# IMMC.COM%282023%29148%20final.ENG.xhtml.1_EN_ACT_part1_v7.docx

european flagEUROPEAN COMMISSION

Strasbourg, 14.3.2023

COM(2023) 148 final

2023/0077(COD)

Proposal for a

REGULATION OF THE EUROPEAN PARLIAMENT AND OF THE COUNCIL

amending Regulations (EU) 2019/943 and (EU) 2019/942 as well as Directives (EU) 2018/2001 and (EU) 2019/944 to improve the Union’s electricity market design

(Text with EEA relevance)

{SWD(2023) 58 final}

EXPLANATORY MEMORANDUM

1.CONTEXT OF THE PROPOSAL

•Reasons for and objectives of the proposal

1.1.Policy context

Energy prices significantly increased throughout 2021 and 2022. This resulted from reductions in gas supply, particularly after the start of Russia’s war against Ukraine and the weaponisation of energy as well as from domestic shortfalls in hydropower and nuclear power. The price rises also resulted from increased energy demand, as the global economy picked up after the COVID-19 pandemic. These price rises were rapidly felt by households, industry and businesses across the EU, and governments immediately took steps to mitigate them. At the European level, the EU swiftly provided an energy prices toolbox
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  with measures to address high prices, in particular for the most vulnerable consumers (including income support, tax breaks, gas saving and storage measures), as well as the REPowerEU plan
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  with further measures and funding to boost energy efficiency and renewable energy in order to reduce dependence on Russian fossil fuels. This was followed by the creation of a temporary State Aid regime
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  to allow certain measures to soften the impact of high prices, a strong gas storage regime
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  , effective demand reduction measures for gas
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  and electricity
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  , faster renewable energy and grid permitting processes
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  , and price limiting regimes to avoid windfall profits in both the gas and electricity markets
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  .

These short-term measures helped Member States to deal with the immediate fall-out of the energy crisis. However, the crisis also showed how exposed consumers and industries are and our lack of resilience to energy price spikes. The impact of fossil fuel-based generation on setting electricity prices was seen as excessive by businesses and citizens, while Member States’ ability to cushion short term prices with longer term contracts appeared inadequate. For this reason, the European Commission President announced in the 2022 State of the Union Address
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  the need for a fundamental reform of the electricity market design.

Whilst the EU’s internal energy market delivers huge gains and growth across Europe, the recent energy crisis has highlighted that the energy market design’s short-term focus can distract from broader, longer-term goals. The reflection of short-term prices in consumers bills led to price shocks where energy bills of many consumers tripled or quadrupled, even as the costs of wind and solar power were declining; the sudden exposure to volatile and high prices triggered some supplier bankruptcies; many industrial enterprises in energy intensive sectors were obliged to shut down. Therefore, the proposal includes a set of measures aimed to create a buffer between short-term markets and electricity bills paid by consumers, in particular by way of incentivizing longer term contracting, to improve the functioning of short-term markets to better integrate renewables and enhance the role of flexibility and to empower and protect consumers.

The recent price volatility has also highlighted the lack of flexibility in the electricity grid, with prices set too often by gas-fired generation and with a general lack of low carbon flexible supply, demand response and energy storage. As more wind and solar power enter the system, low-carbon flexible technologies will be needed to balance the variable supply with variable demand. In parallel with this proposal, the Commission is making recommendations for the advancement of storage innovation, technologies, and capacities.

More broadly, the sensitivity of the electricity price to fossil fuel prices highlighted the need to speed up the deployment of renewables together with the flexibility of the power system to displace fossil fuels. REPowerEU provides such a boost to renewable energy and with it, a boost to economic growth and quality jobs creation. It builds on the European Green Deal’s drive to improve European competitiveness through innovation and the transition to a net zero economy and is closely aligned with the Commission’s Green Deal Industrial Plan. To facilitate the investments needed in the face of recent price volatility, uncoordinated regulatory interventions and grid and regulatory barriers to entry, fundamental reform is needed. Finally, in the Report on the final outcome of the Conference on the Future of Europe, citizens asked the EU institutions to take measures to “Enhance European energy security, and achieve the EU’s energy independence” and to ‘Reduce dependency of EU from foreign actors in economically strategic sectors’, including energy
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1.2.Objectives of the proposal

The proposal is addressing consumer, industry and investors’ concerns over exposure to volatile short-term prices, driven by high prices of fossil fuels. It will optimize the electricity market design by complementing the short-term markets with a greater role for longer-term instruments, allowing consumers to benefit from more fixed priced contracts, and facilitating investments in clean technologies. Ultimately, it will mean that less fossil fuel generation is needed and will lead to lower prices for consumers during future fossil fuel crisis due to the low operational costs of renewable and low carbon energy.

The proposal is putting forward measures to protect consumers from such volatility, empower them with greater contract choice and more direct access to renewable and low carbon energy. To improve investment conditions for businesses, in particular those pursuing decarbonisation pathways. it proposes measures to counter exposure to short term price spikes through power purchase agreements and more prudential obligations for energy suppliers. It also proposes measures to improve the way variable renewable and low carbon energies are integrated into the short-term market. This includes measures boosting the use of demand response and storage, among other forms of non-fossil flexibility. The proposal also improves and clarifies access to longer term contracts for developers (both State supported such as contracts for difference, and private, such as power purchase agreements) in order to provide secure, stable revenues for renewable and low carbon energy developers and bring down risk and capital costs while avoiding windfall profits in periods of high prices.

Whilst the current market design has over many decades delivered an efficient, increasingly integrated market, the energy crisis has highlighted a number of shortcomings relating to: (i) insufficient tools to protect consumers, including businesses, against high short term prices; (ii) the excessive influence of fossil fuel prices on electricity prices and the failure for low cost renewables and low carbon energy to be better reflected in electricity bills; (iii) the impact of extreme price volatility and regulatory interventions on investment; (iv) the lack of sufficient non-fossil flexibility (such as storage or demand response) that could reduce dependence on gas-fired generation; (v) the limited choice of supplier contract types; (vi) the difficulties to directly access renewable energy though energy sharing; and (vii) the need for robust monitoring of the energy market to better protect against market abuse.

To protect consumers from volatile prices, the proposal will provide for the right to fixed price contacts as well as dynamic price contracts, the right to multiple contracts and to better and clearer contract information. Consumers will be offered variety of contracts that best fits their circumstances. In this way, consumers, including small businesses, can lock in secure, long-term prices to mitigate the impact of sudden price shocks, and/or they may choose to have dynamic pricing contracts with suppliers if they wish to take advantage of price variability to use electricity when it is cheaper (e.g., to charge electric cars or use heat pumps). Such a combination of both dynamic and fixed pricing allows to keep market incentives for consumers to adjust their electricity demand, while providing more certainty also for those who wish to invest in renewable energy sources (rooftop solar panels for instance) and stability of costs. In addition to the existing protection framework for energy poor and vulnerable consumers, the proposal will also provide access to regulated retail prices for households and SME consumers in the event of a crisis and stabilise the supply industry by requiring that suppliers make more effort to guard against high price spikes by making greater use of forward contracts with generators (locking in future prices) and by requiring Member States to establish a supplier of last resort regime. The proposal will empower consumers by creating the right to share renewable energy directly, without the need to create energy communities. Greater energy sharing (e.g., sharing surplus roof top solar power with a neighbour) can improve the use made of low cost renewable energy and provide greater access to direct use of renewable energy for consumers who might not otherwise have such access.

To enhance stability and predictability of the cost of energy, thereby contributing to the competitiveness of the EU economy facing excessive volatile prices, the proposal intends to enhance market access to more stable longer-term contracts and markets. Power purchase agreements (PPAs) - long-term private contracts between a generator (typically renewable or low carbon) and a consumer – can protect against price volatility, but they are currently mostly available only to large energy consumers in very few Member States. A barrier to the growth of this market is the credit risk that a consumer will not always be able to buy the electricity over the whole period. To address this, Member States should ensure that instruments to reduce the financial risks associated to off-taker payment default in the framework of PPAs, including guarantee schemes at market prices, are accessible to companies that face entry barriers to the PPA market and are not in financial difficulty. To further encourage the growth of the market for such agreements, renewable and low carbon energy project developers participating in a public support tender should be allowed to reserve a share of the generation for sale through a PPA. In addition, Member States should endeavour to apply in some of these tenders' evaluation criteria to incentivise the access to the PPA market for customers that face entry barriers. Finally, the obligation on suppliers to hedge appropriately may also boost demand for PPAs (which are a way of locking in future prices).

Some forms of public support guarantee the energy producer a minimum price by the government but allow for the producer to nevertheless earn the full market price even when this market price is very high. With the recent high prices much (cheap) publicly supported energy has been receiving these high market prices. To curb this and so stabilise prices, investment support should be structured as “two-way” (two-way contract for difference), which set a minimum price but also a maximum price, so any revenues above the ceiling are paid back. The proposal will apply to new investments for the generation of electricity, which include investments in new power-generating facilities, investments aimed at repowering existing power-generating facilities, investments aimed at extending existing power-generating facilities or at prolonging their lifetime. Moreover, the proposal will require that such money is then channelled to support all electricity consumers in proportion to their consumption to mitigate the effect of high prices.

A further means of guarding against volatile prices is to use long term contracts that lock in future prices (“forward contracts”). This market shows low liquidity in many Member States but could be boosted across the EU, so that more suppliers or consumers can guard against excessively volatile prices over longer periods of time. The proposal will create regional reference prices via a hub to increase price transparency and oblige system operators to allow transmission rights longer than a year, so that if a forward contract is between parties across regions or borders, they can ensure transmission of the electricity.

Finally, to ensure markets that behave competitively and prices are set transparently, regulators’ ability to monitor energy market integrity and transparency will be enhanced.

The third objective is to boost renewable energy investment, in order to ensure that deployment triples, in line with European Green Deal goals. This will be achieved partly by improving the markets for long term contracts. Power purchase agreements and contracts for difference not only provide consumers with stable prices, they also give renewable energy suppliers reliable revenues. This lowers their financial risk and greatly reduces their cost of capital. This creates a virtuous circle where stable revenues lower costs and boost demand for renewable energy.

Renewable energy is also a better investment when its ability to produce power is not curtailed due to technical constraints in the system. The more flexible the system is (generation that can rapidly turn on or off, storage that can absorb or put power onto the system, or responsive consumers who can increase or decrease their demand for power) the more stable prices can be and the more renewable energy the system can integrate. For this reason, the proposal requires Member States to assess their needs for power system flexibility, establish objectives to deliver on these needs. Member States can design or redesign capacity mechanisms in order to promote low-carbon flexibility. Moreover, the proposal opens the possibility for Member States to introduce new support schemes for non-fossil flexibility such as demand side response and storage.

System operators should also play an enhanced role integrating renewables into the grid, partly by increasing transparency surrounding availability of grid connection capacity. First, this clearer information would enhance renewable energy developers’ ability to develop renewables in areas where the grid is less congested. Second, renewable energy can be more efficiently traded and balanced in the system if trades between market participants can take place closer to “real time”. If offers to supply electricity are made minutes before consumption rather than hours before consumption, the offers from wind and solar power producers are more accurate, more wind and solar power can be consumed and the “imbalance costs” of the system are reduced. Thus, trading deadlines will be brought closer to real time.

Consistency with existing policy provisions in the policy area

The proposed initiative is strongly linked and complementary to the legislative proposals brought forward in the context of the European Green Deal Package and speed up the decarbonisation objectives laid down in REPowerEU Plan, in particular as regards the proposal to revise the Renewable Energy Directive (“RED II”), which is the main EU instrument dealing with the promotion of renewable energy. The proposed initiative is complementary in that it aims to enable the acceleration in the uptake of renewable energy. The proposal seeks to ensure more stable long-term sources of revenue to unleash further renewable and low carbon energy investments, while improving the functioning of short-term markets, which are key for the integration of renewables in the electricity system. In addition, the proposal seeks to enable energy sharing to allow consumers to engage in the market and help to speed up the energy transition.

Reducing energy consumption through price signals, energy efficiency measures or voluntary efforts can often be the cheapest, safest and cleanest way to reduce our reliance on fossil fuels, to support security of supply and to reduce our energy bills. The proposal will facilitate the active participation of the consumers in the market and the development of their demand response. It will also enable non-fossil flexibility such as demand side flexibility and storage to compete on a level playing field so that the role of natural gas in the short-term market in providing flexibility is progressively reduced. Therefore, the proposal is in line with the proposed increase of the 2030 target for energy efficiency to 13%, as set out in the proposed amendments to Renewable Energy, Energy Performance of Buildings and Energy Efficiency Directives
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  accompanying the REPowerEU Plan
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  .

There is also an important link between the proposal and the Energy Performance of Buildings Directive which is the main EU instrument to help reach the building and renovation goals set out in the European Green Deal. The proposal is strongly linked in particular to provisions on sub-metering and demand response in addition to the Commission’s proposal, as part of the European Green Deal Package and expressed under the EU Solar Strategy Communication, on the gradual mandatory integration of solar photovoltaic in order to make public, commercial and residential buildings climate neutral.

•Consistency with other Union policies

The proposal’s objectives to protect and empower consumers, improve competitiveness of EU industry and boost renewables and low carbon investment are wholly consistent with the framework of the European Green Deal and coherent and complementary to current initiatives, including the legislative proposal for a “Net-zero Industry Act” which is being adopted in parallel. It responds to the issues that were identified in the Commission’s Communication laying out a “Green Industrial Plan for the net-zero age” issued on 1 February 2023
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  , namely that the competitiveness of many companies has been severely weakened by high energy prices and that long-term price contracts could play an important role to enable electricity users benefit from more predictable and lower costs of renewable power. Last but not least, the legislative proposal is complementary to the ongoing revision of relevant financial market regulations such as the Market Abuse Regulation
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  . The proposal also builds on the Council Recommendation on ensuring a fair transition towards climate neutrality whereby Member States are invited to continue to mobilise public and private financial support to invest into renewable energy, tackle mobility challenges and promote cost-saving opportunities linked to the circular economy
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  .

2.LEGAL BASIS, SUBSIDIARITY AND PROPORTIONALITY

•Legal basis

The proposal is based on Article 194(2) of the Treaty on the Functioning of the European Union (TFEU), which provides the legal basis for proposing measures aiming inter alia to ensure the functioning of the energy market, promote energy efficiency and energy saving and the development of new and renewable forms of energy.
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  In the field of energy, the EU has a shared competence pursuant to Article 4(2)(i) TFEU.

•Subsidiarity (for non-exclusive competence)

The need for EU action

The unprecedented nature of the energy price crisis has shone a spotlight on EU electricity markets. Despite the growing shares of low-cost renewables electricity across the EU, there is a continuing influence of fossil-fuel generated electricity on overall energy bills. Households and businesses across the EU have experienced skyrocketing energy prices during the crisis.

This is an issue of EU-wide relevance which can only be addressed with action at EU level. The increased integration of EU electricity markets requires closer coordination between national actors, also in the context of market monitoring and surveillance. National policy interventions in the electricity sector have a direct impact on neighbouring Member States due to energy interdependence, grid interconnections and ongoing electricity market integration. To preserve the functioning of the electricity system and cross-border trade and investments and to accelerate, in a coordinated way, the energy transition towards a more integrated and more energy-efficient energy system based on renewable generation, a common approach is needed.

The amendments proposed set out a balance between obligations and flexibility left to the Member States on how to achieve the main objectives pursued of ensuring that the lower cost of renewable electricity will be reflected in consumer bills and of boosting the deployment of renewable energy.

Furthermore, the objective of the proposed measures can only be achieved by action at EU level, not at individual Member States’ level, since the proposed action requires changes to the existing EU-wide framework for the electricity market design as set out in the Electricity Regulation (EU) 2019/943 and the Electricity Directive (EU) 2019/944 as well as to existing REMIT framework.

•EU added value

EU action to address the shortcomings of the current electricity market design brings added value because it is more efficient and effective than individual Member States’ actions, thus avoiding a fragmented approach. The measures proposed to address the shortcomings identified will be more ambitious and cost-effective if driven by a common legal and policy framework. In addition, action at Member State level would only be possible within the constraints of the existing EU-wide framework for the electricity market design as set out in the Electricity Regulation and Electricity Directive as well as REMIT Regulation and not be able to achieve the necessary changes to that framework. Consequently, the objectives of this initiative cannot be achieved only by Member States themselves and this is where action at EU-level provides an added value.

•Proportionality

The proposed amendments to the Electricity Regulation, the Electricity Directive, the REMIT Regulation and the ACER Regulation are considered proportionate.

The proposed measures to incentivise the use of long-term contracts such as power purchase agreements and two-way contracts for differences may lead to increased administrative costs and burden for undertakings and national administrations. However, the envisaged economic impacts are necessary and proportionate to achieve the objective of incentivising the use of such long-term contracts and ensuring that the energy bills of European households and companies as well as the revenues of non-fossil fuel technologies with low variable costs become more independent from the fluctuation of prices in short-term markets and thus more stable over longer periods of time.

The measures envisaged to improve the liquidity and integration of markets may also generate some short-term impact on businesses, as these would have to be adapted for new trading arrangements. These are however considered necessary in order to achieve the envisaged objectives of ensuring better integration of renewable and low carbon energy and reducing dependency on fossil fuels for flexibility, and ultimately reaching carbon neutrality in the Union with lower costs for consumers. They are also proportionate to these objectives, since the impact on businesses appears minimal compared to the current framework and the economic gains of the reform would largely surpass any short or long-term administrative reorganisation.

It is also proportionate with the objectives pursued not to envisage measures amending existing provisions in the Electricity Regulation and the Electricity Directive where any issues identified with regard to existing provisions can be addressed through their manner of application or implementation. One such instance relates to the measures concerning resource adequacy in Chapter IV of the Electricity Regulation, in particular, the process for Member States to introduce capacity mechanisms, which could be simplified without amending the relevant provisions.

The measures envisaged to strengthen consumer empowerment, rights and protections will expand duties and obligations placed on suppliers and network operators. However, the additional burdens are necessary and proportionate to achieve the objective of ensuring consumers have access to better information and variety of offers, decoupling their electricity bills from short term movements on energy markets and rebalancing the risk between suppliers and consumers.

The measures envisaged to improve the REMIT framework may increase reporting obligations for market participants due to a broader scope of REMIT. These measures are necessary to achieve the objective of increasing transparency and monitoring capacities and ensuring more effective investigation and enforcement of cross-border cases in the EU so that consumers and market participants have confidence in the integrity of energy markets, prices reflect a fair and competitive interplay between supply and demand and no profits can be drawn from market abuse. They are also proportionate to that objective, since the gains in terms of quality of market monitoring and surveillance would surpass any short or long-term administrative costs.

Finally, the overall package of measures proposed is considered appropriate given the overarching imperative of achieving climate neutrality at the least cost for consumers while ensuring security of supplies.

•Choice of the instrument

The proposal will amend the Electricity Regulation, the Electricity Directive, the REMIT Regulation, the ACER Regulation and the Renewables Energy Directive. Given that the proposal aims to add a limited set of new provisions and amend a limited set of existing provisions in these instruments, the recourse to an amending act is adequate. For the same reason, it also appears appropriate to use the instrument of an amending regulation to introduce amendments both to existing regulations and existing directives.

3.STAKEHOLDER CONSULTATIONS AND STAFF WORKING DOCUMENT

•Stakeholder consultations

In preparation for the present initiative, the Commission has conducted a public consultation from 23 January 2023 to 13 February 2023. The consultation was open to everybody.

The Commission received 1369 replies to this consultation. More than 700 of those have come from citizens, around 450 from businesses and business associations, around 40 from national or local administrations or from national regulators and around 70 from network operators. Also, around 20 energy communities, 15 trade unions and 20 consumers organisations participated. A significant number of NGOs, think tanks and research or other academic organisations submitted responses as well. An overview of stakeholders’ opinions is available in the Staff Working Document accompanying this legislative initiative.

In addition, the Commission organised an online targeted stakeholder consultation meeting on 15 February 2023 which counted with the participation of around 70 market actors, non-governmental organisations, network operators, ACER and national regulators, think tanks and academics. The consultation overall highlighted that the stakeholders considered that:

–Short-term markets and the pricing mechanism based on marginal pricing should be preserved, as they function well and provide the right price signals. Short-term (day-ahead and intraday) markets are well-developed, and they result from years of implementation of EU energy legislation.

–Short-term markets need to be complemented by instruments incentivizing longer term price signals, such as the ones indicated in consultation by the Commission, in particular power purchase agreements (‘PPA’), contracts for difference, and enhanced forward markets. The right balance between the different tools should be established. Nonetheless, there should not be mandatory schemes, and the freedom of choosing the relevant contracts should be preserved.

–The benefits of non-fossil flexibility solutions such as demand response and storage were acknowledged, especially in the context of an increasing share of renewables. Their market participation should be facilitated.

–The future electricity markets will have to be adapted to a high share of renewable energy. Furthermore, there should be more emphasis on the local dimension and grid development. These challenges could be addressed by the solutions presented in the public consultation.

–Consumer protection is essential, as is affordability of energy, but preserving the signals for demand response is equally important. Emerging solutions such as energy communities, self-consumption, energy sharing should be enabled and incentivized.

•Staff Working Document

Given the urgency of the initiative, a Staff Working Document has been produced instead of an impact assessment. The Staff Working Document underpinning the present proposal sets out the explanation and rationale behind the Commission’s proposals for a structural response to the high energy prices experienced by households and businesses and to ensure secure, clean and affordable energy for households and businesses into the future as well as presents the available evidence of relevance for the proposed measures.

The Staff Working Document concludes that the package of proposed reforms is expected to significantly improve the structure and functioning of the European electricity market. It is another building block to enable the delivery of the Green Deal objectives and in addition it takes stock of the shortcomings revealed by the energy crisis and seeks to address them.

The document shows that the reform will contribute to protecting and empowering consumers currently facing high and volatile prices by creating a buffer between them and short-term markets. This proposal will decouple the high prices of fossil-fuel technologies operating in the electricity market from the energy bills of consumers and businesses. More long-term contracting opportunities in the form of PPAs, contracts for difference and forward markets will ensure that the part of the electricity bill exposed to short-term markets can be greatly reduced. In addition, including a hedging obligation on suppliers and an obligation to also offer fixed price contracts will significantly increase the options to reduce the exposure of price volatility for electricity bills. Consumers will also have better information on offers before signing up and Member States will have an obligation to establish suppliers of last resort. Besides, they can enable access to regulated retail prices in a crisis. The right to share energy is a new feature that will empower consumers and support the decentralised rollout of renewable energy as it grants consumers more control over their energy bills.

The Staff Working Document explains how this reform will also enhance the competitiveness of EU industry in a way that is fully complementary to the Net-zero Industry Act. Member States will be required to ensure that the right conditions exist for PPA markets to develop, thereby providing industry access to affordable and clean electricity over the long-term. The improvements to the forward markets will provide far greater access to cross-border renewable energy for industries and suppliers up to three years in advance, a significant improvement compared to today. Overall, public support schemes for renewable energy will increase the energy independence in Member States and the penetration of renewables into the system while supporting local jobs and skills.

The document demonstrates that this reform will accelerate the rollout of renewables and tap into the full potential of firm generation capacity and flexibility solutions to enable Member States to integrate ever higher levels of renewables. The Commission proposes that Member States assess their need for power system flexibility and allows the introduction of new support schemes for demand response and storage. The proposal also introduces extra possibilities for renewables to trade closer to real time at cross-border and national level. In this way, the market can better support the integration of renewables and the business case for flexibility solutions that can contribute to security of supply.

Finally, the Staff Working Document describes how this proposal responds to the request from the European Council to assess ways of optimising the functioning of the electricity market design in the context of the energy crisis. It aims to protect consumers, creating a buffer between them and short-term electricity markets through longer-term contracting and to make those short-term markets work in a more efficient way for renewables and flexibility solutions, with better regulatory oversight. This proposal ensures that the market rules remain fit for purpose to drive the cost-effective decarbonisation of the electricity sector and increase its resilience to energy price volatility.

•Collection and use of expertise

The preparation of the present legislative proposal and the Staff Working Document is based on a large body of material, which is referenced in the footnotes in the Staff Working Document, and on the responses to the public consultation.

•Fundamental rights

The present proposal may have an impact on a number of fundamental rights established by the Charter on Fundamental Rights of the EU, in particular: the freedom to conduct a business (Article 16) and the right to property (Article 17). As explained above, however, to the extent that the proposed measures limit the exercise of these rights, these impacts are considered necessary and proportionate to achieve the objectives of the proposal and therefore constitute legitimate limitations of such rights as allowed under the Charter.

On the other hand, the proposal enhances the protection of fundamental rights, such as the respect for private and family life (Article 7), the right to protection of personal data (Article 8), the prohibition of discrimination (Article 21), access to services of general economic interest (Article 36), the integration of a high level of environmental protection (Article 37) and the right to an effective remedy (Article 47), in particular through a number of provisions concerning consumer empowerment, rights and protection.

•Regulatory fitness and simplification

The proposed amendments to the Electricity Directive, the Electricity Regulation, the REMIT Regulation and the ACER Regulation focus on what is considered necessary to address the shortcomings of the current electricity market design in the context of the energy crisis and to contribute in a cost-effective manner to the Union’s climate ambition. They do not constitute a full revision of these instruments.

The proposal may increase administrative requirements for national administrations and undertakings, albeit in a proportionate way as explained above. For example, the proposed measures to incentivise the use of long-term contracts such as power purchase agreements and two-way contracts for differences may lead to increased administrative costs and burden for undertakings and national administrations. However, the envisaged economic impacts will positively benefit businesses and consumers.

The measures envisaged to improve the liquidity and integration of markets may also generate some short-term impact on businesses, as these would have to be adapted for new trading arrangements. These are however considered minimal compared to the current framework, as the economic gains of the reform would largely surpass any short or long-term administrative reorganisation.

The measures envisaged to strengthened consumer empowerment, rights and protections will expand duties and obligations placed on suppliers and network operators with the objective to improve choice, increase protection and facilitate active market participation by consumers, notably households. However, the additional burdens are minimal because these frameworks are being rolled out across Europe and therefore streamlining of rules is needed.

The measures envisaged to improve the REMIT framework may increase reporting obligations on certain market participants, albeit in a proportionate way. These are however considered minimal compared to the current framework as the gains in terms of quality of market monitoring and surveillance would surpass any short or long-term administrative costs.

4.BUDGETARY IMPLICATIONS

The budgetary impact associated to the proposal on improving the EU’s electricity market design concerns the resources of the European Union Agency for the Cooperation of Energy Regulators (ACER) and of DG Energy which are described in the Legislative Financial Statement accompanying the proposal. Essentially, for the new tasks to be carried out by ACER 4 additional full time equivalent (FTE) for ACER from 2025 onwards, as well as corresponding financial resources will be required. DG Energy’s workload will increase by 3 FTE.

The budgetary impact associated to the proposal amending REMIT concerns the resources of the European Union Agency for the Cooperation of Energy Regulators (ACER) and of DG Energy which are described in the Legislative Financial Statement accompanying the proposal.  Essentially, the new tasks to be carried out by ACER, especially regarding the enhanced investigatory powers require a phasing in of 25 additional full time equivalent (FTE) in ACER from 2025, as well as corresponding financial resources, although most of the additional staff will be funded by fees. To this end Commission Decision (EU) 2020/2152 of 17 December 2020 on fees due to ACER for tasks under REMIT will need to be adapted. DG Energy's workload will increase by 2 FTE.

5.OTHER ELEMENTS

•Implementation plans and monitoring, evaluation and reporting arrangements

The Commission will monitor the transposition and compliance of Member States and other actors with the measures that shall be ultimately adopted and take enforcement measures if and when required. For monitoring and implementation purposes, the Commission will notably be supported by ACER, in particular in relation to the REMIT Regulation. The Commission will also liaise with ACER and the national regulatory authorities in relation to the Electricity Regulation and the Electricity Directive.

Moreover, to facilitate the implementation, the Commission will be available for bilateral meetings and calls with Member States in case of specific questions.

•Explanation of the specific provisions of the proposals

The amendments concerning the Electricity Regulation provide clarifications to the scope and subject matter of the Regulation, emphasising the importance of undistorted market signals to provide for increased flexibility as well as the role of long-term investments to mitigate the volatility of short-term market prices on the electricity bills of consumers including energy intensive industries, SMEs and households. It clarifies certain main principles for trading in the day-ahead and intraday markets. It provides for new rules concerning the procurement by TSOs of demand response in the form of a peak shaving product and rules allowing transmission system operators and distribution system operators to use data from dedicated metering devices. It sets out new rules concerning forward electricity markets, to improve their liquidity. It includes new rules aiming to clarify and incentivise the role and use of longer-term contracts in the form of power purchase agreements and two-way contracts for difference. It provides for new rules regarding the assessment of the flexibility needs by Member States, the possibility for them to introduce flexibility support schemes and design principles for such flexibility support schemes. It also introduces new transparency requirements for transmission system operators as regards the capacity available for new connections in the grid.

The amendments concerning the Electricity Directive provide for new rules on the protection and empowerment of consumers. The amendment regarding Free Choice of Supplier introduces new requirements to ensure that customers are able to have more than one supplier on their premises, by enabling multiple meters (sometimes called submeters) for a single connection point.

The amendments regarding consumer empowerment and protection ensure that customers are offered a variety of contracts that best fits their circumstances, by ensuring that all customers have a least one fixed term, fixed price offer. Furthermore, customers must be provided with clear pre-contractual information in relation to these offers.

A new right for households and small and medium sized enterprises is also established to participate in energy sharing- that is the self-consumption by active customers of renewable energy generated or stored offsite either from facilities they own, lease, rent in whole or in part or which has been transferred to them by another active customer.

Important new protections for customers are also introduced to ensure continuous supply of electricity– including the requirement for Member States to appoint suppliers of last resort who take responsibility for the customers of failed suppliers and protection from disconnection for vulnerable customers. Suppliers will also be required to put in place risk management to limit the risk of failure, by implementing appropriate hedging strategies. These will be overseen by national regulatory authorities.

The amendments to the Electricity Directive introduce new transparency requirements for distribution system operators as regards the capacity available for new connections in the grid. It clarifies the role of regulatory authorities regarding the single allocation platform established in accordance with Regulation (EU) 2016/1719.

The amendments concerning REMIT Regulation adapt the scope of REMIT to current and evolving market circumstances by inter alia extending the scope of data reporting to new electricity balancing markets and coupled markets as well algorithmic trading. It ensures stronger, more established and regular cooperation between energy and financial regulators, including ACER and ESMA regarding derivative wholesale energy products. It will as well improve process for the collection of inside information and market transparency by enhancing the oversight of ACER and adjustment of inside information definition. Amendments to REMIT Regulation enhance supervision of reporting parties such as Registered Reporting Mechanisms (RRMs) and persons professionally arranging transactions (PPATs). Amendments improve data sharing possibilities between ACER, relevant national authorities and the Commission. REMIT amendment introduces stronger role for ACER in investigations of significant cross-border cases to fight against the REMIT breaches. It also sets-out the framework for harmonisation of fines set by regulatory authorities at national level.

The amendments concerning the ACER Regulation aim to clarify the role of ACER as regards the single allocation platform established in accordance with Regulation (EU) 2016/1719 and as regards the new rules introduced in the Electricity Regulation concerning forward markets and flexibility support schemes. It also clarifies the role and competences of ACER in accordance with the amendment to REMIT Regulation. The amendment RED II aims to clarify the scope of application of the rules concerning the types of direct price support schemes for renewable energy sources that Member States may introduce.

2023/0077 (COD)

Proposal for a

REGULATION OF THE EUROPEAN PARLIAMENT AND OF THE COUNCIL

amending Regulations (EU) 2019/943 and (EU) 2019/942 as well as Directives (EU) 2018/2001 and (EU) 2019/944 to improve the Union’s electricity market design

(Text with EEA relevance)

THE EUROPEAN PARLIAMENT AND THE COUNCIL OF THE EUROPEAN UNION,

Having regard to the Treaty on the Functioning of the European Union, and in particular Article 194(2) thereof,

Having regard to the proposal from the European Commission,

After transmission of the draft legislative act to the national parliaments,

Having regard to the opinion of the European Economic and Social Committee,

Having regard to the opinion of the Committee of the Regions,

Acting in accordance with the ordinary legislative procedure,

Whereas:

(1)Very high prices and volatility in electricity markets have been observed since September 2021. As set out by the European Agency for the Cooperation of Energy Regulators (‘ACER’) in its April 2022 assessment of EU wholesale electricity market design
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  , this is mainly a consequence of the high price of gas, which is used as an input to generate electricity.

(2)The escalation of the Russian military aggression against Ukraine, a Contracting Party of the Energy Community, and related international sanctions since February 2022 have disrupted global energy markets, exacerbated the problem of high gas prices, and have had significant knock-on impacts on electricity prices. The Russian invasion of Ukraine has also caused uncertainty on the supply of other commodities, such as hard coal and crude oil, used by power-generating installations. This has resulted in substantial additional increases in the volatility of price levels of electricity.

(3)In response to this situation, the Communication on Energy Prices presented by the Commission in October 2021 contained a toolbox of measures that the EU and its Member States may use to address the immediate impact of high energy prices on households and businesses (including income support, tax breaks, gas savings and storage measures) and to strengthen resilience against future price shocks. In its Communication of 8 March 2022 entitled ‘REPowerEU: Joint European Action for more affordable, secure and sustainable energy’
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  the Commission outlined a series of additional measures to strengthen the toolbox and to respond to rising energy prices. On 23 March 2022, the Commission also established a temporary State Aid regime to allow certain subsidies to soften the impact of high energy prices.
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(4)On 18 May 2022 the Commission presented the REPowerEU plan
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   that introduced additional measures focusing on energy savings, diversification of energy supplies and accelerated roll-out of renewable energy aiming at ending the Union’s dependency on Russian fossil fuels, including a proposal to increase the Union’s 2030 target for renewables to 45%. Furthermore, the Communication on Short-Term Energy Market Interventions and Long-Term Improvements to the Electricity Market Design
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  , in addition to setting out additional short-term measures to tackle high energy prices identified potential areas for improving the electricity market design and announced the intention to assess these areas with a view to change the legislative framework.

(5)To address urgently the price crisis and security concerns and to tackle the price hikes for citizens, and based on a series of Commission proposals, the Union adopted a strong gas storage regime
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  , effective demand reduction measures for gas and electricity
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  , price limiting regimes to avoid windfall profits in both gas and electricity markets
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  and measures to accelerate the permit-granting procedures for renewable energy installations
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  .

(6)A well-integrated market which builds on the Clean Energy for all Europeans Package adopted in 2018 and 2019
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  should allow the Union to reap the economic benefits of a single energy market in normal market circumstances, ensuring security of supply and sustaining the decarbonisation process. Cross-border interconnectivity also ensures safer, more reliable and efficient operation of the power system.

(7)The current electricity market design has also helped the emergence of new and innovative products, services and measures on retail electricity markets, supporting energy efficiency and renewable energy uptake and enhancing choice so as to help consumers reduce their energy bills also through small-scale generation installations and emerging services for providing demand response. Building on and seizing the potential of the digitalisation of the energy system, such as active participation by consumers, should be a key element of our future electricity markets and systems. At the same time, there is a need to respect consumer choices and allow consumers to benefit from a variety of contract offers.

(8)In the context of the energy crisis, the current electricity market design has however also revealed a number of important shortcomings linked to the impact of high and volatile fossil fuel prices on short-term electricity markets, which expose households and companies to significant price spikes with effects on their electricity bills.

(9)A faster deployment of renewable energy and clean flexible technologies constitutes the most sustainable and cost-effective way of structurally reducing the demand for fossil fuels for electricity generation and for direct consumption through electrification and energy system integration. Thanks to their low operational costs, renewable sources can positively impact electricity prices across the Union and reduce direct consumption of fossil fuels.

(10)The changes to the electricity market design should ensure that the benefits from rising renewable power deployment, and the energy transition as a whole, are brought to consumers, including the most vulnerable ones, and ultimately, shield them from energy crises and avoid more households falling into energy poverty trap. These should mitigate the impact of high fossil fuel prices, notably that of gas, on electricity prices, aiming to allow households and companies to reap the benefits of affordable and secure energy from sustainable renewable and low carbon sources in the longer term.

(11)The reform of the electricity market design should benefit not just household consumers but also the competitiveness of the Union’s industries by facilitating their possibilities to make the clean tech investments they require to meet their net zero transition paths. The energy transition in the Union needs to be supported by a strong clean technology manufacturing basis. These reforms will support the affordable electrification of industry and the Union’s position as a global leader in terms of research and innovation in clean energy technologies.

(12)Well-functioning and efficient short-term markets are a key tool for the integration of renewable energy and flexibility sources in the market and facilitate energy system integration in a cost-effective manner.

(13)Intraday markets are particularly important for the integration of variable renewable energy sources in the electricity system at the least cost as they give the possibility to market participants to trade shortages or surplus of electricity closer to the time of delivery. Since variable renewable energy generators are only able to accurately estimate their production close to the delivery time, it is crucial for them to have a maximum of trading opportunities via access to a liquid market as close as possible to the time of delivery of the electricity.

(14)It is therefore important for the intraday markets to adapt to the participation of variable renewable energy technologies such as solar and wind as well as to the participation of demand side response and storage. The liquidity of the intraday markets should be improved with the sharing of the order books between market operators within a bidding zone, also when the cross-zonal capacities are set to zero or after the gate closure time of the intraday market. Furthermore, the gate closure time of the intraday market should be set closer to the time of delivery to maximize the opportunities for market participants to trade shortages and surplus of electricity and contribute to better integrating variable renewables in the electricity system.

(15)In addition, the short-term electricity markets should ensure that small-scale flexibility service providers can participate by lowering the minimum bid size.

(16)To ensure the efficient integration of electricity generated from variable renewable energy sources and to reduce the need for fossil-fuel based electricity generation in times when there is high demand for electricity combined with low levels of electricity generation from variable renewable energy sources, it should be possible for transmission system operators to design a peak shaving product enabling demand response to contribute to decreasing peaks of consumption in the electricity system at specific hours of the day. The peak shaving product should contribute to maximize the integration of electricity produced from renewable sources into the system by shifting the electricity consumption to moments of the day with higher renewable electricity generation. As the peak shaving product aims to reduce and shift the electricity consumption, the scope of this product should be limited to demand side response. The procurement of the peak shaving product should take place in such a way that it does not overlap with the activation of balancing products which aim at maintaining the frequency of the electricity system stable. In order to verify volumes of activated demand reduction, the transmission system operator should use a baseline reflecting the expected electricity consumption without the activation of the peak shaving product.

(17)In order to be able to actively participate in the electricity markets and to provide their flexibility, consumers are progressively equipped with smart metering systems. However, in a number of Member States the roll-out of smart metering systems is still slow. In those instances where smart metering systems are not yet installed and in instances where smart metering systems do not provide for the sufficient level of data granularity, transmission and distribution system operators should be able to use data from dedicated metering devices for the observability and settlement of flexibility services such as demand response and energy storage. Enabling the use of data from dedicated metering devices for observability and settlement should facilitate the active participation of the consumers in the market and the development of their demand response. The use of data from these dedicated metering devices should be accompanied by quality requirements relating to the data.

(18)This Regulation establishes a legal basis for processing of personal data in compliance with Article 6(1)(c) GDPR. Member States should ensure that all personal data protection principles and obligations laid down in the GDPR are met, including on data minimisation. Where the objective of this Directive can be achieved without processing of personal data, providers should rely on anonymised and aggregated data.

(19)Consumers and suppliers need effective and efficient forward markets to cover their long-term price exposure and decrease the dependence on short-term prices. To ensure that energy customers all over the EU can fully benefit from the advantages of integrated electricity markets and competition across the Union, the functioning of the Union’s electricity forward market should be improved via the establishment of regional virtual hubs with a view to overcome the existing market fragmentation and the low liquidity experienced in many bidding zones. Regional virtual hubs should cover multiple bidding zones while ensuring an adequate price correlation. Some bidding zones may not be covered by a virtual hub in terms of contributing to the hub reference price. However, market participants from these bidding zones should still be able to hedge through a hub.

(20)Virtual hubs should reflect the aggregated price of multiple bidding zones and provide a reference price, which should be used by market operators to offer forward hedging products. To that extent, virtual hubs should not be understood as entities arranging or executing transactions. The regional virtual hubs, by providing a reference price index, should enable the pooling of liquidity and provide better hedging opportunities to market participants.

(21)To enhance the possibilities of market participants for hedging, the role of the single allocation platform established in accordance with Commission Regulation (EU) 2016/1719 should be expanded. The single allocation platform should offer trading of financial long-term transmission rights between the different bidding zones and the regional virtual hubs. The orders submitted by market participants for financial transmission rights shall be matched by a simultaneous allocation of long term cross zonal capacity. Such matching and allocation should be performed on a regular basis, to ensure enough liquidity and, hence, efficient hedging possibilities to market participants. The long-term transmission rights should be issued with frequent maturities (ranging from month ahead to at least three years ahead), in order to be aligned with the typical hedging time horizon of market participants. The single allocation platform should be subject to monitoring and enforcement to ensure that it performs its tasks properly.

(22)Network tariffs should incentivise transmission and distribution system operators to use flexibility services through further developing innovative solutions to optimise the existing grid and to procure flexibility services, in particular demand response or storage. For this purpose, network tariffs should be designed so as to take into account the operational and capital expenditures of system operators or an efficient combination of both so that they can operate the electricity system cost-efficiently. This would further contribute to integrating renewables at the least cost for the electricity system and enable final customers to value their flexibility solutions.

(23)Offshore renewable energy sources, such as offshore wind, ocean energy and floating photovoltaic, will play an instrumental role in building a power system largely based on renewables and in ensuring climate neutrality by 2050. There are, however, substantial obstacles to their wider and efficient deployment preventing the massive scale up needed to achieve those objectives. Similar obstacles could arise for other offshore technologies in the future. These obstacles include investment risks associated with the unique topographical situation of offshore hybrid projects connected to more than one market. In order to reduce investment risk for these offshore project developers and to ensure that the projects in an offshore bidding zone have full market access to the surrounding markets, transmission system operators should guarantee access of the offshore project to the capacity of the respective hybrid interconnector for all market time units. If the available transmission capacities are reduced to the extent that the full amount of electricity generation that the offshore project would have otherwise been able to export cannot be delivered to the market, the transmission system operator or operators responsible for the need to limit the capacity should, in future, be enabled to compensate the offshore project operator commensurately using congestion income. This compensation should only be related to the production capability available to the market, which may be weather dependent and excludes the outage and maintenance operations of the offshore project. The details, including the conditions under which the measure may expire, are intended to be defined in an implementing Regulation.

(24)In the day-ahead wholesale market, the power plants with lower marginal costs are dispatched first, but the price received by all market participants is set by the last plant needed to cover the demand, which is the plant with the highest marginal costs, when the markets clear. In this context, the energy crisis has shown that a surge in the price of gas and hard coal can translate into exceptional and lasting increases of the prices at which the gas and coal-fired generation facilities bid in the day-ahead wholesale market. That in turn has led to exceptionally high prices in the day-ahead market across the Union, as gas and coal-fired generation facilities are often the plants with the highest marginal costs needed to meet the demand for electricity.

(25)Given the role of the price in the day-ahead market as a reference for the price in other wholesale electricity markets, and the fact that all market participants receive the clearing price, the technologies with significantly lower marginal costs have consistently recorded high revenues.

(26)To reach the Union’s decarbonisation targets and the objectives set out in REPowerEU to become more energy independent, the Union needs to accelerate the deployment of renewables at a much faster pace. In view of the investment needs required to achieve these goals, the market should ensure that a long-term price signal is established.

(27)In this framework, Member States should strive to create the right market conditions for long-term market-based instruments, such as power purchase agreements (‘PPAs’). PPAs are bilateral purchase agreements between producers and buyers of electricity. They provide long-term price stability for the customer and the necessary certainty for the producer to take the investment decision. Nevertheless, only a handful of Member States have active PPA markets and buyers are typically limited to large companies, not least because PPAs face a set of barriers, in particular the difficulty to cover the risk of payment default from the buyer in these long-term agreements. Member States should take into consideration the need to create a dynamic PPA market when setting the policies to achieve the energy decarbonisation objectives set out in their integrated national energy and climate plans.

(28)According to Article 15(8) of Directive (EU) 2018/2001 of the European Parliament and of the Council, Member States are to assess the regulatory and administrative barriers to long-term renewables PPAs, and shall remove unjustified barriers to, and promote the uptake of, such agreements. In addition, Member States are to describe policies and measures facilitating the uptake of renewables PPAs in their integrated national energy and climate plans. Without prejudice to that obligation to report on the regulatory context affecting the PPA market, Member States should ensure that instruments to reduce the financial risks associated to the buyer defaulting on its long-term payment obligations in the framework of PPAs are accessible to companies that face entry barriers to the PPA market and are not in financial difficulty in line with Articles 107 and 108 TFEU. Member States could decide to set up a guarantee scheme at market prices. Member States should include provisions to avoid lowering the liquidity in the electricity markets, such as by using financial PPAs. Member States should not provide support to PPAs that purchase generation from fossil fuels. While the default approach should be non-discrimination between consumers, Member States could decide to target these instruments to specific categories of consumers, applying objective and non-discriminatory criteria. In this framework, Member States should take into account the potential role of instruments provided at Union level, for instance by the European Investment Bank (‘EIB’).

(29)Member States have at their disposal several instruments to support the development of PPA markets when designing and allocating public support. Allowing renewable energy project developers participating in a public support tender to reserve a share of the generation for sale through a PPA would contribute to nurture and grow PPA markets. In addition, as part of these tender evaluation Member States should endeavour to apply criteria to incentivise the access to the PPA market for actors that face entry barriers, such as small and medium-sized enterprises (‘SMEs’), giving preference to bidders presenting a commitment to sign a PPA for part of the project’s generation from one or several potential buyers that face difficulties to access the PPA market.

(30)Where Member States decide to support publicly financed new investments (“direct price support schemes”) in low carbon, non-fossil fuel electricity generation to achieve the Union’s decarbonisation objectives, those schemes should be structured by way of two-way contracts for difference such as to include, in addition to a revenue guarantee, an upward limitation of the market revenues of the generation assets concerned. New investments for the generation of electricity should include investments in new power generating facilities, investments aimed at repowering existing power generating facilities, investments aimed at extending existing power generating facilities or at prolonging their lifetime.

(31)Such two-way contracts for difference would ensure that revenues of producers stemming from new investments in electricity generation which benefit from public support become more independent from the volatile prices of fossil fuels-based generation which typically sets the price in the day-ahead market.

(32)However, to the extent that the limitation to set out direct price support schemes in the form of two-way contracts for difference narrows down the types of direct price support schemes that Member States can adopt as regards renewable energy sources, it should be limited to low carbon, non-fossil fuel technologies, with low and stable operational costs and to technologies which typically do not provide flexibility to the electricity system, while excluding technologies that are at early stages of their market deployment. This is necessary to ensure that the economic viability of generation technologies with high marginal costs is not jeopardised and to maintain the incentives of the technologies which can offer flexibility to the electricity system to bid in the electricity market based on their opportunity costs. In addition, the limitation to set out direct price support schemes in the form of two-way contracts for difference should not apply to emerging technologies for which other types of direct price support schemes may be better placed to incentivise their uptake. The limitation should be without prejudice to the possible exemption for small-scale installations and demonstration projects pursuant to Article 4 (3) of (EU) 2018/2001 of the European Parliament and of the Council and consider the specificities of renewable energy communities in accordance with Article 22 (7) of that Directive.

(33)In view of the need to provide regulatory certainty of producers, the obligation for Member States to apply direct price support schemes for the production of electricity in the form of two-way contracts for difference should apply only to new investments for the generation of electricity from the sources specified in the recital above.

(34)Thanks to the upward limitation of the market revenues direct price support schemes in the form of two-way contracts for difference should provide an additional source of revenues for Member States in periods of high energy prices. To further mitigate the impact of high electricity prices on the energy bills of consumers, Member States should ensure that the revenues collected from producers subject to direct price support schemes in the form of two-way contracts for difference are passed on to all final electricity customers, including households, SMEs and industrial consumers, based on their consumption. The redistribution of revenues should be done in a way that ensures that consumers are still to some extent exposed to the price signal, so that they reduce their consumption when the prices are high, or shift it to periods of lower prices (which are typically periods with a higher share of RES production). Member States should ensure that the level playing-field and competition between the different suppliers is not affected by the redistribution of revenues to the final electricity consumers.

(35)Furthermore, Member States should ensure that the direct price support schemes, irrespective of their form, do not undermine the efficient, competitive and liquid functioning of the electricity markets, preserving the incentives of producers to react to market signals, including stop generating when electricity prices are below their operational costs, and of final customers to reduce consumption when electricity prices are high. Member States should ensure that support schemes do not constitute a barrier for the development of commercial contracts such as PPAs.

(36)Thus, two-way contracts for difference and power purchase agreements play complementary roles in advancing the energy transition and bringing the benefits of renewables and low carbon energy to consumers. Subject to the requirements set out in the present Regulation, Member States should be free to decide which instruments they use to achieve their decarbonisation objectives. Through PPAs, private investors contribute to additional renewable and low carbon energy deployment while locking low and stable electricity prices over the long-term. Likewise, through two-way contracts for difference, the same objective is achieved by public entities on behalf of consumers. Both instruments are necessary to achieve the Union’s decarbonisation targets through renewable and low carbon energy deployment, while bringing forward the benefits of low-cost electricity generation for consumers.

(37)The accelerated deployment of renewables necessitates a growing availability of flexibility solutions to ensure their integration to the grid and to enable the electricity system and grid to adjust to the variability of electricity generation and consumption across different time horizons. Regulatory authorities should periodically assess the need for flexibility in the electricity system based on the input of transmission and distribution system operators. The assessment of the flexibility needs of the electricity system should take into account all existing and planned investments (including existing assets that are not yet connected to the grid) on sources of flexibility such as flexible electricity generation, interconnectors, demand side response, energy storage or the production of renewable fuels, in view of the need to decarbonise the energy system. On this basis, Member States should define a national objective for non-fossil flexibility such as demand side response and storage which should also be reflected in their integrated national energy and climate plans.

(38)To achieve the national objective for non-fossil flexibility such as demand side response and storage investment needs, Member States can design or redesign capacity mechanisms in order to create a green and flexible capacity mechanism. Member States that apply a capacity mechanism in line with the existing rules should promote the participation of non-fossil flexibility such as demand side response and storage by introducing additional criteria or features in the design.

(39)To support environmental protection objectives the CO2 emissions’ limit, set out in Article 22(4) of Regulation (EU) 2019/943 of the European Parliament and of the Council, should be seen as an upper limit. Therefore, Member States could set technical performance standards and CO2 emissions’ limits that restrict participation in capacity mechanisms to flexible, fossil-free technologies in full alignment with the Guidelines on State aid for climate, environmental protection and energy
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  which encourage Member States to introduce green criteria in capacity mechanisms.

(40)In addition, if Member States do not apply a capacity mechanism or if the additional criteria or features in the design of their capacity mechanism are insufficient to achieve national objective for demand response and storage investment needs they could apply flexibility support schemes consisting of payments for the available capacity of non-fossil flexibility such as demand side response and storage.

(41)The connection of new generation and demand installations, in particular renewable energy plants, often faces delays in grid connection procedures. One of the reasons for such delays is the lack of available grid capacity at the location chosen by the investor, which implies the need for grid extensions or reinforcements to connect the installations to the system in a safe manner. A new requirement for electricity system operators, both at transmission and distribution levels, to publish and update information on the grid capacity available in their areas of operation would contribute to decision-making by investors on the basis of information of grid capacity availability within the system and thus to the required acceleration in the deployment of renewable energy.

(42)Furthermore, to tackle the problem of lengthy reply times on requests for connection to the grid, transmission and distribution system operators should provide clear and transparent information to system users about the status and treatment of their connection requests. Transmission and distribution system operators should endeavour to provide such information within a period of three months from the submission of the request.

(43)During the energy crisis, consumers have been exposed to extremely volatile wholesale energy prices and had limited opportunities to engage in the energy market. Consequently, many households, have been facing difficulties when paying their bills. Vulnerable consumers and the energy poor are the hardest hit
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  , but middle-income households have also been exposed to such difficulties. It is therefore important to update consumer rights and protections, allowing consumers to benefit from the energy transition, decouple their electricity bills from short term price movements on energy markets and rebalance the risk between suppliers and consumers.

(44)Consumers should have access to a wide range of offers so that they can choose a contract according to their needs. However, suppliers have reduced their offers, fixed-price contracts have become scarce, and the choice of offers has become limited. Consumers should always have the possibility to opt for an affordable fixed price and fixed term contract and suppliers should not unilaterally modify the terms and conditions before such contract expires.

(45)When suppliers’ do not ensure that their electricity portfolio is sufficiently hedged changes in wholesale electricity prices can leave them financially at risk and, result in their failure, passing on costs to consumers and other network users. Hence, it should be ensured that suppliers are appropriately hedged when offering fixed price contracts. An appropriate hedging strategy should take into account the suppliers' access to its own generation and its capitalisation as well as its exposure to changes in wholesale market prices.

(46)Consumers should be able to choose the supplier which offers them the price and service which best suits their needs. Advances in metering and sub-metering technology combined with information and communication technology mean that it is now technically possible to have multiple suppliers for a single premises. If they so wish, customers should be able to use these possibilities to choose a separate supplier notably for electricity to power appliances such as heat pumps or electric vehicles which have a particularly high consumption or which also have the capability to shift their electricity consumption automatically in response to price signals. Moreover, with fast-responding dedicated metering devices which are attached to or embedded in appliances with flexible, controllable loads, final customers can participate in other incentive-based demand response schemes that provide flexibility services on the electricity market and to transmission and distribution system operators. Overall, such arrangements should contribute to the increased uptake of demand response and to consumer empowerment allowing them to have more control over their energy use and bills, while providing to the electricity system additional flexibility in order to cope with demand and supply fluctuations.

(47)Due to the increasing complexity of energy offers and different marketing practices, consumers have often difficulties to fully understand what they sign up to. In particular, there is a lack of clarity on how the price is set, the conditions for the renewal of the contract, the consequences of terminating a contract or the reasons for changing conditions by the supplier. Therefore, the key information on energy offers should be provided to consumers by suppliers or market participants engaged in aggregation in a short and easily understandable manner prior to signing the contract.

(48)To ensure continuity of supply for consumers in case of supplier failure, Member States should be obliged to appoint suppliers of last resort which may be treated as the provider of universal service. That supplier might be the sales division of a vertically integrated undertaking which also performs distribution functions, provided that it meets the unbundling requirements of Article 35 of Directive (EU) 2019/944 of the European Parliament and of the Council. However, this does not imply an obligation of Member States to supply at a certain fixed minimum price.

(49)Energy sharing can create resilience against the effects of high and volatile wholesale market prices on consumers’ energy bills, empowers a wider group of consumers that do not otherwise have the option of becoming an active customer due to financial or spatial constraints, such as energy poor and vulnerable consumers, and leads to increased uptake of renewable energy by mobilising additional private capital investments and diversifying remuneration pathways. With the integration of appropriate price signals and storage facilities, electricity sharing can help lay the foundation to help tap into the flexibility potential of smaller consumers.

(50)Active customers that own, lease or rent a storage or generation facility should have the right to share excess production and empower other consumers to become active, or to share the renewable energy generated or stored by jointly leased, rented or owned facilities, either directly or through a third-party facilitator. Energy sharing arrangement are either based on private contractual agreement between active customers or organised through a legal entity. A legal entity that incorporates the criteria of a renewable energy community as defined in Directive (EU) 2018/2001 of the European Parliament and of the Council or a citizen energy community as defined in Directive (EU) 2019/944 of the European Parliament and of the Council can share with their members electricity generated from facilities they have in full ownership. The protection and empowerment framework for energy sharing should pay particular attention to energy poor and vulnerable consumers.

(51)Energy sharing operationalises the collective consumption of self-generated or stored electricity injected into the grid by more than one jointly acting active customers. Member States should put in place the appropriate IT infrastructure to allow for the administrative matching within a certain timeframe of consumption with self-generated or stored renewable energy for the purpose of calculating the energy component of the energy bill. The output of these facilities should be distributed among the aggregated consumer load profiles based on static, variable or dynamic calculation methods that can be pre-defined or agreed upon by the active customers.

(52)Vulnerable customers should be adequately protected from electricity disconnections and should, as well, not be put in a position that forces them to disconnect. The role of suppliers and all relevant national authorities to identify appropriate measures, in both the short and the long-term, which should be made available to vulnerable customers to manage their energy use and costs remain essential, including by means of close cooperation with social security systems.

(53)Public interventions in price setting for the supply of electricity constitute, in principle, a market-distortive measure. Such interventions may therefore only be carried out as public service obligations and are subject to specific conditions. Under this Directive regulated prices are possible for energy poor and vulnerable households, including below costs, and, as a transition measure, for households and micro-enterprises. In times of crisis, when wholesale and retail electricity prices increase significantly, and this is having a negative impact on the wider economy, Member States should be allowed to extend, temporarily, the application of regulated prices also to SMEs. For both households and SMEs, Member States should be temporarily allowed to set regulated prices below costs as long as this does not create distortion between suppliers and suppliers are compensated for the costs of supplying below cost. However, it needs to be ensured that such price regulation is targeted and does not create incentives to increase consumption. Hence, such price regulation should be limited to 80% of median household consumption for households, and 70% of the previous year’s consumption for SMEs. The Commission should determine when such an electricity price crisis exists and consequently when this possibility becomes applicable. The Commission should also specify the validity of that determination, during which the temporary extension of regulated prices applies, which may be for up to one year. To the extent that any of the measures envisaged by the present Regulation constitute State aid, the provisions concerning such measures are without prejudice to the application of Articles 107 and 108 TFEU.

(54)The measures envisaged by the present Regulation are also without prejudice to the application of Directive 2014/65/EU, Regulation (EU) 2016/1011 and Regulation (EU) 648/2012.

(55)Regulation (EU) 2019/942 of the European Parliament and of the Council, Regulation (EU) 2019/943 of the European Parliament and of the Council, Directive (EU) 2019/944 of the European Parliament and of the Council and Directive (EU) 2018/2001 of the European Parliament and of the Council should be amended accordingly.

(56)Since the objectives of this Regulation cannot be sufficiently achieved by the Member States, but can rather be better achieved at Union level, the Union may adopt measures, in accordance with the principle of subsidiarity as set out in Article 5 of the Treaty on European Union. In accordance with the principle of proportionality, as set out in that Article, this Regulation does not go beyond what is necessary to achieve those objectives.

HAS ADOPTED THIS REGULATION:

Article 1

Amendments to Regulation (EU) 2019/943 of the European Parliament and of the Council of 5 June 2019 on the internal market for electricity

Regulation (EU) 2019/943 is amended as follows:

(1) Article 1 is amended as follows:

[a] point (b) is replaced by the following:

‘(b) set fundamental principles for well-functioning, integrated electricity markets, which allow all resource providers and electricity customers non-discriminatory market access, enable the development of forward electricity markets to allow suppliers and consumers to hedge or protect themselves against the risk of future volatility in electricity prices, empower consumers, ensure competitiveness on the global market, enhance flexibility through demand response, energy storage and other non-fossil flexibility solutions, ensure energy efficiency, facilitate aggregation of distributed demand and supply, and enable market and sectoral integration and market-based remuneration of electricity generated from renewable sources;’

[b] the following point is added:

‘(e)
     support long-term investments in renewable energy generation and enable consumers’ to make their energy bills less dependent from fluctuations of short-term electricity market prices, in particular fossil fuel prices in the medium to long-term.’

(2) In Article 2, the following points are added:

‘(72) ‘peak hour’ means an hour with the highest electricity consumption combined with a low level of electricity generated from renewable energy sources, taking cross-zonal exchanges into account;

(73) ‘peak shaving’ means the ability of market participants to reduce electricity consumption at peak hours determined by the transmission system operator;

(74) ‘peak shaving product’ means a market-based product through which market participants can provide peak shaving to the transmission system operators;

(75) ‘virtual hub’ means a non-physical region covering more than one bidding zone for which an index price is set in application of a methodology;

(76) ‘two-way contract for difference’ means a contract signed between a power generating facility operator and a counterpart, usually a public entity, that provides both minimum remuneration protection and a limit to excess remuneration; the contract is designed to preserve incentives for the generating facility to operate and participate efficiently in the electricity markets and complies with the principles set out in Article 4(2) and Article 4(3), first and third subparagraphs, of Directive (EU) 2018/2001;

(77) ‘power purchase agreement’ or ‘PPA’ means a contract under which a natural or legal person agrees to purchase electricity from an electricity producer on a market basis;

(78) ‘market revenue’ means realised income an electricity producer receives in exchange for the sale and delivery of electricity in the Union, regardless of the contractual form in which such exchange takes place, and excluding any support granted by Member States;

(79) ‘dedicated metering device’ means a device attached to or embedded in an asset that sells demand response or flexibility services on the electricity market or to transmission and distribution system operators;

(80) ‘flexibility’ means the ability of an electricity system to adjust to the variability of generation and consumption patterns and grid availability, across relevant market timeframes.’

(3) Article 7 is amended as follows:

[a] paragraph 1 is replaced by the following:

‘1.
     Transmission system operators and NEMOs, or an entity designated by them, shall jointly organise the management of the integrated day-ahead and intraday markets in accordance with Regulation (EU) 2015/1222. Transmission system operators and NEMOs shall cooperate at Union level or, where more appropriate, at a regional level in order to maximise the efficiency and effectiveness of Union electricity day-ahead and intraday trading. The obligation to cooperate shall be without prejudice to the application of Union competition law. In their functions relating to electricity trading, transmission system operators and NEMOs shall be subject to regulatory oversight by the regulatory authorities pursuant to Article 59 of Directive (EU) 2019/944 and ACER pursuant to Articles 4 and 8 of Regulation (EU) 2019/942.’

[b] paragraph 2 is amended as follows:

(i) point (c) is replaced by the following:

(c) maximise the opportunities for all market participants to participate in cross-zonal and intra-zonal trade in a non-discriminatory way and as close as possible to real time across and within all bidding zones;

(ii) the following point (ca) is inserted:

‘(ca) be organised in such a way as to ensure the sharing of liquidity between all NEMOs, both for cross-zonal and for intra-zonal trade;’

(4) the following Articles 7a and 7b are inserted:

‘Article 7a

Peak shaving product

1.Without prejudice to Article 40(5) and 40(6) of the Electricity Directive, transmission system operators may procure peak shaving products in order to achieve a reduction of electricity demand during peak hours.

2.Transmission system operators seeking to procure a peak shaving product shall submit a proposal setting out the dimensioning and conditions for the procurement of the peak shaving product to the regulatory authority of the Member State concerned. The proposal of the transmission system operator shall comply with the following requirements:

(a)the dimensioning of the peak shaving product shall be based on an analysis of the need for an additional service to ensure security of supply. The analysis shall take into account a reliability standard or objective and transparent grid stability criteria approved by the regulatory authority. The dimensioning shall take into account the forecast of demand, the forecast of electricity generated from renewable energy sources and the forecast of other sources of flexibility in the system. The dimensioning of the peak shaving product shall be limited to ensure that the expected benefits of the product do not exceed the forecasted costs;

(b)the procurement of a peak shaving product shall be based on objective, transparent, non-discriminatory criteria and be limited to demand response;

(c)the procurement of the peak shaving product shall take place using a competitive bidding process, with selection based on the lowest cost of meeting pre-defined technical and environmental criteria;

(d)contracts for a peak shaving product shall not be concluded more than two days before its activation and the contracting period shall be no longer than one day;

(e)the activation of the peak shaving product shall not reduce cross-zonal capacity;

(f)the activation of the peak shaving product shall take place after the closure of the day-ahead market and before the start of the balancing market;

(g)the peak shaving product shall not imply starting generation located behind the metering point.

3.The actual reduction of consumption resulting from the activation of a peak shaving product shall be measured against a baseline, reflecting the expected electricity consumption without the activation of the peak shaving product. Transmission system operators shall develop a baseline methodology in consultation with market participants and submit it to the regulatory authority.

4.Regulatory authorities shall approve the proposal of the transmission system operators seeking to procure a peak shaving product and the baseline methodology submitted in accordance with paragraphs 2 and 3 or shall request the transmission system operators to amend the proposal where it does not meet the requirements set out in these paragraphs.

Article 7b

Dedicated metering device

1.“Member States shall allow transmission system operators and distribution system operators to use data from dedicated metering devices for the observability and settlement of demand response and flexibility services, including from storage systems.

2.Member States shall establish requirements for a dedicated metering device data validation process to check and ensure the quality of the respective data.’;

(5) Article 8 is amended as follows:

(a) paragraph 1 is replaced by the following:

‘NEMOs shall allow market participants to trade energy as close to real time as possible and at least up to the intraday cross-zonal gate closure time. By 1 January 2028, the intraday cross-zonal gate closure time shall be at the earliest 30 minutes ahead of real time.’

(b) paragraph 3 is replaced by the following:

‘NEMOs shall provide products for trading in day-ahead and intraday markets which are sufficiently small in size, with minimum bid sizes of 100kW or less, to allow for the effective participation of demand-side response, energy storage and small-scale renewables including direct participation by customers.’

[6] Article 9 is replaced by the following:

Article 9

Forward markets

1.By 1 December 2024 the ENTSO for Electricity shall submit to ACER, after having consulted ESMA, a proposal for the establishment of regional virtual hubs for the forward market. The proposal shall:

(a)define the geographical scope of the virtual hubs for the forward market, including the bidding zones constituting these hubs, aiming to maximise the price correlation between the reference prices and the prices of the bidding zones constituting virtual hubs;

(b)include a methodology for the calculation of the reference prices for the virtual hubs for the forward market, aiming to maximise the correlations between the reference price and the prices of the bidding zones constituting a virtual hub; such methodology shall be applicable to all virtual hubs and based on predefined objective criteria;

(c)include a definition of financial long-term transmission rights from bidding zones to the virtual hubs for the forward market;

(d)maximise the trading opportunities for hedging products referencing the virtual hubs for the forward market as well as for long term transmission rights from bidding zones to virtual hubs.

2.Within six months of receipt of the proposal on the establishment of the regional virtual hubs for the forward market, ACER shall evaluate it and either approve or amend it. In the latter case, ACER shall consult the ENTSO for Electricity before adopting the amendments. The adopted proposal shall be published on ACER's website.

3.The single allocation platform established in accordance with Regulation (EU) 2016/1719 shall have a legal form as referred to in Annex II to Directive (EU) 2017/1132 of the European Parliament and of the Council.

4.The single allocation platform shall:

(a)offer trading of long-term transmission rights between each bidding zone and virtual hub; where a bidding zone is not part of a virtual hub it may issue financial long-term transmission rights to a virtual hub or to other bidding zones that are part of the same capacity calculation region;

(b)allocate long-term cross-zonal capacity on a regular basis and in a transparent, market-based and non-discriminatory manner; the frequency of allocation of the long-term cross-zonal capacity shall support the efficient functioning of the forward market;

(c)offer trading of financial transmission rights that shall allow holders of these financial transmission rights to remove exposure to positive and negative price spreads, and with frequent maturities of up to at least three years ahead.

5.Where a regulatory authority considers that there are insufficient hedging opportunities available for market participants, and after consultation of relevant financial market competent authorities in case the forward markets concern financial instruments as defined under Article 4(1)(15), it may require power exchanges or transmission system operators to implement additional measures, such as market-making activities, to improve the liquidity of the forward market. Subject to compliance with Union competition law and with Directive (EU) 2014/65 and Regulations (EU) 648/2012 and 600/2014, market operators shall be free to develop forward hedging products, including long-term forward hedging products, to provide market participants, including owners of power-generating facilities using renewable energy sources, with appropriate possibilities for hedging financial risks against price fluctuations. Member States shall not require that such hedging activity may be limited to trades within a Member State or bidding zone.

(7) Article 18 is amended as follows:

[a] paragraph 2 is replaced by the following:

“2.
     Tariff methodologies shall reflect the fixed costs of transmission system operators and distribution system operators and shall consider both capital and operational expenditure to provide appropriate incentives to transmission system operators and distribution system operators over both the short and long run, including anticipatory investments, in order to increase efficiencies, including energy efficiency, to foster market integration and security of supply, to support the use of flexibility services, efficient investments including solutions to optimise the existing grid and facilitate demand response and related research activities, and to facilitate innovation in the interest of consumers in areas such as digitalisation, flexibility services and interconnection”;

[b] paragraph 8 is replaced by the following:

“8. Transmission and distribution tariff methodologies shall provide incentives to transmission and distribution system operators for the most cost-efficient operation and development of their networks including through the procurement of services. For that purpose, regulatory authorities shall recognise relevant costs as eligible, shall include those costs in transmission and distribution tariffs, and shall introduce performance targets in order to provide incentives to transmission and distribution system operators to increase efficiencies in their networks, including through energy efficiency, the use of flexibility services and the development of smart grids and intelligent metering systems.”

[c] in paragraph 9, point (f) is replaced by the following:

‘(f) methods to ensure transparency in the setting and structure of tariffs, including anticipatory investments;’

[d] in paragraph 9, the following point (i) is added:

‘(i) incentives for efficient investments in networks, including on flexibility resources and flexible connection agreements.’

[8] in Article 19, paragraph 2 is amended as follows:

[a] point (b) is replaced by the following:

(b) maintaining or increasing cross-zonal capacities through optimisation of the usage of existing interconnectors by means of coordinated remedial actions, where applicable, or covering costs resulting from network investments that are relevant to reduce interconnector congestion; or

[b] the following point (c) is added:

‘(c) compensating offshore generation plant operators in an offshore bidding zone if access to interconnected markets has been reduced in such a way that one or more transmission system operators have not made enough capacity available on the interconnector or the critical network elements affecting the capacity of the interconnector, resulting in the offshore plant operator not being able to export its electricity generation capability to the market.’

[9] The following chapter IIIa is inserted:

Chapter IIIa

Specific investment incentives to achieve the Union’s decarbonisation objectives

Article 19a

Power purchase agreements

1.Member States shall facilitate power purchase agreements (‘PPAs’) with a view to reaching the objectives set out in their integrated national energy and climate plan with respect to the dimension decarbonisation referred to in point (a) of Article 4 of Regulation (EU) 2018/1999, while preserving competitive and liquid electricity markets.

2.Member States shall ensure that instruments such as guarantee schemes at market prices, to reduce the financial risks associated to off-taker payment default in the framework of PPAs are in place and accessible to customers that face entry barriers to the PPA market and are not in financial difficulty in line with Articles 107 and 108 TFEU. For this purpose, Member States shall take into account Union-level instruments. Member States shall determine what categories of customers are targeted by these instruments, applying non-discriminatory criteria.

3.Guarantee schemes for PPAs backed by the Member States shall include provisions to avoid lowering the liquidity in electricity markets and shall not provide support to the purchase of generation from fossil fuels.

4.In the design of the support schemes for electricity from renewable sources, Member States shall allow the participation of projects which reserve part of the electricity for sale through a PPA or other market-based arrangements and endeavour to make use of evaluation criteria to incentivise the access to the PPA market for customers that face entry barriers. In particular, such evaluation criteria may give preference to bidders presenting a signed PPA or a commitment to sign a PPA for part of the project’s generation from one or several potential buyers that face entry barriers to the PPA market.

5.PPAs shall specify the bidding zone of delivery and the responsibility for securing cross-zonal transmission rights in case of a change of bidding zone in accordance with Article 14.

6.PPAs shall specify the conditions under which customers and producers may exit from PPAs, such as any applicable exit fees and notice periods, in accordance with Union competition law.

Article 19b

Direct price support schemes for new investments in generation

1.Direct price support schemes for new investments for the generation of electricity from the sources listed in paragraph 2 shall take the form of a two-way contract for differences. New investments for the generation of electricity shall include investments in new power-generating facilities, investments aimed at repowering existing power-generating facilities, investments aimed at extending existing power-generating facilities or at prolonging their lifetime.

2.Paragraph 1 shall apply to new investments in generation of electricity from the following sources:

(a)wind energy;

(b)solar energy;

(c)geothermal energy;

(d)hydropower without reservoir;

(e)nuclear energy;

3.Direct price support schemes in the form of two-way contracts for difference shall:

(a)be designed so that the revenues collected when the market price is above the strike price are distributed to all final electricity customers based on their share of consumption (same cost / refund per MWh consumed);

(b)ensure that the distribution of the revenues to final electricity customers is designed so as not to remove the incentives of consumers to reduce their consumption or shift it to periods when electricity prices are low and not to undermine competition between electricity suppliers;

Article 19c

Assessment of flexibility needs

1.By 1 January 2025 and every two years thereafter, the regulatory authority of each Member State shall assess and draw up a report on the need for flexibility in the electricity system for a period of at least 5 years, in view of the need to cost effectively achieve security of supply and decarbonise the power system, taking into account the integration of different sectors. The report shall be based on the data and analyses provided by the transmission and distribution system operators of that Member State pursuant to paragraph 2 and using the methodology pursuant to paragraph 3.

2.The report shall include an evaluation of the need for flexibility to integrate electricity generated from renewable sources in the electricity system and consider, in particular, the potential of non-fossil flexibility such as demand side response and storage to fulfil this need, both at transmission and distribution levels. The report shall distinguish between seasonal, daily and hourly flexibility needs.

3.The transmission and distribution system operators of each Member State shall provide the data and analyses needed for the preparation of the report referred to in paragraph 1 to the regulatory authority.

4.The ENTSO for Electricity and the EU DSO entity shall coordinate transmission and distribution system operators as regards the data and analyses to be provided in accordance with paragraph 2. In particular, they shall:

(a)define the type of data and format that transmission and distribution system operators shall provide to the regulatory authorities;

(b)develop a methodology for the analysis by transmission and distribution system operators of the flexibility needs, taking into account at least all existing sources of flexibility and planned investments at interconnection, transmission and distribution level as well as the need to decarbonise the electricity system.

5.The ENTSO for Electricity and the EU DSO entity shall closely cooperate with each other regarding the coordination of transmission and distribution system operators.

6.By 1 March 2024, the ENTSO for Electricity and the EU DSO entity shall jointly submit to ACER a proposal regarding the type of data and format to be submitted to regulatory authorities and the methodology referred to in paragraph 3. Within three months of receipt of the proposal, ACER shall either approve the proposal or amend it. In the latter case, ACER shall consult the ENTSO for Electricity and the EU DSO entity before adopting the amendments. The adopted proposal shall be published on ACER's website.

7.The regulatory authorities shall submit the reports referred to in paragraph 1 to ACER and publish them. Within 12 months of receipt of the reports, ACER shall issue a report analysing them and providing recommendations on issues of cross-border relevance regarding the findings of the regulatory authorities.

Article 19d

Indicative national objective for demand side response and storage

Based on the report of the regulatory authority pursuant to Article 19c(1), each Member State shall define an indicative national objective for demand side response and storage. This indicative national objective shall also be reflected in Member States’ integrated national energy and climate plans as regards the dimension ‘Internal Energy Market’ in accordance with Articles 3, 4 and 7 of Regulation (EU) 2018/1999 and in their integrated biennial progress reports in accordance with Article 17 of Regulation (EU) 2018/1999.

Article 19e

Flexibility support schemes

1.Member States which apply a capacity mechanism in accordance with Article 21 shall consider the promotion of the participation of non-fossil flexibility such as demand side response and storage by introducing additional criteria or features in the design of the capacity mechanism.

2.Where the measures introduced in accordance with paragraph 1 to promote the participation of non-fossil flexibility such as demand response and storage in capacity mechanisms are insufficient to achieve the flexibility needs identified in accordance with19d, Member States may apply flexibility support schemes consisting of payments for the available capacity of non-fossil flexibility such as demand side response and storage.

3.Member States which do not apply a capacity mechanism may apply flexibility support schemes consisting of payments for the available capacity of non-fossil flexibility such as demand side response and storage.

Article 19f

Design principles for flexibility support schemes

Flexibility support scheme for non-fossil flexibility such as demand response and storage applied by Member States in accordance with Article 19e(2) and (3) shall:

(a)not go beyond what is necessary to address the identified flexibility needs in a cost-effective manner;

(b)be limited to new investments in non-fossil flexibility such as demand side response and storage;

(c)must not imply starting fossil fuel-based generation located behind the metering point;

(d)select capacity providers by means of an open, transparent, competitive, non-discriminatory and cost-effective process;

(e)prevent undue distortions to the efficient functioning of the electricity markets including preserving efficient operation incentives and price signals and the exposure to price variation and market risk;

(f)provide incentives for the integration in the electricity market in a market-based and market-responsive way, while avoiding unnecessary distortions of electricity markets as well as taking into account possible system integration costs and grid stability;

(g)set out a minimum level of participation in the market in terms of activated energy, which takes into account the technical specificities of storage and demand response;

(h)apply appropriate penalties to capacity providers which do not respect the minimum level of participation in the market referred to in point (g), or which do not follow efficient operation incentives and prices signals;

(i)be open to cross-border participation.’;

(10) in Article 37 (1), point (a) is replaced by the following:

“(a), carrying out the coordinated capacity calculation in accordance with the methodologies developed pursuant to the forward capacity allocation guideline, the capacity allocation and congestion management guideline and the electricity balancing guideline adopted on the basis of Article 18(5) of Regulation (EC) No 714/2009;”;

(11) Article 50 is amended as follows:

(a) the following paragraph 4a is added:

“4a. Transmission system operators shall publish in a clear and transparent manner, information on the capacity available for new connections in their respective areas of operation, including in congested areas if flexible energy storage connections can be accommodated, and update that information regularly, at least quarterly.

Transmission system operators shall also provide clear and transparent information to system users about the status and treatment of their connection requests. They shall provide such information within a period of three months from the submission of the request ";

(12) in Article 57, the following paragraph 3 is added:

“3. Distribution system operators and transmission system operators shall cooperate with each other in publishing information on the capacity available for new connections in their respective areas of operation in a consistent manner and giving sufficient granular visibility to developers of new energy projects and other potential network users.

(13) in Article 59 (1), point (b) is replaced by the following:

“(b), capacity-allocation and congestion- management rules pursuant to Article 6 of Directive (EU) 2019/944 and Articles 7 to 10, 13 to 17, 19 and 35 to 37 of this Regulation, including rules on day-ahead, intraday and forward capacity calculation methodologies and processes, grid models, bidding zone configuration, redispatching and countertrading, trading algorithms, single day-ahead and intraday coupling including the possibility of being operated by a single entity, the firmness of allocated cross-zonal capacity, congestion income distribution, the allocation of financial long-term transmission rights by the single allocation platform, cross-zonal transmission risk hedging, nomination procedures, and capacity allocation and congestion management cost recovery;”;

(14) The following Article 69a is added:

Article 69a

Interaction with Union financial legislation

Nothing in this Regulation shall derogate from the provisions of Directive (EU) 2014/65, Regulation (EU) 648/2012 and Regulation (EU) 600/2014 when market participants or market operators engage in activities related to financial instruments in particular as defined under Article 4(1)(15) of Directive (EU) 2014/65.

(15) in Annex I point 1.2 is replaced by the following:

“1.2. Coordinated capacity calculation shall be performed for all allocation timeframes”.

Article 2

Amendments to Directive (EU) 2019/944 of the European Parliament and of the Council of 5 June 2019 on common rules for the internal market for electricity

Directive (EU) 2019/944 of the European Parliament and of the Council of 5 June 2019 on common rules for the internal market for electricity is amended as follows:

(1) Article 2 is amended as follows:

(a) points (8) and (49) is replaced by the following:

“(8)
     ‘active customer’ means a final customer, or a group of jointly acting final customers, who consumes or stores electricity generated within its premises located within confined boundaries or self-generated or shared electricity within other premises located within the same bidding zone, or who sells self-generated electricity or participates in flexibility or energy efficiency schemes, provided that those activities do not constitute its primary commercial or professional activity.”;

“(49) 'non-frequency ancillary service' means a service used by a transmission system operator or distribution system operator for steady state voltage control, fast reactive current injections, inertia for local grid stability, short-circuit current, black start capability, island operation capability and peak shaving;”

(b) the following points are added:

(15a) ‘fixed term, fixed price electricity supply contract’ means an electricity supply contract between a supplier and a final customer that guarantees the same contractual conditions, including the price, while it may, within a fixed price, include a flexible element with for example peak and off peak price variations;

(10a) ‘energy sharing’ means the self-consumption by active customers of renewable energy either:

(a)generated or stored offsite or on sites between them by a facility they own, lease, rent in whole or in part; or

(b)the right to which has been transferred to them by another active customer whether free of charge or for a price.

(10b) ‘peer-to-peer trading’ of renewable energy means peer-to-peer trading as defined in point (18) of Article 2 of Directive (EU) 2018/2001.

(24a) ‘supplier of last resort’ means a supplier who is designated by a Member State to take over the supply of electricity to customers of a supplier which has ceased to operate;

(2) Article 4 is replaced by the following:

“Article 4

Free choice of supplier

Member States shall ensure that all customers are free to purchase electricity from the supplier of their choice. Member States shall ensure that all customers are free to have more than one electricity supply contract at the same time, and that for this purpose customers are entitled to have more than one metering and billing point covered by the single connection point for their premises.”

(3) Article 11 is amended as follows:

(a) the title is replaced by the following:

‘Entitlement to a fixed term, fixed price and dynamic electricity price contract’;

(b) paragraph 1 is replaced by the following:

1.   Member States shall ensure that the national regulatory framework enables suppliers to offer fixed-term, fixed-price contracts and dynamic electricity price contracts. Member States shall ensure that final customers who have a smart meter installed can request to conclude a dynamic electricity price contract and that all final customers can request to conclude a fixed-term, fixed-price electricity price contract of a duration of at least one year, with at least one supplier and with every supplier that has more than 200 000 final customers.

(c) the following paragraph 1a is inserted:

1a. Prior to the conclusion or extension of any contract, final customers shall be provided with a summary of the key contractual conditions in a prominent manner and in concise and simple language. This summary shall include at least information on total price, promotions, additional services, discounts and include the rights referred to in points (a), (b), (d), (e) and (f) of Article 10(3). The Commission shall provide guidance in this regard.

(d) paragraph 2 is replaced by the following:

2.   Member States shall ensure that final customers are fully informed by the suppliers of the opportunities, costs and risks of dynamic electricity price contracts, and shall ensure that suppliers are required to provide information to the final customers accordingly, including with regard to the need to have an adequate electricity meter installed. Regulatory authorities shall monitor the market developments and assess the risks that the new products and services may entail and deal with abusive practices.

(4) The following Articles are inserted:

“Article 15a”

Right to energy sharing

1.All households, small and medium sized enterprises and public bodies have the right to participate in energy sharing as active customers.

(a)Active customers shall be entitled to share renewable energy between themselves based on private agreements or through a legal entity.

(b)Active customers may use a third party that owns or manages for installation, operation, including metering and maintenance a storage or renewable energy generation facility for the purpose of facilitating energy sharing, without that third party being considered an active customer.

(c)Member States shall ensure that active customers participating in energy sharing:

(d)are entitled to have the shared electricity netted with their total metered consumption within a time interval no longer than the imbalance settlement period and without prejudice to applicable taxes, levies and network charges;

(e)benefit from all consumer rights and obligations as final customers under this Directive, except in case of energy sharing between households with an installed capacity up to 10.8 kW and up to 50 kW for multi-apartment blocks using peer-to-peer trading agreements;

(f)have access to template contracts with fair and transparent terms and conditions for peer-to-peer trading agreements between households, and for agreements on leasing, renting or investing in storage and renewable energy generation facilities for the purpose of energy sharing; in case of conflicts arising over such agreements, final customers shall have access to out of court dispute settlement in accordance with Article 26;

(g)are not subject to unfair and discriminatory treatment by market participants or their balance responsible parties;

(h)are informed of the possibility for changes in bidding zones in accordance with Article 14 of Regulation (EU) 2019/943 and of the fact that the right to share energy is restricted to within one and the same bidding zone.

(i)Member States shall ensure that relevant transmission or distribution system operators or other designated bodies:

(j)monitor, collect, validate and communicate metering data related to the shared electricity with relevant final customers and market participants at least every month, and in accordance with Article 23;

(k)provide a relevant contact point to register energy sharing arrangements, receive information on relevant metering points, changes in location and participation, and, where applicable, validate calculation methods in a clear, transparent and timely manner.

2.Member States shall take appropriate and non-discriminatory measures to ensure that energy poor and vulnerable households can access energy sharing schemes. Those measures may include financial support measures or production allocation quota.

“Article 18a

Supplier risk management

1.National Regulatory Authorities shall ensure that suppliers have in place and implement appropriate hedging strategies to limit the risk of changes in wholesale electricity supply to the economic viability of their contracts with customers, while maintaining liquidity on and price signals from short-term markets.

2.Supplier hedging strategies may include the use of power purchase agreements. Where sufficiently developed markets for power purchase agreements exist which allow effective competition, Member States may require that a share of suppliers’ risk exposure to changes in wholesale electricity prices is covered using power purchase agreements for electricity generated from renewable energy sources matching the duration of their risk exposure on the consumer side, subject to compliance with Union competition law.

3.Member States shall endeavour to ensure the accessibility of hedging products for citizen energy communities and renewable energy communities.”

(5) The following Article XX is inserted:

“Article 27a

Supplier of last resort

1.Member States shall appoint suppliers of last resort at least for household customers. Suppliers of last resort shall be appointed in a fair, open, transparent and non-discriminatory procedure.

2.Final customers who are transferred to suppliers of last resort shall not lose their rights as customers, in particular those rights laid down in Articles 4, 10, 11, 12, 14, 18 and 26.

3.Member States shall ensure that suppliers of last resort promptly communicate the terms and conditions to transferred customers and ensure seamless continuity of service for those customers for at least 6 months.

4.Member States shall ensure that final customers are provided with information and encouragement to switch to a market-based offer.

5.Member States may require the supplier of last resort to supply electricity to household customers who do not receive market based offers. In such cases, the conditions set out in Article 5 shall apply.”

Article 28a

Protection from disconnections for vulnerable customers

Member States shall ensure that vulnerable customers are protected from electricity disconnections. This shall be provided as part of the concept of vulnerable customers pursuant to Article 28 (1) of this Directive and without prejudice to the measures set out in Article10(11).

(6) in Article 27, paragraph 1 is replaced by the following:

“1. Member States shall ensure that all household customers, and, where Member States consider it appropriate, small enterprises, enjoy universal service, namely the right to be supplied with electricity of a specified quality within their territory at competitive, easily and clearly comparable, transparent and non-discriminatory prices. To ensure the provision of universal service, Member States shall impose on distribution system operators an obligation to connect customers to their network under terms, conditions and tariffs set in accordance with the procedure laid down in Article 59(7). This Directive does not prevent Member States from strengthening the market position of the household customers and small and medium-sized non-household customers by promoting the possibilities for the voluntary aggregation of representation for that class of customers.”

(7) In Article 31, paragraph 3 is replaced by the following:

“3. The distribution system operator shall provide system users with the information they need for efficient access to, including use of, the system. In particular, the distribution system operator shall publish in a clear and transparent manner information on the capacity available for new connections in its area of operation, including in congested areas if flexible energy storage connections can be accommodated, and update that information regularly, at least quarterly.

Distribution system operators shall also provide clear and transparent information to system users about the status and treatment of their connection requests. They shall provide such information within a period of three months from the submission of the request.”

(8) Article 40 is amended as follows:

[a] a new paragraph is added after paragraph 6:

The requirements in paragraphs 5 and 6 shall not apply with regard to the peak shaving product procured in accordance with Article 7a of Regulation (EU) 2019/943.

(9) Article 59 is amended as follows:

[a] In paragraph 1, subparagraph (c) is replaced by the following:

(c), in close coordination with the other regulatory authorities, ensuring the compliance of the single allocation platform established in accordance with Regulation (EU) 2016/1719, the ENTSO for Electricity and the EU DSO entity with their obligations under this Directive, Regulation (EU) 2019/943, the network codes and guidelines adopted pursuant to Articles 59, 60 and 61 of Regulation (EU) 2019/943, and other relevant Union law, including as regards cross-border issues, as well as with ACER's decisions, and jointly identifying non-compliance of the single allocation platform, the ENTSO for Electricity and the EU DSO entity with their respective obligations; where the regulatory authorities have not been able to reach an agreement within a period of four months after the start of consultations for the purpose of jointly identifying non-compliance, the matter shall be referred to the ACER for a decision, pursuant to Article 6(10) of Regulation (EU) 2019/942;

[b] In paragraph 1, subparagraph (z) is replaced by the following:

(z) The regulatory authority shall have the following duties: monitoring the removal of unjustified obstacles to and restrictions on the development of consumption of self-generated electricity and citizen energy communities, including related to the connection of flexible distributed energy generation within a reasonable time in accordance with Article 58(d).

[c] paragraph 4 is replaced by the following:

4. The regulatory authority located in the Member State in which the single allocation platform, the ENTSO for Electricity or the EU DSO entity has its seat shall have the power to impose effective, proportionate and dissuasive penalties on those entities where they do not comply with their obligations under this Directive, Regulation (EU) 2019/943 or any relevant legally binding decisions of the regulatory authority or of ACER, or to propose that a competent court impose such penalties.

(10) the following Article 66a is inserted

“Article 66a

Access to affordable energy during an electricity price crisis

1.The Commission may by decision declare a regional or Union-wide electricity price crisis, if the following conditions are met:

(a)very high prices in wholesale electricity markets at least two and a half times the average price during the previous 5 years which is expected to continue for at least 6 months;

(b)sharp increases in electricity retail prices of at least 70% occur which are expected to continue for at least 6 months; and

(c)the wider economy is being negatively affected by the increases in electricity prices.

2.The Commission shall specify in its decision declaring a regional or Union-wide electricity price crisis the period of validity of that decision which may be for a period of up to one year.

3.Where the Commission has adopted a decision pursuant to paragraph 1, Member States may for the duration of the validity of that decision apply targeted public interventions in price setting for the supply of electricity to small and medium sized enterprises. Such public interventions shall:

(a)be limited to at most 70% of the beneficiary's consumption during the same period of the previous year and retain an incentive for demand reduction;

(b)comply with the conditions set out in Article 5(4) and (7);

(c)where relevant, comply with the conditions set out in Paragraph 4.

4.Where the Commission has adopted a decision pursuant to paragraph 1, Member States may for the duration of the validity of that decision, by way of derogation from Article 5(7), point (c), when applying targeted public interventions in price setting for the supply of electricity pursuant to Article 5(6) or paragraph 3 of this Article, exceptionally and temporarily set a price for the supply of electricity which is below cost provided that the following conditions are fulfilled:

(a)the price set for households only applies to at most 80% of median household consumption and retains an incentive for demand reduction;

(b)there is no discrimination between suppliers;

(c)suppliers are compensated for supplying below cost; and

(d)all suppliers are eligible to provide offers for the price for the supply of electricity which is below cost on the same basis.

(11) in Article 71, paragraph 1 is replaced by the following:

‘1.
     Member States shall bring into force the laws, regulations and administrative provisions necessary to comply with Article 2 points 8 and 49, Articles 3 and 5, Article 6(2) and (3), Article 7(1), point (j) and (l) of Article 8(2), Article 9(2), Article 10(2) to (12), Article 11(3) and (4), Articles 12 to 24, Articles 26, 28 and 29, Article 31(1), (2) and (4) to (10; Articles 32 to 34 and 36, Article 38(2), Articles 40 and 42, point (d) of Article 46(2), Articles 51 and 54, Articles 57 to 58, Article 59(1) points (a), (b) and (d) to (y), Article 59(2) and (3), Article 59(5) to (10), Articles 61 to 63, points (1) to (3), (5)(b) and (6) of Article 70 and Annexes I and II by 31 December 2020. They shall immediately communicate the text of those provisions to the Commission.

However, Member States shall bring into force the laws, regulations and administrative provisions necessary to comply with:

(a) point (5)(a) of Article 70 by 31 December 2019;

(b) point (4) of Article 70 by 25 October 2020.

Member States shall bring into force the laws, regulations and administrative provisions necessary to comply with Article 2 points 10a, 10b, 15a, 24a, Article 4, Article 11(1), (1a) and (2), Article15a, Article 18a, Article 27(1), Article 27a, Article 28a, Article 31(3), Article 40(7), Article 59(1) points (c) and (z), Article 59(4) and Article 66a by six months after entry into force of this Regulation.

When Member States adopt those measures, they shall contain a reference to this Directive or be accompanied by such a reference on the occasion of their official publication. They shall also include a statement that references in existing laws, regulations and administrative provisions to the Directive repealed by this Directive shall be construed as references to this Directive. Member States shall determine how such reference is to be made and how that statement is to be formulated.’

Article 3

Amendment to Directive (EU) 2018/2001of the European Parliament and of the Council of 11 December 2018 on the promotion of the use of energy from renewable sources

Directive (EU) 2018/2001 is amended as follows:

(1) Article 4(3) is amended as follows:

(a) the second subparagraph is replaced by the following:

‘To that end, with regard to direct price support schemes, support shall be granted in the form of a market premium, which could be, inter alia, sliding or fixed. This sentence shall not apply to support for electricity from the renewable sources listed in Article 19b(2) of Regulation (EU) 2019/944, to which Article 19b(1) of that Regulation applies.’

(2) in Article 36, paragraph 1 is replaced by the following:

‘1.   Member States shall bring into force the laws, regulations and administrative provisions necessary to comply with Articles 2 to 13, 15 to 31 and 37 and Annexes II, III and V to IX, by 30 June 2021. However, Member States shall bring into force the laws, regulations and administrative provisions necessary to comply with Article 4(3), second subparagraph, by [six months after entry into force of this Regulation].

They shall immediately communicate the text of those measures to the Commission.

When Member States adopt those measures, they shall contain a reference to this Directive or be accompanied by such a reference on the occasion of their official publication. They shall also include a statement that references in existing laws, regulations and administrative provisions to the Directive repealed by this Directive shall be construed as references to this Directive. Member States shall determine how such reference is to be made and how that statement is to be formulated.’

Article 4

Amendments to Regulation (EU) 2019/942 of the European Parliament and of the Council of 5 June 2019 establishing a European Union Agency for the Cooperation of Energy Regulators

Regulation (EU) 2019/942 is amended as follows:

(1) Article 2 is amended as follows:

(a) point (a) is replaced by the following:

‘(a) issue opinions and recommendations addressed to transmission system operators, the ENTSO for Electricity, the ENTSO for Gas, the EU DSO Entity, the single allocation platform established in accordance with Regulation (EU) 2016/1719, regional coordination centres and nominated electricity market operators , on approving the methodologies, terms and conditions in accordance with Article 4(4), Article 5(2), (3) and (4); on bidding zones reviews as referred to in Article 5(7); on technical issues as referred to in Article 6(1); on arbitration between regulators in accordance with Article 6(10); related to regional coordination centres as referred to in Article 7(2), point (a); on approving and amending methodologies and calculations and technical specifications as referred to in Article 9(1); on approving and amending methodologies as referred to in Article 9(3); on exemptions as referred to in Article 10; on infrastructure as referred to in Article 11 point (d); on matters related to wholesale market integrity and transparency pursuant to Article 12;’

(b) point (d) is replaced by the following:

“ (d) issue individual decisions on the provision of information in accordance with Article 3(2), Article 7(2), point (b), and Article 8, point (c); on approving the methodologies, terms and conditions in accordance with Article 4(4), Article 5(2), (3) and (4); on bidding zones reviews as referred to in Article 5(7); on technical issues as referred to in Article 6(1); on arbitration between regulators in accordance with Article 6(10); related to regional coordination centres as referred to in Article 7(2), point (a); on approving and amending methodologies and calculations and technical specifications as referred to in Article 9(1); on approving and amending methodologies as referred to in Article 9(3); on exemptions as referred to in Article 10; on infrastructure as referred to in Article 11, point (d); on matters related to wholesale market integrity and transparency pursuant to Article 12, on approving and amending proposals from the ENTSO for electricity related to the regional virtual hubs pursuant to Article 5(9); and on approving and amending proposals from the ENTSO for electricity and the EU DSO entity related to the methodology concerning the data and analysis to be provided as regards the flexibility needs pursuant to Article 5(10). ”;

(2) in Article 3(2), the following fourth subparagraph is added:

“This paragraph shall also apply to the single allocation platform established in accordance with Regulation (EU) 2016/1719.”;

(3) in Article 4, the following paragraph 9 is added:

“9. Paragraphs 6, 7 and 8 shall also apply to the single allocation platform established in accordance with Regulation (EU) 2016/1719.”;

(4) in Article 5(8), the following second subparagraph is added:”;

ACER shall monitor the single allocation platform established in accordance with Regulation (EU) 2016/1719.

(5) In Article 5, the following paragraph 9 is added:

“9. ACER shall approve and where necessary amend the proposal from the ENTSO for electricity on the establishment of the regional virtual hubs for the forward market pursuant to Article 9(2) of Regulation (EU) 2019/943.”

(6) In Article 5. the following paragraph 10 is added:

“10. ACER shall approve and where necessary amend the joint proposal from the ENTSO for electricity and the EU DSO entity related to the methodology concerning the data and analysis to be provided as regards the flexibility needs pursuant to Article 19e(5) of Regulation (EU) 2019/943."

(7) in Article 15, the following paragraph 5 is added:

“5. ACER shall issue a report analysing the national assessments of the flexibility needs and providing recommendations on issues of cross-border relevance regarding the findings of the regulatory authorities pursuant to Article 19e(6) of Regulation (EU) 2019/943.”;

Article 5
  Entry into force

This Regulation shall enter into force on the [xxx] day following that of its publication in the Official Journal of the European Union.

This Regulation shall be binding in its entirety and directly applicable in all Member States.

Done at Strasbourg,

For the European Parliament
     For the Council

The President
     The President

LEGISLATIVE FINANCIAL STATEMENT 'AGENCIES'

LEGISLATIVE FINANCIAL STATEMENT 'AGENCIES'

1.FRAMEWORK OF THE PROPOSAL/INITIATIVE

1.

FRAMEWORK OF THE PROPOSAL/INITIATIVE

1.1.Title of the proposal/initiative

1.1.

Title of the proposal/initiative

1.2.Policy area(s) concerned

1.2.

Policy area(s) concerned

1.3.The proposal/initiative relates to:

1.3.

The proposal/initiative relates to:

1.4.Objective(s)

1.4.

Objective(s)

1.4.1.General objective(s)

1.4.1.

General objective(s)

1.4.2.Specific objective(s)

1.4.2.

Specific objective(s)

1.4.3.Expected result(s) and impact

1.4.3.

Expected result(s) and impact

1.4.4.Indicators of performance

1.4.4.

Indicators of performance

1.5.Grounds for the proposal/initiative

1.5.

Grounds for the proposal/initiative

1.5.1.Requirement(s) to be met in the short or long term including a detailed timeline for roll-out of the implementation of the initiative

1.5.1.

Requirement(s) to be met in the short or long term including a detailed timeline for roll-out of the implementation of the initiative

1.5.2.Added value of Union involvement (it may result from different factors, e.g. coordination gains, legal certainty, greater effectiveness or complementarities). For the purposes of this point 'added value of Union involvement' is the value resulting from Union intervention, which is additional to the value that would have been otherwise created by Member States alone.

1.5.2.

Added value of Union involvement (it may result from different factors, e.g. coordination gains, legal certainty, greater effectiveness or complementarities). For the purposes of this point 'added value of Union involvement' is the value resulting from Union intervention, which is additional to the value that would have been otherwise created by Member States alone.

1.5.3.Lessons learned from similar experiences in the past

1.5.4.Compatibility with the Multiannual Financial Framework and possible synergies with other appropriate instruments

1.5.5.Assessment of the different available financing options, including scope for redeployment

1.6.Duration and financial impact of the proposal/initiative

1.7.Method(s) of budget implementation planned

2.MANAGEMENT MEASURES

2.1.Monitoring and reporting rules

2.2.Management and control system(s)

2.2.1.Justification of the management mode(s), the funding implementation mechanism(s), the payment modalities and the control strategy proposed

2.2.2.Information concerning the risks identified and the internal control system(s) set up to mitigate them

2.2.3.Estimation and justification of the cost-effectiveness of the controls (ratio of "control costs ÷ value of the related funds managed"), and assessment of the expected levels of risk of error (at payment & at closure)

2.3.Measures to prevent fraud and irregularities

3.ESTIMATED FINANCIAL IMPACT OF THE PROPOSAL/INITIATIVE

3.1.Heading(s) of the multiannual financial framework and expenditure budget line(s) affected

3.2.Estimated financial impact of the proposal on appropriations

3.2.1.Summary of estimated impact on operational appropriations

3.2.2.Estimated output funded with operational appropriations

3.2.3.Summary of estimated impact on administrative appropriations

3.2.3.1.Estimated requirements of human resources

3.2.4.Compatibility with the current multiannual financial framework

3.2.5.Third-party contributions

3.3.Estimated impact on revenue

LEGISLATIVE FINANCIAL STATEMENT 'AGENCIES'

1.
     FRAMEWORK OF THE PROPOSAL/INITIATIVE

1.1.
     Title of the proposal/initiative

Regulation (EU) of the European Parliament and of the Council amending Regulation (EU) 2019/943, Directive (EU) 2019/944, Directive (EU) 2018/2001 and Regulation (EU) 2019/942 to improve the EU’s electricity market design.

1.2.
     Policy area(s) concerned

1.2.

Policy area: Energy

Activity: European Green Deal

1.3.
     The proposal relates to

1.3.

X a new action

X

a new action

 a new action following a pilot project/preparatory action
  29



a new action following a pilot project/preparatory action

29

X the extension of an existing action

X

the extension of an existing action

 a merger of one or more actions towards another/a new action



a merger of one or more

actions towards another/a new action

1.4.
     Objective(s)

1.4.

1.4.1.
     General objective(s)

1.4.1.

See explanatory memorandum

1.4.2.
     Specific objective(s)

1.4.2.

The following specific objectives focus on those which are addressed by provisions which require additional resources for ACER and DG Energy.

Specific objective No 1:

Facilitating forward markets. Defining the new forward market trading hubs.

Specific objective No 2

Facilitating flexibility solutions, in particular demand response

Specific objective No 3:

Ensuring supplier hedging and fair rules as regards suppliers of last resort. Giving customers a right to energy sharing.

1.4.3.
     Expected result(s) and impact

1.4.3.

Specify the effects which the proposal/initiative should have on the beneficiaries/groups targeted.

Specify the effects which the proposal/initiative should have on the beneficiaries/groups targeted.

The additional resources will allow ACER and DG Energy to carry out the tasks necessary to fulfil their mandate under EU legislation as per the requirements under this proposal.

1.4.4.
     Indicators of performance

1.4.4.

Specify the indicators for monitoring progress and achievements.

Specify the indicators for monitoring progress and achievements.

See explanatory memorandum as regards monitoring progress and achievements of the initiative.

(a)
     Effectiveness and timeliness: indicators should allow to monitor performance by providing information on progress on a regular basis and on achievements along the programming period.

(a)

(b)
     Efficiency: processes should be optimised for collection and processing of data, avoiding unnecessary or duplicative requests for information.

(b)

(c)
     Relevance of the indicators and the need to limit the associated administrative burden.

(c)

(d)
     Clarity: indicators should be delivered in a clear and understandable form, with supporting metadata and in a form that facilitates proper interpretation and meaningful communication.

(d)

1.5.
     Grounds for the proposal/initiative

1.5.

1.5.1.
     Requirement(s) to be met in the short or long term including a detailed timeline for roll-out of the implementation of the initiative

The following assessment, to the extent that it concerns ACER, takes into account the estimates of resources needs in 2023 for comparabel tasks as identified in 2020/2021 by an independent consultant.

Specific objective No 1: Defining the new forward market trading hubs (Article 9):

A new provision is introduced requiring ENTSO-E to submit to ACER a proposal for the establishment of virtual hubs for the forward market. Within 6 months ACER shall either approve or amend it. After the establishment of such virtual hubs, it can be expected that ACER will need to continue monitoring them. ACER will also have a role in enforcing possible failure of compliance by the single allocation platform with EU legislation.

ACER

The design of such hub is of critical importance for their possibility to attract forward liquidity and replace the zonal products. The zone to hub model represents a significant paradigm shift compared to the existing design. In particular, the following new tasks will have to be performed:

Design (including detailed studies) on price formation of forward trading hubs (at least Core and Nordic, potentially others) as well as the approval of a new methodology of the topic

Design (including detailed studies) on price formation of forward trading hubs (at least Core and Nordic, potentially others) as well as the approval of a new methodology of the topic

Design (including detailed studies) on long-term transmission rights products to be offered (geographical reach and design)

Design (including detailed studies) on long-term transmission rights products to be offered (geographical reach and design)

Potential decisions on hedging opportunities stemming from the new requirements following escalations from NRAs

Potential decisions on hedging opportunities stemming from the new requirements following escalations from NRAs

Monitoring activities linked to the new hub design (LTTR volumes, hub liquidity, LTTR valuation, ...)

Monitoring activities linked to the new hub design (LTTR volumes, hub liquidity, LTTR valuation, ...)

Given the increasing importance of forward markets it is estimated that at least 1 FTE will be required for work related to virtual hubs and the single allocation platform.

ENER

Given that forward markets will increase in importance and complement, but not replace electricity markets over shorter time-frames (day-ahead, intraday, balancing) it is estimated that ensuring proper implementation of the new provisions will result in new workload for ENER totalling 1 FTE.

Specific objective No 2: Facilitating flexibility solutions, in particular demand response

Every two years the regulatory authority of each Member State shall assess and produce a report on the need for flexibility in the electricity system based on data and analyses from network operators. ENTSO-E and the EU DSO entity shall coordinate the network operators as regards this data and analyses. For this purpose ENTSO-E and the EU DSO shall propose a methodology. Within 6 months ACER shall either approve or amend it. The regulatory authorities shall submit their national assessments to ACER. ACER then shall issue a report within 12 months.

Member States shall set a national objective for demand side response and include them in their National Energy and Climate Plans. Those Member States which apply a capacity mechanism shall consider demand side response in the design of the capacity mechanism. Other provisions stipulate when financial support can be given to flexibility support schemes and design principles for such schemes.

Also related to this specific objective are new provisions are also introduced related to “peak shaving products” and on the use of data from metering devices.

ACER

Workload of ACER for approving or amending the methodology related to data and analysis of flexibility needs can be expected to be similar to the one for approving of amending ENTSO-E's draft methodology for the European Resource Adequacy Assessment, hence requiring 0.75 FTE. Workload of ACER for preparing the report on flexibility every two years can be expected to be similar to the one for the as well biennial best practice report on transmission and distribution tariffs methodologies pursuant to Article 18(9) of Regulation (EU) 2019/943, hence requiring 0.5 FTE. Additional workload can be expected due to the impact of facilitating flexibility solutions on assessing resource adequacy: ACER’s workload related to the European Resource Adequacy Assessment will likely increase. Furthermore, in case ENTSO-E or the EU DSO do not comply with their obligations under EU law, ACER may need to request information by Decision pursuant to Article 3(2) or ACER together with the national regulators may need to take action pursuant to Articles 4(6) to 4(8) of Regulation (EU) 2019/942 may need to be taken. Therefore, it is estimated that overall 2 FTE are needed for implementing specific objective 2.

ENER

Specific objective 2 will make the Commission’s assessment of capacity mechanisms (both the required preceeding implementation plan as well as the State aid process) more complex. Furthermore, Member States will report national objectives for demand side response under the National Energy and Climate Plan process, informatino which will need to be processed by the Commission. Therefore, it is estimated that this will create new workload for ENER totalling 1 FTE.

Specific objective No 3: Ensuring supplier hedging and fair rules as regards suppliers of last resort. Giving customers a right to energy sharing.

ACER

Not applicable

ENER

Specific objective No 3 includes new rules in the Electricity Directive whose proper transposition and implementation by Member States need to be monitored by the Commission. Furthermore, given that it directly concerns consumers, may lead to a significant number of complaints, letters etc. Therefore, it is estimated that this will create new workload for ENER totalling 1 FTE.

Overhead

ACER

Those additional FTE as described above do not include overhead. One additional FTE, preferably an AST replacing interim staff employed in the Corporate Services Department. ENER

Not applicable

1.5.2.
     Added value of Union involvement (it may result from different factors, e.g. coordination gains, legal certainty, greater effectiveness or complementarities). For the purposes of this point 'added value of Union involvement' is the value resulting from Union intervention which is additional to the value that would have been otherwise created by Member States alone.

1.5.2.

See explanatory memorandum

1.5.3.
     Lessons learned from similar experiences in the past

1.5.3.

The experience with previous legislative proposals has shown that staffing needs of ACER are easily underestimated. In order to avoid a repeat of the experience with the third internal market package of 2009, where underestimating the staffing needs resulted in structural understaffing (only comprehensively solved starting with the EU budget for 2022), for this proposal staffing needs are estimated for several years into the future.

1.5.4.
     Compatibility with the Multiannual Financial Framework and possible synergies with other appropriate instruments

1.5.4.

This initiative is included in the Commission Work Programme for 2023 as part of the European Green Deal.

1.5.5.
     Assessment of the different available financing options, including scope for redeployment

1.5.5.

The FTE are needed for additional tasks while existing tasks will not decrease in the foreseeable future.

1.6.
     Duration and financial impact of the proposal/initiative

 limited duration


     Proposal/initiative in effect from [DD/MM]YYYY to [DD/MM]YYYY


     Financial impact from YYYY to YYYY

X unlimited duration

Implementation with a start-up period from YYYY to YYYY,

followed by full-scale operation.

1.7.
     Method(s) of budget implementation planned
  30

X Direct management by the Commission through


     executive agencies

 Shared management with the Member States

X Indirect management by entrusting budget implementation tasks to:

 international organisations and their agencies (to be specified);

the EIB and the European Investment Fund;

X bodies referred to in Articles 70 and 71;

 public law bodies;

 bodies governed by private law with a public service mission to the extent that they are provided with adequate financial guarantees;

 bodies governed by the private law of a Member State that are entrusted with the implementation of a public-private partnership and that are provided with adequate financial guarantees;

 bodies or persons entrusted with the implementation of specific actions in the CFSP pursuant to Title V of the TEU, and identified in the relevant basic act.

Comments

2.
     MANAGEMENT MEASURES

2.

2.1.
     Monitoring and reporting rules

2.1.

Specify frequency and conditions.

Specify frequency and conditions.

According to its financial regulation, ACER has to provide, in the context of its Programming Document, an annual Work Programme including details on resources, both financial and human, per each of the activities carried out.

ACER reports monthly to DG ENER on budget execution, including commitments, and payments by budget title, and vacancy rates by type of staff.

In addition, DG ENER is directly represented in the governance bodies of ACER. Through its representatives in the Administrative Board, DG ENER will be informed of the use of the budget and the establishment plan at each of its meetings during the year.

Finally, also in line with financial rules, ACER is subject to annual requirements for reporting on activities and the use of resources through the Administrative Board and its Annual Activity Report.

The tasks directly implemented by DG ENER will follow the annual cycle of planning and monitoring, as implemented in the Commission and the executive agencies, including reporting the results through the Annual Activity Report of DG ENER.

2.2.
     Management and control system(s)

2.2.

2.2.1.
     Justification of the management mode(s), the funding implementation mechanism(s), the payment modalities and the control strategy proposed

2.2.1.

While ACER will have to develop new expertise, it is nevertheless most cost-effective to allocate the new tasks under this proposal to an existing agency which already works on similar tasks.

DG ENER established a control strategy for managing its relations with ACER, part of the 2017 Internal Control Framework of the Commission. ACER revised and adopted its own Internal Control Framework in December 2018.

2.2.2.
     Information concerning the risks identified and the internal control system(s) set up to mitigate them

2.2.2.

Main risk are wrong estimates as regards the workload created by this proposal, given that it introduces new tasks. This risk needs to be accepted, since, as experience has shown, if additional resources needs are not included in the initial proposal, it is very difficult to remedy this situation later on.

That the proposal includes several new tasks mitigates this risk, since while the workload of some future tasks may be underestimated, others may be overestimated, providing scope for possible future redeployment.

2.2.3.
     Estimation and justification of the cost-effectiveness of the controls (ratio of "control costs ÷ value of the related funds managed"), and assessment of the expected levels of risk of error (at payment & at closure)

2.2.3.

The allocation of additional tasks to the existing mandate of ACER is not expected to generate specific additional controls at ACER, therefore, the ratio of control costs over value of funds managed will remain unaltered.

Similarly, the tasks assigned for DG ENER will not result in additional controls or change in the ratio of control costs.

2.3.
     Measures to prevent fraud and irregularities

2.3.

Specify existing or envisaged prevention and protection measures, e.g. from the Anti-Fraud Strategy.

Specify existing or envisaged prevention and protection measures, e.g. from the Anti-Fraud Strategy.

ACER applies the anti-fraud principles of decentralised EU Agencies, in line with the Commission approach.

In March 2019 ACER adopted a new Anti-Fraud Strategy, repealing Decision 13/2014 of the Administrative Board of ACER. The new strategy, spanning over a three-year period, is based on the following elements: an annual risks assessment, the prevention and management of conflicts of interest, internal rules on whistleblowing, the policy and procedure for the management of sensitive functions, as well as measures related to ethics and integrity.

DG ENER also adopted a revised Anti-fraud Strategy (AFS) in 2020. The ENER AFS is based on the Comission Anti-fraud Strategy and a specific risk assessment carried out internally to identify the areas most vulnerable to fraud, the controls already in place and the actions necessary to improve DG ENER’s capacity to prevent, detect and correct fraud.

Both the ACER Regulation and the contractual provisions applicable to public procurement ensure that audits and on-the-spot checks can be carried out by the Commission services, including OLAF, using the standard provisions recommended by OLAF.

3.
     ESTIMATED FINANCIAL IMPACT OF THE PROPOSAL/INITIATIVE

3.

3.1.
     Heading(s) of the multiannual financial framework and expenditure budget line(s) affected

3.1.

Existing budget lines

Existing budget lines

In order of multiannual financial framework headings and budget lines.

In order

of multiannual financial framework headings and budget lines.

| Heading of multiannual financial framework | Budget line | Type of

  expenditure | Contribution |
| --- | --- | --- | --- |
| | Number | Diff./Non-diff.
  31 | from EFTA countries
  32 | from candidate countries and potential candidates
  33 | From other third countries | other assigned revenue |
| 02 | 02 10 06 and ITER budget line | Diff./Non-diff. | YES/NO | YES/NO | YES/NO | YES/NO |

Heading of multiannual financial framework

Heading of multiannual financial framework

Budget line

Budget line

Type of

  expenditure

Type of

expenditure

Contribution

Contribution

Number

Number

Diff./Non-diff.
  31

Diff./Non-diff.

31

from EFTA countries
  32

from EFTA countries

32

from candidate countries and potential candidates
  33

from candidate countries and potential candidates

33

From other third countries

From other third countries

other assigned revenue

other assigned revenue

02

02

02 10 06 and ITER budget line

02 10 06 and ITER budget line

Diff./Non-diff.

Diff./

Non-diff.

YES/NO

YES/

NO

YES/NO

YES

/NO

YES/NO

YES

/NO

YES/NO

YES

/NO

New budget lines requested

New budget lines requested

In order of multiannual financial framework headings and budget lines.

In order

of multiannual financial framework headings and budget lines.

Heading of multiannual financial framework

| Heading of multiannual financial framework | Budget line | Type of

  expenditure | Contribution |
| --- | --- | --- | --- |
| | Number | Diff./non-diff. | from EFTA countries | from candidate countries and potential candidates | from other third countries | other assigned revenue |
| | [XX.YY.YY.YY] | | YES/NO | YES/NO | YES/NO | YES/NO |

Budget line

Type of

  expenditure

Contribution

Number

Diff./non-diff.

from EFTA countries

from candidate countries and potential candidates

from other third countries

other assigned revenue

[XX.YY.YY.YY]

YES/NO

YES/NO

YES/NO

YES/NO

3.2.
     Estimated impact on expenditure

3.2.1.
     Summary of estimated impact on expenditure

EUR million (to three decimal places)

| Heading of multiannual financial

  framework | 01 | Single Market, Innovation and Digital |
| --- | --- | --- |

Heading of multiannual financial

  framework

01

Single Market, Innovation and Digital

ACER

| ACER | | | Year

  2024 | Year

  2025 | Year

  2026 | Year

  2027 | Enter as many years as necessary to show the duration of the impact (see point 1.6) | TOTAL |
| --- | --- | --- | --- | --- | --- | --- | --- | --- |
| Title 1: | Commitments | (1) | 0,684 | 0,684 | 0,684 | 0,684 | | | | 2,736 |
| | Payments | (2) | 0,684 | 0,684 | 0,684 | 0,684 | | | | 2,736 |
| Title 2: | Commitments | (1a) | | | | | | | | |
| | Payments | (2a) | | | | | | | | |
| Title 3: | Commitments | (3a) | | | | | | | | |
| | Payments | (3b) | | | | | | | | |
| TOTAL appropriations

  for ACER | Commitments | =1+1a +3a | 0,684 | 0,684 | 0,684 | 0,684 | | | | 2,736 |
| | Payments | =2+2a


  +3b | 0,684 | 0,684 | 0,684 | 0,684 | | | | 2,736 |

Year

  2024

Year

  2025

Year

  2026

Year

  2027

Enter as many years as necessary to show the duration of the impact (see point 1.6)

TOTAL

Title 1:

Commitments

(1)

0,684

0,684

0,684

0,684

2,736

Payments

(2)

0,684

0,684

0,684

0,684

2,736

Title 2:

Commitments

(1a)

Payments

(2a)

Title 3:

Commitments

(3a)

Payments

(3b)

TOTAL appropriations

  for ACER

Commitments

=1+1a +3a

0,684

0,684

0,684

0,684

2,736

Payments

=2+2a

+3b

0,684

0,684

0,684

0,684

2,736

| Heading of multiannual financial

  framework | 7 | ‘Administrative expenditure’ |
| --- | --- | --- |

Heading of multiannual financial

  framework

7

‘Administrative expenditure’

EUR million (to three decimal places)

| | | | Year

  2024 | Year

  2025 | Year

  2026 | Year

  2027 | Enter as many years as necessary to show the duration of the impact (see point 1.6) | TOTAL |
| --- | --- | --- | --- | --- | --- | --- | --- | --- |
| DG: ENER |
| □ Human Resources | 0,513 | 0,513 | 0,513 | 0,513 | | | | 2,052 |
| □ Other administrative expenditure | | | | | | | | |
| TOTAL DG ENER | Appropriations | 0,513 | 0,513 | 0,513 | 0,513 | | | | 2,052 |

Year

  2024

Year

  2025

Year

  2026

Year

  2027

Enter as many years as necessary to show the duration of the impact (see point 1.6)

TOTAL

DG: ENER

□ Human Resources

0,513

0,513

0,513

0,513

2,052

□ Other administrative expenditure

TOTAL DG ENER

Appropriations

0,513

0,513

0,513

0,513

2,052

TOTAL appropriations

  under HEADING 7
  34


  of the multiannual financial framework

| TOTAL appropriations

  under HEADING 7
  34


  of the multiannual financial framework | (Total commitments = Total payments) | 0,513 | 0,513 | 0,513 | 0,513 | | | | 2,052 |
| --- | --- | --- | --- | --- | --- | --- | --- | --- | --- |

(Total commitments = Total payments)

0,513

0,513

0,513

0,513

2,052

EUR million (to three decimal places)

| | | | Year

  2024 | Year

  2025 | Year

  2026 | Year

  2027 | Enter as many years as necessary to show the duration of the impact (see point 1.6) | TOTAL |
| --- | --- | --- | --- | --- | --- | --- | --- | --- |
| TOTAL appropriations

  under HEADINGS 1 to 7
  of the multiannual financial framework | Commitments | 1,197 | 1,197 | 1,197 | 1,197 | | | | 4,788 |
| | Payments | 1,197 | 1,197 | 1,197 | 1,197 | | | | 4,788 |

Year

  2024

Year

  2025

Year

  2026

Year

  2027

Enter as many years as necessary to show the duration of the impact (see point 1.6)

TOTAL

TOTAL appropriations

  under HEADINGS 1 to 7
  of the multiannual financial framework

Commitments

1,197

1,197

1,197

1,197

4,788

Payments

1,197

1,197

1,197

1,197

4,788

3.2.2.
     Estimated impact on [body]'s appropriations


     The proposal/initiative does not require the use of operational appropriations


     The proposal/initiative requires the use of operational appropriations, as explained below:

Amounts in EUR million (to three decimal places)

| Indicate objectives and outputs



   | | | Year

  N | Year

  N+1 | Year

  N+2 | Year

  N+3 | Enter as many years as necessary to show the duration of the impact (see point 1.6) | TOTAL |
| --- | --- | --- | --- | --- | --- | --- | --- | --- |
| | OUTPUTS |
| | Type
  35 | Average cost | No | Cost | No | Cost | No | Cost | No | Cost | No | Cost | No | Cost | No | Cost | Total No | Total cost |
| SPECIFIC OBJECTIVE No 1
  36
  ... | | | | | | | | | | | | | | | | |
| - Output | | | | | | | | | | | | | | | | | | |
| - Output | | | | | | | | | | | | | | | | | | |
| - Output | | | | | | | | | | | | | | | | | | |
| Subtotal for specific objective No 1 | | | | | | | | | | | | | | | | |
| SPECIFIC OBJECTIVE No 2 ... | | | | | | | | | | | | | | | | |
| - Output | | | | | | | | | | | | | | | | | | |
| Subtotal for specific objective No 2 | | | | | | | | | | | | | | | | |
| TOTAL COST | | | | | | | | | | | | | | | | |

Indicate objectives and outputs



Year

  N

Year

  N+1

Year

  N+2

Year

  N+3

Enter as many years as necessary to show the duration of the impact (see point 1.6)

TOTAL

OUTPUTS

Type
  35

Average cost

No

Cost

No

Cost

No

Cost

No

Cost

No

Cost

No

Cost

No

Cost

Total No

Total cost

SPECIFIC OBJECTIVE No 1
  36
  ...

- Output

- Output

- Output

Subtotal for specific objective No 1

SPECIFIC OBJECTIVE No 2 ...

- Output

Subtotal for specific objective No 2

TOTAL COST

Where applicable, amounts reflect the sum of the Union contribution to the agency and other revenue of the agency (fees and charges).

3.2.3.
     Estimated impact on ACER's human resources

3.2.3.1.
     Summary


     The proposal/initiative does not require the use of appropriations of an administrative nature

X
     The proposal/initiative requires the use of appropriations of an administrative nature, as explained below:

EUR million (to three decimal places) Where applicable, amounts reflect the sum of the Union contribution to the agency and other revenue of the agency (fees and charges).

| | Year

  2024 | Year

  2025 | Year

  2026 | Year

  2027 | TOTAL |
| --- | --- | --- | --- | --- | --- |

Year

  2024

Year

  2025

Year

  2026

Year

  2027

TOTAL

Temporary agents (AD Grades)

| Temporary agents (AD Grades) | 0,513 | 0,513 | 0,513 | 0,513 | 2,052 |
| --- | --- | --- | --- | --- | --- |
| Temporary agents (AST grades) | 0,171 | 0,171 | 0,171 | 0,171 | 0,684 |
| Temporary agents (AST/SC grades) | | | | | |
| Contract staff | | | | | |
| Seconded National Experts | | | | | |

0,513

0,513

0,513

0,513

2,052

Temporary agents (AST grades)

0,171

0,171

0,171

0,171

0,684

Temporary agents (AST/SC grades)

Contract staff

Seconded National Experts

TOTAL

| TOTAL | 0,684 | 0,684 | 0,684 | 0,684 | 2,736 |
| --- | --- | --- | --- | --- | --- |

0,684

0,684

0,684

0,684

2,736

Staff requirements (FTE):

| | Year

  2024 | Year

  2025 | Year

  2026 | Year

  2027 | TOTAL |
| --- | --- | --- | --- | --- | --- |

Year

  2024

Year

  2025

Year

  2026

Year

  2027

TOTAL

Temporary agents (AD Grades)

| Temporary agents (AD Grades) | 3 | 3 | 3 | 3 | 3 |
| --- | --- | --- | --- | --- | --- |
| Temporary agents (AST grades) | 1 | 1 | 1 | 1 | 1 |
| Temporary agents (AST/SC grades) | | | | | |
| Contract staff | | | | | |
| Seconded National Experts | | | | | |

3

3

3

3

3

Temporary agents (AST grades)

1

1

1

1

1

Temporary agents (AST/SC grades)

Contract staff

Seconded National Experts

TOTAL

| TOTAL | 4 | 4 | 4 | 4 | 4 |
| --- | --- | --- | --- | --- | --- |

4

4

4

4

4

Planned recruitment date for the FTEs is the 1 January 2024.

3.2.3.2.
     Estimated requirements of human resources for the parent DG


     The proposal/initiative does not require the use of human resources.


     The proposal/initiative requires the use of human resources, as explained below:

Estimate to be expressed in full amounts (or at most to one decimal place)

| | Year

  2024 | Year

  2025 | Year 2026 | Year 2027 | Enter as many years as necessary to show the duration of the impact (see point 1.6) |
| --- | --- | --- | --- | --- | --- |
| ·Establishment plan posts (officials and temporary staff) | | | | | | | |
| 20 01 02 01 and 20 01 02 02 (Headquarters and Commission’s Representation Offices) | 3 | 3 | 3 | 3 | | | |
| 20 01 02 03 (Delegations) | | | | | | | |
| 01 01 01 01 (Indirect research) | | | | | | | |
| 10 01 05 01 (Direct research) | | | | | | | |
| | | | | | | | |
| □ External staff (in Full Time Equivalent unit: FTE)
  37 | | | | | | | |
| 20 02 01 (AC, END, INT from the ‘global envelope’) | | | | | | | |
| 20 02 03 (AC, AL, END, INT and JPD in the Delegations) | | | | | | | |
| Budget line(s) (specify) 
  38 | - at Headquarters
  39 | (1) | | | | | | |
| | - in Delegations | (2) | | | | | | |
| 01 01 01 02 (AC, END, INT – Indirect research) | | | | | | | |
| 10 01 05 02 (AC, END, INT – Direct research) | | | | | | | |
| Other budget lines (specify) | | | | | | | |
| TOTAL | 3 | 3 | 3 | 3 | | | |

Year

  2024

Year

  2025

Year 2026

Year 2027

Enter as many years as necessary to show the duration of the impact (see point 1.6)

·Establishment plan posts (officials and temporary staff)

20 01 02 01 and 20 01 02 02 (Headquarters and Commission’s Representation Offices)

3

3

3

3

20 01 02 03 (Delegations)

01 01 01 01 (Indirect research)

10 01 05 01 (Direct research)

□ External staff (in Full Time Equivalent unit: FTE)
  37

20 02 01 (AC, END, INT from the ‘global envelope’)

20 02 03 (AC, AL, END, INT and JPD in the Delegations)

Budget line(s) (specify) 
  38

- at Headquarters
  39

(1)

- in Delegations

(2)

01 01 01 02 (AC, END, INT – Indirect research)

10 01 05 02 (AC, END, INT – Direct research)

Other budget lines (specify)

TOTAL

3

3

3

3

The human resources required will be met by staff from the DG who are already assigned to management of the action and/or have been redeployed within the DG, together if necessary with any additional allocation which may be granted to the managing DGunder the annual allocation procedure and in the light of budgetary constraints.

Description of tasks to be carried out:

Officials and temporary staff

| Officials and temporary staff | Three additional FTEs (ADs) are needed for the following additional tasks:


  ·To ensure proper implementation of the new provisions


  ·Furthermore, Member States will report national objectives for demand side response under the National Energy and Climate Plan process. This information will need to be processed by the Commission.


  ·To monitor the proper transposition and implementation by Member States of the new rules in the Electricity Directive. Furthermore, given that it directly concerns consumers, it may lead to a significant number of complaints, letters etc. |
| --- | --- |
| External staff | N/A |

Three additional FTEs (ADs) are needed for the following additional tasks:

·To ensure proper implementation of the new provisions

·Furthermore, Member States will report national objectives for demand side response under the National Energy and Climate Plan process. This information will need to be processed by the Commission.

·To monitor the proper transposition and implementation by Member States of the new rules in the Electricity Directive. Furthermore, given that it directly concerns consumers, it may lead to a significant number of complaints, letters etc.

External staff

N/A

3.2.4.
     Compatibility with the current multiannual financial framework


     The proposal/initiative is compatible the current multiannual financial framework.

X
     The proposal/initiative will entail reprogramming of the relevant heading in the multiannual financial framework.

The initiative has been triggered by the current energy crisis and hence was not factored in when the MFF headings were calculated. This specific initiative being new, it will require reprogramming both for the line of the contribution to ACER and the line that will support additional work within DG ENER.The budgetary impact on ACER as described in this legislative financial statement will be offset by a compensatory reduction on programmed spending in the ITER budget line.


     The proposal/initiative requires application of the flexibility instrument or revision of the multiannual financial framework
  40
  .



40

.

Explain what is required, specifying the headings and budget lines concerned and the corresponding amounts.

3.2.5.
     Third-party contributions

3.2.5.

The proposal/initiative does not provide for co-financing by third parties.

The proposal/initiative does not provide for co-financing by third parties.

The proposal/initiative provides for the co-financing estimated below:

EUR million (to three decimal places)

| | Year

  N | Year

  N+1 | Year

  N+2 | Year

  N+3 | Enter as many years as necessary to show the duration of the impact (see point 1.6) | Total |
| --- | --- | --- | --- | --- | --- | --- |
| Specify the co-financing body | | | | | | | | |
| TOTAL appropriations co-financed | | | | | | | | |

Year

  N

Year

  N+1

Year

  N+2

Year

  N+3

Enter as many years as necessary to show the duration of the impact (see point 1.6)

Total

Specify the co-financing body

TOTAL appropriations co-financed

3.3.
     Estimated impact on revenue

X
     The proposal/initiative has no financial impact on revenue.


     The proposal/initiative has the following financial impact:


     on own resources


     on other revenue

please indicate, if the revenue is assigned to expenditure lines 

EUR million (to three decimal places)

| Budget revenue line: | Appropriations available for the current financial year | Impact of the proposal/initiative
  41 |
| --- | --- | --- |
| | | Year

  N | Year

  N+1 | Year

  N+2 | Year

  N+3 | Enter as many years as necessary to show the duration of the impact (see point 1.6) |
| Article ............. | | | | | | | | |

Budget revenue line:

Appropriations available for the current financial year

Impact of the proposal/initiative
  41

Year

  N

Year

  N+1

Year

  N+2

Year

  N+3

Enter as many years as necessary to show the duration of the impact (see point 1.6)

Article .............

For miscellaneous ‘assigned’ revenue, specify the budget expenditure line(s) affected.

Specify the method for calculating the impact on revenue.

Specify the method for calculating the impact on revenue.