ACER publishes its multi-annual work 'Single programming document 2024-2026' which sets out:

• ACER’s strategic goals and priorities in upcoming years;
• ACER’s 2024 annual work programme.

Which are ACER’s priorities for 2024-26?

ACER's will continue its work on:

• the internal energy market;
• infrastructure and security of supply;
• the integrity and transparency of wholesale energy markets;
• longer-term regulatory challenges; and
• the resilience, efficiency and agility of ACER.

Access previous editions.

ACER approves today the proposal received by Transmission System Operators (TSOs) to amend the congestion income distribution methodology in the European electricity markets.

What is the congestion income distribution methodology?

Congestion arises when there is limited capacity to transport electricity between different areas. When a congestion occurs, a price difference emerges between the different bidding zones which generates congestion income. The congestion income distribution methodology describes how to distribute such income among TSOs to ensure fairness and efficient operation of the electricity market.

Why the need to amend the methodology?

There are two main reasons for amending the methodology:

• Several mechanisms (such as flow-based allocation or advanced hybrid coupling) have recently been or will soon be implemented to increase the efficiency of the market coupling. However, these mechanisms can cause unintuitive flows (electricity flows from an expensive zone to a cheaper one). This amendment aims to address the financial consequence of unintuitive flows and to ensure a non-discriminatory treatment of all TSOs.

• In the future, exchange of balancing capacity or sharing of reserve will be implemented. Both mechanisms would generate congestion income that need to be distributed. This amendment will regulate how congestion income will be distributed among TSOs.

What are the next steps?

Following ACER’s approval of the methodology, European TSOs will implement the required changes.  

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

What is it about?

On 1 March 2023, ACER received the TSOs’ proposal for amending the HAR for long-term transmission rights under the Regulation on forward capacity allocation. On 1 August 2023, the TSOs completed their proposal with amendments to the provisions on collaterals.

To take an informed decision, ACER engaged with stakeholders through a public consultation and a workshop in summer 2023.

Why were the rules amended?

Amending the HAR was needed to introduce the flow-based allocation of long-term transmission rights and enable cross-zonal coordination. This will make the long-term electricity market more efficient and aligned with the day-ahead market design.

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 for electricity exchanges between different areas, as well as sensitivity factors.

A flow-based mechanism enables cross-zonal coordination in the long-term electricity markets, which provides more accurate price signals for cross-border trade, reduces market distortions and ensures that the prices reflect the true cost of generating and transmitting electricity.

The amendment of the HAR allows for the implementation of two projects for long-term flow-based capacity calculation and allocation in the Core and Nordic capacity calculation regions. The HAR revision was the final step needed for the implementation of these projects, following ACER’s approval of other related methodologies in March 2023.

What are the next steps?

The amended HAR will apply from the date specified in the amendment notice published by the Joint Allocation Office.

ACER has reached a decision that no alternative electricity bidding zone configurations need to be investigated in the Baltic region. The procedure to decide started on 26 September 2023.

What are the bidding zones?

A bidding zone is the largest geographical area within which market participants can exchange energy without allocating capacity. Currently, bidding zones in Europe are mostly defined by national borders. However, the existing European electricity target model requires defining bidding zones based on network congestions. Hence, the need for alternative bidding zone configurations has to be examined.

What are the Decision’s main highlights?

ACER’s Decision is based on the feedback received from stakeholders in 2021, as well as on the following information provided by Transmission System Operators (TSOs):

• the alternative configurations previously submitted to ACER; and
• the outcome of locational marginal pricing simulations (following the bidding zone review methodology approved in November 2020).

ACER concludes that the current bidding zone configuration in the Baltic region is adequate, and no alternatives should be sought with priority. Nonetheless, this conclusion does not preclude the possibility to investigate potential mergers of the Baltic bidding zones in future reviews.

On 24 October 2023, the National Regulatory Authorities (NRAs) of the Core Capacity Calculation Region (CCR) requested from ACER an extension to agree on the Core Transmission System Operators’ (TSOs’) proposed second amendment to the Core day-ahead electricity capacity calculation methodology.

On 20 December 2023, with its Decision 15/2023, ACER granted an extension of three months to the Core CCR NRAs (Austria, Belgium, Croatia, Czech Republic, France, Germany, Hungary, Luxembourg, the Netherlands, Poland, Romania, Slovakia and Slovenia).

What is the methodology about?

The day-ahead capacity calculation methodology describes the rules of each CCR on how to calculate the amount of capacity available for trading between bidding zones at day-ahead market time frame.

What are the NRAs asked to decide about?

The TSOs’ proposal suggests an implementation of the Advanced Hybrid Coupling (AHC) aiming at reducing the volume of unscheduled allocated flows on the Critical Network Elements with Contingencies (CNECs) of the Core CCR. These unscheduled flows result from electricity exchanges on the bidding zone borders of adjacent CCRs.

What are the next steps?

The Core NRAs have until 6 February 2024 to decide on the TSOs’ proposal for the second amendment to the Core day-ahead capacity calculation methodology.

The EU energy ministers agreed to extend the gas market correction mechanism (MCM) for a period of one year, until 31 January 2025.

Ministers at the Transport, Telecommunications and Energy (TTE) Council meeting (19 December 2023) reached a political agreement to extend the period of application of three Council regulations (adopted in December 2022) designed for emergency situations, including the gas MCM (see the Council's press release).

Next, the Council will aim to formally adopt the regulations by written procedure.

What is the gas market correction mechanism?

The MCM Regulation (December 2022) established a gas MCM to protect EU citizens and the economy against excessively high energy prices. It entered into force on 1 February 2023, initially for a period of one year, and tasked ACER with the calculation and publication of the MCM reference price.

Learn more about the MCM.

Ahead of every winter and summer, the European Network of Transmission System Operators for Electricity (ENTSO-E) assesses the potential risks to the European security of electricity supply for the six months ahead. This analysis allows Transmission System Operators (TSOs) and Member States to take relevant actions and ensure the European consumers are supplied without interruption.

What are the risks this winter?

ENTSO-E’s Winter Outlook 2023-2024 finds that the situation in the European power system for this winter is more secure than last year.

• Risk of power interruption appears in the islands of Ireland, Malta, and Cyprus – a pattern that has repeated in past seasonal outlooks. With limited interconnections, islands need to rely mostly on their own resources. This highlights the major role played by interconnectivity in the security of supply. Finland may also face risk in the event of exceptionally adverse conditions.
• Regional risks: the Outlook also identified a potential risk associated with a surge in French demand, triggered by the drop in temperatures. This demand increase could impact Belgium and Great Britain, showcasing the importance of effective coordination to solve potential regional risks.

What does ACER say?

• Continuing good practice: ACER appreciates that the Winter Outlook continues to analyse the electricity saving potential and the critical gas volume needed to ensure security of electricity supply. This addition provides complementary information to Member States, system operators, and other stakeholders to take relevant actions.
• Collaboration with Ukraine and Moldova: ACER welcomes the enhanced cooperation efforts with the Ukrainian and Moldovan system operators. These efforts contribute to reducing the system risks following Russia’s invasion of Ukraine and addressing the challenges faced.
• Improve the methodology: ACER stresses the methodological gap persisting in the seasonal outlooks, as highlighted in the last opinions. Particularly, ENTSO-E does not apply the flow-based market coupling in its model, although it has already been in place for several years, helping the Transmission System Operators (TSOs) to allocate cross-border capacities more efficiently. Without this approach, the forecasts may diverge from real outcomes and from national seasonal assessments.