ACER runs a public consultation from 17 July 2023 to 25 September 2023 to gather stakeholders’ views on concrete amendment proposals on two European electricity grid connection network codes:

• Network Code on Requirements for Grid Connection of Generators; and 
• Network Code on Demand Connection.

Stakeholders can submit their comments separately, to one or both GC NCs.

The public consultation will last for 10 weeks.

Why change the rules?

Since the development of the first European grid connection codes in 2012, there have been important policy developments in decarbonising Europe’s energy and transport sectors.

The revisions of network codes are needed to update the existing regulatory framework to ensure Europe’s interconnected power system adapts to emerging trends, such as increasing number of electricity storage modules, electrical charging points for e-vehicles, or the proliferation of distributed energy resources.

What is the process of amending the rules?

In September 2022, the European Commission asked ACER to initiate the process of amending the existing European network codes. Since then, ACER has:

• published a Policy Paper;
• launched an initial public consultation to gather amendment proposals from stakeholders;
• held workshops on different technical topics; and
• developed concrete amendment proposals to the network codes for stakeholders' consultation.

On the basis of the input from this summer consultation, ACER prepared a recommendation for amendments to the European Commission later in 2023.

Access the public consultation page.

Learn more about the electricity grid connection codes.

Subscribe to receive automatic notifications on ACER’s public consultations.

On 30 May 2023, ACER approved the Transmission System Operators’ (TSOs’) proposal of 20 December 2022 to amend the methodology for calculating scheduled exchanges resulting from single day-ahead coupling (SDAC).

What is it about?

On 25 January 2023, the EU National Regulatory Authorities (NRAs) referred to ACER a joint TSOs’ proposal on the amendments to the methodology for calculating scheduled exchanges resulting from SDAC under the Capacity allocation and congestion management (CACM) Regulation.

What are the amendments about?

Having gained experience from multiple nominated electricity market operator (NEMO) arrangements, TSOs identified improvements to the methodology, particularly for calculating scheduled exchanges between NEMO trading hubs.

Before approving the TSOs’ proposal, ACER assessed whether changes would contribute to market integration, non-discrimination, effective competition and proper functioning of the EU electricity market. To make an informed decision, ACER also consulted stakeholders in March 2023.

What are the next steps?

TSOs shall implement the methodology for calculating scheduled exchanges resulting from SDAC no later than three months after its approval, i.e. by 30 August 2023.

Access the:

• ACER Decision 10/2023 on the methodology for calculating scheduled exchanges resulting from single day-ahead coupling 
• Annex I
• Annex Ia
• Annex II

ACER invites EU electricity experts to help identify and define 'structural congestion”, in electricity networks. The Regulation on capacity allocation and congestion management (CACM) defines structural congestion in rather vague terms as congestion:

• that can be unambiguously defined;
• is predictable;
• is geographically stable over time; and
• is frequently recurring under normal power system conditions.

ACER considers that the current definition of structural congestion needs to be improved and would benefit from quantitative criteria to better identify such congestion.

Hence, ACER seeks EU electricity network experts' views on how structural congestion should be defined quantitatively and invites them to fill in a survey by 15 June 2023.

On 19 December 2022, the national regulatory authorities (NRAs) of the Nordic Capacity Calculation Region (CCR) requested an extension to decide on the Nordic Transmission System Operators’ (TSOs’) proposed amendment to the market-based cross-zonal capacity allocation methodology.

On 14 April 2023, ACER granted an extension of six months to the Nordic CCR NRAs (Denmark, Finland, Sweden).

What is the market-based allocation process?

The market-based allocation process compares the market value of cross-zonal capacity for the electricity balancing capacity market with the forecasted market value for the day-ahead electricity market. It then allocates the capacity to the market that generates the most welfare by using the cross-zonal capacity, which:

• allows the integration of balancing capacity markets;
• creates welfare;
• lowers the costs for the procurement of balancing capacity;
• lowers the costs for tariff payers; and
• ensures security of supply.

What are the next steps?

Nordic NRAs have until 28 June 2023 to decide on the proposal of the Nordic TSOs’ for amendment to the market-based cross-zonal capacity allocation methodology.

Access the ACER Decision 09/2023 on the extension request for Nordic CCR.

​Each year, the European Network of Transmission System Operators for Electricity (ENTSO-E) assesses the risks to EU security of electricity supply for up to 10 years ahead with its European Resource Adequacy Assessment (ERAA). ERAA is submitted for ACER’s decision by 1 November each year.

ACER appreciates ENTSO-E`s efforts to consult on the 2023 ERAA assumptions and data. Robust results come from robust input data and stakeholder involvement is key in ensuring it.

ACER did not approve the first two ERAAs submitted by ENTSO-E (see the links to the ACER decisions on ERRA 2021 and 2022 respectively).  The ACER decisions provided recommendations to ENTSO-E to improve their subsequent ERAA.

Taking into account the experience gained in the first two years of ERAA, ACER has decided to contribute to the consultation. The aim is to transparently and concretely express ACER’s key data-related concerns to allow ENTSO-E to address them before their submission of the draft ERRA 2023 to ACER later this year. 

ACER’s key suggestions on how to improve the assessment

To improve the assessment, data input needs to be:

• consistently applied within the two ERRA modules (adequacy & investment), and
• consistent with the relevant EU and national policy goals and plans.

Figure 1: ACER’s focus is consistency of data input between ERAA modules and policy goals

Key areas of ACER’s concern

Cross-zonal capacities:

• Cross-zonal electricity exchange represents an important adequacy resource, hence assumptions regarding cross-zonal capacities and the underlying interconnectors are crucial.

• ACER urges ENTSO-E to consistently consider cross-zonal capacities according to the Ten-Year Network Development Plan (TYNDP) developed by the TSOs and ENTSO-E.

Climate-related assumptions:

• Climatic variables can have a significant effect on security of electricity supply and thus on the ERAA results.
• ACER highlights the importance of the consistent application of climatic variables across the two ERAA modules (adequacy & investment).

See ACER’s reply to ENTSO-E’s public consultation on ERAA 2023.

ACER publishes today its Recommendation on the treatment of electricity losses in the Inter-Transmission System Operator Compensation (ITC) mechanism.

What is the ITC mechanism?

The ITC mechanism compensates Transmission System Operators (TSOs) for the costs incurred on national power systems for hosting cross-border flows of electricity (transits). The ITC fund seeks to cover the costs of the incurred transmission losses and infrastructure’s availability.

What are power losses?

Power losses happen with electricity’s transmission and they can give rise to significant costs. In most EU countries, the procurement of energy to cover transmission losses is in the hands of the TSOs. Reducing losses decreases the operational costs of power grids and increases benefits to the society.

The ACER Recommendation is addressed to the European Network of Transmission System Operators for Electricity (ENTSO-E), TSOs and National Regulatory Authorities (NRAs) after ACER having identified potential shortcomings in its latest yearly monitoring report on the ITC mechanism.

What is the summary of ACER’s recommendations?

• The number of snapshots used for the estimation of the volume of losses due to transits should be increased;
• An ex-post reconciliation of the costs of losses due to transits should be applied in the ITC mechanism, to reflect the costs actually incurred; and
• Where relevant, and at least as an interim measure, liquid forward-market prices should be considered instead of historical prices for determination of the relevant components of the value of losses for the ITC mechanism.

Access the Access the ACER Recommendation on the Treatment of Losses for the Purpose of the ITC Mechanism.

ACER launches today a public consultation on electricity grid operators’ proposals for a harmonised cross-zonal capacity allocation methodology for procuring electricity balancing capacity.

Electricity grid operators must keep the power system stable or in balance. Allocating cross-zonal capacity to balancing capacity enables the power system to be balanced more efficiently.

ACER received the Transmission System Operators’ (TSOs’) and ENTSO-E’s proposals:

• for the harmonised methodology for cross-zonal capacity allocation for the exchange of balancing capacity or sharing of reserves;
• for the Regional Coordination Centres’ (RCCs') task of regional sizing; and
• for the RCCs’ task of facilitating the procurement of electricity balancing capacity.

These three proposals aim at integrating balancing capacity markets with the use of cross-zonal capacities. The goal is to lower the costs of procuring electricity balancing capacity while ensuring security of supply. This can be archieved by reducing the overall balancing capacity needs and by lowering the procurement cost of that balancing capacity which needs to be procured.

What are the next steps?

• ACER will assess these proposals and decide on all three by July 2023.
• To collect the views of stakeholders, ACER is running a public consultation on the proposals from 13 April to 11 May 2023.
• ACER invites interested stakeholders to a workshop on 19 April 2023. 

On 31 March 2023, with its Decision 08/2023, ACER approved for the European Union a proposal from 13 October 2022 by Transmission System Operators (TSOs) to include the Norwegian bidding zone borders into the electricity capacity calculation regions (CCRs).

What are the amendments about?

Norway is part of the internal energy market through the Agreement on the European Economic Area (EEA). In 2021, following the Capacity allocation and congestion management (CACM) Regulation becoming binding for Norway, TSOs proposed the inclusion of the Norwegian bidding zone borders in the Hansa and Nordic CCRs.

Before approving the TSOs’ proposal for the EU, ACER assessed whether the changes would contribute to market integration, non-discrimination, effective competition and the proper functioning of the EU electricity market. The EFTA Surveillance Authority (ESA) is conducting in parallel its assessment to prepare its decision for Norway.

To make an informed decision, ACER also consulted stakeholders across the EEA through a public consultation between 28 October and 25 November 2022.

What are the capacity calculation regions and why are they important?

CCRs define the geographic areas (i.e. by listing bidding zone borders) across Europe in which the task of capacity calculation and other processes are coordinated by the TSOs (i.e. subject to regional methodologies).

There are 8 CCRs in Europe: Nordic, Hansa, Core, Italy North, Greece-Italy (GRIT), South-west Europe (SWE), Baltic and South-east Europe (SEE).

Forming CCRs benefits European consumers, as it:

• allows TSOs to run regional processes related to capacity calculation, re-dispatch and countertrading more effectively;
• facilitates the optimal provision of cross-zonal capacity, which allows more cross-zonal trade while ensuring security of supply; and
• further facilitates welfare increases by integrating Norwegian bidding zone borders in European and regional processes.

What are the next steps?

ESA, responsible for overseeing the application of the EEA rules in Iceland, Liechtenstein and Norway, has been asked by the Norwegian Energy Regulatory Authority for (NVE-RME) to decide on the CCR methodology for Norway.

The amendments of the CCRs decided by ACER for the EU will become applicable provided that ESA and NVE-RME adopt their respective decisions on the CCR methodology.

Access the ACER Decision on the amendment to the determination of capacity calculation regions and its annexes:

• ACER Decision 08/2023 on the amendment to the determination of capacity calculation regions
• Annex I
• Annex Ia
• Annex II
• Annex III

Europe requires significant investment in energy infrastructure that is cost-efficient to successfully achieve the energy transition. Every two years, the European grid operators submit their Ten-Year Network Development Plan (or TYNDP) to ACER. Today, ACER identifies, in its two opinions, improvements and shortcomings of the 2022 draft electricity TYNDP developed by the European Network of Transmission System Operators for Electricity (ENTSO-E):

• ACER Opinion on the methodological aspects of the ENTSO-E TYNDP 2022; and
• ACER Opinion on electricity projects in the draft ENTSO-E TYNDP 2022 and in the National Development Plans (NDPs).

What is the TYNDP?

The main objectives of the TYNDP are to:

• Identify investment gaps (including cross border capacities);
• Contribute to a sufficient and non-discriminatory level of cross-border interconnections, effective competition and efficient functioning of the market;
• Ensure a greater transparency of the European electricity transmission network.

The TYNDP also provides essential and comprehensive information for the selection of projects of common interest (PCIs).

What are ACER’s main findings?

In ACER’s opinion, the draft electricity TYNDP 2022 does not sufficiently contribute to the efficient and secure functioning of the electricity market.

While the 2022 draft electricity TYNDP shows certain improvements…

ACER acknowledges the resource intensiveness and complexity of the TYNDP process and welcomes a number of improvements in the 2022 draft electricity TYNDP, for instance in the:

• Inclusion Guidelines;
• Consultation on the Implementation Guidelines;
• Needs identification; and
• Increased transparency of the cost benefit analysis (CBA) assessment.

…ACER also finds shortcomings

ACER finds that the plan does not sufficiently contribute to the efficient and secure functioning of the electricity market, especially compared to previous TYNDPs, mainly due to five shortcomings:

• Insufficient and untimely consultations on the main methodological elements of the TYNDP package (i.e. the scenarios methodology, the needs methodology and the implementation of the CBA methodology).
• Delays in the draft TYNDP delivery, resulting in outdated data and delays in the PCI selection processes.
• Insufficient scope of the CBA analysis, focusing on the 2030 study year, and mainly on one scenario.  
• The starting grid (used as a starting point for the calculation of infrastructure needs) and the reference grids (used as counterfactual in the TYNDP CBA for the calculation of the project benefits) are not fully in line with the criteria set by ENTSO-E.
• Inconsistent data regarding the transfer capabilities.

In addition, ACER was not able to assess whether the system’s resilience to climate change impacts is addressed in the draft electricity TYNDP 2022.

What does ACER recommend for future electricity TYNDPs?

ACER proposes several recommendations to ENTSO-E to serve European consumers and Europe’s decarbonisation and sector integration ambitions.

For the 2022 final Electricity TYNDP, ACER recommends ENTSO-E to:

• Make all relevant inputs accessible in a clear and straightforward format as part of the 2022 final electricity TYNDP publication.
• Provide transparency on how the investment costs for the needs identification were derived by distinguishing between internal reinforcements and overall project costs.
• Publish for each cross-zonal boundary and each flow direction the transfer capacities of the current grid, starting grid (for the purpose of needs identification) and of the reference grid for 2030 and for 2040.
• Use the 10,000 EUR/MWh Value of Lost Load (VoLL) where no specific data is available.
• Explain how an assessment of resilience, if any, was carried out in the 2022 final electricity TYNDP (potentially including improvements for future TYNDPs).
• Review and eliminate the project-specific inconsistencies reported in ACER Opinion on electricity projects and consider the differences identified by national regulators between the NDPs and the 2022 draft electricity TYNDP.

For the 2024 electricity TYNDP and beyond, ACER recommends ENTSO-E to, inter alia:

• Restructure the TYNDP development process in order to complete it by December of the TYNDP year (considering also ACER’s opinion).
• Conduct a substantial consultation of the important methodological elements and parameters considered in the various deliverables of the TYNDP early enough in the process to have the capability to consider stakeholders’ comments.
• Calculate the benefits of projects according to all the joint scenarios developed by ENTSOs, and for all relevant time horizons to ensure adequate consideration of uncertainty.
• Base the modelling of the grid on an appropriate starting grid (for the needs exercise) and reference grids (for the CBA assessments) by including only the projects which strictly comply with the rules set in the respective implementation guidelines.
• Calculate the additional transfer capabilities of each project (and not leave this task to the promoters themselves), perform the calculations with more granularity (e.g. calculate at least seasonal NTCs) and improve their transparency.
• Consider the impact of the 70% interconnection capacity availability targets where relevant in the modelling of the power system for the development of the TYNDP.
• Enhance the consistency between the NDPs and the EU TYNDP by implementing the measures recommended in the ACER Opinion on electricity projects.

Access the ACER opinions:

ACER Opinion 03/2023 on the methodological aspects of the ENTSO-E TYNDP 2022.

ACER Opinion 04/2023 on electricity projects in the draft ENTSO-E TYNDP 2022 and in the National Development Plans (NDPs).

On 1 March 2023, ACER received the Transmission System Operators (TSOs) proposal for the amendment of the Harmonised Allocation Rules (HAR) for long-term electricity transmission rights, mainly to allow for their long-term flow-based allocation. ACER launched a public consultation on 29 August 2023 on the amendments to the rules.

Why change the rules?

Cross-zonal capacity is currently allocated in the long-term electricity market with no coordination between different bidding zone borders, causing inefficiencies in some capacity calculation regions. This HAR amendment is needed to introduce the flow-based allocation of long-term transmission rights, enabling cross-zonal coordination. This will make the long-term market more efficient and aligned with the day-ahead market design.

What is the flow-based approach and what are its benefits?

Flow-based allocation of long-term transmission rights is a mechanism that efficiently allocates cross-border transmission capacity in the electricity market. It takes into account the physical reality of the transmission network by calculating the available capacities of physical network elements (so-called Remaining Available Margins) for electricity exchanges between different areas, as well as sensitivity factors (so-called Power Transfer Distribution Factors).

A flow-based mechanism enables cross-zonal coordination in long term electricity markets, leading to better network representation and more accurate price signals for cross-border trade, reducing market distortions and ensuring that the prices reflect the true cost of generating and transmitting electricity.

Amending the rules will allow the implementation of two projects for long-term flow-based capacity calculation and allocation; in the Core and the Nordic capacity calculation regions. The HAR revision is the final step needed for the implementation of these projects, following the approval of the single allocation platform, the congestion income distribution and sharing costs incurred to ensure firmness and remuneration of long-term transmission rights on 22 March 2023.

What are the next steps?

In addition to this proposal, TSOs submitted to ACER their proposal for amending the HAR provisions on collaterals by 1 August 2023.

ACER will decide on both proposals for amending the rules in a single procedure by the end of 2023.  

To make an informed decision, ACER runs a public consultation (from 29 August to 26 September 2023) on the amendments to harmonised allocation rules for long-term electricity transmission rights.

Public notice.

Update of 22 December 2023

On 22 December 2023, with its Decision 18/2023, ACER approved the TSOs' proposal to amend the Harmonised Allocation Rules (HAR) for long-term electricity transmission rights.