Tariffs for transport services

2023 was the eighth year of the new regulatory period, the term of which has been increased from four to eight years (2016-2023) divided into two sub-periods.

The regulations are included in three Integrated Texts: “Integrated Text of provisions of the Authority for providing electricity transmission and distribution services (TIT)”, Annex A to Resolution 568/2019/R/eel, the “Integrated Text of provisions of the Authority for providing the electricity metering service (TIME)”; Annex B to Resolution 568/2019/R/eel, and the “Integrated Text on provisions of the Authority on the economic conditions for providing connection services (TIC)”, Annex C to Resolution 568/2019/R/eel, published on 27 December 2019.

For the distribution service, ARERA confirmed unbundling of the tariff applied to end customers (the so-called compulsory tariff) from the reference tariff for determination of the constraint on revenue permitted to each company (the reference tariff). The compulsory tariffs for the year 2023 were published with Resolution 720/2022/R/eel for the distribution and metering services for non-domestic customers, with Resolution 719/2022/R/eel for the provision of the transmission service, with Resolution 721/2022/R/eel for provision of the domestic customers network services.

On 16 May 2023, with Resolution 206/2023/R/eel, provisional reference tariffs were published for 2023 for electricity distribution and metering services for distribution companies serving at least 25,000 withdrawal points.

Also note that with Resolution 154/2023/R/eel, published on 11 April 2023, the definitive reference tariffs for 2022 were published.

The regulations in force in the previous regulatory sub-period include:

1. regulatory lag and return on invested capital;
2. extension of regulatory useful life;
3. tariff adjustment criteria: distribution, sale, measurement.

With regard to the first point, ARERA confirmed the method for offsetting the regulatory lag, recognising new investments made for both Distribution and measurement (without backdating).

The criterion based on the increase in the remuneration rate of invested capital recognised for new investments, of 1% (of the year t-2) was replaced by the introduction of recognition in the capital base (so-called RAB) also of investments made in the year t-1, measured on the basis of pre-final data communicated to ARERA. This data will be used to determine the provisional tariffs of reference and will then be replaced by the final data to determine the definitive tariffs of reference published in the initial months of the following year.

In the year t, the ARERA only recognises the remuneration of the invested capital concerning the assets which entered use in the year t-1, without recognising the relevant depreciation rates (which are still recognised in the year t-2).

In the new sub-period, ARERA confirmed the previously established regulatory useful life.

On 23 December 2021, ARERA published Resolution 614/2021/R/com with which it set the criteria for determining the WACC for the 2022 – 2027 period and established the 2022 rate of return on invested capital for the electricity distribution and metering service at 5.2%, also confirmed for year 2023 with resolution 654/2022/R/com.

In terms of operating costs, the new company-based tariff covers the specific costs by means of a national average cost adjustment coefficient, calculated by the ARERA on the basis of actual company costs and on the basis of scale variables.

These costs, when calculating the company-based tariff, according to the definitions of Resolution no. 568/2019, are supplemented by flat rate connection contributions acknowledged throughout Italy, and will be considered as other grants and no longer deducted from operating costs.

Furthermore, the flat rate connection contributions of each company are deducted directly from the invested capital considering them as equal to MV/LV assets.

Updating of the distribution reference tariff after the first year is individual and based on financial increases reported by the companies on the RAB databases. The updating criterion envisages that:

• the portion of the tariff covering operating costs will be updated using the price cap mechanism (with a productivity recovery target of 1.3%);
• the part covering the costs concerning the remuneration of the invested capital will be updated through the deflater of the fixed gross investments, the change in the volume of service provided, the gross investments that are operational and differentiated by level of voltage, effects of dismissals and disposals
• the part covering the depreciation will be updated through the deflater of the fixed gross investments, the change in volume of service provided, the rate of change connected to the reduction in the gross invested capital due to disposal, withdrawal and end of useful lifetime and the rate of change connected to the investments that are now operational.

As regards marketing, ARERA confirmed a single reference tariff that reflects both the costs for managing the network service and marketing costs, with recognition of the specific capital costs also for investments in marketing activities (single all-inclusive company tariff for the distribution and marketing service).

With regard to the transmission tariff, the ARERA confirmed the introduction of a binomial tariff (capacity and consumption) for high voltage customers, and the cost tariff structure for the transmission service to Terna (CTR), also introducing a binomial price. Given the two tariffs, the equalisation mechanism has been confirmed.

The general equalisation mechanisms for distribution and metering costs and revenue for the regulatory cycle in force are:

• equalisation of the revenues from the distribution service;
• equalisation of the revenues from the low-voltage metering service;
• equalisation of the transmission costs;
• equalisation of the value of the difference between effective losses and standard losses.

The purpose of equalising the revenues of the distribution service is to equalise the revenues deriving from the comparison between the revenues billed to users through the compulsory tariff and the distributor’s allowed revenues, calculated through the company’s tariff of reference.

With Resolution 568/2019, ARERA established that the equalisation of the revenues from distribution would be reduced by an amount equal to 50% of the net revenues from the use of the electrical infrastructure for purposes additional to the electric service, recorded at the end of year n-2 should the aforementioned net revenue exceed 0.5% of total recognised revenue.

The equalisation of the transmission costs has the objective of passing the distributor in terms of the cost recognised to Terna for the transmission service (CTR) with what was paid by the end customer based on the compulsory transmission tariff (TRAS).

With circular 21/2023/ETL of 18 May 2023, CSEA invited distributors utilising the individual cost recognition regime to indicate whether or not they wish to make use of the advances mechanism for 2023. areti communicated that it would adhere to this, in a certified email (PEC) sent on 19 May 2023.

On 29 September 2023, the consultation document 423/2023/R/eel was published. Its main aspects involve mechanisms to promote aggregation of distribution companies, rationalisation of high voltage grid assets, the development of incentives to obtain public contributions, reactive energy tariff regulation and updating of the “other specific performance” envisaged in the TIC. The deadline for submission of comments was 27 October 2023.

Following the consultation, ARERA published Resolution 617/2023/R/eel on 27 December 2023, in which it amended, among other things, the incentives for obtaining public contributions. The bonus is equal to 10% of the public contributions collected during the previous year and is ascertained and determined annually by the Authority by 31 October of each year, from 2025 to 2028. Distribution companies must provide the list of public contributions collected by 31 March of the year following the year to which the contribution refers. Bonuses are paid in three equal amounts, unless otherwise ordered and justified by the Authority at the time the economic items are determined, for reasons of liquidity or the overall impact on the tariff.

On 27 December 2023, ARERA published Resolution 616/2023/R/eel with which it approved the tariff regulation for electricity distribution and metering services for 2024-2027, as well as the relative integrated texts for distribution (TIT) and metering (TIME) and for the connection service (TIC). Also note that the TIT was integrated with provisions relative to criteria to recognise costs for companies subject to the ROSS criteria.

With Resolution 449/2020/R/eel of 10 November 2020, the algorithm for calculating the ΔL equalisation relating to the value of the difference between the effective losses and the standard losses starting from the year 2019 was modified; the percentage factor applied for equalisation purposes for commercial losses of electricity on the networks with obligation to connect third parties for the “centre” zone and for the LV voltage level was modified, going from 2% to 1.83%. Table 4 of the TIS was also amended by the same Resolution with effect from 1 January 2021.

On 21 December 2021, ARERA published DCO 602/2021/R/eel in which it proposed, for the 2022-2023 two-year period, the revision of the conventional percentage factors for commercial losses to be applied to distribution companies for equalisation purposes and the revision of the conventional percentage loss factors to be applied for settlement of the dispatching service to end customers as from 1 January 2023. Distribution companies submitted their comments on 31 January 2022.

This consultation procedure concluded with the publication of Resolution 117/2022/R/eel of 22 March 2022, with which the Authority set the conventional percentage factors related to commercial losses to be applied to electricity for equalisation purposes equal to 1.77% in the Centre zone for 2022, and 1.72% in the Centre zone for 2023. It also introduced a cap on the PAU price to be applied, equal to the arithmetic average of the average annual PAUs in 2016 – 2021.

With a specific application to be presented by the end of May 2022, the resolution provided for recognition of network losses attributable to non-recoverable fraudulent withdrawals that manifest with exceptional amounts compared to the levels recognised conventionally. The recognition was provided for exclusively in the case of a negative net equalisation balance on the three years 2019-2021 and will have a value at the most equal to what is necessary to reduce this balance to zero. In addition, with an application to be presented by May 2024, the same recognition was envisaged related to the 2022-2023 two-year period. The application related to the recognition of losses in the 2019-2021 three-year period was submitted by Areti via certified email on 31 May 2022.

On 7 February 2023, ARERA published Resolution 42/2023/R/eel, beginning the procedure to verify the existence of the right to recognition of non-recoverable fraudulent withdrawals claimed by areti, the amount of fraudulent withdrawals to recognise and the corresponding economic value. Following this resolution, in a certified email the Authority communicated the following investigations relative to the procedure:

• the issue involved in the request is accepted (thereby identifying a liability with respect to the company) and is equal to around € 1.0 million;
• the non-recoverable fraudulent withdrawals are recognised solely for cases of “occupied buildings” (138 GWh), and not recognised for cases of “routes at risk” (36 GWh) and “unknown” (7 GWh). In the context of future sessions to update balancing amounts, CSEA will recognise the stated amount for areti and the relative annual updates to which the balancing amounts for 2019-2021 are subject.

Note that with Resolution 181/2023/R/eel of 4 May 2023, the Authority completed the procedure begun with resolution 42/2023/R/eel, authorising CSEA to recognise this amount for areti and the relative annual updates to which the balancing amounts for 2019-2021 are subject, in the context of future sessions to update balancing amounts.

On 25 July 2023, ARERA published resolution 336/2023/R/eel, beginning a procedure to adopt provisions to reform regulations for electric settlement, methods for determining procurement of network losses and the relative equalisation mechanisms, considering the innovations over time in relation to meter reading, the removal of the greater protection service and innovations in dispatching regulation. The reform is structured in phases, with the first actions focussed on going beyond the load profiling regulations and the role of residual user, at present assigned to Acquirente Unico as part of the same regulation, as well as the consequent optimisation of the relative disclosure and monitoring obligations falling to the various entities.

Also note that with Resolution 584/2023/R/eel of 12 December 2023, the Authority extended to 2024 the regulations on equalisation of network losses established pursuant to the TIV for 2022-2023, the conventional loss factors for equalisation purposes established in the TIV for 2023 and the conventional loss factors applied for 2023 to electricity issued and withdrawn pursuant to the TIS. With reference to marginal situations, the mechanism for restoration of losses was confirmed for 2024, with the application to be presented in May 2025 with reference to 2022-2024.

On 3 August 2023 consultation document 377/2023/R/eel was published, in which the Authority presented its initial guidelines on the elimination of load profiling regulations and procurement methods for “residual” energy. The deadline for submission of comments was 25 September 2023.

With resolution 712/22, effective April 2023, ARERA governed the issuing of reactive energy from MV/LV networks to the relevant grid (NTG), establishing amounts differentiated between homogeneous and non-homogeneous areas (€2/MVarth and € 1.44/MVarth).

Homogeneous areas mean notes on the relevant grid, featuring the same impact from reactive energy exchanges (issue/withdrawal).

The Authority published resolution 124/2023 on 28 August 2023, with which it adopted the list of electricity nodes on the relevant grid to which the higher amount is applied for issuing of reactive energy, confirming the application of the amounts for reactive energy issued effective 1 April 2023, with exemptions in the case that adequate offsetting tools are utilised.

On 27 December 2023, with Resolution 615/2023/R/eel, ARERA defined the criteria for tariff regulation for electricity transmission and dispatching services for 2024-2027 (RTTE 6PRTE). A significant passage for areti SpA involves the issue of fees to be paid to Terna for the issuing of reactive energy in the NTG. In particular, the provision establishes that the metering systems on the MV side of the primary areti SpA substations be used until 31 December 2026 to determine reactive energy issued and withdrawn, de facto extending the provisions pursuant to resolution 591/2023/R/eel (12 December 2023) with reference to measuring reactive energy exchanges on high or very high voltage, based on specific grid and metering configurations.

In the new Transport Integrated Text, the ARERA has confirmed the mechanism of advance recognition on a two-monthly basis, of equalisation balances for revenue from the distribution service and transmission costs. With Determination 19/2020 of 13 November 2020, ARERA defined the operating methods of managing the general equalisation mechanisms, confirming the method of calculating the advances every two months.

Further impact on equalisation was linked to the fact-finding investigation launched with Resolution 58/2019/E/eel concerning the regulation of financial items relating to electricity destined for States included in Italian territory. The Authority, with Measure 491/2019/E/eel, ordered Areti to carry out – by 31 December 2019 – the actions necessary to properly define the dispatching point of export related to the electricity destined for dispatching points of export and to obtain the measurement data of the electricity sold.

On 20 December 2019, the company stated that it had complied with the requirements.

The Authority decided that the elements acquired constituted a condition for the launch of a proceeding aimed at ascertaining any breaches on the subject of settling the economic items related to the electricity destined for the dispatching point of export.

In June 2020, areti presented its commitments, which were revised in February 2022 in the light of the results communicated by CSEA and approved by ARERA with resolution 262/2021/E/eel. The relevant items will in any case be settled at the end of the penalty proceedings initiated with Determination 5/2020/eel.

On 5 April 2022, with Resolution 151/2022/S/eel, ARERA approved and published the proposal of commitments submitted by areti. The following phases will follow:

1. third parties could submit their comments by 7 May 2022;
2. within 30 days of the publication of any comments, areti could respond;
3. final approval of the commitments with resolution, which will also specify the terms for the settlement of the financial items and the start date of the monitoring.

With resolution 355/2022/S/eel of 27 July 2022, ARERA approved the commitments proposed by areti SpA in the context of the sanction proceedings for violations of settlement of economic items relative to electricity destined for Vatican City State.

Finally, with Resolution 576/2021/R/eel, Arera provided that for interconnection with the dispatching points of export:

• from 1 January 2022, only the variable components, expressed in c€/kWh, of the tariffs covering transport costs provided for in paragraph 15.1 of the TIT will be applied (currently, the fixed and variable components are both applied);
• from 1 April 2022, the imbalance price for non-enabled units (and no longer the DAM zonal price) will apply for the purpose of regulating actual imbalances);
• from 1 January 2023, uplift shall be applied to the energy actually withdrawn (currently not applied).

In the same measure, the Authority specifies that the entire band must no longer be used to define the dispatching points of export withdrawal schedule; the dispatching user must instead use its own best estimate of withdrawals. The delta between the value of the band and the programme must be treated as a programme imbalance and valued at PUN.

ARERA has confirmed the method of recognising the capital costs for low voltage electronic meters, for firms serving more than 100,000 points of delivery, based on criteria for determining the investments effectively made by the single firms and also retaining the measurement equalisation for the fifth regulatory cycle. The equalisation mechanism is intended to equalise the revenue from the comparison of the obligatory tariffs billed to end users and the revenue set in the reference tariff.

The tariffs hedging the measurement service are updated, as are those for the distribution service, using the price-cap mechanism for the part hedging the operating costs (with the goal of a 0.7% recovery of productivity) and with the deflater, variation in invested capital and rate of change of the volumes supplied for the part covering the invested capital and depreciation. The rate of remuneration of the measurement capital is the same as that for the distribution service.

Note that with Resolution no. 646/2016/R/eel of 10 November 2016, ARERA illustrated the methods for defining and awarding costs related to second generation (2G) smart metering systems for measuring low voltage electricity. On 8 March 2017, it published a release in which it updated the evaluation of the plan for entry into service of the 2G smart metering system prepared by e-distribuzione SpA. In order to present ARERA with an illustrative report on the commissioning plan of the 2G smart metering system, the company defined a project for the development of this system with the aim of replacing the current system of electronic meters.

Starting in 2017, ARERA established in the same resolution that for the annual updating of the return on invested capital and depreciation concerning effective low-voltage metering points, for each distribution firm, the maximum gross investment value recognisable per meter installed is 105% of the corresponding gross investment value per meter for the investments that came into operation in 2015.

On 20 March 2019, with the consultation document 100/2019/R/eel, the Authority introduced an update for the three-year period 2020-2022 of the provisions on the determination and recognition of costs relating to second generation (2G) smart metering systems. In particular, the proposals set out in the consultation document include:

1. the possibility of setting obligations on the timing of commissioning of 2G systems together with the modulation of the “conventional plan” in order to reduce the risk of a “two-speed country”; the updating and simplification of the provisions relating to admission to the shortened programme for companies that launch their plan for commissioning 2G smart metering systems in that three-year period;
2. The assessment of the provisions of Decree 93/2017 of the Minister for Economic Development concerning the periodic verification of electricity meters and the extra costs that could result from them;
3. The possibility of introducing provisions to quantify the penalties to be applied in the event of non-compliance with the expected levels of performance of 2G smart metering systems.

This was followed by Resolution no. 306/2019/R/eel on 16 July, which confirmed the guidelines presented in the previous consultation document. Specifically:

1. The Authority set 2022 as the deadline for the start of the plans for the commissioning of 2G systems and established that the mass replacement phase for the meters must be completed by 2026 (with a target of 95% of the meters included in the plan). Furthermore, in order to avoid the “two-speed country” risk, a new method of calculating the “conventional plan” was introduced for companies that have not yet submitted their rollout plan.
2. Starting from the 4th year of each PMS2, penalties are introduced for failure to meet expected performance levels, with annual and multi-annual ceilings on penalties for greater protection of service users.
3. The regulatory useful life of the asset categories relating to the low-voltage electricity metering service to be applied to investments in 2G smart metering systems is 15 years.
4. The remuneration and depreciation of the invested capital are determined according to a fixed rate depreciation schedule. Depreciation schedule instalments are calculated as deferred annual instalments, considering a return time horizon consistent with the regulatory useful life.

On 20 September 2019, areti sent the Authority the request for admission to the recognition of investments under the specific regime together with the plan for the commissioning of the 2G smart metering system and the other documents required by Resolution no. 306/2019/R/eel. The documentation was made available on 23 September 2019 on the Areti website, and on 21 October a public session was held to present the Plan, during which the Company responded to the comments made by participants. On 20 December the Authority requested detailed information on the actual operating capital costs of Measure 1G and 2G set out in PMS2.

Resolution 213/2020/R/eel, which follows 177/2020/R/eel accompanied by CD 178/2020, provides for transitional amendments for the year 2020 to some of the directives for second generation (2G) smart metering systems for measuring low voltage electricity.

In particular, in consideration of the COVID-19 health emergency and its impacts on the replacement of meters, the Authority expressed the orientation to:

• waive – at least for 2020 – the upgrade criterion at the level of the Municipality or other significant territory:
• establish that the next PDFMs, which must have a maximum quarterly frequency, can only have indicative value as long as the emergency persists. Moreover, each PDFM must be published 15 days in advance of the beginning of the month in which mass replacements of meters are planned;
• suspend – at least for 2020 – the provisions on penalties for failure to achieve at least 95% of the progress (cumulative) envisaged by PMS2 from the second year of the plan (90% for the first year);
• suspend – for the year 2020 only – the application of the IQI (Information Quality Incentive) matrix, which defines the value of the incentives to be paid to companies for the different combinations of actual expenditures incurred and planned, since the comparison between actual costs and expected costs may be subject to factors that affect the comparison.

On 28 July 2020, with Resolution 293/2020/R/eel, the Authority approved the plan of commissioning of the 2G smart metering systems presented by Areti and determined the related conventional commissioning plan and the expenses envisaged for the plan for the purposes of recognition of the costs of capital.

ARERA also considers it appropriate to offer distribution companies the option of proposing the updating of their upgrade plan during 2021 to adjust for the effects of the epidemiological emergency. It is noted that on 31 March 2021, in consideration of the ongoing health emergency and need to further investigate the relevant impact, Areti announced its intention to collect additional information to assess whether it should update its PMS2 by 15 June 2021.

On 14 June 2021, Areti notified Arera that it had promptly intervened, by adapting its processes and procedures so as to absorb the operational impact that had arisen during the health emergency period, and it that it had consequently not identified any effects that would require the plan to be revised. It is noted nonetheless that certain risks are present, including but not limited to the possible increase in asset costs due to raw materials becoming more expensive or the potential shortages in supplies due to the widespread slowdown in production worldwide. In this regard, note that the DSOs, through Utilitalia, are submitting to the Authority a number of requests intended to zero the bonus and penalty mechanisms for the years impacted by the scarcity of 2G meter supplies.

With Resolution 349/2021/R/eel of 3 August 2021, the Authority provided that, for the year 2021, in the case companies that had started PMS2 in previous years, the 2G meter limit below which penalties apply is 90% instead of 95% of the cumulative number of 2G meters provided for by PMS2 as at 31 December 2021. The Authority also resolved that for 2021, the criterion of implementation at municipal or other significantly relevant territorial level shall not apply.

On 23 March 2022, Arera sent to Areti, via certified email, communication of the preliminary findings related to the effective capital cost of the investments in 2G smart metering systems incurred in 2020.

On 28 June 2022, the Authority published DCO 284/2022/R/eel which outlined the guidelines relating to the introduction of transitional changes to the provisions of the 2G Directives for 2022. These transitional changes were deemed necessary following the indirect effects of the COVID-19 pandemic which led to a severe lack of semiconductors at global level and which in turn, at the start of 2022, created significant limitations on the availability of 2G meters that had already been ordered by distribution companies. Interested parties are invited to send their comments to the Authority by 29 July 2022.

With Resolution 280/2022/R/eel of 28 June 2022, Arera initiated proceedings to update the guidelines for the recognition of second generation (2G) smart metering system costs applicable from 2023, currently defined by Resolution 306/2019/R/eel, providing for the conclusion of such proceedings by 31 December 2022.

On 28 June 2022, the Authority published DCO 284/2022/R/eel outlining its guidelines relating to the introduction of transitional changes to the provisions of the 2G Directives for 2022. These transitional changes were deemed necessary following indirect effects of the COVID-19 pandemic which led to a severe lack of semiconductors at global level, which in turn, at the start of 2022, created significant limitations on the availability of 2G meters that had already been ordered by distribution companies. In this DCO, ARERA also discussed the possible transitional derogation of the “operational” criteria for significantly relevant areas, examined possible transitional changes involving the preparation of detailed plans for the mass stage, discussed application methods for the Information Quality Incentive (IQI) matrices, illustrated possible transitional changes to the penalty rules for lack of progress in the operational plan and examined completion schedules for the mass stage of 2G smart metering operations. The interested DSOs were asked to send their comments by 29 July 2022.

Note that on 27 July 2022, the Authority published consultation document 360/2022/R/eel, illustrating guidelines relative to the extension of provisions on the implementation of second generation low voltage electricity smart metering systems. The deadline for submission of comments was 26 September 2022.

On 22 November 2022, following the consultation period begun with DCO 284/2022/R/eel, ARERA published resolution 601/2022/R/eel in which it introduced transitional changes to certain provisions for the second generation (2G) smart metering systems for low voltage electricity. In particular, it establishes: for 2022 and the first half of 2023, non-application of the “operational” criteria in any significantly relevant area; for 2022, provisions pursuant to article 18, paragraphs 1 and 3 of Annex A to resolution 306/2019/R/EEL are suspended, relative to penalties for delays with respect to the forecasts for implementing the service and limited non-compliance with expected performance levels; the effects deriving from the planned and actual numbers of 2G metres for 2022 were sterilised. On 28 March 2023, Arera sent the preliminary findings related to the effective capital cost of the investments in 2G smart metering systems incurred in 2021.

Finally, with resolution 724/2022/R/eel, the Authority updated the 2G Directives for 2023-2025 establishing i) that annual accounting methods for physical progress be made systematic, with time frames similar to the accounting already established for economic and performance progress, ii) that the monitoring period for 2G smart metering system performance be extended to 4 years, activating penalties only as of 1 January of the fifth year of PMS2, in light of the problems which arose relative to the COVID-19 health emergency and the significant limitations on availability of 2G components, iii) an obligation to promptly replace 1G metres with 2G metres for activation requests for collective self-consumption, and iv) a premium mechanism for accelerating PMS2 as an effect of public contributions.

The “Integrated Text on provisions of the Authority on the economic conditions for providing connection services (TIC)”, Annex C to Resolution 568/2019//R/eel, governs the economic terms for the provision of connection services and specific services (transfers of network equipment requested by end users, contract transfers, disconnections, etc.) to passive users, essentially in line with the previous regulatory period.

The regulatory changes that have taken place since 1 January 2016 allow the distributor to affirm that the right to remuneration for invested capital arises, from an accounting point of view, at the same time as investments are made and the depreciation process is initiated in compliance with the accruals concept and the principle of correlation of costs and revenues. For this purpose, the remuneration of the investments (including of the related depreciation and amortisation) was calculated and recognised in the energy margin at the same time as they were made (so-called Regulatory Accounting).

Resolution 119/2022/R/eel of 22 March 2022 established the mechanism to reimburse electricity distributors for receivables not collected and not otherwise recoverable in relation to general system charges and network charges, outlining their conditions for access, quantification criteria of the eligible receivables, criteria for their recognition, operating methods as well as time frames for submitting applications and settlement of the amounts by CSEA. Furthermore, this measure repealed resolution 50/2018/R/eel of 1 February 2018.

Furthermore, note that with Resolution 35/2022/R/eel of 31 January 2022, ARERA arranged for the cancellation of the rates for general electricity system charges for Q1 2022 for all types of users, implementing the Supports ter Law Decree.

On 22 November 2022, the Authority published resolution 599/2022/E/com which began an audit campaign with reference to documents on the topic of accounting separation and declared investments for a sample of regulated companies in the electricity distribution and natural gas distribution and transport sectors for the years 2018-2021.

Note also the publication of DCO 615/2021/R/com of 23 December 2021, in which the Authority illustrates its thinking behind the main lines of action of the ROSS-BASE solution, namely the focus on total expenditure, overcoming the current cost recognition system, which considers operating costs and investments separately, in favour of an integrated approach that gives operators responsibility. In particular, the new integrated approach focuses on the following aspects: realistic forecasts and development plans, based on the future and actual needs of service customers; incentives to improve performance levels, in terms of efficiency, cost-effectiveness and quality of service; removal of any regulatory barriers to the development of innovative solutions. ARERA does not yet go into detail on the regulatory mechanisms that must be developed and which will come into force in 2024 for the electricity distribution and metering service, but it does intend to obtain an initial assessment from operators, end customers and other participants. Comments were sent by 31 January 2022.

On 12 July 2022, the Authority published DCO 317/2022/R/com, offering further clarifications and observations on the scope of application for the ROSS approach and the criteria used to determine the historic cost recognised under the ROSS BASE approach. Comments were sent by 14 September 2022.

On 25 October 2022, ARERA published resolution 527/2022/R/com, beginning a procedure to define the adjustment criteria based on the ROSS-complete model. By 31 December 2023 a framework resolution will be published, containing the general criteria for ROSS Complete adjustments and in 2024 specific sector provisions will be published for the various regulated services, which will contain methods and objectives for experiments.

In DCO 655/2022/R/com, the Authority published its final guidelines on the criteria for determining the cost recognised under the ROSS-base approach and a first draft of the TIROSS (Consolidated regulatory law on spending and service objectives for regulated infrastructure services in the electricity and gas sectors) for 2024-2031: the duration of the regulations contained in TIROSS is 8 years, while the duration of the regulatory period for each regulated service is 4 years. The DCO provides additional indications relative to determining the spending to be included in tariff recognition, on determining total efficiency recoveries and the treatment of capital spending existing as of the cut-off date. Distribution companies can submit their comments until 23 January 2023.

On 18 April 2013, with Resolution 163/2023/R/com, the Authority published the Consolidated law on general criteria and standards for regulating spending and service objectives for 2024-2031 (TIROSS 2024-2031), and approved Part I, containing shared provisions, as well as part II, dedicated to ROSS-base. This Resolution also confirmed the guidance anticipated in DCO 655/2022/R/com, postponing the definition of specific parameters for future specific provisions relative to each regulated infrastructure service. Subsequently, on 18 May 2023, ARERA sent to the main DSOs, Snam and Terna, a request for information, specifically simplified economic, equity and financial projections for the purposes of regulating spending and service objectives (ROSS), to determine future capitalisation rates, the X-Factor and the Z-Factor for the First ROSS Regulatory Period. This information was to be provided for 2023-2027.

With resolution 165/2023 of 18 April 2023, the Authority resolved to begin a procedure to establish provisions for infrastructure regulation with reference to electricity distribution and metering services for regulation period 2024-2027. This procedure will end by 31 December 2023, relative to general aspects, with application for the entire period from 2024-2027, and by 31 December 2027 with regards to specific application aspects, for example preparation of application criteria for the full ROSS regulation and the introduction or updating of output-based regulatory mechanisms.

On 3 August 2023, the Authority published consultation document 381/2023/R/com in which it presented guidelines on the methods for applying the ROSS-base criteria, for natural gas transport and transmission services and for electricity distribution and metering, applicable as of 2024. The document outlined the Authority’s proposals relative to certain aspects not yet defined in resolution 163/2023 approving the TIROSS, in any case postponing to subsequent consultation documents and working groups the aspects linked to cost reporting and monitoring and to analysis of economic/financial returns and the “financeability” of companies. Interested parties are invited to send their comments and proposals to the Authority by 21 September 2023.

Following the consultation, on 2 November 2023 ARERA published Resolution 497/2023/R/com in which it defined the application criteria governing spending and service objectives for natural gas transport and electricity transmission, distribution and metering services. Among many changes, the Authority ordered that the baseline for operating costs in 2024 is equal to the 2022 effective operating costs (COE), appropriately revalued for 2023 and 2024, based on the inflation rates published in resolution 616/2023, respectively equal to 6% and 1.9%. Efficiency recoveries achieved in the 5th regulation period were left to the distribution companies in the four subsequent years, with gradually declining rates (50% the first year, 37.5% the second, 25% the third and 12.5% the fourth).

Efficiencies in the new regulatory period are instead left to the DSO based on the incentive scheme selected (SBP low potential or SAP high potential). Capital costs incurred through 2023 (cut-off) are managed with the previous criteria (amortisation/depreciation in year n-2, capital in year n-1); capital costs after the cut-off year are managed using ROSS logic (amortisation/depreciation and capital at year n-1). Total costs incurred by the company are divided between the Slow money portion (opex) and the Fast money portion (capex) based on a capitalisation rate defined by ARERA.

On 29 November 2023, ARERA requested the information needed to determine the capitalisation rate, the baseline for 2024 operating costs, presentation of the application for the Z-factor and the incentive selected (SBP v.s SAP). On 22 December 2023, in a certified email, areti sent the Authority the requested information, deciding not to present the application to activate the Z-factor, as incremental costs associated with the energy transition were not planned for 2024, and opting for the low-potential scheme (x-factor of zero and efficiencies retained at 100% in the first year and 50% in the three subsequent years).