841\n",
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"value": "\n17. Basic and diluted earnings/(loss) per share\nBoth of these indicators are calculated on the basis of the\naverage number of ordinary shares for the year, equal to\n10,166,679,946, adjusted by the average number of treas-\nury shares held.\nThe number of treasury shares, with a par value of \u20ac1\neach, held at December 31, 2021 was equal to 4,889,152\n(3,269,152 at December 31, 2020).\nMillions of euro\n2021 2020\nPro\ue61ft for the year a\ue61eributable to owners of the Parent (basic) 3,189 2,610\nof which from:\n- continuing operations 3,189 2,610\n- discontinued operations - -\nE\ue61bect of preference rights on dividends (e.g. preference shares) - -\nDividends on equity instruments (e.g., hybrid bonds) (71) -\nOther - -\nPro\ue61ft for the year a\ue61eributable to ordinary owners of the Parent (basic) 3,118 2,610\nof which from:\n- continuing operations 3,118 2,610\n- discontinued operations - -\nNumber of shares (units)\nNumber of ordinary shares issued at 1 January 10,166,679,946 10,166,679,946\nE\ue61bect of treasury shares held (4,111,452) (2,067,594)\nE\ue61bect of share options exercised - -\nOther - -\nWeighted average number of ordinary shares outstanding (total) for basic\nearnings per share\n10,162,568,494 10,164,612,352\nPro\ue61ft for the year a\ue61eributable to ordinary owners of the Parent (basic) 3,118 2,610\nE\ue61bect of dilution:\n- interest on conve\ue61fible bonds - -\n- other - -\nPro\ue61ft for the year a\ue61eributable to ordinary owners of the Parent (diluted) 3,118 2,610\nof which:\n- continuing operations 3,118 2,610\n- discontinued operations - -\nNumber of shares (units)\nWeighted average number of ordinary shares outstanding (total) for basic\nearnings per share\n10,162,568,494 10,164,612,352\nE\ue61bect of conversion of conve\ue61fible notes - -\nOther - -\nWeighted average number of ordinary shares outstanding (total) for diluted\nearnings per share\n10,162,568,494 10,164,612,352\nBasic earnings per share\nBasic earnings per share 0.31 0.26\nBasic earnings per share from continuing operations 0.31 0.26\nBasic earnings/(loss) per share from discontinued operations - -\nDiluted earnings per share\nDiluted earnings per share 0.31 0.26\nDiluted earnings per share from continuing operations 0.31 0.26\nDiluted earnings/(loss) per share from discontinued operations - -\n",
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"period": "2021-01-01T00:00:00/2022-01-01T00:00:00"
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"Tag14": {
"value": "\n18. Prope\ue61ey, plant and equipment \u2013 \u20ac84,572 million\nThe breakdown of and changes in prope\ue61fy, plant and\nequipment for 2021 is given below.\nMillions of euro Land Buildings\nPlant and\nmachinery\nIndustrial\nand\ncommercial\nequipment\nOther\nassets\nLeased\nassets\nLeasehold \nimprovements\nAssets\nunder\nconstruction\n and advances Total\nCost net of accumulated\nimpairment losses\n637 10,263 159,411 523 1,487 2,994 443 8,896 184,654\nAccumulated depreciation - 5,456 97,8 07 380 1,155 819 319 - 105,936\nBalance at Dec. 31, 2020 637 4,807 61,604 143 332 2, 175 124 8,896 78,718\nCapital expenditure 3 39 1,883 22 73 1 9 8,404 10,434\nAssets entering service 28 884 4,741 8 55 8 15 (5,739) -\nExchange di\ue61berences (16) 113 (2) 1 (7) 35 1 103 228\nChange in the\nconsolidation scope\n- - 129 - (2) 8 - 147 282\nDisposals (1) (3) (110) (1) (11) (19) - (15) (160)\nDepreciation - (190) (3,766) (22) (88) (304) (30) - (4,400)\nImpairment losses (8) (191) (2,425) (1) - (4) - (155) (2,784)\nReversals of impairment\nlosses\n- - 8 - - - - - 8\nOther changes - 6 1,312 1 12 731 9 178 2,249\nReclassi\ue61ecations from/to\nassets held for sale\n- - - - (1) (2) - - (3)\nTotal changes 6 658 1,770 8 31 454 4 2,923 5,854\nCost net of accumulated\nimpairment losses\n643 11,115 163,443 547 1,551 3,722 482 11,819 193,322\nAccumulated depreciation - 5,650 100,069 396 1,188 1,093 354 - 108,750\nBalance at Dec. 31, 2021 643 5,465 63,374 151 363 2,629 128 11,819 84,572\n\u201cPlant and machinery\u201d included assets to be relinquished \nfree of charge with a carrying amount of \u20ac7,946 million at\nDecember 31, 2021 (\u20ac8,083 million at December 31, 2020),\nlargely regarding power plants in Iberia and Latin America\namounting to \u20ac3,672 million at December 31, 2021 (\u20ac3,808\nmillion at December 31, 2020), and the electricity distri-\nbution grid in Latin America totaling \u20ac3,506 million at De-\ncember 31, 2021 (\u20ac3,626 million at December 31, 2020).\nFor more information on \u201cLeased assets\u201d, please see note\n20 below.\nThe types of capital expenditure made during 2021 are\nsummarized below by class of asset, comprising the var-\nious categories of prope\ue61fy, plant and equipment and in-\ntangible assets, including the po\ue61fion classi\ue61eed as held for\nsale. These expenditures, totaling \u20ac12,201 million at De-\ncember 31, 2021, increased by \u20ac2,653 million on 2020, in-\ncreases that were pa\ue61ficularly concentrated in solar power\nplants.\n\nMillions of euro\n2021 2020 Change\nPower plants:\n- thermal 550 452 98 21.7%\n- hydroelectric 402 332 70 21.1%\n- geothermal 120 145 (25) -17. 2 %\n- nuclear 157 137 20 14.6%\n- alternative energy sources 4,947 4,007 940 23.5%\nTotal power plants 6,176 5,073 1,103 21.7%\nElectricity distribution grids\n(1)\n4,389 3,288 1,101 33.5%\nEnel X (e-Mobility, e-City, e-Industries, e-Home) 367 303 64 21.1%\nRetail customers 643 460 183 39.8%\nOther 626 424 202 47.6 %\nTOTAL\n(2)\n12,201 9,548 2,653 2 7. 8 %\n(1) The \ue61egure for 2021 does not include \u20ac907 million in respect of infrastructure investments within the scope of IFRIC 12 (\u20ac649 million in 2020).\n(2) The \ue61egure for 2021 includes \u20ac111 million regarding units classi\ue61eed as \u201cheld for sale\u201d.\nThe Enel Group, in line with the Paris Agreement on CO\n2\nemissions reductions and guided by energy e\ue61aciency\nand energy-transition objectives, has invested above all in \ngeneration plants that exploit alternative energy sources.\nCapital expenditure on generation plants mainly regards\nsolar plants and wind farms in the United States, Colom-\nbia, Iberia, Italy, India, Chile and Russia.\nIn order to respond to ever more variable climate devel-\nopments and, therefore, enhance the resilience of grids, \nthe Group continued to invest in the Distribution Busi-\nness Line (\u20ac4,389 million). The \u20ac1,101 million increase is\nmainly a\ue61cributable to greater investments in Italy, Brazil\nand Iberia for the Grid Blue Sky project (a new platform \noperating model that envisages the redesign of systems,\nprocesses and work organization to leverage assets more\ne\ue61bectively, including through the use of a\ue61fi\ue61ecial intelli-\ngence) and for quality and remote control activities.\nIn Italy, following the introduction of measures to revive \nthe economy and to encourage energy upgrading and\nseismic resilience, Enel X has unde\ue61faken greater in-\nvestments in the development of the e-Home business \nassociated with the Vivi Meglio initiative, while in Spain \ne-Home posted an increase as a result of greater sales\nvolumes compared with 2020. In No\ue61fh America and Ko-\nrea, its investments in storage increased.\nExchange gains amounted to \u20ac228 million.\nThe \u201cChange in the consolidation scope\u201d in 2021 mainly\nrefers to the consolidation of the Australian renewables \ncompanies, which had previously been equity-account-\ned, following changes in governance arrangements with-\nout the purchase of additional interests, as well as the \nacquisition of 30 renewable energy companies by Enel\nGreen Power Espa\u00f1a.\n\u201cImpairment losses\u201d amounted to \u20ac2,784 million and are\nmainly a\ue61cributable to the energy-transition process ini-\ntiated by the Group, which in 2021 led to the recognition\nof impairment losses on the Italian thermal generation\nplants of Torrevaldaliga Nord, Fusina, La Spezia and Brin-\ndisi, the Spanish generation plants of Baleares, Canarias,\nCeuta and Melilla and the Bocamina II plant in Chile.\nThis item was also a\ue61bected by the impairment loss on as-\nsets in Australia and Mexico.\n\u201cReclassi\ue61ecations from/to assets held for sale\u201d refer\nmainly to the prope\ue61fy and other assets of the Italian\ncompanies Enel X Paytipper SpA, Paytipper Network Srl\nand CityPoste Payment SpA.\n\u201cOther changes\u201d include the provision for plant retirement\nand site restoration costs in the amount of \u20ac861 million,\nmainly in Spain and Italy, new leases of \u20ac723 million, im-\npairment losses on the prope\ue61fy, plant and equipment of\nthe Argentine companies operating in a hyperin\ue61dation-\nary economy in the amount of \u20ac576 million and the e\ue61bect\nof capitalizing interest on loans speci\ue61ecally dedicated to\ncapital expenditure on prope\ue61fy, plant and equipment of\n\u20ac182 million (\u20ac154 million in 2020). The following table re-\npo\ue61fs capitalized \ue61enancial expense on prope\ue61fy, plant and\nequipment and intangible assets, including the po\ue61fion\nclassi\ue61eed as held for sale, and that on other non-current\nassets.\n\nMillions of euro\n2021 Rate % 2020 Rate % Change\nEnel Green Power - - - - -\nEnel Green Power Brazil - 12 2.4% (12) -\nEnel Green Power No\ue61fh America 17 0.2% 10 0.2% 7 70.0%\nEnel Green Power M\u00e9xico 10 4.3% 23 4.1% (13) -56.5%\nEnel Green Power South Africa 61 6.3% 47 6.3% 14 29.8%\nEnel Am\u00e9ricas Group 23 3.7% 7 5.8% 16 -\nEnel Chile Group 80 7.0 % 21 7. 2% 59 -\nEndesa Group\n(1)\n4 1.5% 3 1.7% 1 33.3%\nEnel Russia Group 18 8.5% 10 7. 2 % 8 80.0%\nEGP India Group 8 8.3% 1 7.5 % 7 -\nEGP Australia Group 1 0.2% 1 3.4% - -\nEnel Green Power Colombia - 2 1.3% (2) -\nEnel Produzione 2 2.1% 4 4.3% (2) -50.0%\nNuove Energie 1 0.5% 1 0.5% - -\nEnel Green Power Italia 5 3.3% 1 3.3% 4 -\nEnel Green Power Chile - 4 4.6% (4) -\nEnel Finance International 12 1.8% 15 1.8% (3) -20.0%\nTotal\n(2)\n242 162 80 49.4%\n(1) The amount for the EGP Spain Group is included in that for the Endesa Group.\n(2) The total for 2021 also includes -\u20ac5 million in capitalized \ue61enancial expense in respect of intangible assets (\u20ac7 million in 2020), \u20ac4 million in other non-current\nassets (\u20ac1 million in 2020) and \u20ac61 million pe\ue61faining to assets held for sale.\nAt December 31, 2021, contractual commitments to pur-\nchase prope\ue61fy, plant and equipment amounted to \u20ac1,437\nmillion.\n",
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"value": "\n20. Leases\nThe table below shows changes in right-of-use assets in\n2021. \n \nMillions of euro Leased land\nLeased\nbuildings Leased plant\nOther leased\nassets Total\nTotal at Dec. 31, 2020 707 551 479 438 2 ,175\nIncreases 442 86 1 203 732\nExchange di\ue61berences 37 1 (2) (1) 35\nDepreciation (38) (114) (34) (118) (304)\nOther changes (1) (7) (3) 2 (9)\nTotal at Dec. 31, 2021 1,147 517 441 524 2,629\nLease liabilities and changes during the year are shown in\nthe table below.\n\nMillions of euro\nTotal at Dec. 31, 2020 2,068\nIncreases 526\nPayments (165)\nOther changes 118\nTotal at Dec. 31, 2021 2,547\nof which medium to long term 2,288\nof which sho\ue61e term 259\nNote that in 2021, despite the e\ue61bects of the pandemic, no\nchanges or renegotiations were made to leases.\nMillions of euro\n2021\nDepreciation of right-of-use assets 304\nInterest expense on lease liabilities 72\nExpense relating to sho\ue61f-term leases (included in costs for services and other materials) 46\nExpense relating to leases of low-value assets (included in costs for services and other materials) -\nVariable lease payments (included in costs for services and other materials) 22\nTotal 444\n",
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"Tag15": {
"value": "\n19. Infrastructure within the scope of \u201cIFRIC 12 - Service concession arrangements\u201d \nService concession arrangements, which are recognized\nin accordance with IFRIC 12, regard ce\ue61fain infrastructure\nserving concessions for electricity distribution in Brazil,\nCosta Rica and Colombia.\nThe following table summarizes the salient details of those\nconcessions.\nMillions of euro\nGrantor Activity Country\nConcession\nperiod\nConcession\nperiod\nremaining\nRenewal\noption\nAmount\nrecognized\namong\ncontract assets\nat Dec. 31,\n2021\nAmount\nrecognized\namong\n\ue61fnancial assets\nat Dec. 31,\n2021\nAmount\nrecognized\namong\nintangible\nassets at Dec. \n31, 2021\nEnel Distribui\u00e7\u00e3o\nRio de Janeiro\nBrazilian\ngovernment\nElectricity\ndistribution\nBrazil 1997-2026 5 years Yes 112 838 404\nEnel Distribui\u00e7\u00e3o\nCear\u00e1\nBrazilian\ngovernment\nElectricity\ndistribution\nBrazil 1998-2028 7 years Yes 63 620 395\nEnel Green Power\nMour\u00e3o\nBrazilian\ngovernment\nElectricity\ngeneration\nBrazil 2016-2046 25 years No - 5 -\nEnel Green Power\nParanapanema\nBrazilian\ngovernment\nElectricity\ngeneration\nBrazil 2016-2046 25 years No - 23 -\nEnel Distribui\u00e7\u00e3o\nGoi\u00e1s\nBrazilian\ngovernment\nElectricity\ndistribution\nBrazil 2015-2045 24 years No 252 69 643\nEnel Green Power\nVolta Grande\nBrazilian\ngovernment\nElectricity\ngeneration\nBrazil 2017-2047 26 years No - 243 -\nEnel Distribui\u00e7\u00e3o\nS\u00e3o Paulo\nBrazilian\ngovernment\nElectricity\ndistribution\nBrazil 1998-2028 7 years No 91 1,001 609\nPH Chucas\nCosta Rican \nElectricity\nInstitute\nHydroelectric \nplant\nCosta \nRica\n2012-2031 10 years No - 101 47\nUSME ZE SAS\nEmpresa de\nTranspo\ue61fe del\nTercer Milenio\n- Transmilenio\nSA\ne-Mobility Colombia 2021-2035 16 years No - 6 -\nFontibon ZE SAS\nEmpresa de\nTranspo\ue61fe del\nTercer Milenio\n- Transmilenio\nSA\ne-Mobility Colombia 2021-2035 16 years No - 47 -\nTotal 518 2,953 2,098\nThe assets classi\ue61eed under \ue61enancial assets are measured\nat fair value at the end of the concessions. For more infor-\nmation, see note 50 \u201cAssets and liabilities measured at fair\nvalue\u201d.\n",
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"concept": "ifrs-full:DisclosureOfServiceConcessionArrangementsExplanatory",
"language": "en",
"entity": "scheme:WOCMU6HCI0OJWNPRZS33",
"period": "2021-01-01T00:00:00/2022-01-01T00:00:00"
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"Tag17": {
"value": "\n21. Investment prope\ue61ey \u2013 \u20ac91 million\nMillions of euro\n2021\nCost net of accumulated impairment losses 159\nAccumulated depreciation 56\nBalance at Dec. 31, 2020 103\nExchange di\ue61berences (1)\nDepreciation (3)\nImpairment losses (4)\nOther changes (4)\nTotal changes (12)\nCost net of accumulated impairment losses 129\nAccumulated depreciation 38\nBalance at Dec. 31, 2021 91\nInvestment prope\ue61fy at December 31, 2021 amounted to\n\u20ac91 million, a decrease of \u20ac12 million on the previous year.\nThe Group\u2019s investment prope\ue61fy consists of prope\ue61fies in\nItaly, Spain, Brazil and Chile, which are free of restrictions\non their sale or the remi\ue61cance of income and proceeds of\ndisposal. In addition, the Group has no contractual obliga-\ntions to purchase, construct or develop investment prop-\ne\ue61fy or for repairs, maintenance or enhancements.\nThe change in 2021 was mainly due to impairment losses\nrecognized on a number of assets in Italy and Spain.\nFor more information on the valuation of investment prop-\ne\ue61fy, see notes 50 \u201cAssets and liabilities measured at fair\nvalue\u201d, and 50.2 \u201cAssets not measured at fair value in the\nstatement of \ue61enancial position\u201d.\n",
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"period": "2021-01-01T00:00:00/2022-01-01T00:00:00"
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"Tag871": {
"value": "\n22. Intangible assets \u2013 \u20ac18,070 million\nA breakdown of and changes in intangible assets for 2021\nare shown below.\nMillions of euro\nDevelopment\nexpenditure\nIndustrial\npatents & \nintellectual \nprope\ue61by\nrights\nConcessions,\nlicenses,\ntrademarks \nand similar\nrights\nService\nconcession\narrangements Other\nLeasehold\nimprovements\nAssets under \ndevelopment\nand advances\nContract \ncosts Total\nCost net of accumulated\nimpairment losses\n44 2,985 12,988 5,452 4,821 10 1,337 1,581 29,218\nAccumulated amo\ue61fization 23 2,418 1,568 3,344 3,326 4 - 867 11,550\nBalance at Dec. 31, 2020 21 567 11,420 2,108 1,495 6 1,337 714 17,668\nCapital expenditure 4 91 92 - 117 - 874 478 1,656\nAssets entering service (1) 335 10 - 202 - (547) 1 -\nExchange di\ue61berences (1) (9) (238) 23 12 - (6) 1 (218)\nChange in the\nconsolidation scope\n- - 1 - 27 - 85 - 113\nDisposals - - (4) (8) 1 - (1) - (12)\nAmo\ue61fization (2) (289) (162) (305) (369) - - (248) (1,375)\nImpairment losses (1) (1) - (126) (10) - - - (138)\nReversals of impairment\nlosses\n- 1 - - - - - - 1\nOther changes 1 49 2 406 (7) (6) 18 1 464\nReclassi\ue61ecations from/to\nassets held for sale\n(1) (3) - - (84) - - (1) (89)\nTotal changes (1) 174 (299) (10) (111) (6) 423 232 402\nCost net of accumulated\nimpairment losses\n43 3,512 12,842 5,781 5,092 - 1,760 2,063 31,093\nAccumulated amo\ue61fization 23 2,771 1,721 3,683 3,708 - - 1,117 13,023\nBalance at Dec. 31, 2021 20 741 11,121 2,098 1,384 - 1,760 946 18,070\nEnel\u2019s intellectual prope\ue61fy (IP) po\ue61ffolio comprises a set of\ncritical information for sustainable growth. The Open In-\nnovability\u00ae ecosystem generates innovation through the\ncreation and sharing of internal and external solutions\nthat give life to ideas that require appropriate forms of le-\ngal protection. Intellectual prope\ue61fy plays a dual role: \ue61erst,\nit enables control over inventive solutions, technologies\nand knowledge generated by both the Group and the in-\nnovation ecosystems of which Enel is a pa\ue61f with the in-\nvolvement of universities, research bodies, suppliers, pro-\ngrammers and consultants; second, intellectual prope\ue61fy\nrights enable the safe and sustainable propagation of the\ntechnological solutions through which electri\ue61ecation, plat-\nformization and stewardship programs are implemented.\nAt December 31, 2021, the Group had applied for 892\npatents in 146 technological families. Of these, 749 have\nbeen granted and 143 are pending. The po\ue61ffolio ensures\nprotection in all the markets in which the Group is pres-\nent. Enel\u2019s po\ue61ffolio also includes 15 utility models and 170\ndesign registrations. Together with patents, utility models\nand designs, IP rights also include industrial secrets of both\na technical and commercial nature which are constantly\ncodi\ue61eed and maintained in line with the provisions of the\nTrade Secrets Management procedure (see below). The\nGroup also owns 1,576 trademarks, of which 1,455 have\nalready been registered, with 121 applications pending.\nThe Enel Green Power and Thermal Generation Global\nBusiness Line is involved in the development of innova-\ntive technical solutions in solar generation that seek (i) to\nincrease the photovoltaic output of plants by increasing\ncharge transfer mechanisms at the micro and nanometric\nlevel in correspondence with di\ue61berent layers both in single\nand heterojunction cells and in tandem systems and (ii) to\ncreate an innovative system for the rapid and automatable\ninstallation of photovoltaic panels on prefabricated sup-\npo\ue61f structures, generating signi\ue61ecant reductions in instal-\nlation times while increasing in the precision and scalability\nof installation and, therefore, the Group\u2019s competitiveness \nat the international level. These solutions cover a total of\n11 patent families currently comprising 28 national and\ninternational patent applications pending and 7 national\npatents granted.\nThe patent assets of Global Infrastructure and Networks\ncontribute signi\ue61ecantly to the strategy of creating plat-\n\nforms and exploiting network externalities in the services\nmarket, as well as to the automation of user management.\nThe Grid Blue Sky project, whose launch was announced\nlast year, is contributing to the creation of a new global op-\nerating platform for the Group\u2019s grids. In consideration of\nthe high intensity of IP generated, fu\ue61fher analysis of the\nproject was conducted, which is discussed in more detail\nlater in this section.\nIn the Enel X Global Business Line, the development of\nsolutions with an impact on IP assets essentially regarded\napplications in the telemedicine business and urban livea-\nbility platforms. The Sma\ue61f Axistance eWell app is an espe-\ncially impo\ue61fant example of the former, a health program\ndesigned and managed by specialists from the Policlinico\nGemelli Foundation and delivered through a telemedicine\nplatform and an app, both created by Enel X and protected\nby copyright. Urban liveability solutions include the 15 Min-\nutes City Index, an urban planning indicator developed in\ncollaboration with the University of Florence, for which Enel\nX is the holder of a trade secret and an Italian patent ap-\nplication. Using open data, the 15 Minutes City Index evalu-\nates essential services (public transpo\ue61f, hospitals, schools,\netc.), identifying underserved areas for each municipality\nand individual micro-district (with respect to population\ndensity), thereby suppo\ue61fing urban planning. As regards\nthe electric mobility business, the IP po\ue61ffolio comprises a\ndiversi\ue61eed range of forms of protection, including patents\nfor inventions, designs, trade secrets, utility models and\ncopyrights with a technological content. Notable exam-\nples of these include: (i) the patent family for bidirection-\nal high-power charging infrastructures, with applications\ninitially deposited in the United States and subsequently\ninitiated at the international level; (ii) the trade secrets con-\nnected with strategic mobility platforms; (iii) the copyright\non the Juice Pass app; (iv) the community design to protect\nthe aesthetic form of Juice Media, an innovative product\nthat enables the simultaneous o\ue61ber of electric charging\nand multimedia adve\ue61fising services in a single structure;\nand (v) the Juice Pole Mini designs, which are protected in\nEurope, India, Chile, Norway, the United States, Canada and\nthe United Kingdom.\nThe Group is also using copyright and trade-secret pro-\ntections for the innovative IP-dense solutions it is develop-\ning concerning climate models and advanced quantitative\nmodels for the analysis of energy systems in order to sup-\npo\ue61f decarbonization and electri\ue61ecation in the main geo-\ngraphical areas in which we operate, using an integrated\nand future-oriented vision.\nAt an organizational and communication level, during\n2021, Enel followed up on two lines of actions intended at\nachieving strategic, responsible and sustainable manage-\nment of its intellectual prope\ue61fy. On the one hand, a new\nIntellectual Prope\ue61fy Management procedure was adopted\nat the Group level. On the other, in the wake of the survey\nof the Group\u2019s IP po\ue61ffolio in 2020, an intellectual prope\ue61fy\nrepo\ue61fing project was continued, to be incorporated within\nthe broader scope of the Enel Group\u2019s non-\ue61enancial re-\npo\ue61fing.\nThe following table repo\ue61fs service concession arrange-\nments that do not fall within the scope of IFRIC 12 and had\na balance as at December 31, 2021.\nMillions of euro\nGrantor Activity Country\nConcession\nperiod\nConcession\nperiod\nremaining\nRenewal\noption\nat Dec. 31,\n2021\nInitial fair\nvalue\nEndesa Distribuci\u00f3n\nEl\u00e9ctrica\n-\nElectricity\ndistribution\nSpain Inde\ue61enite Inde\ue61enite - 5,678 5,673\nCodensa\nRepublic of\nColombia\nElectricity\ndistribution\nColombia Inde\ue61enite Inde\ue61enite - 1,176 1,839\nEnel Distribuci\u00f3n Chile\n(formerly Chilectra)\nRepublic of\nChile\nElectricity\ndistribution\nChile Inde\ue61enite Inde\ue61enite - 1,254 1,667\nEnel Distribuci\u00f3n Per\u00fa\n(formerly Empresa de\nDistribuci\u00f3n El\u00e9ctrica de\nLima No\ue61fe)\nRepublic of\nPeru\nElectricity\ndistribution\nPeru Inde\ue61enite Inde\ue61enite - 525 548\nE-Distribu\u0163ie Muntenia\nRomanian\nMinistry for the\nEconomy\nElectricity\ndistribution\nRomania 2005-2054 33 years Yes 119 191\nAssets with an inde\ue61enite useful life amounted to \u20ac8,633 \nmillion (\u20ac8,892 million at December 31, 2020), essentially\naccounted for by concessions for distribution activities\nin Spain (\u20ac5,678 million), Colombia (\u20ac1,176 million), Chile\n(\u20ac1,254 million) and Peru (\u20ac525 million), for which there\nwas no statutory or currently predictable expiration date.\n\nOn the basis of the forecasts developed, cash \ue61dows for\neach CGU, with which the various concessions are asso-\nciated, were su\ue61acient to recover the carrying amount.\nThe change during the year was essentially a\ue61cributable to\nchanges in exchange rates. For more information on ser-\nvice concession arrangements, see note 19.\nThe change in the consolidation scope for 2021 mainly\nre\ue61dected the acquisition by Enel Green Power Espa\u00f1a of\n100% of 30 renewables companies in Spain.\nImpairment losses amounted to \u20ac138 million in 2021 and\nmainly regarded impairment losses recognized on the PH\nChucas hydro plant. For more information, see note 11.e.\n\u201cOther changes\u201d repo\ue61fed the design costs connected with\nthe acquisition of a number of Brazilian vehicle companies.\n",
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"period": "2021-01-01T00:00:00/2022-01-01T00:00:00"
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"Tag872": {
"value": "\n23. Goodwill \u2013 \u20ac13,821 million\nMillions of euro at Dec. 31, 2020\nChange\nin consol.\nscope\nExchange\ndi\ue61cerences\nImpairment\nlosses\nO\ue61cse\ue61eing\ncost with\naccum.\nimpairment\nlosses\nOther\nchanges at Dec. 31, 2021\nCost\nCumulative\nimpairment\nNet\ncarrying\namount Cost\nCumulative\nimpairment\nNet\ncarrying\namount\nIberian\nPeninsula\n11,177 (2,392) 8,785 - - - - - 11,177 (2,392) 8,785\nChile 1,205 - 1,205 2 2 - - - 1,209 - 1,209\nArgentina 275 (253) 22 - - - - - 275 (253) 22\nPeru 564 - 564 - 2 - - - 566 - 566\nColombia 530 - 530 - (3) - - - 527 - 527\nBrazil 1,273 - 1,273 - 30 - - - 1,303 - 1,303\nCentral\nAmerica\n25 - 25 (1) 1 - - - 25 - 25\nMexico 18 (18) - - - - - - 18 (18) -\nEnel Green\nPower No\ue61fh\nAmerica\n70 - 70 - - - - - 70 - 70\nEnel X No\ue61fh\nAmerica\n184 - 184 - 15 - - - 199 - 199\nEnel X Asia\nPaci\ue61ec\n84 - 84 - - - - - 84 - 84\nEnel X Rest of\nEurope\n(1)\n46 (3) 43 - - - - - 46 (3) 43\nEnel X Italy - - - - - - - - - - -\nMarket Italy\n(2)\n580 - 580 - - - - - 580 - 580\nEnel Green\nPower Italy\n20 - 20 - - - - 1 21 - 21\nRomania 407 (13) 394 - (7) - - - 400 (13) 387\nTotal\n16,458 (2,679) 13,779 1 40 - - 1 16,500 (2,679) 13,821\n(1) Includes Tynemouth and Viva Labs.\n(2) Includes Enel Energia.\n\nGoodwill matrix at December 31, 2020\nMillions of euro\nThermal\nGeneration\nand Trading\nEnel Green\nPower\nInfrastructure\nand Networks\nEnd-user\nMarkets Enel X Services Other Total\nEnel Green Power Italy - 20 - - - - - 20\nMarket Italy\n(1)\n- - - 580 - - - 580\nIberia - 1,190 5,788 1,807 - - - 8,785\nArgentina - 3 19 - - - - 22\nBrazil - 397 876 - - - - 1,273\nChile - 992 213 - - - - 1,205\nColombia - 307 223 - - - - 530\nPeru 43 201 320 - - - - 564\nCentral America - 25 - - - - - 25\nRomania - - 336 58 - - - 394\nEnel Green Power\nNo\ue61fh America\n- 70 - - - - - 70\nEnel X No\ue61fh America - - - - 184 - - 184\nEnel X Asia Paci\ue61ec - - - - 84 - - 84\nEnel X Rest of Europe\n(2)\n- - - - 43 - - 43\nTotal 43 3,205 7,7 7 5 2,445 311 - - 13,779\n(1) Includes Enel Energia.\n(2) Includes Viva Labs.\nThe increase of \u20ac42 million in goodwill was mainly a\ue61crib-\nutable to \u201cExchange di\ue61berences\u201d of \u20ac40 million, with the\nmain changes regarding Brazil and the United States.\nThe criteria used to identify the cash generating units\n(CGUs) are based on revenue separation, which is con-\nsidered the main criterion in view of the nature of our\nbusiness, taking due account of the operational rules and\nregulations of the markets in which they operate and the\ncorporate organization. For the purposes of impairment\ntesting of goodwill, the CGUs are grouped on the basis of\nexpected synergies, consistent with management\u2019s strate-\ngic and operational vision, within the operating segments\nidenti\ue61eed for segment repo\ue61fing purposes.\nGoodwill matrix at December 31, 2021\nMillions of euro\nThermal\nGeneration\nand Trading\nEnel Green\nPower\nInfrastructure\nand Networks\nEnd-user\nMarkets Enel X Services Other Total\nEnel Green Power Italy - 21 - - - - - 21\nMarket Italy\n(1)\n- - - 580 - - - 580\nIberian Peninsula - 1,190 5,788 1,807 - - - 8,785\nArgentina - 3 19 - - - - 22\nBrazil - 423 880 - - - - 1,303\nChile - 996 213 - - - - 1,209\nColombia - 304 223 - - - - 527\nPeru 44 202 320 - - - - 566\nCentral America - 25 - - - - - 25\nRomania - - 330 57 - - - 387\nEnel Green Power\nNo\ue61fh America\n- 70 - - - - - 70\nEnel X No\ue61fh America - - - - 199 - - 199\nEnel X Asia Paci\ue61ec - - - - 84 - - 84\nEnel X Rest of Europe\n(2)\n- - - - 43 - - 43\nTotal 44 3,234 7,7 7 3 2,444 326 - - 13,821\n(1) Includes Enel Energia.\n(2) Includes Tynemouth and Viva Labs.\n\nNote also that in 2021, the existing CGUs underwent ex-\ntensive analysis to assess the possible presence of signi\ue61e-\ncant changes pursuant to IAS 36, paragraph 72.\nThis analysis led to a modi\ue61ecation of existing CGUs for\nSpain only, where in the Peninsular Territories the charac-\nteristics of the market as well as the planning and man-\nagement levels of ce\ue61fain plants enabled the full imple-\nmentation of the strategy of integrating generation and\ncommercial po\ue61ffolios, leveraging the entire value chain.\nThe situation di\ue61bers for assets in the Non-Peninsular Terri-\ntories, which are subject to speci\ue61ec regulation by vi\ue61fue of\nthe special features of their market.\nUnder local regulations, the remuneration of the power\ngeneration companies for their operations in these terri-\ntories must be based on rates governed using parameters\nestablished by the regulator.\nTherefore, given the di\ue61berence between local regulations\nand those applicable on the Iberian Peninsula, where plant\nassets are managed on a fully commercial basis, it is clear\nthat pursuant to IAS 36, paragraph 72, it was necessary to\nmodify the existing CGU for Spain in 2021. More speci\ue61ecal-\nly, two separate CGUs have been identi\ue61eed:\n\u2022 one comprises mainland Iberia (Iberian Peninsula);\n\u2022 the other comprises the Non-Peninsular Territories \n(Iberia NPT), for which the related cash \ue61dows are largely\nindependent of those generated in the peninsular area, \ngiven the regulation of the related market.\nTherefore, at December 31, 2021, the CGUs independently\nunderwent impairment testing and an impairment loss of\n\u20ac1,488 million was recognized for plants in the Non-Pen-\ninsular Territories.\nThe recoverable amount of the goodwill recognized was\nestimated by calculating the value in use of the CGUs us-\ning discounted cash \ue61dow models, which involve estimating\nexpected future cash \ue61dows and applying an appropriate\ndiscount rate, selected on the basis of market inputs such\nas risk-free rates, betas and market-risk premiums.\nCash \ue61dows were determined on the basis of the best in-\nformation available at the time of the estimate, taking ac-\ncount of the speci\ue61ec risks of each CGU, and drawn:\n\u2022 for the explicit period, from the Business Plan approved \nby the Board of Directors of the Parent on November 22,\n2021, containing forecasts for volumes, revenue, oper-\nating costs, capital expenditure, industrial and commer-\ncial organization and developments in the main mac-\nroeconomic variables (in\ue61dation, nominal interest rates\nand exchange rates) and commodity prices. The explicit\nperiod of cash \ue61dows considered in impairment testing\nwas three years;\n\u2022 for subsequent years, from assumptions concerning \nlong-term developments in the main variables that de-\ntermine cash \ue61dows, the average residual useful life of\nassets or the duration of the concessions.\nMore speci\ue61ecally, the terminal value is calculated based on\nthe speci\ue61ec characteristics of the businesses related to\nthe various CGUs subject to impairment testing:\n\u2022 perpetuity, for the businesses of large-hydro (LH) power \ngeneration and of distribution, in which the licenses and\npublic concessions are of a long-term nature and are\neasily renewable; as well as for the Enel X businesses,\nas they feature the development of speci\ue61ec know-how\nthat is sustainable over the long term;\n\u2022 annuity, for CGUs that are predominantly characterized \nby retail business, for which the residual life is, there-\nfore, essentially correlated with the average duration of\nthe customer relationships; as well as for businesses of\nconventional thermal power generation (Generation and\nTrading). This method is also used for the renewable en-\nergy (Enel Green Power) businesses to take account of:\n(i) the value resulting from the remaining useful lives of\nthe plants; and (ii) the residual value, in the event of plant\ndecommissioning, associated with licensing rights, the\ncompetitiveness of the production facilities (in terms of\nnatural resources), and network interconnectivity.\nThe nominal growth rate (g-rate) is equal to the long-term\nrate of growth in electricity and/or in\ue61dation (depending\non the country and business involved) and in any case no\nhigher than the average long-term growth rate of the ref-\nerence market.\nThe analysis of the impact of climate change on factors\nrelevant to the business is a complex activity that requires\nthe construction of a scenario framework and coherent\nanalysis of the various dimensions involved. More informa-\ntion is available in the section at the end of this note en-\ntitled \u201cAnalysis of energy transition scenarios and climate\nchange impacts used in the valuation models\u201d.\nThe Group con\ue61ermed its strategic direction based on the\ntrends associated with the energy transition. The use of\ncapital has been focused on decarbonization through the\ndevelopment of generation assets that use renewable\nsources, on the enabling infrastructures linked to the de-\nvelopment of networks and on the implementation of plat-\nform models, making the most of technological and digi-\ntal evolution, which will foster the electri\ue61ecation of energy\nconsumption, as well as the development of new services\nfor end users. Speci\ue61ecally, in 2021 Enel\u2019s decarbonization\nroadmap was updated to capture the acceleration in the\nspread of renewables and the reduction in thermal gen-\neration capacity envisaged in the new 2022-2024 Strate-\ngic Plan and in the 2030 ambitions presented at the 2021\nCapital Markets Day, se\ue61cing the following objectives in line\nwith the Paris Agreement:\n\nTime horizon Greenhouse gas (GHG) reduction target\nSho\ue61f term 2024 \u2022 Direct emissions of Scope 1 greenhouse gases to 140 gCO\n2eq\n/\nkWh (-36% compared with 2021)\nMedium term 2030 \u2022 Direct emissions of Scope 1 greenhouse gases to 82 gCO\n2eq\n/\nkWh (-80% compared with 2017, consistent with the 1.5 \u00b0C path\nas ce\ue61fi\ue61eed by the SBTi)\n\u2022 55% reduction in indirect Scope 3 emissions associated with gas \nconsumption by end users compared with 2017\nLong term 2040 \u2022 Full decarbonization of energy mix\nNote also that the Group took account of the impacts of\nclimate change in the long term. More speci\ue61ecally:\n\u2022 we consider a long-term growth rate in the estimation \nof the terminal value that is in line with the change in\nelectricity demand over the 2022-2050 period, based\non the speci\ue61ec features of the businesses concerned,\nadopting ce\ue61fain assumptions concerning the increase\nin temperature due to climate change and trends con-\nnected with the energy transition;\n\u2022 we assume that the Group will incur the costs provi-\nsioned for decommissioning of fossil fuel generation\nplants in line with the goal of zero direct (Scope 1) and\nindirect emissions from retail activities (Scope 3);\n\u2022 we pe\ue619orm a sensitivity analysis of the estimation of the \nlong-term growth rate, as detailed below.\nThe value in use calculated as described above was found\nto be greater than the amount recognized on the state-\nment of \ue61enancial position for all CGUs, with the exception\nindicated below.\nIn order to verify the robustness of the value in use of the\nCGUs, sensitivity analyses were conducted for the main \nvalue drivers, in pa\ue61ficular WACC, the long-term growth\nrate and margins, the outcomes of which fully suppo\ue61fed\nthat value.\nThe table below repo\ue61fs the composition of the main\ngoodwill values for the companies within each CGU, along\nwith the discount rates applied and the time horizon over\nwhich the expected cash \ue61dows have been discounted.\n\nMillions of euro\nAmount\nof\ngoodwill\nGrowth\nrate\n(1)\nPre-tax\nWACC\ndiscount\nrate\n(2)\nExplicit\nperiod\nof cash\n\ue61dows\nTerminal\nvalue\n(3)\nAmount\nof\ngoodwill\nGrowth\nrate\n(1)\nPre-tax\nWACC\ndiscount\nrate\n(2)\nExplicit\nperiod\nof cash\n\ue61dows\nTerminal\nvalue\n(3)\nat Dec. 31, 2021 at Dec. 31, 2020\nIberian Peninsula 8,785 1.64% 3.93% 3 years\nPerpetuity/25\nyears EGP/14\nyears G&T\n8,785 1.65% 4.06% 3 years\nPerpetuity/24\nyears EGP/11\nyears G&T\nChile 1,209 2.02% 6.58% 3 years\nPerpetuity/25\nyears EGP/6\nyears G&T\n1,205 1.97% 6.95% 3 years\nPerpetuity/25\nyears EGP/7\nyears G&T\nArgentina 22 24.11% 46.75% 3 years\nPerpetuity/8\nyears G&T\n275 11.79% 41.61% 3 years\nPerpetuity/1\nyear G&T/5\nyears LH\nPeru 566 2.31% 6.64% 3 years\nPerpetuity/23\nyears EGP/9\nyears G&T\n564 2.30% 6.73% 3 years\nPerpetuity/24\nyears EGP/10\nyears G&T\nColombia 527 3.11% 8.82% 3 years\nPerpetuity/28\nyears EGP/16\nyears G&T\n530 3.04% 8.54% 3 years\nPerpetuity/28\nyears EGP/17\nyears G&T\nBrazil 1,303 3.30% 9.09% 3 years\nPerpetuity/26\nyears EGP/7\nyears G&T\n1,273 3.25% 9.35% 3 years\nPerpetuity/26\nyears EGP/8\nyears G&T\nCentral America 25 2.03% 7.85% 3 years 19 years 25 1.97% 8.15% 3 years 22 years\nEnel Green Power\nNo\ue61fh America\n70 2.03% 5.01% 3 years 26 years 70 1.97% 5.49% 3 years 25 years\nEnel X No\ue61fh America 199 2.03% 7.6 2 % 3 years Perpetuity 184 1.97% 8.25% 3 years Perpetuity\nEnel X Asia Paci\ue61ec 84 2.03% 8.81% 3 years Perpetuity 84 2.02% 9.07% 3 years Perpetuity\nEnel X Rest of Europe 43 2.03% 8.24% 3 years Perpetuity 39 2.02% 8.70% 3 years Perpetuity\nEnel Green Power\nItaly\n21 1.52% 4.94% 3 years\nPerpetuity/23\nyears\n20 1.38% 5.44% 3 years\nPerpetuity/24\nyears\nMarket Italy 580 1.48% 9.14% 3 years 15 years 580 1.30% 9.98% 3 years 15 years\nRomania 387 2.06% 7.56% 3 years\nPerpetuity/25\nyears\n394 2.35% 7.98% 3 years\nPerpetuity/26\nyears\nCGUs with no\nrecognized goodwill \nbut that underwent \nimpairment testing\n given the presence\nof the indicators\nprovided for in IAS 36\nIberia NPT (Non-\nPeninsular Territories)\n(4)\n- - 3.42% 5 years 5 years n.a. n.a. n.a. n.a. n.a.\nAustralia\n(5)\n- 0.91% 5.50% 3 years 25 years - 1.35% 4.42% 3 years 26 years\nMexico\n(6)\n- 3.36% 8.77% 3 years 24 years 18 1.43% 8.83% 3 years 25 years\n(1) Perpetual growth rate for cash \ue61dows after the explicit forecast period.\n(2) Pre-tax WACC calculated using the iterative method: the discount rate that ensures that the value in use calculated with pre-tax cash \ue61dows is equal to that\ncalculated with post-tax cash \ue61dows discounted with the post-tax WACC.\n(3) The terminal value has been estimated on the basis of a perpetuity or an annuity with a rising yield for the years indicated in the column (G&T = Generation\n& Trading, EGP = Enel Green Power, LH = Large Hydro).\n(4) With Iberia NPT, it became necessary to pe\ue619orm the test following the deterioration in local market and regulatory conditions.\n(5) With regard to Australia, it became necessary to pe\ue619orm the test following the deterioration in macroeconomic conditions.\n(6) With regard to Mexico, it became necessary to pe\ue619orm the test following the deterioration in industrial and commercial pe\ue619ormance.\nAt December 31, 2021, in the impairment tests pe\ue619ormed\non the CGUs with no goodwill recognized, a post-tax im-\npairment loss of \u20ac1,116 million was found for the Iberia\nNPT CGU, one of \u20ac113 million for the Mexico CGU and one\nof \u20ac21 million for the Australia CGU.\n\nAnalysis of energy transition scenarios and\nclimate change impacts used in the valuation\nmodels\nAnalyzing the impact of climate change on factors relevant\nto our business is a complex endeavor that requires the\nconstruction of a scenario framework and consistent anal-\nyses along the various dimensions involved.\nIn pa\ue61ficular, the transition scenarios describe the possi-\nble industrial and technological con\ue61egurations in speci\ue61ec\ncontexts of social, economic and policy evolution, cor-\nresponding to di\ue61berent greenhouse gas (GHG) emission\ntrends, while the physical scenarios describe the possible\nfuture trends in variables.\nIn 2021, Enel revised the medium- and long-term energy\ntransition scenarios, within the overall framework ensuring\ntheir consistency with the climate scenario, and de\ue61ened\nthree alternative scenario narratives.\n\u2022 Paris scenario \u2013 calls for achieving the objectives of \nthe Paris Agreement, so it is a level of climate ambition\nthat is signi\ue61ecantly higher than business as usual. The\ngreater ambition is suppo\ue61fed by greater electri\ue61ecation\nof energy consumption and a growing development of\nrenewables. \n\u2022 Slow Transition scenario \u2013 characterized by a slower en-\nergy transition that does not achieve the objectives of\nthe Paris Agreement. This scenario involves a slower in-\ncrease in renewables and in the electri\ue61ecation process\nthat of the Paris scenario, pa\ue61ficularly over the sho\ue61f \nterm (i.e., delays in implementation of the energy tran-\nsition).\n\u2022 Best Place scenario: designed to test assumptions that \nimprove upon the Paris scenario. Here, too, the objec-\ntives of the Paris Agreement are achieved, but the sce-\nnario considers a wider range of technology options,\nsuch as a greater penetration of green hydrogen (i.e.,\nproduced using renewable energy) used more widely in\nhard-to-abate sectors, thereby facilitating the decar-\nbonization process towards net zero emissions.\n(25) At December 28, 2021.\nAt Enel, we have selected the Paris scenario, which calls for \nachieving the Paris Agreement objectives, as the bench-\nmark for long-term planning, unlike last year when the\nbenchmark was the stated-policies scenario. We did this\non the belief that the world\u2019s governments, businesses,\norganizations, and people will work together e\ue61bectively to\nmitigate greenhouse gas emissions. The increased com-\nmitment to net zero emissions in 2021 among nations that\ncurrently account for 88% of global emissions\n(25)\n and the\nsuccess of COP26 suppo\ue61f the decision to select a sce-\nnario that achieves the Paris objectives as Enel\u2019s long-term\nbenchmark. As for the possibility of assuming achievement\nof the more challenging Paris Agreement objective, i.e., to\nstabilize average global temperatures to within +1.5 \u00b0C, as\na benchmark for long-term planning, there remain evident\nunce\ue61fainties that a number of countries could remain on\nbusiness-as-usual trajectories, thereby slowing the decar-\nbonization process towards net zero emissions by 2050.\nGiven this external environment, the Enel Group imple-\nments a business model that is in line with the highest am-\nbition of the Paris Agreement and so is consistent with an\nincrease in average global temperatures of 1.5 \u00b0C by 2100.\nEnel has set a long-term objective of reaching zero direct\nemissions (Scope 1) with fully renewable power generation\nand zero emissions connected with the retail sale of ener-\ngy (Scope 3). \nThe assumptions for trends in commodities prices feed-\ning the Paris scenario are consistent with the external sce-\nnarios that achieve the objectives of the Paris Agreement.\nMore speci\ue61ecally, we assume sustained growth in the price\nof CO\n2\n through 2030, caused by a gradual reduction in the\nsupply of permits as demand increases, as well as stabili-\nzation in the price of coal due to declining demand. As for\ngas, we expect pricing pressures to lessen in the coming\nyears as we see a realignment between global supply and\ndemand. Finally, we are forecasting a gradual stabilization\nin oil prices, with demand expected to peak by around\n2030.\n\n(2)\n(2)\n2020\n~127\n~42\n2\nCO\n(1)\n24.7\n(2)\nIn the following tables, the values for \u201cEnel scenario\u201d rep-\nresent the assumptions in the Group\u2019s baseline scenario\n(26) Climate Action Tracker Thermometer, estimates of global heating at 2100 considering existing \u201cPolicies and action\u201d and \u201c2030 targets only\u201d (November 2021 \nupdate).\nused for various applications, including planning activities\nand determining impairment.\n(1) Sources: IEA, Sustainable Development Scenario and Net Zero Scenario; BNEF; IHS green case scenario, Enerdata green scenario. N.B. The scenarios used\nas benchmarks have been published at various points throughout the year and may not be up to date with the latest market trends.\n(2) Actuals.\nThe two alternative scenarios, i.e., Slow Transition and Best \nPlace, are used for strategic stress testing, risk assess-\nment, and the identi\ue61ecation of business oppo\ue61funities.\nThe Group has selected three of the global climate path-\nways developed by the Intergovernmental Panel on Climate\nChange (IPCC):\n\u2022 SSP1-RCP 2.6: compatible with a range of global warm-\ning below 2 \u00b0C from pre-industrial levels (1850-1900) by\n2100. In the analyses that consider both physical and\ntransition variables, the Group associates this scenario\nwith the Paris and Best Place scenarios.\n\u2022 SSP2-RCP 4.5: compatible with an intermediate sce-\nnario that calls for an average temperature increase of\nabout 2.7 \u00b0C by 2100 from pre-industrial levels. This sce-\nnario forecasts global warming in line with the estimates\nof temperature increases that consider current policy\naround the world\n(26)\n; in the analyses that consider both\nphysical and transition variables, the Group associates\nthe SSP2-RCP 4.5 scenario with the Slow Transition \nscenario.\n\u2022 SSP5-RCP 8.5: compatible with a scenario where no \npa\ue61ficular measures to combat climate change are im-\nplemented. This scenario forecasts an increase in global\ntemperatures of about +4.4 \u00b0C from pre-industrial lev-\nels by 2100.\nThe following describes the overall e\ue61bects of the transition\nscenarios and physical scenarios for electricity demand in\nthe main countries in which the Group operates.\nAverage\nbenchmark\nMax \nbenchmark\nMin \nbenchmark\nEnel scenario\n2030\n2030\n43.2\n50.3\n~68\n~72\n~62\n~67\n~70\n~73\n~45\n~65\n2020\n(2)\nBrent ($/barrel) API2 ($/ton)\n9.3\n~21\n~20\n~13\n2030\n~95\n~87\n~53\n2020\n2030\n2020\nEU - ETS (\u20ac/ton)\nTTF (\u20ac/MWh)\n\n-2.1%\n19%\n0.8%\nItaly and Spain\nIntegrated energy system models enable the quanti\ue61eca-\ntion of individual demands for service in a country. This\nlevel of detail therefore makes it possible to discriminate\nthe speci\ue61ec e\ue61bects that a change in temperature can have\non energy requirements.\nSimilarly to the previous year, the speed of the energy\ntransition has had a much greater impact on electricity\ndemand than the increase in temperature as a result of\nclimate change. Decarbonization policies, together with\ntechnological innovation, social responsibility, and con-\nsequent changes in consumer behavior, will play an active\nrole in trends in electricity demand and in the energy mix\ngenerally. However, analysis makes it clear that an increase\nin temperature as a result of climate change will lead to\nan increase in electricity demand, even if limited within a\n(27) Heating Degree Days (HDD); Cooling Degree Days (CDD).\nrange of one percentage point for both Italy and Spain.\nConsidering the integrated view, the potential e\ue61bect of\nmore ambitious transition scenarios has a more signi\ue61ecant\nimpact on electricity demand than the increase in temper-\nature resulting from climate change.\nAlthough the trends in degree days (both HDD and CDD)\nin the various climate scenarios are similar between the\ntwo countries, the percentage di\ue61berences in electricity\ndemand in Spain for the three scenarios are lower than in\nItaly. The essential di\ue61berence concerns the energy system\nby 2030, for which Spain\u2019s existing national energy plan is\nalready very ambitious and in line with RCP 2.6, meaning\nthat the Slow Transition scenario is closer to the Paris sce-\nnario. Therefore, we expect less volatility in energy system\ntrends and in electricity demand over the 2031-2050 pe-\nriod.\nItaly - Average impact on electricity demand (2031-2050) of the three transition scenarios paired\nwith RCP 2.6 and 4.5\nParis RCP 2.6 to Slow Transition RCP 4.5 Paris RCP 2.6 to Best Place RCP 2.6\nBaseline RCP\n2.6 Paris\nBaseline RCP\n2.6 Paris\n-1.3%\n19%\nTemperature\ne\ue61cect\nTemperature\ne\ue61cect\nTransition\ne\ue61cect\nTransition\ne\ue61cect\nBaseline RCP\n4.5 Slow\nTransition\nBaseline RCP\n2.6 Best \nPlace\nItaly\n\n-1.6%\n15%\n0.5%\nSpain - Average impact on electricity demand (2031-2050) of the three transition scenarios\npaired with RCP 2.6 and 4.5\nParis RCP 2.6 to Slow Transition RCP 4.5 Paris RCP 2.6 to Best Place RCP 2.6\nIn order to investigate the e\ue61bect of temperature on tran-\nsition scenarios fu\ue61fher and at the same time expand the\nrange of assumptions regarding climate change, a sensitivi-\nty analysis was carried out by associating the Slow Transition \nscenario with RCP 8.5, in addition to RCP 4.5. An assumption\nof a fu\ue61fher temperature increase, without changing the en-\nergy transition, results in a more limited change in demand\nequal to -0.8% for Italy and -0.6% for Spain. \nE\ue61cect of temperature and transition on electricity demand, average over speci\ue61fed period of temperature and transition\ncontributions for di\ue61cerent combinations of transition scenarios and climate pathways\nParis to Slow Transition RCP 4.5 Paris to Slow Transition RCP 8.5 Paris to Best Place\nTransition\ne\ue61cect\nTemperature\ne\ue61cect from\nRCP 2.6 to\nRCP 4.5\nTotal\nimpact\nTransition\ne\ue61cect\nTemperature\ne\ue61cect from\nRCP 2.6 to\nRCP 8.5\nTotal\nimpact\nTransition\ne\ue61cect\nTemperature\ne\ue61cect from\nRCP 2.6 to\nRCP 2.6\nTotal\nimpact\nItaly\n2022-2030\n2031-2050\n-1.3%\n-2.1%\n0.0%\n0.8%\n-1.3%\n-1.3%\n-1.3%\n-2.1%\n0%\n1.3%\n-1.3%\n-0.8%\n2.7%\n19.0%\n0.0%\n0.0%\n2.7%\n19.0%\nSpain\n2022-2030\n2031-2050\n-0.9%\n-1.6%\n0.0%\n0.5%\n-0.9%\n-1.1%\n-0.9%\n-1.6%\n0.0%\n0.9%\n-0.9%\n-0.6%\n3.1%\n15.2%\n0.0%\n0.0%\n3.1%\n15.2%\nAs a \ue61enal consideration, however, note that, in the future,\ngreater than forecast electri\ue61ecation of residential heating\ncould change both the sign and the size of the tempera-\nture e\ue61bect in both countries. It is therefore necessary to\nmonitor developments in the share of electri\ue61ecation of\nheating during the annual review.\nBaseline RCP\n2.6 Paris\nBaseline RCP\n2.6 Paris\n-1.1%\n15%\nTemperature\ne\ue61cect\nTemperature\ne\ue61cect\nTransition\ne\ue61cect\nTransition\ne\ue61cect\nBaseline RCP\n4.5 Slow \nTransition\nBaseline RCP\n2.6 Best \nPlace\nSpain\n\nLatin America\nIn Latin American countries, the impact of temperature\ntrends, quanti\ue61eed through the heating degree days (HDD)\nand cooling degree days (CDD) metrics, was estimated us-\ning econometric forecasting models based on historical\nelasticity.\nThe analysis shows that Brazil could experience a signi\ue61e-\ncant increase in demand due to the increase in tempera-\nture, with an estimated increase of between 0.8% and 1.5%\nin prospective demand (calculated as the average of the\ndemand forecasts in the 2030-2050 period). The driving\nfactor would be the greater demand for cooling expect-\ned in the country. This change is also con\ue61ermed using a\nsystem modeling approach. However, these forecasts are\nsubject to a signi\ue61ecant degree of unce\ue61fainty given the vol-\natility of Brazilian economic growth.\nArgentina could also experience an increase in demand\nlinked to an increase in temperature, estimated at between\n0.3% and 0.6% of prospective demand. Similarly to Brazil,\nthis forecast depends largely on the impact of macroeco-\nnomic developments in this country on electricity demand.\nThe same considerations can also be extended to the oth-\ner countries in which the Group is present. In pa\ue61ficular,\nin the rest of Latin America, where we again observe the\npositive elasticity of electricity demand to temperatures,\nthe expected rise in temperature would still have less im-\npact than economic growth. In fact, in Chile and Colombia,\nhistorical evidence still shows a strong coupling between\nthe growth of electricity demand and GDP growth, with\ndemand from the industrial sector accounting for around\n50% of electricity consumption. Fu\ue61fhermore, the variabil-\nity of the macroeconomic context could have repercus-\nsions on the electri\ue61ecation of the residential and service\nsectors, which represent the most immediate drivers of\nthe increase in electricity demand in the event of an in-\ncrease in temperatures.\nThe following table summarizes the main temperature ef-\nfects in the Latin American countries, with ranges obtained\nby applying a 95% con\ue61edence interval to our baseline case:\n.\nUpper\nbound\nCountry\nTemperature e\ue61cect (annual average)\nfrom RCP 2.6 to RCP 4.5 from RCP 2.6 to RCP 8.5\nTWh % TWh %\nArgentina 0.68 0.3 1.37 0.6\nBrazil 7.9 2 0.8 15.83 1.5\nChile 0.05 0.0 0.10 0.1\nColombia 0.08 0.1 0.17 0.1\nLower\nbound\nCountry\nTemperature e\ue61cect (annual average)\nfrom RCP 2.6 to RCP 4.5 from RCP 2.6 to RCP 8.5\nTWh % TWh %\nArgentina 0.57 0.3 1.15 0.5\nBrazil 2.48 0 4.96 0\nChile 0.01 0.0 0.01 0.0\nColombia 0.02 0.0 0.05 0.0\nE\ue61bect of the variation in temperature on electricity demand in the main Latin American countries in which the Group operates (average 2030-2050).\n",
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"value": "\n24. Deferred tax assets and liabilities \u2013 \u20ac11,034 million and \u20ac9,259 million\nThe following tables detail changes in deferred tax assets\nand liabilities by type of timing di\ue61berence and calculated\nbased on the tax rates established by applicable regula-\ntions, as well as the amount of deferred tax assets o\ue61bset-\ntable, where permi\ue61ced, with deferred tax liabilities.\nMillions of euro\nIncrease/\n(Decrease)\ntaken to \npro\ue61ft or loss \nIncrease/\n(Decrease)\ntaken to \nequity\nChange in the\nconsolidation\nscope\nExchange\ndi\ue61cerences\nOther\nchanges\nReclassi\ue61fcations \nof assets held \nfor sale\nat Dec. 31,\n2020\nat Dec. 31,\n2021\nDeferred tax assets:\n- di\ue61berences in the\ncarrying amount\nof prope\ue61fy, plant\nand equipment and\nintangible assets\n2,123 342 - - (7) 11 - 2,469\n- accruals to provisions\nfor risks and charges\nand impairment\nlosses with deferred\ndeductibility\n1,725 340 1 - (4) (27) - 2,035\n- tax loss carried\nforward\n508 249 - - 10 18 - 785\n- measurement of\n\ue61enancial instruments\n561 53 1,622 - 5 7 - 2,248\n- employee bene\ue61ets 898 (16) (9) - 2 (4) - 871\n- other items 2,763 (133) (6) - 13 (8) (3) 2,626\nTotal 8,578 835 1,608 - 19 (3) (3) 11,034\nDeferred tax liabilities:\n- di\ue61berences on non-\ncurrent and \ue61enancial\nassets\n5,442 141 3 - (83) 54 (19) 5,538\n- measurement of\n\ue61enancial instruments\n470 (107) 1,150 - 7 7 - 1,527\n- other items 1,885 275 10 10 19 4 (9) 2,194\nTotal 7,797 309 1,163 10 (57) 65 (28) 9,259\nNon-o\ue61cse\ue61eable\ndeferred tax assets\n6,346\nNon-o\ue61cse\ue61eable\ndeferred tax liabilities\n4,230\nExcess net deferred\ntax liabilities after any\no\ue61cse\ue61eing\n341\n\u201cDeferred tax assets\u201d recognized at December 31, 2021,\nas the recovery of such assets is considered reasonably\nce\ue61fain, totaled \u20ac11,034 million (\u20ac8,578 million at Decem-\nber 31, 2020).\nDeferred tax assets increased by \u20ac2,456 million during \nthe year, essentially due to the recognition of greater de-\nferred tax assets associated with the following factors:\n\u2022 impairment losses, mainly in Italy and Spain;\n\u2022 developments in the fair value of cash \ue61dow hedge de-\nrivatives;\n\u2022 provisions for retirement, renovation and digitalization, \nmainly in Italy.\nNoted that deferred tax assets (in the amount of \u20ac187\nmillion) were not recorded on prior and current-year tax\nlosses in the amount of \u20ac754 million because, on the ba-\nsis of current estimates of future taxable income, it is not\nhighly likely that such assets will be recovered.\n\u201cDeferred tax liabilities\u201d amounted to \u20ac9,259 million\nat December 31, 2021 (\u20ac7,797 million at December 31,\n2020). They essentially include the determination of the\ntax e\ue61bects of the adjustments to assets acquired as pa\ue61f \nof the \ue61enal allocation of the cost of acquisitions made\nin the various years and the deferred taxation in respect\nof the di\ue61berences between depreciation charged for tax\npurposes, including accelerated depreciation, and de-\npreciation based on the estimated useful lives of assets.\nDeferred tax liabilities increased by a total of \u20ac1,462 mil-\n\nlion due, in pa\ue61ficular, to:\n\u2022 developments in the fair value of cash \ue61dow hedge de-\nrivatives;\n\u2022 tax reforms in Argentina and Colombia.\nThese e\ue61bects were pa\ue61fially o\ue61bset by the reversals of de-\nferred taxes following the depreciation, amo\ue61fization and\nimpairment of the amounts allocated in the past to prop-\ne\ue61fy, plant and equipment and intangible assets at the\ntime of the acquisition of control as a result of purchase\nprice allocation.\n",
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"value": "\n25. Equity-accounted investments \u2013 \u20ac704 million\nThe following table shows changes in the main invest-\nments in joint ventures and associates accounted for using\nthe equity method.\nMillions of euro % held\nImpact on\npro\ue61ft or\nloss\nChange in\nconsolidation\nscope Dividends\nReclassi\ue61fcations\nfrom/to assets\nheld for sale\nOther\nchanges % held\nat Dec. 31, 2020 at Dec. 31, 2021\nJoint ventures\nSlovak Power Holding 104 50.0% 523 - - - (627) - 50.0%\nEGPNA Renewable Energy\nPa\ue61fners\n115 20.0% 8 - - - (2) 121 20.0%\nZacapa Topco S\u00e0rl 115 20.6% (1) - - (2) 2 114 20.6%\nProject Kino companies 40 20.0% (19) - - - - 21 20.0%\nTejo Energia Produ\u00e7\u00e3o e\nDistribui\u00e7\u00e3o de Energia\nEl\u00e9ctrica\n46 43.8% (17) - (16) - (1) 12 43.8%\nRocky Caney Holding 45 20.0% 5 - - - - 50 20.0%\nDrift Sand Wind Project 35 50.0% 3 - - - 2 40 50.0%\nFront Mar\u00edtim del Bes\u00f2s 33 61.4% - - - - - 33 61.4%\nEnel Green Power Bungala 31 51.0% - (31) - - - - 100.0%\nRusenergosbyt 46 49.5% 44 - (42) - 3 51 49.5%\nEnergie Electrique de\nTahadda\ue61f\n22 32.0% 1 - (2) - (3) 18 32.0%\nTransmisora El\u00e9ctrica de\nQuillota\n9 50.0% - - (6) - (3) - -\nPowerCrop 2 50.0% 4 - (2) (1) (3) - 50.0%\nAssociates\nCESI 60 42.7% - - - - (1) 59 42.7%\nTecnatom 28 45.0% (2) - - - 1 27 45.0%\nSuministradora El\u00e9ctrica\nde C\u00e1diz\n12 33.5% 3 - (5) - - 10 33.5%\nCompa\u00f1\u00eda E\u00f3lica Tierras\nAltas\n8 37.5 % 1 - (1) - - 8 37.5 %\nCogenio Srl 12 20.0% 2 - (1) - (1) 12 20.0%\nOther 98 16 4 (16) (1) 27 128\nTotal 861 571 (27) (91) (4) (606) 704\nThe investment in Slovak Power Holding is accounted for \nusing the equity method. Under the provisions of specif-\nic agreements, its carrying amount can be adjusted to a\nlower amount resulting from the application of a price\nformula that governs the possible sale of the investment\nitself and which is subject to multiple conditions to be\nassessed based on di\ue61berent scenarios\u2019 probability of oc-\ncurrence. At December 31, 2020, the fair value calculat-\ned using that price formula (\u20ac104 million) was lower than\nthe amount obtained using the equity method. In 2021,\ndue to the recognition of a signi\ue61ecant reduction in the\nOCI reserves relating to hedging derivatives (\u20ac687 million)\nand the recognition through pro\ue61et or loss of the pro\ue61et or\nloss (\u20ac555 million) for the period and previous years not\npreviously recognized (due to the adjustments to the low-\ner fair value), the carrying amount of the investment was \nreduced to zero. In addition, a provision for impairment\nlosses on investments of \u20ac28 million was established.\nApa\ue61f from these developments, the change in equity-ac-\ncounted investments is mainly a\ue61cributable to:\n\u2022 dividends distributed in the period in the amount of \n\u20ac91 million, mainly by Rusenergosbyt and Tejo Energia\nProdu\u00e7\u00e3o e Distribui\u00e7\u00e3o de Energia El\u00e9ctrica;\n\n\u2022 the e\ue61bects of changes in the consolidation scope, \nmainly relating to the consolidation of companies be-\nlonging to the Enel Green Power Bungala Group, previ-\nously measured using the equity method (\u20ac31 million).\nThese negative e\ue61bects were o\ue61bset by the \u201cImpact on\npro\ue61et or loss\u201d item, which includes the pro\ue61et or loss rec-\nognized by the companies in propo\ue61fion to the share \nheld in these companies by the Enel Group. It is mainly\naccounted for by the pro\ue61et contributed by Rusenergos-\nbyt (\u20ac44 million). The following tables provide a summary\nof \ue61enancial information for the main joint ventures and \nassociates of the Group not classi\ue61eed as held for sale in\naccordance with IFRS 5.\nMillions of euro Non-current assets Current assets Total assets Non-current liabilities Current liabilities Total liabilities Equity\nat Dec. 31, 2021 at Dec. 31, 2020 at Dec. 31, 2021 at Dec. 31, 2020 at Dec. 31, 2021 at Dec. 31, 2020 at Dec. 31, 2021 at Dec. 31, 2020 at Dec. 31, 2021 at Dec. 31, 2020 at Dec. 31, 2021 at Dec. 31, 2020 at Dec. 31, 2021 at Dec. 31, 2020\nJoint ventures\nSlovak Power Holding 12,194 10,813 1,854 676 14,048 11,489 6,762 6,922 5,369 802 12,131 7,724 1,917 3,765\nZacapa Topco S\u00e0rl 1,393 1,253 176 117 1,569 1,370 871 729 143 90 1,014 819 555 551\nRusenergosbyt 3 2 141 120 144 122 - - 120 106 120 106 24 16\nTejo Energia Produ\u00e7\u00e3o e\nDistribui\u00e7\u00e3o de Energia\nEl\u00e9ctrica\n34 82 107 128 141 210 25 21 14 33 39 54 102 156\nEnergie Electrique de\nTahadda\ue61f\n49 62 22 18 71 80 4 5 10 6 14 11 57 69\nAssociates\nCESI 198 202 28 25 226 227 25 17 - - 25 17 201 210\nTecnatom 61 60 58 58 119 118 24 23 26 33 50 56 69 62\nSuministradora El\u00e9ctrica\nde C\u00e1diz\n64 67 36 32 100 99 23 18 48 45 71 63 29 36\nCompa\u00f1\u00eda E\u00f3lica Tierras\nAltas\n19 21 6 3 25 24 2 2 3 2 5 4 20 20\nMillions of euro Total revenue Pre-tax pro\ue61ft/(loss)\nPro\ue61ft/(Loss) from continuing\noperations\n2021 2020 2021 2020 2021 2020\nJoint ventures\nSlovak Power Holding 3,417 2,954 190 163 137 120\nZacapa Topco S\u00e0rl 267 221 15 7 (4) (3)\nRusenergosbyt 2,288 2,198 112 112 90 90\nTejo Energia Produ\u00e7\u00e3o e Distribui\u00e7\u00e3o de\nEnergia El\u00e9ctrica\n126 114 (7) 17 (16) 8\nEnergie Electrique de Tahadda\ue61f 36 33 7 5 4 3\nAssociates\nCESI 140 122 (7) (14) (8) (16)\nTecnatom 97 78 7 (5) 7 (5)\nSuministradora El\u00e9ctrica de C\u00e1diz 14 25 10 21 8 14\nCompa\u00f1\u00eda E\u00f3lica Tierras Altas 13 8 4 - 3 -\n\nMillions of euro Non-current assets Current assets Total assets Non-current liabilities Current liabilities Total liabilities Equity\nat Dec. 31, 2021 at Dec. 31, 2020 at Dec. 31, 2021 at Dec. 31, 2020 at Dec. 31, 2021 at Dec. 31, 2020 at Dec. 31, 2021 at Dec. 31, 2020 at Dec. 31, 2021 at Dec. 31, 2020 at Dec. 31, 2021 at Dec. 31, 2020 at Dec. 31, 2021 at Dec. 31, 2020\nJoint ventures\nSlovak Power Holding 12,194 10,813 1,854 676 14,048 11,489 6,762 6,922 5,369 802 12,131 7,724 1,917 3,765\nZacapa Topco S\u00e0rl 1,393 1,253 176 117 1,569 1,370 871 729 143 90 1,014 819 555 551\nRusenergosbyt 3 2 141 120 144 122 - - 120 106 120 106 24 16\nTejo Energia Produ\u00e7\u00e3o e\nDistribui\u00e7\u00e3o de Energia\nEl\u00e9ctrica\n34 82 107 128 141 210 25 21 14 33 39 54 102 156\nEnergie Electrique de\nTahadda\ue61f\n49 62 22 18 71 80 4 5 10 6 14 11 57 69\nAssociates\nCESI 198 202 28 25 226 227 25 17 - - 25 17 201 210\nTecnatom 61 60 58 58 119 118 24 23 26 33 50 56 69 62\nSuministradora El\u00e9ctrica\nde C\u00e1diz\n64 67 36 32 100 99 23 18 48 45 71 63 29 36\nCompa\u00f1\u00eda E\u00f3lica Tierras\nAltas\n19 21 6 3 25 24 2 2 3 2 5 4 20 20\n",
"dimensions": {
"concept": "ifrs-full:DisclosureOfInvestmentsAccountedForUsingEquityMethodExplanatory",
"language": "en",
"entity": "scheme:WOCMU6HCI0OJWNPRZS33",
"period": "2021-01-01T00:00:00/2022-01-01T00:00:00"
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"Tag18": {
"value": "\n26. Derivatives\nMillions of euro Non-current Current\nat Dec. 31, 2021 at Dec. 31, 2020 at Dec. 31, 2021 at Dec. 31, 2020\nDerivative \ue61enancial assets 2,772 1,236 22,791 3,471\nDerivative \ue61enancial liabilities 3,339 3,606 24,607 3,531\nFor more information on derivatives classi\ue61eed as non-cur-\nrent \ue61enancial assets, please see note 49 for hedging deriv-\natives and trading derivatives.\n",
"dimensions": {
"concept": "ifrs-full:DisclosureOfDerivativeFinancialInstrumentsExplanatory",
"language": "en",
"entity": "scheme:WOCMU6HCI0OJWNPRZS33",
"period": "2021-01-01T00:00:00/2022-01-01T00:00:00"
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"Tag19": {
"value": "\n27. Current/Non-current contract assets/(liabilities)\nMillions of euro Non-current Current\nat Dec. 31, 2021 at Dec. 31, 2020 at Dec. 31, 2021 at Dec. 31, 2020\nContract assets 530 304 121 176\nContract liabilities 6,214 6,191 1,433 1,275\nNon-current assets deriving from contracts with custom-\ners (contract assets) refer mainly to assets under develop-\nment resulting from public-to-private service concession\narrangements recognized in accordance with IFRIC 12 and\nwhich have an expiration of beyond 12 months (\u20ac517 mil-\nlion). These cases arise when the concession holder has\nnot yet obtained full right to recognize the asset from the\ngrantor, in that there remains a contractual obligation to\nensure that the asset is completed and can be remunerat-\ned through rates. The \ue61egure at December 31, 2021 includes\ninvestments for the year in the amount of \u20ac907 million.\nCurrent contract assets mainly concern construction con-\ntracts in progress (\u20ac98 million) to be invoiced, payments\non which are subject to the ful\ue61ellment of a pe\ue619ormance\nobligation.\nThe carrying amount at December 31, 2021 of non-cur-\nrent contract liabilities is mainly a\ue61cributable to distribution\noperations in Italy (\u20ac3,252 million), Spain (\u20ac2,521 million)\nand Romania (\u20ac438 million) as a result of the accounting\ntreatment of revenue from connections of new customers,\nwhich are deferred over the average duration of the asso-\nciated contracts.\nCurrent contract liabilities include the contractual liabilities\nrelated to revenue from connections to the electricity grid\nexpiring within 12 months in the amount of \u20ac1,016 million,\nmainly recognized in Italy and Spain, as well as liabilities for\nconstruction contracts in progress (\u20ac392 million).\nAs required under IFRS 15, the following table repo\ue61fs the\nreversal to pro\ue61et or loss of contract liabilities by time band.\nMillions of euro\nat Dec. 31, 2021 at Dec. 31, 2020\nWithin 1 year 1,433 1, 275\nWithin 2 years 498 481\nWithin 3 years 480 461\nWithin 4 years 479 460\nWithin 5 years 477 459\nMore than 5 years 4,280 4,330\nTotal 7,6 47 7,466\n",
"dimensions": {
"concept": "enel:DisclosureOfContractAssetsLiabilitiesExplanatory",
"language": "en",
"entity": "scheme:WOCMU6HCI0OJWNPRZS33",
"period": "2021-01-01T00:00:00/2022-01-01T00:00:00"
}
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"Tag20": {
"value": "\n28. Other non-current \ue61fnancial assets \u2013 \u20ac5,704 million\nMillions of euro\nat Dec. 31, 2021 at Dec. 31, 2020 Change\nEquity investments in other companies measured at fair value 72 70 2 2.9%\nFinancial assets and securities included in net \ue61enancial debt (see note 28.1) 2,692 2 ,745 (53) -1.9%\nService concession arrangements 2,890 2,300 590 25.7%\nNon-current \ue61enancial prepayments 50 44 6 13.6%\nTotal 5,704 5,159 545 10.6%\n\u201cOther non-current \ue61enancial assets\u201d increased by \u20ac545\nmillion, mainly re\ue61decting the increase in \ue61enancial assets in\nrespect of service concession arrangements in Brazil and\nCosta Rica. This factor was pa\ue61fially o\ue61bset by a decline in\n\ue61enancial assets included in net \ue61enancial debt, as detailed\nin note 28.1.\nThe following is a breakdown of equity investments in oth-\ner companies measured at fair value.\nMillions of euro\nat Dec. 31,\n2021 % held\nat Dec. 31,\n2020 % held Change\nEmpresa Propietaria de la Red SA 5 11.1% 5 11.1% -\nEuropean Energy Exchange 13 2.4% 13 2.4% -\nAthonet Srl 7 16.0% 7 16.0% -\nKorea Line Corporation 1 0.3% 1 0.3% -\nHubject GmbH 10 12.5% 10 12.5% -\nTermoel\u00e9ctrica Jos\u00e9 de San Ma\ue61f\u00edn SA 11 4.2% 10 3.3% 1\nTermoel\u00e9ctrica Manuel Belgrano SA 12 4.7% 11 3.7% 1\nOther 13 13 -\nTotal 72 70 2\n28.1 Other non-current \ue61fnancial assets included in net \ue61fnancial debt \u2013 \u20ac2,692 million\nMillions of euro\nat Dec. 31, 2021 at Dec. 31, 2020 Change\nSecurities 403 408 (5) -1.2%\nOther \ue61enancial assets 2,289 2,337 (48) -2.1%\nTotal 2,692 2,745 (53) -1.9%\n\u201cSecurities\u201d are primarily represented by \ue61enancial instru-\nments measured at fair value through other comprehen-\nsive income in which the Dutch insurance companies in-\nvest a po\ue61fion of their liquidity.\nThe reduction in \u201cOther \ue61enancial assets\u201d is mainly a\ue61crib-\nutable to:\n\u2022 a decline of \u20ac271 million in the \ue61enancial assets of Enel \nSpA, essentially associated with the disposal of the in-\nvestment in Open Fiber;\n\u2022 the reclassi\ue61ecation of \u20ac90 million of the current po\ue61fion \nof the \ue61enancial assets of e-distribuzione in respect of\nthe Energy and Environmental Services Fund (\u20ac55 mil-\nlion) and the amount receivable in respect of the reim-\nbursement of the extraordinary costs incurred by dis-\ntributors for the early replacement of electromechani-\ncal meters with electronic devices (\u20ac35 million).\nThese factors were pa\ue61fially o\ue61bset by:\n\u2022 an increase of \u20ac198 million the \ue61enancial assets of Enel \nFinance International, mainly regarding the Slovak Pow-\ner Holding BV loan;\n\u2022 an increase of \u20ac42 million in \ue61enancial assets for depos-\nits;\n\u2022 an impairment loss of \u20ac25 million on the amount due \nto Enel Produzione from EP Slovakia BV associated with\nthe sale of 50% of the investment in Slovak Power Hold-\ning.\n\n29. Other current \ue61fnancial assets \u2013 \u20ac8,645 million\nMillions of euro\nat Dec. 31, 2021 at Dec. 31, 2020 Change\nCurrent \ue61enancial assets included in net \ue61enancial debt (see note 29.1) 8,467 4,971 3,496 70.3%\nOther 178 142 36 25.4%\nTotal 8,645 5,113 3,532 69.1%\n\u201cOther current \ue61enancial assets\u201d increased by \u20ac3,532 mil-\nlion, mainly re\ue61decting the increase in current \ue61enancial as-\nsets included in net \ue61enancial debt, as detailed in note 29.1,\nas well as the increase in the current po\ue61fion of \ue61enancial\nassets in respect of service concession arrangements.\n29.1 Other current \ue61fnancial assets included \nin net \ue61fnancial debt \u2013 \u20ac8,467 million\nMillions of euro\nat Dec. 31, 2021 at Dec. 31, 2020 Change\nCurrent po\ue61fion of long-term \ue61enancial assets 1,538 1,428 110 7.7 %\nSecurities at FVTPL 1 - 1 -\nSecurities at FVOCI 87 67 20 29.9%\nFinancial assets and cash collateral 6,485 3,223 3,262 -\nOther 356 253 103 40.7%\nTotal 8,467 4,971 3,496 70.3%\nThe increase in the item is mainly a\ue61cributable to:\n\u2022 \u20ac3,262 million in respect of an increase in cash collat-\neral paid to counterpa\ue61fies for derivatives transactions;\n\u2022 \u20ac110 million in respect of the increase in the current \npo\ue61fion of long-term \ue61enancial assets, which essentially\nre\ue61dects:\n \u2013 the increase in \ue61enancial assets relating to the de\ue61ecit \nof the Spanish electricity system (\u20ac47 million);\n \u2013 an increase in \ue61enancial assets for security deposits \n(\u20ac61 million).\n",
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"concept": "ifrs-full:DisclosureOfFinancialAssetsExplanatory",
"language": "en",
"entity": "scheme:WOCMU6HCI0OJWNPRZS33",
"period": "2021-01-01T00:00:00/2022-01-01T00:00:00"
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"Tag21": {
"value": "\n30. Other non-current assets \u2013 \u20ac3,268 million\nMillions of euro\nat Dec. 31, 2021 at Dec. 31, 2020 Change\nAmounts due from institutional market operators 242 186 56 30.1%\nOther assets 3,026 2,308 718 31.1%\nTotal 3,268 2,494 774 31.0%\n\u201cAmounts due from institutional market operators\u201c in-\ncreased by \u20ac56 million, mainly in Spain as a result of the\nremuneration of distribution operations.\n\u201cOther assets\u201c at December 31, 2021 included tax assets in \nthe amount of \u20ac2,286 million (\u20ac1,539 million at December\n31, 2020), security deposits in the amount of \u20ac340 million\n(\u20ac330 million at the end of 2020) and non-monetary grants\nto be received in respect of green ce\ue61fi\ue61ecates amounting\nto \u20ac56 million (\u20ac73 million at December 31, 2020).\nThe change for the year mainly re\ue61dected the tax assets\nrecognized by distribution companies connected with the\nPIS/COFINS dispute in Brazil in the amount of \u20ac596 million.\n",
"dimensions": {
"concept": "ifrs-full:DisclosureOfOtherNoncurrentAssetsExplanatory",
"language": "en",
"entity": "scheme:WOCMU6HCI0OJWNPRZS33",
"period": "2021-01-01T00:00:00/2022-01-01T00:00:00"
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"Tag22": {
"value": "\n31. Other current assets \u2013 \u20ac5,002 million\nMillions of euro\nat Dec. 31, 2021 at Dec. 31, 2020 Change\nAmounts due from institutional market operators 2,205 1,265 940 74.3%\nAdvances to suppliers 326 309 17 5.5%\nAmounts due from employees 29 30 (1) -3.3%\nAmounts due from others 1,071 956 115 12.0%\nSundry tax assets 1,164 848 316 37.3%\nCurrent accrued income and prepayments 207 170 37 21.8%\nTotal 5,002 3,578 1,424 39.8%\n\u201cAmounts due from institutional market operators\u201c include \namounts due in respect of the Italian system in the amount\nof \u20ac1,519 million (\u20ac890 million at December 31, 2020) and\nthe Spanish system in the amount of \u20ac667 million (\u20ac337\nmillion at December 31, 2020). The increase was essentially\na\ue61cributable to the increase in amounts receivable in Italy\nin respect of the Energy and Environmental Services Fund,\nmainly held by e-distribuzione (\u20ac346 million) and Servizio\nEle\ue61crico Nazionale (\u20ac1,046 million), primarily connected\nwith equalization mechanisms.\nThe increase of \u20ac316 million in sundry tax assets is mainly\na\ue61cributable to an increase in credits for indirect taxes and\nduties in Spain (\u20ac169 million) and Latin America (\u20ac194 mil-\nlion), pa\ue61fially o\ue61bset by a decline in such items in Italy (\u20ac42\nmillion).\n\u201cAmounts due from others\u201c increased, mainly due to an in-\ncrease in receivables for se\ue61cled derivatives transactions in\ncommodities (\u20ac303 million), primarily registered in Italy and\nSpain, pa\ue61fially o\ue61bset by a decrease in assets in respect of\nsecurity deposits and an increase in loss allowances.\n",
"dimensions": {
"concept": "ifrs-full:DisclosureOfOtherCurrentAssetsExplanatory",
"language": "en",
"entity": "scheme:WOCMU6HCI0OJWNPRZS33",
"period": "2021-01-01T00:00:00/2022-01-01T00:00:00"
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},
"Tag23": {
"value": "\n32. Inventories \u2013 \u20ac3,109 million\nMillions of euro\nat Dec. 31, 2021 at Dec. 31, 2020 Change\nRaw and ancillary materials, and consumables:\n- fuels 1,023 595 428 71.9%\n- materials, equipment and other inventories 1,793 1,542 251 16.3%\nTotal 2,816 2,137 679 31.8%\nEnvironmental ce\ue61bi\ue61fcates:\n- CO\n2\n emissions allowances 139 159 (20) -12.6%\n- green ce\ue61fi\ue61ecates 3 5 (2) -40.0%\n- white ce\ue61fi\ue61ecates 16 7 9 -\nTotal 158 171 (13) -7.6 %\nBuildings held for sale 49 52 (3) -5.8%\nPayments on account 86 41 45 -\nTOTAL 3,109 2,401 708 29.5%\n\u201cRaw and ancillary materials, and consumables\u201c consist of \nmaterials and equipment used to operate, maintain, and\nconstruct power plants and distribution networks, as well\nas fuel inventories to cover the Group\u2019s requirements for\ngeneration and trading activities.\nThe overall increase in inventories in 2021 (\u20ac708 million) is\nmainly a\ue61cributable to an increase in inventories of fuel and\nmaterials, devices and other inventories recorded above all\nin Italy (\u20ac358 million), Spain (\u20ac195 million) and Latin Ameri-\nca (\u20ac89 million), notably gas inventories to meet the needs\nof the Group, and an increase in stocks of low- and medi-\num-voltage materials.\n",
"dimensions": {
"concept": "ifrs-full:DisclosureOfInventoriesExplanatory",
"language": "en",
"entity": "scheme:WOCMU6HCI0OJWNPRZS33",
"period": "2021-01-01T00:00:00/2022-01-01T00:00:00"
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"Tag24": {
"value": "\n33. Trade receivables \u2013 \u20ac16,076 million\nMillions of euro\nat Dec. 31, 2021 at Dec. 31, 2020 Change\nCustomers:\n- electricity sales and transpo\ue61f 10,111 7,986 2,125 26.6%\n- distribution and sale of gas 2,658 900 1,758 -\n- other assets 3,158 2,945 213 7. 2 %\nTotal trade receivables due from customers 15,927 11,831 4,096 34.6%\nTrade receivables due from associates and joint ventures 149 215 (66) -30.7%\nTOTAL 16,076 12,046 4,030 33.5%\nTrade receivables due from customers are recognized net\nof loss allowances, which totaled \u20ac3,663 million at the end\nof the year, compared with a balance of \u20ac3,287 million at\nthe end of the previous year.\nSpeci\ue61ecally, the increase in 2021, totaling \u20ac4,030 million,\nmainly recognized in Italy (\u20ac1,495 million), Spain (\u20ac1,625\nmillion) and Latin America (\u20ac728 million), was a\ue61cributable\nto an increase in trade receivables for the sale and trans-\npo\ue61f of electricity and gas, pa\ue61fially o\ue61bset by an increase in\nnet loss allowances.\nFor more information on trade receivables, see note 46\n\u201cFinancial instruments by category\u201d.\n",
"dimensions": {
"concept": "ifrs-full:DisclosureOfTradeAndOtherReceivablesExplanatory",
"language": "en",
"entity": "scheme:WOCMU6HCI0OJWNPRZS33",
"period": "2021-01-01T00:00:00/2022-01-01T00:00:00"
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"Tag25": {
"value": "\n34. Cash and cash equivalents \u2013 \u20ac8,858 million\nCash and cash equivalents, detailed in the following table,\nincreased by \u20ac2,952 million as a result of an increase in\ncash collateral paid by counterpa\ue61fies in derivatives trans-\nactions, pa\ue61fially o\ue61bset by the decrease, especially for the\nParent, a\ue61cributable to cash out\ue61dows linked to the acqui-\nsition of additional equity interests in subsidiaries in Latin\nAmerica.\nMillions of euro\nat Dec. 31, 2021 at Dec. 31, 2020 Change\nBank and postal deposits 8,118 5,699 2,419 42.4%\nCash and cash equivalents on hand 8 42 (34) -81.0%\nOther investments of liquidity 732 165 567 -\nTotal 8,858 5,906 2,952 50.0%\n",
"dimensions": {
"concept": "ifrs-full:DisclosureOfCashAndCashEquivalentsExplanatory",
"language": "en",
"entity": "scheme:WOCMU6HCI0OJWNPRZS33",
"period": "2021-01-01T00:00:00/2022-01-01T00:00:00"
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},
"Tag26": {
"value": "\n35. Assets classi\ue61fed as held for sale and liabilities \nincluded in disposal groups classi\ue61fed as held \nfor sale \u2013 \u20ac1,242 million and \u20ac962 million\nChanges in assets classi\ue61eed as held for sale during 2021\nbreak down as follows:\nMillions of euro\nat Dec. 31, 2020\nReclassi\ue61fcation\nfrom/to current\nand non-current\nassets\nDisposals\nand changes\nin the\nconsolidation\nscope Investments Other changes at Dec. 31, 2021\nPrope\ue61fy, plant and equipment 781 3 (42) 111 46 899\nIntangible assets 58 88 (2) - - 144\nGoodwill - 1 - - - 1\nDeferred tax assets 18 3 - - (5) 16\nEquity-accounted investments 489 4 (614) - 125 4\nNon-current \ue61enancial assets 11 30 - - (1) 40\nCash and cash equivalents 29 13 (1) - 3 44\nInventories, trade receivables and other\ncurrent assets\n30 45 (4) - 23 94\nTotal 1,416 187 (663) 111 191 1,242\nChanges in liabilities included in disposal groups held for\nsale in 2021 break down as follows:\nMillions of euro\nat Dec. 31, 2020\nReclassi\ue61fcation\nfrom/to current\nand non-current\nliabilities\nDisposals and change\nin consolidation\nscope Other changes at Dec. 31, 2021\nLong-term borrowings 687 - - 95 782\nProvisions for risks and charges, non-\ncurrent po\ue61fion\n2 6 (1) 3 10\nDeferred tax liabilities 17 28 (1) 2 46\nNon-current \ue61enancial liabilities 57 - - (17) 40\nOther non-current liabilities - 5 - - 5\nSho\ue61f-term borrowings - 2 - - 2\nOther current \ue61enancial liabilities 12 - - (6) 6\nTrade payables and other current\nliabilities\n33 54 (1) (15) 71\nTotal 808 95 (3) 62 962\nAssets classi\ue61eed as held for sale and liabilities included in dis-\nposal groups classi\ue61eed as held for sale at December 31, 2021\namounted to \u20ac1,242 million and \u20ac962 million, respectively,\nand mainly refer to a number of renewables companies held\nfor sale in Africa and ce\ue61fain Enel X companies in Italy, which,\nfollowing decisions by management, meet the requirements \nof IFRS 5 for classi\ue61ecation within this aggregate.\nA number of companies previously classi\ue61eed as available for\nsale were sold in 2021, in pa\ue61ficular the investment held by\nEnel SpA in Open Fiber, the Enel Green Power companies in\nBulgaria and the solar plant owned by the Panamanian com-\npany Llano Sanchez Solar Power One SA.\nAt December 31, 2020, the aggregate included the Enel\nProduzione business unit formed of the \u201cE\ue61core Majorana\u201d\nsite at Termini Imerese (\u20ac4 million), which at December 31, \n2021 was again classi\ue61eed under \u201cPrope\ue61fy, plant and equip-\nment\u201d as the preliminary sales contract was terminated.\n",
"dimensions": {
"concept": "ifrs-full:DisclosureOfNoncurrentAssetsOrDisposalGroupsClassifiedAsHeldForSaleExplanatory",
"language": "en",
"entity": "scheme:WOCMU6HCI0OJWNPRZS33",
"period": "2021-01-01T00:00:00/2022-01-01T00:00:00"
}
},
"Tag27": {
"value": "\n36. Equity \u2013 \u20ac42,342 million\n36.1 Equity a\ue61bributable to owners of the Parent \u2013 \u20ac29,653 million\nMillions of euro\nat Dec. 31, 2021 at Dec. 31, 2020 Change\nShare capital 10,167 10,167 -\nTreasury share reserve (36) (3) (33)\nOther reserves 1,721 (39) 1,760\nShare premium reserve 7,4 9 6 7,476 20\nReserve for equity instruments - perpetual hybrid bonds 5,567 2,386 3,181\nLegal reserve 2,034 2,034 -\nOther reserves 2,313 2,268 45\nTranslation reserve (8,125) (7,046) (1,079)\nHedging reserve (2,268) (1,917) (351)\nHedging costs reserve (39) (242) 203\nReserve from measurement of \ue61enancial instruments at FVOCI 10 (1) 11\nReserve from equity-accounted investments (721) (128) (593)\nActuarial reserve (1,325) (1,196) (129)\nReserve from disposal of equity interests without loss of control (2,378) (2,381) 3\nReserve from acquisitions of non-controlling interests (843) (1,292) 449\nRetained earnings 17,801 18,200 (399)\nEquity a\ue61eributable to owners of the Parent 29,653 28,325 1,328\nShare capital \u2013 \u20ac10,167 million\nAt December 31, 2021, the fully subscribed and paid-up\nshare capital of Enel SpA totaled \u20ac10,166,679,946, rep-\nresented by the same number of ordinary shares with a\npar value of \u20ac1.00 each. Enel SpA\u2019s share capital was un-\nchanged compared with the amount repo\ue61fed at Decem-\nber 31, 2020.\nAt December 31, 2021, based on the shareholders regis-\nter and the notices submi\ue61ced to CONSOB and received\nby the Parent pursuant to A\ue61ficle 120 of Legislative Decree\n58 of February 24, 1998, as well as other available informa-\ntion, shareholders with interests of greater than 3% in the\nParent\u2019s share capital were the Ministry for the Economy\nand Finance (with a 23.585% stake), BlackRock Inc. (with\na 5.000% stake held for asset management purposes)\nand Capital Research and Management Company (with a\n5.000% stake held for asset management purposes).\nTreasury share reserve \u2013 \u20ac(36) million\nAt December 31, 2021, treasury shares are represented by\n4,889,152 ordinary shares of Enel SpA with a par value of\n\u20ac1.00 each (3,269,152 at December 31, 2020), purchased\nthrough an authorized intermediary for a total of \u20ac36 mil-\nlion. The di\ue61berence between the amount paid and the par\nvalue is recognized as a reduction in equity in the share\npremium reserve.\nOther reserves \u2013 \u20ac1,721 million\nShare premium reserve \u2013 \u20ac7,496 million\nPursuant to A\ue61ficle 2431 of the Italian Civil Code, the share\npremium reserve contains, in the case of the issue of\nshares at a price above par, the di\ue61berence between the is-\nsue price of the shares and their par value, including those\nresulting from conversion from bonds. The reserve, which\nis a capital reserve, may not be distributed until the legal\nreserve has reached the threshold established under A\ue61fi-\ncle 2430 of the Italian Civil Code.\nReserve for equity instruments - perpetual hybrid bonds\n\u2013 \u20ac5,567 million\nThis reserve repo\ue61fs the nominal value, net of transac-\ntion costs, of the non-conve\ue61fible subordinated perpet-\nual hybrid bonds denominated in euros for international\ninvestors.\nThe change during the year re\ue61dected the subscription \nof new non-conve\ue61fible subordinated perpetual hybrid\nbonds in an amount, net of transaction costs, of \u20ac2,214\nmillion and the conversion of bonds already in issue and\nconve\ue61fed into perpetual hybrid bonds in the amount, \nnet of transaction costs, of \u20ac967 million.\nIn 2021, the Group paid \u20ac71 million in coupons to holders\nof perpetual hybrid bonds.\n\nLegal reserve \u2013 \u20ac2,034 million\nThe legal reserve is formed of the pa\ue61f of pro\ue61ets that, \npursuant to A\ue61ficle 2430 of the Italian Civil Code, cannot\nbe distributed as dividends.\nOther reserves \u2013 \u20ac2,313 million\nThese include \u20ac2,215 million related to the remaining\npo\ue61fion of the adjustments carried out when Enel was \ntransformed from a public entity to a joint-stock com-\npany.\nPursuant to A\ue61ficle 47 of the Consolidated Income Tax\nCode (Testo Unico Imposte sul Reddito, or \u201cTUIR\u201d), this\namount does not constitute taxable income when dis-\ntributed.\nTranslation reserve \u2013 \u20ac(8,125) million\nThe decrease for the year, of \u20ac1,079 million, was mainly \ndue to the change in the consolidation scope connected \nwith the purchase of 17.3% of Enel Am\u00e9ricas, pa\ue61fially o\ue61b-\nset by the net depreciation of the functional currencies\nused by the foreign subsidiaries against the Group pres-\nentation currency (the euro).\nHedging reserve \u2013 \u20ac(2,268) million\nThis includes the net loss recognized in equity from the \nmeasurement of cash \ue61dow hedge derivatives.\nHedging costs reserve \u2013 \u20ac(39) million\nIn application of IFRS 9, this reserve includes the fair val-\nue gains and losses on currency basis points and forward \npoints.\nReserve from measurement of \ue61fnancial instruments at\nFVOCI \u2013 \u20ac10 million\nThis includes net unrealized fair value losses on \ue61enancial \nassets.\nReserve from equity-accounted investments \u2013 \u20ac(721)\nmillion\nThe reserve repo\ue61fs the share of comprehensive income \nto be recognized directly in equity of equity-accounted\ninvestees. The change in 2021 is mainly a\ue61cributable to\nthe change in the hedging reserve of Slovak Power Hold-\ning following the sharp rise in commodity prices.\nActuarial reserve \u2013 \u20ac(1,325) million\nThis reserve includes actuarial gains and losses in respect\nof employee bene\ue61et liabilities, net of tax e\ue61bects.\nReserve from disposal of equity interests without loss of\ncontrol \u2013 \u20ac(2,378) million\nThis item mainly repo\ue61fs:\n\u2022 the gain posted on the public o\ue61bering of Enel Green \nPower shares, net of expenses associated with the dis-\nposal and the related taxation;\n\u2022 the sale of non-controlling interests recognized as a re-\nsult of the Enersis (now Enel Am\u00e9ricas and Enel Chile)\ncapital increase;\n\u2022 the capital loss, net of expenses associated with the \ndisposal and the related taxation, from the public o\ue61ber-\ning of 21.92% of Endesa;\n\u2022 the disposal to third pa\ue61fies of the non-controlling in-\nterest in Enel Green Power No\ue61fh America Renewable\nEnergy Pa\ue61fners;\n\u2022 the e\ue61bects of the merger into Enel Am\u00e9ricas of Endesa \nAm\u00e9ricas and Chilectra Am\u00e9ricas;\n\u2022 the disposal to third pa\ue61fies of a non-controlling inter-\nest without loss of control in a number of companies in\nSouth Africa.\nThe change in the reserve in 2021 is associated with the\nsale of additional interests in a number of companies in\nSouth Africa.\nReserve from acquisitions of non-controlling interests \u2013\n\u20ac(843) million\nThis reserve mainly includes the surplus of acquisition\nprices with respect to the carrying amount of the equi-\nty acquired following the acquisition from third pa\ue61fies of\nfu\ue61fher interests in companies already controlled in Latin\nAmerica.\nThe change for the year (\u20ac449 million) mainly re\ue61dects the\ne\ue61bects of the increase of 17.3% in the interest held in Enel\nAm\u00e9ricas following the completion of the voluntary par-\ntial tender o\ue61ber and the completion of the merger of EGP\nAm\u00e9ricas into Enel Am\u00e9ricas. Following these transactions,\nEnel owns approximately 82.3% of the outstanding share\ncapital of Enel Am\u00e9ricas. \nRetained earnings \u2013 \u20ac17,801 million\nThis reserve repo\ue61fs earnings from previous years that\nhave not been distributed or allocated to other reserves.\n\nThe table below shows the changes in gains and losses\nrecognized directly in other comprehensive income, in-\ncluding non-controlling interests, with speci\ue61ec repo\ue61fing\nof the related tax e\ue61bects.\nMillions of euro\nat Dec. 31, 2020 Change at Dec. 31, 2021\nTotal\nOf\nwhich\nowners\nof the\nParent\nOf which\nnon-\ncontrolling\ninterests\nGains/\n(Losses)\nrecognized\nin equity\nduring the\nyear\nReleased\nto pro\ue61ft\nor loss Taxes Total\nOf\nwhich\nowners\nof the\nParent\nOf which\nnon-\ncontrolling\ninterests Total\nOf\nwhich\nowners\nof the\nParent\nOf which\nnon-\ncontrolling\ninterests\nTranslation reserve (11,700) (6,458) (5,242) (90) - - (90) 155 (245) (11,790) (6,303) (5,487)\nHedging reserve (2,236) (1,921) (315) 506 (1,805) 574 (725) (359) (366) (2,961) (2,280) (681)\nHedging costs\nreserve\n(244) (242) (2) 208 (7) (6) 195 203 (8) (49) (39) (10)\nReserve from\nmeasurement \nof \ue61enancial\ninstruments at\nFVOCI\n- 1 (1) 11 - - 11 11 - 11 12 (1)\nShare of OCI of\nequity-accounted\nassociates\n(175) (177) 2 (642) - (3) (645) (648) 3 (820) (825) 5\nReserve from\nmeasurement of\nequity investments\nin other companies\n(32) (32) - - - - - - - (32) (32) -\nActuarial reserve (1,828) (1,276) (552) 40 - (10) 30 11 19 (1,798) (1,265) (533)\nTotal gains/(losses)\nrecognized in\nequity\n(16,215) (10,105) (6,110) 33 (1,812) 555 (1,224) (627) (597) (17,439) (10,732) (6,707)\n36.2 Dividends\nAmount distributed\n(millions of euro)\nDividend per \nshare (euro)\nDividends distributed in 2020\nDividends for 2019 3,334 0.328 \nInterim dividends for 2020\n(1)\n- -\nSpecial dividends - -\nTotal dividends distributed in 2020 3,334 0.328 \nDividends distributed in 2021\nDividends for 2020 3,638 0.358\nInterim dividends for 2021\n(2)\n- -\nSpecial dividends - -\nTotal dividends distributed in 2021 3,638 0.358\n(1) Approved by the Board of Directors on November 5, 2020, and paid as from January 20, 2021 (interim dividend of \u20ac0.175 per share for a total of \u20ac1,779\nmillion).\n(2) Approved by the Board of Directors on November 4, 2021, and paid as from January 26, 2022 (interim dividend of \u20ac0.19 per share for a total of \u20ac1,932 million).\nThe dividend for 2021 is equal to \u20ac0.38 per share, for a to-\ntal of \u20ac3,863 million (of which \u20ac0.19 per share, for a total of\n\u20ac1,932 million, already paid as an interim dividend as from\nJanuary 26, 2022). It will be proposed to the Shareholders\u2019\nMeeting of May 19, 2022 at single call.\nThese consolidated \ue61enancial statements do not take ac-\ncount of the e\ue61bects of the distribution to shareholders\nof the dividend for 2021, except for the liability in respect\nof shareholders for the interim dividend for 2021, which\nwas approved by the Board of Directors on November 4,\n2021 for a potential maximum of \u20ac1,932 million, and paid\nas from January 26, 2022 net of the po\ue61fion pe\ue61faining to\nthe 4,889,152 treasury shares held as at the record date of\nJanuary 25, 2021.\nIn 2021, the Group also paid \u20ac71 million to holders of per-\npetual hybrid bonds.\n\nCapital management \nThe Group\u2019s objectives for managing capital comprise\nsafeguarding the business as a going concern, creating\nvalue for stakeholders and suppo\ue61fing the development of\nthe Group. In pa\ue61ficular, the Group seeks to maintain an ad-\nequate capitalization that enables it to achieve a satisfac-\ntory return for shareholders and ensure access to external\nsources of \ue61enancing, in pa\ue61f by maintaining an adequate\nrating.\nIn this context, the Group manages its capital structure\nand adjusts that structure when changes in economic\nconditions so require. There were no substantive changes\nin objectives, policies or processes in 2021.\nTo this end, the Group constantly monitors developments\nin the level of its debt in relation to equity. The situation at\nDecember 31, 2021 and 2020 is summarized in the follow-\ning table.\nMillions of euro\nat Dec. 31, 2021 at Dec. 31, 2020 Change\nNon-current \ue61enancial debt 54,620 49,519 5,101\nNet current \ue61enancial position 24 (1,359) 1,383\nNon-current \ue61enancial assets and long-term securities (2,692) (2,745) 53\nNet \ue61fnancial debt 51,952 45,415 6,537\nEquity a\ue61cributable to owners of the Parent 29,653 28,325 1,328\nNon-controlling interests 12,689 14,032 (1,343)\nEquity 42,342 42,357 (15)\nDebt/equity ratio 1.23 1.07 0.16\nThe increase in the debt/equity ratio, which measures \ue61e-\nnancial leverage, is essentially a\ue61cributable to the increase\nin net \ue61enancial debt, mainly re\ue61decting the funding require-\nments of investments in the year, the payment of dividends\nand extraordinary transactions in non-controlling interests\nconnected with the acquisition of additional interests in\nEnel Am\u00e9ricas.\nSee note 45 for a breakdown of the individual items in the\ntable.\n\n36.3 Non-controlling interests \u2013 \u20ac12,689 million\nThe following table presents the composition of non-con-\ntrolling interests by geographical segment.\nMillions of euro Non-controlling interests\nPro\ue61ft/(Loss) for the year a\ue61eributable to\nnon-controlling interests\nat Dec. 31, 2021 at Dec. 31, 2020 at Dec. 31, 2021 at Dec. 31, 2020\nItaly 1 2 - -\nIberia 5,238 5,869 193 468\nLatin America 6,511 7,206 467 477\nEurope 635 638 5 55\nNo\ue61fh America 151 160 6 6\nAfrica, Asia and Oceania 153 157 (3) 6\nTotal 12,689 14,032 668 1,012\nThe decrease in the po\ue61fion a\ue61cributable to non-controlling\ninterests mainly re\ue61dects dividends and the increase in the\npercentage holding in Enel Am\u00e9ricas.\nThe \ue61enancial disclosure requirements of IFRS 12 for sub-\nsidiaries with signi\ue61ecant non-controlling interests are re-\npo\ue61fed below.\n\n\nMillions of euro Non-current assets Current assets Total assets\nat Dec. 31, 2021 at Dec. 31, 2020 at Dec. 31, 2021 at Dec. 31, 2020 at Dec. 31, 2021 at Dec. 31, 2020\nSubsidiaries\nEnel Am\u00e9ricas 28,959 21,337 4,711 4,582 33,670 25,919\nEnel Chile 9,887 9,295 (642) 170 9,245 9,465\nEndesa 43,217 41,819 3,853 1,386 47,070 43,205\nMillions of euro\nNon-current\nliabilities Current liabilities Total liabilities Equity\nEquity a\ue61eributable\nto owners of the\nParent\nNon-controlling\ninterests\nat Dec.\n31, 2021\nat Dec.\n31, 2020\nat Dec.\n31, 2021\nat Dec.\n31, 2020\nat Dec.\n31, 2021\nat Dec.\n31, 2020\nat Dec.\n31, 2021\nat Dec.\n31, 2020\nat Dec.\n31, 2021\nat Dec.\n31, 2020\nat Dec.\n31, 2021\nat Dec.\n31, 2020\nSubsidiaries\nEnel Am\u00e9ricas 11,320 8,827 6,073 5,495 17,393 14,322 16,277 11,597 11,556 6,643 4,721 4,954\nEnel Chile 3,356 3,027 1,178 1,066 4,534 4,093 4,711 5,372 2,921 3,326 1,790 2,046\nEndesa 15,196 12,869 11,449 7, 10 1 26,645 19,970 20,425 23,235 15,187 17,366 5,238 5,869\nMillions of euro Total revenue\n(1)\nPre-tax pro\ue61ft/(loss)\nPro\ue61ft/(Loss) from\ncontinuing operations\nPro\ue61ft/(Loss) a\ue61eributable\nto owners of the Parent\nPro\ue61ft/(Loss) a\ue61eributable\nto non-controlling\ninterests\n2021 2020 2021 2020 2021 2020 2021 2020 2021 2020\nSubsidiaries\nEnel Am\u00e9ricas\n(2)\n13,581 10,437 1,516 1,187 757 738 337 274 420 464\nEnel Chile 3,114 2,816 128 (133) 104 (40) 57 (25) 47 (15)\nEndesa 20,217 16,614 769 1,965 589 1,551 396 1,082 193 469\n(1) In order to ensure a uniform comparison of the data, revenue for 2020 was restated by excluding the pa\ue61f of income from commodity contracts, in line with\nthe presentation of revenue in the notes to the \ue61enancial statements. \n(2) For comparative purposes only, \u20ac87 million in 2020 in respect of the component recognized through pro\ue61et or loss deriving from the remeasurement at fair\nvalue of the \ue61enancial assets connected with service concession arrangements involving distribution operations in Brazil falling within the scope of IFRIC 12\nhave been reclassi\ue61eed from \ue61enancial income to revenue. The la\ue61cer classi\ue61ecation had an impact of the same amount on operating pro\ue61et. For more details,\nplease see note 7 to the consolidated \ue61enancial statements.\n",
"dimensions": {
"concept": "ifrs-full:DisclosureOfShareCapitalReservesAndOtherEquityInterestExplanatory",
"language": "en",
"entity": "scheme:WOCMU6HCI0OJWNPRZS33",
"period": "2021-01-01T00:00:00/2022-01-01T00:00:00"
}
},
"Tag28": {
"value": "\n37. Borrowings\nMillions of euro Non-current Current\nat Dec. 31,\n2021\nat Dec. 31,\n 2020\nat Dec. 31,\n2021\nat Dec. 31,\n 2020\nLong-term borrowings 54,500 49,519 4,031 3,168\nSho\ue61f-term borrowings - - 13,306 6,345\nTotal 54,500 49,519 17, 337 9,513\nFor more information on the nature of borrowings, see\nnote 46.2 \u201cFinancial liabilities by category\u201d.\n",
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"concept": "ifrs-full:DisclosureOfBorrowingsExplanatory",
"language": "en",
"entity": "scheme:WOCMU6HCI0OJWNPRZS33",
"period": "2021-01-01T00:00:00/2022-01-01T00:00:00"
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},
"Tag29": {
"value": "\n38. Employee bene\ue61fts \u2013 \u20ac2,724 million\nThe Group provides its employees with a variety of bene-\n\ue61ets, including deferred compensation bene\ue61ets, additional\nmonths\u2019 pay for having reached age limits or eligibility for \nold-age pension, loyalty bonuses for achievement of sen-\niority milestones, supplemental retirement and health-\ncare plans, residential electricity discounts and similar\nbene\ue61ets. More speci\ue61ecally:\n\u2022 for Italy, the item \u201cPension bene\ue61ets\u201d regards estimated \naccruals made to cover bene\ue61ets due under the supple-\nmental retirement schemes of retired executives and\nthe bene\ue61ets due to personnel under law or contract\nat the time the employment relationship is terminated. \nFor the foreign companies, the item refers to post-em-\nployment bene\ue61ets, of which the most material regard\nthe pension bene\ue61et schemes of Endesa in Spain, which\nbreak down into three types that di\ue61ber on the basis of \nemployee seniority and company. In general, under the\nframework agreement of October 25, 2000, employees\npa\ue61ficipate in a speci\ue61ec de\ue61ened contribution pension\nplan and, in cases of disability or death of employees\nin service, a de\ue61ened bene\ue61et plan which is covered by\nappropriate insurance policies. In addition, the group\nhas two other limited-enrollment plans (i) for current\nand retired Endesa employees covered by the elec-\ntricity industry collective bargaining agreement prior\nto the changes introduced with the framework agree-\nment noted earlier and (ii) for employees of the Catalan\ncompanies merged in the past (Fecsa/Enher/HidroEm-\npord\u00e0). Both are de\ue61ened bene\ue61et plans and bene\ue61ets are\nfully ensured, with the exception of the former plan for\nbene\ue61ets in the event of the death of a retired employ-\nee. Finally, the Brazilian companies have also established\nde\ue61ened bene\ue61et plans;\n\u2022 the item \u201cElectricity discount\u201d comprises bene\ue61ets re-\ngarding electricity supply associated in pa\ue61ficular with\nforeign companies;\n\u2022 the item \u201cHealth insurance\u201d refers to bene\ue61ets for cur-\nrent or retired employees covering medical expenses;\n\u2022 \u201cOther bene\ue61ets\u201d mainly regard the loyalty bonus, which \nis adopted in various countries and for Italy is repre-\nsented by the estimated liability for the bene\ue61et entitling\nemployees covered by the electricity workers national\ncollective bargaining agreement to a bonus for achieve-\nment of seniority milestones (25th and 35th year of ser-\nvice). It also includes other incentive plans, which pro-\nvide for the award to ce\ue61fain Company managers of a\nmonetary bonus subject to speci\ue61eed conditions.\nThe following table repo\ue61fs changes in the de\ue61ened bene-\n\ue61et obligation for post-employment and other long-term\nemployee bene\ue61ets at December 31, 2021, and December\n31, 2020, respectively, as well as a reconciliation of that\nobligation with the actuarial liability.\n\nMillions of euro 2021 2020\nPension\nbene\ue61fts\nElectricity\ndiscount\nHealth\ninsurance\nOther\nbene\ue61fts Total\nPension\nbene\ue61fts\nElectricity\ndiscount\nHealth\ninsurance\nOther\nbene\ue61fts Total\nCHANGES IN ACTUARIAL\nOBLIGATION\nActuarial obligation at the\nsta\ue61b of the year\n4,408 403 217 222 5,250 5,691 904 263 242 7, 10 0\nCurrent service cost 17 2 4 28 51 18 3 4 38 63\nInterest expense 214 3 7 3 227 249 5 7 4 265\nActuarial (gains)/losses arising\nfrom changes in demographic\nassumptions\n192 - (6) - 186 45 12 6 1 64\nActuarial (gains)/losses arising\nfrom changes in \ue61enancial\nassumptions\n(664) (14) 6 (1) (673) 105 19 (2) 2 124\nExperience adjustments 452 31 (9) - 474 466 (21) (7) (8) 430\nPast service cost (17) - - (3) (20) (24) (504) (13) (1) (542)\n(Gains)/Losses arising from\nse\ue61clements\n(4) - - - (4) (584) - - - (584)\nExchange di\ue61berences 14 (1) (1) - 12 (1,206) (1) (30) (7) (1,244)\nEmployer contributions - - - - - - - - - -\nEmployee contributions - - - - - 1 - - - 1\nBene\ue61ets paid (379) (15) (12) (58) (464) (358) (16) (11) (48) (433)\nOther changes 7 1 - (1) 7 5 2 - (1) 6\nLiabilities included in disposal\ngroups classi\ue61eed as held for\nsale\n- - - - - - - - - -\nActuarial obligation at year-\nend (A)\n4,240 410 206 190 5,046 4,408 403 217 222 5,250\nCHANGES IN PLAN ASSETS\nFair value of plan assets at the\nsta\ue61b of the year\n2,299 - - - 2,299 3,374 - - - 3,374\nInterest income 121 - - - 121 160 - - - 160\nExpected return on plan assets\nexcluding amounts included in\ninterest income\n38 - - - 38 85 - - - 85\nExchange di\ue61berences 17 - - - 17 (782) - - - (782)\nEmployer contributions 252 15 12 28 307 342 16 11 21 390\nEmployee contributions - - - - - 1 - - - 1\nBene\ue61ets paid (379) (15) (12) (28) (434) (358) (16) (11) (21) (406)\nOther payments - - - - - (523) - - - (523)\nChanges in the consolidation\nscope\n- - - - - - - - - -\nFair value of plan assets at\nyear-end (B)\n2,348 - - - 2,348 2,299 - - - 2,299\nEFFECT OF ASSET CEILING\nAsset ceiling at the sta\ue61b of\nthe year\n13 - - - 13 45 - - - 45\nInterest income 1 - - - 1 3 - - - 3\nChanges in asset ceiling 12 - - - 12 (24) - - - (24)\nExchange di\ue61berences - - - - - (11) - - - (11)\nChanges in the consolidation\nscope\n- - - - - - - - - -\nAsset ceiling at year-end (C) 26 - - - 26 13 - - - 13\nNet liability in statement of\n\ue61fnancial position (A-B+C)\n1,918 410 206 190 2,724 2,122 403 217 222 2,964\n\nMillions of euro\n2021 2020\n(Gains)/Losses taken to pro\ue61ft or loss\nService cost and past service cost 9 (509)\nNet interest expense 107 108\n(Gains)/Losses arising from se\ue61clements (4) (61)\nActuarial (gains)/losses on other long-term bene\ue61ets 22 31\nOther changes 1 (9)\nTotal 135 (440)\nMillions of euro\n2021 2020\nChange in (gains)/losses in OCI\nExpected return on plan assets excluding amounts included in interest income (38) (85)\nActuarial (gains)/losses on de\ue61ened bene\ue61et plans (13) 626\nChanges in asset ceiling excluding amounts included in interest income 12 (24)\nOther changes (1) (1)\nTotal (40) 516\nThe change in the cost recognized in pro\ue61et or loss was\nequal to \u20ac575 million. The impact on the income state-\nment is, therefore, greater than in the previous year, due\nmainly to the signing in 2020 of the 5th Endesa Collective\nBargaining Agreement, which modi\ue61eed the electricity dis-\ncount bene\ue61et for current and former employees, with the\nconsequent reversal of the associated provision.\nThe liability recognized in the statement of \ue61enancial posi-\ntion at the end of the year is repo\ue61fed net of the fair value\nof plan assets, amounting to \u20ac2,348 million at December\n31, 2021. Those assets, which are entirely in Spain and Bra-\nzil, break down as follows.\nat Dec. 31,\n2021\nat Dec. 31,\n2020\nInvestments quoted in active markets\nEquity instruments 8% 7%\nFixed-income securities 54% 63%\nInvestment prope\ue61fy 3% 2%\nOther - -\nUnquoted investments\nAssets held by insurance unde\ue61fakings - -\nOther 35% 28%\nTotal 100% 100%\nThe main actuarial assumptions used to calculate the lia-\nbilities in respect of employee bene\ue61ets and the plan assets,\nwhich are consistent with those used the previous year, are\nset out in the following table.\nItaly Iberia Latin America\nOther\ncountries Italy Iberia Latin America\nOther\ncountries\n2021 2020\nDiscount rate 0.00%-0.80% 0.00%-1.16% 5.60%-9.67% 0.80%-8.40% 0.00%-0.50% 0.00%-0.61% 2.55%-7.95% 0.75%-6.30%\nIn\ue61dation rate 1.50% 2.20% 3.00% -8.00% 1.50%-4.01% 0.50% 1.00% 3.00%-4.85% 0.75%-3.83%\nRate of wage\nincreases\n0.80%-1.80% 2.20% 3.80%-8.00% 2.50%-10.00% 0.50%-2.50% 1.00% 3.80%-5.04% 2.25%-3.83%\nRate of increase in\nhealthcare costs\n2.50% 4.40% 7.12%-8.00% - 1.50% 3.20% 7.12%-8.00% -\nExpected rate of\nreturn on plan assets\n- 0.57% 9.30%-9.46% - - 0.57% 6.08%-7.33% -\n\nThe following table repo\ue61fs the outcome of a sensitivity\nanalysis that demonstrates the e\ue61bects on the de\ue61ened ben-\ne\ue61et obligation of changes reasonably possible at the end\nof the year in the actuarial assumptions used in estimating\nthe obligation.\nPension\nbene\ue61fts\nElectricity\ndiscount\nHealth\ninsurance\nOther\nbene\ue61fts\nPension \nbene\ue61fts\nElectricity\ndiscount\nHealth\ninsurance\nOther \nbene\ue61fts\nat Dec. 31, 2021 at Dec. 31, 2020\nDecrease of 0.5% in\ndiscount rate\n225 27 11 - 239 30 11 (1)\nIncrease of 0.5% in\ndiscount rate\n(184) (30) (14) (10) (190) (30) (15) (11)\nIncrease of 0.5% in\nin\ue61dation rate\n2 (4) (2) (6) (1) (5) (3) (7)\nDecrease of 0.5% in\nin\ue61dation rate\n28 (2) 9 (2) 33 2 7 (4)\nIncrease of 0.5% in\nremuneration\n14 (3) (2) - 14 (2) (3) (3)\nIncrease of 0.5% in\npensions currently\nbeing paid\n14 (3) (2) (5) 15 (2) (3) (6)\nIncrease of 1% in\nhealthcare costs\n- - 20 1 - - (2) -\nIncrease of 1 year in life\nexpectancy of active\nand retired employees\n98 (3) 14 (5) 27 (11) 2 (34)\nThe sensitivity analysis used an approach that extrapolates\nthe e\ue61bect on the de\ue61ened bene\ue61et obligation of reasonable\nchanges in an individual actuarial assumption, leaving the\nother assumptions unchanged.\nThe contributions expected to be paid into de\ue61ened bene\ue61et\nplans in the subsequent year amount to \u20ac196 million.\nThe following table repo\ue61fs expected bene\ue61et payments in\nthe coming years for de\ue61ened bene\ue61et plans.\nMillions of euro\nat Dec. 31, 2021 at Dec. 31, 2020\nWithin 1 year 392 366\nIn 1-2 years 364 337\nIn 2-5 years 1,077 971\nMore than 5 years 1,714 1,534\nExpected payments are increasing in general. This is main-\nly due to Brazil, where forecasts have been impacted by\nrising life expectancy and a signi\ue61ecant increase in expect-\ned in\ue61dation. The amount of future payments shown in the\ntable, not being subject to discounting, is signi\ue61ecantly af-\nfected by this increase. Finally, it should be noted that the\nliability does not increase in the same manner, as the in-\n\ue61dationary e\ue61bects are o\ue61bset by the e\ue61bects of discounting.\n",
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"Tag30": {
"value": "\n39. Provisions for risks and charges \u2013 \u20ac8,323 million \nMillions of euro\nat Dec. 31, 2021 at Dec. 31, 2020\nNon-current Current Total Non-current Current Total\nProvision for litigation, risks and other charges:\n- nuclear decommissioning 666 - 666 596 - 596\n- site retirement, removal and restoration 3,066 203 3,269 2,017 99 2,116\n- litigation 790 44 834 734 86 820\n- environmental ce\ue61fi\ue61ecates - 32 32 - 42 42\n- taxes and duties 267 28 295 288 43 331\n- other 821 347 1,168 757 343 1,100\nTotal 5,610 654 6,264 4,392 613 5,005\nProvision for early retirement incentives and other\nrestructuring plans\n435 293 728 623 444 1,067\nProvision for restructuring programs connected with\nthe energy transition\n1,152 179 1,331 759 - 759\nTOTAL 7, 197 1,126 8,323 5,774 1,057 6,831\nMillions of euro Accrual Reversal Utilization Discounting\nProvisions \nfor site\nretirement\nand\nrestoration\nChange in the \nconsolidation\nscope\nExchange\ndi\ue61cerences\nOther \nchanges\nReclassi\ue61fcations \nof liabilities\nincluded in\ndisposal groups\nheld for sale\nat Dec. 31,\n2020\nat Dec. 31,\n2021\nProvision for litigation,\nrisks and other charges:\n- nuclear\ndecommissioning\n596 - - - 1 69 - - - - 666\n- site retirement, removal\nand restoration\n2,116 455 (13) (87) 3 799 8 (14) 2 - 3,269\n- litigation 820 213 (113) (124) 44 - - (3) (3) - 834\n- environmental\nce\ue61fi\ue61ecates\n42 15 (4) (21) - - - - - - 32\n- taxes and duties 331 64 (41) (21) 6 - - - (44) - 295\n- other 1,100 338 (95) (162) 14 (7) - (3) (11) (6) 1,168\nTotal 5,005 1,085 (266) (415) 68 861 8 (20) (56) (6) 6,264\nProvision for early\nretirement incentives\nand other restructuring\nplans\n1,067 16 (15) (361) - - - - 21 - 728\nProvision for\nrestructuring programs\nconnected with the\nenergy transition\n759 687 (18) (95) 16 - - (1) (17) - 1,331\nTOTAL 6,831 1,788 (299) (871) 84 861 8 (21) (52) (6) 8,323\nNuclear decommissioning provision\nAt December 31, 2021, the provision re\ue61dected solely the\ncosts that would be incurred at the time of decommis-\nsioning of nuclear plants by Enresa, a Spanish public entity\nresponsible for such activities in accordance with Royal\nDecree 1349/2003 and Law 24/2005.\nIn general, the costs are quanti\ue61eed on the basis of a stand-\nard contract between Enresa and the electricity compa-\nnies approved by the Ministry for the Economy in Septem-\nber 2001, which regulates the retirement and closing of\nnuclear power plants. The time horizon envisaged, three\nyears, corresponds to the period from the termination of\npower generation to the transfer of plant management to\nEnresa (so-called \u201cpost-operational costs\u201c) and takes ac-\ncount, among the various assumptions used to estimate\nthe amount, of the quantity of unused nuclear fuel expect-\ned at the date of closure of each of the Spanish nucle-\nar plants on the basis of the provisions of the concession\nagreement.\nSite retirement, removal and restoration\nprovision\nThis provision represents the present value of the esti-\nmated cost for the retirement and removal of non-nuclear\nplants where there is a legal or constructive obligation to\n\ndo so. The provision mainly regarded the Endesa Group\nand Enel Produzione. The change in the provision in 2021\nwas mainly linked to the redetermination of the future re-\ntirement costs of ce\ue61fain plants in Iberia and Italy and an\nincrease in provisions for retirement costs resulting from\nthe Group\u2019s decision to promote the termination of gener-\nation from coal-\ue61ered power plants and reconve\ue61f plans as\npa\ue61f of the energy transition.\nThe following table summarizes the temporal breakdown\nof payments connected with the site retirement, removal\nand restoration provision.\nMillions of euro\nPayments by time bracket\n(nominal value) Discounted amount\nWithin 1 year 652 651\nIn 1-5 years 929 896\nMore than 5 years 2,671 1,722\nTotal 4,252 3,269\nLitigation provision\nThe litigation provision covers contingent liabilities in re-\nspect of pending litigation and other disputes. It includes \nan estimate of the potential liability relating to disputes\nthat arose during the year, as well as revised estimates of\nthe potential costs associated with disputes initiated in\nprior years. The balance for litigation mainly regards the\ncompanies in Spain (\u20ac181 million), Italy (\u20ac133 million) and\nLatin America (\u20ac497 million).\nThe increase compared with the previous year, equal to\n\u20ac14 million, mainly re\ue61dects the increase in the provision \nin Italy, Iberia and Brazil, re\ue61decting provisions for new dis-\nputes, o\ue61bset by an increase in uses in Peru following the \nresolution of a number of disputes.\nProvision for environmental ce\ue61ei\ue61fcates\nThe provision for environmental ce\ue61fi\ue61ecates covers costs\nin respect of sho\ue61ffalls in the environmental ce\ue61fi\ue61ecates\nneeded for compliance with national or supranational en-\nvironmental protection requirements and mainly regards\nEnel Energ\u00eda and Endesa Energ\u00eda.\nProvision for taxes and duties\nThe provision for taxes and duties covers the estimated\nliability deriving from tax disputes concerning direct and\nindirect taxes.\nThe balance of the provision also includes the provision\nfor current and potential disputes concerning local prop-\ne\ue61fy tax (whether the Imposta Comunale sugli Immobili \n(ICI) or the Imposta Municipale Unica (IMU)) in Italy. In Ita-\nly, the Group has taken due account of developments in\nland registry regulations (which with e\ue61bect from January\n1, 2016 excluded machinery, devices, equipment and oth-\ner plant speci\ue61ec to a production process from the calcu-\nlation of the imputed rent for buildings classi\ue61eed in land\nregistry group D, which includes generation plants) in es-\ntimating the liability for such taxes, both for the purposes\nof quantifying the probable risk associated with pending\nlitigation and generating a reasonable valuation of prob-\nable future charges on positions that have not yet been\nassessed by the Revenue Agency and municipalities.\nOther provisions\nOther provisions cover various risks and charges, mainly\nin connection with regulatory disputes and disputes with\nlocal authorities regarding various duties and fees or oth-\ner charges.\nThe increase of \u20ac68 million in other provisions is, in ad-\ndition to provisions for new insurance indemnities, mainly\na\ue61cributable to Enel Global Trading for provisions recog-\nnized by the company in view of a possible adjustment of\nthe gas contract price to the market price by the supplier.\nProvision for early retirement incentives and\nother restructuring plans\nThe provision for early retirement incentives and other\nrestructuring plans includes the estimated charges relat-\ned to binding agreements for the voluntary termination\nof employment contracts in response to organizational\nneeds. The reduction of \u20ac339 million for the year main-\nly re\ue61dects uses of provisions for incentives established in\nSpain (Acuerdo de Salida Voluntaria) and Italy in previous \nyears to cover the early termination of employment for \nce\ue61fain employees.\nProvision for restructuring programs\nconnected with the energy transition\nEnel, in its role as a leader of the energy transition, has\nplaced decarbonization and growth of renewables around \nthe world at the center of its strategy.\n\nIn this context, Enel has begun restructuring the activi-\nties associated with the energy-transition process, which\ninvolves thermal generation plants in all the geographi-\ncal areas in which the Group operates. The consequent\nrevision of processes and operating models will require \nchanges in the roles and skills of employees, which the \nGroup intends to implement with highly sustainable plans\nbased on redeployment programs, with major upskilling\nand reskilling plans and voluntary individual early retire-\nment agreements. The energy transition is also based\non the progressive and expansive development of digital\ntools, as digitization is essential to responding to multiple\nexternal forces and making informed and well-consid-\nered decisions at every level within the Group.\nA provision was therefore established in 2020 for restruc-\nturing programs, which at December 31, 2021 amounted\nto \u20ac1,331 million, which is mainly a\ue61cributable to Spain and \nItaly, and represents the estimated costs that the Group\nwill incur following the acceleration of the energy tran-\nsition, for all direct and indirect activities related to the \nreview of processes and operating models and the roles\nand skills of employees.\n",
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"Tag31": {
"value": "\n40. Other non-current \ue61fnancial liabilities \u2013 \u20ac120 million\nMillions of euro\nat Dec. 31, 2021 at Dec. 31, 2020 Change\nOther non-current \ue61enancial liabilities 120 - 120 -\nTotal 120 - 120 -\n\u201cOther non-current \ue61enancial liabilities\u201d repo\ue61f the non-cur-\nrent po\ue61fion of liabilities in respect of the Spanish electri-\ncal system de\ue61ecit in the amount of \u20ac120 million (\u20ac0 million\nat December 31, 2020), which are included in net \ue61enancial\ndebt.\n\n44. Other current \ue61fnancial liabilities \u2013 \u20ac625 million\nMillions of euro\nat Dec. 31, 2021 at Dec. 31, 2020 Change\nAccrued \ue61enancial expense and deferred \ue61enancial income 539 535 4 0.7%\nOther items 86 87 (1) -1.1%\nTotal 625 622 3 0.5%\nOther current \ue61enancial liabilities are vi\ue61fually unchanged on\nDecember 31, 2020.\nOther items mainly regard liabilities for accrued interest.\n",
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"period": "2021-01-01T00:00:00/2022-01-01T00:00:00"
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"Tag32": {
"value": "\n41. Other non-current liabilities \u2013 \u20ac4,525 million\nMillions of euro\nat Dec. 31, 2021 at Dec. 31, 2020 Change\nAccrued operating expenses and deferred income 498 500 (2) -0.4%\nOther items 4,027 2,958 1,069 36.1%\nTotal 4,525 3,458 1,067 30.9%\nThe change in \u201cOther items\u201d re\ue61dected an increase of \u20ac42\nmillion in amounts due to institutional market operators,\nan increase of \u20ac156 million in liabilities for tax pa\ue61fnerships\nbeyond 12 months in the United States and an increase in\nliabilities relating to the outcome of the PIS/COFINS dis-\npute in Brazil (already discussed under \u201cOther non-current\nassets\u201d) in the amount of \u20ac766 million.\n",
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"concept": "ifrs-full:DisclosureOfOtherNoncurrentLiabilitiesExplanatory",
"language": "en",
"entity": "scheme:WOCMU6HCI0OJWNPRZS33",
"period": "2021-01-01T00:00:00/2022-01-01T00:00:00"
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"Tag33": {
"value": "\n42. Other current liabilities \u2013 \u20ac12,959 million\nMillions of euro\nat Dec. 31, 2021 at Dec. 31, 2020 Change\nAmounts due to customers 1,950 1,481 469 31.7%\nAmounts due to institutional market operators 2,961 4,012 (1,051) -26.2%\nAmounts due to employees 471 438 33 7.5 %\nOther tax liabilities 1,274 886 388 43.8%\nAmounts due to social security institutions 205 207 (2) -1.0%\nContingent consideration 45 53 (8) -15.1%\nPut options granted to non-controlling shareholders 4 1 3 -\nCurrent accrued expenses and deferred income 395 346 49 14.2%\nDividends 2,191 2,135 56 2.6%\nOther 3,463 2,092 1,371 65.5%\nTotal 12,959 11,651 1,308 11.2%\n\u201cAmounts due to customers\u201c include \u20ac1,169 million (\u20ac822 \nmillion at December 31, 2020) in security deposits related\nprimarily to amounts received from customers in Spain as\npa\ue61f of electricity and gas supply contracts. Following the\n\ue61enalization of the contract, deposits for electricity sales,\nthe use of which is not restricted in any way, are classi\ue61eed\nas current liabilities given that the Parent does not have an\nunconditional right to defer repayment beyond 12 months.\nAmounts due to institutional market operators include\nliabilities arising from the application of equalization\nmechanisms to electricity purchases on the Italian market\namounting to \u20ac1,976 million (\u20ac2,444 million at December\n31, 2020), on the Spanish market amounting to \u20ac938 mil-\nlion (\u20ac1,538 million at December 31, 2020) and on the Latin\nAmerican market amounting to \u20ac47 million (\u20ac30 million at\nDecember 31, 2020).\nThe increase in \u201cOther\u201d liabilities is mainly a\ue61cributable to\nItaly in respect of expired derivatives on energy commod-\nities.\nThe increase in \u201cOther tax liabilities\u201d is mainly a\ue61cributable\nto Italy following the sta\ue61f in 2021 of the Group se\ue61clement\nmechanism for VAT obligations by the Parent, Enel SpA.\n",
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"Tag34": {
"value": "\n43. Trade payables \u2013 \u20ac16,959 million\nThe item amounted to \u20ac16,959 million (\u20ac12,859 million at\nDecember 31, 2020) and includes payables in respect of\nelectricity supplies, fuel, materials, equipment associated\nwith tenders, and other services.\nMore speci\ue61ecally, trade payables falling due in less than 12\nmonths amounted to \u20ac16,865 million (\u20ac12,282 million at\nDecember 31, 2020), while those falling due in more than\n12 months amounted to \u20ac94 million (\u20ac577 million at De-\ncember 31, 2020).\n",
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"concept": "ifrs-full:DisclosureOfTradeAndOtherPayablesExplanatory",
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"Tag35": {
"value": "\n Consolidated \ue61enancial\nstatements\nFinancial instruments\n46. Financial instruments by category\nThis note provides disclosures necessary for users to\nassess the signi\ue61ecance of \ue61enancial instruments for the\nGroup\u2019s \ue61enancial position and pe\ue619ormance. \n46.1 Financial assets by category\nThe following table repo\ue61fs the carrying amount for each\ncategory of \ue61enancial asset provided for under IFRS 9, bro-\nken down into current and non-current \ue61enancial assets,\nshowing hedging derivatives and derivatives measured at\nfair value through pro\ue61et or loss separately.\nMillions of euro Non-current Current\nNotes\nat Dec. 31,\n2021\nat Dec. 31,\n2020\nat Dec. 31,\n2021\nat Dec. 31,\n2020\nFinancial assets at amo\ue61bized cost 46.1.1 4,092 3,966 34,671 22,967\nFinancial assets at FVOCI 46.1.2 443 448 87 67\nFinancial assets at fair value through pro\ue61ft or loss\nDerivative \ue61enancial assets at FVTPL 46.1.3 277 52 19,664 2,765\nOther \ue61enancial assets at FVTPL 46.1.3 2,662 2,087 141 301\nTotal \ue61fnancial assets at fair value through pro\ue61ft or loss 2,939 2,139 19,805 3,066\nDerivative \ue61fnancial assets designated as hedging instruments\nFair value hedge derivatives 46.1.4 61 50 - 28\nCash \ue61dow hedge derivatives 46.1.4 2,434 1,134 3,127 678\nTotal derivative \ue61fnancial assets designated as hedging instruments 2,495 1,184 3,127 706\nTOTAL 9,969 7,7 37 57,69 0 26,806\nFor more information on the recognition and classi\ue61ecation\nof current and non-current derivative assets, please see\nnote 49 \u201cDerivatives and hedge accounting\u201d.\nFor more information on fair value measurement, see note\n50 \u201cAssets and liabilities measured at fair value\u201d.\n46.1.1 Financial assets measured at amo\ue61eized cost\nThe following table repo\ue61fs \ue61enancial assets measured at\namo\ue61fized cost by nature, broken down into current and\nnon-current \ue61enancial assets.\nMillions of euro Non-current Current\nNotes\nat Dec. 31,\n2021\nat Dec. 31,\n2020 Notes\nat Dec. 31,\n2021\nat Dec. 31,\n2020\nCash and cash equivalents - - 34 8,759 5,702\nTrade receivables 33 1,301 1,200 33 14,775 10,846\nCurrent po\ue61fion of long-term loan assets - - 29.1 1,538 1,331\nCash collateral - - 29.1 6,485 3,223\nOther \ue61enancial assets 28.1 2,289 2,337 29.1 315 253\nFinancial assets from service concession arrangements at\namo\ue61fized cost\n28 260 243 29 64 9\nOther \ue61enancial assets at amo\ue61fized cost 242 186 2,735 1,603\nTotal 4,092 3,966 34,671 22,967\n\nImpairment of \ue61fnancial assets at amo\ue61eized cost\nFinancial assets measured at amo\ue61fized cost amounted to\n\u20ac38,763 million at December 31, 2021 (\u20ac26,933 million at\nDecember 31, 2020) and are recognized net of loss allow-\nances for expected credit losses totaling \u20ac4,051 million at\nDecember 31, 2021 (\u20ac3,624 million at the end of the pre-\nvious year).\nThe Group mainly has the following types of \ue61enancial as-\nsets measured at amo\ue61fized cost subject to impairment\ntesting:\n\u2022 cash and cash equivalents;\n\u2022 trade receivables and contract assets;\n\u2022 loan assets; \n\u2022 other \ue61enancial assets. \nWhile cash and cash equivalents are also subject to the\nimpairment requirements of IFRS 9, the identi\ue61eed impair-\nment loss was immaterial.\nThe expected credit loss (ECL) \u2013 determined using proba-\nbility of default (PD), loss given default (LGD) and exposure\nat default (EAD) \u2013 is the di\ue61berence between all contractual\ncash \ue61dows that are due in accordance with the contract and\nall cash \ue61dows that are expected to be received (i.e., all sho\ue61f-\nfalls) discounted at the original e\ue61bective interest rate (EIR).\nFor calculating ECL, the Group applies two di\ue61berent ap-\nproaches:\n\u2022 the general approach, for \ue61enancial assets other than \ntrade receivables, contract assets and lease receivables.\nThis approach, based on an assessment of any signif-\nicant increase in credit risk since initial recognition, is\npe\ue619ormed comparing PD at origination with PD at the\nrepo\ue61fing date, at each repo\ue61fing date.\n Then, based on the results of the assessment, a loss al-\nlowance is recognized based on 12-month ECL or life-\ntime ECL (i.e., staging):\n \u2013 12-month ECL, for \ue61enancial assets for which there \nhas not been a signi\ue61ecant increase in credit risk since\ninitial recognition;\n \u2013 lifetime ECL, for \ue61enancial assets for which there has \nbeen a signi\ue61ecant increase in credit risk or which are\ncredit impaired (i.e., defaulted based on past due in-\nformation);\n\u2022 the simpli\ue61eed approach, for trade receivables, contract \nassets and lease receivables with or without a signi\ue61e-\ncant \ue61enancing component, based on lifetime ECL with-\nout tracking changes in credit risk.\nA forward-looking adjustment can be applied considering\nqualitative and quantitative information in order to re\ue61dect\nfuture events and macroeconomic developments that\ncould impact the risk associated with the po\ue61ffolio or \ue61e-\nnancial instrument.\nDepending on the nature of the \ue61enancial assets and the\ncredit risk information available, the assessment of the in-\ncrease in credit risk can be pe\ue619ormed on:\n\u2022 an individual basis, if the receivables are individually sig-\nni\ue61ecant and for all receivables which have been individ-\nually identi\ue61eed for impairment based on reasonable and\nsuppo\ue61fable information; \n\u2022 a collective basis, if no reasonable and suppo\ue61fable infor-\nmation is available without undue cost or e\ue61bo\ue61f to meas-\nure expected credit losses on an individual instrument\nbasis.\nWhen there is no reasonable expectation of recovering a\n\ue61enancial asset in its entirety or a po\ue61fion thereof, the gross\ncarrying amount of the \ue61enancial asset shall be reduced.\nA write-o\ue61b represents a derecognition event (e.g., the right\nto cash \ue61dows is legally or contractually extinguished, trans-\nferred or expired).\nThe following table repo\ue61fs expected credit losses on \ue61e-\nnancial assets measured at amo\ue61fized cost on the basis of\nthe general simpli\ue61eed approach.\nMillions of euro at Dec. 31, 2021 at Dec. 31, 2020\nGross\namount\nLoss\nallowance\nfor\nexpected\ncredit losses Total\nGross\namount\nLoss\nallowance\nfor\nexpected\ncredit losses Total\nCash and cash equivalents 8,759 - 8,759 5,702 - 5,702\nTrade receivables 19,739 3,663 16,076 15,333 3,287 12,046\nLoan assets 10,861 234 10,627 7,352 208 7, 14 4\nOther \ue61enancial assets at amo\ue61fized cost 3,455 154 3,301 2,170 129 2,041\nTotal 42,814 4,051 38,763 30,557 3,624 26,933\nTo measure expected losses, the Group assesses trade\nreceivables and contract assets with the simpli\ue61eed ap-\nproach, both on an individual basis (e.g., government enti-\nties, authorities, \ue61enancial counterpa\ue61fies, wholesale sellers,\ntraders and large companies, etc.) and a collective basis\n(e.g., retail customers).\n\nIn the case of individual assessments, PD is generally ob-\ntained from external providers.\nOtherwise, in the case of collective assessments, trade re-\nceivables are grouped on the basis of their shared credit risk\ncharacteristics and information on past due positions, con-\nsidering a speci\ue61ec de\ue61enition of default.\nBased on each business and local regulatory framework, as\nwell as di\ue61berences between customer po\ue61ffolios, including\ntheir default and recovery rates (comprising expectations\nfor recovery beyond 90 days):\n\u2022 the Group mainly de\ue61enes a defaulted position as one that \nis 180 days past due. Accordingly, beyond this time lim-\nit, trade receivables are presumed to be credit impaired;\nand\n\u2022 speci\ue61ec clusters are de\ue61ened on the basis of speci\ue61ec mar-\nkets, business and risk characteristics.\nContract assets substantially have the same risk character-\nistics as trade receivables for the same types of contracts.\nIn order to measure ECL for trade receivables on a collective\nbasis, as well as for contract assets, the Group uses the fol-\nlowing assumptions regarding the ECL parameters:\n\u2022 PD, assumed equal to the average default rate, is calcu-\nlated by cluster and considering historical data from at\nleast 24 months;\n\u2022 LGD is a function of the recovery rates for each cluster, \ndiscounted using the e\ue61bective interest rate; and\n\u2022 EAD is estimated as equal to the carrying amount at the \nrepo\ue61fing date net of cash deposits, including invoices is-\nsued but not past due and invoices to be issued.\nThe following table repo\ue61fs changes in the loss allowance for\nexpected credit losses on loan assets in accordance with \nthe general approach.\nMillions of euro ECL 12-month allowance ECL lifetime allowance\nOpening balance at Jan. 1, 2020 78 153\nAccruals 354 8\nUses - -\nReversals to pro\ue61et or loss (4) (4)\nOther changes (363) (14)\nClosing balance at Dec. 31, 2020 65 143\nOpening balance at Jan. 1, 2021 65 143\nAccruals - 9\nUses - -\nReversals to pro\ue61et or loss (25) (9)\nOther changes 25 26\nClosing balance at Dec. 31, 2021 65 169\nThe following table repo\ue61fs changes in the loss allowance\nfor expected credit losses on trade receivables in accord-\nance with the simpli\ue61eed approach.\nMillions of euro\nOpening balance at Jan. 1, 2020 2,980\nAccruals 1,505\nUses (819)\nReversals to pro\ue61et or loss (194)\nOther changes (185)\nClosing balance at Dec. 31, 2020 3,287\nOpening balance at Jan. 1, 2021 3,287\nAccruals 1,361\nUses (709)\nReversals to pro\ue61et or loss (258)\nOther changes (18)\nClosing balance at Dec. 31, 2021 3,663\n\nThe following table repo\ue61fs changes in the loss allowance\nfor expected credit losses on other \ue61enancial assets at am-\no\ue61fized cost in accordance with the simpli\ue61eed approach.\nMillions of euro ECL lifetime allowance\nOpening balance at Jan. 1, 2020 159\nAccruals 22\nUses -\nReversals to pro\ue61et or loss (23)\nOther changes (29)\nClosing balance at Dec. 31, 2020 129\nOpening balance at Jan. 1, 2021 129\nAccruals 87\nUses -\nReversals to pro\ue61et or loss (21)\nOther changes (41)\nClosing balance at Dec. 31, 2021 154\nNote 47 \u201cRisk management\u201d provides additional informa-\ntion on the exposure to credit risk and expected losses.\n46.1.2 Financial assets at fair value through other\ncomprehensive income\nThe following table shows \ue61enancial assets at fair value\nthrough other comprehensive income by nature, broken\ndown into current and non-current \ue61enancial assets.\nMillions of euro Non-current Current\nNotes\nat Dec. 31,\n2021\nat Dec. 31,\n2020 Notes\nat Dec. 31,\n2021\nat Dec. 31,\n2020\nInvestments in other companies at FVOCI 28 40 40 - -\nSecurities 28.1 403 408 29.1 87 67\nTotal 443 448 87 67\nChanges in \ue61fnancial assets at FVOCI\nInvestments in other companies\nMillions of euro Non-current Current\nOpening balance at Jan. 1, 2020 64 -\nPurchases 6 -\nSales - -\nChanges in fair value through OCI (21) -\nOther changes (9) -\nClosing balance at Dec. 31, 2020 40 -\nOpening balance at Jan. 1, 2021 40 -\nPurchases 2 -\nSales - -\nChanges in fair value through OCI - -\nOther changes (2) -\nClosing balance at Dec. 31, 2021 40 -\n\nSecurities at FVOCI\nMillions of euro Non-current Current\nOpening balance at Jan. 1, 2020 416 61\nPurchases 124 -\nSales (54) -\nChanges in fair value through OCI (3) -\nReclassi\ue61ecations (75) 75\nOther changes - (69)\nClosing balance at Dec. 31, 2020 408 67\nOpening balance at Jan. 1, 2021 408 67\nPurchases 165 -\nSales (87) -\nChanges in fair value through OCI 2 -\nReclassi\ue61ecations (85) 85\nOther changes - (65)\nClosing balance at Dec. 31, 2021 403 87\n46.1.3 Financial assets at fair value through pro\ue61ft or loss\nThe following table shows \ue61enancial assets at fair value\nthrough pro\ue61et or loss by nature, broken down into current\nand non-current \ue61enancial assets.\nMillions of euro Non-current Current\nNotes\nat Dec. 31,\n2021\nat Dec. 31,\n2020 Notes\nat Dec. 31,\n2021\nat Dec. 31,\n2020\nDerivatives at FVTPL 49 277 52 49 19,664 2,765\nInvestments in liquid assets - - 34 99 204\nFinancial assets at FVTPL - - 29, 29.1 41 97\nSecurities - - 29.1 1 -\nEquity investments in other companies at FVTPL 28 32 30 - -\nFinancial assets from service concession arrangements at FVTPL 28 2,630 2,057 - -\nTotal 2,939 2,139 19,805 3,066\n46.1.4 Derivative \ue61fnancial assets designated as \nhedging instruments\nFor more information on derivative \ue61enancial assets, please\nsee note 49 \u201cDerivatives and hedge accounting\u201d.\n\n46.2 Financial liabilities by category\nThe following table shows the carrying amount for each\ncategory of \ue61enancial liability provided for under IFRS 9,\nbroken down into current and non-current \ue61enancial liabil-\nities, showing hedging derivatives and derivatives meas-\nured at fair value through pro\ue61et or loss separately.\nMillions of euro Non-current Current\nNotes\nat Dec. 31,\n2021\nat Dec. 31,\n2020\nat Dec. 31,\n2021\nat Dec. 31,\n2020\nFinancial liabilities measured at amo\ue61bized cost 46.2.1 54,914 50,254 42,330 29,598\nFinancial liabilities at fair value through pro\ue61ft or loss\nDerivative \ue61enancial liabilities at FVTPL 46.4 169 29 19,696 2,887\nTotal \ue61fnancial liabilities at fair value through pro\ue61ft or loss 169 29 19,696 2,887\nDerivative \ue61fnancial liabilities designated as hedging instruments\nFair value hedge derivatives 46.4 5 - - -\nCash \ue61dow hedge derivatives 46.4 3,165 3,577 4,911 644\nTotal derivative \ue61fnancial liabilities designated as hedging\ninstruments\n3,170 3,577 4,911 644\nTOTAL 58,253 53,860 66,937 33,129\nFor more information on fair value measurement, please\nsee note 50 \u201cAssets and liabilities measured at fair value\u201d.\n46.2.1 Financial liabilities measured at amo\ue61eized cost\nThe following table shows \ue61enancial liabilities at amo\ue61fized\ncost by nature, broken down into current and non-current\n\ue61enancial liabilities.\nMillions of euro Non-current Current\nNotes\nat Dec. 31,\n2021\nat Dec. 31,\n2020 Notes\nat Dec. 31,\n2021\nat Dec. 31,\n2020\nLong-term borrowings 46.3 54,500 49,519 46.3 4,031 3,168\nSho\ue61f-term borrowings - - 46.3 13,306 6,345\nTrade payables 43 94 577 43 16,865 12,282\nOther \ue61enancial liabilities 320 158 8,128 7, 8 03\nTotal 54,914 50,254 42,330 29,598\n\n46.3 Borrowings\n46.3.1 Long-term borrowings (including the po\ue61eion\nfalling due within 12 months) \u2013 \u20ac58,531 million\nThe following table repo\ue61fs the nominal value, carrying\namount and fair value of long-term borrowings including\nthe po\ue61fion falling due within 12 months.\nLong-term borrowings by category and type of interest rate\n(1)\nMillions of euro\n Nominal\nvalue\n Carrying\namount\nCurrent\npo\ue61bion\nPo\ue61bion\ndue in\nmore than\n12 months\nFair\nvalue\n Nominal\nvalue\n Carrying\namount\nCurrent\npo\ue61bion\nPo\ue61bion\ndue in\nmore\nthan 12\nmonths\nFair\nvalue\nChanges\nin\ncarrying\namount\n2021-\n2020\nat Dec. 31, 2021 at Dec. 31, 2020\nBonds:\n- listed, \ue61exed rate 27, 8 57 27,413 2,119 25,294 30,279 23,629 23,052 1,041 22,011 27,470 4,361\n- listed, \ue61doating\nrate\n2,574 2,557 434 2,123 2,545 2,817 2,800 260 2,540 2,937 (243)\n- unlisted, \ue61exed\nrate\n11,293 11,207 50 11,157 12,670 13,262 13,184 - 13,184 15,753 (1,977)\n- unlisted, \ue61doating\nrate\n622 622 97 525 728 733 733 111 622 828 (111)\nTotal bonds 42,346 41,799 2,700 39,099 46,222 40,441 39,769 1,412 38,357 46,988 2,030\nBank borrowings:\n- \ue61exed rate 2,414 2,405 238 2,167 2,298 790 782 254 528 833 1,623\n- \ue61doating rate 10,139 10,109 751 9,358 10,037 9,278 9,250 1,115 8,135 9,259 859\n- use of revolving\ncredit lines\n1,054 1,054 - 1,054 1,054 - - - - - 1,054\nTotal bank\nborrowings\n13,607 13,568 989 12,579 13,389 10,068 10,032 1,369 8,663 10,092 3,536\nLeases:\n- \ue61exed rate 2,477 2,477 242 2,235 2,477 1,979 1,979 225 1,754 1,979 498\n- \ue61doating rate 70 70 17 53 70 89 89 22 67 89 (19)\nTotal leases 2,547 2,547 259 2,288 2,547 2,068 2,068 247 1,821 2,068 479\nOther non-bank\nborrowings:\n- \ue61exed rate 571 595 69 526 569 607 639 74 565 630 (44)\n- \ue61doating rate 34 22 14 8 25 191 179 66 113 160 (157)\nTotal other non-\nbank borrowings\n605 617 83 534 594 798 818 140 678 790 (201)\nTotal \ue61fxed-rate\nborrowings\n44,612 44,097 2,718 41,379 48,293 40,267 39,636 1,594 38,042 46,665 4,461\nTotal \ue61doating-rate\nborrowings\n14,493 14,434 1,313 13,121 14,459 13,108 13,051 1 ,574 11,477 13,273 1,383\nTOTAL 59,105 58,531 4,031 54,500 62,752 53,375 52,687 3,168 49,519 59,938 5,844\n(1) Does not include other non-current \ue61enancial borrowings repo\ue61fed under \u201cOther non-current \ue61enancial liabilities\u201d in the statement of \ue61enancial position that\nare included in long-term \ue61enancial debt.\n\nThe table below repo\ue61fs long-term \ue61enancial debt by cur-\nrency and interest rate.\nLong-term \ue61fnancial debt by currency and interest rate\n(1)\nMillions of euro\nCarrying\namount\nNominal\nvalue\nCarrying\namount\nNominal\nvalue\nCurrent\naverage\nnominal\ninterest rate\nCurrent\ne\ue61cective\ninterest\nrate\nCurrent\naverage\nnominal\ninterest rate\nCurrent\ne\ue61cective\ninterest\nrate\nat Dec. 31, 2021 at Dec. 31, 2020 at Dec. 31, 2021 at Dec. 31, 2020\nEuro 32,041 32,387 25,581 26,089 1.6% 1.9% 2.2% 2.6%\nUS dollar 17,51 8 17,62 9 18,500 18,589 4.2% 4.3% 4.5% 4.7%\nPound sterling 3,901 3,976 3,955 3,998 5.0% 5.2% 5.1% 5.3%\nColombian peso 1,341 1,341 1,283 1,283 6.5% 6.5% 6.8% 6.8%\nBrazilian real 1,720 1,753 1,832 1,864 8.8% 8.9% 5.3% 5.3%\nSwiss franc 343 344 328 329 1.8% 1.8% 1.8% 1.8%\nChilean peso/UF 423 428 368 374 5.2% 5.2% 4.9% 5.0%\nPeruvian sol 415 415 388 388 5.2% 5.2% 5.8% 5.8%\nRussian ruble 427 427 281 286 6.8% 7.3 % 7. 1 % 7. 1 %\nOther currencies 402 405 171 175\nTotal non-euro currencies 26,490 26,718 27, 10 6 27, 286\nTOTAL 58,531 59,105 52,687 53,375\n(1) Does not include other non-current \ue61enancial borrowings repo\ue61fed under \u201cOther non-current \ue61enancial liabilities\u201d in the statement of \ue61enancial position.\nLong-term \ue61enancial debt denominated in currencies other\nthan the euro decreased by \u20ac616 million, largely a\ue61cributa-\nble to the changes in debt denominated in US dollars.\nChange in the nominal value of long-term debt\n(1)\nMillions of euro Nominal value Repayments\nChange in the\nconsolidation\nscope\nNew\nborrowings Other changes\nExchange\ndi\ue61cerences Nominal value\nat Dec. 31,\n2020\nat Dec. 31,\n2021\nBonds 40,441 (9,049) - 10,368 (900) 1,486 42,346\nBorrowings 12,934 (2,272) 183 5,527 (131) 518 16,759\n- of which leases 2,068 (165) 2 526 - 116 2,547\nTotal \ue61fnancial debt 53,375 (11,321) 183 15,895 (1,031) 2,004 59,105\n(1) Does not include changes in the nominal value of other non-current \ue61enancial borrowings repo\ue61fed under \u201cOther non-current \ue61enancial liabilities\u201d in the\nstatement of \ue61enancial position.\n\nThe nominal value of long-term debt amounted to \u20ac59,105\nmillion at December 31, 2021, an increase of \u20ac5,730 mil-\nlion compared with December 31, 2020. The increase in\ndebt re\ue61dected new borrowings of \u20ac15,895 million, ex-\nchange losses of \u20ac2,004 million and the consolidation of\nthe debt of a number of Australian companies amounting\nto \u20ac183 million. These factors were only pa\ue61fially o\ue61bset by\nrepayments of \u20ac11,321 million and other changes in the\ndebt equal to \u20ac1,031 million, of which \u20ac900 million were\na\ue61cributable to the change in the accounting treatment\nof non-conve\ue61fible subordinated hybrid bonds in euros\nissued by Enel SpA and conve\ue61fed into perpetual hybrid\nbonds in 2021.\nRepayments in 2021 involved bonds in the amount of\n\u20ac9,049 million and loans in the amount of \u20ac2,272 million.\nSpeci\ue61ecally, repayments in 2021 included:\n\u2022 \u20ac1,069 million in respect of the repurchase and subse-\nquent cancellation of pa\ue61f of four series of convention-\nal bonds in euros by Enel Finance International in June\n2021 through a non-binding voluntary tender o\ue61ber;\n\u2022 $6,000 million (equivalent to \u20ac5,101 million at the repay-\nment date) in respect of the cash repurchase of four\nconventional bonds denominated in US dollars by Enel\nFinance International in July 2021 following the exercise\nof a repurchase option;\n\u2022 $1,472 million (equivalent to \u20ac1,275 million at the repay-\nment date) in respect of the repurchase and subsequent \ncancellation of pa\ue61f of two series of conventional bonds\ndenominated in US dollars by Enel Finance International\nin October 2021 through a voluntary non-binding tender\no\ue61ber;\n\u2022 \u20ac533 million in respect of \ue61exed-rate bonds issued by Enel \nFinance International, maturing in July 2021;\n\u2022 the equivalent of \u20ac292 million in respect of hybrid bonds \ndenominated in British pounds issued by Enel SpA, matur-\ning in September 2021;\n\u2022 the equivalent of \u20ac171 million in respect of the repayment \nof bonds in local currency by Emgesa, maturing in January\n2021;\n\u2022 the equivalent of \u20ac114 million in respect of the repayment \nof bonds in local currency by Enel Distribui\u00e7\u00e3o S\u00e3o Paulo,\nmaturing in September 2021.\nThe main repayments of loans made during the year included:\n\u2022 \u20ac200 million in respect of a \ue61doating-rate loan of Enel SpA;\n\u2022 the equivalent of \u20ac196 million in respect of a \ue61doating-rate \nloan in US dollars of Enel SpA;\n\u2022 \u20ac178 million in respect of Endesa loans, of the which \u20ac166 \nmillion in sustainable loans;\n\u2022 \u20ac294 million in respect of sustainable loans of the Group\u2019s \nItalian companies;\n\u2022 the equivalent of \u20ac1,019 million relating to South American \ncompanies.\nNew borrowings in 2021 involved \u20ac10,368 million in bonds\nand \u20ac5,527 million in loans.\nThe table below shows the main characteristics of \ue61enancial\ntransactions carried out in 2021 and translated into euros at\nthe exchange rate prevailing at December 31, 2021.\n\nIssuer/Borrower\nIssue/\nGrant date\nAmount\nin\nmillions\nof euro Currency Interest rate\nInterest rate\ntype Maturity\nBonds\nEnel Finance International 17.06.2021 1,000 EUR 0.00% Fixed rate 17.06.2027\nEnel Finance International 17.06.2021 1,250 EUR 0.50% Fixed rate 17.06.2030\nEnel Finance International 17.06.2021 1,000 EUR 0.875% Fixed rate 17.06.2036\nEnel Finance International 12.07.2021 1,104 USD 1.375% Fixed rate 12.07.2026\nEnel Finance International 12.07.2021 883 USD 1.875% Fixed rate 12.07.2028\nEnel Finance International 12.07.2021 883 USD 2.250% Fixed rate 12.07.2031\nEnel Finance International 12.07.2021 662 USD 2.875% Fixed rate 12.07.2041\nEnel Finance International 28.09.2021 1,250 EUR - Fixed rate 28.05.2026\nEnel Finance International 28.09.2021 1,000 EUR 0.375% Fixed rate 28.05.2029\nEnel Finance International 28.09.2021 1,250 EUR 0.875% Fixed rate 28.09.2034\nEnel Distribui\u00e7\u00e3o S\u00e3o Paulo 30.04.2021 114 BRL IPCA + 4.26% Floating rate 15.04.2031\nEnel Distribui\u00e7\u00e3o S\u00e3o Paulo 04.10.2021 91 BRL CDI + 1.64% a.a Floating rate 04.10.2028\nTotal bonds 10,487\nBank borrowings\nEnel SpA 05.05.2021 200 EUR Euribor 6M + 0.3% Floating rate 03.05.2024\nEnel SpA 12.10.2021 308 USD\nUSD SOFR 3M\nCMP 5LB + 0.7%\nFloating rate 12.10.2025\nEnel SpA 30.12.2021 1,000 EUR Euribor 6M + 0.4% Floating rate 05.03.2026\ne-distribuzione 30.07.2021 150 EUR\nEuribor 6M +\n0.257%\nFloating rate 30.07.2036\ne-distribuzione 22.12.2021 150 EUR\nEuribor 6M +\n0.275%\nFloating rate 22.12.2036\nEndesa 15.04.2021 150 EUR\nEuribor 3M +\n0.82%\nFloating rate 18.04.2028\nEndesa 28.06.2021 75 EUR 0.27% Fixed rate 28.06.2028\nEndesa 30.07.2021 75 EUR 0.26% Fixed rate 30.07.2028\nEndesa 30.07.2021 50 EUR 0.26% Fixed rate 30.07.2028\nEndesa 15.10.2021 125 EUR 0.09% Fixed rate 15.10.2026\nEndesa 15.10.2021 75 EUR 0.11% Fixed rate 15.10.2026\nEndesa 27.10.2021 100 EUR 0.25% Fixed rate 27.10.2028\nEndesa 22.11.2021 250 EUR\nEuribor 6M +\n0.313%\nFloating rate 22.11.2036\nEndesa 09.12.2021 275 EUR 0.00% Fixed rate 09.12.2024\nEndesa 17.12.2021 225 EUR 0.156% Fixed rate 17.12.2024\nEnel Distribui\u00e7\u00e3o Cear\u00e1 06.01.2021 69 USD 1.225% Fixed rate 06.01.2023\nEnel Distribui\u00e7\u00e3o S\u00e3o Paulo 19.04.2021 74 USD 1 .974% Fixed rate 19.04.2024\nEnel Distribui\u00e7\u00e3o S\u00e3o Paulo 09.09.2021 68 USD 2.365% Fixed rate 09.09.2025\nCodensa 14.05.2021 87 COP\nCOP IBR 3M +\n0.75%\nFloating rate 14.05.2026\nCodensa 15.07.2021 65 COP\nCOP IBR 6M +\n0.5%\nFloating rate 15.07.2026\nCodensa 30.11.2021 56 COP\nCOP IBR 3M +\n0.085%\nFloating rate 30.11.2026\nEnel Chile 03.12.2021 132 USD\nUSD LIBOR +\n1.10%\nFloating rate 03.12.2026\nEnel Brasil 15.09.2021 61 USD 1.91% Fixed rate 16.09.2024\nTotal bank borrowings 3,820\n\nThe following table repo\ue61fs the impact on gross long-term\ndebt of hedges to mitigate currency risk.\nStructure of long-term \ue61fnancial debt by currency after hedging\n(1)\nMillions of\neuro at Dec. 31, 2021 at Dec. 31, 2020\nInitial debt structure\nImpact of\nhedge\nDebt structure after\nhedging Initial debt structure\nImpact of\nhedge\nDebt structure after\nhedging\nCarrying\namount\nNominal\nvalue %\nCarrying\namount\nNominal\nvalue %\nEuro 32,041 32,387 54.8% 16,657 49,044 83.0% 25,581 26,089 48.9% 18,423 44,512 83.4%\nUS dollar 17,51 8 17,6 2 9 29.8% (13,423) 4,206 7. 1 % 18,500 18,589 34.8% (14,955) 3,634 6.8%\nPound sterling 3,901 3,976 6.7% (3,976) - - 3,955 3,998 7.5 % (3,998) - -\nColombian\npeso\n1,341 1,341 2.3% - 1,341 2.3% 1,283 1,283 2.4% - 1,283 2.4%\nBrazilian real 1,720 1,753 3.0% 1,028 2,781 4.7% 1,832 1,864 3.5% 794 2,658 5.0%\nSwiss franc 343 344 0.6% (344) - - 328 329 0.6% (329) - -\nChilean peso/\nUF\n423 428 0.7% - 428 0.7% 368 374 0.7% - 374 0.7%\nPeruvian sol 415 415 0.7% - 415 0.7% 388 388 0.7% - 388 0.7%\nRussian ruble 427 427 0.7% - 427 0.7% 281 286 0.5% - 286 0.5%\nOther\ncurrencies\n402 405 0.7% 58 463 0.8% 171 175 0.4% 65 240 0.5%\nTotal\nnon-euro\ncurrencies\n26,490 26,718 45.2% (16,657) 10,061 17. 0 % 27, 10 6 27, 286 51.1% (18,423) 8,863 16.6%\nTOTAL 58,531 59,105 100.0% - 59,105 100.0% 52,687 53,375 100.0% - 53,375 100.0%\n(1) Does not include other non-current \ue61enancial borrowings repo\ue61fed under \u201cOther non-current \ue61enancial liabilities\u201d in the statement of \ue61enancial position.\nThe amount of \ue61doating-rate debt that is not hedged\nagainst interest rate risk is the main risk factor that could\nadversely impact pro\ue61et or loss (raising borrowing costs) in\nthe event of an increase in market interest rates. \nMillions of euro 2021 2020\nPre-hedge % Post-hedge % Pre-hedge % Post-hedge %\nFloating rate 27,811 38.4% 22,478 31.0% 19,458 32.6% 13,672 22.9%\nFixed rate 44,612 61.6% 49,945 69.0% 40,267 67.4% 46,053 77.1%\nTotal 72,423 72,423 59,725 59,725\nAt December 31, 2021, 38.4% of \ue61enancial debt was \ue61doat-\ning rate (32.6% at December 31, 2020). Taking account of\nhedges of interest rates considered e\ue61bective pursuant to\nthe IFRS-EU, 31.0% of net \ue61enancial debt at December 31,\n2021 (22.9% at December 31, 2020) was exposed to inter-\nest rate risk. These \ue61egures are in line with the limits estab-\nlished in the risk management policy.\nThe following table shows the impact of the IBOR reform\non long-term \ue61enancial debt for the main indices (for more\ndetails, please see the section \u201cReform of benchmarks for\nthe determination of interest rates - IBOR reform\u201d in note\n49.1).\nMillions of euro Notional amount\nat Dec. 31, 2021\nLong-term \ue61fnancial debt Phase 1 Phase 2\nUSD LIBOR/SOFR 888 -\nGBP LIBOR/SONIA - -\nTotal 888 - \n\nLong-term debt - Main covenants \nThe Group\u2019s main long-term \ue61enancial liabilities are gov-\nerned by covenants that are commonly adopted in inter-\nnational business practice. These liabilities primarily re-\ngard bond issues carried out within the framework of the\nGlobal/Euro Medium Term Notes program, issues of sub-\nordinated unconve\ue61fible hybrid bonds (so-called \u201chybrid\nbonds\u201d) and loans granted by banks and other \ue61enancial\ninstitutions (including the European Investment Bank and\nCassa Depositi e Prestiti SpA).\nThe main covenants regarding bond issues carried out\nwithin the framework of the Global/Euro Medium Term \nNotes program of Enel and Enel Finance International NV\n(including the green bonds of Enel Finance International\nNV guaranteed by Enel SpA, which are used to \ue61enance the\nGroup\u2019s so-called \u201celigible green projects\u201c) and those re-\ngarding bonds issued by Enel Finance International NV on\nthe US market guaranteed by Enel SpA can be summarized\nas follows:\n\u2022 negative pledge clauses under which the issuer and \nthe guarantor may not establish or maintain mo\ue61fgages,\nliens or other encumbrances on all or pa\ue61f of its assets\nor revenue to secure ce\ue61fain \ue61enancial liabilities, unless\nthe same encumbrances are extended equally or pro\nrata to the bonds in question;\n\u2022 pari passu clauses, under which the bonds and the as-\nsociated security constitute a direct, unconditional and\nunsecured obligation of the issuer and the guarantor\nand are issued without preferential rights among them\nand have at least the same seniority as other present\nand future unsubordinated and unsecured bonds of the\nissuer and the guarantor;\n\u2022 cross-default clauses, under which the occurrence of a \ndefault event in respect of a speci\ue61eed \ue61enancial liability\n(above a threshold level) of the issuer, the guarantor or,\nin some cases, \u201csigni\ue61ecant\u201d subsidiaries, constitutes a\ndefault in respect of the liabilities in question, which be-\ncome immediately repayable.\nSince 2019, Enel Finance International NV has issued a\nnumber of \u201csustainable\u201d bonds on the European market (as\npa\ue61f of the Euro Medium Term Notes - EMTN bond issue\nprogram) and on the American market, both guaranteed\nby Enel SpA, linked to the achievement of a number of the\nSustainable Development Goals (SDGs) of the United Na-\ntions that contain the same covenants as other bonds of\nthe same type.\nThe main covenants covering Enel\u2019s hybrid bonds, includ-\ning the perpetual hybrid bond issues, which will only be\nrepaid in the event of the dissolution or liquidation of the\nCompany, can be summarized as follows:\n\u2022 subordination clauses, under which each hybrid bond is \nsubordinate to all other bonds issued by the company\nand has the same seniority with all other hybrid \ue61enancial\ninstruments issued, being senior only to equity instru-\nments;\n\u2022 prohibition on mergers with other companies, the sale \nor leasing of all or a substantial pa\ue61f of the company\u2019s\nassets to another company, unless the la\ue61cer succeeds\nin all obligations of the issuer.\nThe main covenants envisaged in the loan contracts\nof Enel and Enel Finance International NV and the other\nGroup companies, including the sustainability-linked loan\nfacility agreements obtained by Enel SpA, can be summa-\nrized as follows:\n\u2022 negative pledge clauses, under which the borrower and, \nin some cases, the guarantor are subject to limitations on\nthe establishment of mo\ue61fgages, liens or other encum-\nbrances on all or pa\ue61f of their respective assets, with the\nexception of expressly permi\ue61ced encumbrances;\n\u2022 disposals clauses, under which the borrower and, in \nsome cases, the guarantor may not dispose of their as-\nsets or operations, with the exception of expressly per-\nmi\ue61ced disposals;\n\u2022 pari passu clauses, under which the payment unde\ue61fak-\nings of the borrower have the same seniority as its other\nunsecured and unsubordinated payment obligations;\n\u2022 change of control clauses, under which the borrower \nand, in some cases, the guarantor could be required to\nrenegotiate the terms and conditions of the \ue61enancing or\nmake compulsory early repayment of the loans granted;\n\u2022 rating clauses, which provide for the borrower or the \nguarantor to maintain their rating above a ce\ue61fain spec-\ni\ue61eed level;\n\u2022 cross-default clauses, under which the occurrence of a \ndefault event in respect of a speci\ue61eed \ue61enancial liability\n(above a threshold level) of the issuer or, in some cases,\nthe guarantor constitutes a default in respect of the lia-\nbilities in question, which become immediately repayable.\nIn some cases, the covenants are also binding for the sig-\nni\ue61ecant companies or subsidiaries of the obligated pa\ue61fies.\nAll the borrowings considered specify \u201cevents of default\u201d\ntypical of international business practice, such as, for ex-\nample, insolvency, bankruptcy proceedings or the entity\nceasing trading.\nIn addition, the guarantees issued by Enel in the interest\nof e-distribuzione SpA for ce\ue61fain loans to e-distribuzi-\none SpA from Cassa Depositi e Prestiti SpA require that\nat the end of each six-month measurement period Enel\u2019s\nnet consolidated \ue61enancial debt shall not exceed 4.5 times\nannual consolidated gross operating pro\ue61et.\n\nFinally, the debt of Endesa SA, Enel Am\u00e9ricas SA, Enel Chile\nSA and the other Spanish and Latin American subsidiaries\n(notably Enel Generaci\u00f3n Chile SA) contain covenants and\nevents of default typical of international business practice.\n46.3.2 Sho\ue61e-term borrowings \u2013 \u20ac13,306 million\nAt December 31, 2021 sho\ue61f-term borrowings totaled\n\u20ac13,306 million, an increase of \u20ac6,961 million compared\nwith December 31, 2020, and break down as follows:\nMillions of euro\nat Dec. 31, 2021 at Dec. 31, 2020 Change \nSho\ue61f-term bank borrowings 1,329 711 618\nCommercial paper 10,708 4,854 5,854\nCash collateral and other \ue61enancing on derivatives 918 370 548\nOther sho\ue61f-term borrowings\n(1)\n351 410 (59)\nSho\ue61b-term borrowings 13,306 6,345 6,961\n(1) Does not include other current borrowings included in \u201cOther current \ue61enancial liabilities\u201d of the statement of \ue61enancial position included in \ue61enancial debt.\nCommercial paper liabilities totaling \u20ac10,708 million con-\ncerned issues by Enel Finance International, Enel Finance\nAmerica and Endesa.\nThe main commercial paper programs include:\n\u2022 \u20ac6,000 million of Enel Finance International linked to \nsustainability objectives;\n\u2022 \u20ac4,000 million of Endesa linked to sustainability objec-\ntives;\n\u2022 $5,000 million (equivalent to \u20ac4,414 million at Decem-\nber 31, 2021) of Enel Finance America linked to sustain-\nability objectives. During 2021, Enel Finance America\nexpanded its commercial paper program from $3,000\nmillion to $5,000 million.\nAt December 31, 2021 commercial paper issues linked to\nsustainability objectives amounted to \u20ac10,343 million.\n46.4 Derivative \ue61fnancial liabilities\nFor more information on derivative \ue61enancial liabilities,\nplease see note 49 \u201cDerivatives and hedge accounting\u201d.\n46.5 Net gains and losses\nThe following table shows net gains and losses by category\nof \ue61enancial instruments, excluding derivatives.\nMillions of euro 2021 2020\nNet gain/(loss)\nOf which\nimpairment\nloss/gain Net gain/(loss)\nOf which\nimpairment\nloss/gain\nFinancial assets at amo\ue61bized cost (915) (1,194) (1,326) (1,334)\nFinancial assets at FVOCI\nEquity investments at FVOCI - - 1 -\nOther \ue61enancial assets at FVOCI 15 - 6 -\nTotal \ue61fnancial assets at FVOCI 15 - 7 -\nFinancial assets at FVTPL\nFinancial assets at FVTPL 28 25 (125) (346)\nFinancial assets designated upon initial recognition (fair value option) - - - -\nTotal \ue61fnancial assets at FVTPL 28 25 (125) (346)\nFinancial liabilities measured at amo\ue61bized cost (4,325) - (1,385) -\nFinancial liabilities at FVTPL\nFinancial liabilities held for trading - - - -\nFinancial liabilities designated upon initial recognition (fair value option) - - - -\nTotal \ue61fnancial liabilities at FVTPL - - - -\nFor more details on net gains and losses on derivatives,\nplease see note 13 \u201cNet \ue61enancial income/(expense) from\nderivatives\u201d.\n\n45. Net \ue61fnancial position and long-term \ue61fnancial assets and securities \u2013 \n\u20ac51,952 million\nThe following table shows the net \ue61enancial position and\nlong-term \ue61enancial assets and securities on the basis of\nthe items on the statement of consolidated \ue61enancial po-\nsition.\nMillions of euro\nNotes at Dec. 31, 2021 at Dec. 31, 2020 Change\nLong-term borrowings 37 54,500 49,519 4,981 10.1%\nOther non-current \ue61enancial borrowings\n(1)\n40 120 - 120 -\nSho\ue61f-term borrowings 37 13,306 6,345 6,961 -\nOther current \ue61enancial borrowings\n(2)\n12 5 7 -\nCurrent po\ue61fion of long-term borrowings 37 4,031 3,168 863 27. 2%\nOther non-current \ue61enancial assets included in net \ue61enancial debt 28.1 (2,692) (2,745) 53 1.9%\nOther current \ue61enancial assets included in net \ue61enancial debt 29.1 (8,467) (4,971) (3,496) -70.3%\nCash and cash equivalents 34 (8,858) (5,906) (2,952) -50.0%\nTotal 51,952 45,415 6,537 14.4%\n(1) The item \u201cOther non-current \ue61enancial borrowings\u201d is represented by \u201cOther non-current \ue61enancial liabilities\u201d in the statement of \ue61enancial position.\n(2) The item \u201cOther current \ue61enancial borrowings\u201d is included under \u201cOther current \ue61enancial liabilities\u201d in the statement of \ue61enancial position.\nThe net \ue61enancial debt of the Enel Group at December 31,\n2021 and December 31, 2020 is repo\ue61fed below in accord-\nance with Guideline 39, issued on March 4, 2021, by ESMA,\napplicable as from May 5, 2021, and with warning notice\nno. 5/2021 issued by CONSOB on April 29, 2021, recon-\nciled with net \ue61enancial debt as provided for in the pres-\nentation methods of the Enel Group.\nThe references to the CESR Recommendations contained\nin previous CONSOB communications shall be considered\nto have been replaced by references to the ESMA Guide-\nline cited above, including the references in Communica-\ntion no. DEM/6064293 of July 28, 2006 regarding the net\n\ue61enancial position.\n\nMillions of euro\nat Dec. 31, 2021 at Dec. 31, 2020 Change\nLiquidity\nCash and cash equivalents on hand 8 42 (34) -81.0%\nBank and post o\ue61ace deposits 8,118 5,699 2,419 42.4%\nLiquid assets 8,126 5,741 2,385 41.5%\nCash equivalents 732 165 567 -\nSecurities 88 67 21 31.3%\nSho\ue61f-term loan assets 6,841 3,476 3,365 96.8%\nCurrent po\ue61fion of long-term loan assets 1,538 1,428 110 7.7 %\nOther current \ue61fnancial assets 8,467 4,971 3,496 70.3%\nLiquidity 17, 3 2 5 10,877 6,448 59.3%\nCurrent \ue61enancial debt\nBank debt (1,329) (711) (618) -86.9%\nCommercial paper (10,708) (4,854) (5,854) -\nOther sho\ue61f-term borrowings\n(1)\n(1,281) (785) (496) -63.2%\nCurrent \ue61fnancial debt (including debt instruments) (13,318) (6,350) (6,968) -\nCurrent po\ue61fion of long-term bank borrowings (989) (1,369) 380 27.8 %\nBonds issued (current po\ue61fion) (2,700) (1,412) (1,288) -91.2%\nOther borrowings (current po\ue61fion) (342) (387) 45 11.6%\nNon-current \ue61fnancial debt (current po\ue61bion) (4,031) (3,168) (863) -2 7. 2 %\nCurrent \ue61fnancial debt (17,349) (9,518) (7,831) -82.3%\nNet current \ue61fnancial debt (24) 1,359 (1,383) -\nNon-current \ue61enancial debt\nBank borrowings (12,579) (8,663) (3,916) -45.2%\nOther borrowings\n(2)\n(2,942) (2,499) (443) -17.7 %\nNon-current \ue61fnancial debt (excluding current po\ue61bion and debt\ninstruments)\n(15,521) (11,162) (4,359) -39.1%\nBonds (39,099) (38,357) (742) -1.9%\nTrade payables and other non-interest-bearing non-current liabilities with a\nsigni\ue61ecant \ue61enancing component\n- - - -\nNon-current \ue61fnancial debt (54,620) (49,519) (5,101) -10.3%\nNet \ue61fnancial debt as per CONSOB instructions (54,644) (48,160) (6,484) -13.5%\nLong-term \ue61enancial assets and securities 2,692 2 ,745 (53) -1.9%\nNET FINANCIAL DEBT (51,952) (45,415) (6,537) -14.4%\n(1) Includes current \ue61enancial borrowings included in \u201cOther current \ue61enancial liabilities\u201d in the statement of \ue61enancial position.\n(2) Includes other non-current \ue61enancial borrowings presented under \u201cOther non-current \ue61enancial liabilities\u201d in the statement of \ue61enancial position.\nThis statement of the net \ue61enancial position does not in-\nclude \ue61enancial assets and liabilities in respect of deriva-\ntives, since derivative contracts, even if not designated as\nhedges for hedge accounting purposes, are in any case\nentered into by the Group for hedging purposes.\nAt December 31, 2021, those \ue61enancial assets and liabili-\nties are repo\ue61fed separately in the statement of \ue61enancial\nposition under the following items: \u201cNon-current \ue61enancial\nderivative assets\u201d in the amount of \u20ac2,772 million (\u20ac1,236\nmillion at December 31, 2020), \u201cCurrent \ue61enancial derivative\nassets\u201d in the amount of \u20ac22,791 million (\u20ac3,471 million at\nDecember 31, 2020), \u201cNon-current \ue61enancial derivative lia-\nbilities\u201d in the amount of \u20ac3,339 million (\u20ac3,606 million at\n31 December, 2020) and \u201cCurrent \ue61enancial derivative lia-\nbilities\u201d in the amount of \u20ac24,607 million (\u20ac3,531 million at\nDecember 31, 2020).\n",
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"period": "2021-01-01T00:00:00/2022-01-01T00:00:00"
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"value": "\n47. Risk management\nFinancial risk management governance and\nobjectives\nAs pa\ue61f of its operations, the Enel Group is exposed to a va-\nriety of \ue61enancial risks, notably interest rate risk, commodity\nrisk, currency risk, credit and counterpa\ue61fy risk and liquidity\nrisk.\nThe Group\u2019s governance arrangements for \ue61enancial risks\ninclude internal commi\ue61cees and the establishment of spe-\nci\ue61ec policies and operational limits. Enel\u2019s primary objec-\ntive is to mitigate \ue61enancial risks appropriately so that they\ndo not give rise to unexpected changes in results.\nThe Group\u2019s policies for managing \ue61enancial risks provide\nfor the mitigation of the e\ue61bects on pe\ue619ormance of chang-\nes in interest rates and exchange rates with the exclusion\nof translation risk (connected with consolidation of the\naccounts). This objective is achieved at the source of the\nrisk, through the diversi\ue61ecation of both the nature of the\n\ue61enancial instruments and the sources of revenue, and by\nmodifying the risk pro\ue61ele of speci\ue61ec exposures with deriv-\natives entered into on over-the-counter markets or with\nspeci\ue61ec commercial agreements.\nAs pa\ue61f of its governance of compliance risks, the Enel\nGroup monitors non-risk-reducing positions in OTC de-\nrivatives contracts in relation to the threshold values es-\ntablished under the EMIR (Regulation (EU) no. 648/2012)\nfor the various asset classes. In 2021, the Group was posi-\ntioned below those clearing thresholds for all asset class-\nes, maintaining its classi\ue61ecation as a non-\ue61enancial coun-\nterpa\ue61fy.\nThere were no changes in the sources of exposure to such\nrisks compared with the previous year.\nFinally, the impact of COVID-19 on risk management is-\nsues was limited and in any case not such as to directly and\nmaterially in\ue61duence the valuation of derivative instruments\nand the outcome of the assessment of the e\ue61bectiveness of\nhedges of exchange rates, interest rates and commodities.\nThe \ue61enancial underlyings were not a\ue61bected by the adverse\nimpact of COVID-19 either, and no changes were recorded\nin the exposures.\nInterest rate risk\nInterest rate risk derives primarily from the use of \ue61enancial\ninstruments and manifests itself as unexpected changes\nin charges on \ue61enancial liabilities, if indexed to \ue61doating rates\nand/or exposed to the unce\ue61fainty of \ue61enancial terms and\nconditions in negotiating new debt instruments, or as an\nunexpected change in the value of \ue61enancial instruments\nmeasured at fair value (such as \ue61exed-rate debt).\nThe main \ue61enancial liabilities held by the Group include\nbonds, bank borrowings, borrowings from other lenders,\ncommercial paper, derivatives, cash deposits received to\nsecure commercial or derivative contracts (guarantees,\ncash collateral).\nThe Enel Group mainly manages interest rate risk through\nthe de\ue61enition of an optimal \ue61enancial structure, with the\ndual goal of stabilizing borrowing costs and containing the\ncost of funds.\nThis goal is pursued through the diversi\ue61ecation of the po\ue61f-\nfolio of \ue61enancial liabilities by contract type, maturity and\ninterest rate, and modifying the risk pro\ue61ele of speci\ue61ec ex-\nposures using OTC derivatives, mainly interest rate swaps\nand interest rate options. The term of such derivatives\ndoes not exceed the maturity of the underlying \ue61enancial li-\nability, so that any change in the fair value and/or expected\ncash \ue61dows of such contracts is o\ue61bset by a corresponding\nchange in the fair value and/or cash \ue61dows of the hedged\nposition.\nProxy hedging techniques can be used in a number of re-\nsidual circumstances, when the hedging instruments for\nthe risk factors are not available on the market or are not\nsu\ue61aciently liquid.\nFor the purpose of EMIR compliance, in order to test the\nactual e\ue61bectiveness of the hedging techniques adopted,\nthe Group subjects its hedge po\ue61ffolios to periodic statis-\ntical assessment.\nUsing interest rate swaps, the Enel Group agrees with the\ncounterpa\ue61fy to periodically exchange \ue61doating-rate in-\nterest \ue61dows with \ue61exed-rate \ue61dows, both calculated on the\nsame notional principal amount.\nFloating-to-\ue61exed interest rate swaps transform \ue61doat-\ning-rate \ue61enancial liabilities into \ue61exed rate liabilities, there-\nby neutralizing the exposure of cash \ue61dows to changes in\ninterest rates.\nFixed-to-\ue61doating interest rate swaps transform \ue61exed rate\n\ue61enancial liabilities into \ue61doating-rate liabilities, thereby neu-\ntralizing the exposure of their fair value to changes in in-\nterest rates.\nFloating-to-\ue61doating interest rate swaps transform the in-\ndexing criteria for \ue61doating-rate \ue61enancial liabilities.\nSome structured borrowings have multi-stage cash \ue61dows\nhedged by interest rate swaps that at the repo\ue61fing date,\nand for a limited time, provide for the exchange of \ue61exed-\nrate interest \ue61dows.\nInterest rate options involve the exchange of interest dif-\nferences calculated on a notional principal amount once\nce\ue61fain thresholds (strike prices) are reached. These\nthresholds specify the e\ue61bective maximum rate (cap) or\nthe minimum rate (\ue61door) to which the synthetic \ue61enancial\ninstrument will be indexed as a result of the hedge. Ce\ue61fain\nhedging strategies provide for the use of combinations of\noptions (collars) that establish the minimum and maximum\nrates at the same time. In this case, the strike prices are\nnormally set so that no premium is paid on the contract\n(zero cost collars).\nSuch contracts are normally used when the \ue61exed interest\nrate that can be obtained in an interest rate swap is con-\nsidered too high with respect to market expectations for\nfuture interest rate developments. In addition, interest rate\n\noptions are also considered most appropriate in periods\nof greater unce\ue61fainty about future interest rate develop-\nments because they make it possible to bene\ue61et from any \ndecrease in interest rates.\nThe following table repo\ue61fs the notional amount of interest\nrate derivatives at December 31, 2021 and December 31,\n2020 broken down by type of contract.\nMillions of euro Notional amount\nat Dec. 31,\n2021\nat Dec. 31,\n2020\nFloating-to-\ue61exed interest rate swaps 7,70 0 7,323\nFixed-to-\ue61doating interest rate swaps 722 173\nFixed-to-\ue61exed interest rate swaps - -\nFloating-to-\ue61doating interest rate swaps 391 276\nInterest rate options 50 50\nTotal 8,863 7,82 2\nFor more details on interest rate derivatives, please see\nnote 49 \u201cDerivatives and hedge accounting\u201d.\nInterest rate risk sensitivity analysis\nEnel analyzes the sensitivity of its exposure by estimating\nthe e\ue61bects of a change in interest rates on the po\ue61ffolio of\n\ue61enancial instruments.\nMore speci\ue61ecally, sensitivity analysis measures the po-\ntential impact on pro\ue61et or loss and on equity of market\nscenarios that would cause a change in the fair value of\nderivatives or in the \ue61enancial expense associated with un-\nhedged gross debt.\nThese market scenarios are obtained by simulating parallel\nincreases and decreases in the yield curve as at the re-\npo\ue61fing date.\nThere were no changes introduced in the methods and as-\nsumptions used in the sensitivity analysis compared with\nthe previous year.\nWith all other variables held constant, the Group\u2019s pre-tax\npro\ue61et would be a\ue61bected by a change in the level of interest\nrates as follows.\nMillions of euro 2021\nPre-tax impact \non pro\ue61ft or loss\nPre-tax impact \non equity\nBasis points Increase Decrease Increase Decrease\nChange in \ue61enancial expense on gross long-term \ue61doating-rate debt\nafter hedging\n25 23 (23) - -\nChange in fair value of derivatives classi\ue61eed as non-hedging\ninstruments\n25 38 (38) - -\nChange in fair value of derivatives designated as hedging\ninstruments\nCash \ue61dow hedges 25 - - 67 (67)\nFair value hedges 25 - - - -\nAt December 31, 2021, 24.5% (24.6% at December 31,\n2020) of gross long-term \ue61enancial debt was \ue61doating rate.\nTaking account of e\ue61bective cash \ue61dow hedges of interest\nrate risk (in accordance with the provisions of the IFRS-EU),\n84.5% of gross long-term \ue61enancial debt was hedged at\nDecember 31, 2021 (86.3% at December 31, 2020).\nCurrency risk\nCurrency risk mainly manifests itself as unexpected\nchanges in the \ue61enancial statement items associated with\ntransactions denominated in a currency other than the\npresentation currency. The Group\u2019s consolidated \ue61enancial\nstatements are also exposed to translation risk as a result\nof the conversion of the \ue61enancial statements of foreign\nsubsidiaries, which are denominated in local currencies,\ninto euros as the Group\u2019s presentation currency.\nThe Group\u2019s exposure to currency risk is connected with\nthe purchase or sale of fuels and power, investments (cash\n\ue61dows for capitalized costs), dividends and the purchase or\nsale of equity investments, commercial transactions and\n\ue61enancial assets and liabilities.\nThe Group policies for managing currency risk provide for\nthe mitigation of the e\ue61bects on pro\ue61et or loss of changes\nin the level of exchange rates, with the exception of the\ntranslation e\ue61bects connected with consolidation.\nIn order to minimize the exposure to currency risk, Enel im-\nplements diversi\ue61eed revenue and cost sources geograph-\nically, and uses indexing mechanisms in commercial con-\n\ntracts. Enel also uses various types of derivatives, typically\non the OTC market.\nThe derivatives in the Group\u2019s po\ue61ffolio of \ue61enancial instru-\nments include cross currency interest rate swaps, currency\nforwards and currency swaps. The term of such contracts\ndoes not exceed the maturity of the underlying instru-\nment, so that any change in the fair value and/or expected\ncash \ue61dows of such instruments o\ue61bsets the corresponding\nchange in the fair value and/or cash \ue61dows of the hedged\nposition.\nCross currency interest rate swaps are used to transform\na long-term \ue61enancial liability denominated in a currency\nother than the presentation currency into an equivalent\nliability in the presentation currency.\nCurrency forwards are contracts in which the counter-\npa\ue61fies agree to exchange principal amounts denominat-\ned in di\ue61berent currencies at a speci\ue61eed future date and\nexchange rate (the strike). Such contracts may call for the\nactual exchange of the two principal amounts (deliverable\nforwards) or payment of the di\ue61berence generated by dif-\nferences between the strike exchange rate and the prevail-\ning exchange rate at maturity (non-deliverable forwards). In\nthe la\ue61cer case, the strike rate and/or the spot rate can be\ndetermined as averages of the rates observed in a given\nperiod.\nCurrency swaps are contracts in which the counterpa\ue61fies\nenter into two transactions of the opposite sign at di\ue61ber-\nent future dates (normally one spot, the other forward) that\nprovide for the exchange of principal denominated in dif-\nferent currencies.\nThe following table repo\ue61fs the notional amount of trans-\nactions outstanding at December 31, 2021 and December\n31, 2020, broken down by type of hedged item.\nMillions of euro Notional amount\nat Dec. 31,\n2021\nat Dec. 31,\n2020\nCross currency interest rate swaps (CCIRSs) hedging debt denominated in currencies other than the euro 21,123 20,636\nCurrency forwards hedging currency risk on commodities 6,183 5,469\nCurrency forwards/CCIRSs hedging future cash \ue61dows in currencies other than the euro 5,034 3,971\nOther currency forwards 926 990\nTotal 33,266 31,066\nMore speci\ue61ecally, these include:\n\u2022 CCIRSs with a notional amount of \u20ac21,123 million to \nhedge the currency risk on debt denominated in cur-\nrencies other than the euro (\u20ac20,636 million at Decem-\nber 31, 2020);\n\u2022 currency forwards and cross currency swaps with a total \nnotional amount of \u20ac11,217 million used to hedge the\ncurrency risk associated with purchases of natural gas\nand fuel and expected cash \ue61dows in currencies other\nthan the euro (\u20ac9,440 million at December 31, 2020);\n\u2022 other currency forwards, which include OTC derivatives \ntransactions carried out to mitigate currency risk on\nexpected cash \ue61dows in currencies other than the pres-\nentation currency connected with the purchase of in-\nvestment goods in the renewables and infrastructure\nand networks sectors (new generation digital meters),\non operating costs for the supply of cloud services and\non revenue from the sale of renewable energy.\nAt December 31, 2021, 45% (51% at December 31, 2020)\nof Group long-term debt was denominated in currencies\nother than the euro.\nTaking account of hedges of currency risk, the percentage\nof debt not hedged against that risk amounted to 17% at\nDecember 31, 2021 (17% at December 31, 2020).\nCurrency risk sensitivity analysis\nThe Group analyzes the sensitivity of its exposure by es-\ntimating the e\ue61bects of a change in exchange rates on the\npo\ue61ffolio of \ue61enancial instruments.\nMore speci\ue61ecally, sensitivity analysis measures the poten-\ntial impact on pro\ue61et or loss and equity of market scenarios\nthat would cause a change in the fair value of derivatives or\nin the \ue61enancial expense associated with unhedged gross\nmedium/long-term debt.\nThese scenarios are obtained by simulating the apprecia-\ntion/depreciation of the euro against all of the currencies\ncompared with the value observed as at the repo\ue61fing date.\nThere were no changes in the methods or assumptions\nused in the sensitivity analysis compared with the previous\nyear.\nWith all other variables held constant, the pre-tax pro\ue61et\nwould be a\ue61bected by changes in exchange rates as follows.\n\nMillions of euro 2021\nPre-tax impact \non pro\ue61ft or loss\nPre-tax impact \non equity\nExchange rate Increase Decrease Increase Decrease\nChange in fair value of derivatives classi\ue61eed as non-hedging\ninstruments\n10% 485 (592) - -\nChange in fair value of derivatives designated as hedging\ninstruments\nCash \ue61dow hedges 10% - - (2,458) 3,003\nFair value hedges 10% (50) 61 - -\nCommodity price risk\nThe risk of \ue61ductuations in the price of energy commodities\nsuch as electricity, gas, oil, CO\n2\n, etc. is generated by the vol-\natility of prices and structural correlations between them,\nwhich create unce\ue61fainty in the margin on purchases and\nsales of electricity and fuels at variable prices (e.g., indexed\nbilateral contracts, transactions on the spot market, etc.).\nThe exposures on indexed contracts are quanti\ue61eed by\nbreaking down the contracts that generate exposure into\nthe underlying risk factors.\nTo contain the e\ue61bects of \ue61ductuations and stabilize margins,\nin accordance with the policies and operating limits deter-\nmined by the Group\u2019s governance and leaving an appropri-\nate margin of \ue61dexibility to seize any sho\ue61f-term oppo\ue61funi-\nties that may present themselves, Enel develops and plans\nstrategies that impact the various phases of the industrial\nprocess linked to the production and sale of electricity and\ngas (such as forward procurement and long-term com-\nmercial agreements), as well as risk mitigation plans and\ntechniques using derivative contracts (hedging).\nAs regards electricity sold by the Group, Enel mainly uses\n\ue61exed-price contracts in the form of bilateral physical con-\ntracts (PPAs) and \ue61enancial contracts (e.g., contracts for dif-\nferences, VPP contracts, etc.) in which di\ue61berences are paid\nto the counterpa\ue61fy if the market electricity price exceeds\nthe strike price and to Enel in the opposite case. The resid-\nual exposure in respect of the sale of energy on the spot\nmarket not hedged with such contracts is aggregated by\nuniform risk factors that can be managed with hedging\ntransactions on the market. Proxy hedging techniques\ncan be used for the industrial po\ue61ffolios when the hedg-\ning instruments for the speci\ue61ec risk factors generating\nthe exposure are not available on the market or are not\nsu\ue61aciently liquid. In addition, Enel uses po\ue61ffolio hedging\ntechniques to assess oppo\ue61funities for ne\ue61cing intercom-\npany exposures.\nThe Group mainly uses plain vanilla derivatives for hedging\n(more speci\ue61ecally, forwards, swaps, options on commodi-\nties, futures, contracts for di\ue61berences).\nSome of these products can be indexed to a variety of un-\nderlyings (coal, gas, oil, CO\n2\n, di\ue61berent geographical areas,\netc.) and the approaches can be assessed and adapted to\nspeci\ue61ec needs.\nEnel also engages in proprietary trading in order to main-\ntain a presence in the Group\u2019s reference energy com-\nmodity markets. These operations consist in taking on\nexposures in energy commodities (oil products, gas, coal,\nCO\n2\n ce\ue61fi\ue61ecates and electricity) using \ue61enancial derivatives\nand physical contracts traded on regulated and over-the-\ncounter markets, optimizing pro\ue61ets through transactions\ncarried out on the basis of expected market developments.\nThe following table repo\ue61fs the notional amount of out-\nstanding transactions at December 31, 2021 and Decem-\nber 31, 2020, broken down by type of instrument.\nMillions of euro Notional amount\nat Dec. 31,\n2021\nat Dec. 31,\n2020\nForward and futures contracts 90,273 48,064\nSwaps 12,122 1,862\nOptions 1,076 576\nEmbedded - 7\nTotal 103,471 50,509\nFor more details, please see note 49 \u201cDerivatives and\nhedge accounting\u201d.\nSensitivity analysis of commodity price risk\nThe following table presents the results of the analysis of\nsensitivity to a reasonably possible change in the com-\nmodity prices underlying the valuation model used in the\nscenario at the same date, with all other variables held\nconstant.\nThe impact on pre-tax pro\ue61et of shifts of +15% and -15% in\nthe price curve for the main commodities that make up\nthe fuel scenario and the basket of formulas used in the\n\ncontracts is mainly a\ue61cributable to the change in the price\nof electricity, gas and petroleum products and, to a lesser\nextent, of CO\n2\n. The impact on equity of the same shifts in\nthe price curve is primarily due to changes in the price of\nelectricity, petroleum products and, to a lesser extent, CO\n2\n.\nThe Group\u2019s exposure to changes in the prices of other\ncommodities is not material.\nMillions of euro 2021\nPre-tax impact \non pro\ue61ft or loss\nPre-tax impact \non equity\nCommodity\nprice Increase Decrease Increase Decrease\nChange in the fair value of trading derivatives on commodities 15% (621) 632 - -\nChange in the fair value of derivatives on commodities designated as\nhedging instruments\n15% - - 72 (88)\nCredit and counterpa\ue61ey risk\nThe Group\u2019s commercial, commodity and \ue61enancial trans-\nactions expose it to credit and counterpa\ue61fy risk, i.e., the\npossibility of a deterioration in the creditwo\ue61fhiness of a\ncounterpa\ue61fy that has an adverse impact on the expected\nvalue of the creditor position or, for trade payables only,\nincreases average collection times.\nAccordingly, the exposure to credit risk is a\ue61cributable to\nthe following types of transactions:\n\u2022 the sale and distribution of electricity and gas in free \nand regulated markets and the supply of goods and\nservices (trade receivables);\n\u2022 trading activities that involve the physical exchange \nof assets or transactions in \ue61enancial instruments (the\ncommodity po\ue61ffolio);\n\u2022 trading in derivatives, bank deposits and, more general-\nly, \ue61enancial instruments (the \ue61enancial po\ue61ffolio).\nIn order to minimize credit risk, credit exposures are man-\naged at the region/country/Global Business Line level by\ndi\ue61berent units, thereby ensuring the necessary segregation\nof risk management and control activities. Monitoring the\nconsolidated exposure is carried out by Enel SpA.\nIn addition, at the Group level the policy provides for the use\nof uniform criteria \u2013 in all the main regions/countries/Global\nBusiness Lines and at the consolidated level \u2013 in measuring\ncommercial credit exposures in order to promptly identify\nany deterioration in the quality of outstanding receivables\nand any mitigation actions to be taken.\nThe policy for managing credit risk associated with com-\nmercial activities provides for a preliminary assessment of\nthe creditwo\ue61fhiness of counterpa\ue61fies and the adoption\nof mitigation instruments, such as obtaining collateral or\nunsecured guarantees.\nIn addition, the Group unde\ue61fakes transactions to factor\nreceivables without recourse, which results in the com-\nplete derecognition of the corresponding assets involved\nin the factoring, as the risks and rewards associated with\nthem have been transferred.\nFinally, with regard to \ue61enancial and commodity transac-\ntions, risk mitigation is pursued with a uniform system for\nassessing counterpa\ue61fies at the Group level, including im-\nplementation at the level of regions/countries/Global Busi-\nness Lines, as well as with the adoption of speci\ue61ec stand-\nardized contractual frameworks that contain risk mitiga-\ntion clauses (e.g., ne\ue61cing arrangements) and possibly the\nexchange of cash collateral.\nDespite the deterioration in the collection status of some\ncustomer segments, which was taken into account in the\nassessment of the impairment of trade receivables, to date\nthe Group po\ue61ffolio has displayed resilience to the global\npandemic. This re\ue61dects the strengthening of digital collec-\ntion channels and a sound diversi\ue61ecation of commercial\ncustomers with a low exposure to the impacts of COVID\n(e.g., utilities and distribution companies).\nLoan assets\nMillions of euro\nat Dec. 31, 2021\nStaging\n Basis for\nrecognition of\nexpected credit loss\nallowance\n Average loss rate\n(PD*LGD)\n Gross carrying\namount\n Expected credit loss\nallowance\n Carrying \namount\nPe\ue619orming 12 m ECL 0.6% 10,585 65 10,520 \nUnderpe\ue619orming Lifetime ECL 27.8 % 72 20 52 \nNon-pe\ue619orming Lifetime ECL 73.0% 204 149 55\nTotal 10,861 234 10,627 \n\nContract assets, trade receivables and other \ue61fnancial assets: individual measurement\nMillions of euro\nat Dec. 31, 2021\nAverage loss\nrate (PD*LGD)\nGross carrying\namount\nExpected credit \nloss allowance\nCarrying\namount\nContract assets - 110 - 110\nTrade receivables\nTrade receivables not past due 0.7% 5,339 39 5,300\nTrade receivables past due:\n- 1-30 days 1.2% 489 6 483\n- 31-60 days 3.4% 89 3 86 \n- 61-90 days 10.2% 59 6 53\n- 91-120 days 50.0% 34 17 17 \n- 121-150 days 31.6% 19 6 13 \n- 151-180 days 26.9% 26 7 19 \n- more than 180 days (credit impaired) 77.1% 1,813 1,397 416 \nTotal trade receivables 7,868 1,481 6,387\nOther \ue61fnancial assets\nOther \ue61enancial assets not past due 1.9% 1,712 32 1,680\nOther \ue61enancial assets past due:\n- 1-30 days - 352 - 352\n- 31-60 days - 244 - 244\n- 61-90 days - - - -\n- 91-120 days - 2 - 2\n- 121-150 days - - - -\n- 151-180 days - - - -\n- more than 180 days (credit impaired) 13.9% 332 46 286\nTotal other \ue61fnancial assets 2,642 78 2,564\nTOTAL 10,620 1,559 9,061 \nMillions of euro\nat Dec. 31, 2020\nAverage loss\nrate (PD*LGD)\nGross carrying\namount\nExpected credit\nloss allowance\nCarrying\namount\nContract assets 4.3% 23 1 22\nTrade receivables\nTrade receivables not past due 1.3% 4,953 66 4,887 \nTrade receivables past due:\n- 1-30 days 1.5% 453 7 446\n- 31-60 days 2.8% 106 3 103 \n- 61-90 days 12.8% 39 5 34\n- 91-120 days 28.0% 25 7 18 \n- 121-150 days 12.9% 31 4 27 \n- 151-180 days 100.0% 53 53 - \n- more than 180 days (credit impaired) 83.8% 1,692 1,418 274 \nTotal trade receivables 7,352 1,563 5,789 \nOther \ue61fnancial assets\nOther \ue61enancial assets not past due 3.1% 1,243 38 1,205\nOther \ue61enancial assets past due:\n- 1-30 days 15.6% 499 78 421 \n- 31-60 days - 11 - 11\n- 61-90 days - - - -\n- 91-120 days - - - -\n- 121-150 days - - - -\n- 151-180 days 40.0% 5 2 3\n- more than 180 days (credit impaired) 6.3% 79 5 74 \nTotal other \ue61fnancial assets 1,837 123 1,714 \nTOTAL 9,212 1,687 7,525 \n\nContract assets, trade receivables and other \ue61fnancial assets: collective measurement\nMillions of euro\nat Dec. 31, 2021\nAverage loss\nrate (PD*LGD)\nGross carrying\namount\nExpected credit\nloss allowance\nCarrying\namount\nContract assets 11.5% 26 2 24 \nTrade receivables\nTrade receivables not past due 1.7% 4,603 77 4,526 \nTrade receivables past due:\n- 1-30 days 2.8% 3,321 94 3,227\n- 31-60 days 9.9% 272 27 245 \n- 61-90 days 15.3% 183 28 155\n- 91-120 days 26.1% 111 29 82 \n- 121-150 days 32.4% 111 36 75 \n- 151-180 days 33.3% 90 30 60\n- more than 180 days (credit impaired) 58.5% 3,180 1,861 1,319 \nTotal trade receivables 11,871 2,182 9,689\nOther \ue61fnancial assets\nOther \ue61enancial assets not past due - 804 76 728 \nOther \ue61enancial assets past due:\n- 1-30 days - 7 - 7\n- 31-60 days - - - -\n- 61-90 days - - - -\n- 91-120 days - - - -\n- 121-150 days - - - -\n- 151-180 days - 1 - 1\n- more than 180 days (credit impaired) - 1 - 1\nTotal other \ue61fnancial assets 813 76 737 \nTOTAL 12,710 2,260 10,450 \nMillions of euro\nat Dec. 31, 2020\nAverage loss\nrate (PD*LGD)\nGross carrying\namount\nExpected credit\nloss allowance\nCarrying\namount\nContract assets 1.2% 163 2 161 \nTrade receivables\nTrade receivables not past due 0.6% 5,487 32 5,455\nTrade receivables past due:\n- 1-30 days 7. 2 % 554 40 514 \n- 31-60 days 16.2% 154 25 129\n- 61-90 days 26.4% 110 29 81\n- 91-120 days 36.6% 71 26 45 \n- 121-150 days 43.1% 58 25 33\n- 151-180 days 100.0% 79 79 -\n- more than 180 days (credit impaired) 100.0% 1,468 1,468 - \nTotal trade receivables 7,981 1,724 6,257 \nOther \ue61fnancial assets\nOther \ue61enancial assets not past due 2.2% 274 6 268\nOther \ue61enancial assets past due:\n- 1-30 days - 3 - 3\n- 31-60 days - 1 - 1\n- 61-90 days - - - -\n- 91-120 days - - - -\n- 121-150 days - - - -\n- 151-180 days - - - -\n- more than 180 days (credit impaired) - 55 - 55\nTotal other \ue61fnancial assets 333 6 327 \nTOTAL 8,477 1,732 6,745 \n\nLiquidity risk\nLiquidity risk manifests itself as unce\ue61fainty about the\nGroup\u2019s ability to discharge its obligations associated with\n\ue61enancial liabilities that are se\ue61cled by delivering cash or an-\nother \ue61enancial asset.\nEnel manages liquidity risk by implementing measures to\nensure an appropriate level of liquid \ue61enancial resources,\nminimizing the associated oppo\ue61funity cost and maintain-\ning a balanced debt structure in terms of its maturity pro-\n\ue61ele and funding sources.\nIn the sho\ue61f term, liquidity risk is mitigated by maintaining\nan appropriate level of unconditionally available resources,\nincluding liquidity on hand and sho\ue61f-term deposits, avail-\nable commi\ue61ced credit lines and a po\ue61ffolio of highly liquid\nassets.\nIn the long term, liquidity risk is mitigated by maintaining a\nbalanced maturity pro\ue61ele for our debt, access to a range of\nsources of funding on di\ue61berent markets, in di\ue61berent cur-\nrencies and with diverse counterpa\ue61fies.\nThe mitigation of liquidity risk enables the Group to main-\ntain a credit rating that ensures access to the capital mar-\nket and limits the cost of funds, with a positive impact on\nits \ue61enancial position and pe\ue619ormance.\nThe Group holds the following undrawn lines of credit and\ncommercial paper programs.\nMillions of euro at Dec. 31, 2021 at Dec. 31, 2020\nExpiring within \none year\nExpiring beyond \none year\nExpiring within \none year\nExpiring beyond \none year\nCommi\ue61ced credit lines 438 14,822 4,028 14,531\nUncommi\ue61ced credit lines 888 - 802 -\nCommercial paper 3,709 - 7,591 -\nTotal\n5,035 14,822 12,421 14,531\nMaturity analysis \nThe table below summarizes the maturity pro\ue61ele of the\nGroup\u2019s long-term debt.\nMillions of euro\nAt Dec. 31, 2021 Maturing in\nLess\nthan 3 \nmonths\nFrom 3\nmonths \nto 1 year 2023 2024 2025 2026 Beyond\nBonds:\n- listed, \ue61exed rate 59 2,060 2,078 4,691 2,150 3,782 12,593\n- listed, \ue61doating rate 128 306 466 357 298 191 811\n- unlisted, \ue61exed rate 50 - - 1,320 - 1,094 8,743\n- unlisted, \ue61doating rate - 97 97 97 97 97 137\nTotal bonds 237 2,463 2,641 6,465 2,545 5,164 22,284\nBank borrowings:\n- \ue61exed rate 65 173 206 945 197 334 485\n- \ue61doating rate 96 655 756 1,261 1,072 2,313 3,956\n- use of revolving credit lines - - 50 - 4 1,000 -\nTotal bank borrowings 161 828 1,012 2,206 1,273 3,647 4,441\nLeases:\n- \ue61exed rate 67 175 213 166 151 147 1,558\n- \ue61doating rate 4 13 15 13 13 9 3\nTotal leases 71 188 228 179 164 156 1,561\nOther non-bank borrowings\n(1)\n:\n- \ue61exed rate 11 58 73 80 66 74 233\n- \ue61doating rate 3 11 - 120 5 1 2\nTotal other non-bank borrowings 14 69 73 200 71 75 235\nTOTAL 483 3,548 3,954 9,050 4,053 9,042 28,521\n(1) Includes other non-current \ue61enancial borrowings repo\ue61fed under \u201cOther non-current \ue61enancial liabilities\u201d in the statement of \ue61enancial position.\n\nCommitments to purchase commodities\nIn conducting its business, the Enel Group has entered into\ncontracts to purchase speci\ue61eed quantities of commodities\nat a ce\ue61fain future date for its own use, which qualify for\nthe own use exemption provided for under IFRS 9.\nThe following table repo\ue61fs the undiscounted cash \ue61dows\nassociated with outstanding commitments at December\n31, 2021.\nMillions of euro\nat Dec. 31,\n2021 2022-2025 2026-2030 2031-2035 Beyond\nCommitments to purchase commodities:\n- electricity 71,244 22,916 16,201 13,932 18,195\n- fuels 58,042 11,542 34,027 8,038 4,435\nTotal 129,286 34,458 50,228 21,970 22,630\n",
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"value": "\n48. O\ue61cse\ue61bing \ue61fnancial assets and\n\ue61fnancial liabilities\nAt December 31, 2021, the Group did not hold o\ue61bset posi-\ntions in assets and liabilities, as it is not the Enel Group\u2019s poli-\ncy to se\ue61cle \ue61enancial assets and liabilities on a net basis.\n",
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"value": "\n49. Derivatives and hedge accounting\nThe following tables show the notional amount and the fair\nvalue of derivative \ue61enancial assets and derivative \ue61enancial\nliabilities eligible for hedge accounting or measured at\nFVTPL, classi\ue61eed on the basis of the type of hedge rela-\ntionship and the hedged risk, broken down into current\nand non-current instruments.\nThe notional amount of a derivative contract is the amount\non the basis of which cash \ue61dows are exchanged. This\namount can be expressed as a value or a quantity (for ex-\nample tons, conve\ue61fed into euros by multiplying the no-\ntional amount by the agreed price). Amounts denominated\nin currencies other than the euro are translated at the o\ue61a-\ncial closing exchange rates provided by the World Markets\nRe\ue61enitiv (WMR) Company.\nMillions of euro Non-current Current\nNotional Fair value Notional Fair value\nat Dec. 31,\n2021\nat Dec. 31,\n2020\nat Dec. 31,\n2021\nat Dec. 31,\n2020\nat Dec. 31,\n2021\nat Dec. 31,\n2020\nat Dec. 31,\n2021\nat Dec. 31,\n2020\nDERIVATIVE ASSETS\nFair value hedge derivatives:\n- on interest rates 139 138 19 22 - - - -\n- on exchange rates 672 639 42 28 - 79 - 28\nTotal 811 777 61 50 - 79 - 28\nCash \ue61dow hedge derivatives:\n- on interest rates 404 161 19 21 - - - -\n- on exchange rates 14,980 5,061 1,356 685 2,690 698 104 51\n- on commodities 2,693 2,541 1,059 428 3,469 2,165 3,023 627\nTotal 18,077 7,763 2,434 1,134 6,159 2,863 3,127 678\nTrading derivatives:\n- on interest rates - 50 - 2 50 - 1 -\n- on exchange rates 26 71 - 4 2,154 3,430 23 79\n- on commodities 1 ,147 379 277 46 48,304 21,424 19,640 2,686\nTotal 1,173 500 277 52 50,508 24,854 19,664 2,765\nTOTAL DERIVATIVE ASSETS 20,061 9,040 2,772 1,236 56,667 27,796 22,791 3,471\n\nMillions of euro Non-current Current\nNotional Fair value Notional Fair value\nat Dec. 31,\n2021\nat Dec. 31,\n2020\nat Dec. 31,\n2021\nat Dec. 31,\n2020\nat Dec. 31,\n2021\nat Dec. 31,\n2020\nat Dec. 31,\n2021\nat Dec. 31,\n2020\nDERIVATIVE LIABILITIES\nFair value hedge derivatives:\n- on interest rates 660 - 5 - - - - -\n- on exchange rates - - - - - - - -\nTotal 660 - 5 - - - - -\nCash \ue61dow hedge derivatives:\n- on interest rates 6,807 7, 2 01 620 938 653 122 9 2\n- on exchange rates 7, 2 24 16,310 1,244 2,491 1,892 3,766 49 263\n- on commodities 3,312 1,535 1,301 148 2,067 1,466 4,853 379\nTotal 17, 3 4 3 25,046 3,165 3,577 4,612 5,354 4,911 644\nTrading derivatives:\n- on interest rates - 50 - 4 150 100 73 88\n- on exchange rates 73 28 2 3 3,555 984 60 41\n- on commodities 884 89 167 22 41,595 20,910 19,563 2,758\nTotal 957 167 169 29 45,300 21,994 19,696 2,887\nTOTAL DERIVATIVE\nLIABILITIES\n18,960 25,213 3,339 3,606 49,912 27,348 24,607 3,531\n49.1 Derivatives designated as hedging\ninstruments\nDerivatives are initially recognized at fair value, on the trade\ndate of the contract and are subsequently re-measured\nat their fair value. The method of recognizing the result-\ning gain or loss depends on whether the derivative is des-\nignated as a hedging instrument, and if so, the nature of\nthe item being hedged.\nHedge accounting is applied to derivatives entered into in \norder to reduce risks such as interest rate risk, currency\nrisk, commodity price risk and net investments in foreign \noperations when all the criteria provided by IFRS 9 are\nmet.\nAt the inception of the transaction, the Group docu-\nments the relationship between hedging instruments\nand hedged items, as well as its risk management objec-\ntives and strategy. The Group also documents its assess-\nment, both at hedge inception and on an ongoing basis,\nof whether hedging instruments are highly e\ue61bective in\no\ue61bse\ue61cing changes in fair values or cash \ue61dows of hedged\nitems.\nFor cash \ue61dow hedges of forecast transactions designat-\ned as hedged items, the Group assesses and documents\nthat they are highly probable and present an exposure to \nchanges in cash \ue61dows that a\ue61bect pro\ue61et or loss.\nDepending on the nature of the risk exposure, the Group\ndesignates derivatives as either:\n\u2022 fair value hedges; \n\u2022 cash \ue61dow hedges.\nFor more details about the nature and the extent of risks\narising from \ue61enancial instruments to which the Group is\nexposed, please see note 47 \u201cRisk management\u201d.\nTo be e\ue61bective a hedge relationship shall meet all of the \nfollowing criteria:\n\u2022 existence of an economic relationship between hedg-\ning instrument and hedged item;\n\u2022 the e\ue61bect of credit risk does not dominate the value \nchanges resulting from the economic relationship;\n\u2022 the hedge ratio de\ue61ened at initial designation shall be \nequal to the one used for risk management purpos-\nes (i.e., same quantity of the hedged item that the en-\ntity actually hedges and the quantity of the hedging\ninstrument that the entity actually uses to hedge the\nquantity of the hedged item).\nBased on the IFRS 9 requirements, the existence of an \neconomic relationship is evaluated by the Group through \na qualitative assessment or a quantitative computation,\ndepending on the following circumstances:\n\u2022 if the underlying risk of the hedging instrument and \nthe hedged item is the same, the existence of an eco-\nnomic relationship will be provided through a qualita-\ntive analysis;\n\u2022 on the other hand, if the underlying risk of the hedging \ninstrument and the hedged item is not the same, the\nexistence of the economic relationship will be demon-\nstrated through a quantitative method in addition to a\nqualitative analysis of the nature of the economic rela-\ntionship (i.e., linear regression). \nIn order to demonstrate that the behavior of the hedging\ninstrument is in line with those of the hedged item, di\ue61ber-\nent scenarios will be analyzed.\n\nFor hedging of commodity price risk, the existence of an\neconomic relationship is deduced from a ranking matrix\nthat de\ue61enes, for each possible risk component, a set of all\nstandard derivatives available in the market whose rank-\ning is based on their e\ue61bectiveness in hedging the consid-\nered risk.\nIn order to evaluate the credit risk e\ue61bects, the Group con-\nsiders the existence of risk mitigating measures (collat-\neral, mutual break-up clauses, ne\ue61cing agreements, etc.).\nThe Group has established a hedge ratio of 1:1 for all\nthe hedge relationships (including commodity price risk\nhedging) as the underlying risk of the hedging derivative\nis identical to the hedged risk, in order to minimize hedg-\ning ine\ue61bectiveness.\nThe hedge ine\ue61bectiveness will be evaluated through a\nqualitative assessment or a quantitative computation,\ndepending on the following circumstances:\n\u2022 if the critical terms of the hedged item and hedging \ninstrument match and there are no other sources of\nine\ue61bectiveness included the credit risk adjustment on \nthe hedging derivative, the hedge relationship will be\nconsidered fully e\ue61bective on the basis of a qualitative\nassessment;\n\u2022 if the critical terms of the hedged item and hedging in-\nstrument do not match or there is at least one source\nof ine\ue61bectiveness, the hedge ine\ue61bectiveness will be\nquanti\ue61eed applying the dollar o\ue61bset cumulative meth-\nod with hypothetical derivative. This method compares\nchanges in fair value of the hedging instrument and\nthe hypothetical derivative between the repo\ue61fing date \nand the inception date.\nThe main causes of hedge ine\ue61bectiveness can be the fol-\nlowing: \n\u2022 basis di\ue61berences (i.e., the fair value or cash \ue61dows of \nthe hedged item depend on a variable that is di\ue61ber-\nent from the variable that causes the fair value or cash\n\ue61dows of the hedging instrument to change);\n\u2022 timing di\ue61berences (i.e., the hedged item and hedging \ninstrument occur or are se\ue61cled at di\ue61berent dates);\n\u2022 quantity or notional amount di\ue61berences (i.e., the \nhedged item and hedging instrument are based on\ndi\ue61berent quantities or notional amounts);\n\u2022 other risks (i.e., changes in the fair value or cash \ue61dows \nof a derivative hedging instrument or hedged item re-\nlate to risks other than the speci\ue61ec risk being hedged);\n\u2022 credit risk (i.e., the counterpa\ue61fy credit risk di\ue61berently \nimpacts the changes in the fair value of the hedging\ninstruments and hedged items).\nFair value hedges\nFair value hedges are used to protect the Group against \nexposures to changes in the fair value of assets, liabilities\nor \ue61erm commitment a\ue61cributable to a pa\ue61ficular risk that\ncould a\ue61bect pro\ue61et or loss.\nChanges in the fair value of derivatives that qualify and \nare designated as hedging instruments are recognized\nin the income statement, together with changes in the\nfair value of the hedged item that are a\ue61cributable to the\nhedged risk.\nIf the hedge no longer meets the criteria for hedge ac-\ncounting, the adjustment to the carrying amount of a\nhedged item for which the e\ue61bective interest rate method\nis used is amo\ue61fized to pro\ue61et or loss over the period to\nmaturity.\nCash \ue61dow hedges\nCash \ue61dow hedges are applied in order to hedge the Group\nexposure to changes in future cash \ue61dows that are a\ue61cribut-\nable to a pa\ue61ficular risk associated with a recognized asset\nor liability or a highly probable transaction that could a\ue61bect\npro\ue61et or loss.\nThe e\ue61bective po\ue61fion of changes in the fair value of deriv-\natives that are designated and qualify as cash \ue61dow hedges\nis recognized in other comprehensive income. The gain or\nloss relating to the ine\ue61bective po\ue61fion is recognized imme-\ndiately in the income statement.\nAmounts accumulated in equity are reclassi\ue61eed to pro\ue61et\nor loss in the periods when the hedged item a\ue61bects pro\ue61et\nor loss (for example, when the hedged forecast sale takes\nplace).\nIf the hedged item results in the recognition of a non-\ue61e-\nnancial asset (i.e., prope\ue61fy, plant and equipment or inven-\ntories, etc.) or a non-\ue61enancial liability, or a hedged forecast\ntransaction for a non-\ue61enancial asset or a non-\ue61enancial\nliability becomes a \ue61erm commitment for which fair value\nhedge accounting is applied, the amount accumulated in\nequity (i.e., hedging reserve) shall be removed and included\nin the initial amount (cost or other carrying amount) of the\nasset or the liability hedged (i.e., \u201cbasis adjustment\u201d).\nWhen a hedging instrument expires or is sold, or when a\nhedge no longer meets the criteria for hedge accounting,\nany cumulative gain or loss existing in equity at that time\nremains in equity and is recognized when the forecast\ntransaction is ultimately recognized in the income state-\nment. When a forecast transaction is no longer expected\nto occur, the cumulative gain or loss that was repo\ue61fed in\nequity is immediately transferred to the income statement.\nFor hedge relationships using forwards as a hedging in-\nstrument, where only the change in the value of the spot\nelement is designated as the hedging instrument, ac-\ncounting for the forward element (pro\ue61et or loss vs. OCI) \nis de\ue61ened case by case. This approach is actually applied\nby the Group for hedging of currency risk on renewables\nassets.\nConversely, for hedge relationships using cross currency\ninterest rate swaps as hedging instruments, the Group\n\nseparates foreign currency basis spread, in designating\nthe hedging derivative, and presents them in other com-\nprehensive income (OCI) as hedging costs.\nWith speci\ue61ec regard to cash \ue61dow hedges of commodity\nrisk, in order to improve their consistency with the risk\nmanagement strategy, the Enel Group applies a dynamic\nhedge accounting approach based on speci\ue61ec liquidity\nrequirements (the so-called \u201cliquidity-based approach\u201c).\nThis approach requires the designation of hedges \nthrough the use of the most liquid derivatives available\non the market and replacing them with others that are \nmore e\ue61bective in covering the risk in question.\nConsistent with the risk management strategy, the liquid-\nity-based approach allows the roll-over of a derivative by \nreplacing it with a new derivative, not only in the event of\nexpiry but also during the hedge relationship, if and only \nif the new derivative meets both of the following require-\nments:\n\u2022 it represents a best proxy of the old derivative in terms \nof ranking;\n\u2022 it meets speci\ue61ec liquidity requirements.\nSatisfaction of these requirements is veri\ue61eed qua\ue61ferly.\nAt the roll-over date, the hedge relationship is not dis-\ncontinued. Accordingly, sta\ue61fing from that date, changes\nin the e\ue61bective fair value of the new derivative will be rec-\nognized in equity (the hedging reserve), while changes in \nthe fair value of the old derivative are recognized through\npro\ue61et or loss.\nReform of benchmarks for the determination of \ninterest rates \u2013 IBOR reform\nOverview\nInterbank O\ue61bered Rates (\u201cIBORs\u201d) are benchmark rates at\nwhich banks can borrow funds on the interbank market\non an unsecured basis for a given period ranging from\novernight to 12 months, in a speci\ue61ec currency.\nIn recent years there have been a number of cases of\nmanipulation of these rates by the banks contributing\nto their calculation. For this reason, regulators around\nthe world have begun a sweeping reform of interest \nrate benchmarks that includes the replacement of some\nbenchmarks with alternative risk-free rates (the IBOR re-\nform).\nThe Group\u2019s main exposure is based on Euribor, USD LI-\nBOR and GBP LIBOR.\nEuribor is still considered compliant with the European\nBenchmarks Regulation (BMR) and this permits market\npa\ue61ficipants to continue to use it for both existing and \nnew contracts.\nIn line with the most recent guidance issued by the major\nregulatory bodies:\n\u2022 the 1-month, 3-month and 6-month USD LIBOR \nbenchmarks will become unrepresentative after June \n30, 2023 and the alternative reference rate will be the \nSecured Overnight Financing Rate (SOFR);\n\u2022 the 1-month, 3-month and 6-month GBP LIBOR \nbenchmarks will become unrepresentative after De-\ncember 31, 2021 and the alternative reference rate will\nbe the Sterling Overnight Index Average (SONIA).\nAs a result of the IBOR reform, a number of temporary \nexceptions to the rules on hedge relationships have been\nallowed in implementation of the amendments to IFRS \n9 issued in September 2019 (Phase 1) and August 2020\n(Phase 2) to address, respectively:\n\u2022 pre-replacement issues that impact \ue61enancial repo\ue61fing \nin the period preceding the replacement of an existing\ninterest rate benchmark with an alternative risk-free \nrate (Phase 1); and\n\u2022 post-replacement issues that could impact \ue61enancial \nrepo\ue61fing when an existing interest rate benchmark\nis reformed or replaced and there is there no longer\nany initial unce\ue61fainty, but hedge contracts and rela-\ntionships still need to be updated to re\ue61dect the new\nbenchmark rates (Phase 2).\nImpact of the IBOR reform on the Group\nIn a context of unce\ue61fainty regarding the IBOR transition\nin the various countries, the Group has determined the \noverall number and nominal value of the contracts im-\npacted by the reform. In addition, a number of contractu-\nal amendments have already been implemented in con-\ntracts previously indexed to GBP LIBOR and others will be\namended in 2022-2023 on the basis of the evolution of\nthe IBOR reform and best market practice.\nDebt and derivatives\nThe Group\u2019s \ue61doating rate debt is mainly benchmarked\nagainst Euribor and USD LIBOR and is almost entirely \nhedged using \ue61enancial derivatives.\nAt the repo\ue61fing date, the Group is planning to take no\naction with regard to Euribor since, as stated above, this \nbenchmark has been comprehensively reformed to com-\nply with the European Benchmarks Regulation. Despite\nthe continuity with Euribor, replacement clauses may\nbe required and could therefore be implemented by the\nGroup in the new contracts in accordance with the evolu-\ntion of accepted market practice.\nDuring 2021, the Group obtained new US dollar loans\nindexed to SOFR and proactively changed its existing\nexposure in derivatives by switching from GPB LIBOR to\nSONIA. The main focus over the coming months will be\nhow to change existing USD LIBOR to USD SOFR expo-\nsures and how to use the new, alternative risk-free rates\nfor new \ue61enancial transactions.\nThe Group\u2019s derivative instruments are managed through\ncontracts that are mainly based on framework agree-\nments de\ue61ened by the International Swaps and Derivatives\nAssociation (ISDA).\n\nThe ISDA has revised its standardized contracts in light \nof the IBOR reform and amended the choices for \ue61doating\nrates within the 2006 ISDA de\ue61enitions to include replace-\nment clauses that would apply upon the permanent dis-\ncontinuation of speci\ue61ec key benchmarks. These changes\ntook e\ue61bect on January 25, 2021. Transactions represent-\ned in the 2006 ISDA de\ue61enitions carried out on January 25,\n2021 or later include adjusted \ue61doating-rate options (e.g.,\nthe choice of \ue61doating rate with replacement clause), while\ntransactions completed before that date (previous deriv-\native contracts) continue to be based on the 2006 ISDA\nde\ue61enitions.\nFor this reason, the ISDA published an IBOR Fallback Pro-\ntocol to facilitate multilateral amendments to include the\namended de\ue61enitions.\nThe Group is assessing whether to: (i) adopt that protocol\nin the light of its exposure and developments in the IBOR\nreform or (ii) adjust in advance any contracts impacted bi-\nlaterally by the reform.\nHedge relationships\nAt the repo\ue61fing date, hedged items and hedging instru-\nments are primarily indexed to Euribor, USD LIBOR and\nGBP SONIA.\nThe Group has assessed the impact of unce\ue61fainty engen-\ndered by the IBOR reform on hedge relationships at De-\ncember 31, 2021 with reference to both hedging instru-\nments and hedged items. Both the hedged items and the\nhedging instruments will change their parameterization\nfrom interbank market-based benchmarks (IBORs) to al-\nternative risk-free rates (RFRs) as a result of the contrac-\ntual amendments that will take e\ue61bect in the coming years.\nIn pa\ue61ficular, unce\ue61fainty remains as to how the replacement\nwill take place with regard to both hedging instruments and\nhedged items indexed to USD LIBOR. The Group manages\nthe unce\ue61fainty associated with these hedge relationships\nby continuing to apply the temporary exceptions provided\nfor in the amendments to IFRS 9 issued in September 2019\n(Phase 1). It was therefore felt that the benchmark indices\nfor determining the interest rates on which the cash \ue61dows\nof the hedged items or the hedging instruments are based\nwould not change as a consequence of the IBOR reform.\nThe exception was applied for the following hedge rela-\ntionship requirements:\n\u2022 determine if a forecast transaction is highly probable;\n\u2022 establish whether the future hedged cash \ue61dows will \narise in a discontinued cash \ue61dow hedge relationship;\n\u2022 assess the economic relationship between the hedged \nitem and the hedging instrument.\nThe hedge relationships impacted may become ine\ue61bective\na\ue61cributable to di\ue61berent replacements of existing bench-\nmarks with alternative risk-free benchmarks. In any case,\nthe Group will seek to implement the replacements at the\nsame time.\nIn addition, the Group changed the reference to GBP LIBOR\nin its interest rate hedging instruments used in cash \ue61dow\nhedge relationships with the new, economically equivalent,\nSONIA benchmark at the end of 2021. There is therefore\nno longer any unce\ue61fainty as to how and when the replace-\nment can take place both with reference to the hedged\nitems and the hedging instruments. Consequently, the\nGroup no longer applies the amendments to IFRS 9 issued\nin September 2019 (Phase 1) to these hedge relationships\nand, consequently, has begun to apply the amendments\nto IFRS 9 issued in August 2020 (Phase 2), modifying the\nformal designation of the hedge relationship as required\nby the IBOR reform and without considering this event as a\ntermination of the hedge relationship.\nFu\ue61fhermore, for cash \ue61dow hedge relationships, in modify-\ning the description of the hedged item in the hedge rela-\ntionship, the amounts accumulated in the hedging reserve \nwere considered on the basis of the alternative benchmark\nindex in relation to which the future hedged cash \ue61dows are\ndetermined.\nThe following table provides details of the notional amounts\nof the hedging instruments for which the amendments to\nIFRS 9 (both Phase 1 and Phase 2) were applied as at De-\ncember 31, 2021, broken down by the alternative bench-\nmark index used for determining the interest rate.\nMillions of euro Notional amount\nat Dec. 31, 2021\nHedging instruments\n(1)\nPhase 1 Phase 2\nUSD LIBOR/SOFR 1,315 -\nGBP LIBOR/SONIA - 1,309\nTotal 1,315 1,309 \n(1) Since the hedge relationships mentioned are considered highly e\ue61bective, the amounts speci\ue61eed in the table as de facto \u201chedging instruments\u201d represent\nthe equivalent amounts of the associated hedged items.\n\nUnamended contracts including those with speci\ue61fc\nreplacement clauses \nThe Group is monitoring the evolution of the transition from\nthe old interest rate benchmarks to the new rates, review-\ning the overall amounts of contracts that have not yet been\nindexed to the new benchmark rates and, among these, the\namounts of contracts which already include speci\ue61ec re-\nplacement clauses. The Group considers a contract to have\nnot yet incorporated an alternative benchmark rate when\nthe interest rate of the contract is indexed to an interest rate\nbenchmark still involved in the IBOR reform and, therefore,\nwhen unce\ue61fainties still exist as to how and when replace-\nment with the new benchmark will take place.\n49.1.1 Hedge relationships by type of risk hedged\nInterest rate risk\nThe following table shows the notional amount and the\naverage interest rate of instruments hedging the interest\nrate risk on transactions outstanding at December 31,\n2021 and December 31, 2020, broken down by maturity.\nMillions of euro Maturity\n2022 2023 2024 2025 2026 Beyond Total\nAt Dec. 31, 2021\nInterest rate swaps\nTotal notional amount 653 169 729 582 942 5,588 8,663\nNotional amount related to IRS in euro 128 169 639 582 729 4,582 6,829\nAverage IRS rate in euro 5.0651 4.2791 0.8596 1.9099 2.2703 1.6826 \nNotional amount related to IRS in US dollars 353 - 44 - - 674 1,071\nAverage IRS rate in US dollars 3.5227 0.6950 2.4672\nMillions of euro Maturity\n2021 2022 2023 2024 2025 Beyond Total\nAt Dec. 31, 2020\nInterest rate swaps\nTotal notional amount 122 461 178 155 591 6,115 7,6 2 2\nNotional amount related to IRS in euro - 135 178 155 591 5,295 6,354\nAverage IRS rate in euro 5.0139 4.1593 4.4380 1.9058 1.8321 \nNotional amount related to IRS in US dollars 122 326 - - - 639 1,087\nAverage IRS rate in US dollars 2.0350 3.5227 2.4648 \nThe following table shows the notional amount and the fair\nvalue of the hedging instruments on the interest rate risk\nof transactions outstanding as at December 31, 2021 and\nDecember 31, 2020, broken down by type of hedged item.\nMillions of euro Fair value\nNotional\namount Fair value\nNotional\namount\nHedging instrument Hedged item\nAssets Liabilities Assets Liabilities\nat Dec. 31, 2021 at Dec. 31, 2020\nFair value hedges\nInterest rate swaps Floating-rate borrowings/bonds 13 (1) 241 15 - 126\nInterest rate swaps Fixed-rate borrowings/bonds 6 (4) 558 7 - 12\nCash \ue61dow hedges\nInterest rate swaps Floating-rate bonds - (167) 1,190 - (232) 1,190\nInterest rate swaps Floating-rate loan assets 13 (1) 164 21 - 161\nInterest rate swaps Floating-rate borrowings 6 (461) 6,510 - (708) 6,133\nTotal 38 (634) 8,663 43 (940) 7,6 2 2\n\nThe following table shows the notional amount and the\nfair value of hedging derivatives on interest rate risk as\nat December 31, 2021 and December 31, 2020, broken\ndown by type of hedge.\nMillions of euro Notional amount Fair value assets Notional amount Fair value liabilities\nDerivatives\nat Dec. 31,\n2021\nat Dec. 31,\n2020\nat Dec. 31,\n2021\nat Dec. 31,\n2020\nat Dec. 31,\n2021\nat Dec. 31,\n2020\nat Dec. 31,\n2021\nat Dec. 31,\n2020\nFair value hedges\nInterest rate swaps 139 138 19 22 660 - (5) -\nTotal 139 138 19 22 660 - (5) -\nCash \ue61dow hedges\nInterest rate swaps 404 161 19 21 7,460 7,32 3 (629) (940)\nTotal 404 161 19 21 7, 46 0 7,3 2 3 (629) (940)\nTOTAL INTEREST RATE\nDERIVATIVES\n543 299 38 43 8,120 7, 323 (634) (940)\nThe notional amount of derivatives classi\ue61eed as hedg-\ning instruments at December 31, 2021 came to \u20ac8,663\nmillion, with a corresponding negative fair value of \u20ac596\nmillion.\nCompared with December 31, 2020, the notional amount\nincreased by \u20ac1,041 million, mainly re\ue61decting:\n\u2022 the expiry of interest rate swaps amounting to \u20ac122 \nmillion;\n\u2022 the consolidation of Australian companies holding in-\nterest rate swaps amounting to \u20ac340 million;\n\u2022 new interest rate swaps amounting to \u20ac952 million. \nThe amount also re\ue61dects the reduction of \u20ac129 million in\nthe notional amount of amo\ue61fizing interest rate swaps.\nThe improvement in the fair value of \u20ac301 million mainly \nre\ue61dects developments in the yield curve.\nFair value hedge derivatives\nThe following table repo\ue61fs net gains and losses recog-\nnized through pro\ue61et or loss in respect of fair value hedge \nderivatives and the hedged item that are a\ue61cributable to \ninterest rate risk both in 2021 and the previous year. \nMillions of euro 2021 2020\nNet gain/(loss) Net gain/(loss)\nInterest rate hedging instruments (11) 15\nHedged item (8) (14)\nIne\ue61cective po\ue61bion (19) 1\nThe following table shows the impact of fair value hedges\nof interest rate risk in the statement of \ue61enancial position\nat December 31, 2021 and December 31, 2020.\n Millions of euro at Dec. 31, 2021 at Dec. 31, 2020\nNotional\namount\nCarrying\namount\nFair value used\nto measure\nine\ue61cectiveness\nin the year\nNotional\namount\nCarrying\namount\nFair value used\nto measure\nine\ue61cectiveness\nin the year\nInterest rate swaps 799 14 14 138 22 22\n\nThe following table shows the impact of the hedged item \nof fair value hedges in the statement of \ue61enancial position\nat December 31, 2021 and December 31, 2020.\n Millions of euro at Dec. 31, 2021 at Dec. 31, 2020\nCarrying\namount\nCumulative\nadjustment of\nfair value of\nhedged item\nFair value used\nto measure\nine\ue61cectiveness\nin the year\nCarrying\namount\nCumulative\nadjustment of\nfair value of\nhedged item\nFair value used\nto measure\nine\ue61cectiveness\nin the year\nFixed-rate borrowings 518 6 (5) 20 7 (7)\nFloating-rate borrowings 306 (11) 9 146 15 (15)\nTotal 824 (5) 4 166 22 (22)\nCash \ue61dow hedge derivatives\nThe following table shows the cash \ue61dows expected in\ncoming years from cash \ue61dow hedge derivatives on inter-\nest rate risk.\n Millions of euro Fair value Distribution of expected cash \ue61dows\nat Dec. 31, 2021 2022 2023 2024 2025 2026 Beyond\nCash \ue61dow hedge derivatives on interest rates\nPositive fair value 19 3 2 1 3 3 5\nNegative fair value (629) (139) (121) (96) (78) (66) (163)\n \nThe following table shows the impact of cash \ue61dow hedges \nof interest rate risk in the statement of \ue61enancial position\nat December 31, 2021 and December 31, 2020.\nMillions of euro at Dec. 31, 2021 at Dec. 31, 2020\nNotional\namount\nCarrying\namount\nFair value used\nto measure\nine\ue61cectiveness\nin the year\nNotional\namount\nCarrying\namount\nFair value used\nto measure\nine\ue61cectiveness\nin the year\nInterest rate swaps 7,864 (610) (610) 7,484 (919) (919)\nThe following table shows the impact of the hedged item \nof cash \ue61dow hedges in the statement of \ue61enancial position\nat December 31, 2021 and December 31, 2020.\nMillions of euro at Dec. 31, 2021 at Dec. 31, 2020\nFair value used\nto measure\nine\ue61cectiveness\nin the year\nFair value\nat the \ndesignation\ndate of CFH\nderivatives\nthrough \npro\ue61ft or loss\nHedging\nreserve\nHedging\ncosts \nreserve \nIne\ue61cective\npo\ue61bion of\ncarrying\namount\nof CFH\nderivatives\nFair value used\nto measure\nine\ue61cectiveness\nin the year\nFair value\nat the \ndesignation\ndate of CFH\nderivatives\nthrough \npro\ue61ft or loss\nHedging\nreserve\nHedging\ncosts \nreserve \nIne\ue61cective\npo\ue61bion of\ncarrying\namount\nof CFH\nderivatives\nFloating-rate\nbonds\n167 - (167) - - 232 - (232) - -\nFloating-rate\nloan assets\n(12) - 12 - - (21) - 21 - -\nFloating-rate\nborrowings\n417 (32) (417) - (6) 653 (44) (653) - (11)\nTotal 572 (32) (572) - (6) 864 (44) (864) - (11)\n\nCurrency risk\nThe following table repo\ue61fs the maturity pro\ue61ele of the\nnotional amount and associated average contractual ex-\nchange rate for the instruments hedging currency risk on\ntransactions outstanding at December 31, 2021 and De-\ncember 31, 2020.\nMillions of euro Maturity\n2022 2023 2024 2025 2026 Beyond Total\nAt Dec. 31, 2021\nCross currency interest rate swaps (CCIRS)\nTotal notional amount of CCIRS 258 1 ,574 4,638 1,002 1,153 12,814 21,439\nNotional amount for CCIRS EUR/USD - 1,104 2,158 661 1,104 8,632 13,659\nAverage exchange rate EUR/USD 1.3350 1.1345 1.1742 1.1790 1.2094\nNotional amount for CCIRS EUR/GBP - - 1,012 - - 3,678 4,690\nAverage exchange rate EUR/GBP 0.8765 0.8241 \nNotional amount for CCIRS EUR/CHF - - 218 - - 126 344\nAverage exchange rate EUR/CHF 1.0642 1.2100\nNotional amount for CCIRS USD/BRL 98 132 295 155 49 244 973\nAverage exchange rate USD/BRL 4.8123 5.2217 5.5483 5.2921 5.3875 3.5655\nNotional value for CCIRS EUR/BRL 160 339 402 79 - 77 1,057\nAverage exchange rate EUR/BRL 6.4122 6.4379 6.2482 6.7126 3.9197\nCurrency forwards\nTotal notional amount of forwards 4,324 1,320 371 4 - - 6,019\nNotional amount - currency forwards EUR/USD 3,064 1,268 371 4 - - 4,707\nAverage currency forward rate - EUR/USD 1.1600 1.1900 1.1800 1.1800\nNotional amount - currency forwards USD/BRL 311 - - - - - 311\nAverage currency forward rate - USD/BRL 5.6500\nNotional amount - currency forwards USD/COP 284 - - - - - 284\nAverage currency forward rate - USD/COP 3,964\nNotional amount - currency forwards EUR/CLP 145 - - - - - 145\nAverage currency forward rate - EUR/CLP 818.9400\nNotional amount - currency forwards EUR/CAD 107 - - - - - 107\nAverage currency forward rate - EUR/CAD 1.2400\n\nMillions of euro Maturity\n2021 2022 2023 2024 2025 Beyond Total\nAt Dec. 31, 2020\nCross currency interest rate swaps (CCIRS)\nTotal notional amount of CCIRS 859 1,702 3,120 3,088 1,336 10,882 20,987\nNotional amount for CCIRS EUR/USD 185 1,630 2,038 1,223 1,223 6,928 13,227\nAverage exchange rate EUR/USD 1.1348 1.1213 1.2493 1.1039 1.1593 1.2397\nNotional amount for CCIRS EUR/GBP 278 - - 946 - 3,443 4,667\nAverage exchange rate EUR/GBP 0.8248 0.8765 0.7876 \nNotional amount for CCIRS EUR/CHF - - - 208 - 120 328\nAverage exchange rate EUR/CHF 1.0642 0.9040\nNotional amount for CCIRS USD/BRL 395 71 64 - - 244 774\nAverage exchange rate USD/BRL 4.3935 4. 1779 5.1967 3.4489\nCurrency forwards\nTotal notional amount of forwards 3,684 1,871 12 - - - 5,567\nNotional amount - currency forwards EUR/USD 2,671 1,786 12 - - - 4,469\nAverage currency forward rate - EUR/USD 1. 1473 1.1535 1.1976\nNotional amount - currency forwards USD/BRL 379 37 - - - - 416\nAverage currency forward rate - USD/BRL 5.2226 5.4405\nNotional amount - currency forwards USD/COP 187 - - - - - 187\nAverage currency forward rate - USD/COP 3,782\nNotional amount - currency forwards EUR/CLP 121 - - - - - 121\nAverage currency forward rate - EUR/CLP 716.8847\nNotional amount - currency forwards EUR/RUB 100 - - - - - 100\nAverage currency forward rate - EUR/RUB 91.8464\n\nThe following table shows the notional amount and the\nfair value of the hedging instruments on the currency risk\nof transactions outstanding as at December 31, 2021 and\nDecember 31, 2020, broken down by type of hedged item.\nMillions of euro Fair value\nNotional\namount Fair value\nNotional\namount\nHedging instrument Hedged item Assets Liabilities Assets Liabilities\nat Dec. 31, 2021 at Dec. 31, 2020\nFair value hedges\nCross currency interest rate\nswaps (CCIRS)\nFixed-rate borrowings/bonds in\nforeign currencies\n12 - 595 28 - 639\nCross currency interest rate\nswaps (CCIRS)\nFloating-rate borrowings in\nforeign currencies\n30 - 77 28 - 79\nCash \ue61dow hedges\nCross currency interest rate\nswaps (CCIRS)\nFloating-rate borrowings/\n\ue61enancial assets in foreign\ncurrencies\n88 (19) 953 67 (15) 579\nCross currency interest rate\nswaps (CCIRS)\nFixed-rate borrowings in foreign\ncurrencies\n43 (58) 2,553 50 - 484\nCross currency interest rate\nswaps (CCIRS)\nFloating-rate bonds in foreign\ncurrencies\n37 - 344 12 - 356\nCross currency interest rate\nswaps (CCIRS)\nFixed-rate bonds in foreign\ncurrencies\n1,159 (1,095) 16,601 588 (2,374) 18,499\nCross currency interest rate\nswaps (CCIRS)\nFuture cash \ue61dows denominated\nin foreign currencies\n- (75) 316 7 (4) 351\nCurrency forwards\nFuture cash \ue61dows denominated\nin foreign currencies\n7 (3) 378 3 (12) 574\nCurrency forwards\nFuture commodity purchases\ndenominated in foreign\ncurrencies\n106 (36) 4,802 5 (309) 4,167\nCurrency forwards\nPurchases of investment goods\nand other in foreign currency\n20 (7) 839 4 (40) 825\nTotal 1,502 (1,293) 27, 4 5 8 792 (2,754) 26,553\nCash \ue61dow hedges and fair value hedges include:\n\u2022 CCIRSs with a notional amount of \u20ac19,749 million used \nto hedge the currency risk on \ue61exed-rate debt denomi-\nnated in currencies other than the euro, with a positive\nfair value of \u20ac61 million;\n\u2022 CCIRSs with a notional amount of \u20ac1,690 million used to \nhedge the currency risk on \ue61doating-rate debt denomi-\nnated in currencies other than the euro, with a positive\nfair value of \u20ac61 million;\n\u2022 currency forwards with a notional amount of \u20ac5,180 \nmillion used to hedge the currency risk associated with\npurchases of natural gas, purchases of fuel and expect-\ned cash \ue61dows in currencies other than the euro, with a\npositive fair value of \u20ac74 million;\n\u2022 currency forwards with a notional amount of \u20ac839 mil-\nlion and a positive fair value of \u20ac13 million in respect of\nOTC transactions to mitigate the currency risk on ex-\npected cash \ue61dows in currencies other than the pres-\nentation currency connected with the purchase of in-\nvestment goods in the renewables and infrastructure\nand networks sectors (new generation digital meters),\non operating costs for the supply of cloud services and\non revenue from the sale of renewable energy.\n\nThe following table repo\ue61fs the notional amount and fair\nvalue of foreign exchange derivatives at December 31,\n2021 and December 31, 2020, broken down by type of\nhedge.\nMillions of euro Notional amount Fair value assets Notional amount Fair value liabilities\nDerivatives\nat Dec. 31,\n2021\nat Dec. 31,\n2020\nat Dec. 31,\n2021\nat Dec. 31,\n2020\nat Dec. 31,\n2021\nat Dec. 31,\n2020\nat Dec. 31,\n2021\nat Dec. 31,\n2020\nFair value hedges\nCCIRS 672 718 42 56 - - - -\nTotal 672 718 42 56 - - - -\nCash \ue61dow hedges\nCurrency forwards 4, 117 476 133 12 1,902 5,090 (46) (361)\nCCIRS 13,553 5,582 1,327 724 7, 2 14 14,687 (1,247) (2,393)\nTotal 17,670 6,058 1,460 736 9,116 19,777 (1,293) (2,754)\nTOTAL EXCHANGE RATE\nDERIVATIVES\n18,342 6,776 1,502 792 9,116 19,777 (1,293) (2,754)\nThe notional amount of CCIRSs at December 31, 2021\namounted to \u20ac21,439 million (\u20ac20,987 million at Decem-\nber 31, 2020), an increase of \u20ac452 million. Cross currency\ninterest rate swaps with a total amount of \u20ac859 million ex-\npired, while new derivatives amounted to \u20ac6,470 million,\nof which \u20ac3,532 million in respect of bond issues denom-\ninated in US dollars in July 2021. In addition, following the\nearly redemption of conventional bonds in US dollars by\nEnel Finance International during the year, cross currency\ninterest rate swaps of \u20ac5,909 million were terminated ear-\nly. The amount also re\ue61dects developments in the exchange\nrate of the euro against the main other currencies and the\ne\ue61bect of amo\ue61fization, which caused their notional amount\nto increase by \u20ac750 million.\nThe notional amount of currency forwards at December\n31, 2021 amounted to \u20ac6,019 million (\u20ac5,566 million at De-\ncember 31, 2020), an increase of \u20ac453 million. The expo-\nsure to currency risk, especially that associated with the\nUS dollar, is mainly due to purchases of natural gas, pur-\nchases of fuel and cash \ue61dows in respect of investments.\nChanges in the notional amount are connected with nor-\nmal developments in operations.\nFair value hedge derivatives\nThe following table repo\ue61fs net gains and losses recog-\nnized through pro\ue61et or loss, re\ue61decting changes in the fair\nvalue of fair value hedge derivatives and the hedged item\nthat are a\ue61cributable to currency risk for 2021 and the pre-\nvious year.\nMillions of euro 2021 2020\nNet gain/(loss) Net gain/(loss)\nInterest rate hedging instruments 1 44\nHedged item (2) (51)\nIne\ue61cective po\ue61bion (1) (7)\nThe following table shows the impact of fair value hedges\nof currency risk in the statement of \ue61enancial position at\nDecember 31, 2021 and December 31, 2020.\n Millions of euro at Dec. 31, 2021 at Dec. 31, 2020\nNotional\namount\nCarrying\namount\nFair value used\nto measure\nine\ue61cectiveness\nin the year\nNotional\namount\nCarrying\namount\nFair value used\nto measure\nine\ue61cectiveness\nin the year\nCross currency interest rate swaps\n(CCIRS)\n672 42 37 718 56 56\n\nThe following table shows the impact of the hedged item\nof fair value hedges in the statement of \ue61enancial position\nat December 31, 2021 and December 31, 2020.\n Millions of euro at Dec. 31, 2021 at Dec. 31, 2020\nCarrying\namount\nCumulative\nadjustment of\nfair value of\nhedged item\nFair value used\nto measure\nine\ue61cectiveness\nin the year\nCarrying\namount\nCumulative\nadjustment of\nfair value of\nhedged item\nFair value used\nto measure\nine\ue61cectiveness\nin the year\nFixed-rate borrowings in foreign currency 639 (35) (44) 637 34 (34)\nFloating-rate borrowings in foreign\ncurrency\n- - - 79 28 (28)\nTotal 639 (35) (44) 716 62 (62)\nCash \ue61dow hedge derivatives\nThe following table shows the cash \ue61dows expected in com-\ning years from cash \ue61dow hedge derivatives on currency\nrisk.\n Millions of euro Fair value Distribution of expected cash \ue61dows\nat Dec. 31,\n2021 2022 2023 2024 2025 2026 Beyond\nCash \ue61dow hedge derivatives on exchange rates\nPositive fair value 1,460 305 407 247 180 205 1,780\nNegative fair value (1,293) (9) 13 (66) (49) (27) (256)\nThe following table shows the impact of cash \ue61dow hedges\nof currency risk in the statement of \ue61enancial position at\nDecember 31, 2021 and December 31, 2020.\n Millions of euro at Dec. 31, 2021 at Dec. 31, 2020\nNotional\namount\nCarrying\namount\nFair value used\nto measure\nine\ue61cectiveness\nin the year\nNotional\namount\nCarrying\namount\nFair value used\nto measure\nine\ue61cectiveness\nin the year\nCross currency interest rate swaps\n(CCIRS)\n20,767 80 82 20,269 (1,669) (1,463)\nCurrency forwards 6,019 87 89 5,566 (349) (342)\nTotal 26,786 167 171 25,835 (2,018) (1,805)\n\nThe following table shows the impact of the hedged item\nof cash \ue61dow hedges in the statement of \ue61enancial position\nat December 31, 2021 and December 31, 2020.\n Millions of euro at Dec. 31, 2021 at Dec. 31, 2020\nFair value used\nto measure\nine\ue61cectiveness\nin the year\nHedging\nreserve\nHedging\ncosts\nreserve\nIne\ue61cective\npo\ue61bion of\ncarrying\namount\nof CFH\nderivatives\nFair value used\nto measure\nine\ue61cectiveness\nin the year\nHedging\nreserve\nHedging\ncosts\nreserve\nIne\ue61cective\npo\ue61bion of\ncarrying\namount\nof CFH\nderivatives\nFloating-rate borrowings in\nforeign currencies\n(69) 69 - - (52) 52 - -\nFixed-rate borrowings in foreign\ncurrencies\n15 (15) - - (50) 50 - -\nFloating-rate bonds in foreign\ncurrencies\n(37) 37 - - (12) 12 - -\nFixed-rate bonds in foreign\ncurrencies\n(66) 66 (2) - 1,580 (1,580) (205) -\nFuture cash \ue61dows denominated in\nforeign currencies (hedged with\nCCIRSs)\n75 (75) - - (3) 3 - -\nFuture cash \ue61dows denominated in\nforeign currencies (hedged with\nforwards)\n(2) 2 1 - 7 (7) (3) -\nFuture commodity purchases\ndenominated in foreign currencies\n(72) 72 - - 305 (305) - 1\nPurchases of investment goods\nand other in foreign currency\n(15) 15 (3) - 30 (30) (5) (1)\nTotal (171) 171 (4) - 1,805 (1,805) (213) -\n\nCommodity price risk\nMillions of euro Maturity\n2022 2023 2024 2025 2026 Beyond Total\nAt Dec. 31, 2021\nCommodity swaps\nNotional value on power 124 164 168 149 146 472 1,223\nAverage commodity swap price on power (\u20ac/MWh) 51.8 53.7 47.5 46.6 46.0 33.2\nNotional value on gas 131 372 129 11 17 93 753\nAverage commodity swap price on gas (\u20ac/MWh) 63.8 13.7 12.1 9.4 12.0 9.6\nNotional amount on oil 669 244 99 - - - 1,012\nAverage commodity swap price on oil ($/bbl) 86.4 92.9 79.4\nCommodity forwards/futures\nNotional value on power 319 637 302 288 248 856 2,650\nAverage commodity forward/future price on power (\u20ac/MWh) 29.7 43.3 20.0 19.7 18.7 16.6\nNotional value on coal/shipping 14 - - - - - 14\nAverage commodity forward/future price on coal/shipping ($/ton) 90.8\nNotional value on gas 3,315 1,048 5 - - - 4,368\nAverage commodity forward/future price on gas (\u20ac/MWh) 15.1 18.9 18.0\nNotional value on CO\n2\n476 61 - - - - 537\nAverage commodity forward/future price on CO\n2\n (\u20ac/ton) 46.1 38.4\nNotional value on oil 600 57 - - - - 657\nAverage commodity forward/future price on oil ($/bbl) 37.7 51.6\nCommodity options\nNotional value on power 10 21 21 21 21 134 228\nAverage commodity option price on power (\u20ac/MWh) 26.3 29.3 29.9 29.8 29.8 32.6\nNotional value on gas 99 - - - - - 99\nAverage commodity option price on gas (\u20ac/MWh) 50.5\nMillions of euro Maturity\n2021 2022 2023 2024 2025 Beyond Total\nAt Dec. 31, 2020\nCommodity swaps\nNotional value on power 78 65 64 65 53 281 606\nAverage commodity swap price on power (\u20ac/MWh) 40.3 37. 9 37.7 37.7 37.6 37.7\nNotional value on coal/shipping 32 2 - - - - 34\nAverage commodity swap price on coal/shipping ($/ton) 51.2 57.9\nNotional value on gas - - - - - - -\nAverage commodity swap price on gas (\u20ac/MWh)\nCommodity forwards/futures\nNotional value on power 1,065 244 246 197 191 741 2,684\nAverage commodity forward/future price on power (\u20ac/MWh) 43.2 25.0 19.1 17. 9 17.4 15.2\nNotional value on gas 1,521 973 17 20 20 108 2,659\nAverage commodity forward/future price on gas (\u20ac/MWh) 14.3 14.9 15.2 4.9 4.9 2.5\nNotional value on CO\n2\n317 134 37 - - - 488\nAverage commodity forward/future price on CO\n2\n (\u20ac/ton) 24.2 26.6 27.9\nNotional value on oil 744 413 - - - - 1,157\nAverage commodity forward/future price on oil ($/bbl) 45.0 44.3\nCommodity options\nNotional value on power - 8 9 9 9 45 80\nAverage commodity option price on power (\u20ac/MWh) 29.7 26.4 26.4 26.4 31.7\n\nThe following table repo\ue61fs the notional amount and fair\nvalue of instruments hedging commodity price risk on\ntransactions outstanding at December 31, 2021 and De-\ncember 31, 2020, broken down by type of commodity.\nMillions of euro Notional amount Fair value assets Notional amount Fair value liabilities\nat Dec. 31,\n2021\nat Dec. 31,\n2020\nat Dec. 31,\n2021\nat Dec. 31,\n2020\nat Dec. 31,\n2021\nat Dec. 31,\n2020\nat Dec. 31,\n2021\nat Dec. 31,\n2020\nDerivatives\nCash \ue61dow hedges\nDerivatives on power:\n- swaps 820 369 640 70 401 236 (263) (56)\n- forwards/futures 769 2,066 351 361 1,881 571 (598) (16)\n- options 229 70 49 - - - (18) -\nTotal derivatives on power 1,818 2,505 1,040 431 2,282 807 (879) (72)\nDerivatives on coal/shipping:\n- swaps - 34 - 11 - - - -\n- forwards/futures 14 - 3 - - - - -\n- options - - - - - - - -\nTotal derivatives on coal/shipping 14 34 3 11 - - - -\nDerivatives on gas and oil:\n- swaps 669 - 69 - 1,095 - (99) -\n- forwards/futures 3,094 1,674 2,557 456 1,932 2,189 (5,150) (455)\n- options 30 11 3 18 70 - (26) -\nTotal derivatives on gas and oil 3,793 1,685 2,629 474 3,097 2,189 (5,275) (455)\nDerivatives on CO\n2\n:\n- swaps - - - - - - - -\n- forwards/futures 537 482 410 139 - 5 - -\n- options - - - - - - - -\nTotal derivatives on CO\n2\n537 482 410 139 - 5 - -\nTOTAL COMMODITY DERIVATIVES 6,162 4,706 4,082 1,055 5,379 3,001 (6,154) (527)\nThe table repo\ue61fs the notional amount and fair value of de-\nrivatives hedging commodity price risk at December 31,\n2021 and at December 31, 2020, broken down by type of\nhedge.\nThe positive fair value of cash \ue61dow hedge derivatives on\ncommodities regards derivatives on gas and oil commod-\nities in the amount of \u20ac2,629 million, derivatives on CO\n2\n \n(\u20ac410 million), derivatives on power (\u20ac1,040 million) and, to\na lesser extent, hedges of coal purchases requested by the\ngeneration companies in the amount of \u20ac3 million.\nThe \ue61erst category primarily regards hedges of \ue61ductuations\nin the price of natural gas, for both purchases and sales,\ncarried out for oil commodities and gas products.\nThe CO\n2\n category mainly includes hedging transactions\nunde\ue61faken for Enel Group compliance purposes.\nThe power category mainly includes medium/long-term\nhedging transactions, especially in Spain and No\ue61fh Amer-\nica.\nCash \ue61dow hedge derivatives on commodities included in\nliabilities regard derivatives on gas and oil commodities in\nthe amount of \u20ac5,275 million (mainly for derivatives hedg-\ning sales) and derivatives on power in the amount of \u20ac879\nmillion.\n\nCash \ue61dow hedge derivatives\nThe following table shows the cash \ue61dows expected in com-\ning years from cash \ue61dow hedge derivatives on commodity\nprice risk.\n Millions of euro Fair value Distribution of expected cash \ue61dows\nat Dec. 31,\n2021 2022 2023 2024 2025 2026 Beyond\nCash \ue61dow hedge derivatives on commodities\nPositive fair value 4,082 2,960 720 122 72 45 163\nNegative fair value (6,154) (4,892) (858) (126) (84) (58) (136)\nThe following table shows the impact of cash \ue61dow hedges\nof commodity price risk in the statement of \ue61enancial posi-\ntion at December 31, 2021 and December 31, 2020.\n Millions of euro at Dec. 31, 2021 at Dec. 31, 2020\nNotional\namount\nCarrying\namount\nFair value used\nto measure\nine\ue61cectiveness\nin the year\nNotional\namount\nCarrying\namount\nFair value used\nto measure\nine\ue61cectiveness\nin the year\nPower swaps 1,221 377 377 605 23 23\nCoal/shipping swaps - - - 34 11 11\nGas and oil swaps 1,764 (30) (30) - - -\nPower forwards/futures 2,675 (223) (223) 2,717 375 356\nCoal/shipping forwards/futures 14 3 3 - - -\nGas and oil forwards/futures 5,027 (2,592) (2,592) 3,794 (20) (20)\nCO\n2\n forwards/futures 537 410 410 487 139 139\nPower options 204 7 7 70 - -\nGas and oil options 99 (24) (24) - - -\nTotal 11,541 (2,072) (2,072) 7,7 07 528 509\nThe following table shows the impact of the hedged item\nof cash \ue61dow hedges in the statement of \ue61enancial position\nat December 31, 2021 and December 31, 2020.\n Millions of euro at Dec. 31, 2021 at Dec. 31, 2020\nFair value used\nto measure\nine\ue61cectiveness\nin the year\nHedging\nreserve\nHedging\ncosts\nreserve\nIne\ue61cective\npo\ue61bion of\ncarrying\namount\nof CFH\nderivatives\nFair value used\nto measure\nine\ue61cectiveness\nin the year\nHedging\nreserve\nHedging\ncosts\nreserve\nIne\ue61cective\npo\ue61bion of\ncarrying\namount\nof CFH\nderivatives\nFuture transactions in power (297) 297 - (29) (316) 374 - 24\nFuture transactions in coal/\nshipping\n(3) 3 - - (11) 11 - -\nFuture transactions in gas\nand oil\n2,751 (2,751) - (2) 20 (20) - -\nFuture transactions in CO\n2\n(410) 410 - - (139) 139 - -\nTotal 2,041 (2,041) - (31) (446) 504 - 24\nFinally, with regard to cash \ue61dow hedge derivatives on com-\nmodity prices, in 2021 the entire commodities market\nexperienced major price swings. The greatest impact in\nterms of changes in the hedging reserve is a\ue61cributable to\nfuture transactions in gas, which of all commodities was\nthe one most a\ue61bected by the high volatility.\n\n49.2 Derivatives at fair value through pro\ue61ft or loss\nThe following table shows the notional amount and the fair\nvalue of derivatives at FVTPL as at December 31, 2021 and\nDecember 31, 2020.\nMillions of euro Notional amount Fair value assets Notional amount Fair value liabilities\nat Dec. 31,\n2021\nat Dec. 31,\n2020\nat Dec. 31,\n2021\nat Dec. 31,\n2020\nat Dec. 31,\n2021\nat Dec. 31,\n2020\nat Dec. 31,\n2021\nat Dec. 31,\n2020\nDerivatives at FVTPL\non interest rates:\n- interest rate swaps 50 50 1 2 100 100 (71) (88)\n- interest rate options - - - - 50 50 (2) (4)\non exchange rates:\n- currency forwards 2,180 3,501 23 83 3,628 1,012 (62) (44)\n- CCIRSs - - - - - - - -\non commodities\nDerivatives on power:\n- swaps 777 144 (78) 14 1,088 109 (198) (18)\n- forwards/futures 23,207 5,493 3,368 75 17, 97 0 5,626 (2,927) (428)\n- options 3 137 78 24 113 9 (16) (12)\nTotal derivatives on\npower\n23,987 5,774 3,368 113 19,171 5,744 (3,141) (458)\nDerivatives on coal:\n- swaps 35 47 4 4 133 16 23 (1)\n- forwards/futures 213 200 63 40 455 144 (148) (27)\n- options - - - - - - - -\nTotal derivatives on coal 248 247 67 44 588 160 (125) (28)\nDerivatives on gas and oil:\n- swaps 2,904 635 (1,049) 81 4,199 259 1,843 (34)\n- forwards/futures 19,001 13,993 16,706 2,108 16,755 14, 121 (17,374) (1,999)\n- options 232 185 268 165 399 170 (402) (173)\nTotal derivatives on gas\nand oil\n22,137 14,813 15,925 2,354 21,353 14,550 (15,933) (2,206)\nDerivatives on CO\n2\n:\n- swaps - - - - - - - -\n- forwards/futures 3,079 770 557 209 1,366 290 (530) (72)\n- options - - - - - 5 - (5)\nTotal derivatives on CO\n2\n3,079 770 557 209 1,366 295 (530) (77)\nDerivatives on other:\n- swaps - - - - 1 13 (1) (7)\n- forwards/futures - 195 - 9 - 234 - (1)\n- options - - - - - - - -\nTotal derivatives on other - 195 - 9 1 247 (1) (8)\nEmbedded derivatives - 4 - 3 - 3 - (3)\nTOTAL 51,681 25,354 19,941 2,817 46,257 22,161 (19,865) (2,916)\nAt December 31, 2021 the notional amount of trading deriv-\natives on interest rates came to \u20ac200 million. The negative\nfair value of \u20ac72 million improved by \u20ac18 million on the pre-\nvious year, mainly due to developments in the yield curve.\nAt December 31, 2021, the notional amount of derivatives\non exchange rates was \u20ac5,808 million. The overall increase\nin their notional value of \u20ac1,295 million and the decrease in\nthe associated net fair value of \u20ac78 million mainly re\ue61dected\nnormal operations and developments in exchange rates.\n\nAt December 31, 2021, the notional amount of derivatives\non commodities came to \u20ac91,930 million. The fair value\nof trading derivatives on commodities classi\ue61eed as assets\nmainly re\ue61dects the market valuation of hedges of gas and\noil amounting to \u20ac15,925 million, derivatives on power\namounting to \u20ac3,368 million, derivatives on CO\n2\n amount-\ning to \u20ac557 million and, to a lesser extent, derivatives on\ncoal totaling \u20ac67 million.\nThe fair value of trading derivatives on commodities\nclassi\ue61eed as liabilities mainly regards hedges of gas and\noil amounting to \u20ac15,933 million, derivatives on power\namounting to \u20ac3,141 million and derivatives on CO\n2\n and\ncoal in the amount of \u20ac530 million and \u20ac125 million, re-\nspectively.\nThese amounts include transactions managed within the\ntrading po\ue61ffolios and transactions that, although estab-\nlished for hedging purposes, did not meet the require-\nments for hedge accounting.\nThe \u201cother\u201d category includes hedges using weather deriv-\natives. In addition to commodity risk, the Group companies\nare also exposed to changes in volumes associated with\nweather conditions (for example, temperature impacts the\nconsumption of gas and power).\n",
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"concept": "ifrs-full:DisclosureOfHedgeAccountingExplanatory",
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"period": "2021-01-01T00:00:00/2022-01-01T00:00:00"
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"Tag41": {
"value": "\n50. Assets and liabilities measured at fair\nvalue\nThe Group determines fair value in accordance with IFRS 13\nwhenever such measurement is required by the IFRSs as a\nrecognition or measurement criterion.\nFair value is de\ue61ened as the price that would be received to\nsell an asset or paid to transfer a liability, in an orderly trans-\naction, between market pa\ue61ficipants, at the measurement\ndate (i.e., an exit price).\nThe best proxy of fair value is market price, i.e., the current\npublicly available price actually used on a liquid and active \nmarket.\nThe fair value of assets and liabilities is classi\ue61eed in ac-\ncordance with the three-level hierarchy described below,\ndepending on the inputs and valuation techniques used in\ndetermining their fair value:\n\u2022 Level 1, where the fair value is determined on the basis \nof quoted prices (unadjusted) in active markets for iden-\ntical assets or liabilities that the entity can access at the\nmeasurement date;\n\u2022 Level 2, where the fair value is determined on the basis of \ninputs other than quoted prices included within Level 1 \nthat are observable for the asset or liability, either directly\n(such as prices) or indirectly (derived from prices);\n\u2022 Level 3, where the fair value is determined on the basis of \nunobservable inputs.\nThis note also provides detailed disclosures concerning\nthe valuation techniques and inputs used to pe\ue619orm these\nmeasurements.\nTo that end:\n\u2022 recurring fair value measurements of assets or liabilities \nare those required or permi\ue61ced by the IFRSs in the state-\nment of \ue61enancial position at the close of each period;\n\u2022 non-recurring fair value measurements are those re-\nquired or permi\ue61ced by the IFRSs in the statement of \ue61e-\nnancial position in pa\ue61ficular circumstances.\nFor general information or speci\ue61ec disclosures on the ac-\ncounting treatment of these circumstances, please see\nnote 2 \u201cAccounting policies\u201d.\n50.1 Assets measured at fair value in the\nstatement of \ue61fnancial position\nThe following table shows, for each class of assets meas-\nured at fair value on a recurring or non-recurring basis in\nthe statement of \ue61enancial position, the fair value measure-\nment at the end of the repo\ue61fing period and the level in the\nfair value hierarchy into which the fair value measurements\nof those assets are classi\ue61eed.\n\nMillions of euro Non-current assets Current assets\nNotes Fair value Level 1 Level 2 Level 3 Fair value Level 1 Level 2 Level 3\nat Dec. 31, 2021 at Dec. 31, 2021\nEquity investments in other companies at FVOCI 28 41 4 15 22 - - - -\nSecurities at FVOCI 28.1, 29.1 404 404 - - 87 87 - -\nSecurities at FVTPL 29.1 - - - - 1 1 - -\nEquity investments in other companies at FVTPL 28 32 23 - 9 - - - -\nFinancial assets from service concession\narrangements at FVTPL\n28 2,630 - 2,630 - - - - -\nLoan assets and other \ue61enancial assets measured at\nfair value\n28 25 - - 25 140 140 - -\nFair value hedge derivatives:\n- on interest rates 49 19 - 19 - - - - -\n- on exchange rates 49 42 - 42 - - - - -\nCash \ue61dow hedge derivatives:\n- on interest rates 49 19 - 19 - - - - -\n- on exchange rates 49 1,356 - 1,356 - 104 - 104 -\n- on commodities 49 1,059 332 387 340 3,023 1,066 1,681 276\nTrading derivatives:\n- on interest rates 49 - - - - 1 - 1 -\n- on exchange rates 49 - - - - 23 - 23 -\n- on commodities 49 277 114 162 1 19,640 8,236 11,404 -\nInventories measured at fair value 49 - - - - 55 53 2 -\nContingent consideration 30, 31 - - - - 15 - 2 13\nThe fair value of \u201cEquity investments in other companies\nat FVOCI\u201d is determined for listed companies on the basis \nof the quoted price at the close of the year, while that for\nunlisted companies is based on a reliable valuation of the\nrelevant assets and liabilities.\n\u201cFinancial assets from service concession arrangements at\nFVTPL\u201d concern electricity distribution operations in Brazil,\nmainly by Enel Distribui\u00e7\u00e3o Rio de Janeiro, Enel Distribui\u00e7\u00e3o\nCear\u00e1, and Enel Distribui\u00e7\u00e3o S\u00e3o Paulo, as well as the gener-\nation plant of PH Chucas in Costa Rica, and are accounted\nfor in accordance with IFRIC 12.\nFair value was estimated as the net replacement cost based\non the most recent rate information available and on the\ngeneral price index for the Brazilian market.\nThe current po\ue61fion of \u201cLoan assets and other \ue61enancial as-\nsets measured at fair value\u201d essentially regards investments\nof liquidity. Their fair value is determined using Level 1 mar-\nket inputs.\nLevel 3 of the non-current po\ue61fion of \u201cLoan assets and other\n\ue61enancial assets measured at fair value\u201d repo\ue61fs the receiv-\nable in respect of the sale of Slovak Power Holding, which\namounted to \u20ac25 million at December 31, 2021. Its fair value\nwas determined using the contractual price formula.\nThe fair value of derivative contracts is determined using the\no\ue61acial prices for instruments traded on regulated markets.\nThe fair value of instruments not listed on a regulated mar-\nket is determined using valuation methods appropriate for\neach type of \ue61enancial instrument and market data as of the\nend of the repo\ue61fing period (such as interest rates, exchange\nrates, volatility), discounting expected future cash \ue61dows on\nthe basis of the market yield curve and translating amounts\nin currencies other than the euro using exchange rates pro-\nvided by the World Markets Re\ue61enitiv (WMR) Company.\nDerivatives on interest rates and exchange rates are all\nmeasured using Level 2 inputs.\nThe fair value of derivatives on commodities is almost al-\nways measured using Level 1 or Level 2 inputs, as the deter-\nmination is based on market inputs as these contracts are\nentered into with exchange counterpa\ue61fies, leading sector\noperators or \ue61enancial institutions.\nMarginal exceptions for both cash \ue61dow hedges and trading\ntransactions include ce\ue61fain derivatives relating to weather\nderivatives, which are measured on the basis of ce\ue61fi\ue61eed\nhistorical data for the underlying variables as well as cer-\ntain long-term \ue61enancial contracts (vi\ue61fual power purchase\nagreements, or VPPAs), for which internal measurement\nmodels were also used in pa\ue61f in order to measure these in-\nstruments over longer time horizons, given the illiquidity of\nthe underlying variables.\nIn accordance with the IFRSs, the Group assesses credit\nrisk, both of the counterpa\ue61fy (Credit Valuation Adjustment\nor CVA) and its own (Debit Valuation Adjustment or DVA), in\norder to adjust the fair value of \ue61enancial instruments for the\n\ncorresponding amount of counterpa\ue61fy risk where neces-\nsary. More speci\ue61ecally, the Group measures CVA/DVA us-\ning a Potential Future Exposure valuation technique for the\nnet exposure of the position and subsequently allocating\nthe adjustment to the individual \ue61enancial instruments that\nmake up the overall po\ue61ffolio. All of the inputs used in this\ntechnique are observable on the market.\n50.2 Assets not measured at fair value in the\nstatement of \ue61fnancial position\nFor each class of assets not measured at fair value on a\nrecurring basis but whose fair value must be repo\ue61fed, the\nfollowing table repo\ue61fs the fair value at the end of the year \nand the level in the fair value hierarchy into which the fair\nvalue measurements of those assets are classi\ue61eed.\nMillions of euro Non-current assets Current assets\nNotes Fair value Level 1 Level 2 Level 3 Fair value Level 1 Level 2 Level 3\nat Dec. 31,\n2021\nat Dec. 31,\n2021\nInvestment prope\ue61fy 21 150 15 - 135 - - - -\nInventories 32 - - - - 50 - 1 49\nThe table repo\ue61fs the fair value of investment prope\ue61fy and\ninventories of real estate not used in the business in the\namount of \u20ac150 million and \u20ac50 million respectively. The\namounts were calculated with the assistance of apprais-\nals conducted by independent expe\ue61fs, who used di\ue61berent\nmethods depending on the speci\ue61ec assets involved.\n50.3 Liabilities measured at fair value \nin the statement of \ue61fnancial position\nThe following table repo\ue61fs for each class of liabilities\nmeasured at fair value on a recurring or non-recurring\nbasis in the statement of \ue61enancial position the fair value\nmeasurement at the end of the repo\ue61fing period and the\nlevel in the fair value hierarchy into which the fair value\nmeasurements are classi\ue61eed.\nMillions of euro Non-current liabilities Current liabilities\nNotes Fair value Level 1 Level 2 Level 3 Fair value Level 1 Level 2 Level 3\nat Dec. 31,\n2021\nat Dec. 31,\n2021\nFair value hedge derivatives:\n- on interest rates 49 5 - 5 - - - - -\n- on exchange rates 49 - - - - - - - -\n- on commodities 49 - - - - - - - -\nCash \ue61dow hedge derivatives:\n- on interest rates 49 620 - 620 - 9 - 9 -\n- on exchange rates 49 1,244 - 1,244 - 49 - 49 -\n- on commodities 49 1,301 416 742 143 4,853 2,366 2,480 7\nTrading derivatives:\n- on interest rates 49 - - - - 73 - 73 -\n- on exchange rates 49 2 - 2 - 60 - 60 -\n- on commodities 49 167 72 95 - 19,563 7,6 28 11,934 1\nContingent consideration 40, 41 84 - - 84 45 - 43 2\nContingent consideration mainly regards a number of eq-\nuity investments held by the Group in No\ue61fh America and\nGreece, whose fair value was determined on the basis of\nthe contractual terms and conditions.\n\n50.4 Liabilities not measured at fair value \nin the statement of \ue61fnancial position\nFor each class of liabilities not measured at fair value in the\nstatement of \ue61enancial position but whose fair value must\nbe repo\ue61fed, the following table repo\ue61fs the fair value at the\nend of the period and the level in the fair value hierarchy\ninto which the fair value measurements of those liabilities\nare classi\ue61eed.\nMillions of euro\nNotes Fair value Level 1 Level 2 Level 3\nat Dec. 31, 2021\nBonds:\n- \ue61exed rate 46.3.1 42,949 39,709 3,240 -\n- \ue61doating rate 46.3.1 3,273 147 3,126 -\nBank borrowings:\n- \ue61exed rate 46.3.1 2,298 - 2,298 -\n- \ue61doating rate 46.3.1 11,091 - 11,091 -\nNon-bank borrowings:\n- \ue61exed rate 46.3.1 3,046 - 3,046 -\n- \ue61doating rate 46.3.1 95 - 95 -\nTotal 62,752 39,856 22,896 - \nFor listed debt instruments, the fair value is given by o\ue61acial\nprices. For unlisted instruments the fair value is determined\nusing appropriate valuation techniques for each category\nof \ue61enancial instrument and market data at the close of the\nyear, including the credit spreads of Enel.\n",
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"concept": "ifrs-full:DisclosureOfFairValueMeasurementExplanatory",
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"period": "2021-01-01T00:00:00/2022-01-01T00:00:00"
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"Tag42": {
"value": "\nOther information\n51. Share-based payments\nSta\ue61fing in 2019, the Shareholders\u2019 Meeting of Enel SpA\n(\u201cEnel\u201d or the \u201cCompany\u201d) has each year approved the\nadoption of long-term share-based incentive plans for the\nmanagement of Enel and/or its subsidiaries pursuant to\nA\ue61ficle 2359 of the Italian Civil Code. Each of the incentive\nplans approved (the 2019 Long-Term Incentive Plan, the\n2020 Long-Term Incentive Plan and the 2021 Long-Term\nIncentive Plan; referred to hereinafter, respectively, the\n\u201c2019 LTI Plan\u201d, the \u201c2020 LTI Plan\u201d and the \u201c2021 LTI Plan\u201d\nand, jointly, the \u201cPlans\u201d) provides for the grant of ordinary\nCompany shares (\u201cShares\u201d) to the respective bene\ue61eciaries\nsubject to the achievement of speci\ue61ec pe\ue619ormance tar-\ngets.\nPlan bene\ue61eciaries are the Chief Executive O\ue61acer/General\nManager of Enel and Enel Group managers in the positions\nmost directly responsible for company pe\ue619ormance or\nconsidered to be of strategic interest. The Plans provide\nfor the award to the bene\ue61eciaries of an incentive consist-\ning of a monetary component and an equity component.\nThis incentive \u2013 determined, at the time of the award, as\na base value calculated in relation to the \ue61exed remuner-\nation of the individual bene\ue61eciary \u2013 may vary depending\non the degree of achievement of each of the three-year\npe\ue619ormance targets of the Plans, ranging from zero up to\na maximum of 280% or 180% of the base value in the case,\nrespectively, of the Chief Executive O\ue61acer/General Man-\nager or the other bene\ue61eciaries.\nThe Plans establish that, of the total incentive e\ue61bectively\nvested, the bonus will be fully paid in shares in the amount\nof (i) up to 100% of the base value for the Chief Executive\nO\ue61acer/General Manager and (ii) up to 50% of the base val-\nue for the other bene\ue61eciaries.\nThe actual award of the bonus under the Plans is subject\nto the achievement of speci\ue61ec pe\ue619ormance targets dur-\ning the three year pe\ue619ormance period. If these targets are\nachieved, 30% of both the equity and cash components\nof the incentive will be paid in the \ue61erst year following the\nend of the pe\ue619ormance period and the remaining 70% will\nbe paid in the second year following the end of the per-\nformance period. The payment of a substantial po\ue61fion\nof long-term variable remuneration (70% of the total) is\ntherefore deferred to the second year following the end of\nthe pe\ue619ormance period of the individual Plans.\nThe following table provides information on the 2019 LTI\nPlan, the 2020 LTI Plan and the 2021 LTI Plan.\nFor more information on the characteristics of the Plans,\nplease see the information documents prepared pursuant\n\nto A\ue61ficle 84-bis of the CONSOB Regulation issued with\nResolution no. 11971 of May 14, 1999 (the Issuers Regu-\nlation), which are available to the public in the section of\n(28) The date on which the Board of Directors approved the procedures and timing for granting the 2019 LTI Plan to the bene\ue61eciaries (taking account of the \nproposal issued by the Nomination and Compensation Commi\ue61cee at its meeting of November 11, 2019).\n(29) On the occasion of the approval of the consolidated \ue61enancial statements of the Enel Group at December 31, 2021, the Board of Directors will verify the level \nof achievement of the pe\ue619ormance targets of the 2019 LTI Plan.\n(30) The date on which the Board of Directors approved the procedures and timing for granting the 2020 LTI Plan to the bene\ue61eciaries (taking account of the \nproposal issued by the Nomination and Compensation Commi\ue61cee at its meeting of September 16, 2020).\n(31) On the occasion of the approval of the consolidated \ue61enancial statements of the Enel Group at December 31, 2022, the Board of Directors will verify the level \nof achievement of the pe\ue619ormance targets of the 2020 LTI Plan.\n(32) The date on which the Board of Directors approved the procedures and timing for granting the 2021 LTI Plan to the bene\ue61eciaries (taking account of the \nproposal issued by the Nomination and Compensation Commi\ue61cee at its meeting of June 9, 2021).\n(33) On the occasion of the approval of the consolidated \ue61enancial statements of the Enel Group at December 31, 2023, the Board of Directors will verify the level \nof achievement of the pe\ue619ormance targets of the 2021 LTI Plan.\n(34) Shares purchased in the period between September 23 and December 2, 2019, equal to about 0.015% of share capital.\n(35) Shares purchased in the period between September 3 and October 28, 2020, equal to about 0.017% of share capital.\n(36) Shares purchased in the period between June 18 and July 21, 2021, equal to about 0.016% of share capital.\n(37) The \ue61egure has been restated from that published in the \ue61enancial statements for 2020.\n(38) The \ue61egure has been restated from that published in the \ue61enancial statements for 2020.\nEnel\u2019s website (www.enel.com) dedicated to the Sharehold-\ners\u2019 Meetings held respectively on May 16, 2019, May 14,\n2020 and May 20, 2021.\nGrant date Pe\ue61aormance period\nVeri\ue61fcation of achievement \nof targets Payout\n2019 LTI Plan 12.11.2019\n(28)\n2019-2021 2022\n(29)\n2022-2023\n2020 LTI Plan 17.09.2020\n(30)\n2020-2022 2023\n(31)\n2023-2024\n2021 LTI Plan 16.09.2021\n(32)\n2021-2023 2024\n(33)\n2024-2025\nIn implementation of the authorizations granted by the\nShareholders\u2019 Meetings held on May 16, 2019, May 14, 2020\nand May 20, 2021 and in compliance with the associated\nterms and conditions, the Board of Directors approved \u2014\nat its meetings of September 19, 2019, July 29, 2020 and\nJune 17, 2021 \u2014 the launch of share buyback programs to\nserve the 2019 LTI Plan, the 2020 LTI Plan and the 2021 LTI\nPlan respectively. The number of Shares whose purchase\nwas authorized by the Board of Directors for each Plan,\nthe actual number of Shares purchased, the associated\nweighted average price and total value are shown below.\nPurchases authorized by the Board of Directors Actual purchases\n Number of shares Number of shares\nWeighted average\nprice (euros per\nshare) Total value (euros)\n2019 LTI Plan\nNo more than 2,500,000\nfor a maximum amount of \u20ac10,500,000 million\n1,549,152\n(34)\n6.7779 10,499,999\n2020 LTI Plan 1,720,000 1,720,000\n(35)\n7.4366 12,790,870\n2021 LTI Plan 1,620,000 1,620,000\n(36)\n7.8737 12,755,459\nAs a result of the purchases made to suppo\ue61f the 2019 LTI\nPlan, the 2020 LTI Plan and the 2021 LTI Plan, at December\n31, 2021 Enel holds a total of 4,889,152 treasury shares,\nequal to about 0.048% of share capital.\nThe following information concerns the equity instruments\ngranted in 2019, 2020 and 2021.\n 2021 2020 2019\n \nNumber of\nshares granted\nat the grant\ndate \nFair value per\nshare at the\ngrant date\nNumber\nof shares \npotentially\navailable for\naward\nNumber of\nshares granted\nat the grant\ndate \nFair value per\nshare at the\ngrant date\nNumber\nof shares \npotentially\navailable for\naward\nNumber of\nshares granted\nat the grant\ndate \nFair value per\nshare at the\ngrant date\nNumber\nof shares \npotentially\navailable for\naward\n2019 LTI\nPlan\n1,529,182 1,529,182 1,538,547 6.983 1,538,547\n2020 LTI\nPlan\n1,638,775 1,638,775\n(37)\n7.38 1,638,775\n(38)\n2021 LTI\nPlan\n1,577,773 7.001 1,577,773\n\nThe fair value of those equity instruments is measured on\nthe basis of the market price of Enel Shares at the grant\ndate.\n(39)\nThe cost of the equity component is determined on the\nbasis of the fair value of the equity instruments granted\nand is recognized over the duration of the vesting period\nthrough an equity reserve.\nThe total costs recognized by the Group through pro\ue61et or\nloss amounted to \u20ac9 million in 2021 (\u20ac5 million in 2020).\nThere have been no terminations or amendments involving\nthe 2019 LTI Plan, the 2020 LTI Plan or the 2021 LTI Plan.\n",
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"value": "\n(39) For the 2019 LTI Plan, the grant date is November 12, 2019, i.e., the date of the meeting of the Board of Directors that approved the procedures and timing \nof the grant under the 2019 LTI Plan to the bene\ue61eciaries.\n For the 2020 LTI Plan, the grant date is September 17, 2020, i.e., the date of the meeting of the Board of Directors that approved the procedures and timing\nof the grant under the 2020 LTI Plan to the bene\ue61eciaries.\n For the 2021 LTI Plan, the grant date is September 16, 2021, i.e., the date of the meeting of the Board of Directors that approved the procedures and timing\nof the grant under the 2021 LTI Plan to the bene\ue61eciaries.\n52. Related pa\ue61eies \nAs an operator in the \ue61eeld of generation, distribution,\ntranspo\ue61f and sale of electricity and the sale of natural gas,\nEnel carries out transactions with a number of companies\ndirectly or indirectly controlled by the Italian State, the\nGroup\u2019s controlling shareholder.\nThe table below summarizes the main types of transac-\ntions carried out with such counterpa\ue61fies.\nRelated pa\ue61by Relationship Nature of main transactions\nSingle Buyer Fully controlled (indirectly) by the Ministry for the\nEconomy and Finance\nPurchase of electricity for the enhanced protection market\nCassa Depositi e\nPrestiti Group\nDirectly controlled by the Ministry for the\nEconomy and Finance\nSale of electricity on the Ancillary Services Market (Terna)\nSale of electricity transpo\ue61f services (Eni Group)\nPurchase of transpo\ue61f, dispatching and metering services (Terna)\nPurchase of postal services (Poste Italiane)\nPurchase of fuels for generation plants and natural gas storage and\ndistribution services (Eni Group)\nESO - Energy\nServices Operator\nFully controlled (directly) by the Ministry for the\nEconomy and Finance\nSale of subsidized electricity\nPayment of A3 component for renewable resource incentives\nEMO - Energy\nMarkets Operator\nFully controlled (indirectly) by the\nMinistry for the Economy and Finance\nSale of electricity on the Power Exchange (EMO)\nPurchase of electricity on the Power Exchange for pumping and\nplant planning (EMO)\nLeonardo Group Directly controlled by the Ministry for the\nEconomy and Finance\nPurchase of IT services and supply of goods\nIn addition, the Group conducts essentially commercial\ntransactions with associates or companies in which it\nholds non-controlling interests.\nFinally, Enel also maintains relationships with the pension\nfunds FOPEN and FONDENEL, as well as Fondazione Enel\nand Enel Cuore, an Enel non-pro\ue61et company devoted to\nproviding social and healthcare assistance.\nAll transactions with related pa\ue61fies were carried out on\nnormal market terms and conditions, which in some cas-\nes are determined by the Regulatory Authority for Energy,\nNetworks and the Environment.\n \nThe following tables summarize transactions with related\npa\ue61fies, associates and joint ventures outstanding at De-\ncember 31, 2021 and December 31, 2020 and carried out\nduring the period.\n\nMillions of euro\nSingle Buyer EMO ESO\nCassa Depositi e\nPrestiti Group\n(1)\nOther Total 2021\nAssociates and joint \nventures Overall total 2021\nTotal in \ue61fnancial \nstatements % of total\nIncome statement\nRevenue from sales and services - 3,018 275 3,165 210 6,668 342 7,010 84,104 8.3%\nOther income - - - 5 - 5 1 6 3,902 0.2%\nOther \ue61enancial income - - - 15 - 15 123 138 1,882 7.3 %\nElectricity, gas and fuel purchases 4,613 6,363 - 2,572 - 13,548 278 13,826 49,093 28.2%\nCosts for services and other materials - 75 3 2,874 57 3,009 143 3,152 19,609 16.1%\nOther operating costs 6 198 - 13 1 218 - 218 2,095 10.4%\nNet results from commodity contracts - - - 13 - 13 11 24 2,522 1.0%\nOther \ue61enancial expense - - - 10 - 10 22 32 6,114 0.5%\n(1) The \ue61egure includes Open Fiber SpA, which was considered an associate last year.\nMillions of euro\nSingle Buyer EMO ESO\nCassa Depositi e\nPrestiti Group\n(1)\nOther Total at Dec. 31, 2021\nAssociates and joint \nventures\nOverall total at Dec. 31, \n2021\nTotal in \ue61fnancial \nstatements % of total\nStatement of \ue61fnancial position\nOther non-current \ue61enancial assets - - - - - - 1,120 1,120 5,704 19.6%\nNon-current \ue61enancial derivative assets - - - - - - 14 14 2,772 0.5%\nOther non-current assets - - - 119 - 119 - 119 3,268 3.6%\nTrade receivables - 469 9 659 36 1,173 148 1,321 16,076 8.2%\nCurrent \ue61enancial derivative assets - - - - - - 32 32 22,791 0.1%\nOther current \ue61enancial assets - - - - 1 1 156 157 8,645 1.8%\nOther current assets - - 76 21 2 99 24 123 5,002 2.5%\nLong-term borrowings - - - 536 - 536 344 880 54,500 1.6%\nNon-current contract liabilities - - - 187 7 194 - 194 6,214 3.1%\nNon-current \ue61enancial derivative liabilities - - - - - - 1 1 3,339 -\nSho\ue61f-term borrowings - - - - - - 6 6 13,306 -\nCurrent po\ue61fion of long-term\nborrowings\n- - - 89 - 89 20 109 4,031 2.7%\nTrade payables 1,903 641 1 1,466 12 4,023 59 4,082 16,959 24.1%\nCurrent contract liabilities - - - 12 - 12 - 12 1,433 0.8%\nOther current liabilities - - - 38 38 76 4 80 12,959 0.6%\nOther information\nGuarantees issued - 40 - 11 59 110 - 110\nGuarantees received - - - 138 36 174 - 174\nCommitments - - - 401 - 401 - 401\n(1) The \ue61egure includes Open Fiber SpA, which was considered an associate last year.\n\nOther Total 2021\nAssociates and joint\nventures Overall total 2021\nTotal in \ue61fnancial \nstatements % of total\nIncome statement\nRevenue from sales and services - 3,018 275 3,165 210 6,668 342 7,010 84,104 8.3%\nOther income - - - 5 - 5 1 6 3,902 0.2%\nOther \ue61enancial income - - - 15 - 15 123 138 1,882 7.3 %\nElectricity, gas and fuel purchases 4,613 6,363 - 2,572 - 13,548 278 13,826 49,093 28.2%\nCosts for services and other materials - 75 3 2,874 57 3,009 143 3,152 19,609 16.1%\nOther operating costs 6 198 - 13 1 218 - 218 2,095 10.4%\nNet results from commodity contracts - - - 13 - 13 11 24 2,522 1.0%\nOther \ue61enancial expense - - - 10 - 10 22 32 6,114 0.5%\n(1) The \ue61egure includes Open Fiber SpA, which was considered an associate last year.\nMillions of euro\nSingle Buyer EMO ESO\nCassa Depositi e\nPrestiti Group\n(1)\nOther Total at Dec. 31, 2021\nAssociates and joint\nventures\nOverall total at Dec. 31,\n2021\nTotal in \ue61fnancial \nstatements % of total\nStatement of \ue61fnancial position\nOther non-current \ue61enancial assets - - - - - - 1,120 1,120 5,704 19.6%\nNon-current \ue61enancial derivative assets - - - - - - 14 14 2,772 0.5%\nOther non-current assets - - - 119 - 119 - 119 3,268 3.6%\nTrade receivables - 469 9 659 36 1,173 148 1,321 16,076 8.2%\nCurrent \ue61enancial derivative assets - - - - - - 32 32 22,791 0.1%\nOther current \ue61enancial assets - - - - 1 1 156 157 8,645 1.8%\nOther current assets - - 76 21 2 99 24 123 5,002 2.5%\nLong-term borrowings - - - 536 - 536 344 880 54,500 1.6%\nNon-current contract liabilities - - - 187 7 194 - 194 6,214 3.1%\nNon-current \ue61enancial derivative liabilities - - - - - - 1 1 3,339 -\nSho\ue61f-term borrowings - - - - - - 6 6 13,306 -\nCurrent po\ue61fion of long-term\nborrowings\n- - - 89 - 89 20 109 4,031 2.7%\nTrade payables 1,903 641 1 1,466 12 4,023 59 4,082 16,959 24.1%\nCurrent contract liabilities - - - 12 - 12 - 12 1,433 0.8%\nOther current liabilities - - - 38 38 76 4 80 12,959 0.6%\nOther information\nGuarantees issued - 40 - 11 59 110 - 110\nGuarantees received - - - 138 36 174 - 174\nCommitments - - - 401 - 401 - 401\n\nMillions of euro\nSingle Buyer EMO ESO\nCassa Depositi e\nPrestiti Group Other Total 2020\nAssociates and joint \nventures Overall total 2020\nTotal in \ue61fnancial \nstatements % of total\nIncome statement\nRevenue from sales and services - 808 295 2,542 187 3,832 206 4,038 63,642\n(1) (2)\n6.3%\nOther income - - - - 1 1 9 10 2,362 0.4%\nFinancial income - - - - - - 62 62 2,676\n(2)\n2.3%\nElectricity, gas and fuel purchases 2,038 2,059 - 1,122 - 5,219 166 5,385 26,026\n(1)\n20.7%\nCosts for services and other materials - 38 3 2,728 44 2,813 145 2,958 18,366\n(1)\n16.1%\nOther operating costs 6 183 - 9 1 199 3 202 2,202 9.2%\nResults from commodity contracts - - - 1 - 1 - 1 (99)\n(1)\n-1.0%\nOther \ue61enancial expense - - - 13 - 13 58 71 4,485 1.6%\n(1) The \ue61egures for 2020 have been adjusted, for comparative purposes only, to take account of the e\ue61bects associated with the change in classi\ue61ecation connect-\ned with the fair value measurement of outstanding contracts at the end of the period for the purchase and sale of commodities with physical se\ue61clement.\nThe change in classi\ue61ecation had no impact on operating pro\ue61et. For more details, please see note 7 to these consolidated \ue61enancial statements.\n(2) For comparative purposes only, \u20ac87 million in 2020 in respect of the component recognized through pro\ue61et or loss deriving from the remeasurement at fair\nvalue of the \ue61enancial assets connected with service concession arrangements involving distribution operations in Brazil falling within the scope of IFRIC 12\nhave been reclassi\ue61eed from \ue61enancial income to revenue. The la\ue61cer classi\ue61ecation had an impact of the same amount on operating pro\ue61et. For more details,\nplease see note 7 to these consolidated \ue61enancial statements.\nMillions of euro\nSingle Buyer EMO ESO\nCassa Depositi e\nPrestiti Group Other\nTotal \nat Dec. 31, 2020\nAssociates and joint \nventures\nOverall total \nat Dec. 31, 2020\nTotal in \ue61fnancial \nstatements % of total\nStatement of \ue61fnancial position\nOther non-current \ue61enancial assets - - - - - - 1,144 1,144 5,159 22.2%\nNon-current \ue61enancial derivative assets - - - - - - 21 21 1,236 1.7%\nTrade receivables - 35 15 569 29 648 215 863 12,046 7. 2 %\nOther current \ue61enancial assets - - - - 1 1 189 190 5,113 3.7%\nOther current assets - 9 84 63 2 158 6 164 3,578 4.6%\nLong-term borrowings - - - 625 - 625 359 984 49,519 2.0%\nNon-current contract liabilities - - - 4 6 10 151 161 6,191 2.6%\nSho\ue61f-term borrowings - - - - - - 21 21 6,345 0.3%\nCurrent po\ue61fion of long-term\nborrowings\n- - - 89 - 89 19 108 3,168 3.4%\nTrade payables 554 83 746 748 5 2,136 69 2,205 12,859 17. 1 %\nCurrent contract liabilities - - - - 1 1 15 16 1,275 1.3%\nOther current liabilities - - - 15 13 28 9 37 11,651 0.3%\nOther information\nGuarantees issued - 250 - 13 83 346 - 346\nGuarantees received - - - 157 36 193 - 193\nCommitments - - - 102 2 104 - 104\n\nPrestiti Group Other Total 2020\nAssociates and joint\nventures Overall total 2020\nTotal in \ue61fnancial \nstatements % of total\nIncome statement\nRevenue from sales and services - 808 295 2,542 187 3,832 206 4,038 63,642\n(1) (2)\n6.3%\nOther income - - - - 1 1 9 10 2,362 0.4%\nFinancial income - - - - - - 62 62 2,676\n(2)\n2.3%\nElectricity, gas and fuel purchases 2,038 2,059 - 1,122 - 5,219 166 5,385 26,026\n(1)\n20.7%\nCosts for services and other materials - 38 3 2,728 44 2,813 145 2,958 18,366\n(1)\n16.1%\nOther operating costs 6 183 - 9 1 199 3 202 2,202 9.2%\nResults from commodity contracts - - - 1 - 1 - 1 (99)\n(1)\n-1.0%\nOther \ue61enancial expense - - - 13 - 13 58 71 4,485 1.6%\nTotal \nat Dec. 31, 2020\nAssociates and joint\nventures\nOverall total \nat Dec. 31, 2020\nTotal in \ue61fnancial\nstatements % of total\nStatement of \ue61fnancial position\nOther non-current \ue61enancial assets - - - - - - 1,144 1,144 5,159 22.2%\nNon-current \ue61enancial derivative assets - - - - - - 21 21 1,236 1.7%\nTrade receivables - 35 15 569 29 648 215 863 12,046 7. 2 %\nOther current \ue61enancial assets - - - - 1 1 189 190 5,113 3.7%\nOther current assets - 9 84 63 2 158 6 164 3,578 4.6%\nLong-term borrowings - - - 625 - 625 359 984 49,519 2.0%\nNon-current contract liabilities - - - 4 6 10 151 161 6,191 2.6%\nSho\ue61f-term borrowings - - - - - - 21 21 6,345 0.3%\nCurrent po\ue61fion of long-term\nborrowings\n- - - 89 - 89 19 108 3,168 3.4%\nTrade payables 554 83 746 748 5 2,136 69 2,205 12,859 17. 1 %\nCurrent contract liabilities - - - - 1 1 15 16 1,275 1.3%\nOther current liabilities - - - 15 13 28 9 37 11,651 0.3%\nOther information\nGuarantees issued - 250 - 13 83 346 - 346\nGuarantees received - - - 157 36 193 - 193\nCommitments - - - 102 2 104 - 104\n\nWith regard to disclosures on the remuneration of di-\nrectors, members of the Board of Statutory Auditors, the\nGeneral Manager and key management personnel, provid-\ned for under IAS 24, please see the following tables.\nMillions of euro\n2021 2020 Change\nRemuneration of members of the Board of Directors and Board of\nStatutory Auditors and the General Manager\nSho\ue61f-term employee bene\ue61ets 5 6 (1) -16.7%\nOther long-term bene\ue61ets 1 4 (3) -75.0%\nTotal 6 10 (4) -40.0%\nMillions of euro\n2021 2020 Change\nRemuneration of key management personnel\nSho\ue61f-term employee bene\ue61ets 13 13 - -\nOther long-term bene\ue61ets 4 8 (4) -50.0%\nTotal 17 21 (4) -19.0%\nIn November 2010, the Board of Directors of Enel SpA ap-\nproved a procedure governing the approval and execution\nof transactions with related pa\ue61fies carried out by Enel\nSpA directly or through subsidiaries. The procedure (both\nthe version in e\ue61bect until June 30, 2021 and the version\namended in June 2021 and in e\ue61bect from July 1, 2021 are\navailable at h\ue61cps://www.enel.com/investors/governance/\nbylaws-rules-policies/) sets out rules designed to ensure \nthe transparency and procedural and substantive propri-\nety of transactions with related pa\ue61fies. It was adopted in\nimplementation of the provisions of A\ue61ficle 2391-bis of the\nItalian Civil Code and the implementing regulations issued\nby CONSOB. In 2021, no transactions were carried out for\nwhich it was necessary to make the disclosures required\nIn the rules on transactions with related pa\ue61fies adopted \nwith CONSOB Resolution no. 17221 of March 12, 2010, as\namended.\n",
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"value": "\n53. Government grants - Disclosure\npursuant to A\ue61eicle 1, paragraphs \n125-129, of Law 124/2017\nPursuant to A\ue61ficle 1, paragraphs 125-129, of Law 124/2017\nas amended, the following provides information on grants\nreceived from Italian public agencies and bodies, as well as\ndonations by Enel SpA and the fully consolidated subsidi-\naries to companies, individuals and public and private enti-\nties. The disclosure comprises: (i) grants received from Ital-\nian public entities/State entities; and (ii) donations made\nby Enel SpA and Group subsidiaries to public or private\npa\ue61fies resident or established in Italy.\nThe following disclosure includes payments in excess of\n\u20ac10,000 made by the same grantor/donor during 2021,\neven if made in multiple \ue61enancial transactions. They are\nrecognized on a cash basis.\nPursuant to the provisions of A\ue61ficle 3-quater of Decree \nLaw 135 of December 14, 2018, rati\ue61eed with Law 12 of Feb-\nruary 11, 2019, for grants received, please refer to the in-\nformation contained in the National Register of State Aid\nreferred to in A\ue61ficle 52 of Law 234 of December 24, 2012.\nGrants received in millions of euro\nFinancial\ninstitution/Grantor Bene\ue61fciary Amount Notes\nAnpal Enel Green Power\nItaly Srl\n0.02 Instalment of grant received in \ue61erst instance FNC-C-05468, \ue61enanced through the \nNew Skills Fund referred to in A\ue61ficle 88 of Decree Law of May 19, 2020 and the\nministerial decree of October 9, 2020\nAnpal Enel Green Power\nItaly Srl\n0.05 Instalment of grant received in second instance FNC-C-06952, \ue61enanced through \nthe New Skills Fund referred to in A\ue61ficle 88 of Decree Law of May 19, 2020 and the\nministerial decree of October 9, 2020\nAnpal Enel Green Power\nItaly Srl\n0.09 Instalment of grant received in \ue61erst instance FNC-C-05468, \ue61enanced through the \nNew Skills Fund referred to in A\ue61ficle 88 of Decree Law of May 19, 2020 and the\nministerial decree of October 9, 2020\nInvitalia Enel Green Power\nItaly Srl\n8.44 Instalment of grant received under 3SUN Development Contract, \ue61enanced under\nInvitalia Measure of November 17, 2017\nAnpal Enel Energia SpA 0.03 Instalment of grant received in \ue61erst instance FNC-C-05468, \ue61enanced through the\nNew Skills Fund referred to in A\ue61ficle 88 of Decree Law of May 19, 2020 and the\nministerial decree of October 9, 2020\nAnpal Enel Energia SpA 0.15 Instalment of grant received in second instance FNC-C-06952, \ue61enanced through\nthe New Skills Fund referred to in A\ue61ficle 88 of Decree Law of May 19, 2020 and the\nministerial decree of October 9, 2020\nAnpal Enel Energia SpA 0.04 Instalment of grant received in \ue61erst instance FNC-C-10223, \ue61enanced through the New\nSkills Fund referred to in A\ue61ficle 88 of Decree Law of May 19, 2020 and the ministerial\ndecree of October 9, 2020\nAnpal Servizio Ele\ue61crico\nNazionale SpA\n0.03 Instalment of grant received in \ue61erst instance FNC-C-05468, \ue61enanced through the \nNew Skills Fund referred to in A\ue61ficle 88 of Decree Law of May 19, 2020 and the\nministerial decree of October 9, 2020\nAnpal Servizio Ele\ue61crico\nNazionale SpA\n0.03 Instalment of grant received in second instance FNC-C-06952, \ue61enanced through \nthe New Skills Fund referred to in A\ue61ficle 88 of Decree Law of May 19, 2020 and the\nministerial decree of October 9, 2020\nAnpal Servizio Ele\ue61crico\nNazionale SpA\n0.02 Instalment of grant received in \ue61erst instance FNC-C-10223, \ue61enanced through the New \nSkills Fund referred to in A\ue61ficle 88 of Decree Law of May 19, 2020 and the ministerial\ndecree of October 9, 2020\nAnpal Enel Global Trading\nSpA\n0.01 Instalment of grant received in second instance FNC-C-06952, \ue61enanced through \nthe New Skills Fund referred to in A\ue61ficle 88 of Decree Law of May 19, 2020 and the\nministerial decree of October 9, 2020\nAnpal Enel Global Trading\nSpA\n0.01 Instalment of grant received in \ue61erst instance FNC-C-10223, \ue61enanced through the New \nSkills Fund referred to in A\ue61ficle 88 of Decree Law of May 19, 2020 and the ministerial\ndecree of October 9, 2020\nAnpal Enel X Srl 0.01 Instalment of grant received in \ue61erst instance FNC-C-05468, \ue61enanced through the\nNew Skills Fund referred to in A\ue61ficle 88 of Decree Law of May 19, 2020 and the\nministerial decree of October 9, 2020\nAnpal Enel X Srl 0.03 Instalment of grant received in second instance FNC-C-06952, \ue61enanced through\nthe New Skills Fund referred to in A\ue61ficle 88 of Decree Law of May 19, 2020 and the\nministerial decree of October 9, 2020\n\nGrants received in millions of euro\nFinancial\ninstitution/Grantor Bene\ue61fciary Amount Notes\nAnpal Enel X Srl 0.01 Instalment of grant received in third instance FNC-C-10223, \ue61enanced through the\nNew Skills Fund referred to in A\ue61ficle 88 of Decree Law of May 19, 2020 and the\nministerial decree of October 9, 2020\nAnpal Enel Sole Srl 0.01 Instalment of grant received in third instance FNC-C-10223, \ue61enanced through the\nNew Skills Fund referred to in A\ue61ficle 88 of Decree Law of May 19, 2020 and the\nministerial decree of October 9, 2020\nAnpal Enel Produzione\nSpA\n0.03 Instalment of grant received in \ue61erst instance FNC-C-05468, \ue61enanced through the \nNew Skills Fund referred to in A\ue61ficle 88 of Decree Law of May 19, 2020 and the\nministerial decree of October 9, 2020\nAnpal Enel Produzione\nSpA\n0.05 Instalment of grant received in second instance FNC-C-06952, \ue61enanced through \nthe New Skills Fund referred to in A\ue61ficle 88 of Decree Law of May 19, 2020 and the\nministerial decree of October 9, 2020\nAnpal Enel Produzione\nSpA\n0.06 Instalment of grant received in third instance FNC-C-10223, \ue61enanced through the \nNew Skills Fund referred to in A\ue61ficle 88 of Decree Law of May 19, 2020 and the\nministerial decree of October 9, 2020\nAnpal Enel Global\nServices Srl\n0.01 Instalment of grant received in \ue61erst instance FNC-C-05468, \ue61enanced through the \nNew Skills Fund referred to in A\ue61ficle 88 of Decree Law of May 19, 2020 and the\nministerial decree of October 9, 2020\nAnpal Enel Global\nServices Srl\n0.13 Instalment of grant received in second instance FNC-C-06952, \ue61enanced through \nthe New Skills Fund referred to in A\ue61ficle 88 of Decree Law of May 19, 2020 and the\nministerial decree of October 9, 2020\nAnpal Enel Global\nServices Srl\n0.02 Instalment of grant received in \ue61erst instance FNC-C-10223, \ue61enanced through the New \nSkills Fund referred to in A\ue61ficle 88 of Decree Law of May 19, 2020 and the ministerial\ndecree of October 9, 2020\nAnpal e-distribuzione\nSpA\n0.44 Instalment of grant received in \ue61erst instance FNC-C-05468, \ue61enanced through the\nNew Skills Fund referred to in A\ue61ficle 88 of Decree Law of May 19, 2020 and the\nministerial decree of October 9, 2020\nAnpal e-distribuzione\nSpA\n0.19 Instalment of grant received in second instance FNC-C-06952, \ue61enanced through \nthe New Skills Fund referred to in A\ue61ficle 88 of Decree Law of May 19, 2020 and the\nministerial decree of October 9, 2020\nAnpal e-distribuzione\nSpA\n0.20 Instalment of grant received in third instance FNC-C-10223, \ue61enanced through the\nNew Skills Fund referred to in A\ue61ficle 88 of Decree Law of May 19, 2020 and the\nministerial decree of October 9, 2020\nAnpal Enel Global\nInfrastructure and\nNetworks Srl\n0.09 Instalment of grant received in second instance FNC-C-06952, \ue61enanced through \nthe New Skills Fund referred to in A\ue61ficle 88 of Decree Law of May 19, 2020 and the\nministerial decree of October 9, 2020\nAnpal Enel Global\nInfrastructure and\nNetworks Srl\n0.07 Instalment of grant received in third instance FNC-C-10223, \ue61enanced through the \nNew Skills Fund referred to in A\ue61ficle 88 of Decree Law of May 19, 2020 and the\nministerial decree of October 9, 2020\nAnpal Enel Italia SpA 0.03 Instalment of grant received in \ue61erst instance FNC-C-05468, \ue61enanced through the\nNew Skills Fund referred to in A\ue61ficle 88 of Decree Law of May 19, 2020 and the\nministerial decree of October 9, 2020\nAnpal Enel Italia SpA 0.07 Instalment of grant received in second instance FNC-C-06952, \ue61enanced through\nthe New Skills Fund referred to in A\ue61ficle 88 of Decree Law of May 19, 2020 and the\nministerial decree of October 9, 2020\nAnpal Enel Italia SpA 0.02 Instalment of grant received in \ue61erst instance FNC-C-10223, \ue61enanced through the New\nSkills Fund referred to in A\ue61ficle 88 of Decree Law of May 19, 2020 and the ministerial\ndecree of October 9, 2020\nMinistry of\nUniversities and\nResearch (MUIR)\nEnel Italia SpA 0.03 Instalment of grant received for \ue61erst and second progress status repo\ue61f for Project\nSE4I, \ue61enanced under MUIR NOP \u201cR&I\u201d 2014-2020, Decree of Director 1735/Ric. of\nJuly 13, 2017 \u201cNotice for the presentation of industrial research and experimental\ndevelopment projects in the 12 specialist areas indicated in the 2015-2020 NRP\u201d\n10.43 Total\n\nDonations made in millions of euro\nGrantor Bene\ue61fciary Amount Notes\nEnel SpA Enel Cuore Onlus 0.04 2021 donation\nEnel SpA OECD International Energy\nAgency (IEA)\n0.08 2021 donation\nEnel SpA Ashoka Italy Onlus 0.02 2021 donation\nEnel SpA European University Institute 0.10 2021 donation\nEnel SpA Universit\u00e0 Commerciale Luigi\nBocconi\n0.07 Donation to suppo\ue61f study grants\nEnel X Srl Enel Cuore Onlus 0.04 2021 donation\nEnel Produzione SpA Ente della zona industriale di\nPo\ue61fo Marghera\n0.02 2021 association dues\nEnel Produzione SpA Assocarboni 0.03 Enel 2021 pa\ue61ficipation\nEnel Produzione SpA Fondazione Centro Studi Enel 0.09 50% advance on 2021 donation\nEnel Produzione SpA Enel Cuore Onlus 0.13 Balance of 2021 donation\nEnel Produzione SpA Enel Cuore Onlus 0.04 2021 donation\nEnel Produzione SpA Enel Cuore Onlus 0.03 2021 special donation\nEnel Produzione SpA Fondazione Centro Studi Enel 0.09 2021 donation\nEnel Produzione SpA Assonime 0.03 2021 association dues\nEnel Italia SpA ASES - Agricoltori,\nSostenibilit\u00e0 E Sviluppo\n(Associazione non pro\ue61et)\n0.02 Donation for #lanaturanonsiferma project\nEnel Italia SpA Comune di Brindisi 0.01 Donation to suppo\ue61f Brindisi Brilla project under patronage of\nCity of Brindisi, implemented in collaboration with Associazione\nIl Cielo Itinerante. The project is intended to encourage young\npeople to study STEM \ue61eelds (Science, Technology, Engineering and\nMathematics)\nEnel Italia SpA Enel Cuore Onlus 0.11 Donation to \ue61enance institutional activities, mainly aimed at\nsuppo\ue61fing projects consistent with the purposes of the association\nEnel Italia SpA Fondazione Accademia\nNazionale \u201cSanta Cecilia\u201d\n1.20 Donation to suppo\ue61f the Foundation\u2019s cultural activities\nEnel Italia SpA Fondazione Centro Studi Enel 0.15 Donation to suppo\ue61f research projects and advanced training\nEnel Italia SpA Fondazione Maggio Musicale\nFiorentino\n0.40 Donation to suppo\ue61f the Foundation\u2019s cultural activities\nEnel Italia SpA Moige - Movimento italiano\ngenitori Onlus\n0.10 Donation to suppo\ue61f the Young Ambassadors Campaign for digital \ncitizenship to counter cyber risk, bullying and cyberbullying in all its\nforms\nEnel Italia SpA Societ\u00e0 Cooperativa Sociale\nCamelot Onlus\n0.02 Donation to suppo\ue61f the project with the Sustainable Development \nSchool to create learning courses for teachers in order to promote\nglobal citizenship education\nEnel Italia SpA Fondazione Teatro alla Scala 0.60 Donation to suppo\ue61f the Foundation\u2019s cultural activities\ne-distribuzione SpA Enel Cuore Onlus 2.44 80% balance of 2019 donation\ne-distribuzione SpA Enel Cuore Onlus 0.52 20% of 2021 donation\ne-distribuzione SpA Fondazione Centro Studi Enel 1.40 50% balance of 2020 donation\ne-distribuzione SpA Fondazione Centro Studi Enel 1.41 50% of 2021 donation\ne-distribuzione SpA Centro Vaccinale - Varese 0.01 Donation of grid connection for healthcare facilities involved in\n\ue61eghting COVID-19\nEnel Energia SpA Anigas 0.08 Balance of 2020 association dues\nEnel Energia SpA Anigas 0.10 Advance on 2021 association dues\nEnel Energia SpA Anigas 0.10 Balance of 2021 association dues\nEnel Energia SpA Con\ue61emprese 0.01 2021 association dues\nEnel Energia SpA Fondazione Centro Studi Enel 1.23 Balance of 2020 donation\nEnel Energia SpA Fondazione Centro Studi Enel 1.01 50% advance on 2021 donation\nEnel Energia SpA Assonime 0.02 2021 association dues\nEnel Energia SpA Enel Cuore Onlus 1.26 80% balance of 2019 donation\nEnel Energia SpA Enel Cuore Onlus 0.37 50% of 2021 donation\nEnel Global Trading SpA Enel Cuore Onlus 0.04 2021 donation\nEnel Global Trading SpA Fondazione Centro Studi Enel 0.10 2021 donation to suppo\ue61f research projects and advanced training\n13.50 Total\n",
"dimensions": {
"concept": "ifrs-full:DisclosureOfGovernmentGrantsExplanatory",
"language": "en",
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"Tag45": {
"value": "\n54. Contractual commitments and\nguarantees\nThe commitments entered into by the Enel Group and the\nguarantees given to third pa\ue61fies are shown below.\nMillions of euro\nat Dec. 31, 2021 at Dec. 31, 2020 Change\nGuarantees given:\n- sureties and other guarantees granted to third pa\ue61fies 4,937 11,451 (6,514)\nCommitments to suppliers for:\n- electricity purchases 71,244 67,400 3,844\n- fuel purchases 58,042 41,855 16,187\n- various supplies 1,631 1,511 120\n- tenders 4,668 3,604 1,064\n- other 6,187 4,348 1,839\nTotal 141,772 118,718 23,054\nTOTAL 146,709 130,169 16,540\nCompared with December 31, 2020, the increase of \u20ac3,844\nmillion in commitments for electricity purchases is essential-\nly a\ue61cributable to companies in Latin America, in pa\ue61ficular in\nBrazil, and mainly re\ue61dects exchange rate e\ue61bects, high prices\ndue to in\ue61dation in the period and di\ue61berences in the state of\nprogress of outstanding contracts.\nThe increase of \u20ac16,187 million in commitments for fuel pur-\nchases mainly regards gas supplies, especially in Spain and\nItaly, and re\ue61dected the increase in demand for natural gas and\nin gas prices, as well as exchange rate e\ue61bects.\nFor more details on the expiry of commitments and guar-\nantees, please see the section \u201cCommitments to purchase\ncommodities\u201d in note 47.\nThe Group, acting through its subsidiary Enel Italia, has also \nentered into two guarantee contracts with which it provid-\ned Open Fiber with the turnover necessary to pa\ue61ficipate in\ntwo calls for tenders organized by Infratel (respectively, on\nJune 3, 2016 and August 8, 2016), which Open Fiber itself did\nnot have at the time of pa\ue61ficipation in those tenders. None-\ntheless, to date the pro\ue61etability and \ue61enancial position now \nachieved by Open Fiber makes it highly unlikely that the guar-\nantee will be called in.\n",
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"concept": "ifrs-full:DisclosureOfCommitmentsExplanatory",
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"period": "2021-01-01T00:00:00/2022-01-01T00:00:00"
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"Tag46": {
"value": "\n55. Contingent assets and liabilities\nThe following repo\ue61fs the main contingent assets and lia-\nbilities at December 31, 2021, which are not recognized in\nthe consolidated \ue61enancial statements as they do not meet\nthe requirements provided for in IAS 37.\nBrindisi Sud thermal generation plant - Ash\ndispute - Italy\nWith regard to the criminal investigation initiated by the\nPublic Prosecutor\u2019s O\ue61ace of the Cou\ue61f of Lecce in 2017\nconcerning the use of \ue61dy ash in the cement industry, the\nBrindisi Sud power plant was involved in a criminal inves-\ntigation that resulted in the issue of a preventive seizure\norder that allowed operation of the plant subject to cer-\ntain technical requirements. The order also provided for\nthe seizure of Enel Produzione assets and receivables in\nan amount of about \u20ac523 million. On August 1, 2018, the\nLecce Public Prosecutor lifted its seizure of the plant, with\nthe consequent termination of the judicial custody/ad-\nministration of the facility and the restitution of the other\nseized assets to Enel Produzione. The lifting of the seizure\norder was granted as a result of the fact that during the\ninvestigation the independent expe\ue61fs appointed by the\ninvestigating magistrate at the Cou\ue61f of Lecce issued a re-\npo\ue61f, \ue61eled \ue61erst in preliminary form on July 16, 2018 and de-\n\ue61enitively on October 10, 2018, that con\ue61ermed the non-haz-\nardous nature of the ash, \ue61ending it suitable for use in the\ncement-making process, as well as the appropriateness of\nthe operation of the plant. Although the seizure was lifted,\nthe preliminary investigation continued both against the\naccused individuals and the company pursuant to Legis-\nlative Decree 231 of June 8, 2001. Following the hearing of\nJanuary 22, 2019, ordered by the investigating magistrate\nat the request of the Public Prosecutor to receive testimo-\nny from the expe\ue61fs on their repo\ue61f, the expe\ue61fs reiterat-\ned the non-hazardous nature of the ash produced by the\nplant and the possibility of their use in the production of\ncement.\n\nSubsequently, a pre-trial hearing was conducted in 2021, \nfollowing which the pre-trial hearing judge granted peti-\ntions to pa\ue61ficipate in the trial as civil plainti\ue61b \ue61eled by the City\nof Brindisi, which quanti\ue61eed damages at about \u20ac27 million, \nrequesting a provisional award of \u20ac8 million, and by the Re-\ngion of Puglia, which has not yet quanti\ue61eed the damages\nrequested. The pre-trial hearing judge remanded all of the\ndefendants before the Cou\ue61f of Brindisi at the hearing of\nDecember 9, 2021.\nBrindisi Sud thermal generation plant - \nCriminal proceedings against Enel employees\n- Italy\nAgain with regard to the Brindisi Sud thermal generation\nplant, a criminal proceeding was held before the Cou\ue61f of\nBrindisi. A number of employees of Enel Produzione \u2013 cit-\ned as a liable pa\ue61fy in civil litigation \u2013 have been accused of\ncausing criminal damage and dumping of hazardous sub-\nstances with regard to the alleged contamination of land\nadjacent to the plant with coal dust as a result of actions be-\ntween 1999 and 2011. At the end of 2013, the accusations\nwere extended to cover 2012 and 2013. As pa\ue61f of the pro-\nceeding, injured pa\ue61fies, including the Province and City of\nBrindisi, have submi\ue61ced claims for total damages of about\n\u20ac1.4 billion. In its decision of October 26, 2016, the Cou\ue61f of\nBrindisi: (i) acqui\ue61ced nine of the thi\ue61feen defendants for not\nhaving commi\ue61ced the o\ue61bense; (ii) ruled that it did not have to\nproceed for two of the defendants as the o\ue61bense was time-\nbarred; and (iii) convicted the remaining two defendants,\nsentencing them with all the allowances provided for by law\nto nine months\u2019 imprisonment. With regard to payment of\ndamages, the Cou\ue61f\u2019s ruling also: (i) denied all claims of pub-\nlic pa\ue61fies and associations acting in the criminal proceed-\ning to recover damages; and (ii) granted most of the claims\n\ue61eled by the private pa\ue61fies acting to recover damages, refer-\nring the la\ue61cer to the civil cou\ue61fs for quanti\ue61ecation without\ngranting a provisional award. The convicted employees and\nthe civilly liable defendant, Enel Produzione, as well as one of\nthe employees for whom the expiry of period of limitations\nhad been declared, appealed the conviction. On February\n8, 2019, the Lecce Cou\ue61f of Appeal: (i) con\ue61ermed the trial\ncou\ue61f ruling regarding the criminal convictions of two Enel\nProduzione executives; (ii) denied the claims for damages of\nsome private appellants; (iii) granted some claims for dam-\nages, which had been denied in the trial cou\ue61f, referring the\npa\ue61fies, like the others \u2013 whose claims had been granted by \nthe trial cou\ue61f \u2013 to the civil cou\ue61fs for quanti\ue61ecation, without\ngranting a provisional award; (iv) con\ue61ermed for the rest the\nruling of the Cou\ue61f of Brindisi except for extending litigation\ncosts to the Province of Brindisi, which had not been award-\ned damages at either the trial cou\ue61f or on appeal.\nWith a subsequent ruling, the Cou\ue61f of Appeal of Lec-\nce granted the appeal lodged by the Province of Brindisi\nagainst the ruling, acknowledging that a material error had\nbeen made and therefore recognizing the generic entitle-\nment of the Province to damages. The defendants \ue61eled an\nappeal against ruling with the Cou\ue61f of Cassation. Follow-\ning the hearing of October 1, 2020, the Cou\ue61f of Cassation\nove\ue61furned the ruling of the Cou\ue61f of Appeal of Lecce, with \nreferral to another section of the same cou\ue61f for a new pro-\nceeding. The new proceeding was held before the mixed\ncriminal section of the Cou\ue61f of Appeal of Lecce, which, at\nthe hearing of November 10, 2021, acqui\ue61ced the defend-\nants for not having commi\ue61ced the o\ue61bense and consequent-\nly revoked the civil rulings.\nIn addition to the proceeding above, two criminal proceed-\nings are also under way before the Cou\ue61fs of Reggio Cal-\nabria and Vibo Valentia against a number of employees of\nEnel Produzione for the o\ue61bense of illegal waste disposal in\nconnection with alleged violations concerning the disposal\nof waste from the Brindisi plant. Enel Produzione was not\nnamed a liable pa\ue61fy for civil damages in these proceedings.\nBoth of the aforementioned trials were resolved positively\nfor the employees of Enel Produzione: as regards the pro-\nceedings before the Cou\ue61f of Vibo Valentia, at the hearing\nof June 17, 2021, the Cou\ue61f read out the operative po\ue61fion of\nthe ruling, declaring that it should not proceed against the\ndefendants as the o\ue61bences with which they were charged\nwere time-barred under the statute of limitations, also de-\nnying the aggravating circumstance referred to in A\ue61ficle\n434, paragraph 2 of the Criminal Code. The criminal pro-\nceedings before the Cou\ue61f of Reggio Calabria had ended\npreviously at the hearing of June 23, 2016. The cou\ue61f ac-\nqui\ue61ced the defendants because it found that no crime had\nbeen commi\ue61ced for nearly all the most serious charges and\nfor expiration of the statute of limitations for one serious\ncharge and for all of the remaining charges involving minor\no\ue61benses.\nEnel, Enel Energia and Servizio Ele\ue61brico \nNazionale antitrust proceeding - Italy\nOn May 11, 2017, the Competition Authority announced the\nbeginning of proceedings for alleged abuse of a dominant \nposition against Enel SpA (Enel), Enel Energia SpA (EE) and\nServizio Ele\ue61crico Nazionale SpA (SEN), with the concomitant\npe\ue619ormance of inspections. The proceeding was initiated\non the basis of complaints \ue61eled by the Italian Association of\nEnergy Wholesalers and Traders (AIGET) and the company\nGreen Network SpA (GN), as well as a number of complaints\nfrom individual consumers.\nOn December 20, 2018 the Competition Authority issued its\n\ue61enal ruling, with which it levied a \ue61ene on Enel SpA, SEN and\nEE of \u20ac93,084,790.50, for abuse of a dominant position in\nviolation of A\ue61ficle 102 of the Treaty on the Functioning of\nthe European Union (TFEU).\n\nThe disputed conduct consisted in the adoption of a strat-\negy to exclude competitors from the free market for retail\npower supply on the pa\ue61f of the Group\u2019s operating compa-\nnies, in pa\ue61ficular EE, who allegedly used the privacy con-\nsent given by consumers to channel their o\ue61bers within the\nGroup in order to contact SEN customers who were still\nbeing served on the regulated market.\nWith regard to other allegations made with the measure to\ninitiate the proceeding, concerning the organization and\npe\ue619ormance of sales activities at physical locations (Enel\nPoints and Enel Point Pa\ue61fner Shops) and winback policies\nrepo\ue61fed by GN, the Competition Authority reached the\nconclusion that the preliminary \ue61endings did not provide\nsu\ue61acient evidence of any abusive conduct on the pa\ue61f of\nEnel Group companies.\nThe companies involved challenged the measures of the\nCompetition Authority and \ue61eled an appeal to void the ruling\nbefore the Lazio Regional Administrative Cou\ue61f. The deci-\nsion of that cou\ue61f, \ue61eled on October 17, 2019, pa\ue61fially upheld\nthe appeals \ue61eled by SEN and EE, declaring that the abusive\nconduct had been engaged in for a period of 1 year and\n9 months, rather than the original period of 5 years and 5\nmonths, and requiring the Authority to recalculate the pen-\nalty in accordance with the criteria speci\ue61eed in the ruling.\nWith the same ruling, the Regional Administrative Cou\ue61f \ndenied Enel\u2019s appeal \u2013 which challenged the joint and sev-\neral liability of the Parent with SEN and EE. The ruling had no\nautonomous \ue61enancial impact on the Competition Author-\nity\u2019s obligation to recalculate the penalty. With a measure\ndated November 27, 2019, the Competition Authority set\nthe recalculated penalty at \u20ac27,529,786.46.\nThe rulings of the Regional Administrative Cou\ue61f were\nchallenged on appeal before the Council of State by the\nthree Enel Group companies and a precautionary request\nwas presented at the same time asking for the suspension\nof the measure for recalculating the penalty levied by the\nCompetition Authority. With an order of July 20, 2020, the\nCouncil of State, after the joinder of the three appeals, sus-\npended the ruling and ordered that the issue be submi\ue61ced\nfor a preliminary ruling before the Cou\ue61f of Justice of the\nEuropean Union (CJEU) pursuant to A\ue61ficle 267 of the TFEU,\nformulating a number of questions aimed at clarifying the\ninterpretation of the concept of \u201cabuse of a dominant po-\nsition\u201d to be applied to the present case. On September\n11 and 18, 2020, the CJEU noti\ue61eed EE and SEN and Enel,\nrespectively, of the initiation of a proceeding pursuant to\nA\ue61ficle 267 of the TFEU. The companies then \ue61eled briefs\nand, subsequently, EE and SEN pa\ue61ficipated at a hearing on\nSeptember 9, 2021. At the following hearing of December\n9, 2021, the conclusions of the Advocate General were pre-\nsented to the CJEU.\nPending the opening of the proceedings before the CJEU,\nEnel, EE and SEN \ue61eled an additional precautionary petition\nto the Council of State asking for the suspension of the en-\nforceability of the contested ruling of the Regional Admin-\nistrative Cou\ue61f and the measure recalculating the penalty.\nWith three separate orders with identical content \u2013 pub-\nlished on November 16, 2020 \u2013 the Council of State grant-\ned the request for suspension \ue61eled by the Enel companies\nand, as a guarantee of payment of the penalty in the event\nof an unfavorable \ue61enal ruling, required the issue of a \ue61erst\ndemand surety in favor of the Competition Authority in an\namount equal to that of the recalculated penalty suspend-\ned with the precautionary orders. The guarantee was duly\nprovided.\nWith a separate ruling, the Council of State also set the\ndate of the \ue61enal trial session of the appeal for November\n11, 2021. That hearing was postponed pending a decision\nfrom the CJEU.\nBEG litigation - Italy, France, the Netherlands,\nLuxembourg\nFollowing an arbitration proceeding initiated by BEG SpA\n(BEG) in Italy, Enelpower SpA (Enelpower) obtained a rul-\ning in its favor in 2002, which was upheld by the Cou\ue61f of\nCassation in 2010, which entirely rejected the petition for\ndamages with regard to alleged breach by Enelpower of an\nagreement concerning the construction of a hydroelectric\npower station in Albania. Subsequently, BEG, acting through\nits subsidiary Albania BEG Ambient, \ue61eled suit against Enel-\npower and Enel SpA (Enel) in Albania concerning the ma\ue61cer, \nobtaining a ruling from the District Cou\ue61f of Tirana on March\n24, 2009, upheld by the Albanian Cou\ue61f of Cassation, order-\ning Enelpower and Enel to pay to\ue61fious damages of about\n\u20ac25 million for 2004 as well as an unspeci\ue61eed amount of\nto\ue61fious damages for subsequent years. Following the rul-\ning, Albania BEG Ambient demanded payment of more than\n\u20ac430 million from Enel.\nWith a ruling of June 16, 2015, the \ue61erst level was complet-\ned in the additional suit lodged by Enelpower SpA and Enel\nSpA with the Cou\ue61f of Rome asking the Cou\ue61f to asce\ue61fain\nthe liability of BEG SpA for having evaded compliance with\nthe arbitration ruling issued in Italy in favor of Enelpower\nSpA through the legal action taken by Albania BEG Ambient\nShpk. With this action, Enelpower SpA and Enel SpA asked\nthe Cou\ue61f to \ue61end BEG liable and order it to pay damages in\nthe amount that the other could be required to pay to Al-\nbania BEG Ambient Shpk in the event of the enforcement\nof the ruling issued by the Albanian cou\ue61fs. With the ruling,\nthe Cou\ue61f of Rome found that BEG SpA did not have stand-\ning to be sued, or alternatively, that the request was not ad-\nmissible for lack of an interest for Enel SpA and Enelpower\nSpA to sue, as the Albanian ruling had not yet been declared\nenforceable in any cou\ue61f. The Cou\ue61f ordered the se\ue61cing o\ue61b \nof cou\ue61f costs. Enel SpA and Enelpower SpA appealed the\nruling before the Rome Cou\ue61f of Appeal, asking that it be\nove\ue61furned in full. The ruling is at the decision stage.\n\nOn November 5, 2016, Enel SpA and Enelpower SpA \ue61eled\na petition with the Albanian Cou\ue61f of Cassation, asking for\nthe ruling issued by the District Cou\ue61f of Tirana on March\n24, 2009 to be voided. The proceeding is still pending.\nOn May 20, 2021, the European Cou\ue61f of Human Rights\n(ECHR) issued a ruling with which it decided the appeal\nbrought by BEG against the Italian State for violation of A\ue61fi-\ncle 6.1 of the European Convention on Human Rights. With\nthis decision, the Cou\ue61f denied BEG's request to reopen the\narbitration proceedings, and also rejected BEG's claim for\npecuniary damages amounting to about \u20ac1.2 billion due\nto the absence of a causal link with the disputed conduct,\ngranting it only \u20ac15,000.00 in non-pecuniary damages.\nNonetheless, on December 29, 2021, BEG, with an action\nthat the Company and its legal counsel deem unfounded\nand specious, also decided to sue the Italian State before\nthe Cou\ue61f of Milan, to demand, as a consequence of the\nECHR ruling, damages for to\ue61fious liability in an amount of\nabout \u20ac1.8 billion. In this case, BEG also involved Enel and\nEnelpower by way of a claim of joint and several liability. The\ninitial hearing is currently scheduled for April 27, 2022. Enel\nand Enelpower are preparing their defense for the appear-\nance in cou\ue61f.\nProceedings unde\ue61eaken by Albania BEG\nAmbient Shpk (ABA) to obtain enforcement\nof the ruling of the District Cou\ue61e of Tirana of\nMarch 24, 2009\nFrance\nIn February 2012, ABA \ue61eled suit against Enel and Enelpow-\ner with the Tribunal de Grande Instance in Paris in order \nto render the ruling of the Albanian cou\ue61f enforceable in\nFrance. Enel SpA and Enelpower SpA challenged the suit.\nFollowing the beginning of the case before the Tribunal de\nGrande Instance, between 2012 and 2013 Enel France was\nserved with a number of \u201cSaisie Conservatoire de Cr\u00e9anc-\nes\u201d (orders for the precautionary a\ue61cachment of receiva-\nbles) in favor of ABA to conserve any receivables of Enel in\nrespect of Enel France.\nOn January 29, 2018, the Tribunal de Grande Instance is-\nsued a ruling in favor of Enel and Enelpower, denying ABA\nthe recognition and enforcement of the Tirana cou\ue61f\u2019s rul-\ning in France for lack of the requirements under French\nlaw for the purposes of granting exequatur. Among other\nissues, the Tribunal de Grande Instance ruled that: (i) the Al-\nbanian ruling con\ue61dicted with an existing decision (the arbi-\ntration ruling of 2002); and that (ii) the fact that BEG sought\nto obtain in Albania what it was not able to obtain in the\nItalian arbitration proceeding, resubmi\ue61cing the same claim\nthrough ABA, represented fraud.\nABA appealed that ruling. With a ruling of May 4, 2021, the\nParis Cou\ue61f of Appeal denied the appeal by ABA in full, or-\ndering it to reimburse Enel and Enelpower \u20ac200,000.00\neach for legal costs. In pa\ue61ficular, the Cou\ue61f of Appeal fully\nupheld the ruling of the Tribunal de Grande Instance with\nregard to the con\ue61dict of the Albanian ruling with the 2002\narbitration award, which, having the value of res judicata\nunder French law, does not require the cou\ue61f to assess the\nissue raised.\nOn June 21, 2021, ABA \ue61eled an appeal with the Cour de Cas-\nsation against the ruling of the Paris Cou\ue61f of Appeal. Enel \nand Enelpower are preparing their defense for the appear-\nance before the Cour de Cassation. Finally, Enel and Enel-\npower initiated a separate proceeding to obtain release of\nthe precautionary a\ue61cachments granted to ABA and which\nare no longer valid as a result of the appeal ruling.\nThe Netherlands\nAt the end of July 2014, ABA \ue61eled suit with the Cou\ue61f of\nAmsterdam to render the ruling of the Albanian cou\ue61f en-\nforceable in the Netherlands. With a ruling of June 29, 2016,\nthe trial cou\ue61f recognized the Albanian ruling in the Neth-\nerlands and therefore ordered Enel and Enelpower to pay\n\u20ac433,091,870.00 to ABA, in addition to costs and ancillary\ncharges of \u20ac60,673.78. With the same ruling, the Cou\ue61f of\nAmsterdam denied ABA\u2019s request to declare the ruling pro-\nvisionally enforceable.\nIn a ruling of July 17, 2018, the Amsterdam Cou\ue61f of Appeal\nupheld the appeal advanced by Enel and Enelpower, ruling\nthat the Albanian judgment cannot be recognized and en-\nforced in the Netherlands. The Cou\ue61f of Appeal found that\nthe Albanian decision was arbitrary and manifestly unrea-\nsonable and therefore contrary to Dutch public order.\nThe proceeding before the Cou\ue61f of Appeal continued with\nregard to the subordinate question raised by ABA with\nwhich it asked the Dutch cou\ue61f to rule on the merits of the\ndispute in Albania and in pa\ue61ficular the alleged to\ue61fious lia-\nbility of Enel and Enelpower in the failure to build the power\nplant in Albania.\nOn December 3, 2019, the Amsterdam Cou\ue61f of Appeal\nissued a de\ue61enitive ruling in which it fully quashed the trial\ncou\ue61f judgment of June 29, 2016, rejecting any claim made\nby ABA. The Cou\ue61f came to this conclusion after a\ue61arming\nits jurisdiction over ABA\u2019s subordinate claim and re-analyz-\ning the merits of the case under Albanian law, \ue61ending no\nto\ue61fious liability on the pa\ue61f of Enel and Enelpower. Accord-\ningly, Enel and Enelpower are therefore not liable to pay\nany amount to ABA, which was in fact ordered by the Cou\ue61f \nof Appeal to reimburse the companies for the losses in-\ncurred in illegitimate conservative seizures, to be quanti\ue61eed\nas pa\ue61f of a speci\ue61ec procedure, and the costs of the trial\nand appeal proceedings. ABA \ue61eled an appeal of the ruling\nwith the Supreme Cou\ue61f of the Netherlands. Following the\n\ue61eling of the opinion of the Advocate General, who ruled in\nfavor of Enel and Enelpower, requesting the denial of the\nappeal lodged by ABA, on July 16, 2021 the Supreme Cou\ue61f \ncompletely rejected ABA's claims, ordering it to reimburse\n\ncou\ue61f costs. The decision of the Cou\ue61f of Appeal has thus\nbecome \ue61enal and, therefore, no more proceedings are\npending in the Netherlands.\nLuxembourg\nIn Luxembourg, again at the initiative of ABA, J.P. Morgan\nBank Luxembourg SA was also served with an order for a\nnumber of precautionary seizures of any receivables of\nboth Enel Group companies in respect of the bank.\nIn parallel ABA \ue61eled a claim to obtain enforcement of the\nruling of the Cou\ue61f of Tirana in Luxembourg. The pro-\nceeding is still in the initial stages and no ruling has been\nissued.\nUnited States and Ireland\nIn 2014, ABA had initiated two proceedings requesting\nexecution of the Albanian ruling before the cou\ue61fs of the\nState of New York and Ireland, which both ruled in favor\nof Enel and Enelpower, respectively, on February 23 and\nFebruary 26, 2018. Accordingly, there are no lawsuits\npending in Ireland or New York State.\nEnvironmental incentives - Spain\nWith the Decision of the European Commission of No-\nvember 27, 2017 on the issue of environmental incentives \nfor thermal power plants, the Commission reached the\npreliminary conclusion that the environmental incen-\ntive for coal power plants provided for in Spain\u2019s Order\nITC/3860/2007 represents State aid pursuant to A\ue61ficle \n107, paragraph 1, of the Treaty on the Functioning of the \nEuropean Union (TFEU), expressing doubts about the\ncompatibility of the incentive with the internal market\nwhile recognizing that the incentives are in line with the\nEuropean Union\u2019s environmental policy. The Commission's\nDirectorate-General for Competition has initiated a for-\nmal enquiry pursuant to A\ue61ficle 108, paragraph 2, of the\nTFEU in order to establish whether the incentive in ques-\ntion constituted state aid compatible with the internal \nmarket. On April 13, 2018, Endesa Generaci\u00f3n SA, acting\nas an interested third pa\ue61fy, submi\ue61ced comments con-\ntesting this interpretation. Subsequently, on September \n8, 2021, the appeal of the decision lodged by Gas Natural\n(now Naturgy) with the Cou\ue61f of Justice of the European \nUnion (CJEU) was denied. The enquiry under A\ue61ficle 108 of\nthe TFEU is still open.\nSocial Bonus - Spain\nWith the rulings of October 24 and 25, 2016 and No-\nvember 2, 2016, the Spanish Tribunal Supremo declared \nA\ue61ficle 45, paragraph 4 of the Spain\u2019s Electricity Indus-\ntry Law 24 of December 26, 2013 void for incompatibility\nwith Directive 2009/72/EC of the European Parliament\nand of the Council of July 13, 2009, granting the appeals\n\ue61eled by Endesa against the obligation to \ue61enance the So-\ncial Bonus mechanism. The Tribunal Supremo recognized \nEndesa\u2019s right to receive all amounts that had been paid\nto users under the Social Bonus system, provided for in\nthe law declared void by the Tribunal Supremo, for a total \nof about \u20ac214 million plus interest. The government chal-\nlenged these rulings of the Tribunal Supremo, requesting \nthat they be ove\ue61furned, but the related appeals were de-\nnied.\nSubsequently, the government initiated two proceedings\nbefore the Constitutional Cou\ue61f requesting the reopen-\ning of the Tribunal Supremo proceedings so that the lat-\nter may ask for a preliminary ruling from the European\nCou\ue61f of Justice (CJEU). The Constitutional Cou\ue61f granted\nthe appeals and, accordingly, the Tribunal Supremo sub-\nmi\ue61ced a petition for a preliminary ruling from the CJEU.\nAll pa\ue61fies, including Endesa, presented their respective\nwri\ue61cen conclusions. On October 14, 2021, after the Ad-\nvocate General had issued a favorable opinion to Endesa, \nthe CJEU issued a preliminary ruling in favor of Endesa, \nrecognizing the incompatibility of A\ue61ficle 45, paragraph 4,\nof the Electricity Industry Law with the Directive referred\nto above. On December 21, 2021 the Tribunal Supremo \nissued a \ue61enal ruling with which it con\ue61ermed the provisions\nof the previous ruling of October 24, 2016. In pa\ue61ficular,\nthe Tribunal Supremo found that the social bonus \ue61enanc-\ning scheme provided for in A\ue61ficle 45, paragraph 4, of the\nElectricity Industry Law is inapplicable as it does not com-\nply with A\ue61ficle 3.2 of Directive 2009/72/EC, and voided\nRoyal Decree 968/2014.\n\u201cEndesa I\u201d industrial relations dispute - Spain\nAfter a series of meetings of the Comisi\u00f3n Negociado-\nra of the 5th Endesa Collective Bargaining Agreement \n(Comisi\u00f3n Negociadora) which began in October 2017 \nand continued throughout 2018, in view of the impossi-\nbility of reaching an agreement between the social pa\ue61f-\nners, Endesa noti\ue61eed the workers and their union repre-\nsentatives that, with e\ue61bect from January 1, 2019, the 4th\nCollective Bargaining Agreement must be considered \nterminated under the terms of the \u201cframework guarantee\ncontract\u201d and the \u201cagreement on the voluntary suspen-\nsion or resolution of employment contracts in the peri-\nod 2013-2018\u201d, applying from that date the provisions of\ngeneral labor law, as well as the applicable legal criteria \nestablished in the ma\ue61cer.\nDespite the resumption of negotiations within the\nComisi\u00f3n Negociadora in February 2019, the interpre-\ntative di\ue61berences between Endesa and the trade union\nrepresentatives regarding the e\ue61bects of the resolution of\nthe 4th Collective Bargaining Agreement with regard, in\npa\ue61ficular, to the social bene\ue61ets granted to retired per-\nsonnel, led to the initiation of a suit by the unions rep-\nresented in the company. On March 26, 2019 a hearing \n\nwas held before the cou\ue61f of \ue61erst instance, which issued\na ruling in favor of Endesa, upholding the company\u2019s po-\nsition concerning the legitimacy of abolishing ce\ue61fain so-\ncial bene\ue61ets for retired personnel as a consequence of\nthe termination of the 4th Endesa Collective Bargaining\nAgreement. The unions appealed this decision before the \nTribunal Supremo, while the initial ruling remained provi-\nsionally enforceable. Endesa entered the proceeding. In\nDecember 2019, Endesa\u2019s largest union decided to waive\nits appeal before the Tribunal Supremo in order to volun-\ntarily submit the dispute to arbitration before the Servi-\ncio Interconfederal de Mediaci\u00f3n y Arbitraje (SIMA) with \na view to resolving the main issues concerning the 5th \nEndesa Collective Bargaining Agreement with the com-\npany. The other trade unions involved refused to join the \narbitration proceeding, electing to go ahead with the \nproceedings before the Tribunal Supremo.\nOn January 21, 2020, the arbitration award was issued, \nwith the amendment of ce\ue61fain pa\ue61fs of the 5th Ende-\nsa Collective Bargaining Agreement, which was subse-\nquently signed by the social pa\ue61fners. It entered force on\nJanuary 23, 2020. On the same date, Endesa also signed \ntwo fu\ue61fher collective bargaining agreements (a \u201cframe-\nwork guarantee contract\u201d and an \u201cagreement on vol-\nuntary measures to suspend or terminate employment \ncontracts\u201d) with all the unions present in the company.\nOn June 17, 2020, the 5th Endesa Collective Bargaining \nAgreement was published in the Spanish O\ue61acial Journal\n(Bolet\u00edn O\ue61dcial del Estado), taking full e\ue61bect. \nOn July 7, 2021, the Tribunal Supremo issued a decision \n(noti\ue61eed on July 22, 2021) in which it denied the appeals\nlodged by the aforementioned unions in full, upholding\nthe ruling of the cou\ue61f of \ue61erst instance of March 26, 2019.\nIn pa\ue61ficular, the Tribunal Supremo a\ue61armed that social \nbene\ue61ets (including those relating to electricity prices)\noriginate exclusively in the collective bargaining agree-\nments, both for employees currently in service and those\nwho have retired, as well as for their family members, with\nthe consequence that the termination of such agree-\nments (as happened in the case of the 4th Collective \nBargaining Agreement) produces the general contrac-\ntual regulation of the conditions established therein for\nemployees currently in service and, for those who have\nretired and their family members, the de\ue61enitive extinction\nof all their rights, until new regulations are introduced with\nthe 5th Endesa Collective Bargaining Agreement. Numer-\nous individual suits have been \ue61eled by sta\ue61b and former\nemployees who had agreed to pa\ue61ficipate in termination\nincentive agreements in order to obtain judicial con\ue61er-\nmation that the termination of the 4th Endesa Collective\nBargaining Agreement did not a\ue61bect them. The majori-\nty of these proceedings were suspended or were being \nsuspended pending the de\ue61enition of the collective action\npending before the Tribunal Supremo, as the ruling of the \nla\ue61cer, in regarding a \u201ccollective dispute\u201d, would have the\nvalue of res judicata in respect of individual proceedings\nconcerning the same issue. As a result of the ruling of the\nTribunal Supremo of July 7, 2021, the suspension of many \nof these proceedings was revoked in order to enable the\ncou\ue61f to deny the suits.\n\u201cEndesa II\u201d industrial relations dispute - \nSpain\nOn December 30, 2020, the Audiencia Nacional noti-\n\ue61eed Endesa a petition for a \u201ccollective dispute\u201d initiated\nby three trade unions with minority representation \ue61eled \non December 16, 2020 concerning the cancellation of\nsome \u201cderogatory provisions\u201d of the 5th Endesa Collec-\ntive Bargaining Agreement. The plainti\ue61bs claim that the\ncontested \u201cderogatory provisions\u201d would imply the ille-\ngitimate abolition of social bene\ue61ets and economic rights\nof workers. Endesa considers these provisions to be fully\nlegitimate, in line with the arguments made during pro-\nceeding concerning the reduction of social bene\ue61ets for \nretired personnel. With a ruling of November 15, 2021, the\npetitions of the plainti\ue61b unions were rejected, with veri\ue61e-\ncation of the legitimacy of the 5th Endesa Collective Bar-\ngaining Agreement. The ruling was appealed by the trade \nunions before the Tribunal Supremo.\nFurnas-Tractebel litigation - Brazil\nIn 1998 the Brazilian company CIEN (now Enel CIEN)\nsigned an agreement with Tractebel for the delivery of\nelectricity from Argentina through its Argentina-Brazil\ninterconnection line. As a result of Argentine regulatory\nchanges introduced as a consequence of the economic\ncrisis in 2002, Enel CIEN was unable to make the electric-\nity available to Tractebel.\nIn October 2009, Tractebel sued Enel CIEN, which sub-\nmi\ue61ced its defense. Enel CIEN cited force majeure as a re-\nsult of the Argentine crisis as the main argument in its\ndefense. Out of cou\ue61f, the Tractebel has indicated that it\nplans to acquire 30% of the interconnection line involved \nin the dispute. On February 14, 2019, Enel CIEN received \nnotice of an order beginning expe\ue61f witness operations, \nwhich are still under way. The amount involved in the dis-\npute is estimated at about R$118 million (about \u20ac28 mil-\nlion), plus interest, revaluations and unspeci\ue61eed damages. \nFor analogous reasons, in May 2010 Furnas had also \ue61eled\nsuit against Enel CIEN for failure to deliver electricity, re-\nquesting payment of about R$571.6 million (about \u20ac91 \nmillion), in addition to unspeci\ue61eed damages, seeking to \nacquire ownership (in this case 70%) of the interconnec-\ntion line. The proceeding was decided in Enel CIEN\u2019s favor\nwith a ruling of the Tribunal de Justi\u00e7a with a de\ue61enitive \nruling of October 18, 2019, which denied all of the claims\nof Furnas.\n\n(40) The trading name of Ampla is Enel Distribui\u00e7\u00e3o Rio de Janeiro.\n(41) The trading name of Coelce is Enel Distribui\u00e7\u00e3o Cear\u00e1.\n(42) The trading name of Eletropaulo is Enel Distribui\u00e7\u00e3o S\u00e3o Paulo.\ntablished speci\ue61ecally to pursue the expansion project. \nThe contracts provided for the payment of a monthly fee\nby Coelce, which was also required to maintain the net-\nworks.\nThose contracts, between cooperatives established in\nspecial circumstances and the then public-sector com-\npany, do not speci\ue61ecally identify the grids governed by \nthe agreements, which prompted a number of the coop-\neratives to sue Coelce asking for, among other things, a\nrevision of the fees agreed in the contracts.\nThese proceedings include the suit \ue61eled by Cooperativa\nde Eletri\ue61eca\u00e7\u00e3o Rural do Vale do Acarau Ltda (Coperva)\nwith a value of about R$374 million (about \u20ac59.3 million).\nCoelce was granted rulings in its favor from the trial cou\ue61f \nand the cou\ue61f of appeal, but Coperva \ue61eled a fu\ue61fher ap-\npeal (Embargo de Declara\u00e7\u00e3o) based on procedural is-\nsues, which was also denied by the appeal cou\ue61f in a ruling\nof January 11, 2016. On February 3, 2016, Coperva lodged\nan extraordinary appeal before the Superior Tribunal de \nJusti\u00e7a (STJ) against the appeal cou\ue61f ruling on the merits, \nwhich was granted on November 5, 2018 for the ruling\nissued in the previous appeal (Embargo de Declara\u00e7\u00e3o). \nOn December 3, 2018, Coelce \ue61eled an appeal (Agravo In-\nterno) against this ruling of the STJ. The proceedings are \ncurrently pending.\nAGM litigation - Brazil\nIn 1993, Celg-D,\n(42)\n the Association of Municipalities of\nGoi\u00e1s (AGM), the State of Goi\u00e1s and the Bank of Goi\u00e1s \nreached an agreement (Convenio) for the payment of \nmunicipal debts to Celg-D through the transfer of the\npo\ue61fion of ICMS - Imposto sobre Circula\u00e7\u00e3o de Merca-\ndorias e Servi\u00e7os (tax on the circulation of goods and \nservices) that the State would have transferred to those \ngovernments. In 2001 the pa\ue61fies to the agreement were\nsued by the individual municipal governments to obtain a\nruling that the agreement was invalid, a position then up-\nheld by the Supreme Federal Cou\ue61f on the grounds of the\nnon-pa\ue61ficipation of the local governments themselves \nin the agreement process. In September 2004, Celg-D\nreached a se\ue61clement with 23 municipalities. Between\n2007 and 2008, Celg-D was again sued on numerous \noccasions by a number of municipal governments (there\nare currently 65 pending suits) seeking the restitution of\namounts paid under the agreement. Despite the ruling\nthat the agreement was void, Celg-D argues that the pay-\nment of the debts on the pa\ue61f of the local governments is \nlegitimate, as electricity was supplied in accordance with\nthe supply contracts and, accordingly, the claims for res-\nCibran litigation - Brazil\nCompanhia Brasileira de Antibi\u00f3ticos (Cibran) has \ue61eled\nsix suits against the Enel Group company Ampla Energia\ne Servi\u00e7os SA (Ampla)\n(40)\n to obtain damages for alleged\nlosses incurred as a result of the interruption of electric-\nity service by the Brazilian distribution company between\n1987 and 2002, in addition to non-pecuniary damages.\nThe Cou\ue61f ordered a uni\ue61eed technical appraisal for those\ncases, the \ue61endings of which were pa\ue61fly unfavorable to\nAmpla. The la\ue61cer challenged the \ue61endings, asking for a\nnew study, which led to the denial of pa\ue61f of Cibran\u2019s peti-\ntions. Cibran subsequently challenged the \ue61endings of the\nnew study and the ruling was in favor of Ampla. \nThe \ue61erst suit, \ue61eled in 1999 and regarding the years from\n1995 to 1999, was adjudicated in September 2014 when \nthe cou\ue61f of \ue61erst instance issued a ruling against Amp-\nla, levying a \ue61ene of about R$200,000 (about \u20ac46,000) as\nwell as other damages to be quanti\ue61eed separately. Ampla\nappealed the ruling and the appeal was upheld by the Tri-\nbunal de Justi\u00e7a, which denied all of Cibran\u2019s claims. The \nruling became de\ue61enitive on August 24, 2020.\nWith regard to the second case, \ue61eled in 2006 and re-\ngarding the years from 1987 to 1994, on June 1, 2015, the \ncou\ue61fs issued a ruling ordering Ampla to pay R$96,465,103\n(about \u20ac23 million) plus interest in pecuniary damages\nand R$80,000 Brazilian (about \u20ac19,000) in non-pecuniary\ndamages. On July 8, 2015 Ampla appealed the decision\nwith the Tribunal de Justi\u00e7a of Rio de Janeiro, which on \nNovember 6, 2019 issued a ruling on merits granting Am-\npla\u2019s petition and denying all of Cibran\u2019s claims. On No-\nvember 25, 2019, Cibran \ue61eled an appeal against the rul-\ning of the Tribunal de Justi\u00e7a of Rio de Janeiro, which was \npreliminarily denied for formal reasons on September 10,\n2020. On January 29, 2021, Cibran appealed (Agravo de \nInstrumento) the decisions before the Superior Tribunal \nde Justi\u00e7a (STJ), which was denied on June 8, 2021. On \nJune 22, 2021, Cibran \ue61eled an appeal (Agravo Interno) with \nthe STJ and the proceeding is pending.\nA ruling from the cou\ue61f of \ue61erst instance is still pending for\nthe remaining four suits for the years 2001 and 2002. The\nvalue of all the disputes is estimated at about R$612.1\nmillion (about \u20ac96.02 million).\nCoperva litigation - Brazil\nAs pa\ue61f of the project to expand the grid in rural areas\nof Brazil, in 1982 Companhia Energ\u00e9tica do Cear\u00e1 SA\n(Coelce),\n(41)\n then owned by the Brazilian government and \nnow an Enel Group company, had entered into contracts\nfor the use of the grids of a number of cooperatives es-\n\ntitution of amounts paid should be denied.\nThe proceedings pending before the Goi\u00e1s State Cou\ue61f \ninclude: (i) a suit \ue61eled by the Municipio de Aparecida de\nGoi\u00e2nia, which is pending at the preliminary stage at \ue61erst\ninstance, for an amount of approximately R$726 million\n(about \u20ac113.4 million); (ii) a suit \ue61eled by the Municipio de\nQuirin\u00f3polis, also pending at the preliminary stage of\nthe proceeding at \ue61erst instance for an amount of about\nR$388 million (about \u20ac61.48 million); and (iii) a suit \ue61eled by\nthe Municipio de An\u00e1polis with the cou\ue61f of \ue61erst instance \nafter a failed a\ue61cempt at conciliation between the pa\ue61fies\nand now pending in the preliminary stages, for an amount\nof about R$368.7 million (about \u20ac54.4 million).\nThe total value of the suits is equal to about R$3.92 bil-\nlion (about \u20ac621.5 million). The contingent liability deriv-\ning from this dispute is covered by the \u201cFunac\u201d provision\nestablished during the privatization of Celg-D.\nANEEL litigation - Brazil\nIn 2014, Eletropaulo\n(43)\n initiated an action before the Bra-\nzilian federal cou\ue61fs seeking to void the administrative\nmeasure of the Ag\u00eancia Nacional de Energia El\u00e9trica \n(ANEEL, the national electricity agency), which in 2012\nretroactively introduced a negative coe\ue61acient to be ap-\nplied in determining rates for the following regulatory\nperiod (2011-2015). With this provision, the Authority or-\ndered the restitution of the value of some components\nof the network previously included in rates because they\nwere considered non-existent and denied Eletropaulo\u2019s\nrequest to include additional components in rates. The\nadministrative measure of ANEEL was challenged and on \nSeptember 9, 2014 it was suspended on a precautionary \nbasis. The \ue61erst-instance proceeding is still in its prelim-\ninary stages and the value of the suit is about R$1,288\nmillion (about \u20ac204.1 million).\nEl Quimbo - Colombia\nA number of legal actions (\u201cacciones de grupo\u201d and \u201cac-\nciones populares\u201d) brought by residents and \ue61eshermen \nin the a\ue61bected area are pending with regard to the El\nQuimbo project for the construction of a 400 MW hy-\ndroelectric plant in the region of Huila (Colombia). More\nspeci\ue61ecally, the \ue61erst collective action, currently in the pre-\nliminary stage, was brought by around 1,140 residents of \nthe municipality of Garz\u00f3n, who claim that the construc-\ntion of the plant would reduce their business revenue by\n30%. A second action was brought, between August 2011 \nand December 2012, by residents and businesses/asso-\n(43) The trading name of Eletropaulo is Enel Distribui\u00e7\u00e3o S\u00e3o Paulo.\nciations of \ue61eve municipalities of Huila claiming damages\nrelated to the closing of a bridge (Paso El Colegio). With\nregard to acciones populares, or class action lawsuits, in \n2008 a suit was \ue61eled by a number of residents of the area\ndemanding, among other things, that the environmental \npermit be suspended. As pa\ue61f of this action, on Septem-\nber 11, 2020, the Huila Cou\ue61f issued an unfavorable ruling\nagainst Emgesa, sentencing it to ful\ue61ell the obligations al-\nready provided for in the environmental license. ANLA has\nsubmi\ue61ced a request for clari\ue61ecation of the ruling. \nAnother acci\u00f3n popular was brought by a number of \ue61esh \nfarming companies over the alleged impact that \ue61elling the\nQuimbo basin would have on \ue61eshing in the Betania basin\ndownstream from Quimbo. After a number of precaution-\nary rulings, on February 22, 2016, the Huila Cou\ue61f issued\na ruling allowing generation to continue for six months.\nThe cou\ue61f ordered Emgesa to prepare a technical design\nthat would ensure compliance with oxygen level require-\nments and to provide collateral of about 20,000,000,000\nColombian pesos (about \u20ac5.5 million).\nThe Huila Cou\ue61f subsequently extended the six-month \ntime limit, and therefore, in the absence of contrary cou\ue61f \nrulings the Quimbo plant is continuing to generate elec-\ntricity as the oxygenation system installed by Emgesa has\nso far demonstrated that it can maintain the oxygen lev-\nels required by the cou\ue61f. On March 22, 2018, ANLA and\nCAM jointly presented the \ue61enal repo\ue61f on the monitoring\nof water quality downstream of the dam of the El Quimbo\nhydroelectric plant. Both authorities con\ue61ermed the com-\npliance of Emgesa with the oxygen level requirements.\nAfter the pa\ue61fies had \ue61eled briefs, on January 12, 2021, it\nwas learned that the ruling of \ue61erst instance of the Cou\ue61f \nof Huila had been issued (it was subsequently noti\ue61eed to\nthe company on February 1, 2021). The ruling, while ac-\nknowledging that the oxygenation system implemented\nby Emgesa had mitigated the risks associated with the\nprotection of fauna in the Bethany basin, imposed a se-\nries of obligations on the environmental authorities in-\nvolved, as well as on Emgesa itself. In pa\ue61ficular, the lat-\nter is required to implement a decontamination project\nto ensure that the water in the basin does not generate\nrisks for the \ue61dora and fauna of the river, which will be sub-\nject to veri\ue61ecation by ANLA, and to make permanent the\noperation of the oxygenation system, adapting it to com-\nply with the parameters established by ANLA. On March\n4, 2021, Emgesa challenged the appeal ruling before the\nCouncil of State.\nOn December 31, 2021, the Council of State ruled that\nEmgesa\u2019s appeal was admissible. The proceeding is con-\ntinuing at the appeal level.\n\nNivel de Tensi\u00f3n Uno proceedings - Colombia\nThis dispute involves an \u201cacci\u00f3n de grupo\u201d brought by Cen-\ntro M\u00e9dico de la Sabana hospital and other pa\ue61fies against\nCodensa seeking restitution of allegedly excess rates. The\naction is based upon the alleged failure of Codensa to ap-\nply a subsidized rate that they claim the users should have\npaid as Tensi\u00f3n Uno category users (voltage of less than 1 \nkV) and owners of infrastructure, as established in Resolu-\ntion no. 82/2002, as amended by Resolution no. 97/2008.\nThe suit is at a preliminary stage. The estimated value of\nthe proceeding is about 337 billion Colombian pesos\n(about \u20ac96 million).\nGab\u010d\u00edkovo dispute - Slovakia\nSlovensk\u00e9 elektr\u00e1rne (SE) is involved in a number of cas-\nes before the national cou\ue61fs concerning the 720 MW\nGab\u010d\u00edkovo hydroelectric plant, which is administered\nby Vodohospod\u00e1rska V\u00fdsatavba \u0160t\u00e1tny Podnik (VV) and\nwhose operation and maintenance, as pa\ue61f of the privat-\nization of SE in 2006, had been entrusted to SE for a pe-\nriod of 30 years under an operating agreement (the VEG\nOperating Agreement).\nImmediately after the closing of the privatization, the Pub-\nlic Procurement O\ue61ace (PPO) \ue61eled suit with the Cou\ue61f of\nBratislava seeking to void the VEG Operating Agreement\non the basis of alleged violations of the regulations gov-\nerning public tenders, qualifying the contract as a service\ncontract and as such governed by those regulations. In \nNovember 2011 the trial cou\ue61f ruled in favor of SE, where-\nupon the PPO immediately appealed the decision.\nIn parallel with the PPO action, VV also \ue61eled a number of\nsuits, asking in pa\ue61ficular for the voidance of the VEG Op-\nerating Agreement.\nOn December 12, 2014, VV withdrew unilaterally from the\nVEG Operating Agreement, notifying its termination on \nMarch 9, 2015, for breach of contract. On March 9, 2015,\nthe decision of the appeals cou\ue61f ove\ue61furned the ruling of\nthe trial cou\ue61f and voided the contract as pa\ue61f of the ac-\ntion pursued by the PPO. SE lodged an extraordinary ap-\npeal against that decision before the Supreme Cou\ue61f. At a\nhearing of June 29, 2016, the Supreme Cou\ue61f denied the\nappeal. SE then appealed the ruling to the Constitutional\nCou\ue61f, which denied the appeal on January 18, 2017.\nIn addition, SE lodged a request for arbitration with the\nVienna International Arbitral Centre (VIAC) under the VEG\nIndemnity Agreement. Under that accord, which had been\nsigned as pa\ue61f of the privatization between the National\nPrope\ue61fy Fund (now MH Manazment - MHM) of the Slovak\nRepublic and SE, the la\ue61cer is entitled to an indemnity in\nthe event of the early termination of the VEG Operating\nAgreement for reasons not a\ue61cributable to SE. The arbitra-\ntion cou\ue61f rejected the objection that it did not have juris-\ndiction and the arbitration proceeding continued to ex-\namine the merits of the case, with a ruling on the amount\ninvolved being deferred to any subsequent proceeding.\nOn June 30, 2017, the arbitration cou\ue61f issued its ruling de-\nnying the request of SE.\nIn parallel with the arbitration proceeding launched by SE,\nboth VV and MHM \ue61eled two suits in the Slovakian cou\ue61fs to \nvoid the VEG Indemnity Agreement owing to the alleged\nconnection of the la\ue61cer with the VEG Operating Agree-\nment. These proceedings were joindered and, on Septem-\nber 27, 2017, a hearing was held before the Cou\ue61f of Brati-\nslava in which the judge denied the request of the plain-\nti\ue61bs for procedural reasons. Both VV and MHM appealed\nthat decision. The appeal \ue61eled by MHM was denied by the\nBratislava Cou\ue61f of Appeal on June 8, 2019, upholding the\ndecision of the cou\ue61f of \ue61erst instance in favor of SE. Simi-\nlarly, the appeal \ue61eled by VV was denied, upholding the trial\ncou\ue61f decision in favor of SE. VV \ue61eled a fu\ue61fher appeal (do-\nvolanie) against that decision on March 9, 2020, with the \nSupreme Cou\ue61f, to which SE replied with a brief submi\ue61ced\non June 8, 2020. On March 24, 2021, the Supreme Cou\ue61f \nove\ue61furned the decision of the Bratislava Cou\ue61f of Appeal,\nreferring the judgment to the la\ue61cer cou\ue61f. On July 21, 2021,\nSE \ue61eled an appeal before the Slovak Constitutional Cou\ue61f,\nwhich was denied on July 29, 2021, and the proceeding is\ncurrently pending before the Bratislava Cou\ue61f of Appeal.\nAt the local level, SE was sued by VV for alleged unjusti\ue61eed\nenrichment (estimated at about \u20ac360 million plus interest)\nfor the period from 2006 to 2015. SE \ue61eled counter-claims\nfor all of the proceedings under way. Developments in\nthose proceedings can be summarized as follows:\n\u2022 for 2006-2008, at the hearing of June 26, 2019, the \nCou\ue61f of Bratislava denied the claims of both pa\ue61fies for\nprocedural reasons. The ruling in \ue61erst instance was ap-\npealed by both VV and SE and the appeals for the years\n2006 and 2008 are pending. As for the appeal pro-\nceedings relating to 2007, in November 2019, SE had\nraised a preliminary question which was rejected by\nthe Cou\ue61f of Appeal on January 15, 2020. On August 18, \n2020, SE \ue61eled an appeal with the Constitutional Cou\ue61f \nbut the appeal was denied on September 18, 2021. The\nproceeding is therefore continuing before the Cou\ue61f of\nAppeal;\n\u2022 the proceedings relating to the years from 2009 to \n2011 and from 2013 to 2015 are all pending before the\ncou\ue61f of \ue61erst instance. In a number of cases, briefs have \nbeen exchanged. For all the proceedings, hearings be-\nfore the cou\ue61f of \ue61erst instance were scheduled but then\nwere initially postponed to speci\ue61eed dates before be-\ning postponed to dates to be determined owing to the\npandemic;\n\u2022 the proceeding involving 2012 is pending before the \nCou\ue61f of Appeal level following VV\u2019s appeal of the ruling\nin favor of SE by the cou\ue61f of \ue61erst instance.\nFinally, in another proceeding before the Cou\ue61f of Brati-\nslava, VV asked for SE to return the fee for the transfer\nfrom SE to VV of the technology assets of the Gab\u010d\u00edko-\n\nvo plant as pa\ue61f of the privatization, with a value of about\n\u20ac43 million plus interest. The pa\ue61fies exchanged briefs. At\nthe hearing on November 19, 2019, the cou\ue61f issued a pre-\nliminary decision on the case in which it noted the lack\nof standing of VV. At the hearing of October 1, 2020, the\npa\ue61fies \ue61eled their \ue61enal briefs and on December 18, 2020,\nthe cou\ue61f issued a decision in favor of SE, rejecting VV\u2019s\nclaims. On January 4, 2021, VV \ue61eled an appeal against that\ndecision, and the proceeding is pending.\nChucas arbitration - Costa Rica\nPH Chucas SA (Chucas) is a special purpose entity estab-\nlished by Enel Green Power Costa Rica SA after it won a \ntender organized in 2007 by the Instituto Costarricense\nde Electricidad (ICE) for the construction of a 50 MW hy-\ndroelectric plant and the sale of the power generated by\nthe plant to ICE under a build, operate and transfer con-\ntract (BOT).\nOn May 27, 2015, Chucas initiated an arbitration proceed-\ning before the C\u00e1mara Costarricense-No\ue61eeamericana de \nComercio (AMCHAM CICA) seeking reimbursement of the \nadditional costs incurred to build the plant and as a result\nof the delays in completing the project as well as voidance\nof the \ue61ene levied by ICE for alleged delays in \ue61enalizing the\nworks. In a decision issued in November 2017, the arbitra-\ntion board ruled in Chucas\u2019 favor, granting recognition of\nthe additional costs incurred in the amount of about $113\nmillion (about \u20ac91 million) and legal costs and found that\nChucas was not liable to pay the \ue61enes to ICE. ICE appealed\nthe arbitration ruling before the Supreme Cou\ue61f and on \nSeptember 5, 2019 Chucas was noti\ue61eed of the ruling par-\ntially upholding ICE\u2019s appeal to void the arbitration ruling\nfor a number of formal procedural reasons. On September\n11, 2019, Chucas \ue61eled a \u201crecurso de aclaraci\u00f3n y adici\u00f3n\u201d \nwith the same cou\ue61f and it was pa\ue61fially upheld on June 8,\n2020. The Cou\ue61f\u2019s decision expanded on the ruling of Sep-\ntember 5, 2019 with information concerning the admis-\nsion of evidence deposited by Chucas without, however,\nmodifying the decision concerning the voidance of the\narbitration award. On July 14, 2020, Chucas \ue61eled a new re-\nquest for arbitration with the AMCHAM CICA for a prelim-\ninary estimated amount of about $240 million. On August\n14, 2020, ICE \ue61eled its response, requesting the dismissal\nof the proceeding for lack of jurisdiction on the pa\ue61f of the\narbitration tribunal. The request for dismissal was denied\nby AMCHAM CICA. In parallel, ICE \ue61eled precautionary ap-\npeals to the Tribunal Contencioso Administrativo against \nChucas and the AMCHAM CICA seeking to suspend the\narbitration proceedings. While these appeals were pre-\nliminarily upheld, they were subsequently denied. In May\n2021, Chucas \ue61eled its arbitration request complete with\npreliminary demands, quantifying the value of its claim\nat about $362 million (about \u20ac305 million). In June 2021,\nICE \ue61eled its defense, continuing to asse\ue61f a lack of juris-\ndiction. ICE has not made a counterclaim. On August 4,\n2021, the arbitration tribunal rejected ICE's claim of lack of\njurisdiction. The ma\ue61cer has now been submi\ue61ced for con-\nsideration to the \ue61erst section of the Supreme Cou\ue61f. The\narbitration proceedings remain suspended pending the\nSupreme Cou\ue61f decision on jurisdiction.\nGasAtacama Chile - Chile\nOn August 4, 2016, the Superintendencia de Electricidad \ny Combustibles (SEC) \ue61ened GasAtacama Chile (now Enel \nGeneraci\u00f3n Chile) $8.3 million (about 5.8 billion Chilean\npesos) for information provided by the la\ue61cer to the CDEC-\nSING (Centro de Despacho Econ\u00f3mico de Carga) between \nJanuary 1, 2011 and October 29, 2015, relating to the Min-\nimum Technical and Minimum Operating Time variables at\nthe Atacama plant.\nEnel Generaci\u00f3n Chile appealed this measure with the\nSEC, which denied the appeal on November 2, 2016. Enel\nGeneraci\u00f3n Chile appealed this decision before the Santi-\nago Cou\ue61f of Appeal, which on April 9, 2019, issued a ruling \nreducing the \ue61ene to $432,000 (about 290 million Chilean \npesos). Both Enel Generaci\u00f3n Chile and the SEC appealed\nthis decision before the Supreme Cou\ue61f of Chile. On June\n28, 2019, a hearing was held for both pa\ue61fies to submit\narguments and on January 15, 2020 the Supreme Cou\ue61f \nupheld the ruling of the Santiago Cou\ue61f of Appeal, leaving\nunchanged the reduction in the \ue61ene established by that \ncou\ue61f. The adjusted \ue61ene was paid on March 12, 2020.\nIn parallel, Enel Generaci\u00f3n Chile had also \ue61eled an appeal \nbefore the Constitutional Cou\ue61f, claiming that the legal\nprovisions under which the SEC imposed the \ue61ene had\nbeen repealed at the time the penalty was issued. On July\n17, 2018, the Constitutional Cou\ue61f rejected Enel Gener-\naci\u00f3n Chile\u2019s appeal.\nIn relation to this issue, some operators of the Sistema \nInterconectado del No\ue61ee Grande (SING), including Aes \nGener SA, El\u00e9ctrica Angamos SA and Engie Energ\u00eda Chile\nSA, sued Enel Generaci\u00f3n Chile to obtain damages in an\namount of about \u20ac58 million (the former) and about \u20ac141 \nmillion (the la\ue61cer two). The disputes were joindered in pa\ue61f \nin a single proceeding and are currently pending. After the\nsuspension of the proceeding under the state of national\nemergency declared in response to the COVID-19 pan-\ndemic, the plainti\ue61b asked for the proceeding to resume,\na request the cou\ue61f granted. The cou\ue61f ordered the no-\nti\ue61ecation of a measure that determines the substantive,\npe\ue61finent and disputed facts of the case. The preliminary\nphase has not yet begun.\nKino arbitration - Mexico\nOn September 16, 2020, Kino Contractor SA de Cv (Kino\nContractor), Kino Facilities Manager SA de Cv (Kino Facili-\nties) and Enel SpA (Enel) were noti\ue61eed of a request for arbi-\n\ntration \ue61eled by Parque Solar Don Jos\u00e9 SA de Cv, Villanueva\nSolar SA de Cv and Parque Solar Villanueva Tres SA de Cv\n(together, \u201cProject Companies\u201d) in which the Project Com-\npanies alleged the violation (i) by Kino Contractor of ce\ue61fain\nprovisions of the EPC Contract and (ii) by Kino Facilities of\nce\ue61fain provisions of the Asset Management Agreement,\nboth contracts concerning solar projects owned by the\nthree companies \ue61eling for arbitration.\nEnel \u2014 which is the guarantor of the obligations assumed\nby Kino Contractor and Kino Facilities under the above\ncontracts \u2014 has also been called into the arbitration pro-\nceeding, but no speci\ue61ec claims have been \ue61eled against it\nfor the moment.\nThe Project Companies, in which Enel Green Power SpA is\na non-controlling shareholder, are controlled by CDPQ In-\nfraestructura Pa\ue61ficipaci\u00f3n SA de Cv (which is controlled by\nCaisse de D\u00e9p\u00f4t et Placement du Qu\u00e9bec) and CKD Infrae-\nstructura M\u00e9xico SA de Cv. \nAfter the request for arbitration and the related response\nfrom the defendants, the pa\ue61fies exchanged fu\ue61fher intro-\nductory briefs, in which the \ue61enancial claim of the counter-\npa\ue61fies was quanti\ue61eed at about $140 million, while Kino Fa-\ncilities quanti\ue61eed its own counterclaim at about $3.3 million.\nThe document production phase is currently under way.\nTax litigation in Brazil\nWithholding tax - Ampla\nIn 1998, Ampla Energia e Servi\u00e7os SA (Ampla) \ue61enanced the\nacquisition of Coelce with the issue of bonds in the amount\nof $350 million (\u201cFixed Rate Notes\u201d - FRN) subscribed by\nits Panamanian subsidiary, which had been established to\nraise funds abroad. Under the special rules then in force,\nsubject to maintaining the bonds until 2008, the interest\npaid by Ampla to its subsidiary was not subject to with-\nholding tax in Brazil.\nHowever, the \ue61enancial crisis of 1998 forced the Panama-\nnian company to re\ue61enance itself with its Brazilian parent,\nwhich for that purpose obtained loans from local banks.\nThe tax authorities considered this \ue61enancing to be the\nequivalent of the early redemption of the bonds, with the\nconsequent loss of entitlement to the exemption from\nwithholding tax.\nIn December 2005, Ampla carried out a spin-o\ue61b that in-\nvolved the transfer of the residual FRN debt and the as-\nsociated rights and obligations to Ampla Investimentos e\nServi\u00e7os SA.\nOn November 6, 2012, the C\u00e2mara Superior de Recursos \nFiscais (the highest level of administrative cou\ue61fs) issued \na ruling against Ampla, for which the company promptly\nasked that body for clari\ue61ecations. On October 15, 2013,\nAmpla was noti\ue61eed of the denial of the request for clari-\n\ue61ecation (Embargo de Declara\u00e7\u00e3o), thereby upholding the \nprevious adverse decision. The company provided security\nfor the debt and on June 27, 2014 continued litigation be-\nfore the ordinary cou\ue61fs (Tribunal de Justi\u00e7a). \nIn December 2017, the cou\ue61f appointed an expe\ue61f to ex-\namine the issue in greater detail in suppo\ue61f of the future\nruling. In September 2018, the expe\ue61f submi\ue61ced a repo\ue61f,\nrequesting additional documentation.\nIn December 2018, the company provided the additional\ndocumentation and is awaiting the cou\ue61f\u2019s assessment of\nthe arguments and documents presented.\nThe amount involved in the dispute at December 31, 2021\nwas about \u20ac211 million.\nIRPJ/CSLL - Eletropaulo\nOn October 5, 2021, Eletropaulo received an assessment\nnotice from the Brazilian tax authorities contesting the\ndeductibility for income tax purposes (Imposto sobre a \nRenda das Pessoas Jur\u00eddicas - IRPJ and Contribui\u00e7\u00e3o So-\ncial sobre o Lucro L\u00edquido - CSLL) of the amo\ue61fization of \nthe increased amounts generated by extraordinary cor-\nporate transactions carried out before the acquisition of\nthe company by the Enel Group. The contested period runs\nfrom 2017 to 2019.\nConsidering its position sound, the company presented its\ndefense at the \ue61erst level of administrative adjudication.\nThe amount involved in the dispute was about \u20ac110 million\nat December 31, 2021.\nPIS - Eletropaulo\nIn July 2000, Eletropaulo \ue61eled suit seeking a tax credit for\nPIS (Programa Integra\u00e7\u00e3o Social) paid in application of \nregulations (Decree Laws 2.445/1988 and 2.449/1988)\nthat were subsequently declared unconstitutional by the\nSupremo Tribunal Federal (STF). In May 2012, the Superior \nTribunal de Justi\u00e7a (STJ) issued a \ue61enal ruling in favor of the \ncompany that recognized the right to the credit.\nIn 2002, before the issue of that favorable \ue61enal ruling, the\ncompany had o\ue61bset its credit against other federal taxes.\nThis behavior was contested by the federal tax authorities\nbut the company, claiming it had acted correctly, chal-\nlenged in cou\ue61f the assessments issued by the federal tax\nauthorities. Following defeat at the initial level of adjudica-\ntion, the company appealed.\nThe amount involved in the dispute at December 31, 2021\nwas about \u20ac106 million.\nICMS - Ampla, Coelce and Eletropaulo\nThe States of Rio de Janeiro, Cear\u00e1 and S\u00e3o Paulo issued\na number of tax assessments against Ampla Energia e\nServi\u00e7os SA (for the years 1996-1999 and 2007-2017),\nCompanhia Energ\u00e9tica do Cear\u00e1 (Coelce) (2003, 2004,\n2006-2012, 2015 and 2016) and Eletropaulo (2008-2020),\nchallenging the deduction of ICMS - Imposto sobre Circu-\nla\u00e7\u00e3o de Mercadorias e Servi\u00e7os (tax on the circulation of \n\ngoods and services) in relation to the purchase of ce\ue61fain\nnon-current assets. The companies challenged the as-\nsessments, arguing that they correctly deducted the tax\nand asse\ue61fing that the assets, the purchase of which gen-\nerated the ICMS, are intended for use in their electricity\ndistribution activities.\nThe companies are continuing to defend their actions at\nthe various levels of adjudication.\nThe amount involved in the disputes totaled approximately\n\u20ac79 million at December 31, 2021.\nWithholding tax - Endesa Brasil\nOn November 4, 2014, the Brazilian tax authorities issued\nan assessment against Endesa Brasil SA (now Enel Bras-\nil SA) alleging the failure to apply withholding tax to pay-\nments of allegedly higher dividends to non-resident recip-\nients.\nMore speci\ue61ecally, in 2009, Endesa Brasil, as a result of the\n\ue61erst-time application of the IFRS, had derecognized good-\nwill, recognizing the e\ue61bects in equity, on the basis of the\ncorrect application of the accounting standards it had\nadopted. The Brazilian tax authorities, however, asse\ue61fed\n\u2013 during an audit \u2013 that the accounting treatment was in-\ncorrect and that the e\ue61bects of the derecognition should\nhave been recognized through pro\ue61et or loss. As a result,\nthe corresponding amount (about \u20ac202 million) was re-\nclassi\ue61eed as a payment of income to non-residents and,\ntherefore, subject to withholding tax of 15%.\nIt should be noted that the accounting treatment adopted\nby the company was agreed with the external auditor and\nalso con\ue61ermed by a speci\ue61ec legal opinion issued by a local\n\ue61erm.\nFollowing unfavorable rulings from the administrative\ncou\ue61fs, the company is continuing to defend its actions\nand the appropriateness of the accounting treatment in\ncou\ue61f.\nThe overall amount involved in the dispute at December\n31, 2021 was about \u20ac58 million.\nICMS - Coelce \nThe State of Cear\u00e1 has \ue61eled various tax assessments\nagainst Companhia Energ\u00e9tica do Cear\u00e1 SA (Coelce) over\nthe years (for tax periods from 2005 to 2014), contesting\nthe determination of the deductible po\ue61fion of the ICMS -\nImposto sobre Circula\u00e7\u00e3o de Mercadorias e Servi\u00e7os (tax \non the circulation of goods and services) and in pa\ue61ficular\nthe method of calculation of the pro-rata deduction with\nreference to the revenue deriving from the application of a\nspecial rate envisaged by the Brazilian government for the\nsale of electricity to low-income households (Baixa Renda).\nThe company has appealed the individual assessments, ar-\nguing that the tax deduction was calculated correctly. The\ncompany is defending its actions in the various levels of\njurisdiction.\nThe overall amount involved in the dispute at December\n31, 2021 was about \u20ac40 million.\nPIS - Eletropaulo\nIn December 1995, the Brazilian government increased\nthe rate of the federal PIS (Programa Integra\u00e7\u00e3o Social) tax \nfrom 0.50% to 0.65% with the issue of a provisional meas-\nure (Executive Provisional Order).\nSubsequently, the provisional measure was re-issued \ue61eve\ntimes before its de\ue61enitive rati\ue61ecation into law in 1998. Un-\nder Brazilian legislation, an increase in the tax rate (or the\nestablishment of a new tax) can only be ordered by law and\ntake e\ue61bect 90 days after its publication.\nEletropaulo therefore \ue61eled suit arguing that an increase in\nthe tax rate would only have been e\ue61bective 90 days after\nthe last Provisional Order, claiming that the e\ue61bects of the\n\ue61erst four provisional measures should be considered void\n(since they were never rati\ue61eed into law). This dispute ended\nin April 2008 with recognition of the validity of the increase\nin the PIS rate sta\ue61fing from the \ue61erst provisional measure.\nIn May 2008, the Brazilian tax authorities \ue61eled a suit against\nEletropaulo to request payment of taxes corresponding\nto the rate increase from March 1996 to December 1998.\nEletropaulo has fought the request at the various levels of\nadjudication, arguing that the time limit for the issue of\nthe notice of assessment had lapsed. In pa\ue61ficular, since\nmore than \ue61eve years have passed since the taxable event\n(December 1995, the date of the \ue61erst provisional measure)\nwithout issuing any formal instrument, the right of the tax\nauthorities to request the payment of additional taxes and\nthe authority to unde\ue61fake legal action to obtain payment\nhave been challenged.\nIn 2017, following the unfavorable decisions issued in pre-\nvious rulings, Eletropaulo \ue61eled an appeal in defense of its\nrights and its actions with the Superior Tribunal de Justi\u00e7a \n(STJ) and the Supremo Tribunal Federal (STF). The proceed-\nings are still pending while the amounts subject to dispute\nhave been covered by a bank guarantee.\nWith regard to the request of the O\ue61ace of the A\ue61corney\nGeneral of the Brazilian National Treasury Depa\ue61fment to\nreplace the bank guarantee with a deposit in cou\ue61f, the\ncou\ue61f of second instance granted the petition. The com-\npany therefore replaced the bank guarantee with a cash\ndeposit and \ue61eled a clari\ue61ecation motion against the related\ndecision, which is currently awaiting a decision.\nThe overall amount involved in the dispute at December\n31, 2021 was about \u20ac39 million.\nFINSOCIAL - Eletropaulo \nFollowing a \ue61enal ruling issued by the Federal Regional Cou\ue61f \non September 11, 2011, Eletropaulo was recognized the\nright to compensation for ce\ue61fain FINSOCIAL credits (so-\ncial contributions) relating to sums paid from September\n1989 to March 1992.\n\nDespite the expiration of the relative statute of limitations,\nthe Federal Tax Authority contested the determination of\nsome credits and rejected the corresponding o\ue61bse\ue61cing,\nissuing tax assessments that the company promptly chal-\nlenged in the administrative cou\ue61fs, defending the legiti-\nmacy of its calculations and actions.\nAfter an unfavorable ruling at \ue61erst instance, the company\n\ue61eled an appeal before the administrative cou\ue61f of second\ninstance.\nThe overall amount involved in the dispute at December\n31, 2021 was about \u20ac37 million.\nTax litigation in Spain\nIncome tax - Enel Iberia, Endesa and subsidiaries\nIn 2018, the Spanish tax authorities completed a general\naudit involving the companies of the Group pa\ue61ficipating\nin the Spanish tax consolidation mechanism. This audit,\nwhich began in 2016, involved corporate income tax, value\nadded tax and withholding taxes (mainly for the years 2012\nto 2014).\nWith reference to the main claims, the companies involved\nhave challenged the related assessments at the \ue61erst ad-\nministrative level (Tribunal Econ\u00f3mico-Administrativo Cen-\ntral - TEAC), defending the correctness of their actions.\nWith regard to the disputes concerning corporate income\ntax, the issues for which an unfavorable outcome is con-\nsidered possible amounted to about \u20ac155 million at De-\ncember 31, 2021:\n\u2022 Enel Iberia is defending the appropriateness of the cri-\nterion adopted for determining the deductibility of cap-\nital losses deriving from stock sales (around \u20ac106 mil-\nlion) and ce\ue61fain \ue61enancial expense (around \u20ac18 million);\n\u2022 Endesa and its subsidiaries are mainly defending the \nappropriateness of the criteria adopted for the deduct-\nibility of ce\ue61fain \ue61enancial expense (about \u20ac25 million)\nand costs for decommissioning nuclear power plants\n(about \u20ac6 million).\nIn 2021, the Spanish tax authorities concluded a new gen-\neral audit for the years from 2015 to 2018. The companies\ninvolved challenged the related assessments at the \ue61erst\nlevel of administrative adjudication (TEAC), arguing that\nthey had acted correctly.\nIn relation to the main dispute regarding corporate income\ntax, which concerned the deductibility of ce\ue61fain \ue61enancial\ncharges, the dispute for which an adverse outcome is con-\nsidered possible has a value of about \u20ac232 million at De-\ncember 31, 2021 (Enel Iberia \u20ac219 million and Endesa SA\n\u20ac13 million).\nIncome tax - Enel Green Power Espa\u00f1a SL \nOn June 7, 2017, the Spanish tax authorities issued a notice\nof assessment to Enel Green Power Espa\u00f1a SL, contesting\nthe treatment of the merger of Enel Uni\u00f3n Fenosa Renova-\nbles SA (\u201cEUFER\u201d) into Enel Green Power Espa\u00f1a SL in 2011\nas a tax neutral transaction, asse\ue61fing that the transaction\nhad no valid economic reason.\nOn July 6, 2017, the company appealed the assessment at\nthe \ue61erst administrative level (Tribunal Econ\u00f3mico-Adminis-\ntrativo Central - TEAC), defending the appropriateness of \nthe tax treatment applied to the merger. The company has\nprovided the suppo\ue61fing documentation demonstrating\nthe synergies achieved as a result of the merger in order\nto prove the existence of a valid economic reason for the\ntransaction. On December 10, 2019, the TEAC denied the\nappeal and the company is continuing to defend its ac-\ntions in cou\ue61f (Audiencia Nacional).\nThe overall amount involved in the dispute at December\n31, 2021 was about \u20ac98 million.\nTax litigation in Italy\nWithholding tax - Enel Servizio Ele\ue61brico Nazionale \nAs a result of a tax audit initiated in March 2018 and fol-\nlowing a subsequent investigation conducted with ques-\ntionnaires submi\ue61ced to the banks involved as assignees\nin ce\ue61fain transfers of receivables from Servizio Ele\ue61crico\nNazionale SpA (SEN) in respect of mass market customers\nunder a framework agreement, on December 19, 2018, the\nRevenue Agency - Regional Directorate of Lazio - Large\nTaxpayers O\ue61ace, noti\ue61eed the company of an assessment\nin respect of the alleged violation of withholding tax obli-\ngations relating to the amounts paid to the banks as pa\ue61f \nof the aforementioned transfers in 2013.\nIn pa\ue61ficular, the dispute arises from an assessment by the\nO\ue61ace that: (i) reclassi\ue61eed, for tax purposes only, the assign-\nment of receivables as a \ue61enancing transaction; (ii) asse\ue61fed\nan alleged withholding obligation for the company com-\nmensurate with the cost of the transaction (as the di\ue61ber-\nence between the nominal value of the assigned receiva-\nbles and the transfer price), reconstructing the subsequent\ntransactions involving the assigned receivables (fu\ue61fher\nsales and/or securitizations with non-residents carried out\nby the banks), in which the company had no role.\nIn the \ue61erst stages of the proceeding, which arose following\nSEN\u2019s appeal of the assessment, the company\u2019s objections\nconcerning the illegitimacy of the O\ue61ace\u2019s reclassi\ue61ecation\nof the transaction for tax purposes and, consequently, of\nthe payment \ue61dows were not upheld, despite signi\ue61ecant\nprocedural violations in the assessment activity.\nBelieving that it has valid legal grounds to continue the\ndispute, the company \ue61eled an appeal with the Cou\ue61f of\nCassation, asse\ue61fing the illegitimacy of the tax claim for vi-\nolation and false application of the rules that, in the view\nof the trial cou\ue61f, permit the classi\ue61ecation of the income\ngenerated by the assignment of receivables as \u201cprope\ue61fy\nincome\u201d, which, consequently, would require SEN to apply\nwithholding tax.\nThe overall amount involved in the dispute at December\n31, 2021 is about \u20ac81 million.\n",
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"value": "\n56. Future accounting standards \nThe following provides a list of accounting standards,\namendments and interpretations that will take e\ue61bect for\nthe Group after December 31, 2021.\n\u2022 \u201cAmendments to IAS 1 - Classi\ue61dcation of Liabilities as \nCurrent or Non-current\u201d, issued in January 2020. The \namendments regard the provisions of IAS 1 concern-\ning the presentation of liabilities. More speci\ue61ecally, the\nchanges clarify:\n \u2013 the criteria to adopt in classifying a liability as current \nor non-current, specifying the meaning of right of an\nentity to defer se\ue61clement and that that right must\nexist at the end of the repo\ue61fing period;\n \u2013 that the classi\ue61ecation is una\ue61bected by the intentions \nor expectations of management about when the\nentity will exercise its right to defer se\ue61clement of a\nliability;\n \u2013 that the right to defer exists if and only if the enti-\nty satis\ue61ees the terms of the loan at the end of the\nrepo\ue61fing period, even if the creditor does not verify\ncompliance until later; and\n \u2013 that se\ue61clement regards the transfer to the coun-\nterpa\ue61fy of cash, equity instruments, other assets or\nservices.\nThe amendments will take e\ue61bect, subject to endorse-\nment, for annual periods beginning on or after January\n1, 2023, with earlier application permi\ue61ced.\n\u2022 \u201cAmendments to IFRS 3 - Reference to the Conceptual \nFramework\u201d issued in May 2020. The amendments are \nintended to replace a reference to the de\ue61enitions of as-\nsets and liabilities provided by the Revised Conceptual\nFramework for Financial Repo\ue61fing issued in March 2018\n(Conceptual Framework) without signi\ue61ecantly changing\nits provisions.\nThe amendments also add to IFRS 3 a requirement that,\nfor transactions and other events within the scope of\n\u201cIAS 37 - Provisions, contingent liabilities and contin-\ngent assets\u201d or \u201cIFRIC 21 - Levies\u201d, an acquirer applies\nIAS 37 or IFRIC 21 (instead of the Conceptual Frame-\nwork) to identify the liabilities it has assumed in a busi-\nness combination.\nFinally, the amendments clarify the existing guidelines\nin IFRS 3 for contingent assets acquired in a business\ncombination, specifying that, if it is not sure that an as-\nset exists at the acquisition date, the contingent asset\nshall not be recognized.\nThe amendments will take e\ue61bect for annual periods be-\nginning on or after January 1, 2022.\n\u2022 \u201cAmendments to IAS 16 - Prope\ue61ey, Plant and Equipment: \nProceeds before Intended Use\u201d, issued in May 2020. The \namendments prohibit a company from deducting from\nthe cost of prope\ue61fy, plant and equipment amounts re-\nceived from selling items produced while the company\nis preparing the asset for its intended use. Instead, a\ncompany will recognize such sales proceeds and relat-\ned cost in pro\ue61et or loss. The amendments will take ef-\nfect for annual periods beginning on or after January 1,\n2022. Early application is permi\ue61ced.\n\u2022 \u201cAmendments to IAS 37 - Onerous Contracts - Costs \nof Ful\ue61dlling a Contract\u201d, issued in May 2020. The amend-\nments specify which costs an entity includes in deter-\nmining the cost of ful\ue61elling a contract for the purpose\nof assessing whether the contract is onerous. To this\nend, the cost of ful\ue61elling a contract comprises the costs\nthat relate directly to the contract. These consist of\nthe incremental costs of ful\ue61elling that contract or the\nallotment of other costs that relate directly to ful\ue61elling\ncontracts. The amendments will take e\ue61bect for annual\nperiods beginning on or after January 1, 2022. Early ap-\nplication is permi\ue61ced.\n\u2022 \u201cAnnual improvements to IFRS Standards 2018-2020\u201d, \nissued in May 2020. The document mainly comprises\namendments to the following standards:\n \u2013 \u201cIFRS 1 - First-Time Adoption of International Finan-\ncial Repo\ue61eing Standards\u201d; the amendment simpli\ue61ees \nthe application of IFRS 1 by an investee (subsidiary,\nassociate or joint venture) that becomes a \ue61erst-time\nadopter of IFRS Standards after its parent has al-\nready adopted them. More speci\ue61ecally, if the inves-\ntee adopts the IFRSs after its parent and applies IFRS\n1.D16 (a), then the investee can elect to measure the\ncumulative translation di\ue61berences for all foreign op-\nerations at the amounts that would be included in the\nparent\u2019s consolidated \ue61enancial statements, based on\nparent\u2019s date of transition to the IFRSs;\n \u2013 \u201cIFRS 9 - Financial Instruments\u201d; with regard to fees \nincluded in the \u201c10 per cent\u201c test for derecognition\nof \ue61enancial liabilities, the amendment clari\ue61ees the\nfees that an entity includes when assessing whether\nthe terms of a new or modi\ue61eed \ue61enancial liability are\nsubstantially di\ue61berent from the terms of the origi-\nnal \ue61enancial liability. In determining those fees paid\nnet of fees received, the borrower shall include only\nfees paid or received between the borrower and the\nlender, including fees paid or received by either the\nborrower or lender on the other pa\ue61fy\u2019s behalf;\n \u2013 \u201cIFRS 16 - Leases\u201d; the International Accounting \nStandards Board amended Illustrative Example 13\naccompanying \u201cIFRS 16 - Leases\u201d. Speci\ue61ecally, the\namendment eliminates the potential for confu-\nsion in the application of IFRS 16 created by the\nway in which Illustrative Example 13 had illustrated\nthe requirements for lease incentives. The example\nhad included a reimbursement relating to lease-\nhold improvements without explaining whether\nthe reimbursement quali\ue61eed as a lease incentive.\nThe amendment removes the illustration of a re-\nimbursement relating to leasehold improvements\nfrom the example;\n\n \u2013 \u201cIAS 41 - Agriculture\u201d; the amendment removes the \nrequirement for entities to exclude cash \ue61dows for tax-\nation when measuring fair value. Accordingly, entities\nshall use pre-tax cash \ue61dows and a pre-tax rate to dis-\ncount those cash \ue61dows.\nThe amendments shall be applied prospectively for an-\nnual periods beginning on or after January 1, 2022. Early\napplication is permi\ue61ced.\n\u2022 \u201cAmendments to IAS 1 and IFRS Practice Statement 2 \n- Disclosure of Accounting Policies\u201d, issued in February \n2021. The amendments are intended to suppo\ue61f entities\nin deciding which accounting policies to disclose in the\n\ue61enancial statements. The amendments to IAS 1 require\ncompanies to disclose their material accounting policy\ninformation rather than their signi\ue61ecant accounting pol-\nicies. A guide on how to apply the concept of materiality\nto disclosures on accounting policies is provided in the \namendments to IFRS Practice Statement 2. The amend-\nments will take e\ue61bect for annual periods beginning on or\nafter January 1, 2023. Early application is permi\ue61ced.\n\u2022 \u201cAmendments to IAS 8 - De\ue61dnition of Accounting Esti-\nmates\u201d, issued in February 2021. The amendments clarify \nhow companies should distinguish changes in account-\ning policies from changes in accounting estimates. The \nde\ue61enition of changes in accounting estimates has been\nreplaced with a de\ue61enition of accounting estimates as\n\u201cmonetary amounts in \ue61enancial statements that are sub-\nject to measurement unce\ue61fainty\u201d. The amendments will\ntake e\ue61bect for annual periods beginning on or after Jan-\nuary 1, 2023. Early application is permi\ue61ced.\n\u2022 \u201cAmendments to IAS 12 Income Taxes: Deferred Tax relat-\ned to Assets and Liabilities arising from a Single Transac-\ntion\u201d, issued in May 2021. The amendments require enti-\nties to recognize deferred tax on transactions that at in-\nitial recognition give rise to equal taxable and deductible\ntemporary di\ue61berences. The amendments will take e\ue61bect,\nsubject to endorsement, for annual periods beginning on\nor after January 1, 2023. Early application is permi\ue61ced.\n\u2022 \u201cAmendments to IFRS 10 and IAS 28 - Sale or Contribu-\ntion of Assets between an Investor and its Associate or\nJoint Venture\u201d, issued in September 2014. The amend-\nments clarify the accounting treatment for sales or con-\ntribution of assets between an investor and its associates\nor joint ventures. They con\ue61erm that the accounting treat-\nment depends on whether the assets sold or contributed\nto an associate or joint venture constitute a \u201cbusiness\u201c \n(as de\ue61ened in IFRS 3). The IASB has deferred the e\ue61bective \ndate of these amendments inde\ue61enitely.\n\u2022 \u201cIFRS 17 - Insurance Contracts\u201d, issued in May 2017. The \nstandard will take e\ue61bect for annual periods beginning on\nor after January 1, 2023, with earlier application permit-\nted.\nThe Group is assessing the potential impact of the future\napplication of the new provisions.\n",
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"period": "2021-01-01T00:00:00/2022-01-01T00:00:00"
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"value": "\n57. Events after the repo\ue61eing period\nEnel completes acquisition of 527 MW of\nhydro capacity from ERG\nOn January 3, 2022, Enel Produzione SpA \ue61enalized the ac-\nquisition of the entire share capital of ERG Hydro Srl from \nERG Power Generation SpA. Enel Produzione paid around \n\u20ac1,039 million for the company, as well as an initial price\nadjustment at closing of around \u20ac226 million to re\ue61dect\nthe mark-to-market valuation of ce\ue61fain hedging deriv-\natives of ERG Power Generation concerning pa\ue61f of the\nfuture power to be generated by the ERG Hydro plants.\nThe agreement also provides for an additional price ad-\njustment in the coming months, which will be calculated\nmainly on the basis of the changes in ERG Hydro\u2019s net\nworking capital and net \ue61enancial position, and the level of\nwater reserves in ce\ue61fain basins included in the sale. The\nplants owned by ERG Hydro, which are located in the Um-\nbria, Lazio, and Marche regions, have an installed capacity\nof 527 MW and an average annual output of around 1.5\nTWh.\nEnel places a \u20ac2.75 billion \u201csustainability-\nlinked bond\u201d in three tranches on the\neurobond market\nOn January 10, 2022, Enel Finance International NV, the\nDutch-registered \ue61enance company controlled by Enel\nSpA, placed a \u20ac2.75 billion \u201csustainability-linked bond\u201d in\nthree tranches, linked to the achievement of Enel\u2019s sus-\ntainability objective for the reduction of direct green-\nhouse gas emissions (Scope 1), contributing to the\nachievement of the United Nations Sustainable Develop-\nment Goal (SDG) 13 \u201cClimate Action\u201d and in line with the\nGroup\u2019s Sustainability-Linked Financing Framework.\nFitch revises Enel\u2019s long-term rating to\n\u201cBBB+\u201d and makes no change to the sho\ue61e-\nterm rating of \u201cF-2\u201d. The outlook is stable\nOn February 4, 2022, Fitch Ratings announced that it has\nrevised Enel SpA\u2019s long-term rating to \u201cBBB+\u201d from the \nprevious \u201cA-\u201d. The agency also con\ue61ermed Enel\u2019s sho\ue61f-\nterm rating at \u201cF-2\u201d. The outlook remains stable.\nAccording to the agency, the change in Enel\u2019s rating\nmainly re\ue61dects the expected increase in \ue61enancial leverage\nin the medium term due to the investment oppo\ue61funities \nthat have prompted Enel to gradually expand its capital\nexpenditure plans in response to the energy transition.\n\nRussia-Ukraine con\ue61dict\nOn February 24, 2022, the Russian President announced \n\u201ca special military operation\u201d in Ukrainian territory that led \nto the outbreak of con\ue61dict between the two countries.\nIn the previous weeks, various a\ue61cempts had been made\nto achieve a diplomatic solution to the strains between \nRussia and Ukraine that, following extensive and pro-\nlonged military maneuvers by the Russian armed forces \nalong the Ukrainian border, had persisted for some time.\nAs the days went by, hostilities escalated, with an intensi-\n\ue61ecation of clashes.\nThe Russian military intervention in Ukraine triggered\nprompt reactions from various countries and interna-\ntional organizations. The European Council called on \nRussia to immediately cease hostilities and withdraw its \narmed forces from Ukraine in compliance with interna-\ntional law. The United Nations General Assembly, meet-\ning in an emergency session, also approved a resolution\ncondemning the Russian military action in Ukraine, asking\nRussia to withdraw the army.\nAt the same time, the European Commission is address-\ning the humanitarian crisis engendered by the con\ue61dict\nin Ukraine, with the deployment of humanitarian aid and\nemergency aid programs, including increased \ue61enancial\nsuppo\ue61f to Ukraine.\nNegotiations are under way between the pa\ue61fies involved\nto seek a diplomatic solution that will prevent the situa-\ntion from becoming a threat to international peace and\nsecurity.\nThe European Union and other countries (e.g., the United\nStates, the United Kingdom, Australia, Japan, Switzerland\nand others) have imposed severe sanctions on Russia, \nwhich, although of varying e\ue61bectiveness, have impacted\nstrategic sectors of the Russian economy and the \ue61enan-\ncial sector and imposed personal restrictions on the Rus-\nsian President and other political and business \ue61egures.\nThe main European sanctions involve:\n\u2022 freezing Russian assets in the euro area;\n\u2022 blocking the access of Russian banks to European \ue61e-\nnancial markets;\n\u2022 imposing expo\ue61f control measures (including a ban on \nthe expo\ue61f of goods to Russia and Belarus in the avia-\ntion, maritime, space, technology and \u201cdual-use\u201d sec-\ntors);\n\u2022 freezing commercial transactions with the Ukrainian \nregions of Donetsk and Luhansk;\n\u2022 excluding major Russian banks from the international \nSWIFT transaction system;\n\u2022 blocking current accounts with the Sberbank banking \ngroup;\n\u2022 closing airspace to Russian \ue61dights;\n\u2022 freezing the personal assets of the Russian President, \noligarchs, politicians and senior executives of the Rus-\nsian companies that suppo\ue61f him.\nThese sanctions have had an initial impact on the ex-\nchange rate of the ruble, which has depreciated sharply\nagainst the euro and the US dollar, on local interest rates\n(which were increased to 20% by the Russian Central \nBank) and on the share prices of companies listed on the\nMoscow Stock Exchange (with a signi\ue61ecant decline being\nrecorded in March).\nFinancial di\ue61aculties have also been associated with an\nincreased level of IT risk, to which businesses and gov-\nernments are exposed, making it necessary to adopt ad-\nequate defense measures and stringent internal controls \nto safeguard their digital infrastructure.\nConsidering this background, the Enel Group has activat-\ned a task force to carefully monitor the status and evolu-\ntion of current developments and manage potential risks.\nToday, the Enel Group is present in Russia with a num-\nber of companies in which it holds control or joint con-\ntrol with other investors. More speci\ue61ecally, the Enel Group\ncontrols:\n\u2022 Enel Russia PJSC (56.43% owned by Enel SpA), a com-\npany listed on the Moscow Stock Exchange that gen-\nerates electricity, mainly with three thermal generation \nplants, and holds 100% stakes in three renewable gen-\neration companies;\n\u2022 Enel Green Power Rus LLC (a 100% indirect subsidiary of \nEnel SpA), a company that provides services for the de-\nvelopment of renewable energy projects and which holds\n100% stakes in four renewable generation companies;\n\u2022 Enel X Rus LLC (a 99% indirect subsidiary of Enel SpA). \nEnel SpA also directly holds an investment of 49.5% in a \njoint venture (Rusenergosbyt LLC) operating in the End-us-\ner Markets Business Line.\nAt the end of 2021, the three thermal generation plants\noperating in Russia had an installed capacity of 5,276 MW,\nwhile renewables installed wind capacity was equal to 228\nMW (including 138 MW of pa\ue61fial additional capacity of the\nMurmansk Kolskaya Wind Farm plant, which is under con-\nstruction).\nThe contribution of the Russian companies to the main\nconsolidated pe\ue619ormance aggregates in 2021 (consider-\ning the average 2021 euro/ruble exchange rate of 87.18) is\nnot signi\ue61ecant and includes revenue of \u20ac564 million (0.6%\nof the total consolidated revenue of the Enel Group), op-\nerating pro\ue61et of \u20ac51 million (0.7% of total Enel Group oper-\nating pro\ue61et) and pro\ue61et of \u20ac64 million (2.0% of Enel Group\npro\ue61et).\nAt December 31, 2021, considering the end-2021 euro/ru-\nble exchange rate of 85.35, the main statement of \ue61enancial\nposition items of the Enel Group companies operating in\nRussia regarded:\n\u2022 under assets, \u20ac846 million of prope\ue61fy, plant and equip-\nment, \u20ac47 million in deferred tax assets, \u20ac44 million\nin trade receivables and \u20ac123 million in cash and cash\nequivalents;\n\n\u2022 under liabilities, \u20ac428 million in borrowings, \u20ac54 million in \ndeferred tax liabilities and \u20ac93 million in trade payables.\nThe Enel Group is constantly monitoring the impact of the\ninternational crisis on its operations in Russia (with pa\ue61ficu-\nlar regard to the procurement of materials, services and\nlabor) and evaluating developments in market variables\n(exchange rates, interest rates), \ue61erst and foremost taking\nconsideration of the potential e\ue61bects on pe\ue619ormance and\n\ue61enancial position of the depreciation of the ruble against\nthe euro. Fu\ue61fhermore, the Enel Group is also assessing de-\nvelopments associated with the counter-sanctions being\ndeployed by Russia against investments in the country.\nThe Enel Group is conducting analyses to assess the in-\ndirect impacts of the war in Ukraine on operations, the\n\ue61enancial situation and pe\ue619ormance in the main euro-ar-\nea countries in which it operates, with pa\ue61ficular regard\nto sho\ue61fages of raw materials from the areas a\ue61bected by \nthe con\ue61dict and the generalized increase in commodity\nprices.\nThe Enel Group does not have gas supply contracts \n(pipeline and LNG) with Russia, but in Italy measures are\nbeing evaluated at the regulatory level to reduce the de-\nmand for gas and to contain price volatility on the mar-\nkets. In Spain (where the Group is present with its subsid-\niary Endesa SA), in addition to regulatory developments,\nwe are analyzing the e\ue61bects on nuclear fuel orders from\nRussia.\nPa\ue61ficular a\ue61cention is also paid to the impacts of the war\non activities in Slovakia, where the Enel Group is present\nwith the jointly controlled company Slovensk\u00e9 elektr\u00e1rne\nAS (SE), of which Enel SpA indirectly holds 33%. It oper-\nates in the generation of electricity from nuclear, thermal\nand hydroelectric sources with an installed capacity of 4\nGW. SE\u2019s nuclear plants have links with Russia involving\ntechnical-operational activities (supply of nuclear fuel\nand technology), investments (Russian suppliers involved\nin the construction of the MO3/4 plant who are currently\nnot targeted by the sanctions) and loans (SE\u2019s debt expo-\n(44) ESMA no. 71-99-1864 of March 14, 2022; CONSOB warning notice in the weekly bulletin of March 9-14, 2022.\nsure to Sberbank).\nIn this highly \ue61duid situation, characterized by considera-\nble regulatory unce\ue61fainty and high and volatile prices, the\nEnel Group is carefully monitoring macroeconomic and\nbusiness variables in order to develop the most accurate\nreal-time estimates of impacts connected with regulatory \nchanges, sanctions and restrictions on assets, as well as \non suppliers and contracts applicable to the Enel Group,\ntaking due account of the recommendations issued by \nnational and supranational organizations on this issue.\n(44)\nEnel \ue61fnalizes renewal of pa\ue61enership with\nCinven in U\ue61fnet Latam\nOn March 24, 2022, Enel X International Srl (Enel X Inter-\nnational), a wholly-owned subsidiary of Enel X Srl (Enel X), \nclosed the agreement signed on December 21, 2021 with\na holding company controlled by the Sixth Cinven Fund \nand a holding company controlled by the Seventh Cin-\nven Fund acquiring indirectly, through a holding compa-\nny, about 79% of the share capital of U\ue61enet Latam SLU\n(\u201cU\ue61enet\u201d or the \u201cCompany\u201d) from the Sixth Cinven Fund\nand simultaneously selling 80.5% of the Company\u2019s share\ncapital to the Seventh Cinven Fund. As a result, Enel X In-\nternational now indirectly retains a stake equal to 19.5%\nof U\ue61enet, renewing the pa\ue61fnership in the Company with\nCinven.\nMore speci\ue61ecally, Enel X International, which previously\nindirectly owned a stake of about 21% in the Company,\nexercised the call option to acquire around 79% of the\nshare capital of U\ue61enet for \u20ac1,320 million. At the same\ntime, Enel X International received around \u20ac207 million as\na distribution of available reserves from U\ue61enet and simul-\ntaneously sold 80.5% of the Company\u2019s share capital to\nthe Seventh Cinven Fund for about \u20ac1,186 million.\nUnder the agreement, Enel X International, in addition to\nindirectly retaining 19.5% of the share capital of U\ue61enet,\nkeeps representation on the la\ue61cer and its holding com-\npany\u2019s boards of directors, retaining standard minority\nshareholder protection rights.\n",
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"value": "\nDeclaration of the Chief Executive O\ue618cer and the o\ue618cer in charge of\n\ue61fnancial repo\ue61eing of the Enel Group at December 31, 2021, pursuant\nto the provisions of A\ue61eicle 154-bis, paragraph 5, of Legislative Decree\n58 of February 24, 1998 and A\ue61eicle 81-ter of CONSOB Regulation no.\n11971 of May 14, 1999\n1. The undersigned Francesco Starace and Albe\ue61fo De \nPaoli, in their respective capacities as Chief Executive\nO\ue61acer and o\ue61acer in charge of \ue61enancial repo\ue61fing of\nEnel SpA, hereby ce\ue61fify, taking account of the provi-\nsions of A\ue61ficle 154-bis, paragraphs 3 and 4, of Legisla-\ntive Decree 58 of February 24, 1998:\n a. the appropriateness with respect to the character-\nistics of the Enel Group and\n b. the e\ue61bective adoption of\n the administrative and accounting procedures for\nthe preparation of the consolidated \ue61enancial state-\nments of the Enel Group in the period between Jan-\nuary 1, 2021 and December 31, 2021.\n2. In this regard, we repo\ue61f that:\n a. the appropriateness of the administrative and ac-\ncounting procedures used in the preparation of the\nconsolidated \ue61enancial statements of the Enel Group\nhas been veri\ue61eed in an assessment of the internal\ncontrol system for \ue61enancial repo\ue61fing. The assess-\nment was carried out on the basis of the guidelines\nset out in the \u201cInternal Controls - Integrated Frame-\nwork\u201d issued by the Commi\ue61cee of Sponsoring Or-\nganizations of the Treadway Commission (COSO);\n b. the assessment of the internal control system for \ue61e-\nnancial repo\ue61fing did not identify any material issues.\n3. In addition, we ce\ue61fify that the consolidated \ue61enancial \nstatements of the Enel Group at December 31, 2021:\n a. have been prepared in compliance with the Inter-\nnational Financial Repo\ue61fing Standards endorsed by\nthe European Union pursuant to Regulation (EC) no.\n1606/2002 of the European Parliament and of the\nCouncil of July 19, 2002;\n b. correspond to the information in the books and oth-\ner accounting records;\n c. provide a true and fair representation of the \ue61enancial \nposition, \ue61enancial pe\ue619ormance and cash \ue61dows of\nthe issuer and the companies included in the con-\nsolidation scope.\n4. Finally, we ce\ue61fify that the Repo\ue61f on Operations, ac-\ncompanied by the consolidated \ue61enancial statements of\nthe Enel Group at December 31, 2021, contains a relia-\nble analysis of operations and pe\ue619ormance, as well as\nthe situation of the issuer and the companies included\nin the consolidation scope, together with a description\nof the main risks and unce\ue61fainties to which they are ex-\nposed.\nRome, March 17, 2022\nFrancesco Starace\nChief Executive O\ue61acer \nof Enel SpA\nAlbe\ue61fo De Paoli\nO\ue61acer in charge of \ue61enancial repo\ue61fing \nof Enel SpA\n",
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"value": "Enel SpA",
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"Tag50": {
"value": "\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nEndesa Medios y\nSistemas SL (Sociedad\nUnipersonal)\nMadrid ES 89,999,790.00 EUR Line-by-line Endesa SA 100.00% 70.11%\nEndesa Operaciones y\nServicios Comerciales\nSL\nMadrid ES 10,138,580.00 EUR Line-by-line Endesa Energ\u00eda SA 100.00% 70.11%\nEndesa Red SA \n(Sociedad Unipersonal)\nMadrid ES 719,901,723.26 EUR Line-by-line Endesa SA 100.00% 70.11%\nEndesa SA Madrid ES 1,270,502,540.40 EUR Line-by-line\nEndesa SA 0.02%\n70.11%\nEnel Iberia Srl 70.10%\nEndesa Soluciones SL Madrid ES 2,874,621.80 EUR Equity\nEndesa X Servicios\nSLU \n20.00% 14.02%\nEndesa X Servicios SLU Madrid ES 60,000.00 EUR Line-by-line Endesa SA 100.00% 70.11%\nEnel Albe\ue61fa Wind Inc. Albe\ue61fa CA 16,251,021.00 CAD Line-by-line\nEnel Green Power\nCanada Inc. \n100.00% 100.00%\nEnel Am\u00e9ricas SA\nSantiago de\nChile\nCL 15,799,498,544.85 USD Line-by-line\nEnel Am\u00e9ricas SA 0.00%\n82.27%\nEnel SpA 82.27%\nEnel and Shikun &\nBinui Innovation\nInfralab Ltd\nAirpo\ue61f City IL 38,000.00 ILS Equity\nEnel Global\nInfrastructure and\nNetworks Srl\n50.00% 50.00%\nEnel Argentina SA Buenos Aires AR 2,297,711,908.00 ARS Line-by-line\nEnel Am\u00e9ricas SA 99.92%\n82.25%\nEnel Generaci\u00f3n\nChile SA\n0.08%\nEnel Bella Energy\nStorage LLC\nWilmington US - USD Line-by-line\nEnel Energy\nStorage Holdings\nLLC (formerly EGP\nEnergy Storage\nHoldings LLC)\n100.00% 100.00%\nEnel Brasil Central SA Rio de Janeiro BR 10,000.00 BRL Line-by-line Enel Brasil SA 100.00% 82.27%\nEnel Brasil SA Niter\u00f3i BR 32,387,634,190.06 BRL Line-by-line\nEnel Am\u00e9ricas SA 99.50%\n82.27%\nEnel Brasil SA 0.50%\nEnerg\u00eda y Servicios\nSouth America\nSpA\n0.00%\nEnel Chile SA\nSantiago de\nChile\nCL 3,882,103,470,184.00 CLP Line-by-line Enel SpA 64.93% 64.93%\nEnel CIEN SA Rio de Janeiro BR 285,044,682.00 BRL Line-by-line Enel Brasil SA 100.00% 82.27%\nEnel Colina SA\nSantiago de\nChile\nCL 82,222,000.00 CLP Line-by-line\nEnel Chile SA 0.00%\n64.34%\nEnel Distribuci\u00f3n\nChile SA\n100.00%\nEnel Cove Fo\ue61f II LLC Wilmington US - USD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nEnel Cove Fo\ue61f LLC Beaver US - USD Line-by-line\nEnel Geothermal\nLLC \n100.00% 100.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nEnel Distribuci\u00f3n Chile\nSA\nSantiago de\nChile\nCL 177,568,664,063.00 CLP Line-by-line Enel Chile SA 99.09% 64.34%\nEnel Distribuci\u00f3n Per\u00fa\nSAA\nSan Miguel PE 638,563,900.00 PEN Line-by-line Enel Per\u00fa SAC 83.15% 68.41%\nEnel Energia SpA Rome IT 302,039.00 EUR Line-by-line Enel Italia SpA 100.00% 100.00%\nEnel Energ\u00eda SA de Cv Mexico City MX 25,000,100.00 MXN Line-by-line\nEnel Green Power\nM\u00e9xico S de RL\nde Cv\n100.00%\n100.00%\nEnerg\u00eda Nueva de\nIguu S de RL de Cv\n0.00%\nEnel Energie Muntenia\nSA\nBucharest RO 37,004,350.00 RON Line-by-line Enel SpA 78.00% 78.00%\nEnel Energie SA Bucharest RO 140,000,000.00 RON Line-by-line Enel SpA 51.00% 51.00%\nEnel Energy Australia\n(Pty) Ltd\nSydney AU 200,100.00 AUD Line-by-line\nEnel Green Power\nAustralia (Pty) Ltd\n100.00% 100.00%\nEnel Energy South\nAfrica\nWilmington ZA 100.00 ZAR Line-by-line\nEnel X\nInternational Srl\n100.00% 100.00%\nEnel Energy Storage\nHoldings LLC (formerly\nEGP Energy Storage\nHoldings LLC)\nAndover US 100.00 USD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nEnel Finance America\nLLC\nWilmington US 200,000,000.00 USD Line-by-line\nEnel No\ue61fh\nAmerica Inc. \n100.00% 100.00%\nEnel Finance\nInternational NV\nAmsterdam NL 1,478,810,371.00 EUR Line-by-line\nEnel Holding\nFinance Srl\n75.00%\n100.00%\nEnel SpA 25.00%\nEnel Fo\ue61funa SA Panama City PA 100,000,000.00 USD Line-by-line\nEnel Green Power\nPanam\u00e1 Srl \n50.06% 41.18%\nEnel Future Project \n2020 #1 LLC\nAndover US - USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nEnel Future Project \n2020 #10 LLC\nAndover US - USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nEnel Future Project \n2020 #11 LLC\nAndover US - USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nEnel Future Project \n2020 #12 LLC\nAndover US - USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nEnel Future Project \n2020 #13 LLC\nAndover US - USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nEnel Future Project \n2020 #14 LLC\nAndover US - USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nEnel Future Project \n2020 #15 LLC\nAndover US - USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nEnel Future Project \n2020 #16 LLC\nAndover US - USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nEnel Future Project \n2020 #17 LLC\nAndover US - USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nEnel Future Project \n2020 #18 LLC\nAndover US - USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nEnel Future Project \n2020 #19 LLC\nAndover US - USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nEnel Future Project \n2020 #2 LLC\nAndover US - USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nEnel Future Project \n2020 #20 LLC\nAndover US - USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nEnel Future Project \n2020 #3 LLC\nAndover US - USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nEnel Future Project \n2020 #4 LLC\nAndover US - USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nEnel Future Project \n2020 #5 LLC\nAndover US - USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nEnel Future Project \n2020 #6 LLC\nAndover US - USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nEnel Future Project \n2020 #7 LLC\nAndover US - USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nEnel Future Project \n2020 #8 LLC\nAndover US - USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nEnel Future Project \n2020 #9 LLC\nAndover US - USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nEnel Generaci\u00f3n Chile\nSA\nSantiago de\nChile\nCL 552,777,320,871.00 CLP Line-by-line Enel Chile SA 93.55% 60.74%\nEnel Generaci\u00f3n\nCostanera SA\nBuenos Aires AR 701,988,378.00 ARS Line-by-line Enel Argentina SA 75.68% 62.25%\nEnel Generaci\u00f3n El\nChoc\u00f3n SA\nBuenos Aires AR 18,321,776,559.00 ARS Line-by-line\nEnel Argentina SA 8.67%\n54.07%\nHidroinvest SA 59.00%\nEnel Generaci\u00f3n Per\u00fa\nSAA\nSan Miguel PE 2,108,101,266.48 PEN Line-by-line Enel Per\u00fa SAC 83.60% 68.78%\nEnel Generaci\u00f3n Piura\nSA\nSan Miguel PE 73,982,594.00 PEN Line-by-line Enel Per\u00fa SAC 96.50% 79.39%\nEnel Generaci\u00f3n SA\nde Cv\nMexico City MX 7,100,100.00 MXN Line-by-line\nEnel Green Power\nM\u00e9xico S de RL\nde Cv\n100.00%\n100.00%\nEnerg\u00eda Nueva de\nIguu S de RL de Cv\n0.00%\nEnel Geothermal LLC Wilmington US - USD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nEnel Global\nInfrastructure and\nNetworks Srl\nRome IT 10,100,000.00 EUR Line-by-line Enel SpA 100.00% 100.00%\nEnel Global Services Srl Rome IT 10,000.00 EUR Line-by-line Enel SpA 100.00% 100.00%\nEnel Global Thermal\nGeneration Srl\nRome IT 1,000,000.00 EUR Line-by-line Enel SpA 100.00% 100.00%\nEnel Global Trading\nSpA\nRome IT 90,885,000.00 EUR Line-by-line Enel SpA 100.00% 100.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nEnel Green Power\nArgentina SA\nBuenos Aires AR 463,577,761.00 ARS Line-by-line\nEnel Am\u00e9ricas SA 99.86%\n82.27%\nEnel Green Power\nSpA\n0.00%\nEnerg\u00eda y Servicios\nSouth America\nSpA\n0.14%\nEnel Green Power\nAroeira 01 SA\nRio de Janeiro BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power\nAroeira 02 SA\nRio de Janeiro BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power\nAroeira 03 SA\nRio de Janeiro BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power\nAroeira 04 SA\nRio de Janeiro BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power\nAroeira 05 SA\nRio de Janeiro BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power\nAroeira 06 SA\nRio de Janeiro BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power\nAroeira 07 SA\nRio de Janeiro BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power\nAroeira 08 SA\nRio de Janeiro BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power\nAroeira 09 SA (formerly\nEnel Green Power S\u00e3o\nGon\u00e7alo Pa\ue61ficipa\u00e7\u00f5es\nSA)\nRio de Janeiro BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power\nAustralia (Pty) Ltd\nSydney AU 100.00 AUD Line-by-line\nEnel Green Power\nSpA\n100.00% 100.00%\nEnel Green Power\nAustralia Trust\nSydney AU 100.00 AUD Line-by-line\nEnel Green Power\nSpA\n100.00% 100.00%\nEnel Green Power\nAzure Blue Jay Solar\nHoldings LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nEnel Green Power\nAzure Ranchland\nHoldings LLC\nAndover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEnel Green Power Boa\nVista 01 Ltda\nSalvador BR 3,554,607.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.00%\nEnel Green Power Boa\nVista E\u00f3lica SA\nRio de Janeiro BR 104,890,000.00 BRL Line-by-line Enel Brasil SA 100.00% 82.27%\nEnel Green Power\nBouldercombe Holding\n(Pty) Ltd\nSydney AU 100.00 AUD Line-by-line\nEnel Green Power\nAustralia (Pty) Ltd\n100.00% 100.00%\nEnel Green Power\nBouldercombe Trust\nSydney AU 10.00 AUD Line-by-line\nEnel Green Power\nAustralia Trust \n100.00% 100.00%\nEnel Green Power\nBrejol\u00e2ndia Solar SA\nRio de Janeiro BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power\nBungala (Pty) Ltd\nSydney AU 100.00 AUD Line-by-line\nEnel Green Power\nAustralia (Pty) Ltd\n100.00% 100.00%\nEnel Green Power\nBungala Trust\nSydney AU - AUD Line-by-line\nEnel Green Power\nAustralia (Pty) Ltd\n100.00% 100.00%\nEnel Green Power\nCabe\u00e7a de Boi SA\nNiter\u00f3i BR 270,114,539.00 BRL Line-by-line Enel Brasil SA 100.00% 82.27%\nEnel Green Power\nCachoeira Dourada SA\nCachoeira\nDourada\nBR 64,339,835.85 BRL Line-by-line\nEnel Brasil SA 99.61%\n82.07%\nEnel Green\nPower Cachoeira\nDourada SA\n0.15%\nEnel Green Power\nCalabria Srl\nRome IT 10,000.00 EUR Line-by-line\nEnel Green Power\nItalia Srl\n100.00% 100.00%\nEnel Green Power\nCanada Inc.\nMontreal CA 85,681,857.00 CAD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nEnel Green Power\nCerrado Solar SA\nRio de Janeiro BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power\nChile SA\nSantiago de\nChile\nCL 842,121,530.67 USD Line-by-line\nEnel Chile SA 99.99%\n64.93%\nEnel SpA 0.01%\nEnel Green Power\nCimarron Bend Wind\nHoldings III LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEnel Green Power\nCohuna Holdings (Pty)\nLtd\nSydney AU 3,419,700.00 AUD Line-by-line\nEnel Green Power\nAustralia (Pty) Ltd\n100.00% 100.00%\nEnel Green Power\nCohuna Trust\nSydney AU - AUD Line-by-line\nEnel Green Power\nAustralia Trust \n100.00% 100.00%\nEnel Green Power\nColombia SAS ESP\nBogot\u00e1 CO 13,849,425,000.00 COP Line-by-line Enel Am\u00e9ricas SA 100.00% 82.27%\nEnel Green Power\nCosta Rica SA\nSan Jos\u00e9 CR 27,500,000.00 USD Line-by-line ESSA2 SpA 100.00% 82.27%\n\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nEnel Green Power Cove \nFo\ue61f Solar LLC\nWilmington US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEnel Green Power\nCremzow GmbH &\nCo. Kg\nSchenkenberg DE 1,000.00 EUR Line-by-line\nEnel X Germany\nGmbH\n90.00% 90.00%\nEnel Green Power\nCremzow Verwaltungs\nGmbH\nSchenkenberg DE 25,000.00 EUR Line-by-line\nEnel X Germany\nGmbH\n90.00% 90.00%\nEnel Green Power\nCristal E\u00f3lica SA\nRio de Janeiro BR 144,784,899.00 BRL Line-by-line\nEnel Brasil SA 99.17%\n82.27%\nEnel Green Power\nCristal E\u00f3lica SA\n0.00%\nEnel Green Power\nDesenvolvimento\nLtda \n0.83%\nEnel Green Power\nCumaru 01 SA\nNiter\u00f3i BR 204,653,590.90 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.00%\nEnel Green Power\nCumaru 02 SA\nNiter\u00f3i BR 210,001,000.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.00%\nEnel Green Power\nCumaru 03 SA\nRio de Janeiro BR 200,001,000.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.00%\nEnel Green Power\nCumaru 04 SA\nRio de Janeiro BR 200,001,000.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.00%\nEnel Green Power\nCumaru 05 SA\nRio de Janeiro BR 180,208,000.90 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.00%\nEnel Green Power\nCumaru Pa\ue61ficipa\u00e7\u00f5es\nSA\nRio de Janeiro BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power\nCumaru Solar 01 SA\nRio de Janeiro BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power\nCumaru Solar 02 SA\nRio de Janeiro BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nEnel Green Power\nDamascena E\u00f3lica SA\nRio de Janeiro BR 83,709,003.00 BRL Line-by-line\nEnel Brasil SA 99.16%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.84%\nEnel Green Power\nDel\ue61ena A E\u00f3lica SA\nRio de Janeiro BR 549,062,483.00 BRL Line-by-line Enel Brasil SA 100.00% 82.27%\nEnel Green Power\nDel\ue61ena B E\u00f3lica SA\nRio de Janeiro BR 93,068,000.00 BRL Line-by-line Enel Brasil SA 100.00% 82.27%\nEnel Green Power\nDel\ue61ena C E\u00f3lica SA\nRio de Janeiro BR 31,105,000.00 BRL Line-by-line Enel Brasil SA 100.00% 82.27%\nEnel Green Power\nDel\ue61ena D E\u00f3lica SA\nRio de Janeiro BR 105,864,000.00 BRL Line-by-line Enel Brasil SA 100.00% 82.27%\nEnel Green Power\nDel\ue61ena E E\u00f3lica SA\nNiter\u00f3i BR 105,936,000.00 BRL Line-by-line Enel Brasil SA 100.00% 82.27%\nEnel Green Power\nDesenvolvimento Ltda\nRio de Janeiro BR 46,617,590.35 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nEnerg\u00eda y Servicios\nSouth America\nSpA\n0.00%\nEnel Green Power\nDevelopment Srl\nRome IT 20,000.00 EUR Line-by-line\nEnel Green Power\nSpA\n100.00% 100.00%\nEnel Green Power\nDiamond Vista Wind\nProject LLC\nWilmington US 1.00 USD Line-by-line\nDiamond Vista\nHoldings LLC\n100.00% 100.00%\nEnel Green Power Dois\nRiachos E\u00f3lica SA\nRio de Janeiro BR 130,354,009.00 BRL Line-by-line Enel Brasil SA 100.00% 82.27%\nEnel Green Power\nEgypt SAE\nCairo EG 250,000.00 EGP Line-by-line\nEnel Green Power\nSpA\n100.00% 100.00%\nEnel Green Power El\nSalvador SA de Cv\nEl Salvador SV 22,860.00 USD Line-by-line\nEnel Green Power\nSpA\n99.96%\n99.99%\nEnerg\u00eda y Servicios\nSouth America\nSpA\n0.04%\nEnel Green Power\nElkwater Wind Limited\nPa\ue61fnership\nAlbe\ue61fa CA 1,000.00 CAD Line-by-line\nEnel Albe\ue61fa Wind\nInc.\n1.00%\n100.00%\nEnel Green Power\nCanada Inc. \n99.00%\nEnel Green Power\nElmsthorpe Wind LP\nCalgary CA 1,000.00 CAD Line-by-line\nEnel Albe\ue61fa Wind\nInc.\n0.10%\n100.00%\nEnel Green Power\nCanada Inc. \n99.90%\nEnel Green Power\nEmiliana E\u00f3lica SA\nRio de Janeiro BR 135,191,530.00 BRL Line-by-line\nEnel Brasil SA 98.81%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n1.19%\nEnel Green Power\nEmiliana E\u00f3lica SA\n0.00%\nEnel Green Power\nEspa\u00f1a SLU\nSeville ES 11,152.74 EUR Line-by-line\nEndesa\nGeneraci\u00f3n SA\n100.00% 70.11%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nEnel Green Power\nEsperan\u00e7a E\u00f3lica SA\nRio de Janeiro BR 129,418,174.00 BRL Line-by-line\nEnel Brasil SA 99.14%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.86%\nEnel Green Power\nEsperan\u00e7a Solar SA\nRio de Janeiro BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power\nFazenda SA\nNiter\u00f3i BR 264,141,174.00 BRL Line-by-line Enel Brasil SA 100.00% 82.27%\nEnel Green Power\nFontes dos Ventos 2 SA\nRio de Janeiro BR 283,315,219.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.00%\nEnel Green Power\nFontes dos Ventos 3 SA\nRio de Janeiro BR 221,001,000.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.00%\nEnel Green Power\nFontes II Pa\ue61ficipa\u00e7\u00f5es\nSA\nRio de Janeiro BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power\nFontes Solar SA\nRio de Janeiro BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power\nFrance SAS\nParis FR 100,000.00 EUR Line-by-line\nEnel Green Power\nSpA\n100.00% 100.00%\nEnel Green Power\nGermany GmbH\nBerlin DE 25,000.00 EUR Line-by-line\nEnel Green Power\nSpA\n100.00% 100.00%\nEnel Green Power\nGirgarre Holdings\n(Pty) Ltd\nSydney AU 100.00 AUD Line-by-line\nEnel Green Power\nAustralia (Pty) Ltd\n100.00% 100.00%\nEnel Green Power\nGirgarre Trust\nSydney AU 10.00 AUD Line-by-line\nEnel Green Power\nAustralia Trust \n100.00% 100.00%\nEnel Green Power\nGlobal Investment BV\nAmsterdam NL 10,000.00 EUR Line-by-line\nEnel Green Power\nSpA\n100.00% 100.00%\nEnel Green Power\nGuatemala SA\nGuatemala City GT 67,208,000.00 GTQ Line-by-line\nEnel Am\u00e9ricas SA 0.00%\n82.27%\nESSA2 SpA 100.00%\nEnel Green Power\nHadros Wind Limited \nPa\ue61fnership\n- CA 1,000.00 CAD Line-by-line\nEnel Albe\ue61fa Wind\nInc.\n1.00%\n100.00%\nEnel Green Power\nCanada Inc. \n99.00%\nEnel Green Power\nHellas SA\nMaroussi GR 159,187,850.00 EUR Line-by-line\nEnel Green Power\nSpA\n100.00% 100.00%\nEnel Green Power\nHellas Supply Single\nMember SA\nMaroussi GR 600,000.00 EUR Line-by-line\nEnel Green Power\nHellas SA\n100.00% 100.00%\n\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nEnel Green Power\nHellas Wind Parks \nSouth Evia Single\nMember SA\nMaroussi GR 141,569,641.00 EUR Line-by-line\nEnel Green Power\nHellas SA\n100.00% 100.00%\nEnel Green Power\nHilltopper Wind LLC \n(formerly Hilltopper\nWind Power LLC)\nDover US 1.00 USD Line-by-line\nHilltopper Wind\nHoldings LLC\n100.00% 100.00%\nEnel Green Power\nHorizonte Mp Solar SA\nRio de Janeiro BR 431,566,053.00 BRL Line-by-line\nAlba Energia Ltda 0.01%\n82.27%\nEnel Brasil SA 99.99%\nEnel Green Power India\nPrivate Limited\nNew Delhi IN 113,504,823.00 INR Line-by-line\nEnel Green Power\nDevelopment Srl\n100.00% 100.00%\nEnel Green Power\nItalia Srl\nRome IT 272,000,000.00 EUR Line-by-line Enel Italia SpA 100.00% 100.00%\nEnel Green Power\nItuverava No\ue61fe Solar \nSA\nRio de Janeiro BR 210,706,645.67 BRL Line-by-line\nBondia Energia\nLtda \n0.09%\n82.27%\nEnel Brasil SA 99.91%\nEnel Green\nPower Brasil\nPa\ue61ficipa\u00e7\u00f5es Ltda\n0.00%\nEnel Green Power\nItuverava Solar SA\nRio de Janeiro BR 219,235,933.00 BRL Line-by-line\nBondia Energia\nLtda \n0.00%\n82.27%\nEnel Brasil SA 100.00%\nEnel Green Power\nItuverava Sul Solar SA\nRio de Janeiro BR 407,279,143.00 BRL Line-by-line\nBondia Energia\nLtda \n0.00%\n82.27%\nEnel Brasil SA 100.00%\nEnel Green Power\nJoana E\u00f3lica SA\nRio de Janeiro BR 130,259,530.00 BRL Line-by-line\nEnel Brasil SA 98.84%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n1.16%\nEnel Green Power\nKenya Limited\nNairobi KE 100,000.00 KES Line-by-line\nEnel Green Power\nRSA (Pty) Ltd\n1.00%\n100.00%\nEnel Green Power\nSpA\n99.00%\nEnel Green Power\nKorea LLC\nSeoul KR 4,350,000,000.00 KRW Line-by-line\nEnel Green Power\nSpA\n100.00% 100.00%\nEnel Green Power\nLagoa do Sol 01 SA\nTeresina BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power\nLagoa do Sol 02 SA\nTeresina BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\n\nEnel Green Power\nDesenvolvimento\nLtda \n0.80%\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nEnel Green Power\nLagoa do Sol 03 SA\nTeresina BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power\nLagoa do Sol 04 SA\nTeresina BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power\nLagoa do Sol 05 SA\nTeresina BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power\nLagoa do Sol 06 SA\nTeresina BR 1,000,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power\nLagoa do Sol 07 SA\nTeresina BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power\nLagoa do Sol 08 SA\nTeresina BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power\nLagoa do Sol 09 SA\nTeresina BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power\nLagoa II Pa\ue61ficipa\u00e7\u00f5es \nSA\nRio de Janeiro BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power\nLagoa III Pa\ue61ficipa\u00e7\u00f5es \nSA\nRio de Janeiro BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power\nLagoa Pa\ue61ficipa\u00e7\u00f5es SA \n(formerly Enel Green\nPower Projetos 45 SA)\nRio de Janeiro BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power Lily\nSolar Holdings LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEnel Green Power\nMani\u00e7oba E\u00f3lica SA\nRio de Janeiro BR 90,722,530.00 BRL Line-by-line\nEnel Brasil SA 99.20%\n82.27%\n\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nEnel Green Power\nMatimba Srl\nRome IT 10,000.00 EUR Equity\nEnel Green Power\nSpA\n50.00% 50.00%\nEnel Green Power\nMetehara Solar Private\nLimited Company\n- ET 5,600,000.00 ETB Line-by-line\nEnel Green Power\nSolar Metehara\nSpA\n80.00% 80.00%\nEnel Green Power\nM\u00e9xico S de RL de Cv\nMexico City MX 662,949,966.00 MXN Line-by-line\nEnel Green Power\nSpA\n100.00%\n100.00%\nEnel Rinnovabile \nSA de Cv\n0.00%\nEnel Green Power\nModelo I E\u00f3lica SA\nRio de Janeiro BR 132,642,000.00 BRL Line-by-line Enel Brasil SA 100.00% 82.27%\nEnel Green Power\nModelo II E\u00f3lica SA\nRio de Janeiro BR 107,742,000.00 BRL Line-by-line Enel Brasil SA 100.00% 82.27%\nEnel Green Power\nMorocco SARLAU\nCasablanca MA 480,000,000.00 MAD Line-by-line\nEnel Green Power\nSpA\n100.00% 100.00%\nEnel Green Power\nMorro do Chap\u00e9u I\nE\u00f3lica SA\nRio de Janeiro BR 248,138,287.11 BRL Line-by-line Enel Brasil SA 100.00% 82.27%\nEnel Green Power\nMorro do Chap\u00e9u II\nE\u00f3lica SA\nRio de Janeiro BR 206,050,114.05 BRL Line-by-line Enel Brasil SA 100.00% 82.27%\nEnel Green Power\nMorro do Chap\u00e9u\nSolar 01 SA (formerly\nEnel Green Power\nS\u00e3o Gon\u00e7alo III\nPa\ue61ficipa\u00e7\u00f5es SA)\nRio de Janeiro BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power\nMour\u00e3o SA\nRio de Janeiro BR 25,600,100.00 BRL Line-by-line Enel Brasil SA 100.00% 82.27%\nEnel Green Power\nNamibia (Pty) Ltd\nWindhoek NA 10,000.00 NAD Line-by-line\nEnel Green Power\nSpA\n100.00% 100.00%\nEnel Green Power\nNo\ue61fh America\nDevelopment LLC\nWilmington US - USD Line-by-line\nEnel No\ue61fh\nAmerica Inc. \n100.00% 100.00%\nEnel Green Power\nNo\ue61fh America Inc.\nAndover US - USD Line-by-line\nEnel No\ue61fh\nAmerica Inc. \n100.00% 100.00%\nEnel Green Power Nova \nOlinda 01 SA\nTeresina BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power Nova \nOlinda 02 SA\nTeresina BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power Nova \nOlinda 03 SA\nTeresina BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power Nova \nOlinda 04 SA\nTeresina BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nEnel Green Power Nova \nOlinda 05 SA\nTeresina BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power Nova \nOlinda 06 SA\nTeresina BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power Nova \nOlinda 07 SA\nTeresina BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power Nova \nOlinda 08 SA\nTeresina BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power Nova \nOlinda 09 SA\nTeresina BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power Novo \nLapa 01 SA\nRio de Janeiro BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power Novo \nLapa 02 SA\nRio de Janeiro BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power Novo \nLapa 03 SA\nRio de Janeiro BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power Novo \nLapa 04 SA\nRio de Janeiro BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power Novo \nLapa 05 SA\nRio de Janeiro BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power Novo \nLapa 06 SA\nRio de Janeiro BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nEnel Green Power Novo \nLapa 07 SA\nRio de Janeiro BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power Novo \nLapa 08 SA\nRio de Janeiro BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power O&M\nSolar LLC\nAndover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEnel Green Power\nPanam\u00e1 Srl\nPanama City PA 3,001.00 USD Line-by-line\nEnel Am\u00e9ricas SA 0.03%\n82.27%\nESSA2 SpA 99.97%\nEnel Green Power\nParanapanema SA\nNiter\u00f3i BR 162,567,500.00 BRL Line-by-line Enel Brasil SA 100.00% 82.27%\nEnel Green Power\nPa\ue61fecipazioni Speciali\nSrl\nRome IT 10,000.00 EUR Line-by-line\nEnel Green Power\nSpA\n100.00% 100.00%\nEnel Green Power Pau\nFerro E\u00f3lica SA\nRio de Janeiro BR 125,124,000.00 BRL Line-by-line\nEnel Brasil SA 98.77%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n1.23%\nEnel Green Power\nPau Ferro E\u00f3lica\nSA\n0.00%\nEnel Green Power\nPedra do Ger\u00f4nimo\nE\u00f3lica SA\nRio de Janeiro BR 184,319,527.57 BRL Line-by-line\nEnel Brasil SA 98.86%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n1.14%\nEnel Green Power Per\u00fa\nSAC\nSan Miguel PE 973,213,507.00 PEN Line-by-line\nEnel Am\u00e9ricas SA 100.00%\n82.27%\nEnerg\u00eda y Servicios\nSouth America\nSpA\n0.00%\nEnel Green Power\nPrimavera E\u00f3lica SA\nRio de Janeiro BR 143,674,900.01 BRL Line-by-line\nEnel Brasil SA 99.00%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n1.00%\nEnel Green Power\nPuglia Srl\nRome IT 1,000,000.00 EUR Line-by-line\nEnel Green Power\nItalia Srl\n100.00% 100.00%\nEnel Green Power RA\nSAE in liquidation\nCairo EG 15,000,000.00 EGP Line-by-line\nEnel Green Power\nEgypt SAE\n100.00% 100.00%\nEnel Green Power\nRa\ue61clesnake Creek\nWind Project LLC\n(formerly Ra\ue61clesnake\nCreek Wind Project\nLLC)\nDelaware US 1.00 USD Line-by-line\nRa\ue61clesnake Creek\nHoldings LLC\n100.00% 100.00%\nEnel Green Power\nRoadrunner Solar\nProject Holdings II LLC\nAndover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nEnel Green Power\nRoadrunner Solar\nProject Holdings LLC\nAndover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEnel Green Power\nRoadrunner Solar\nProject II LLC\nDover US 100.00 USD Line-by-line\nEnel Roadrunner\nSolar Project \nHoldings II LLC\n100.00% 100.00%\nEnel Green Power\nRockhaven Ranchland \nHoldings LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEnel Green Power\nRomania Srl\nBucharest RO 2,430,631,000.00 RON Line-by-line\nEnel Green Power\nSpA\n100.00% 100.00%\nEnel Green Power\nRoseland Solar LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEnel Green Power RSA\n(Pty) Ltd\nJohannesburg ZA 1,000.00 ZAR Line-by-line\nEGP Matimba \nNewCo 1 Srl\n100.00% 100.00%\nEnel Green Power RSA\n2 (RF) (Pty) Ltd\nJohannesburg ZA 120.00 ZAR AFS\nEnel Green Power\nRSA (Pty) Ltd\n100.00% 100.00%\nEnel Green Power\nRus Limited Liability\nCompany\nMoscow RU 60,500,000.00 RUB Line-by-line\nEnel Green Power\nPa\ue61fecipazioni\nSpeciali Srl\n1.00%\n100.00%\nEnel Green Power\nSpA\n99.00%\nEnel Green Power SpA Rome IT 272,000,000.00 EUR Line-by-line Enel SpA 100.00% 100.00%\nEnel Green Power Salto\nApiac\u00e1s SA (formerly \nEnel Green Power\nDamascena E\u00f3lica SA)\nRio de Janeiro BR 274,420,832.00 BRL Line-by-line Enel Brasil SA 100.00% 82.27%\nEnel Green Power\nSannio Srl\nRome IT 750,000.00 EUR Line-by-line\nEnel Green Power\nItalia Srl\n100.00% 100.00%\nEnel Green Power S\u00e3o\nAbra\u00e3o E\u00f3lica SA\nRio de Janeiro BR 91,300,000.00 BRL Line-by-line Enel Brasil SA 100.00% 82.27%\nEnel Green Power\nS\u00e3o Gon\u00e7alo 01 SA \n(formerly Enel Green\nPower Projetos 10)\nTeresina BR 105,245,553.82 BRL Line-by-line\nAlba Energia Ltda 0.00%\n82.27%\nEnel Brasil SA 100.00%\nEnel Green Power\nS\u00e3o Gon\u00e7alo 02 SA\n(formerly Enel Green\nPower Projetos 11)\nTeresina BR 129,213,750.53 BRL Line-by-line\nAlba Energia Ltda 0.00%\n82.27%\nEnel Brasil SA 100.00%\nEnel Green Power\nS\u00e3o Gon\u00e7alo 07 SA\n(formerly Enel Green\nPower Projetos 42 SA)\nTeresina BR 142,249,180.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.00%\nEnel Green Power\nS\u00e3o Gon\u00e7alo 08 SA\n(formerly Enel Green\nPower Projetos 43 SA)\nTeresina BR 77,008,993.34 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.00%\nEnel Green Power\nS\u00e3o Gon\u00e7alo 10 SA\n(formerly Enel Green\nPower Projetos 15)\nTeresina BR 124,817,216.25 BRL Line-by-line\nAlba Energia Ltda 0.00%\n82.27%\nEnel Brasil SA 100.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nEnel Green Power\nS\u00e3o Gon\u00e7alo 11 SA\n(formerly Enel Green\nPower Projetos 44 SA)\nTeresina BR 82,202,330.00 BRL Line-by-line Enel Brasil SA 100.00% 82.27%\nEnel Green Power\nS\u00e3o Gon\u00e7alo 12 SA \n(formerly Enel Green\nPower Projetos 22 SA)\nTeresina BR 75,750,090.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.00%\nEnel Green Power S\u00e3o\nGon\u00e7alo 14\nTeresina BR 210,001,000.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.00%\nEnel Green Power S\u00e3o\nGon\u00e7alo 15\nTeresina BR 180,779,180.90 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.00%\nEnel Green Power S\u00e3o\nGon\u00e7alo 17 SA\nTeresina BR 175,728,754.90 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.00%\nEnel Green Power\nS\u00e3o Gon\u00e7alo 18 SA\n(formerly Enel Green\nPower Ventos de Santa\n\u00c2ngela 13 SA)\nTeresina BR 177,703,455.40 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.00%\nEnel Green Power S\u00e3o\nGon\u00e7alo 19 SA\nTeresina BR 174,189,501.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.00%\nEnel Green Power\nS\u00e3o Gon\u00e7alo 21 SA\n(formerly Enel Green\nPower Projetos 16)\nTeresina BR 139,939,932.22 BRL Line-by-line\nAlba Energia Ltda 0.00%\n82.27%\nEnel Brasil SA 100.00%\nEnel Green Power\nS\u00e3o Gon\u00e7alo 22 SA\n(formerly Enel Green\nPower Projetos 30)\nTeresina BR 138,733,692.21 BRL Line-by-line\nAlba Energia Ltda 0.00%\n82.27%\nEnel Brasil SA 100.00%\nEnel Green Power S\u00e3o\nGon\u00e7alo 3 SA (formerly\nEnel Green Power\nProjetos 12)\nTeresina BR 216,609,843.02 BRL Line-by-line\nAlba Energia Ltda 0.00%\n82.27%\nEnel Brasil SA 100.00%\nEnel Green Power S\u00e3o\nGon\u00e7alo 4 SA (formerly\nEnel Green Power\nProjetos 13)\nTeresina BR 124,870,989.57 BRL Line-by-line\nAlba Energia Ltda 0.00%\n82.27%\nEnel Brasil SA 100.00%\nEnel Green Power S\u00e3o\nGon\u00e7alo 5 SA (formerly\nEnel Green Power\nProjetos 14)\nTeresina BR 123,176,257.11 BRL Line-by-line\nAlba Energia Ltda 0.00%\n82.27%\nEnel Brasil SA 100.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nEnel Green Power S\u00e3o\nGon\u00e7alo 6 SA (formerly\nEnel Green Power\nProjetos 19 SA)\nTeresina BR 180,887,848.28 BRL Line-by-line\nAlba Energia Ltda 0.00%\n82.27%\nEnel Brasil SA 100.00%\nEnel Green\nPower Brasil\nPa\ue61ficipa\u00e7\u00f5es Ltda\n0.00%\nEnel Green Power S\u00e3o\nJudas E\u00f3lica SA\nNiter\u00f3i BR 143,674,900.00 BRL Line-by-line\nEnel Brasil SA 99.00%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n1.00%\nEnel Green Power S\u00e3o\nMicael 01 SA (formerly\nEnel Green Power S\u00e3o\nGon\u00e7alo 9 SA)\nTeresina BR 1,000.00 BRL Line-by-line\nAlba Energia Ltda 0.10%\n82.27%\nEnel Brasil SA 99.90%\nEnel Green Power S\u00e3o\nMicael 02 SA (formerly\nEnel Green Power S\u00e3o\nGon\u00e7alo 13)\nTeresina BR 1,000.00 BRL Line-by-line\nAlba Energia Ltda 0.10%\n82.27%\nEnel Brasil SA 99.90%\nEnel Green Power S\u00e3o\nMicael 03 SA (formerly\nEnel Green Power S\u00e3o\nGon\u00e7alo 16 SA)\nTeresina BR 1,000.00 BRL Line-by-line\nAlba Energia Ltda 0.10%\n82.27%\nEnel Brasil SA 99.90%\nEnel Green Power S\u00e3o\nMicael 04 SA (formerly \nEnel Green Power S\u00e3o\nGon\u00e7alo 20 SA)\nTeresina BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power S\u00e3o\nMicael 05 SA\nTeresina BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power\nServices LLC\nWilmington US 100.00 USD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nEnel Green Power Shu\nSAE in liquidation\nCairo EG 15,000,000.00 EGP Line-by-line\nEnel Green Power\nEgypt SAE\n100.00% 100.00%\nEnel Green Power\nSingapore Pte Ltd\nSingapore SG 6,100,000.00 SGD Line-by-line\nEnel Green Power\nSpA\n100.00% 100.00%\nEnel Green Power Solar\nEnergy Srl\nRome IT 10,000.00 EUR Line-by-line\nEnel Green Power\nItalia Srl\n100.00% 100.00%\nEnel Green Power Solar\nMetehara SpA\nRome IT 50,000.00 EUR Line-by-line\nEnel Green Power\nSpA\n100.00% 100.00%\nEnel Green Power Solar\nNgonye SpA (formerly\nEnel Green Power\nAfrica Srl)\nRome IT 50,000.00 EUR AFS\nEGP Matimba \nNewCo 2 Srl\n100.00% 100.00%\nEnel Green Power\nSouth Africa (Pty) Ltd\nJohannesburg ZA 1,000.00 ZAR Line-by-line\nEnel Green Power\nSpA\n100.00% 100.00%\nEnel Green Power\nSouth Africa 3 (Pty) Ltd\nGauteng ZA 1,000.00 ZAR Line-by-line\nEnel Green Power\nSpA\n100.00% 100.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nEnel Green Power Swift\nWind LP\nCalgary CA 1,000.00 CAD Line-by-line\nEnel Albe\ue61fa Wind\nInc.\n0.10%\n100.00%\nEnel Green Power\nCanada Inc. \n99.90%\nEnel Green Power\nTacaic\u00f3 E\u00f3lica SA\nRio de Janeiro BR 86,034,360.00 BRL Line-by-line\nEnel Brasil SA 98.76%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n1.24%\nEnel Green Power\nTefnut SAE in\nliquidation\nCairo EG 15,000,000.00 EGP Line-by-line\nEnel Green Power\nEgypt SAE\n100.00% 100.00%\nEnel Green Power\nTurkey Enerj\u00ed\nYatirimlari\nAnon\u00edm \u015e\u00edrket\u00ed\nIstanbul TR 65,654,658.00 TRY Line-by-line\nEnel Green Power\nSpA\n100.00% 100.00%\nEnel Green Power\nUB33 GmbH & Co. Kg\nBerlin DE 75,000.00 EUR Line-by-line\nEnel Green Power\nGermany GmbH\n100.00% 100.00%\nEnel Green Power\nVentos de Santa\n\u00c2ngela 1 SA\nTeresina BR 132,001,000.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nVentos de Santa\n\u00c2ngela Energias\nRenov\u00e1veis SA\n0.00%\nEnel Green Power\nVentos de Santa\n\u00c2ngela 10 SA (formerly\nEnel Green Power\nProjetos 21)\nTeresina BR 171,001,000.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nVentos de Santa\n\u00c2ngela Energias\nRenov\u00e1veis SA\n0.00%\nEnel Green Power\nVentos de Santa\n\u00c2ngela 11 SA (formerly \nEnel Green Power\nProjetos 23)\nTeresina BR 185,001,000.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nVentos de Santa\n\u00c2ngela Energias\nRenov\u00e1veis SA\n0.00%\nEnel Green Power\nVentos de Santa\n\u00c2ngela 14 SA (formerly\nEnel Green Power\nProjetos 24)\nTeresina BR 241,769,350.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nVentos de Santa\n\u00c2ngela Energias\nRenov\u00e1veis SA\n0.00%\nEnel Green Power\nVentos de Santa\n\u00c2ngela 15 SA (formerly\nEnel Green Power\nProjetos 25)\nTeresina BR 182,001,000.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nVentos de Santa\n\u00c2ngela Energias\nRenov\u00e1veis SA\n0.00%\nEnel Green Power\nVentos de Santa\n\u00c2ngela 17 SA (formerly\nEnel Green Power\nProjetos 26)\nTeresina BR 198,001,000.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nVentos de Santa\n\u00c2ngela Energias\nRenov\u00e1veis SA\n0.00%\nEnel Green Power\nVentos de Santa\n\u00c2ngela 19 SA (formerly\nEnel Green Power\nProjetos 27)\nTeresina BR 126,001,000.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nVentos de Santa\n\u00c2ngela Energias\nRenov\u00e1veis SA\n0.00%\nEnel Green Power\nVentos de Santa\n\u00c2ngela 2 SA\nTeresina BR 249,650,000.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nVentos de Santa\n\u00c2ngela Energias\nRenov\u00e1veis SA\n0.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nEnel Green Power\nVentos de Santa\n\u00c2ngela 20 SA (formerly \nEnel Green Power\nProjetos 28)\nTeresina BR 126,001,000.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nVentos de Santa\n\u00c2ngela Energias\nRenov\u00e1veis SA\n0.00%\nEnel Green Power\nVentos de Santa\n\u00c2ngela 21 SA (formerly\nEnel Green Power\nProjetos 29)\nTeresina BR 113,001,000.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nVentos de Santa\n\u00c2ngela Energias\nRenov\u00e1veis SA\n0.00%\nEnel Green Power\nVentos de Santa\n\u00c2ngela 3 SA (formerly \nEnel Green Power\nProjetos 4)\nTeresina BR 132,001,000.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nVentos de Santa\n\u00c2ngela Energias\nRenov\u00e1veis SA\n0.00%\nEnel Green Power\nVentos de Santa\n\u00c2ngela 4 SA (formerly \nEnel Green Power\nProjetos 6)\nTeresina BR 132,001,000.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nVentos de Santa\n\u00c2ngela Energias\nRenov\u00e1veis SA\n0.00%\nEnel Green Power\nVentos de Santa\n\u00c2ngela 5 SA (formerly \nEnel Green Power\nProjetos 7)\nTeresina BR 132,001,000.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nVentos de Santa\n\u00c2ngela Energias\nRenov\u00e1veis SA\n0.00%\nEnel Green Power\nVentos de Santa\n\u00c2ngela 6 SA (formerly \nEnel Green Power\nProjetos 8)\nTeresina BR 132,001,000.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nVentos de Santa\n\u00c2ngela Energias\nRenov\u00e1veis SA\n0.00%\nEnel Green Power\nVentos de Santa\n\u00c2ngela 7 SA (formerly \nEnel Green Power\nProjetos 9)\nTeresina BR 106,001,000.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nVentos de Santa\nEsperan\u00e7a \nEnergias\nRenov\u00e1veis SA\n0.00%\nEnel Green Power\nVentos de Santa\n\u00c2ngela 8 SA (formerly \nEnel Green Power\nProjetos 18)\nTeresina BR 132,001,000.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nVentos de Santa\n\u00c2ngela Energias\nRenov\u00e1veis SA\n0.00%\nEnel Green Power\nVentos de Santa\n\u00c2ngela 9 SA (formerly \nEnel Green Power\nProjetos 20)\nTeresina BR 185,001,000.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nVentos de Santa\n\u00c2ngela Energias\nRenov\u00e1veis SA\n0.00%\nEnel Green Power\nVentos de Santa\n\u00c2ngela ACL 12\n(formerly Enel Green\nPower Projetos 36)\nTeresina BR 125,853,581.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.00%\nEnel Green Power\nVentos de Santa\n\u00c2ngela ACL 13 SA \n(formerly Enel Green\nPower Projetos 17 SA)\nTeresina BR 115,001,000.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nEnel Green Power\nVentos de Santa\n\u00c2ngela ACL 16 SA\n(formerly Enel Green\nPower Projetos 38 SA)\nTeresina BR 128,700,091.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.00%\nEnel Green Power\nVentos de Santa\n\u00c2ngela ACL 18 SA\n(formerly Enel Green\nPower Projetos 47 SA)\nTeresina BR 128,279,231.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.00%\nEnel Green Power\nVentos de Santa\nEsperan\u00e7a 08 SA \n(formerly Enel Green\nPower Projetos 34 SA)\nRio de Janeiro BR 110,200,000.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.00%\nEnel Green Power\nVentos de Santa\nEsperan\u00e7a 1 SA \n(formerly Enel Green\nPower Fonte dos\nVentos 1 SA)\nRio de Janeiro BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power\nVentos de Santa\nEsperan\u00e7a 13 (formerly\nEnel Green Power\nProjetos 33 SA)\nRio de Janeiro BR 147,000,000.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.00%\nEnel Green Power\nVentos de Santa\nEsperan\u00e7a 15 SA\nRio de Janeiro BR 202,100,000.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.00%\nEnel Green Power\nVentos de Santa\nEsperan\u00e7a 16 SA\n(formerly Enel Green\nPower Projetos 35 SA)\nRio de Janeiro BR 183,700,000.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.00%\nEnel Green Power\nVentos de Santa\nEsperan\u00e7a 17 SA\n(formerly Enel Green\nPower Projetos 31 SA)\nRio de Janeiro BR 183,700,000.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.00%\nEnel Green Power\nVentos de Santa\nEsperan\u00e7a 21 SA \n(formerly Enel Green\nPower Projetos 37 SA)\nRio de Janeiro BR 202,100,000.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.00%\nEnel Green Power\nVentos de Santa\nEsperan\u00e7a 22 SA \n(formerly Enel Green\nPower Projetos 39 SA)\nRio de Janeiro BR 202,100,000.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.00%\nEnel Green Power\nVentos de Santa\nEsperan\u00e7a 25 SA \n(formerly Enel Green\nPower Projetos 40 SA)\nRio de Janeiro BR 110,200,000.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nEnel Green Power\nVentos de Santa\nEsperan\u00e7a 26 SA\n(formerly Enel Green\nPower Projetos 41 SA)\nRio de Janeiro BR 202,100,000.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.00%\nEnel Green Power\nVentos de Santa\nEsperan\u00e7a 26 SA\n(formerly Enel\nGreen Power\nProjetos 41 SA)\n0.00%\nEnel Green Power\nVentos de Santa\nEsperan\u00e7a 3 SA\nRio de Janeiro BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power\nVentos de Santa\nEsperan\u00e7a 7 SA \n(formerly Enel Green\nPower Lagedo Alto SA)\nRio de Janeiro BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green\nPower Ventos de\nSanta Esperan\u00e7a\nPa\ue61ficipa\u00e7\u00f5es SA \n(formerly Enel Green\nPower Cumaru 06 SA)\nRio de Janeiro BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power\nVentos de Santo\nOrestes 1 SA\nRio de Janeiro BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power\nVentos de Santo\nOrestes 2 SA\nRio de Janeiro BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power\nVentos de S\u00e3o Roque\n01 SA\nTeresina BR 313,963,791.98 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.00%\nEnel Green Power\nVentos de S\u00e3o Roque\n02 SA\nTeresina BR 300,285,891.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.00%\nEnel Green Power\nVentos de S\u00e3o Roque\n03 SA\nTeresina BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power\nVentos de S\u00e3o Roque\n04 SA\nTeresina BR 270,507,771.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nEnel Green Power\nVentos de S\u00e3o Roque\n05 SA\nTeresina BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power\nVentos de S\u00e3o Roque\n06 SA\nTeresina BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power\nVentos de S\u00e3o Roque\n07 SA\nTeresina BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power\nVentos de S\u00e3o Roque\n08 SA\nTeresina BR 138,001,000.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.00%\nEnel Green Power\nVentos de S\u00e3o Roque\n11 SA\nTeresina BR 301,267,691.98 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.00%\nEnel Green Power\nVentos de S\u00e3o Roque\n13 SA\nTeresina BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power\nVentos de S\u00e3o Roque\n16 SA\nTeresina BR 283,811,791.98 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.00%\nEnel Green Power\nVentos de S\u00e3o Roque\n17 SA\nTeresina BR 138,001,000.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.00%\nEnel Green Power\nVentos de S\u00e3o Roque\n18 SA\nTeresina BR 138,001,000.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.00%\nEnel Green Power\nVentos de S\u00e3o Roque\n19 SA\nTeresina BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power\nVentos de S\u00e3o Roque\n22 SA\nTeresina BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nEnel Green Power\nVentos de S\u00e3o Roque\n26 SA\nTeresina BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power\nVentos de S\u00e3o Roque\n29 SA\nTeresina BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Green Power\nVerwaltungs GmbH\nBerlin DE 25,000.00 EUR Line-by-line\nEnel Green Power\nGermany GmbH\n100.00% 100.00%\nEnel Green Power\nVietnam LLC (C\u00f4ng \nty TNHH Enel Green\nPower Vi\u00eat Nam)\nHo Chi Minh\nCity\nVN 231,933.00 USD Line-by-line\nEnel Green Power\nSpA\n100.00% 100.00%\nEnel Green Power\nVilloresi Srl\nRome IT 1,200,000.00 EUR Line-by-line\nEnel Green Power\nItalia Srl\n51.00% 51.00%\nEnel Green Power Volta\nGrande SA (formerly\nEnel Green Power\nProjetos 1 SA)\nNiter\u00f3i BR 565,756,528.00 BRL Line-by-line Enel Brasil SA 100.00% 82.27%\nEnel Green Power\nZambia Limited\nLusaka ZM 15,000.00 ZMW Line-by-line\nEnel Green Power\nDevelopment Srl\n1.00%\n100.00%\nEnel Green Power\nRSA (Pty) Ltd\n99.00%\nEnel Green Power Zeus \nII - Del\ue61ena 8 SA\nRio de Janeiro BR 129,639,980.00 BRL Line-by-line Enel Brasil SA 100.00% 82.27%\nEnel Green Power Zeus \nSul 1 Ltda\nRio de Janeiro BR 6,986,993.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.00%\nEnel Green Power Zeus \nSul 2 SA\nRio de Janeiro BR 1,000.00 BRL Line-by-line\nEnel Brasil SA 99.90%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.10%\nEnel Holding Finance\nSrl\nRome IT 10,000.00 EUR Line-by-line Enel SpA 100.00% 100.00%\nEnel Iberia Srl Madrid ES 336,142,500.00 EUR Line-by-line Enel SpA 100.00% 100.00%\nEnel Innovation Hubs\nSrl\nRome IT 1,100,000.00 EUR Line-by-line Enel SpA 100.00% 100.00%\nEnel Insurance NV Amsterdam NL 60,000.00 EUR Line-by-line Enel SpA 100.00% 100.00%\nEnel Investment\nHolding BV\nAmsterdam NL 1,000,000.00 EUR Line-by-line Enel SpA 100.00% 100.00%\nEnel Italia SpA Rome IT 100,000,000.00 EUR Line-by-line Enel SpA 100.00% 100.00%\nEnel Kansas\nDevelopment Holdings\nLLC\nAndover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEnel Kansas LLC Wilmington US - USD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nEnel Land HoldCo LLC Andover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEnel Logistics Srl Rome IT 1,000,000.00 EUR Line-by-line Enel Italia SpA 100.00% 100.00%\nEnel Minnesota\nHoldings LLC\nMinneapolis US - USD Line-by-line\nEGP Geronimo\nHolding Company\nInc.\n100.00% 100.00%\nEnel Nevkan Inc. Wilmington US - USD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nEnel No\ue61fh America Inc. Andover US 50.00 USD Line-by-line Enel SpA 100.00% 100.00%\nEnel Operations\nCanada Ltd\nAlbe\ue61fa CA 1,000.00 CAD Line-by-line\nEnel Green Power\nCanada Inc. \n100.00% 100.00%\nEnel Per\u00fa SAC San Miguel PE 5,361,789,105.00 PEN Line-by-line Enel Am\u00e9ricas SA 100.00% 82.27%\nEnel Produzione SpA Rome IT 1,800,000,000.00 EUR Line-by-line Enel Italia SpA 100.00% 100.00%\nEnel Rinnovabile SA \nde Cv\nMexico City MX 100.00 MXN Line-by-line\nEnel Green Power\nGlobal Investment\nBV \n99.00%\n100.00%\nHidroelectricidad\ndel Pac\u00ed\ue61eco S de\nRL de Cv\n1.00%\nEnel Roadrunner Solar\nProject Holdings II LLC\nAndover US - USD Line-by-line\nEnel Green Power\nRoadrunner Solar\nProject Holdings\nII LLC\n100.00% 100.00%\nEnel Roadrunner Solar\nProject Holdings LLC\nDover US 100.00 USD Line-by-line\nEnel Green Power\nRoadrunner Solar\nProject Holdings\nLLC \n100.00% 100.00%\nEnel Romania SA Buftea RO 200,000.00 RON Line-by-line Enel SpA 100.00% 100.00%\nEnel Rus Finance LLC Konakovo RU 10,000.00 RUB Line-by-line Enel Russia PJSC 100.00% 56.43%\nEnel Rus Wind Azov\nLLC\nMoscow RU 200,000,000.00 RUB Line-by-line Enel Russia PJSC 100.00% 56.43%\nEnel Rus Wind Kola LLC Murmansk City RU 10,000.00 RUB Line-by-line Enel Russia PJSC 100.00% 56.43%\nEnel Rus Wind\nStavropolye LLC\nRegion of\nStavropol\nRU 350,000.00 RUB Line-by-line Enel Russia PJSC 100.00% 56.43%\nEnel Russia PJSC Yekaterinburg RU 35,371,898,370.00 RUB Line-by-line Enel SpA 56.43% 56.43%\nEnel Salt Wells LLC Fallon US - USD Line-by-line\nEnel Geothermal\nLLC \n100.00% 100.00%\nEnel Saudi Arabia\nLimited\nAl Khobar SA 1,000,000.00 SAR Line-by-line\ne-distribuzione\nSpA\n60.00% 60.00%\nEnel Servicii Comune\nSA\nBucharest RO 33,000,000.00 RON Line-by-line\nE-Distribu\u0163ie Banat \nSA\n50.00%\n51.00%\nE-Distribu\u0163ie\nDobrogea SA \n50.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nEnel Solar Srl Panama City PA 10,100.00 USD Line-by-line\nEnel Green Power\nPanam\u00e1 Srl \n99.01%\n82.27%\nESSA2 SpA 0.99%\nEnel Sole Srl Rome IT 4,600,000.00 EUR Line-by-line Enel Italia SpA 100.00% 100.00%\nEnel Solu\u00e7\u00f5es\nEnerg\u00e9ticas Ltda\nRio de Janeiro BR 42,863,000.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.00%\nEnel Solu\u00e7\u00f5es\nEnerg\u00e9ticas Ltda\n0.00%\nEnel Stillwater LLC Wilmington US - USD Line-by-line\nEnel Geothermal\nLLC \n100.00% 100.00%\nEnel Surprise Valley LLC Wilmington US - USD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nEnel Texkan Inc. Wilmington US 100.00 USD Line-by-line Chi Power Inc. 100.00% 100.00%\nEnel Trade Energy Srl Bucharest RO 2,437,050.00 RON Line-by-line Enel Romania SA 100.00% 100.00%\nEnel Trade Serbia doo Belgrade RS 300,000.00 EUR Line-by-line\nEnel Global\nTrading SpA\n100.00% 100.00%\nEnel Trading Argentina\nSrl\nBuenos Aires AR 14,011,100.00 ARS Line-by-line\nEnel Am\u00e9ricas SA 55.00%\n82.26%\nEnel Argentina SA 45.00%\nEnel Trading Brasil SA Rio de Janeiro BR 5,280,312.00 BRL Line-by-line Enel Brasil SA 100.00% 82.27%\nEnel Trading No\ue61fh\nAmerica LLC\nWilmington US 10,000,000.00 USD Line-by-line\nEnel No\ue61fh\nAmerica Inc. \n100.00% 100.00%\nEnel Transmisi\u00f3n Chile\nSA\nSantiago de\nChile\nCL 52,569,315,875.00 CLP Line-by-line Enel Chile SA 99.09% 64.34%\nEnel Uruguay SA Montevideo UY 20,000.00 UYU Line-by-line Enel Brasil SA 100.00% 82.27%\nEnel Vayu (Project 2) \nPrivate Limited\nGurugram IN 45,000,000.00 INR Line-by-line\nEnel Green Power\nIndia Private\nLimited\n100.00% 100.00%\nEnel Wind Project\n(Amberi) Private Limited\nNew Delhi IN 5,000,000.00 INR Line-by-line\nEnel Green Power\nIndia Private\nLimited\n100.00% 100.00%\nEnel X AMPCI Ebus\nChile SpA\nSantiago de\nChile\nCL 18,000,000.00 USD Equity Enel X Chile SpA 20.00% 12.99%\nEnel X AMPCI L1\nHoldings SpA\nSantiago de\nChile\nCL 18,000,000.00 USD Equity\nEnel X AMPCI Ebus\nChile SpA\n100.00% 12.99%\nEnel X AMPCI L1 SpA\nSantiago de\nChile\nCL 18,000,000.00 USD Equity\nEnel X AMPCI L1\nHoldings SpA\n100.00% 12.99%\nEnel X Arecibo LLC Boston US - USD Line-by-line\nEnel X Pr Holdings\nLLC \n100.00% 100.00%\nEnel X Argentina SAU Buenos Aires AR 127,800,000.00 ARS Line-by-line\nEnel X\nInternational Srl\n100.00% 100.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nEnel X Asputeck Ave.\nProject LLC\nBoston US - USD Line-by-line\nEnel X Finance\nPa\ue61fner LLC\n100.00% 100.00%\nEnel X Australia Holding\n(Pty) Ltd\nMelbourne AU 21,224,578.00 AUD Line-by-line\nEnel X\nInternational Srl\n100.00% 100.00%\nEnel X Australia (Pty)\nLtd\nMelbourne AU 9,880.00 AUD Line-by-line\nEnergy Response\nHoldings (Pty) Ltd \n100.00% 100.00%\nEnel X Ba\ue61cery Storage\nLimited Pa\ue61fnership\nOakville CA 10,000.00 CAD Line-by-line\nEnel X Canada\nHolding Inc.\n0.01%\n100.00%\nEnel X Canada Ltd 99.99%\nEnel X Brasil\nGerenciamento de\nEnergia Ltda\nSorocaba BR 5,538,403.00 BRL Line-by-line\nEnel X Ireland\nLimited\n0.00%\n100.00%\nEnerNOC UK II\nLimited\n100.00%\nEnel X Brasil SA Niter\u00f3i BR 324,725,892.00 BRL Line-by-line Enel Brasil SA 100.00% 82.27%\nEnel X Canada Holding\nInc.\nOakville CA 1,000.00 CAD Line-by-line Enel X Canada Ltd 100.00% 100.00%\nEnel X Canada Ltd Mississauga CA 1,000.00 CAD Line-by-line\nEnel No\ue61fh\nAmerica Inc. \n100.00% 100.00%\nEnel X Chile SpA\nSantiago de\nChile\nCL 3,800,000,000.00 CLP Line-by-line Enel Chile SA 100.00% 64.93%\nEnel X College Ave.\nProject LLC\nBoston US - USD Line-by-line\nEnel X MA\nHoldings LLC\n100.00% 100.00%\nEnel X Colombia SAS Bogot\u00e1 CO 5,186,737,000.00 COP Line-by-line Codensa SA ESP 100.00% 39.74%\nEnel X Energy\n(Shanghai) Co. Ltd\nShanghai CN 3,500,000.00 USD Line-by-line\nEnel X\nInternational Srl\n100.00% 100.00%\nEnel X Federal LLC Boston US 5,000.00 USD Line-by-line\nEnel X No\ue61fh\nAmerica Inc. \n100.00% 100.00%\nEnel X Finance Pa\ue61fner \nLLC\nBoston US 100.00 USD Line-by-line\nEnel X No\ue61fh\nAmerica Inc. \n100.00% 100.00%\nEnel X Financial\nServices Srl\nRome IT 1,000,000.00 EUR AFS Enel X Srl 100.00% 100.00%\nEnel X France SAS Paris FR 2,901,000.00 EUR Line-by-line\nEnel X\nInternational Srl\n100.00% 100.00%\nEnel X Germany GmbH Berlin DE 25,000.00 EUR Line-by-line\nEnel X\nInternational Srl\n100.00% 100.00%\nEnel X Hayden Rowe St.\nProject LLC\nBoston US 100.00 USD Line-by-line\nEnel X MA\nHoldings LLC\n100.00% 100.00%\nEnel X International Srl Rome IT 100,000.00 EUR Line-by-line Enel X Srl 100.00% 100.00%\nEnel X Ireland Limited Dublin IE 10,841.00 EUR Line-by-line\nEnel X\nInternational Srl\n100.00% 100.00%\nEnel X Italia Srl Rome IT 200,000.00 EUR Line-by-line Enel Italia SpA 100.00% 100.00%\nEnel X Japan KK Tokyo JP 655,000,000.00 JPY Line-by-line\nEnel X\nInternational Srl\n100.00% 100.00%\nEnel X KOMIPO Solar\nLimited\nSeoul KR 8,472,600,000.00 KRW Line-by-line\nEnel X Korea\nLimited\n80.00% 80.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nEnel X Korea Limited Seoul KR 11,800,000,000.00 KRW Line-by-line\nEnel X\nInternational Srl\n100.00% 100.00%\nEnel X Las Piedras LLC Boston US - USD Line-by-line\nEnel X Pr Holdings\nLLC \n100.00% 100.00%\nEnel X MA Holdings LLC Boston US 100.00 USD Line-by-line\nEnel X Finance\nPa\ue61fner LLC\n100.00% 100.00%\nEnel X MA PV Po\ue61ffolio\n1 LLC\nBoston US - USD Line-by-line\nEnel X MA\nHoldings LLC\n100.00% 100.00%\nEnel X MA PV Po\ue61ffolio\n2 LLC\nBoston US - USD Line-by-line\nEnel X No\ue61fh\nAmerica Inc. \n100.00% 100.00%\nEnel X MA PV Po\ue61ffolio\n3 LLC\nBoston US - USD Line-by-line\nEnel X Finance\nPa\ue61fner LLC\n100.00% 100.00%\nEnel X Mobility HPC Srl Rome IT 1,000,000.00 EUR Equity Enel X Srl 50.00% 50.00%\nEnel X Mobility\nRomania Srl\nBucharest RO 6,937,800.00 RON Line-by-line\nEnel X\nInternational Srl\n99.86%\n100.00%\nEnel X Srl 0.14%\nEnel X Mobility Srl Rome IT 100,000.00 EUR Line-by-line Enel Italia SpA 100.00% 100.00%\nEnel X Morrissey Blvd. \nProject LLC\nBoston US 100.00 USD Line-by-line\nEnel X MA\nHoldings LLC\n100.00% 100.00%\nEnel X New Zealand\nLimited\nWellington NZ 313,606.00 AUD Line-by-line\nEnergy Response\nHoldings (Pty) Ltd \n100.00% 100.00%\nEnel X No\ue61fh America\nInc.\nBoston US 1,000.00 USD Line-by-line\nEnel No\ue61fh\nAmerica Inc. \n100.00% 100.00%\nEnel X Norway AS Porsgrunn NO 1,000,000.00 NOK Line-by-line\nEnel X\nInternational Srl\n100.00% 100.00%\nEnel X Per\u00fa SAC San Miguel PE 12,005,000.00 PEN Line-by-line Enel Per\u00fa SAC 100.00% 82.27%\nEnel X Polska Sp. zo.o. Warsaw PL 12,275,150.00 PLN Line-by-line\nEnel X Ireland\nLimited\n100.00% 100.00%\nEnel X Pr Holdings LLC Boston US - USD Line-by-line\nEnel X Finance\nPa\ue61fner LLC\n100.00% 100.00%\nEnel X Project MP\nHoldings LLC\nBoston US - USD Line-by-line\nEnel X Project MP\nSponsor LLC\n100.00% 100.00%\nEnel X Project MP\nSponsor LLC\nBoston US - USD Line-by-line\nEnel X No\ue61fh\nAmerica Inc. \n100.00% 100.00%\nEnel X Romania Srl Bucharest RO 7,044,450.00 RON Line-by-line\nEnel X\nInternational Srl\n99.97%\n100.00%\nEnel X Srl 0.03%\nEnel X Rus LLC Moscow RU 8,000,000.00 RUB Line-by-line\nEnel X\nInternational Srl\n99.00% 99.00%\nEnel X Srl Rome IT 1,050,000.00 EUR Line-by-line Enel SpA 100.00% 100.00%\nEnel X Services India\nPrivate Limited\nMumbai City IN 45,000.00 INR Line-by-line\nEnel X\nInternational Srl\n100.00%\n100.00%\nEnel X No\ue61fh\nAmerica Inc. \n0.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nEnel X Singapore Pte \nLtd\nSingapore SG 1,212,000.00 SGD Line-by-line\nEnel X\nInternational Srl\n100.00% 100.00%\nEnel X Sweden AB Stockholm SE 50,000.00 SEK Line-by-line\nEnel X\nInternational Srl\n100.00% 100.00%\nEnel X Taiwan Co. Ltd Taipei City TW 70,000,000.00 TWD Line-by-line\nEnel X Ireland\nLimited\n100.00% 100.00%\nEnel X UK Limited London GB 32,626.00 GBP Line-by-line\nEnel X\nInternational Srl\n100.00% 100.00%\nEnel X Wood St. Project \nLLC\nBoston US - USD Line-by-line\nEnel X Finance\nPa\ue61fner LLC\n100.00% 100.00%\nEnelco SA Maroussi GR 60,108.80 EUR Line-by-line\nEnel Investment\nHolding BV\n75.00% 75.00%\nEnelpower Contractor\nand Development\nSaudi Arabia Ltd\nRiyadh SA 5,000,000.00 SAR Line-by-line Enelpower SpA 51.00% 51.00%\nEnelpower do Brasil \nLtda\nRio de Janeiro BR 5,689,000.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nEnerg\u00eda y Servicios\nSouth America\nSpA\n0.00%\nEnelpower SpA Milan IT 2,000,000.00 EUR Line-by-line Enel SpA 100.00% 100.00%\nEnerg\u00e9tica Monz\u00f3n\nSAC\nSan Miguel PE 6,463,000.00 PEN Line-by-line\nEnel Green Power\nPer\u00fa SAC\n100.00%\n82.27%\nEnerg\u00eda y Servicios\nSouth America\nSpA\n0.00%\nEnerg\u00eda Base Natural\nSLU\nValencia ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nEnerg\u00eda Ceuta XXI \nComercializadora de\nReferencia SA\nCeuta ES 65,000.00 EUR Line-by-line\nEmpresa de\nAlumbrado\nEl\u00e9ctrico de Ceuta\nSA\n100.00% 67.59%\nEnerg\u00eda E\u00f3lica \u00c1brego\nSLU\nValencia ES 3,576.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nEnerg\u00eda E\u00f3lica Galerna\nSLU\nMadrid ES 3,413.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nEnerg\u00eda E\u00f3lica Gregal\nSLU\nMadrid ES 3,250.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nEnergia Eolica Srl - \nEN.EO. Srl\nRome IT 4,840,000.00 EUR Line-by-line\nEnel Green Power\nItalia Srl\n100.00% 100.00%\nEnerg\u00eda Global de\nM\u00e9xico (Enermex) SA\nde Cv\nMexico City MX 50,000.00 MXN Line-by-line\nEnel Green Power\nSpA\n99.00% 99.00%\nEnerg\u00eda Global\nOperaciones Srl\nSan Jos\u00e9 CR 10,000.00 CRC Line-by-line\nEnel Green Power\nCosta Rica SA \n100.00% 82.27%\nEnerg\u00eda Limpia de\nAmistad SA de Cv\nMexico City MX 33,452,769.00 MXN Equity\nTenedora de\nEnerg\u00eda Renovable \nSol y Viento SAPI\nde Cv \n60.80% 20.00%\nEnerg\u00eda Limpia de Palo\nAlto SA de Cv\nMexico City MX 673,583,489.00 MXN Equity\nTenedora de\nEnerg\u00eda Renovable \nSol y Viento SAPI\nde Cv \n60.80% 20.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nEnerg\u00eda Limpia de\nPue\ue61fo Libe\ue61fad S de \nRL de Cv\nMexico City MX 2,953,980.00 MXN Line-by-line\nEnel Green Power\nM\u00e9xico S de RL\nde Cv\n0.01%\n100.00%\nEnel Rinnovabile \nSA de Cv\n99.99%\nEnerg\u00eda Marina SpA\nSantiago de\nChile\nCL 2,404,240,000.00 CLP Equity\nEnel Green Power\nChile SA\n25.00% 16.23%\nEnerg\u00eda Neta Sa Caseta\nLlucmajor SL (Sociedad\nUnipersonal)\nPalma de\nMallorca\nES 9,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nEnerg\u00eda Nueva de Iguu\nS de RL de Cv\nMexico City MX 51,879,307.00 MXN Line-by-line\nEnel Green Power\nM\u00e9xico S de RL\nde Cv\n99.90%\n99.91%\nEnerg\u00eda Nueva\nEnerg\u00eda Limpia\nM\u00e9xico S de RL\nde Cv\n0.01%\nEnerg\u00eda Nueva Energ\u00eda\nLimpia M\u00e9xico S de RL\nde Cv\nMexico City MX 5,339,650.00 MXN Line-by-line\nEnel Green Power\nGuatemala SA\n0.04%\n99.99%\nEnel Green Power\nSpA\n99.96%\nEnerg\u00eda XXI\nComercializadora de\nReferencia SL\nMadrid ES 2,000,000.00 EUR Line-by-line Endesa Energ\u00eda SA 100.00% 70.11%\nEnerg\u00eda y Naturaleza\nSLU\nValencia ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nEnerg\u00eda y Servicios\nSouth America SpA\nSantiago de\nChile\nCL 12,120,575.70 USD Line-by-line Enel Am\u00e9ricas SA 100.00% 82.27%\nEnerg\u00edas Alternativas\ndel Sur SL\nLas Palmas de\nGran Canaria\nES 546,919.10 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n54.95% 38.52%\nEnerg\u00edas de Arag\u00f3n I SL Zaragoza ES 3,200,000.00 EUR Line-by-line\nEndesa Red \nSA (Sociedad\nUnipersonal)\n100.00% 70.11%\nEnerg\u00edas de Graus SL Barcelona ES 1,298,160.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n66.67% 46.74%\nEnerg\u00edas Especiales de \nCare\u00f3n SA\nSantiago de\nCompostela\nES 270,450.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n77.00% 53.99%\nEnerg\u00edas Especiales de \nPe\u00f1a Armada SA\nMadrid ES 963,300.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n80.00% 56.09%\nEnerg\u00edas Especiales del \nAlto Ulla SA\nMadrid ES 19,594,860.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nEnerg\u00edas Especiales del \nBierzo SA\nTorre del Bierzo ES 1,635,000.00 EUR Equity\nEnel Green Power\nEspa\u00f1a SLU\n50.00% 35.06%\nEnerg\u00edas Renovables La\nMata SA de Cv\nMexico City MX 656,615,400.00 MXN Line-by-line\nEnel Green Power\nM\u00e9xico S de RL\nde Cv\n99.00%\n100.00%\nEnerg\u00eda Nueva de\nIguu S de RL de Cv\n1.00%\nEnergie Electrique de\nTahadda\ue61f SA\nTanger MA 510,270,000.00 MAD Equity\nEndesa\nGeneraci\u00f3n SA\n32.00% 22.44%\nEnergo Sonne Srl Bucharest RO 31,520.00 RON Line-by-line\nEnel Green Power\nRomania Srl\n100.00% 100.00%\nEnergotel AS Bratislava SK 2,191,200.00 EUR Equity\nSlovensk\u00e9\nelektr\u00e1rne AS\n20.00% 6.60%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nEnergy Hydro Piave Srl\nin liquidation\nBelluno IT 800,000.00 EUR Line-by-line\nEnel Produzione \nSpA\n100.00% 100.00%\nEnergy Response\nHoldings (Pty) Ltd\nMelbourne AU 630,451.00 AUD Line-by-line\nEnel X Australia\nHolding (Pty) Ltd \n100.00% 100.00%\nEnerlive Srl Rome IT 6,520,000.00 EUR Line-by-line Maicor Wind Srl 100.00% 100.00%\nEnerNOC GmbH Munich DE 25,000.00 EUR Line-by-line\nEnel X No\ue61fh\nAmerica Inc. \n100.00% 100.00%\nEnerNOC Ireland\nLimited\nDublin IE 10,535.00 EUR Line-by-line\nEnel X Ireland\nLimited\n100.00% 100.00%\nEnerNOC UK II Limited London GB 21,000.00 GBP Line-by-line Enel X UK Limited 100.00% 100.00%\nEntech (China) \nInformation Technology\nCo. Ltd\nShenzhen CN 140,000.00 USD Equity\nEnerNOC UK II\nLimited\n50.00% 50.00%\nEntech Utility Service\nBureau Inc.\nLutherville US 1,500.00 USD Line-by-line\nEnel X No\ue61fh\nAmerica Inc. \n100.00% 100.00%\nEnvatios Promoci\u00f3n\nI SLU\nMadrid ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nEnvatios Promoci\u00f3n\nII SLU\nMadrid ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nEnvatios Promoci\u00f3n\nIII SLU\nMadrid ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nEnvatios Promoci\u00f3n\nXX SLU\nMadrid ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nE\u00f3lica Valle del Ebro SA Zaragoza ES 3,561,342.50 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n50.50% 35.40%\nE\u00f3lica Zopiloapan SA\nde Cv\nMexico City MX 1,877,201.54 MXN Line-by-line\nEnel Green Power\nM\u00e9xico S de RL\nde Cv\n56.98%\n96.48%\nEnel Green Power\nPa\ue61fecipazioni\nSpeciali Srl\n39.50%\nE\u00f3licas de Agaete SL\nLas Palmas de\nGran Canaria\nES 240,400.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n80.00% 56.09%\nE\u00f3licas de Fuencaliente \nSA\nLas Palmas de\nGran Canaria\nES 216,360.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n55.00% 38.56%\nE\u00f3licas de\nFue\ue61feventura AIE\nPue\ue61fo del\nRosario\nES - EUR Equity\nEnel Green Power\nEspa\u00f1a SLU\n40.00% 28.04%\nE\u00f3licas de la Patagonia\nSA\nBuenos Aires AR 480,930.00 ARS Equity\nEnel Green Power\nEspa\u00f1a SLU\n50.00% 35.06%\nE\u00f3licas de Lanzarote SL\nLas Palmas de\nGran Canaria\nES 1,758,000.00 EUR Equity\nEnel Green Power\nEspa\u00f1a SLU\n40.00% 28.04%\nE\u00f3licas de Tenerife AIE\nSanta Cruz de \nTenerife\nES 420,708.40 EUR Equity\nEnel Green Power\nEspa\u00f1a SLU\n50.00% 35.06%\nE\u00f3licas de Tirajana SL\nLas Palmas de\nGran Canaria\nES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n60.00% 42.07%\nEpresa Energ\u00eda SA Cadiz ES 2,500,000.00 EUR Equity\nEndesa Red \nSA (Sociedad\nUnipersonal)\n50.00% 35.06%\nE-Solar Srl Rome IT 2,500.00 EUR Line-by-line\nEnel Green Power\nItalia Srl\n100.00% 100.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nESSA2 SpA\nSantiago de\nChile\nCL 701,166,335.30 USD Line-by-line Enel Am\u00e9ricas SA 100.00% 82.27%\nEssaouira Wind Farm Casablanca MA 300,000.00 MAD Equity\nNareva Enel Green\nPower Morocco\nSA\n70.00% 35.00%\nEuropean Energy\nExchange AG\nLeipzig DE 40,050,000.00 EUR -\nEnel Global\nTrading SpA\n2.38% 2.38%\nExpedition Solar\nProject LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nExplorer Wind Project\nLLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nExplotaciones E\u00f3licas \nde Escucha SA\nZaragoza ES 3,505,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n70.00% 49.08%\nExplotaciones E\u00f3licas \nEl Pue\ue61fo SA\nZaragoza ES 3,230,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n73.60% 51.60%\nExplotaciones E\u00f3licas \nSanto Domingo de \nLuna SA\nZaragoza ES 100,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n51.00% 35.76%\nExplotaciones E\u00f3licas \nSaso Plano SA\nZaragoza ES 5,488,500.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n65.00% 45.57%\nExplotaciones E\u00f3licas \nSierra Costera SA\nZaragoza ES 8,046,800.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n90.00% 63.10%\nExplotaciones E\u00f3licas \nSierra La Virgen SA\nZaragoza ES 4,200,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n90.00% 63.10%\nFaye\ue61ce Solar I LLC Andover US 1.00 USD Line-by-line\nBrick Road Solar\nHoldings LLC\n100.00% 100.00%\nFazenda Aroeira\nEmpreendimento de\nEnergia Ltda\nRio de Janeiro BR 2,362,045.90 BRL Line-by-line Enel Brasil SA 100.00% 82.27%\nFence Post Solar \nProject LLC\nAndover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nFenner Wind Holdings\nLLC\nDover US 100.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nFinsec Lab Ltd Tel Aviv IL 100.00 ILS Equity Enel X Srl 30.00% 30.00%\nFlagpay Srl Milan IT 10,000.00 EUR AFS PayTipper SpA 100.00% 55.00%\nFlat Rock Wind Project\nLLC\nAndover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nFlat Top Solar Project\nLLC\nAndover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nFlint Rock Solar Project \nLLC\nAndover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nFlorence Hills LLC Minneapolis US - USD Line-by-line\nChi Minnesota\nWind LLC\n51.00% 51.00%\nFlowing Spring Farms\nLLC\nAndover US 1.00 USD Line-by-line\nBrick Road Solar\nHoldings LLC\n100.00% 100.00%\nFontibon ZE SAS Bogot\u00e1 CO 392,420,000.00 COP Line-by-line Bogot\u00e1 ZE SAS 100.00% 39.74%\nF\u00f3tons de Santo\nAnchieta Energias\nRenov\u00e1veis SA\nRio de Janeiro BR 577,000.00 BRL Line-by-line Enel Brasil SA 100.00% 82.27%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nFotovoltaica Yunclillos\nSLU\nMadrid ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nFourmile Wind Project \nLLC\nAndover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nFranklintown Farm LLC Andover US 1.00 USD Line-by-line\nBrick Road Solar\nHoldings LLC\n100.00% 100.00%\nFreedom Energy\nStorage LLC\nAndover US - USD Line-by-line\nEnel Energy\nStorage Holdings\nLLC (formerly EGP\nEnergy Storage\nHoldings LLC)\n100.00% 100.00%\nFront Mar\u00edtim del\nBes\u00f2s SL\nBarcelona ES 9,000.00 EUR Equity\nEndesa\nGeneraci\u00f3n SA\n61.37% 43.03%\nFrontiersman Solar\nProject LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nFRV Corchitos I SLU Madrid ES 75,800.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nFRV Corchitos II SOLAR\nSLU\nMadrid ES 22,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nFRV Gibalb\u00edn - Jerez \nSLU\nMadrid ES 23,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nFRV Tarifa SLU Madrid ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nFRV Villalobillos SLU Madrid ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nFRV Zamora Solar 1 \nSLU\nMadrid ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nFRV Zamora Solar 3 \nSLU\nMadrid ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nFundamental\nRecognized Systems\nSLU\nRivas-\nVaciamadrid\nES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nFuratena Solar 1 SLU Seville ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nGalaxy Wind Project \nLLC\nAndover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nGanado Solar LLC Andover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nGanado Storage LLC Andover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nGarob Wind Farm (RF)\n(Pty) Ltd\nJohannesburg ZA 100.00 ZAR AFS\nEnel Green Power\nRSA 2 (RF) (Pty) Ltd\n55.00% 55.00%\nGas y Electricidad\nGeneraci\u00f3n SAU\nPalma de\nMallorca\nES 213,775,700.00 EUR Line-by-line\nEndesa\nGeneraci\u00f3n SA\n100.00% 70.11%\nGauley Hydro LLC Wilmington US - USD Equity\nGRPP Holdings\nLLC \n100.00% 50.00%\nGauley River \nManagement LLC\nWillison US 1.00 USD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nGeneradora de\nOccidente Ltda\nGuatemala City GT 16,261,697.33 GTQ Line-by-line\nEnel Green Power\nGuatemala SA\n1.00%\n82.27%\nESSA2 SpA 99.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nGeneradora E\u00f3lica Alto\nPacora Srl\nPanama City PA 10,100.00 USD Line-by-line\nEnel Green Power\nPanam\u00e1 Srl \n99.01%\n82.27%\nESSA2 SpA 0.99%\nGeneradora\nMontecristo SA\nGuatemala City GT 3,820,000.00 GTQ Line-by-line\nEnel Green Power\nGuatemala SA\n0.00%\n82.27%\nESSA2 SpA 100.00%\nGeneradora Solar\nAustral SA\nChiriqu\u00ed PA 10,000.00 USD Line-by-line\nEnel Green Power\nPanam\u00e1 Srl \n100.00% 82.27%\nGeneradora Solar de\nOccidente SA\nPanama City PA 10,000.00 USD Line-by-line\nEnel Green Power\nPanam\u00e1 Srl \n100.00% 82.27%\nGeneradora Solar El\nPue\ue61fo SA\nChiriqu\u00ed PA 10,000.00 USD Line-by-line\nEnel Green Power\nPanam\u00e1 Srl \n100.00% 82.27%\nGeneradora Solar\nTol\u00e9 Srl\nPanama City PA 10,100.00 USD Line-by-line\nEnel Green Power\nPanam\u00e1 Srl \n99.01%\n82.27%\nESSA2 SpA 0.99%\nGeot\u00e9rmica del No\ue61fe\nSA\nSantiago de\nChile\nCL 326,577,419,702.00 CLP Line-by-line\nEnel Green Power\nChile SA\n84.59% 54.92%\nGibson Bay Wind Farm\n(RF) (Pty) Ltd\nJohannesburg ZA 1,000.00 ZAR Line-by-line\nEnel Green Power\nRSA (Pty) Ltd\n60.00% 60.00%\nGirgarre Solar Farm\n(Pty) Ltd\nSydney AU - AUD Line-by-line\nEnel Green Power\nGirgarre Holdings\n(Pty) Ltd \n100.00% 100.00%\nGirgarre Solar Farm\nTrust\nSydney AU 10.00 AUD Line-by-line\nEnel Green Power\nGirgarre Trust\n100.00% 100.00%\nGlobal Commodities\nHoldings Limited\nLondon GB 4,042,375.00 GBP -\nEnel Global\nTrading SpA\n4.68% 4.68%\nGlobyte SA San Jos\u00e9 CR 900,000.00 CRC -\nEnel Green Power\nCosta Rica SA \n10.00% 8.23%\nGloucester Solar I LLC Andover US 1.00 USD Line-by-line\nBrick Road Solar\nHoldings LLC\n100.00% 100.00%\nGnl Chile SA\nSantiago de\nChile\nCL 3,026,160.00 USD Equity\nEnel Generaci\u00f3n\nChile SA\n33.33% 20.25%\nGoodwell Wind Project\nLLC\nWilmington US - USD Equity\nOrigin Goodwell\nHoldings LLC\n100.00% 20.00%\nGorona del Viento El\nHierro SA\nSanta Cruz de \nTenerife\nES 30,936,736.00 EUR Equity\nUni\u00f3n El\u00e9ctrica\nde Canarias\nGeneraci\u00f3n SAU\n23.21% 16.27%\nGrand Prairie Solar\nProject LLC\nAndover US - USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nGridspe\ue61fise Latam SA S\u00e3o Paulo BR 2,010,000.00 BRL Line-by-line\nEnel Brasil SA 0.00%\n100.00%\nGridspe\ue61fise Srl 100.00%\nGridspe\ue61fise Srl Rome IT 7,500,000.00 EUR Line-by-line\nEnel Global\nInfrastructure and\nNetworks Srl\n100.00% 100.00%\nGRPP Holdings LLC Andover US 2.00 USD Equity\nEGPNA REP\nHoldings LLC\n50.00% 50.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nGuadarranque Solar\n4 SLU\nSeville ES 3,006.00 EUR Line-by-line\nEndesa\nGeneraci\u00f3n II SA\n100.00% 70.11%\nGuayepo Solar SAS Bogot\u00e1 CO 1,000,000.00 COP Line-by-line\nEnel Green Power\nColombia SAS ESP\n100.00% 82.27%\nGusty Hill Wind Project \nLLC\nAndover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nGV Energie Rigenerabili\nITAL-RO Srl\nBucharest RO 1,145,400.00 RON Line-by-line\nEnel Green Power\nRomania Srl\n100.00%\n100.00%\nEnel Green Power\nSpA\n0.00%\nHadley Ridge LLC Minneapolis US - USD Line-by-line\nChi Minnesota\nWind LLC\n51.00% 51.00%\nHamilton County Solar \nProject LLC\nAndover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nHansborough Valley \nSolar Project LLC\nAndover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nHarmony Plains Solar\nI LLC\nAndover US 1.00 USD Line-by-line\nBrick Road Solar\nHoldings LLC\n100.00% 100.00%\nHarvest Ridge Solar \nProject LLC\nAndover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nHarvest Ridge Wind\nProject LLC\nAndover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nHastings Solar LLC Wilmington US - USD Line-by-line\nAurora Distributed\nSolar LLC \n100.00% 74. 13%\nHatch Data Inc. San Francisco US 10,000.00 USD -\nEnel X No\ue61fh\nAmerica Inc. \n5.00% 5.00%\nHea\ue61fland Farms Wind\nProject LLC\nWilmington US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nHidroel\u00e9ctrica de \nCatalunya SL\nBarcelona ES 126,210.00 EUR Line-by-line\nEndesa Red \nSA (Sociedad\nUnipersonal)\n100.00% 70.11%\nHidroel\u00e9ctrica de \nOurol SL\nLugo ES 1,608,200.00 EUR Equity\nEnel Green Power\nEspa\u00f1a SLU\n30.00% 21.03%\nHidroelectricidad del\nPac\u00ed\ue61eco S de RL de Cv\nColima MX 30,890,736.00 MXN Line-by-line\nEnel Green Power\nM\u00e9xico S de RL\nde Cv\n99.99% 99.99%\nHidro\ue618amicell SL Barcelona ES 78,120.00 EUR Line-by-line\nHidroel\u00e9ctrica de \nCatalunya SL\n75.00% 52.58%\nHidroinvest SA Buenos Aires AR 55,312,093.00 ARS Line-by-line\nEnel Am\u00e9ricas SA 41.94%\n79.55%\nEnel Argentina SA 54.76%\nHIF H2 SpA\nSantiago de\nChile\nCL 6,303,000.00 USD Equity\nEnel Green Power\nChile SA\n50.00% 32.46%\nHigh Chaparral Solar \nProject LLC\nAndover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nHigh Lonesome\nStorage LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nHigh Lonesome Wind\nHoldings LLC\nWilmington US 100.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nHigh Lonesome Wind\nPower LLC\nBoston US 100.00 USD Line-by-line\nHigh Lonesome\nWind Holdings\nLLC \n100.00% 100.00%\nHigh Noon Solar\nProject LLC\nAndover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nHigh Street\nCorporation (Pty) Ltd\nMelbourne AU 2.00 AUD Line-by-line\nEnergy Response\nHoldings (Pty) Ltd \n100.00% 100.00%\nHilltopper Wind\nHoldings LLC\nWilmington US 1,000.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nHispano Generaci\u00f3n de \nEnerg\u00eda Solar SL\nJerez de los\nCaballeros\nES 3,500.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n51.00% 35.76%\nHoney Stone Solar\nProject LLC\nAndover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nHoneybee Solar Project\nLLC\nAndover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nHope Creek LLC Crestview US - USD Line-by-line\nChi Minnesota\nWind LLC\n51.00% 51.00%\nHope Ridge Wind\nProject LLC\nAndover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nHorse Run Solar I LLC Andover US 1.00 USD Line-by-line\nBrick Road Solar\nHoldings LLC\n100.00% 100.00%\nHorse Wrangler Solar\nProject LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nHubject eRoaming\nTechnology (Shanghai)\nCo. Ltd\nShanghai CN 12,668,015.70 CNY - Hubject GmbH 100.00% 12.50%\nHubject GmbH Berlin DE 65,943.00 EUR -\nEnel X\nInternational Srl\n12.50% 12.50%\nHubject Inc. Santa Monica US 100,000.00 USD - Hubject GmbH 100.00% 12.50%\nHydro Energies\nCorporation\nWillison US 5,000.00 USD AFS\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nIdalia Park Solar Project\nLLC\nAndover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nIdrosicilia SpA Milan IT 22,520,000.00 EUR Equity Enel SpA 1.00% 1.00%\nIfx Networks Argentina\nSrl\nBuenos Aires AR 2,260,551.00 ARS Equity\nIfx/eni - Spc V Inc. 99.85%\n20.60%\nMinority Stock\nHolding Corp.\n0.15%\nIfx Networks Chile SA\nSantiago de\nChile\nCL 6,235,913,725.00 CLP Equity\nIfx/eni - Spc IV Inc. 41.20%\n20.60%\nServicios de\nInternet Eni Chile \nLtda\n58.80%\nIfx Networks Colombia\nSAS\nBogot\u00e1 CO 15,734,959,000.00 COP Equity\nIfx Networks\nPanama SA\n58.33%\n20.60%\nIfx/eni - Spc III Inc. 41.67%\nIfx Networks LLC Wilmington US 80,848,653.00 USD Equity U\ue61enet Latam SLU 100.00% 20.60%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nIfx Networks Ltd To\ue61fola VG 50,001.00 USD Equity Ifx Networks LLC 100.00% 20.60%\nIfx Networks Panama\nSA\nPanama City PA 21,000.00 USD Equity\nIfx/eni - Spc\nPanama Inc.\n100.00% 20.60%\nIfx/eni - Spc III Inc. To\ue61fola VG 100.00 USD Equity Ifx Networks Ltd 100.00% 20.60%\nIfx/eni - Spc IV Inc. To\ue61fola VG 100.00 USD Equity Ifx Networks Ltd 100.00% 20.60%\nIfx/eni - Spc Panama\nInc.\nTo\ue61fola VG 100.00 USD Equity Ifx Networks Ltd 100.00% 20.60%\nIfx/eni - Spc V Inc. To\ue61fola VG 100.00 USD Equity Ifx Networks Ltd 100.00% 20.60%\nInfraestructuras Pue\ue61fo \nSanta Mar\u00eda 220 SL\nMadrid ES 3,000.00 EUR Line-by-line\nPue\ue61fo Santa Mar\u00eda\nEnerg\u00eda I SLU\n50.00%\n70.11%\nPue\ue61fo Santa Mar\u00eda\nEnerg\u00eda II SLU\n50.00%\nInfraestructuras San\nServ\u00e1n 220 SL\nMadrid ES 12,000.00 EUR Equity\nCastiblanco Solar\nSL\n10.20%\n21.59%Navalvillar Solar SL 10.30%\nValdecaballero\nSolar SL\n10.30%\nInkolan Informaci\u00f3n\ny Coordinaci\u00f3n de\nobras AIE\nBilbao ES 84,141.68 EUR -\nEdistribuci\u00f3n\nRedes Digitales\nSL (Sociedad\nUnipersonal)\n14.29% 10.02%\nInternational\nMultimedia University\nSrl in bankruptcy\n- IT 24,000.00 EUR - Enel Italia SpA 13.04% 13.04%\nInversora Codensa SAS Bogot\u00e1 CO 6,500,000.00 COP Line-by-line Codensa SA ESP 100.00% 39.74%\nInversora Dock Sud SA Buenos Aires AR 828,941,660.00 ARS Line-by-line Enel Am\u00e9ricas SA 57. 14% 47.01%\nIsamu Ikeda Energia SA Niter\u00f3i BR 45,474,475.77 BRL Line-by-line Enel Brasil SA 100.00% 82.27%\nItalgest Energy (Pty) Ltd Johannesburg ZA 1,000.00 ZAR Line-by-line\nEnel Green Power\nRSA (Pty) Ltd\n100.00% 100.00%\nJack River LLC Minneapolis US - USD Line-by-line\nChi Minnesota\nWind LLC\n51.00% 51.00%\nJade Energia Ltda Rio de Janeiro BR 4,107,097.00 BRL Line-by-line Enel Brasil SA 100.00% 82.27%\nJaguito Solar 10 MW SA Panama City PA 10,000.00 USD Line-by-line\nEnel Green Power\nPanam\u00e1 Srl \n100.00% 82.27%\nJessica Mills LLC Minneapolis US - USD Line-by-line\nChi Minnesota\nWind LLC\n51.00% 51.00%\nJuiceNet GmbH Berlin DE 25,000.00 EUR Line-by-line\nEnel X\nInternational Srl\n100.00% 100.00%\nJuiceNet Ltd London GB 1.00 GBP Line-by-line\nEnel X\nInternational Srl\n100.00% 100.00%\nJulia Hills LLC Minneapolis US - USD Line-by-line\nChi Minnesota\nWind LLC\n51.00% 51.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nJuna Renewable Energy \nPrivate Limited\nGurugram IN 36,600,000.00 INR Line-by-line\nEnel Green Power\nIndia Private\nLimited\n100.00% 100.00%\nJunia Insurance Srl\nMosciano\nSant\u2019Angelo\n(Teramo)\nIT 100.00 EUR Line-by-line Enel X Srl 100.00% 100.00%\nKeeneys Creek Solar\nI LLC\nAndover US 1.00 USD Line-by-line\nBrick Road Solar\nHoldings LLC\n100.00% 100.00%\nKelley\u2019s Falls LLC Wilmington US - USD AFS\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nKen Renewables India\nPrivate Limited\nGurugram IN 100,000.00 INR Line-by-line\nEnel Green Power\nIndia Private\nLimited\n100.00% 100.00%\nKhaba Renewable\nEnergy Private Limited\nGurugram IN 10,100,000.00 INR Line-by-line\nEnel Green Power\nIndia Private\nLimited\n100.00% 100.00%\nKhidrat Renewable\nEnergy Private Limited\nGurugram IN 38,100,000.00 INR Line-by-line\nEnel Green Power\nIndia Private\nLimited\n100.00% 100.00%\nKing Branch Solar I LLC Andover US 1.00 USD Line-by-line\nBrick Road Solar\nHoldings LLC\n100.00% 100.00%\nKings River Hydro\nCompany Inc.\nWilmington US 100.00 USD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nKingston Energy \nStorage LLC\nWilmington US - USD Line-by-line\nEnel Energy\nStorage Holdings\nLLC (formerly EGP\nEnergy Storage\nHoldings LLC)\n100.00% 100.00%\nKino Contractor SA\nde Cv\nMexico City MX 100.00 MXN Line-by-line\nEnel Green Power\nM\u00e9xico S de RL\nde Cv\n99.00%\n100.00%\nHidroelectricidad\ndel Pac\u00ed\ue61eco S de\nRL de Cv\n1.00%\nKino Facilities Manager\nSA de Cv\nMexico City MX 100.00 MXN Line-by-line\nEnel Green Power\nM\u00e9xico S de RL\nde Cv\n99.00%\n100.00%\nHidroelectricidad\ndel Pac\u00ed\ue61eco S de\nRL de Cv\n1.00%\nKongul Enerj\u00ed\nSanay\u00ed Ve T\u00edcaret\nAnon\u00edm \u015e\u00edrket\u00ed\nIstanbul TR 125,000,000.00 TRY Line-by-line\nEnel Green Power\nTurkey Enerj\u00ed\nYatirimlari Anon\u00edm\n\u015e\u00edrket\u00ed\n100.00% 100.00%\nKoporie WPS LLC\nRegion of\nLeningrad\nRU 21,000,000.00 RUB Line-by-line\nEnel Green Power\nRus Limited\nLiability Company\n100.00% 100.00%\nKorea Line Corporation Seoul KR 122,132,520,000.00 KRW -\nEnel Global\nTrading SpA\n0.25% 0.25%\nKromschroeder SA Barcelona ES 627,126.00 EUR Equity\nEndesa Medios\ny Sistemas\nSL (Sociedad\nUnipersonal)\n29.26% 20.51%\nLake Emily Solar LLC Wilmington US - USD Line-by-line\nAurora Distributed\nSolar LLC \n100.00% 74. 13%\nLake Pulaski Solar LLC Wilmington US - USD Line-by-line\nAurora Distributed\nSolar LLC \n100.00% 74. 13%\nLand Run Wind Project\nLLC\nDover US 100.00 USD Line-by-line\nSundance Wind\nProject LLC\n100.00% 100.00%\nLantern Trail Solar\nProject LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nLatamsolar Fotovoltaica\nFundaci\u00f3n SAS\nBogot\u00e1 CO 8,000,000.00 COP Line-by-line\nEnel Green Power\nColombia SAS ESP\n100.00% 82.27%\nLathrop Solar I LLC Andover US 1.00 USD Line-by-line\nBrick Road Solar\nHoldings LLC\n100.00% 100.00%\nLava Solar Project LLC Andover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nLawrence Creek Solar\nLLC\nMinneapolis US - USD Line-by-line\nAurora Distributed\nSolar LLC \n100.00% 74. 13%\nLebanon Solar I LLC Andover US 1.00 USD Line-by-line\nBrick Road Solar\nHoldings LLC\n100.00% 100.00%\nLemonade Solar\nProject LLC\nAndover US - USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nLibe\ue61fy Energy Storage\nLLC\nAndover US - USD Line-by-line\nEnel Energy\nStorage Holdings\nLLC (formerly EGP\nEnergy Storage\nHoldings LLC)\n100.00% 100.00%\nLibyan Italian Joint\nCompany - Azienda\nLibico-Italiana (A.L.I)\nTripoli LY 1,350,000.00 EUR - Enelpower SpA 0.33% 0.33%\nLily Solar Holdings LLC Andover US 1.00 USD Line-by-line\nEnel Green Power\nLily Solar Holdings\nLLC \n100.00% 100.00%\nLily Solar LLC Andover US - USD Line-by-line\nEnel Kansas\nDevelopment\nHoldings LLC\n100.00% 100.00%\nLindahl Wind Holdings\nLLC\nWilmington US - USD Line-by-line\nEGPNA Preferred\nWind Holdings\nLLC \n100.00% 100.00%\nLindahl Wind Project\nLLC\nWilmington US - USD Line-by-line\nLindahl Wind\nHoldings LLC\n100.00% 100.00%\nLi\ue61cle Elk Wind Holdings\nLLC\nWilmington US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nLi\ue61cle Elk Wind Project\nLLC\nWilmington US - USD Line-by-line\nLi\ue61cle Elk Wind\nHoldings LLC\n100.00% 100.00%\nLi\ue61cle Salt Solar Project \nLLC\nAndover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nLi\ue61cleville Power\nCompany Inc.\nBoston US 100.00 USD AFS\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nLitus Energy Storage\nLLC\nAndover US - USD Line-by-line\nEnel Energy\nStorage Holdings\nLLC (formerly EGP\nEnergy Storage\nHoldings LLC)\n100.00% 100.00%\nLivister Guatemala SA Guatemala City GT 742,000.00 GTQ Equity\nLivister Latam SLU 99.99%\n20.60%\nU\ue61enet Guatema\nSA\n0.01%\nLivister Latam SLU Madrid ES 2,442,066.00 EUR Equity U\ue61enet Latam SLU 100.00% 20.60%\nLlano S\u00e1nchez Solar \nPower One Srl\nPanama City PA 10,020.00 USD Line-by-line\nEnel Green Power\nPanam\u00e1 Srl \n99.80%\n82.27%\nESSA2 SpA 0.20%\nLone Pine Wind Inc. Albe\ue61fa CA - CAD -\nEnel Green Power\nCanada Inc. \n10.00% 10.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nLone Pine Wind Project\nLP\nAlbe\ue61fa CA - CAD Equity\nEnel Green Power\nCanada Inc. \n10.00% 10.00%\nLower Valley LLC Wilmington US - USD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nLucas Sostenible SL Madrid ES 1,099,775.00 EUR Equity\nEnel Green Power\nEspa\u00f1a SLU\n35.29% 24.74%\nLuminary Highlands\nSolar Project LLC\nAndover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nLuz de Angra Energia\nSA\nRio de Janeiro BR 4,062,085.00 BRL Line-by-line Enel X Brasil SA 51.00% 41.96%\nLuz de Macap\u00e1 Energia \nSA\nRio de Janeiro BR 1,000.00 BRL Equity Enel X Brasil SA 51.00% 41.96%\nMaicor Wind Srl Rome IT 20,850,000.00 EUR Line-by-line\nEnel Green Power\nItalia Srl\n100.00% 100.00%\nMalaspina Energy Scarl\nin liquidation\nBergamo IT 100,000.00 EUR Line-by-line Enel X Italia Srl 100.00% 100.00%\nMaple Canada\nSolutions Holdings Ltd\n- CA - CAD Equity Enel X Canada Ltd 20.00% 20.00%\nMaple Energy Solutions\nLP\n- CA - CAD Equity\nEnel X Canada\nHolding Inc.\n20.00% 20.00%\nMarengo Solar LLC Wilmington US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nMa\ue61fe Srl Rome IT 6,100,000.00 EUR Line-by-line\nEnel Green Power\nItalia Srl\n100.00% 100.00%\nMarudhar Wind Energy \nPrivate Limited\nGurugram IN 100,000.00 INR Line-by-line\nEnel Green Power\nIndia Private\nLimited\n100.00% 100.00%\nM\u00e1s Energ\u00eda S de\nRL de Cv\nMexico City MX 61,872,926.00 MXN Line-by-line\nEnel Green Power\nM\u00e9xico S de RL\nde Cv\n99.99%\n100.00%\nHidroelectricidad\ndel Pac\u00ed\ue61eco S de\nRL de Cv\n0.01%\nMason Mountain Wind \nProject LLC\nWilmington US - USD Line-by-line\nPadoma Wind\nPower LLC\n100.00% 100.00%\nMatrigenix (Pty) Ltd Johannesburg ZA 1,000.00 ZAR Line-by-line\nEnel Green Power\nRSA (Pty) Ltd\n100.00% 100.00%\nMaty Energia Srl Rome IT 10,000.00 EUR Line-by-line\nEnel Green Power\nItalia Srl\n100.00% 100.00%\nMC Solar I LLC Andover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nMcBride Wind Project\nLLC\nWilmington US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nMedidas Ambientales \nSL\nBurgos ES 60,100.00 EUR Equity Tecnatom SA 50.00% 15.78%\nMerit Wind Project LLC Andover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nMetro Wind LLC Minneapolis US - USD Line-by-line\nChi Minnesota\nWind LLC\n51.00% 51.00%\nMexicana de \nHidroelectricidad\nMexhidro S de RL de Cv\nMexico City MX 181,728,901.00 MXN Line-by-line\nEnel Green Power\nM\u00e9xico S de RL\nde Cv\n99.99% 99.99%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nMibgas SA Madrid ES 3,000,000.00 EUR - Endesa SA 1.35% 0.95%\nMidelt Wind Farm SA Casablanca MA 145,000,000.00 MAD Equity\nNareva Enel Green\nPower Morocco\nSA\n70.00% 35.00%\nMinglanilla Renovables \n400 kV AIE\nValencia ES - EUR Propo\ue61fional\nEnerg\u00eda Base\nNatural SLU\n4.79%\n25.35%\nEnerg\u00eda E\u00f3lica \n\u00c1brego SLU\n7.98%\nEnerg\u00eda E\u00f3lica \nGalerna SLU \n9.31%\nEnerg\u00eda E\u00f3lica \nGregal SLU\n9.31%\nEnerg\u00eda y\nNaturaleza SLU\n4.79%\nMinicentrales Acequia \nCinco Villas AIE\nEjea de los\nCaballeros\nES 3,346,993.04 EUR -\nEnel Green Power\nEspa\u00f1a SLU\n5.39% 3.78%\nMinicentrales del Canal\nde las B\u00e1rdenas AIE\nZaragoza ES 1,202,000.00 EUR -\nEnel Green Power\nEspa\u00f1a SLU\n15.00% 10.52%\nMinicentrales del Canal\nImperial-Gallur SL\nZaragoza ES 1,820,000.00 EUR Equity\nEnel Green Power\nEspa\u00f1a SLU\n36.50% 25.59%\nMinority Stock Holding\nCorp.\nTo\ue61fola VG 100.00 USD Equity Ifx Networks Ltd 100.00% 20.60%\nMira Energy (Pty) Ltd Johannesburg ZA 100.00 ZAR Line-by-line\nEnel Green Power\nRSA (Pty) Ltd\n100.00% 100.00%\nMiranda Plataforma\nLog\u00edstica SA\nBurgos ES 1,800,000.00 EUR - Nuclenor SA 0.22% 0.08%\nMoebius Tecnologia\nem Inform\u00e1tica SA\nRio de Janeiro BR 150,000.00 BRL Equity\nU\ue61enet Brasil\nTelecomunica\u00e7\u00e3o \nLtda\n70.00% 35.00%\nMonte Reina\nRenovables SL\nMadrid ES 4,000.00 EUR Equity\nFRV Zamora Solar \n1 SLU\n20.58% 14.43%\nMontrose Solar LLC Wilmington US - USD Line-by-line\nAurora Distributed\nSolar LLC \n100.00% 74. 13%\nMoonbeam Solar\nProject LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nMorgan Branch Solar\nI LLC\nAndover US 1.00 USD Line-by-line\nBrick Road Solar\nHoldings LLC\n100.00% 100.00%\nMountrail Wind Project\nLLC\nAndover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nMPG Solar I LLC Andover US 1.00 USD Line-by-line\nBrick Road Solar\nHoldings LLC\n100.00% 100.00%\nMucho Viento Wind\nProject LLC\nAndover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nMuskegon County \nSolar Project LLC\nAndover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nMuskegon Green Wind \nProject LLC\nAndover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nMustang Run Wind \nProject LLC\nAndover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nNabb Solar I LLC Andover US 1.00 USD Line-by-line\nBrick Road Solar\nHoldings LLC\n100.00% 100.00%\nNapolean Wind Project \nLLC\nAndover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nNareva Enel Green\nPower Morocco SA\nCasablanca MA 98,750,000.00 MAD Equity\nEnel Green Power\nMorocco SARLAU\n50.00% 50.00%\nNavalvillar Solar SL Madrid ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nNegocios y Telefon\u00eda\nNedetel SA\nGuayaquil EC 4,773,525.00 USD - Livister Latam SLU 70.00% 14.42%\nNet Botanic Internet\nInteligente SA\nRio de Janeiro BR 450,000.00 BRL Equity\nU\ue61enet Brasil\nTelecomunica\u00e7\u00e3o \nLtda\n70.00% 35.00%\nNevkan Renewables \nLLC\nWilmington US - USD Line-by-line Enel Nevkan Inc. 100.00% 100.00%\nNew York Distributed\nStorage Projects LLC\nBoston US - USD Line-by-line\nEnel X No\ue61fh\nAmerica Inc. \n100.00% 100.00%\nNewbury Hydro\nCompany LLC\nAndover US - USD AFS\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nNgonye Power\nCompany Limited\nLusaka ZM 10.00 ZMW AFS\nEnel Green Power\nSolar Ngonye \nSpA (formerly\nEnel Green Power\nAfrica Srl)\n80.00% 80.00%\nNojoli Wind Farm (RF)\n(Pty) Ltd\nJohannesburg ZA 10,000,000.00 ZAR Line-by-line\nEnel Green Power\nRSA (Pty) Ltd\n60.00% 60.00%\nNo\ue61fh English Wind\nProject LLC\nAndover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nNo\ue61fh Rock Wind LLC Andover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nNo\ue61fhland Wind Project \nLLC\nAndover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nNo\ue61fhstar Wind Project\nLLC\nAndover US - USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nNo\ue61fhumberland Solar\nProject I LLC\nAndover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nNo\ue61fhwest Hydro LLC Wilmington US - USD Line-by-line Chi West LLC 100.00% 100.00%\nNotch Bu\ue61ce Hydro\nCompany Inc.\nWilmington US 100.00 USD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nNuclenor SA Burgos ES 102,000,000.00 EUR Equity\nEndesa\nGeneraci\u00f3n SA\n50.00% 35.06%\nNuove Energie Srl\nPo\ue61fo \nEmpedocle\nIT 5,204,028.73 EUR Line-by-line\nEnel Global\nTrading SpA\n100.00% 100.00%\nNxuba Wind Farm (RF)\n(Pty) Ltd\nJohannesburg ZA 1,000.00 ZAR AFS\nEnel Green Power\nRSA 2 (RF) (Pty) Ltd\n51.00% 51.00%\nNyc Storage (353\nChester) Spe LLC\nWilmington US 1.00 USD Line-by-line\nEnel X No\ue61fh\nAmerica Inc. \n100.00% 100.00%\nOchrana A Bezpecnost\nSe SRO\nKaln\u00e1 Nad\nHronom\nSK 33,193.92 EUR Equity\nSlovensk\u00e9\nelektr\u00e1rne AS\n100.00% 33.00%\nOlathe Solar I LLC Andover US 1.00 USD Line-by-line\nBrick Road Solar\nHoldings LLC\n100.00% 100.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nOlivum PV Farm 01 SLU Madrid ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nOMIP - Operador\ndo Mercado Ib\u00e9rico\n(Po\ue61fugal) SGPS SA\nLisbon PT 2,610,000.00 EUR - Endesa SA 5.00% 3.51%\nOpen Range Wind\nProject LLC\nAndover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nOperador del Mercado\nIb\u00e9rico de Energ\u00eda -\nPolo Espa\u00f1ol SA\nMadrid ES 1,999,998.00 EUR - Endesa SA 5.00% 3.51%\nOravita Power Park Srl Bucharest RO 2,000.00 RON Line-by-line\nEnel Green Power\nRomania Srl\n100.00% 100.00%\nOrchid Acres Solar\nProject LLC\nAndover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nOrigin Goodwell\nHoldings LLC\nWilmington US - USD Equity\nEGPNA Wind\nHoldings 1 LLC\n100.00% 20.00%\nOrigin Wind Energy\nLLC\nWilmington US - USD Equity\nOrigin Goodwell\nHoldings LLC\n100.00% 20.00%\nOsage Wind Holdings\nLLC\nWilmington US 100.00 USD Line-by-line Enel Kansas LLC 50.00% 50.00%\nOsage Wind LLC Wilmington US - USD Line-by-line\nOsage Wind\nHoldings LLC\n100.00% 50.00%\nO\ue61cauquechee Hydro\nCompany Inc.\nWilmington US 100.00 USD AFS\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nOvacik Eol\u00edko\nEnerj\u00ed Elektr\u00edk\n\u00dcret\u00edm Ve T\u00edcaret\nAnon\u00edm \u015e\u00edrket\u00ed\nIstanbul TR 11,250,000.00 TRY Line-by-line\nEnel Green Power\nTurkey Enerj\u00ed\nYatirimlari Anon\u00edm\n\u015e\u00edrket\u00ed\n100.00% 100.00%\nOxagesa AIE Alca\u00f1iz ES 6,010.00 EUR Equity\nEnel Green Power\nEspa\u00f1a SLU\n33.33% 23.37%\nOyster Bay Wind Farm \n(RF) (Pty) Ltd\nJohannesburg ZA 1,000.00 ZAR AFS\nEnel Green Power\nRSA 2 (RF) (Pty) Ltd\n55.00% 55.00%\nPadoma Wind Power\nLLC\nElida US - USD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nPalo Alto Farms Wind \nProject LLC\nDallas US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nPampinus PV Farm\n01 SLU\nMadrid ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nParadise Creek Wind\nProject LLC\nAndover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nParavento SL Lugo ES 3,006.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n90.00% 63.10%\nParc E\u00f2lic La\nTossa - La Mola\nd\u2019en Pascual SL\nMadrid ES 1,183,100.00 EUR Equity\nEnel Green Power\nEspa\u00f1a SLU\n30.00% 21.03%\nParc E\u00f2lic Los Aligars\nSL\nMadrid ES 1,313,100.00 EUR Equity\nEnel Green Power\nEspa\u00f1a SLU\n30.00% 21.03%\nParco Eolico Monti\nSicani Srl\nRome IT 10,000.00 EUR Line-by-line\nEnel Green Power\nItalia Srl\n100.00% 100.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nParque Amistad II SA\nde Cv\nMexico City MX 1,413,533,480.00 MXN Line-by-line\nEnel Rinnovabile \nSA de Cv\n99.00%\n100.00%\nHidroelectricidad\ndel Pac\u00ed\ue61eco S de\nRL de Cv\n1.00%\nParque Amistad III SA\nde Cv\nMexico City MX 931,692,540.00 MXN Line-by-line\nEnel Rinnovabile \nSA de Cv\n99.00%\n100.00%\nHidroelectricidad\ndel Pac\u00ed\ue61eco S de\nRL de Cv\n1.00%\nParque Amistad IV SA\nde Cv\nMexico City MX 1,489,508,400.00 MXN Line-by-line\nEnel Rinnovabile \nSA de Cv\n99.00%\n100.00%\nHidroelectricidad\ndel Pac\u00ed\ue61eco S de\nRL de Cv\n1.00%\nParque E\u00f3lico A\nCapelada SL (Sociedad\nUnipersonal)\nLa Coru\u00f1a ES 5,857,704.33 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nParque E\u00f3lico BR-1\nSAPI de Cv\nMexico City MX - MXN Line-by-line\nEnel Green Power\nM\u00e9xico S de RL\nde Cv\n0.50%\n25.50%\nEnel Rinnovabile \nSA de Cv\n25.00%\nParque E\u00f3lico\nCarretera de Arinaga\nSA\nLas Palmas de\nGran Canaria\nES 1,603,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n80.00% 56.09%\nParque E\u00f3lico de\nBarbanza SA\nLa Coru\u00f1a ES 3,606,072.60 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n75.00%\n52.58%\nParque E\u00f3lico de\nBarbanza SA\n0.00%\nParque E\u00f3lico de\nBelmonte SA\nMadrid ES 120,400.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n50.17% 35.17%\nParque E\u00f3lico de San\nAndr\u00e9s SA\nLa Coru\u00f1a ES 552,920.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n82.00% 57.49 %\nParque E\u00f3lico de Santa \nLuc\u00eda SA\nLas Palmas de\nGran Canaria\nES 901,500.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n65.67%\n46.51%\nParque E\u00f3lico de\nSanta Luc\u00eda SA\n1.00%\nParque E\u00f3lico Finca de\nMog\u00e1n SA\nSanta Cruz de \nTenerife\nES 3,810,340.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n90.00% 63.10%\nParque E\u00f3lico Montes \nde Las Navas SA\nMadrid ES 6,540,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n75.50% 52.93%\nParque E\u00f3lico Muniesa\nSL\nMadrid ES 3,006.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nParque E\u00f3lico Palmas\ndos Ventos Ltda\nSalvador BR 4,096,626.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.00%\nParque E\u00f3lico Pampa\nSA\nBuenos Aires AR 477,139,364.00 ARS Line-by-line\nEnel Green Power\nSpA\n100.00% 100.00%\nParque E\u00f3lico Punta de \nTeno SA\nSanta Cruz de \nTenerife\nES 528,880.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n52.00% 36.46%\nParque E\u00f3lico Sierra del\nMadero SA\nMadrid ES 7,193,970.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n58.00% 40.66%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nParque E\u00f3lico Tico SLU Zaragoza ES 234,900.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nParque Salitrillos SA\nde Cv\nMexico City MX 100.00 MXN Equity\nTenedora de\nEnerg\u00eda Renovable \nSol y Viento SAPI\nde Cv \n60.80% 20.00%\nParque Solar Cauchari\nIV SA\nSan Salvador\nde Jujuy\nAR 500,000.00 ARS Equity\nEnel Green Power\nArgentina SA\n95.00%\n82.27%\nEnerg\u00eda y Servicios\nSouth America\nSpA\n5.00%\nParque Solar Don Jos\u00e9\nSA de Cv\nMexico City MX 100.00 MXN Equity\nTenedora de\nEnerg\u00eda Renovable \nSol y Viento SAPI\nde Cv \n60.80% 20.00%\nParque Solar Villanueva\nTres SA de Cv\nMexico City MX 306,024,631.13 MXN Equity\nTenedora de\nEnerg\u00eda Renovable \nSol y Viento SAPI\nde Cv \n60.80% 20.00%\nParque Talinay Oriente\nSA\nSantiago de\nChile\nCL 66,092,165,170.93 CLP Line-by-line\nEnel Green Power\nChile SA\n60.91%\n78.64%\nEnel Green Power\nSpA\n39.09%\nPastis - Centro\nNazionale per la\nricerca e lo sviluppo\ndei materiali SCPA in\nliquidation\nBrindisi IT 2,065,000.00 EUR - Enel Italia SpA 1.14% 1.14%\nPaynesville Solar LLC Wilmington US - USD Line-by-line\nAurora Distributed\nSolar LLC \n100.00% 74. 13%\nPayTipper Network Srl Cascina IT 40,000.00 EUR AFS PayTipper SpA 100.00% 55.00%\nPayTipper SpA Milan IT 3,000,000.00 EUR AFS Enel X Srl 55.00% 55.00%\nPDP Technologies Ltd Israel IL 1,129,252.00 ILS -\nEnel Global\nInfrastructure and\nNetworks Srl\n5.72% 5.72%\nPegop - Energia \nEl\u00e9ctrica SA\nPego PT 50,000.00 EUR Equity\nEndesa\nGeneraci\u00f3n\nPo\ue61fugal SA\n0.02%\n35.06%\nEndesa\nGeneraci\u00f3n SA\n49.98%\nPH Chucas SA San Jos\u00e9 CR 100,000.00 CRC Line-by-line\nEnel Green Power\nCosta Rica SA \n40.31%\n53.48%\nESSA2 SpA 24.69%\nPH Don Pedro SA San Jos\u00e9 CR 100,001.00 CRC Line-by-line\nEnel Green Power\nCosta Rica SA \n33.44%\n32.99%\nGlobyte SA 66.54%\nPH R\u00edo Volc\u00e1n SA San Jos\u00e9 CR 100,001.00 CRC Line-by-line\nEnel Green Power\nCosta Rica SA \n34.32%\n33.64%\nGlobyte SA 65.66%\nPilesgrove Solar I LLC Andover US 1.00 USD Line-by-line\nBrick Road Solar\nHoldings LLC\n100.00% 100.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nPincher Creek LP Albe\ue61fa CA - CAD Line-by-line\nEnel Albe\ue61fa Wind\nInc.\n99.00%\n100.00%\nEnel Green Power\nCanada Inc. \n1.00%\nPine Island Distributed\nSolar LLC\nWilmington US - USD Line-by-line\nAurora Distributed\nSolar LLC \n100.00% 74. 13%\nPlanta E\u00f3lica Europea \nSAU\nSeville ES 1,198,532.32 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nPoint Rider Solar\nProject LLC\nAndover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nPomerado Energy\nStorage LLC\nWilmington US 1.00 USD Line-by-line\nEnel Energy\nStorage Holdings\nLLC (formerly EGP\nEnergy Storage\nHoldings LLC)\n100.00% 100.00%\nPotoc Power Park Srl Bucharest RO 2,000.00 RON Line-by-line\nEnel Green Power\nRomania Srl\n100.00% 100.00%\nPowerCrop\nMacchiareddu Srl\nBologna IT 100,000.00 EUR AFS\nPowerCrop\nSpA (formerly\nPowerCrop Srl)\n100.00% 50.00%\nPowerCrop Russi Srl Bologna IT 100,000.00 EUR AFS\nPowerCrop\nSpA (formerly\nPowerCrop Srl)\n100.00% 50.00%\nPowerCrop SpA\n(formerly PowerCrop \nSrl)\nBologna IT 4,000,000.00 EUR AFS\nEnel Green Power\nItalia Srl\n50.00% 50.00%\nPrairie Rose\nTransmission LLC\nMinneapolis US - USD Equity\nPrairie Rose Wind\nLLC \n100.00% 20.00%\nPrairie Rose Wind LLC Albany US - USD Equity\nEGPNA REP Wind\nHoldings LLC\n100.00% 20.00%\nPrimavera Energia SA Niter\u00f3i BR 36,965,444.64 BRL Line-by-line Enel Brasil SA 100.00% 82.27%\nProductive Solar\nSystems SLU\nRivas-\nVaciamadrid\nES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nProductora de Energ\u00edas \nSA\nBarcelona ES 60,101.22 EUR Equity\nEnel Green Power\nEspa\u00f1a SLU\n30.00% 21.03%\nProductora El\u00e9ctrica\nUrgelense SA\nL\u00e9rida ES 8,400,000.00 EUR - Endesa SA 8.43% 5.91%\nProgreso Solar 20\nMW SA\nPanama City PA 10,000.00 USD Line-by-line\nEnel Green Power\nPanam\u00e1 Srl \n100.00% 82.27%\nPromociones\nEnerg\u00e9ticas del Bierzo \nSL\nMadrid ES 12,020.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nProveedora de\nElectricidad de\nOccidente S de RL \nde Cv\nMexico City MX 89,708,835.00 MXN Line-by-line\nEnel Green Power\nM\u00e9xico S de RL\nde Cv\n99.99% 99.99%\nProyecto Almer\u00eda\nMediterr\u00e1neo SA\nMadrid ES 601,000.00 EUR Equity Endesa SA 45.00% 31.55%\nProyectos \nUniversitarios de\nEnerg\u00edas Renovables SL\nAlicante ES 27,000.00 EUR Equity\nEnel Green Power\nEspa\u00f1a SLU\n33.33% 23.37%\n\nA\ue61fachments\nSubsidiaries, associates and other signi\ue61fcant equity\ninvestments of the Enel Group at December 31, 2021\nIn compliance with A\ue61ficles 38 and 39 of Legislative Decree\n127/1991 and CONSOB Notice no. DEM/6064293 of July\n28, 2006, a list of subsidiaries and associates of Enel SpA\nat December 31, 2021, pursuant to A\ue61ficle 2359 of the Ita-\nlian Civil Code, and of other signi\ue61ecant equity investments\nis provided below. Enel has full title to all investments.\nThe following information is included for each company:\nname, registered o\ue61dce, share capital, currency in which\nshare capital is denominated, business segment, method\nof consolidation, Group companies that have a stake in the\ncompany and their respective ownership share, and the\nGroup\u2019s ownership share.\nThe following provides a key to the icons representing the\nbusiness segments.\nBusiness segment Description of business segments\nGroup holding company\nCountry holding company\nEnel Green Power\nThermal Generation\nTrading\nInfrastructure and Networks\nEnel X\nEnd-user Markets\nServices\nFinance\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nParent\nEnel SpA Rome IT 10,166,679,946.00 EUR Holding 100.00%\nSubsidiaries\n25 Mile Creek\nWindfarm LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\n400 Manley Solar LLC Boston US - USD Line-by-line\nEnel X Finance\nPa\ue61fner LLC\n100.00% 100.00%\n4814 Investments LLC Andover US - USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nABC Solar 11 SpA\nSantiago de\nChile\nCL 1,000,000.00 CLP Equity\nEnel Green Power\nChile SA\n100.00% 64.93%\nABC Solar 3 SpA\nSantiago de\nChile\nCL 1,000,000.00 CLP Equity\nEnel Green Power\nChile SA\n100.00% 64.93%\nAbu Renewables India\nPrivate Limited\nGurugram IN 100,000.00 INR Line-by-line\nEnel Green Power\nIndia Private\nLimited\n100.00% 100.00%\nAced Renewables\nHidden Valley (RF)\n(Pty) Ltd\nJohannesburg ZA 1,000.00 ZAR AFS\nEnel Green Power\nRSA 2 (RF) (Pty) Ltd\n55.00% 55.00%\nAcefat AIE Barcelona ES 793,340.00 EUR -\nEdistribuci\u00f3n\nRedes Digitales\nSL (Sociedad\nUnipersonal)\n14.29% 10.02%\nAdams Solar PV Project \nTwo (RF) (Pty) Ltd\nJohannesburg ZA 10,000,000.00 ZAR Line-by-line\nEnel Green Power\nRSA (Pty) Ltd\n60.00% 60.00%\nAdria Link Srl Gorizia IT 300,297.00 EUR Equity\nEnel Produzione \nSpA\n50.00% 50.00%\nAero-Tanna Srl Rome IT 15,000.00 EUR Line-by-line\nEnel Green Power\nItalia Srl\n100.00% 100.00%\nAgassiz Beach LLC Minneapolis US - USD Line-by-line\nChi Minnesota\nWind LLC\n51.00% 51.00%\nAgatos Green Power\nTrino Srl\nRome IT 10,000.00 EUR Line-by-line\nEnel Green Power\nSolar Energy Srl\n100.00% 100.00%\nAguil\u00f3n 20 SA Zaragoza ES 2,682,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n51.00% 35.76%\nAlba Energia Ltda Rio de Janeiro BR 16,045,169.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.00%\nAlbany Solar LLC Wilmington US - USD Line-by-line\nAurora Distributed\nSolar LLC \n100.00% 74. 13%\nAlliance SA Managua NI 6,180,150.00 NIO Equity U\ue61enet Latam SLU 49.90% 10.28%\nAlpe Adria Energia Srl Udine IT 900,000.00 EUR Equity\nEnel Produzione \nSpA\n50.00% 50.00%\nAlta Farms Azure\nRanchland Holdings\nLLC\nDover US 100.00 USD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nAlta Farms Wind\nProject II LLC\nAndover US 1.00 USD Line-by-line\nEnel Green Power\nAzure Ranchland\nHoldings LLC\n100.00% 100.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nAlvorada Energia SA Niter\u00f3i BR 22,317,415.92 BRL Line-by-line Enel Brasil SA 100.00% 82.27%\nAmpla Energia e\nServi\u00e7os SA\nRio de Janeiro BR 2,498,230,386.65 BRL Line-by-line Enel Brasil SA 99.73% 82.05%\nAnnandale Solar LLC Wilmington US - USD Line-by-line\nAurora Distributed\nSolar LLC \n100.00% 74. 13%\nApiac\u00e1s Energia SA Rio de Janeiro BR 14,216,846.33 BRL Line-by-line Enel Brasil SA 100.00% 82.27%\nAquilla Wind Project \nLLC\nAndover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nAragonesa de\nActividades\nEnerg\u00e9ticas SA\nTeruel ES 60,100.00 EUR Line-by-line\nEndesa Red \nSA (Sociedad\nUnipersonal)\n100.00% 70.11%\nArano\ue61f Desarrollos SL Madrid ES 3,010.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nAravalli Surya (Project 1) \nPrivate Limited\nGurugram IN 8,100,000.00 INR Line-by-line\nEnel Green Power\nIndia Private\nLimited\n100.00% 100.00%\nArcadia Power Inc. Washington DC US - USD -\nEnel X No\ue61fh\nAmerica Inc. \n0.14% 0.14%\nArena Power Solar\n11 SLU\nMadrid ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nArena Power Solar\n12 SLU\nMadrid ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nArena Power Solar\n13 SLU\nSeville ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nArena Power Solar\n20 SLU\nSeville ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nArena Power Solar\n33 SLU\nMadrid ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nArena Power Solar\n34 SLU\nMadrid ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nArena Power Solar\n35 SLU\nSeville ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nAsociaci\u00f3n Nuclear\nAsc\u00f3-Vandell\u00f3s II AIE\nTarragona ES 19,232,400.00 EUR Propo\ue61fional\nEndesa\nGeneraci\u00f3n SA\n85.41% 59.88%\nAteca Renovables SL Madrid ES 3,000.00 EUR Equity\nBaylio Solar SLU 19.72%\n35.06%\nDehesa de los\nGuadalupes Solar\nSLU \n14.93%\nSeguidores\nSolares Planta\n2 SL (Sociedad\nUnipersonal)\n15.35%\nAthonet France SASU Paris FR 50,000.00 EUR - Athonet Srl 100.00% 16.00%\nAthonet Srl Trieste IT 68,927.57 EUR - Enel X Srl 16.00% 16.00%\nAthonet UK Ltd\nBa\ue61cle, East \nSussex\nGB 250,001.00 GBP - Athonet Srl 100.00% 16.00%\nAthonet USA Inc. Wilmington US 1.00 USD - Athonet Srl 100.00% 16.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nAtl\u00e1ntico Photovoltaic\nSAS ESP\nBarranquilla CO 2,000,000.00 COP Line-by-line\nEnel Green Power\nColombia SAS ESP\n100.00% 82.27%\nAtwater Solar LLC Wilmington US - USD Line-by-line\nAurora Distributed\nSolar LLC \n100.00% 74. 13%\nAurora Distributed\nSolar LLC\nWilmington US - USD Line-by-line\nAurora Solar\nHoldings LLC\n74. 13% 74. 13 %\nAurora Land Holdings\nLLC\nWilmington US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nAurora Solar Holdings\nLLC\nWilmington US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nAurora Wind Holdings\nLLC\nAndover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nAurora Wind Project\nLLC\nAndover US 1.00 USD Line-by-line\nAurora Wind\nHoldings LLC\n100.00% 100.00%\nAutumn Hills LLC Wilmington US - USD Line-by-line\nChi Minnesota\nWind LLC\n51.00% 51.00%\nAvikiran Energy India\nPrivate Limited\nGurugram IN 73,300,000.00 INR Line-by-line\nEnel Green Power\nIndia Private\nLimited\n100.00% 100.00%\nAvikiran Solar India\nPrivate Limited\nNew Delhi IN 253,659,580.00 INR Line-by-line\nEnel Green Power\nIndia Private\nLimited\n100.00% 100.00%\nAvikiran Surya India\nPrivate Limited\nGurugram IN 100,000.00 INR Line-by-line\nEnel Green Power\nIndia Private\nLimited\n100.00% 100.00%\nAvikiran Vayu India\nPrivate Limited\nGurugram IN 100,000.00 INR Line-by-line\nEnel Green Power\nIndia Private\nLimited\n100.00% 100.00%\nAzure Blue Jay Holdings\nLLC\nDover US 100.00 USD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nAzure Blue Jay Solar\nHoldings LLC\nAndover US 1.00 USD Line-by-line\nEnel Green Power\nAzure Blue Jay\nSolar Holdings LLC \n100.00% 100.00%\nAzure Sky Solar Project\nLLC\nAndover US 1.00 USD Line-by-line\nAzure Blue Jay\nSolar Holdings LLC \n100.00% 100.00%\nAzure Sky Wind\nHoldings LLC\nAndover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nAzure Sky Wind Project\nLLC\nAndover US 1.00 USD Line-by-line\nEnel Green Power\nAzure Ranchland\nHoldings LLC\n100.00% 100.00%\nAzure Sky Wind\nStorage LLC\nAndover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nBaikal Enterprise SL\nPalma de\nMallorca\nES 3,006.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nBaleares Energy SL\nPalma de\nMallorca\nES 4,509.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nBarnwell County Solar\nProject LLC\nAndover US - USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nBaylio Solar SLU Seville ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nBeaver Falls Water \nPower Company\nWilmington US - USD Line-by-line\nBeaver Valley\nHoldings LLC\n67.50% 67.50%\nBeaver Valley Holdings\nLLC\nWilmington US - USD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nBelomechetskaya WPS Moscow RU 3,010,000.00 RUB Line-by-line\nEnel Green Power\nRus Limited\nLiability Company\n100.00% 100.00%\nBijou Hills Wind LLC Andover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nBioenergy Casei Gerola\nSrl\nRome IT 100,000.00 EUR Line-by-line\nEnel Green Power\nItalia Srl\n100.00% 100.00%\nBison Meadows Wind\nProject LLC\nAndover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nBlair Solar I LLC Andover US 1.00 USD Line-by-line\nBrick Road Solar\nHoldings LLC\n100.00% 100.00%\nBlue Jay Solar I LLC Andover US 1.00 USD Line-by-line\nAzure Blue Jay\nSolar Holdings LLC \n100.00% 100.00%\nBlue Jay Solar II LLC Andover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nBlue Star Wind Project\nLLC\nAndover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nBluRe MA San Jos\u00e9 LU 7,092,970.00 EUR -\nSlovensk\u00e9\nelektr\u00e1rne AS\n5.00% 1.65%\nBogaris PV1 SLU Madrid ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nBogot\u00e1 ZE SAS Bogot\u00e1 CO 503,609,700.00 COP Line-by-line\nCodensa SA ESP 62.99%\n39.74%\nEnel X Colombia\nSAS\n37.01%\nBoiro Energ\u00eda SA Boiro ES 601,010.00 EUR Equity\nEnel Green Power\nEspa\u00f1a SLU\n40.00% 28.04%\nBondia Energia Ltda Niter\u00f3i BR 2,950,888.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\nEnel Green Power\nDesenvolvimento\nLtda \n0.00%\nBoone Stephens Solar\nI LLC\nAndover US 1.00 USD Line-by-line\nBrick Road Solar\nHoldings LLC\n100.00% 100.00%\nBosa del Ebro SL Zaragoza ES 3,010.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n51.00% 35.75%\nBo\ue61com Grass Solar\nProject LLC\nAndover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nBoujdour Wind Farm Casablanca MA 300,000.00 MAD Equity\nNareva Enel Green\nPower Morocco\nSA\n90.00% 45.00%\nBouldercombe Solar\nFarm Trust\nSydney AU 10.00 AUD Line-by-line\nEnel Green Power\nBouldercombe\nTrust \n100.00% 100.00%\nBouldercombe Solar\n(Pty) Ltd\nSydney AU 100.00 AUD Line-by-line\nEnel Green Power\nBouldercombe\nHolding (Pty) Ltd \n100.00% 100.00%\nBp Hydro Finance\nPa\ue61fnership\nSalt Lake City US - USD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n24.08%\n100.00%\nEnel Kansas LLC 75.92%\nBrandonville Solar I LLC Andover US 1.00 USD Line-by-line\nBrick Road Solar\nHoldings LLC\n100.00% 100.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nBravo Dome Wind\nProject LLC\nAndover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nBrazoria West Solar\nProject LLC\nAndover US - USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nBrazos Flat Solar\nProject LLC\nAndover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nBrick Road Solar\nHoldings LLC\nAndover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nBrush County Solar\nProject LLC\nAndover US - USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nBuckshutem Solar I LLC Andover US 1.00 USD Line-by-line\nBrick Road Solar\nHoldings LLC\n100.00% 100.00%\nBuckshutem Solar \nII LLC\nAndover US 1.00 USD Line-by-line\nBrick Road Solar\nHoldings LLC\n100.00% 100.00%\nBu\ue61balo Dunes Wind\nProject LLC\nTopeka US - USD Line-by-line\nEGPNA\nDevelopment\nHoldings LLC\n75.00% 75.00%\nBu\ue61balo Jump LP Albe\ue61fa CA 10.00 CAD Line-by-line\nEnel Albe\ue61fa Wind\nInc.\n0.10%\n100.00%\nEnel Green Power\nCanada Inc. \n99.90%\nBu\ue61balo Spirit Wind\nProject LLC\nAndover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nBungala One Finco\n(Pty) Ltd\nSydney AU 1,000.00 AUD Line-by-line\nBungala One\nPrope\ue61fy (Pty) Ltd\n100.00% 51.00%\nBungala One Operation\nHolding Trust\nSydney AU 100.00 AUD Line-by-line\nEnel Green Power\nBungala (Pty) Ltd\n50.00% 50.00%\nBungala One\nOperations Holding\n(Pty) Ltd\nSydney AU 100.00 AUD Line-by-line\nEnel Green Power\nBungala (Pty) Ltd\n51.00% 51.00%\nBungala One\nOperations (Pty) Ltd\nSydney AU 1,000.00 AUD Line-by-line\nBungala One\nOperations\nHolding (Pty) Ltd \n100.00% 51.00%\nBungala One\nOperations Trust\nSydney AU - AUD Line-by-line\nBungala One\nOperations\nHolding (Pty) Ltd \n100.00% 51.00%\nBungala One Prope\ue61fy\nHolding (Pty) Ltd\nSydney AU 100.00 AUD Line-by-line\nEnel Green Power\nBungala (Pty) Ltd\n51.00% 51.00%\nBungala One Prope\ue61fy\nHolding Trust\nSydney AU 100.00 AUD Line-by-line\nEnel Green Power\nBungala (Pty) Ltd\n50.00% 50.00%\nBungala One Prope\ue61fy\n(Pty) Ltd\nSydney AU 1,000.00 AUD Line-by-line\nBungala One\nPrope\ue61fy Holding\n(Pty) Ltd \n100.00% 51.00%\nBungala One Prope\ue61fy\nTrust\nSydney AU - AUD Line-by-line\nBungala One\nPrope\ue61fy Holding\n(Pty) Ltd \n100.00% 51.00%\nBungala Two Finco\n(Pty) Ltd\nSydney AU - AUD Line-by-line\nBungala Two\nPrope\ue61fy (Pty) Ltd\n100.00% 51.00%\nBungala Two\nOperations Holding\n(Pty) Ltd\nSydney AU - AUD Line-by-line\nEnel Green Power\nBungala (Pty) Ltd\n51.00% 51.00%\nBungala Two\nOperations Holding\nTrust\nSydney AU - AUD Line-by-line\nEnel Green Power\nBungala (Pty) Ltd\n50.00% 50.00%\nBungala Two\nOperations (Pty) Ltd\nSydney AU - AUD Line-by-line\nBungala Two\nOperations\nHolding (Pty) Ltd \n100.00% 51.00%\n\nEnel Green Power\nDesenvolvimento\nLtda \n0.00%\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nBungala Two\nOperations Trust\nSydney AU - AUD Line-by-line\nBungala Two\nOperations\nHolding (Pty) Ltd \n100.00% 51.00%\nBungala Two Prope\ue61fy\nHolding (Pty) Ltd\nSydney AU - AUD Line-by-line\nEnel Green Power\nBungala (Pty) Ltd\n51.00% 51.00%\nBungala Two Prope\ue61fy\nHolding Trust\nSydney AU - AUD Line-by-line\nEnel Green Power\nBungala (Pty) Ltd\n50.00% 50.00%\nBungala Two Prope\ue61fy\n(Pty) Ltd\nSydney AU - AUD Line-by-line\nBungala Two\nPrope\ue61fy Holding\n(Pty) Ltd \n100.00% 51.00%\nBungala Two Prope\ue61fy\nTrust\nSydney AU 1.00 AUD Line-by-line\nBungala Two\nPrope\ue61fy Holding\n(Pty) Ltd \n100.00% 51.00%\nBusiness Venture\nInvestments 1468\n(Pty) Ltd\nJohannesburg ZA 100.00 ZAR Line-by-line\nEnel Green Power\nRSA (Pty) Ltd\n100.00% 100.00%\nBu\ue61ce\ue61aly Meadows \nSolar Project LLC\nAndover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nC&C Castelvetere Srl Rome IT 100,000.00 EUR Line-by-line\nEnel Green Power\nItalia Srl\n100.00% 100.00%\nC&C Uno Energy Srl Rome IT 118,000.00 EUR Line-by-line\nEnel Green Power\nItalia Srl\n100.00% 100.00%\nCanastota Wind Power\nLLC\nAndover US - USD Line-by-line\nFenner Wind\nHoldings LLC\n100.00% 100.00%\nCaney River Wind \nProject LLC\nOverland Park US - USD Equity\nRocky Caney Wind\nLLC \n100.00% 20.00%\nCastiblanco Solar SL Madrid ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nCastle Rock Ridge \nLimited Pa\ue61fnership\nAlbe\ue61fa CA - CAD Line-by-line\nEnel Albe\ue61fa Wind\nInc.\n0.10%\n100.00%\nEnel Green Power\nCanada Inc. \n99.90%\nCatalana d\u2019Iniciatives\nSCR SA\nBarcelona ES 30,862,800.00 EUR -\nEndesa Red \nSA (Sociedad\nUnipersonal)\n0.94% 0.66%\nCCP.RO Bucharest SA Bucharest RO 79,800,000.00 RON - Enel Romania SA 9.52% 9.52%\nCdec - Sic Ltda\nSantiago de\nChile\nCL 709,783,206.00 CLP -\nEnel Green Power\nChile SA\n6.00% 3.90%\nCedar Run Wind\nProject LLC\nAndover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nCelg Distribui\u00e7\u00e3o SA -\nCelg D\nGoi\u00e1s BR 5,664,951,979.22 BRL Line-by-line Enel Brasil SA 99.96% 82.24%\nCentral Dock Sud SA Buenos Aires AR 1,231,270,567.54 ARS Line-by-line\nEnel Argentina SA 0.24%\n33.94%\nInversora Dock\nSud SA\n71.78%\nCentral Geradora\nFotovoltaica Bom\nNome Ltda\nSalvador BR 4,979,739.00 BRL Line-by-line\nEnel Brasil SA 100.00%\n82.27%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nCentral Geradora\nFotovoltaica S\u00e3o\nFrancisco Ltda\nNiter\u00f3i BR 113,749,250.00 BRL Line-by-line\nEnel Brasil SA 0.00%\n82.27%\nEnel X Brasil SA 100.00%\nCentral Geradora\nTermel\u00e9trica Fo\ue61faleza \nSA\nFo\ue61faleza BR 151,935,779.00 BRL Line-by-line Enel Brasil SA 100.00% 82.27%\nCentral Hidr\u00e1ulica\nG\u00fcejar-Sierra SL\nSeville ES 364,213.34 EUR Equity\nEnel Green Power\nEspa\u00f1a SLU\n33.30% 23.35%\nCentral T\u00e9rmica de\nAnllares AIE\nMadrid ES 595,000.00 EUR Equity\nEndesa\nGeneraci\u00f3n SA\n33.33% 23.37%\nCentral Vuelta de\nObligado SA\nBuenos Aires AR 500,000.00 ARS Equity\nCentral Dock\nSud SA\n6.40%\n20.93%\nEnel Generaci\u00f3n\nCostanera SA\n1.30%\nEnel Generaci\u00f3n El\nChoc\u00f3n SA\n33.20%\nCentrales Nucleares\nAlmaraz-Trillo AIE\nMadrid ES - EUR Equity\nEndesa\nGeneraci\u00f3n SA\n24.18% 16.95%\nCentrum Pre Vedu A\nVyskum SRO\nKaln\u00e1 Nad\nHronom\nSK 6,639.00 EUR Equity\nSlovensk\u00e9\nelektr\u00e1rne AS\n100.00% 33.00%\nCESI - Centro \nEle\ue61crotecnico\nSperimentale Italiano\nGiacinto Mo\ue61ca SpA\nMilan IT 8,550,000.00 EUR Equity Enel SpA 42.70% 42.70%\nChampagne Storage\nLLC\nWilmington US 1.00 USD Line-by-line\nEnel Energy\nStorage Holdings\nLLC (formerly EGP\nEnergy Storage\nHoldings LLC)\n100.00% 100.00%\nCheyenne Ridge II \nWind Project LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nCheyenne Ridge Wind \nProject LLC\nAndover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nChi Black River LLC Wilmington US - USD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nChi Minnesota Wind\nLLC\nWilmington US - USD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nChi Operations Inc. Andover US 100.00 USD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nChi Power Inc. Naples US 100.00 USD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nChi Power Marketing\nInc.\nWilmington US 100.00 USD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nChi West LLC San Francisco US 100.00 USD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nChinango SAC San Miguel PE 295,249,298.00 PEN Line-by-line\nEnel Generaci\u00f3n\nPer\u00fa SAA\n80.00% 55.02%\nChisago Solar LLC Wilmington US - USD Line-by-line\nAurora Distributed\nSolar LLC \n100.00% 74. 13%\nChisholm View II\nHolding LLC\nWilmington US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nChisholm View Wind\nProject II LLC\nWilmington US - USD Line-by-line\nChisholm View II\nHolding LLC\n62.79% 62.79%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nChisholm View Wind\nProject LLC\nNew York US - USD Equity\nEGPNA REP Wind\nHoldings LLC\n100.00% 20.00%\nCimarron Bend Assets \nLLC\nWilmington US - USD Line-by-line\nCimarron Bend\nWind Project I LLC\n49.00%\n100.00%\nCimarron Bend\nWind Project II LLC\n49.00%\nCimarron Bend\nWind Project III\nLLC \n1.00%\nEnel Kansas LLC 1.00%\nCimarron Bend III\nHoldCo LLC\nAndover US 1.00 USD Line-by-line\nEnel Green Power\nCimarron Bend\nWind Holdings\nIII LLC\n100.00% 100.00%\nCimarron Bend Wind\nHoldings I LLC\nWilmington US - USD Line-by-line\nCimarron Bend\nWind Holdings\nII LLC\n100.00% 100.00%\nCimarron Bend Wind\nHoldings II LLC\nDover US 100.00 USD Line-by-line\nCimarron Bend\nWind Holdings\nLLC \n100.00% 100.00%\nCimarron Bend Wind\nHoldings III LLC\nAndover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nCimarron Bend Wind\nHoldings LLC\nWilmington US - USD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nCimarron Bend Wind\nProject I LLC\nWilmington US - USD Line-by-line\nCimarron Bend\nWind Holdings\nI LLC\n100.00% 100.00%\nCimarron Bend Wind\nProject II LLC\nWilmington US - USD Line-by-line\nCimarron Bend\nWind Holdings\nI LLC\n100.00% 100.00%\nCimarron Bend Wind\nProject III LLC\nWilmington US - USD Line-by-line\nCimarron Bend\nWind Holdings\nIII LLC\n100.00% 100.00%\nCipher Solar Project \nLLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nCityPoste Payment \nDigital Srl\nTeramo IT 10,000.00 EUR AFS\nCityPoste Payment \nSpA\n100.00% 100.00%\nCityPoste Payment SpA Teramo IT - EUR AFS Enel X Srl 100.00% 100.00%\nCivDrone Haifa IL 1,093,350.00 ILS -\nEnel Global\nInfrastructure and\nNetworks Srl\n4.27% 4.27%\nClear Sky Wind Project \nLLC\nAndover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nClinton Farms Wind \nProject LLC\nAndover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nCloudwalker Wind \nProject LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nCodensa SA ESP Bogot\u00e1 CO 13,487,545,000.00 COP Line-by-line Enel Am\u00e9ricas SA 48.30% 39.74%\nCogein Sannio Srl Rome IT 10,000.00 EUR Line-by-line\nEnel Green Power\nItalia Srl\n100.00% 100.00%\nCogeneraci\u00f3n El Salto\nSL\nZaragoza ES 36,060.73 EUR Equity\nEnel Green Power\nEspa\u00f1a SLU\n20.00% 14.02%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nCogenio Srl Rome IT 2,310,000.00 EUR Equity Enel X Italia Srl 20.00% 20.00%\nCohuna Solar Farm\n(Pty) Ltd\nSydney AU 100.00 AUD Line-by-line\nEnel Green Power\nCohuna Holdings\n(Pty) Ltd \n100.00% 100.00%\nCohuna Solar Farm\nTrust\nSydney AU 1.00 AUD Line-by-line\nEnel Green Power\nCohuna Trust\n100.00% 100.00%\nComanche Crest \nRanch LLC\nAndover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nComercializadora\nEl\u00e9ctrica de C\u00e1diz SA\nCadiz ES 600,000.00 EUR Equity\nEndesa Red \nSA (Sociedad\nUnipersonal)\n33.50% 23.49%\nCompagnia Po\ue61fo di \nCivitavecchia SpA in\nliquidation\nRome IT 14,730,800.00 EUR Equity\nEnel Produzione \nSpA\n25.00% 25.00%\nCompanhia Energ\u00e9tica \ndo Cear\u00e1 - Coelce\nFo\ue61faleza BR 914,346,885.76 BRL Line-by-line Enel Brasil SA 74.05% 60.92%\nCompa\u00f1\u00eda de\nTrasmisi\u00f3n del\nMercosur SA - CTM\nBuenos Aires AR 2,025,191,313.00 ARS Line-by-line\nEnel Brasil SA 74.15%\n82.27%Enel CIEN SA 25.85%\nEnel SpA 0.00%\nCompa\u00f1\u00eda Energ\u00e9tica \nVeracruz SAC\nSan Miguel PE 2,886,000.00 PEN Line-by-line Enel Per\u00fa SAC 100.00% 82.27%\nCompa\u00f1\u00eda E\u00f3lica\nTierras Altas SA\nSoria ES 13,222,000.00 EUR Equity\nCompa\u00f1\u00eda E\u00f3lica\nTierras Altas SA \n5.00%\n26.29%\nEnel Green Power\nEspa\u00f1a SLU\n35.63%\nConce\ue61f Srl Rome IT 10,000.00 EUR Line-by-line\nEnel Global\nThermal\nGeneration Srl\n100.00% 100.00%\nConcho Solar I LLC Andover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nConsolidated Hydro\nNew Hampshire LLC\nWilmington US - USD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nConsolidated Hydro\nSoutheast LLC\nWilmington US - USD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nConsolidated Pumped\nStorage Inc.\nWilmington US 550,000.00 USD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n81.83% 81.83%\nConza Green Energy\nSrl\nRome IT 73,000.00 EUR Line-by-line\nEnel Green Power\nItalia Srl\n100.00% 100.00%\nCopper Landing Solar\nProject LLC\nAndover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nCorporaci\u00f3n\nEmpresarial de\nExtremadura SA\nBadajoz ES 44,538,000.00 EUR - Endesa SA 1.01% 0.71%\nCorporaci\u00f3n E\u00f3lica de \nZaragoza SL\nLa Puebla de\nAl\ue61enden\nES 271,652.00 EUR Equity\nEnel Green Power\nEspa\u00f1a SLU\n25.00% 17.53%\nCountry Roads Solar\nProject LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nCow Creek Wind\nProject LLC\nAndover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nCrocke\ue61c Solar I LLC Andover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nCross Trails Energy\nStorage Project LLC\nAndover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nDairy Meadows Wind\nProject 1 LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nDairy Meadows Wind\nProject 2 LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nDairy Meadows Wind\nProject 3 LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nDaisy Patch Solar\nProject LLC\nAndover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nDanax Energy (Pty) Ltd Sandton ZA 100.00 ZAR Line-by-line\nEnel Green Power\nRSA (Pty) Ltd\n100.00% 100.00%\nDara Solar Investment\nSrl\nBucharest RO 592,400.00 RON Line-by-line\nEnel Green Power\nRomania Srl\n100.00% 100.00%\nDauphin Solar I LLC Andover US 1.00 USD Line-by-line\nBrick Road Solar\nHoldings LLC\n100.00% 100.00%\nDe Rock Int\u2019l Srl Bucharest RO 5,629,000.00 RON Line-by-line\nEnel Green Power\nRomania Srl\n100.00%\n100.00%\nEnel Green Power\nSpA\n0.00%\nDehesa de los\nGuadalupes Solar SLU\nSeville ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nDehesa PV Farm 03 \nSLU\nMadrid ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nDehesa PV Farm 04\nSLU\nMadrid ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nDepuraci\u00f3n Destilaci\u00f3n\nReciclaje SL\nBoiro ES 600,000.00 EUR Equity\nEnel Green Power\nEspa\u00f1a SLU\n40.00% 28.04%\nDerivex SA Bogot\u00e1 CO 715,292,000.00 COP - Emgesa SA ESP 5.00% 1.99%\nDesarrollo de Fuerzas \nRenovables S de RL\nde Cv\nMexico City MX 33,101,350.00 MXN Line-by-line\nEnel Green Power\nM\u00e9xico S de RL\nde Cv\n99.99%\n100.00%\nEnerg\u00eda Nueva\nEnerg\u00eda Limpia\nM\u00e9xico S de RL\nde Cv\n0.01%\nDI.T.N.E. - Distre\ue61co \nTecnologico Nazionale\nsull\u2019Energia -\nSociet\u00e0 Conso\ue61file a\nResponsabilit\u00e0 Limitata\nRome IT 436,535.29 EUR -\nEnel Produzione \nSpA\n1.76% 1.76%\nDiamond Vista\nHoldings LLC\nWilmington US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nDistribuidora de\nEnerg\u00eda El\u00e9ctrica del \nBages SA\nBarcelona ES 108,240.00 EUR Line-by-line\nEndesa Red \nSA (Sociedad\nUnipersonal)\n55.00%\n70.11%\nHidroel\u00e9ctrica de \nCatalunya SL\n45.00%\nDistribuidora El\u00e9ctrica \ndel Pue\ue61fo de la Cruz \nSA\nSanta Cruz de \nTenerife\nES 12,621,210.00 EUR Line-by-line\nEndesa Red \nSA (Sociedad\nUnipersonal)\n100.00% 70.11%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nDistrilec Inversora SA Buenos Aires AR 497,612,021.00 ARS Line-by-line Enel Am\u00e9ricas SA 51.50% 42.37%\nDmd Holding AS in\nliquidation\nTren\u010d\u00edn-\nZlatovce\nSK 199,543,284.87 EUR -\nSlovensk\u00e9\nelektr\u00e1rne AS\n2.94% 0.97%\nDodge Center \nDistributed Solar LLC\nWilmington US - USD Line-by-line\nAurora Distributed\nSolar LLC \n100.00% 74. 13%\nDolores Wind SA de Cv Mexico City MX 200.00 MXN Line-by-line\nEnel Rinnovabile \nSA de Cv\n99.00%\n100.00%\nHidroelectricidad\ndel Pac\u00ed\ue61eco S de\nRL de Cv\n1.00%\nDominica Energ\u00eda \nLimpia SA de Cv\nMexico City MX 2,070,600,646.00 MXN Equity\nTenedora de\nEnerg\u00eda Renovable \nSol y Viento SAPI\nde Cv \n60.80% 20.00%\nDorset Ridge Wind\nProject LLC\nAndover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nDover Solar I LLC Andover US - USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nDragon\ue618y Fields Solar\nProject LLC\nAndover US - USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nDrift Sand Wind\nHoldings LLC\nWilmington US - USD Equity Enel Kansas LLC 50.00% 50.00%\nDrift Sand Wind Project\nLLC\nWilmington US - USD Equity\nDrift Sand Wind\nHoldings LLC\n100.00% 50.00%\nDwarka Vayu 1 Private\nLimited\nGurgaon IN 100,000.00 INR Line-by-line\nEnel Green Power\nIndia Private\nLimited\n100.00% 100.00%\nE.S.CO. Comuni Srl Bergamo IT 1,000,000.00 EUR Line-by-line Enel X Italia Srl 60.00% 60.00%\nEastwood Solar LLC Wilmington US - USD Line-by-line\nAurora Distributed\nSolar LLC \n100.00% 74. 13%\nEbenezer Solar I LLC Andover US 1.00 USD Line-by-line\nBrick Road Solar\nHoldings LLC\n100.00% 100.00%\nEdga\ue61fown Depot Solar\n1 LLC\nBoston US - USD Line-by-line\nEnel X MA\nHoldings LLC\n100.00% 100.00%\nEdistribuci\u00f3n Redes\nDigitales SL (Sociedad\nUnipersonal)\nMadrid ES 1,204,540,060.00 EUR Line-by-line\nEndesa Red \nSA (Sociedad\nUnipersonal)\n100.00% 70.11%\nE-Distribu\u0163ie Banat SA Timisoara RO 382,158,580.00 RON Line-by-line Enel SpA 51.00% 51.00%\nE-Distribu\u0163ie Dobrogea\nSA\nConstan\u0163a RO 280,285,560.00 RON Line-by-line Enel SpA 51.00% 51.00%\nE-Distribu\u0163ie Muntenia\nSA\nBucharest RO 271,635,250.00 RON Line-by-line Enel SpA 78.00% 78.00%\ne-distribuzione SpA Rome IT 2,600,000,000.00 EUR Line-by-line Enel Italia SpA 100.00% 100.00%\nEF Divesture LLC Andover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nE\ue61dcientya Srl Bergamo IT 100,000.00 EUR Equity Enel X Italia Srl 50.00% 50.00%\nEGP Australia (Pty) Ltd Sydney AU 10,000.00 AUD Line-by-line\nEnel Green Power\nAustralia (Pty) Ltd\n100.00% 100.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nEGP Bioenergy Srl Rome IT 1,000,000.00 EUR Line-by-line\nEnel Green Power\nPuglia Srl\n100.00% 100.00%\nEGP Fotovoltaica La\nLoma SAS in liquidation\nBogot\u00e1 CO 8,000,000.00 COP Line-by-line\nEnel Green Power\nColombia SAS ESP\n100.00% 82.27%\nEGP Geronimo Holding\nCompany Inc.\nWilmington US 1,000.00 USD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nEGP HoldCo 1 LLC Andover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGP HoldCo 10 LLC Andover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGP HoldCo 11 LLC Andover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGP HoldCo 12 LLC Andover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGP HoldCo 13 LLC Andover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGP HoldCo 14 LLC Andover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGP HoldCo 15 LLC Andover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGP HoldCo 16 LLC Andover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGP HoldCo 17 LLC Andover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGP HoldCo 18 LLC Andover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGP HoldCo 2 LLC Andover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGP HoldCo 3 LLC Andover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGP HoldCo 4 LLC Andover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGP HoldCo 5 LLC Andover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGP HoldCo 6 LLC Andover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGP HoldCo 7 LLC Andover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGP HoldCo 8 LLC Andover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGP HoldCo 9 LLC Andover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGP Magdalena Solar\nSA de Cv\nMexico City MX 691,771,740.00 MXN Line-by-line\nEnel Rinnovabile \nSA de Cv\n99.00%\n100.00%\nHidroelectricidad\ndel Pac\u00ed\ue61eco S de\nRL de Cv\n1.00%\nEGP Matimba NewCo \n1 Srl\nRome IT 10,000.00 EUR Line-by-line\nEnel Green Power\nSpA\n100.00% 100.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nEGP Matimba NewCo \n2 Srl\nRome IT 10,000.00 EUR Line-by-line\nEnel Green Power\nSpA\n100.00% 100.00%\nEGP Nevada Power LLC Wilmington US - USD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nEGP Salt Wells Solar \nLLC\nWilmington US - USD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nEGP San Leandro\nMicrogrid I LLC\nWilmington US - USD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nEGP Solar Services LLC Andover US - USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nEGP Stillwater Solar\nLLC\nWilmington US - USD Line-by-line Enel Stillwater LLC 100.00% 100.00%\nEGP Stillwater Solar PV\nII LLC\nWilmington US 1.00 USD Line-by-line\nStillwater Woods \nHill Holdings LLC\n100.00% 100.00%\nEGP Timber Hills\nProject LLC\nLos Angeles US - USD Line-by-line\nPadoma Wind\nPower LLC\n100.00% 100.00%\nEGPNA 2020 HoldCo \n1 LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGPNA 2020 HoldCo \n10 LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGPNA 2020 HoldCo \n11 LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGPNA 2020 HoldCo \n12 LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGPNA 2020 HoldCo \n13 LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGPNA 2020 HoldCo \n14 LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGPNA 2020 HoldCo \n15 LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGPNA 2020 HoldCo \n16 LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGPNA 2020 HoldCo \n17 LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGPNA 2020 HoldCo \n18 LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGPNA 2020 HoldCo \n19 LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGPNA 2020 HoldCo \n2 LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGPNA 2020 HoldCo \n20 LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGPNA 2020 HoldCo \n21 LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGPNA 2020 HoldCo \n22 LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGPNA 2020 HoldCo \n23 LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGPNA 2020 HoldCo \n24 LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nEGPNA 2020 HoldCo \n25 LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGPNA 2020 HoldCo \n26 LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGPNA 2020 HoldCo \n27 LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGPNA 2020 HoldCo \n28 LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGPNA 2020 HoldCo \n29 LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGPNA 2020 HoldCo \n3 LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGPNA 2020 HoldCo \n30 LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGPNA 2020 HoldCo \n4 LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGPNA 2020 HoldCo \n5 LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGPNA 2020 HoldCo \n6 LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGPNA 2020 HoldCo \n7 LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGPNA 2020 HoldCo \n8 LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGPNA 2020 HoldCo \n9 LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGPNA Development \nHoldings LLC\nWilmington US - USD Line-by-line\nEnel Green Power\nNo\ue61fh America\nDevelopment LLC \n100.00% 100.00%\nEGPNA Hydro Holdings\nLLC\nWilmington US - USD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nEGPNA Preferred Wind\nHoldings II LLC\nWilmington US - USD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nEGPNA Preferred Wind\nHoldings LLC\nWilmington US - USD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nEGPNA Project HoldCo\n1 LLC\nDover US 100.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nEGPNA Project HoldCo\n2 LLC\nDover US 100.00 USD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nEGPNA Project HoldCo\n5 LLC\nDover US 100.00 USD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nEGPNA Project HoldCo\n6 LLC\nDover US 100.00 USD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nEGPNA Project HoldCo\n7 LLC\nDover US 100.00 USD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nEGPNA Renewable \nEnergy Pa\ue61fners LLC\nWilmington US - USD Equity\nEGPNA REP\nHoldings LLC\n20.00% 20.00%\nEGPNA REP Holdings\nLLC\nWilmington US - USD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nEGPNA REP Solar \nHoldings LLC\nWilmington US - USD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nEGPNA REP Wind\nHoldings LLC\nWilmington US - USD Equity\nEGPNA Renewable \nEnergy Pa\ue61fners\nLLC \n100.00% 20.00%\nEGPNA Wind Holdings\n1 LLC\nWilmington US - USD Equity\nEGPNA REP Wind\nHoldings LLC\n100.00% 20.00%\nEGPNA-SP Seven \nCowboy Holdings LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nElcogas SA in\nliquidation\nPue\ue61follano\n(Ciudad Real)\nES 809,690.40 EUR Equity\nEndesa\nGeneraci\u00f3n SA\n40.99%\n33.06%\nEnel SpA 4.32%\nElcomex Solar Energy\nSrl\nBucharest RO 4,590,000.00 RON Line-by-line\nEnel Green Power\nRomania Srl\n100.00%\n100.00%\nEnel Green Power\nSpA\n0.00%\nElecgas SA Pego PT 50,000.00 EUR Equity\nEndesa\nGeneraci\u00f3n\nPo\ue61fugal SA\n50.00% 35.06%\nElectra Capital (RF) \n(Pty) Ltd\nJohannesburg ZA 10,000,000.00 ZAR Line-by-line\nEnel Green Power\nRSA (Pty) Ltd\n60.00% 60.00%\nEl\u00e9ctrica de Jafre SA Barcelona ES 165,876.00 EUR Line-by-line\nEndesa Red \nSA (Sociedad\nUnipersonal)\n52.54%\n70.11%\nHidroel\u00e9ctrica de \nCatalunya SL\n47.46%\nEl\u00e9ctrica de Lijar SL Cadiz ES 1,081,821.79 EUR Equity\nEndesa Red \nSA (Sociedad\nUnipersonal)\n50.00% 35.06%\nEl\u00e9ctrica del Ebro SA \n(Sociedad Unipersonal)\nBarcelona ES 500,000.00 EUR Line-by-line\nEndesa Red \nSA (Sociedad\nUnipersonal)\n100.00% 70.11%\nElectricidad de Pue\ue61fo\nReal SA\nCadiz ES 4,960,246.40 EUR Equity\nEndesa Red \nSA (Sociedad\nUnipersonal)\n50.00% 35.06%\nElectrometal\u00fargica del\nEbro SL\nBarcelona ES 2,906,862.00 EUR -\nEnel Green Power\nEspa\u00f1a SLU\n0.18% 0.12%\nEletropaulo \nMetropolitana\nEletricidade de S\u00e3o\nPaulo SA\nS\u00e3o Paulo BR 3,079,524,934.33 BRL Line-by-line Enel Brasil SA 100.00% 82.27%\nElini Antwerp BE 76,273,810.00 EUR -\nSlovensk\u00e9\nelektr\u00e1rne AS\n4.00% 1.32%\nEmerging Networks El\nSalvador SA de Cv\nSan Salvador SV 2,000.00 USD Equity\nLivister Guatemala\nSA\n1.00%\n20.60%\nLivister Latam SLU 99.00%\nEmerging Networks\nLatam Inc.\nWilmington US 100.00 USD Equity Ifx Networks Ltd 100.00% 20.60%\nEmerging Networks\nPanama SA\nPanama City PA 300.00 USD Equity\nIfx/eni - Spc\nPanama Inc.\n100.00% 20.60%\nEmgesa SA ESP Bogot\u00e1 CO 655,222,312,800.00 COP Line-by-line Enel Am\u00e9ricas SA 48.48% 39.89%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nEmintegral Cycle SLU Madrid ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nEmpresa Carbon\u00edfera\ndel Sur SA\nMadrid ES 18,030,000.00 EUR Line-by-line\nEndesa\nGeneraci\u00f3n SA\n100.00% 70.11%\nEmpresa de Alumbrado\nEl\u00e9ctrico de Ceuta\nDistribuci\u00f3n SA\n(Sociedad Unipersonal)\nCeuta ES 9,335,000.00 EUR Line-by-line\nEmpresa de\nAlumbrado\nEl\u00e9ctrico de Ceuta\nSA\n100.00% 67.59%\nEmpresa de Alumbrado\nEl\u00e9ctrico de Ceuta SA\nCeuta ES 16,562,250.00 EUR Line-by-line\nEndesa Red \nSA (Sociedad\nUnipersonal)\n96.41% 67.5 9%\nEmpresa de\nGeneraci\u00f3n El\u00e9ctrica \nLos Pinos SA\nSan Miguel PE 7,928,044.00 PEN Line-by-line\nEnel Green Power\nPer\u00fa SAC\n100.00%\n82.27%\nEnerg\u00e9tica \nMonz\u00f3n SAC\n0.00%\nEmpresa de\nGeneraci\u00f3n El\u00e9ctrica \nMarcona SAC\nSan Miguel PE 3,368,424.00 PEN Line-by-line\nEnel Green Power\nPer\u00fa SAC\n100.00%\n82.27%\nEnerg\u00e9tica \nMonz\u00f3n SAC \n0.00%\nEmpresa Distribuidora\nSur SA - Edesur\nBuenos Aires AR 898,585,028.00 ARS Line-by-line\nDistrilec Inversora\nSA\n56.36%\n59.33%\nEnel Argentina SA 43.10%\nEmpresa El\u00e9ctrica \nPehuenche SA\nSantiago de\nChile\nCL 175,774,920,733.00 CLP Line-by-line\nEnel Generaci\u00f3n\nChile SA\n92.65% 56.27%\nEmpresa Propietaria de\nla Red SA\nPanama City PA 58,500,000.00 USD - Enel SpA 11.11% 11.11%\nEndesa Capital SA Madrid ES 60,200.00 EUR Line-by-line Endesa SA 100.00% 70.11%\nEndesa\nComercializa\u00e7\u00e3o de\nEnergia SA\nPo\ue61fo PT 250,000.00 EUR Line-by-line Endesa Energ\u00eda SA 100.00% 70.11%\nEndesa Energ\u00eda\nRenovable SL\n(Sociedad Unipersonal)\nMadrid ES 100,000.00 EUR Line-by-line Endesa Energ\u00eda SA 100.00% 70.11%\nEndesa Energ\u00eda SA Madrid ES 14,445,575.90 EUR Line-by-line Endesa SA 100.00% 70.11%\nEndesa Financiaci\u00f3n\nFiliales SA\nMadrid ES 4,621,003,006.00 EUR Line-by-line Endesa SA 100.00% 70.11%\nEndesa Generaci\u00f3n\nII SA\nSeville ES 63,107.00 EUR Line-by-line Endesa SA 100.00% 70.11%\nEndesa Generaci\u00f3n\nNuclear SA\nSeville ES 60,000.00 EUR Line-by-line\nEndesa\nGeneraci\u00f3n SA\n100.00% 70.11%\nEndesa Generaci\u00f3n\nPo\ue61fugal SA\nLisbon PT 50,000.00 EUR Line-by-line\nEndesa Energ\u00eda SA 0.20%\n70.11%\nEndesa\nGeneraci\u00f3n SA\n99.20%\nEnel Green Power\nEspa\u00f1a SLU\n0.60%\nEndesa Generaci\u00f3n SA Seville ES 1,940,379,735.35 EUR Line-by-line Endesa SA 100.00% 70.11%\nEndesa Ingenier\u00eda SLU Seville ES 965,305.00 EUR Line-by-line\nEndesa Red \nSA (Sociedad\nUnipersonal)\n100.00% 70.11%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nProyectos y Soluciones\nRenovables SAC\nSan Miguel PE 1,000.00 PEN Line-by-line\nEnel Green Power\nPa\ue61fecipazioni\nSpeciali Srl\n99.90%\n99.98%\nEnerg\u00eda y Servicios\nSouth America\nSpA\n0.10%\nPSG Energy Private\nLimited\nHyderabad IN 100,000.00 INR Line-by-line\nEnel Green Power\nIndia Private\nLimited\n100.00% 100.00%\nPT Enel Green Power\nOptima Way Ratai\nJaka\ue61fa ID 10,002,600.00 USD Line-by-line\nEnel Green Power\nSpA\n90.00% 90.00%\nPue\ue61fo Santa Mar\u00eda\nEnerg\u00eda I SLU\nMadrid ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nPue\ue61fo Santa Mar\u00eda\nEnerg\u00eda II SLU\nMadrid ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nPulida Energy (RF)\n(Pty) Ltd\nJohannesburg ZA 10,000,000.00 ZAR Line-by-line\nEnel Green Power\nRSA (Pty) Ltd\n52.70% 52.70%\nPumpkin Vine Wind\nProject LLC\nAndover US - USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nQuatiara Energia SA Niter\u00f3i BR 13,766,118.96 BRL Line-by-line Enel Brasil SA 100.00% 82.27%\nQueens Energy\nStorage LLC\nAndover US - USD Line-by-line\nEnel Energy\nStorage Holdings\nLLC (formerly EGP\nEnergy Storage\nHoldings LLC)\n100.00% 100.00%\nRaleigh Solar I LLC Andover US 1.00 USD Line-by-line\nBrick Road Solar\nHoldings LLC\n100.00% 100.00%\nRanchland Solar \nProject LLC\nAndover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nRanchland Wind\nHoldings LLC\nAndover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nRanchland Wind\nProject II LLC\nAndover US 1.00 USD Line-by-line\nRanchland Wind\nHoldings LLC\n100.00% 100.00%\nRanchland Wind\nProject LLC\nAndover US - USD Line-by-line\nRockhaven\nRanchland\nHoldings LLC\n100.00% 100.00%\nRanchland Wind\nStorage LLC\nAndover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nRa\ue61clesnake Creek\nHoldings LLC\nDelaware US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nRausch Creek Wind\nProject LLC\nAndover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nRC Wind Srl Milan IT 10,000.00 EUR -\nEnel Green Power\nItalia Srl\n0.50% 0.50%\nRE Arroyo LLC Andover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nReakto\ue61fest SRO Trnava SK 66,389.00 EUR Equity\nSlovensk\u00e9\nelektr\u00e1rne AS\n49.00% 16.17%\nRed Centroamericana \nde Telecomunicaciones \nSA\nPanama City PA 2,700,000.00 USD - Enel SpA 11.11% 11.11%\nRed Di\ue61f Wind Holdings \nI LLC\nDover US 100.00 USD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nRed Di\ue61f Wind Holdings \nLLC\nWilmington US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nRed Di\ue61f Wind Project\nLLC\nDover US 1.00 USD Line-by-line\nRed Di\ue61f Wind \nHoldings LLC\n100.00% 100.00%\nRed Fox Wind Project \nLLC\nWilmington US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nRedes y \nTelecomunicaciones S \nde RL de Cv\nSan Pedro Sula HN 82,395,000.00 HNL - Livister Latam SLU 80.00% 16.48%\nRenovables Andorra \nSLU\nMadrid ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nRenovables de\nGuatemala SA\nGuatemala City GT 1,924,465,600.00 GTQ Line-by-line\nEnel Green Power\nGuatemala SA\n0.00%\n82.27%\nESSA2 SpA 100.00%\nRenovables La Pedrera\nSLU\nZaragoza ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nRenovables\nManzanares 400 kV SL\nMadrid ES 5,000.00 EUR Equity\nEnel Green Power\nEspa\u00f1a SLU\n27.86% 19.53%\nRenovables Mediavilla\nSLU\nZaragoza ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nRenovables Teruel SLU Madrid ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nRiverbend Farms Wind\nProject LLC\nAndover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nRiverview LP Albe\ue61fa CA - CAD Line-by-line\nEnel Albe\ue61fa Wind\nInc.\n99.00%\n100.00%\nEnel Green Power\nCanada Inc. \n1.00%\nRiverview Solar I LLC Andover US 1.00 USD Line-by-line\nBrick Road Solar\nHoldings LLC\n100.00% 100.00%\nRoadrunner Solar\nProject LLC\nAndover US 100.00 USD Line-by-line\nEnel Roadrunner\nSolar Project \nHoldings LLC\n100.00% 100.00%\nRoadrunner Storage\nLLC\nAndover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nRochelle Solar LLC Coral Springs US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nRock Creek Wind\nHoldings I LLC\nDover US 100.00 USD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nRock Creek Wind\nHoldings II LLC\nDover US 100.00 USD Line-by-line\nRock Creek Wind\nHoldings LLC\n100.00% 100.00%\nRock Creek Wind\nHoldings LLC\nWilmington US - USD Line-by-line\nEGPNA Preferred\nWind Holdings\nII LLC\n100.00% 100.00%\nRock Creek Wind\nProject LLC\nClayton US 1.00 USD Line-by-line\nRock Creek Wind\nHoldings LLC\n100.00% 100.00%\nRockhaven Ranchland \nHoldings LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nRockhaven Wind\nProject LLC\nAndover US 1.00 USD Line-by-line\nRockhaven\nRanchland\nHoldings LLC\n100.00% 100.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nRocky Caney Holdings\nLLC\nOklahoma City US 1.00 USD Equity Enel Kansas LLC 20.00% 20.00%\nRocky Caney Wind LLC Albany US - USD Equity\nRocky Caney\nHoldings LLC\n100.00% 20.00%\nRocky Ridge Wind \nProject LLC\nOklahoma City US - USD Equity\nRocky Caney Wind\nLLC \n100.00% 20.00%\nRodnikovskaya WPS Moscow RU 6,010,000.00 RUB Line-by-line\nEnel Green Power\nRus Limited\nLiability Company\n100.00% 100.00%\nRoha Renewables India\nPrivate Limited\nGurugram IN 100,000.00 INR Line-by-line\nEnel Green Power\nIndia Private\nLimited\n100.00% 100.00%\nRolling Farms Wind \nProject LLC\nAndover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nRusenergosbyt LLC Moscow RU 18,000,000.00 RUB Equity Enel SpA 49.50% 49.50%\nRusenergosbyt Siberia\nLLC\nKrasnoyarsk\nCity\nRU 4,600,000.00 RUB Equity\nRusenergosbyt\nLLC \n50.00% 24.75%\nRustler Wind Project\nLLC\nAndover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nRuthton Ridge LLC Minneapolis US - USD Line-by-line\nChi Minnesota\nWind LLC\n51.00% 51.00%\nSaburoy SA Montevideo UY 100,000.00 UYU Equity Ifx Networks LLC 100.00% 20.60%\nSacme SA Buenos Aires AR 12,000.00 ARS Equity\nEmpresa\nDistribuidora Sur\nSA - Edesur\n50.00% 29.66%\nSaddle House Solar\nProject LLC\nAndover US - USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nSalmon Falls Hydro LLC Wilmington US - USD AFS\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nSalt Springs Wind\nProject LLC\nAndover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nSalto de San Rafael SL Seville ES 462,185.98 EUR Equity\nEnel Green Power\nEspa\u00f1a SLU\n50.00% 35.06%\nSan Francisco de\nBorja SA\nZaragoza ES 60,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n66.67% 46.74%\nSan Juan Mesa Wind\nProject II LLC\nWilmington US - USD Line-by-line\nPadoma Wind\nPower LLC\n100.00% 100.00%\nSanosari Energy Private\nLimited\nGurugram IN 100,000.00 INR Line-by-line\nAvikiran Energy\nIndia Private\nLimited\n100.00% 100.00%\nSanto Rostro \nCogeneraci\u00f3n SA\nSeville ES 207,340.00 EUR Equity\nEnel Green Power\nEspa\u00f1a SLU\n45.00% 31.55%\nSardhy Green\nHydrogen Srl \nSarroch IT 10,000.00 EUR Equity\nEnel Green Power\nItalia Srl\n50.00% 50.00%\nSaugus River Energy \nStorage LLC\nDover US 100.00 USD Line-by-line\nEnel Energy\nStorage Holdings\nLLC (formerly EGP\nEnergy Storage\nHoldings LLC)\n100.00% 100.00%\nSavanna Power Solar\n10 SLU\nMadrid ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nSavanna Power Solar\n12 SLU\nSeville ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nSavanna Power Solar\n13 SLU\nSeville ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nSavanna Power Solar\n4 SLU\nMadrid ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nSavanna Power Solar\n5 SLU\nMadrid ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nSavanna Power Solar\n6 SLU\nMadrid ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nSavanna Power Solar\n9 SLU\nMadrid ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nSe Slu\u017eby In\u017einierskych\nStavieb SRO\nKaln\u00e1 Nad\nHronom\nSK 200,000.00 EUR Equity\nSlovensk\u00e9\nelektr\u00e1rne AS\n100.00% 33.00%\nSeguidores Solares\nPlanta 2 SL (Sociedad\nUnipersonal)\nMadrid ES 3,010.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nServicio de Operaci\u00f3n\ny Mantenimiento para\nEnerg\u00edas Renovables S\nde RL de Cv\nMexico City MX 3,000.00 MXN Line-by-line\nEnel Green Power\nGuatemala SA\n0.01%\n99.99%\nEnerg\u00eda Nueva\nEnerg\u00eda Limpia\nM\u00e9xico S de RL\nde Cv\n99.99%\nServicios de Internet \nEni Chile Ltda\nSantiago de\nChile\nCL 2,768,688,228.00 CLP Equity\nIfx Networks Ltd 0.10%\n20.60%\nIfx/eni - Spc IV Inc. 99.90%\nServizio Ele\ue61crico\nNazionale SpA\nRome IT 10,000,000.00 EUR Line-by-line Enel Italia SpA 100.00% 100.00%\nSetyl Srl Bergamo IT 100,000.00 EUR Equity Enel X Italia Srl 27.50% 27.50%\nSeven Cowboy Wind\nProject Holdings LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nSeven Cowboy Wind\nProject II LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nSeven Cowboy Wind\nProject LLC\nAndover US 1.00 USD Line-by-line\nSeven Cowboy\nWind Project\nHoldings LLC\n100.00% 100.00%\nSeven Cowboys Solar\nProject LLC\nAndover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nShiawassee Wind \nProject LLC\nWilmington US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nShield Energy Storage\nProject LLC\nWilmington US - USD Line-by-line\nEnel Energy\nStorage Holdings\nLLC (formerly EGP\nEnergy Storage\nHoldings LLC)\n100.00% 100.00%\nShikhar Surya (One)\nPrivate Limited\nGurugram IN 10,100,000.00 INR Line-by-line\nEnel Green Power\nIndia Private\nLimited\n100.00% 100.00%\nSIET - Societ\u00e0\nInformazioni\nEsperienze\nTermoidrauliche SpA\nPiacenza IT 697,820.00 EUR Equity\nEnel Innovation \nHubs Srl\n41.55% 41.55%\nSilt Solar I LLC Andover US 1.00 USD Line-by-line\nBrick Road Solar\nHoldings LLC\n100.00% 100.00%\n\n5.05%\nSAS\nInversora Codensa\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nSilver Dollar Solar \nProject LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nSinergia GP6 Srl Rome IT 10,000.00 EUR Equity\nEnel Green Power\nItalia Srl\n100.00% 100.00%\nSinergia GP7 Srl Rome IT 10,000.00 EUR Equity\nEnel Green Power\nItalia Srl\n100.00% 100.00%\nSistema El\u00e9ctrico de \nConexi\u00f3n Valcaire SL\nMadrid ES 175,200.00 EUR Equity\nEnel Green Power\nEspa\u00f1a SLU\n28.13% 19.72%\nSistemas Energ\u00e9ticos\nMa\u00f1\u00f3n O\ue61figueira SA\nLa Coru\u00f1a ES 2,007,750.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n96.00% 67.31%\nSkyview Wind Project \nLLC\nAndover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nSleep Hollow Solar\nI LLC\nAndover US 1.00 USD Line-by-line\nBrick Road Solar\nHoldings LLC\n100.00% 100.00%\nSlovak Power Holding\nBV\nAmsterdam NL 25,010,000.00 EUR Equity\nEnel Produzione \nSpA\n50.00% 50.00%\nSlovensk\u00e9\nelektr\u00e1rne -\nEnergetick\u00e9\nSlu\u017eby SRO\nBratislava SK 4,505,000.00 EUR Equity\nSlovensk\u00e9\nelektr\u00e1rne AS\n100.00% 33.00%\nSlovensk\u00e9 elektr\u00e1rne\nAS\nBratislava SK 1,269,295,724.66 EUR Equity\nSlovak Power\nHolding BV\n66.00% 33.00%\nSlovensk\u00e9\nelektr\u00e1rne \u010cesk\u00e1\nRepublika SRO\nMoravsk\u00e1\nOstrava \nCZ 295,819.00 CZK Equity\nSlovensk\u00e9\nelektr\u00e1rne AS\n100.00% 33.00%\nSmoky Hill Holdings\nII LLC\nWilmington US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nSmoky Hills Wind Farm\nLLC\nTopeka US - USD Line-by-line\nEGPNA Project\nHoldCo 1 LLC\n100.00% 100.00%\nSmoky Hills Wind\nProject II LLC\nLenexa US - USD Line-by-line\nEGPNA Project\nHoldCo 1 LLC\n100.00% 100.00%\nSnyder Wind Farm LLC Hermleigh US - USD Line-by-line Texkan Wind LLC 100.00% 100.00%\nSocibe Energia SA Niter\u00f3i BR 12,969,032.25 BRL Line-by-line Enel Brasil SA 100.00% 82.27%\nSociedad Agr\u00edcola de\nCameros Ltda\nSantiago de\nChile\nCL 5,738,046,495.00 CLP Line-by-line Enel Chile SA 57.50% 37.33%\nSociedad de\nInversiones K Cuatro\nSpA\nSantiago de\nChile\nCL 316,318,800.00 CLP - Enel X Chile SpA 10.00% 6.49%\nSociedad E\u00f3lica de\nAndaluc\u00eda SA\nSeville ES 4,507,590.78 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n64.75% 45.40%\nSociedad E\u00f3lica El\nPuntal SL\nSeville ES 1,643,000.00 EUR Equity\nEnel Green Power\nEspa\u00f1a SLU\n50.00% 35.06%\nSociedad E\u00f3lica Los\nLances SA\nSeville ES 2,404,048.42 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n60.00% 42.07%\nSociedad para el\nDesarrollo de Sierra\nMorena Cordobesa SA\nCordoba ES 86,063.20 EUR -\nEndesa\nGeneraci\u00f3n SA\n1.82% 1.27%\nSociedad Po\ue61fuaria\nCentral Ca\ue61fagena SA\nBogot\u00e1 CO 89,714,600.00 COP Line-by-line\nEmgesa SA ESP 94.94%\n39.87%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nSociet\u00e0 Ele\ue61crica Trigno\nSrl\nTrivento IT 100,000.00 EUR Line-by-line\nEnel Green Power\nItalia Srl\n100.00% 100.00%\nSoetwater Wind Farm \n(RF) (Pty) Ltd\nJohannesburg ZA 1,000.00 ZAR AFS\nEnel Green Power\nRSA 2 (RF) (Pty) Ltd\n55.00% 55.00%\nSolana Renovables SL Madrid ES 5,000.00 EUR Equity\nEnel Green Power\nEspa\u00f1a SLU\n49.84% 34.94%\nSolas Electricity Srl Bucharest RO 740,000.00 RON Line-by-line\nEnel Green Power\nRomania Srl\n100.00% 100.00%\nSoliloquoy Ridge LLC Minneapolis US - USD Line-by-line\nChi Minnesota\nWind LLC\n51.00% 51.00%\nSomerswo\ue61fh Hydro\nCompany Inc.\nWilmington US 100.00 USD AFS\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nSona Enerj\u00ed\n\u00dcret\u00edm Anon\u00edm\n\u015e\u00edrket\u00ed\nIstanbul TR 50,000.00 TRY Line-by-line\nEnel Green Power\nTurkey Enerj\u00ed\nYatirimlari Anon\u00edm\n\u015e\u00edrket\u00ed\n100.00% 100.00%\nSonak Solar Project\nLLC\nAndover US - USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nSotavento Galicia SA\nSantiago de\nCompostela\nES 601,000.00 EUR Equity\nEnel Green Power\nEspa\u00f1a SLU\n36.00% 25.24%\nSouth Italy Green \nHydrogen Srl \nRome IT 10,000.00 EUR Equity\nEnel Green Power\nItalia Srl\n50.00% 50.00%\nSouth Rock Wind \nProject LLC\nAndover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nSouth Wind Energy Srl Bucharest RO 2,000.00 RON Line-by-line\nEnel Green Power\nRomania Srl\n100.00% 100.00%\nSouthwest \nTransmission LLC\nCedar Blu\ue61b US - USD Line-by-line\nChi Minnesota\nWind LLC\n100.00% 100.00%\nSpa\ue61fan Hills LLC Minneapolis US - USD Line-by-line\nChi Minnesota\nWind LLC\n51.00% 51.00%\nSpinazzola SPV Srl Rome IT 10,000.00 EUR Line-by-line\nEnel Green Power\nItalia Srl\n100.00% 100.00%\nSpring Wheat Solar\nProject LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nStampede Solar\nProject LLC\nAndover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nSterling and Wilson\nEnel X e-Mobility\nPrivate Limited\nMumbai IN 90,000,000.00 INR Equity\nEnel X\nInternational Srl\n50.00% 50.00%\nStillman Valley Solar \nLLC\nWilmington US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nStillwater Woods Hill \nHoldings LLC\nWilmington US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nStipa Naya\u00e1 SA de Cv Mexico City MX 1,811,016,348.00 MXN Line-by-line\nEnel Green Power\nM\u00e9xico S de RL\nde Cv\n55.21%\n95.37%\nEnel Green Power\nPa\ue61fecipazioni\nSpeciali Srl\n40.16%\nStockyard Solar Project \nLLC\nAndover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nStrinestown Solar I LLC Andover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nSuave Energ\u00eda S de RL\nde Cv\nMexico City MX 1,000.00 MXN Line-by-line\nEnel Green Power\nM\u00e9xico S de RL\nde Cv\n0.10%\n100.00%\nEnel Rinnovabile \nSA de Cv\n99.90%\nSublunary Trading (RF)\n(Pty) Ltd\nBryanston ZA 13,750,000.00 ZAR Line-by-line\nEnel Green Power\nRSA (Pty) Ltd\n57.00% 57.00%\nSugar Pine Solar\nProject LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nSuggestion Power\n(Unipessoal) Ltda\nPa\u00e7o de Arcos PT 50,000.00 EUR Line-by-line\nEndesa\nGeneraci\u00f3n\nPo\ue61fugal SA\n100.00% 70.11%\nSuministradora de \nbuses K Cuatro SpA\nSantiago de\nChile\nCL 14,840,473,200.00 CLP -\nSociedad de\nInversiones K\nCuatro SpA\n99.00% 6.43%\nSuministradora \nEl\u00e9ctrica de C\u00e1diz SA\nCadiz ES 12,020,240.00 EUR Equity\nEndesa Red \nSA (Sociedad\nUnipersonal)\n33.50% 23.49%\nSuministro de Luz y \nFuerza SL\nBarcelona ES 2,800,000.00 EUR Line-by-line\nHidroel\u00e9ctrica de \nCatalunya SL\n60.00% 42.07%\nSummit Energy\nStorage Inc.\nWilmington US 1,000.00 USD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n75.00% 75.00%\nSun River LLC Bend US - USD Line-by-line\nChi Minnesota\nWind LLC\n51.00% 51.00%\nSundance Wind\nProject LLC\nDover US 100.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nSun\ue618ower Prairie Solar\nProject LLC\nAndover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nSwather Solar Project\nLLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nSweet Apple Solar \nProject LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nTae Technologies Inc. Pauling US 53,207,936.00 USD -\nEnel Produzione \nSpA\n1.12%\n1.12%\nTae Technologies\nInc.\n0.00%\nTauste Energ\u00eda\nDistribuida SL\nZaragoza ES 60,508.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n51.00% 35.76%\nTecnatom SA Madrid ES 4,025,700.00 EUR Equity\nEndesa\nGeneraci\u00f3n SA\n45.00% 31.55%\nTecnoguat SA Guatemala City GT 30,948,000.00 GTQ Line-by-line ESSA2 SpA 75.00% 61.70%\nTejo Energia\n- Produ\u00e7\u00e3o e\nDistribui\u00e7\u00e3o de\nEnergia El\u00e9ctrica\nSA\nLisbon PT 5,025,000.00 EUR Equity\nEndesa\nGeneraci\u00f3n SA\n43.75% 30.67%\nTenedora de Energ\u00eda\nRenovable Sol y Viento\nSAPI de Cv\nMexico City MX 2,892,643,576.00 MXN Equity\nEnel Green Power\nSpA\n32.89% 32.90%\nTeploprogress JSC Sredneuralsk RU 128,000,000.00 RUB Line-by-line Enel Russia PJSC 60.00% 33.86%\nTera Renewables India\nPrivate Limited\nGurugram IN 100,000.00 INR Line-by-line\nEnel Green Power\nIndia Private\nLimited\n100.00% 100.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nTermica Colleferro SpA Bologna IT 6,100,000.00 EUR Equity Cogenio Srl 60.00% 12.00%\nTermoel\u00e9ctrica Jos\u00e9 de\nSan Ma\ue61f\u00edn SA\nBuenos Aires AR 7,078,298.00 ARS -\nCentral Dock\nSud SA\n0.42%\n4.22%\nEnel Generaci\u00f3n\nCostanera SA\n1.68%\nEnel Generaci\u00f3n El\nChoc\u00f3n SA\n5.60%\nTermoel\u00e9ctrica Manuel \nBelgrano SA\nBuenos Aires AR 7,078,307.00 ARS -\nCentral Dock\nSud SA\n0.47%\n4.71%\nEnel Generaci\u00f3n\nCostanera SA\n1.89%\nEnel Generaci\u00f3n El\nChoc\u00f3n SA\n6.23%\nTermotec Energ\u00eda AIE\nin liquidation\nLa Pobla de\nVallbona\nES 481,000.00 EUR Equity\nEnel Green Power\nEspa\u00f1a SLU\n45.00% 31.55%\nTerrer Renovables SL Madrid ES 5,000.00 EUR Equity\nBaylio Solar SLU 11.66%\n20.73%\nDehesa de los\nGuadalupes Solar\nSLU \n8.83%\nSeguidores\nSolares Planta\n2 SL (Sociedad\nUnipersonal)\n9.08%\nTesting Stand of\nIvanovskaya GRES JSC\nKomsomolsk RU 118,213,473.45 RUB - Enel Russia PJSC 1.65% 0.93%\nTexkan Wind LLC Andover US - USD Line-by-line Enel Texkan Inc. 100.00% 100.00%\nThar Surya 1 Private\nLimited\nGurgaon IN 100,000.00 INR Line-by-line\nAvikiran Surya\nIndia Private\nLimited\n100.00% 100.00%\nThunder Ranch Wind\nHoldings I LLC\nDover US 100.00 USD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nThunder Ranch Wind\nHoldings LLC\nWilmington US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nThunder Ranch Wind\nProject LLC\nDover US 1.00 USD Line-by-line\nThunder Ranch\nWind Holdings\nLLC \n100.00% 100.00%\nThunderegg Wind\nProject LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nTico Solar 1 SLU Zaragoza ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nTico Solar 2 SLU Zaragoza ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nTobivox (RF) (Pty) Ltd Johannesburg ZA 10,000,000.00 ZAR Line-by-line\nEnel Green Power\nRSA (Pty) Ltd\n60.00% 60.00%\nToledo PV AIE Madrid ES 26,887.96 EUR Equity\nEnel Green Power\nEspa\u00f1a SLU\n33.33% 23.37%\nToplet Power Park Srl Bucharest RO 2,000.00 RON Line-by-line\nEnel Green Power\nRomania Srl\n100.00% 100.00%\nTopwind Energy Srl Bucharest RO 2,000.00 RON Line-by-line\nEnel Green Power\nRomania Srl\n100.00% 100.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nToro Renovables 400\nkV SL\nMadrid ES 3,000.00 EUR -\nFRV Zamora Solar \n1 SLU\n8.28% 5.81%\nTorrepalma Energy\n1 SLU\nMadrid ES 3,100.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nTradewind Energy Inc. Wilmington US 1,000.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nTransmisora de Energ\u00eda\nRenovable SA\nGuatemala City GT 233,561,800.00 GTQ Line-by-line\nEnel Green Power\nGuatemala SA\n0.00%\n82.27%ESSA2 SpA 100.00%\nGeneradora\nMontecristo SA\n0.00%\nTranspo\ue61fadora de\nEnerg\u00eda SA-TESA\nBuenos Aires AR 2,584,473,416.00 ARS Line-by-line\nEnel Argentina SA 0.00%\n82.27%\nEnel Brasil SA 60.15%\nEnel CIEN SA 39.85%\nTranspo\ue61fes y\nDistribuciones\nEl\u00e9ctricas SA in\nliquidation\nGirona ES 72,121.45 EUR Line-by-line\nEdistribuci\u00f3n\nRedes Digitales\nSL (Sociedad\nUnipersonal)\n73.33% 51.42%\nTr\u00e9vago Renovables SL Madrid ES 3,000.00 EUR Equity\nFuratena Solar \n1 SLU\n17.73 %\n24.89%\nSeguidores\nSolares Planta\n2 SL (Sociedad\nUnipersonal)\n17.77%\nTsar Nicholas LLC Minneapolis US - USD Line-by-line\nChi Minnesota\nWind LLC\n51.00% 51.00%\nTula WPS LLC Tula RU - RUB Line-by-line\nEnel Green Power\nRus Limited\nLiability Company\n100.00% 100.00%\nTulip Grove Solar\nProject LLC\nAndover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nTunga Renewable\nEnergy Private Limited\nGurugram IN 19,100,000.00 INR Line-by-line\nAvikiran Energy\nIndia Private\nLimited\n100.00% 100.00%\nTWE Franklin Solar\nProject LLC\nAndover US - USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nTWE ROT DA LLC Andover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nTwin Lake Hills LLC Minneapolis US - USD Line-by-line\nChi Minnesota\nWind LLC\n51.00% 51.00%\nTwin Saranac Holdings\nLLC\nWilmington US - USD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nTyme Srl Bergamo IT 100,000.00 EUR Equity Enel X Italia Srl 50.00% 50.00%\nU\ue61enet Argentina SA Buenos Aires AR 9,745,583.00 ARS Equity\nU\ue61enet Latam SLU 99.95%\n20.60%\nU\ue61enet Panam\u00e1 SA 0.05%\nU\ue61enet Brasil\nPa\ue61ficipa\u00e7\u00f5es Ltda\nSanto Andr\u00e9 BR 120,784,639.00 BRL Equity\nZacapa Topco\nII S\u00e0rl\n100.00% 50.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nU\ue61enet Brasil SA Barueri BR 29,800,000.00 BRL Equity\nU\ue61enet Brasil\nTelecomunica\u00e7\u00e3o \nLtda\n60.00% 30.00%\nU\ue61enet Brasil\nTelecomunica\u00e7\u00e3o Ltda\nSanto Andr\u00e9 BR 120,784,638.00 BRL Equity\nU\ue61enet Brasil\nPa\ue61ficipa\u00e7\u00f5es Ltda\n100.00%\n50.00%\nU\ue61enet Latam SLU 0.00%\nU\ue61enet Chile SpA\nSantiago de\nChile\nCL 233,750,000.00 CLP Equity U\ue61enet Latam SLU 100.00% 20.60%\nU\ue61enet Colombia\nPa\ue61ficipaciones SAS\nBogot\u00e1 CO 10,001,001,000.00 COP Equity U\ue61enet Latam SLU 100.00% 20.60%\nU\ue61enet Colombia SA Bogot\u00e1 CO 1,180,000,000.00 COP Equity\nU\ue61enet Guatemala \nSA\n0.00%\n18.54%\nU\ue61enet Honduras \nSA\n0.00%\nU\ue61enet Latam SLU 90.00%\nU\ue61enet Panam\u00e1 SA 0.00%\nU\ue61enet Costa Rica SA San Jos\u00e9 CR 25,000.00 USD Equity U\ue61enet Latam SLU 100.00% 20.60%\nU\ue61enet Ecuador U\ue61eec\nSA\nQuito EC 9,865,110.00 USD Equity\nU\ue61enet Guatemala \nSA\n0.00%\n20.60%\nU\ue61enet Latam SLU 100.00%\nU\ue61enet El Salvador SA\nde Cv\nSan Salvador SV 10,000.00 USD Equity\nU\ue61enet Guatemala \nSA\n0.01%\n20.60%\nU\ue61enet Latam SLU 99.99%\nU\ue61enet FTTH Guatemala\nLtda\nGuatemala City GT 50,000.00 GTQ - U\ue61enet Latam SLU 51.00% 10.51%\nU\ue61enet Guatemala SA Guatemala City GT 3,000,000.00 GTQ Equity\nU\ue61enet Latam SLU 99.99%\n20.60%\nU\ue61enet Panam\u00e1 SA 0.01%\nU\ue61enet Honduras SA Tegucigalpa HN 194,520.00 HNL Equity\nU\ue61enet Latam SLU 99.99%\n20.60%\nU\ue61enet Panam\u00e1 SA 0.01%\nU\ue61enet Latam SLU Madrid ES 15,906,312.00 EUR Equity Zacapa S\u00e0rl 100.00% 20.60%\nU\ue61enet M\u00e9xico S de RL\nde Cv\nMexico City MX 7,635,430.00 MXN Equity\nU\ue61enet Guatemala \nSA\n1.31%\n20.60%\nU\ue61enet Latam SLU 98.69%\nU\ue61enet Nicaragua SA Managua NI 2,800,000.00 NIO Equity\nU\ue61enet Guatemala \nSA\n0.50%\nUfinet Latam SLU 99.00% 20.60%\nU\ue61enet Panam\u00e1 SA 0.50%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nU\ue61enet Panam\u00e1 SA Panama City PA 1,275,000.00 USD Equity U\ue61enet Latam SLU 100.00% 20.60%\nU\ue61enet Paraguay SA Asunci\u00f3n PY 79,488,240,000.00 PYG Equity U\ue61enet Latam SLU 75.00% 15.45%\nU\ue61enet Per\u00fa SAC Lima PE 2,836,474.00 PEN Equity\nU\ue61enet Latam SLU 100.00%\n20.60%\nU\ue61enet Panam\u00e1 SA 0.00%\nU\ue61enet US LLC Wilmington US 1,000.00 USD Equity U\ue61enet Latam SLU 100.00% 20.60%\nUkuqala Solar\nProprietary Limited\nJohannesburg ZA 1,000.00 ZAR Line-by-line\nEnel Green Power\nRSA (Pty) Ltd\n100.00% 100.00%\nUni\u00f3n El\u00e9ctrica de\nCanarias Generaci\u00f3n \nSAU\nLas Palmas de\nGran Canaria\nES 190,171,520.00 EUR Line-by-line\nEndesa\nGeneraci\u00f3n SA\n100.00% 70.11%\nUpington Solar (Pty) Ltd Johannesburg ZA 1,000.00 ZAR Line-by-line\nEnel Green Power\nRSA (Pty) Ltd\n100.00% 100.00%\nUSME ZE SAS Bogot\u00e1 CO 104,872,000.00 COP Line-by-line Bogot\u00e1 ZE SAS 100.00% 39.74%\nUstav Jadern\u00e9ho \nV\u00fdzkumu Rez AS\n\u0158e\u017e CZ 524,139,000.00 CZK Equity\nSlovensk\u00e9\nelektr\u00e1rne AS\n27.77% 9. 17%\nValdecaballero Solar SL Madrid ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nVayu (Project 1) Private\nLimited\nGurugram IN 30,000,000.00 INR Line-by-line\nEnel Green Power\nIndia Private\nLimited\n100.00% 100.00%\nVekt\u00f6r Enerj\u00ed\n\u00dcret\u00edm Anon\u00edm\n\u015e\u00edrket\u00ed\nIstanbul TR 3,500,000.00 TRY AFS Enel SpA 100.00% 100.00%\nVentos de Santa\n\u00c2ngela Energias\nRenov\u00e1veis SA\nRio de Janeiro BR 7,315,000.00 BRL Line-by-line Enel Brasil SA 100.00% 82.27%\nVentos de Santa\nEsperan\u00e7a Energias\nRenov\u00e1veis SA\nRio de Janeiro BR 4,727,414.00 BRL Line-by-line Enel Brasil SA 100.00% 82.27%\nVentos de Santo\nOrestes Energias\nRenov\u00e1veis SA\nRio de Janeiro BR 1,754,031.00 BRL Line-by-line Enel Brasil SA 100.00% 82.27%\nVentos de S\u00e3o Roque\nEnergias Renov\u00e1veis SA\nRio de Janeiro BR 10,188,722.00 BRL Line-by-line Enel Brasil SA 100.00% 82.27%\nVientos del Altiplano\nSA de Cv\nMexico City MX 1,455,854,094.00 MXN Equity\nTenedora de\nEnerg\u00eda Renovable \nSol y Viento SAPI\nde Cv \n60.80% 20.00%\nVillanueva Solar SA\nde Cv\nMexico City MX 205,316,027.15 MXN Equity\nTenedora de\nEnerg\u00eda Renovable \nSol y Viento SAPI\nde Cv \n60.80% 20.00%\nViruleiros SL\nSantiago de\nCompostela\nES 160,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n67.00% 46.97%\nViva Labs AS Oslo NO 104,724.90 NOK Line-by-line\nEnel X\nInternational Srl\n60.00% 60.00%\nWapella Blu\ue61bs Wind\nProject LLC\nAndover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nWaseca Solar LLC Waseca US - USD Line-by-line\nAurora Distributed\nSolar LLC \n100.00% 74. 13%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nWaypost Solar Project\nLLC\nAndover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nWeber Energy Storage\nProject LLC\nWilmington US - USD Line-by-line\nEnel Energy\nStorage Holdings\nLLC (formerly EGP\nEnergy Storage\nHoldings LLC)\n100.00% 100.00%\nWespire Inc. Boston US 1,625,000.00 USD -\nEnel X No\ue61fh\nAmerica Inc. \n11.21% 11.21%\nWest Faribault Solar\nLLC\nWilmington US - USD Line-by-line\nAurora Distributed\nSolar LLC \n100.00% 74. 13%\nWest Hopkinton Hydro\nLLC\nWilmington US - USD AFS\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nWest Waconia Solar\nLLC\nWilmington US - USD Line-by-line\nAurora Distributed\nSolar LLC \n100.00% 74. 13%\nWestern New York\nWind Corporation\nAlbany US 300.00 USD Line-by-line\nEnel Green Power\nNo\ue61fh America Inc. \n100.00% 100.00%\nWha\ue61fon-El Campo\nSolar Project LLC\nAndover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nWhite Cloud Wind\nHoldings LLC\nAndover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nWhite Cloud Wind\nProject LLC\nAndover US 1.00 USD Line-by-line\nWhite Cloud Wind\nHoldings LLC\n100.00% 100.00%\nWhite Peaks Wind\nProject LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nWhitetail Trails Solar\nProject LLC\nAndover US - USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nWhitney Hill Wind\nPower Holdings LLC\nAndover US 99.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nWhitney Hill Wind\nPower LLC\nAndover US - USD Line-by-line\nWhitney Hill Wind\nPower Holdings \nLLC \n100.00% 100.00%\nWhi\ue61cle\u2019s Ferry Solar\nProject LLC\nAndover US 1.00 USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nWild Run LP Albe\ue61fa CA 10.00 CAD Line-by-line\nEnel Albe\ue61fa Wind\nInc.\n0.10%\n100.00%\nEnel Green Power\nCanada Inc. \n99.90%\nWildcat Flats Wind\nProject LLC\nAndover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nWilderness Range\nSolar Project LLC\nAndover US - USD Line-by-line Enel Kansas LLC 100.00% 100.00%\nWind Belt Transco LLC Andover US 1.00 USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\nWind Energy Green\nPark Srl\nBucharest RO 2,000.00 RON Line-by-line\nEnel Green Power\nRomania Srl\n100.00% 100.00%\nWind Parks Anatolis -\nPrinias Single Member\nSA\nMaroussi GR 15,803,388.00 EUR Line-by-line\nEnel Green Power\nHellas Wind Parks \nSouth Evia Single\nMember SA\n100.00% 100.00%\nWind Parks Bolibas SA Maroussi GR 551,500.00 EUR Equity\nEnel Green Power\nHellas SA\n30.00% 30.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nWind Parks Distomos\nSA\nMaroussi GR 556,500.00 EUR Equity\nEnel Green Power\nHellas SA\n30.00% 30.00%\nWind Parks Folia SA Maroussi GR 424,000.00 EUR Equity\nEnel Green Power\nHellas SA\n30.00% 30.00%\nWind Parks Gagari SA Maroussi GR 389,000.00 EUR Equity\nEnel Green Power\nHellas SA\n30.00% 30.00%\nWind Parks Goraki SA Maroussi GR 551,500.00 EUR Equity\nEnel Green Power\nHellas SA\n30.00% 30.00%\nWind Parks Gourles SA Maroussi GR 555,000.00 EUR Equity\nEnel Green Power\nHellas SA\n30.00% 30.00%\nWind Parks Kafoutsi SA Maroussi GR 551,500.00 EUR Equity\nEnel Green Power\nHellas SA\n30.00% 30.00%\nWind Parks Katharas\nSingle Member SA\nMaroussi GR 19,932,048.00 EUR Line-by-line\nEnel Green Power\nHellas Wind Parks \nSouth Evia Single\nMember SA\n100.00% 100.00%\nWind Parks Kerasias\nSingle Member SA\nMaroussi GR 26,107,790.00 EUR Line-by-line\nEnel Green Power\nHellas Wind Parks \nSouth Evia Single\nMember SA\n100.00% 100.00%\nWind Parks Milias\nSingle Member SA\nMaroussi GR 19,909,374.00 EUR Line-by-line\nEnel Green Power\nHellas Wind Parks \nSouth Evia Single\nMember SA\n100.00% 100.00%\nWind Parks Mitikas \nSingle Member SA\nMaroussi GR 22,268,039.00 EUR Line-by-line\nEnel Green Power\nHellas Wind Parks \nSouth Evia Single\nMember SA\n100.00% 100.00%\nWind Parks Petalo SA Maroussi GR 575,000.00 EUR Equity\nEnel Green Power\nHellas SA\n30.00% 30.00%\nWind Parks Platanos\nSingle Member SA\nMaroussi GR 13,342,867.00 EUR Line-by-line\nEnel Green Power\nHellas Wind Parks \nSouth Evia Single\nMember SA\n100.00% 100.00%\nWind Parks Skoubi SA Maroussi GR 472,000.00 EUR Equity\nEnel Green Power\nHellas SA\n30.00% 30.00%\nWind Parks Spilias\nSingle Member SA\nMaroussi GR 28,267,490.00 EUR Line-by-line\nEnel Green Power\nHellas Wind Parks \nSouth Evia Single\nMember SA\n100.00% 100.00%\nWind Parks\nStrouboulas SA\nMaroussi GR 576,500.00 EUR Equity\nEnel Green Power\nHellas SA\n30.00% 30.00%\nWind Parks Vitalio SA Maroussi GR 361,000.00 EUR Equity\nEnel Green Power\nHellas SA\n30.00% 30.00%\nWind Parks Vourlas SA Maroussi GR 554,000.00 EUR Equity\nEnel Green Power\nHellas SA\n30.00% 30.00%\nWinter\u2019s Spawn LLC Minneapolis US - USD Line-by-line\nChi Minnesota\nWind LLC\n51.00% 51.00%\nWkn Basilicata\nDevelopment PE1 Srl\nRome IT 10,000.00 EUR Line-by-line\nEnel Green Power\nItalia Srl\n100.00% 100.00%\nWoods Hill Solar LLC Wilmington US - USD Line-by-line\nStillwater Woods \nHill Holdings LLC\n100.00% 100.00%\nXaloc Solar SLU Valencia ES 3,000.00 EUR Line-by-line\nEnel Green Power\nEspa\u00f1a SLU\n100.00% 70.11%\nX-bus Italia Srl Milan IT 15,000.00 EUR Equity Enel X Italia Srl 20.00% 20.00%\n\nCompany name Headqua\ue61eers Country Share capital Currency Segment\nConsolidation\nmethod Held by % holding\nGroup %\nholding\nYacylec SA Buenos Aires AR 20,000,000.00 ARS Equity Enel Am\u00e9ricas SA 33.33% 27.4 2 %\nYedesa-Cogeneraci\u00f3n\nSA\nAlmer\u00eda ES 234,394.72 EUR Equity\nEnel Green Power\nEspa\u00f1a SLU\n40.00% 28.04%\nZacapa HoldCo S\u00e0rl Luxembourg LU 76,180,812.49 EUR Equity Zacapa Topco S\u00e0rl 100.00% 20.60%\nZacapa LLC Wilmington US 100.00 USD Equity Zacapa Topco S\u00e0rl 100.00% 20.60%\nZacapa S\u00e0rl Luxembourg LU 82,866,475.04 USD Equity\nZacapa HoldCo\nS\u00e0rl\n100.00% 20.60%\nZacapa Topco II S\u00e0rl Luxembourg LU 12,000.00 EUR Equity\nEnel X\nInternational Srl\n50.00% 50.00%\nZacapa Topco S\u00e0rl Luxembourg LU 30,000,000.00 EUR Equity\nEnel X\nInternational Srl\n20.60% 20.60%\nZephir 3 Constanta Srl Bucharest RO 1,031,260.00 RON Line-by-line\nEnel Green Power\nRomania Srl\n100.00% 100.00%\nZoo Solar Project LLC Andover US - USD Line-by-line\nTradewind Energy \nInc.\n100.00% 100.00%\n",
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"language": "en",
"entity": "scheme:WOCMU6HCI0OJWNPRZS33",
"period": "2021-01-01T00:00:00/2022-01-01T00:00:00"
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"value": "RomeViale Regina Margherita, 137",
"dimensions": {
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"footnote1": {
"value": "(1) The figures for 2020 have been adjusted, for comparative purposes only, to take account of the effects associated with the change in classification connect-
\ned with the fair value measurement of outstanding contracts at the end of the period for the purchase and sale of commodities with physical settlement.
\nThe change in classification had no impact on operating profit. For more details, please see note 7 to these consolidated financial statements.
",
"dimensions": {
"concept": "xbrl:note",
"noteId": "footnote1",
"language": "en"
}
},
"footnote3": {
"value": "(1) For comparative purposes only, in 2020 the component recognized through profit or loss deriving from the remeasurement at fair value of the financial
\nassets connected with service concession arrangements involving distribution operations in Brazil falling within the scope of IFRIC 12 was reclassified from
\nfinancial income to revenue. The latter classification did not have an impact on cash flows from operating activities.
",
"dimensions": {
"concept": "xbrl:note",
"noteId": "footnote3",
"language": "en"
}
},
"footnote5": {
"value": "(3) Of which cash and cash equivalents equal to \u20ac8,858 million at December 31, 2021 (\u20ac5,906 million at December 31, 2020), short-term securities equal to \u20ac88
\nmillion at December 31, 2021 (\u20ac67 million at December 31, 2020) and cash and cash equivalents pertaining to \u201cAssets held for sale\u201d in the amount of \u20ac44
\nmillion at December 31, 2021 (\u20ac29 million at December 31, 2020).
",
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"noteId": "footnote5",
"language": "en"
}
},
"footnote4": {
"value": "(2) Of which cash and cash equivalents equal to \u20ac5,906 million at January 1, 2021 (\u20ac9,029 million at January 1, 2020), short-term securities equal to \u20ac67 million
\nat January 1, 2021 (\u20ac51 million at January 1, 2020) and cash and cash equivalents pertaining to \u201cAssets held for sale\u201d in the amount of \u20ac29 million at January
\n1, 2021.
",
"dimensions": {
"concept": "xbrl:note",
"noteId": "footnote4",
"language": "en"
}
},
"footnote2": {
"value": "(2) For comparative purposes only, \u20ac87 million in 2020 in respect of the component recognized through profit or loss deriving from the remeasurement at fair
\nvalue of the financial assets connected with service concession arrangements involving distribution operations in Brazil falling within the scope of IFRIC 12
\nhave been reclassified from financial income to revenue. The latter classification had an impact of the same amount on operating profit. For more details,
\nplease see note 7 to these consolidated financial statements.
",
"dimensions": {
"concept": "xbrl:note",
"noteId": "footnote2",
"language": "en"
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}