Implementation of European regulations

ELES as the transmission system operator of the electric power network is in accordance with the legislation obliged to notify the public about the procedures of adoption and implementation of European regulations in the field of electric power transmission.

NRA approvals and adopted documents

All TSOs’ proposal for a Congestion Income Distribution (CID-FCA) methodology

This document is a common proposal developed by all Transmission System Operators regarding a methodology for congestion income distribution in accordance with Article 57 of Commission Regulation (EU) 2016/1719 establishing a guideline on Forward Capacity Allocation.

The Proposal takes into account the congestion income distribution methodology in accordance with Article 73 of the CACM Regulation and the general principles of congestion income use in Article 16 (6) of Regulation (EC) No 714/2009 of the European Parliament and of the Council of 13 July 2009 on conditions for access to the network for cross-border exchanges in electricity.

The CID-FCA methodology shall be considered as the common proposal of all TSOs in accordance with Article 57 of FCA Regulation and shall cover the distribution of congestion income from Forward Capacity Allocation for:
 

  • all existing and future Bidding Zone borders and interconnectors within and between Member States, to which the CACM and the FCA Regulations apply and where Congestion Income from Forward Capacity Allocation is collected;
  • Interconnectors which are owned by TSOs or by other legal entities.

The Energy Agency approved the proposal on 6.6.2019.

Details of the All TSOs’ Proposal for a Congestion Income Distribution (CID) methodology in accordance with Article 57 of the Commission Regulation (EU) 2016/1719 of 26 September 2016 establishing a guideline on forward capacity allocation and Annex 1

Complementary Regional Intraday Auctions proposal for Italy North Capacity Calculation Region (CRIDA)

Document or “CRIDA proposal”, is a common proposal developed by Nominated Electricity Market Operators and the Transmission System Operators of Italy North Capacity Calculation Region for the design and implementation of Complementary Regional Auctions according to Article 63 of Regulation (EU) 2015/1222 on Capacity Allocation and Congestion Management. The Proposal takes into account the congestion income distribution methodology in accordance with Article 73 of the CACM Regulation and the general principles of congestion income use in Article 16 (6) of Regulation (EC) No 714/2009 of the European Parliament and of the Council of 13 July 2009 on conditions for access to the network for cross-border exchanges in electricity.

The Proposal includes the implementation of continuous energy trading mechanism accommodating the implicit allocation of the intraday cross-zonal capacity and the implementation of Complementary Regional Intraday Auction Mechanism on Italy North CCR.

The Energy Agency approved the proposal on 4.6.2019.

Details of the Complementary Regional Intraday Auctions proposal for Italy North Capacity Calculation Region in accordance with Article 63 of the Commission Regulation (EU) 2015/1222 of 24 July 2015 establishing a Guideline on Capacity Allocation and Congestion Management

All TSOs’ proposal for a Methodology for Calculating Scheduled Exchanges resulting from single day-ahead coupling

Document provides a methodology for calculating Scheduled Exchanges resulting from the SDAC (”hereafter referred to as ”DA SEC Methodology”) in accordance with Article 43 of Commission Regulation (EU) 2015/1222 establishing a guideline on Capacity Allocation and Congestion Management. The DA SEC Proposal, in line with Article 45 of CACM Regulation, accommodates situations where there are more than one Nominated Electricity Market Operator (hereafter referred to as “NEMO”) designated and/or offering day-ahead trading services in a particular geographic area. The DA SEC Proposal shall consider situations where the bidding zone is equal to the scheduling area, as well as where there are multiple scheduling areas within a bidding zone.

The DA SEC Proposal provides for the calculation of Scheduled Exchanges between bidding zones, scheduling areas and NEMO trading hubs.

The Energy Agency approved the proposal on 13.3.2019.

Details of the All TSOs’ proposal for a Methodology for Calculating Scheduled Exchanges resulting from single day-ahead coupling

All TSOs’ proposal for a Methodology for Calculating Scheduled Exchanges resulting from single intra-day coupling

Document provides a methodology for calculating Scheduled Exchanges resulting from the SIDC (”hereafter referred to as ”ID SEC Methodology”) in accordance with Article 56 of Commission Regulation (EU) 2015/1222 establishing a guideline on Capacity Allocation and Congestion Management. The ID SEC Proposal, in line with Article 56 of CACM Regulation, accommodates situations where there are more than one Nominated Electricity Market Operator (hereafter referred to as “NEMO”) designated and/or offering intraday trading services in a particular geographic area. The ID SEC Proposal shall consider situations where the bidding zone is equal to the scheduling area, as well as where there are multiple scheduling areas within a bidding zone.

This ID SEC Proposal provides for the calculation of Scheduled Exchanges between bidding zones, scheduling areas and NEMO trading hubs.

The Energy Agency approved the proposal on 13.3.2019.

Details of the All TSOs’ proposal for a Methodology for Calculating Scheduled Exchanges resulting from single intra-day coupling

Proposal for nomination rules for Physical Transmission Rights for the bidding zone border(s) between Austria, Croatia, Czech Republic, Germany, Hungary, Poland, Slovakia and Slovenia

Document is a common proposal developed by the Transmission System Operators of the bidding zone border(s) between Austria, Croatia, Czech Republic, Germany, Hungary, Poland, Slovakia and Slovenia for Nomination Rules for Physical Transmission Rights in accordance with Article 36 of Commission Regulation (EU) 2016/1719 establishing a guideline on Forward Capacity Allocation (FCA).

Article 31 of the FCA foresees that long-term cross-zonal capacity shall be allocated to market participants in the form of Physical Transmission Rights (PTRs) pursuant to the UIOSI principle or in the form of Financial Transmission Rights (FTRs) — options or FTRs — obligations. This Proposal only applies to the physical transmission rights acquired in forward capacity allocation. It lays down the rules for nomination of physical transmission rights for the bidding zone border(s) between Austria, Croatia, Czech Republic, Germany, Hungary, Poland, Slovakia and Slovenia.

This Proposal is in accordance with the FCA and valid Harmonised allocation rules for long-term transmission rights binding for the holders of Physical Transmission Rights, their counterparties where applicable, and authorised third parties acting on their behalf.

The Energy Agency approved the proposal on 27.08.2018.

Details of the

Proposal for nomination rules for Physical Transmission Rights for the bidding zone border(s) Italy NORD - Slovenia

Document is a common proposal developed by the Transmission System Operators of the bidding zone border(s) Italy NORD - Slovenia for Nomination Rules for Physical Transmission Rights in accordance with Article 36 of Commission Regulation (EU) 2016/1719 establishing a guideline on Forward Capacity Allocation (FCA).

Article 31 of the FCA foresees that long-term cross-zonal capacity shall be allocated to market participants in the form of Physical Transmission Rights (PTRs) pursuant to the UIOSI principle or in the form of Financial Transmission Rights (FTRs) — options or FTRs — obligations. This Proposal only applies to the physical transmission rights acquired in forward capacity allocation. It lays down the rules for nomination of physical transmission rights for the bidding zone border(s) Italy NORD - Slovenia.

This Proposal is in accordance with the FCA and valid Harmonised allocation rules for long-term transmission rights binding for the holders of Physical Transmission Rights, their counterparties where applicable, and authorised third parties acting on their behalf.

The Energy Agency approved the proposal on 18.05.2018.

Details of the

Italy North TSOs proposal for fallback procedure

Document  is a common proposal developed by all Transmission System Operators within the Italy North Capacity Calculation Region regarding the proposal for fallback procedures in the event that the single day-ahead coupling process is unable to produce results. This proposal is required by Article 44 of Regulation (EU) 2015/1222 on Capacity Allocation and Congestion Management (CACM Regulation).
As required under Article 44 of the CACM Regulation, each TSO of Italy North Capacity Calculation Region, in coordination with all the other TSOs, shall develop a proposal for robust and timely fallback procedures to ensure efficient, transparent and non-discriminatory capacity allocation in the event that the single day-ahead coupling process is unable to produce results within the Italy North Region. This procedure shall apply to all relevant borders of Italy North Region.
Shadow Auction Rules are the Annex to the proposal.

The Energy Agency approved the proposal on 19.10.2017.

Italy North TSOs proposal for design of Long Term Transmission Rights

Document is the Italy North CCR TSOs’ long-term transmission rights proposal required by Article 31 of the FCA regulation. In line with this article TSOs of a capacity calculation region, where long-term transmission rights exist, to jointly develop a proposal for the regional design of long-term transmission rights to be issued on each bidding zone border within the CCR.

The Energy Agency approved the proposal on 19.10.2017.

Core CCR TSOs’ proposal for the regional design of long-term transmission rights

Document is the Core CCR TSOs’ long-term transmission rights proposal required by Article 31 of the FCA regulation. In line with this article TSOs of a capacity calculation region, where long-term transmission rights exist, to jointly develop a proposal for the regional design of long-term transmission rights to be issued on each bidding zone border within the CCR.

The Energy Agency approved the proposal on 19.10.2017.

All TSOs’ proposal for the establishment of a Single Allocation Platform (SAP)

Document is the common proposal developed by all Transmission System Operators for a set of requirements and for the establishment of the Single Allocation Platform in accordance with Article 49 and for a cost sharing methodology in accordance with Article 59 of Commission Regulation (EU) 2016/1719 establishing a guideline on Forward Capacity Allocation (FCA Regulation).
The SAP Proposal lays down the functional requirements, governance, liabilities and cost sharing methodology for the Single Allocation Platform. The SAP shall be able to perform, at least, the execution of the long-term auctions in accordance with the valid Harmonised allocation rules for long-term transmission rights (HAR) and any associated additional tasks required in the provision of long-term auctions (such as clearing and settlement and on call support) as described in Article 50 of the FCA Regulation.
All TSOs agree to use JAO as the SAP Operator and shall ensure through the SAP Operator, as a vehicle of cooperation, that the SAP is operational and complies with the functional requirements of this SAP Proposal, the HAR and the FCA Regulation.

The Energy Agency approved the proposal on 11.12.2017.

All TSOs’ proposal for the day-ahead firmness deadline (DAFD)

Document is a common proposal developed by all Transmission System Operators regarding the development of a day-ahead firmness deadline (DAFD) in accordance with Article 69 of Commission Regulation (EU) 2015/1222 establishing a guideline on Capacity Allocation and Congestion Management (CACM Regulation).
Article 2(35) of the CACM Regulation defines the DAFD as “the point in time after which cross-zonal capacity becomes firm”. The DAFD shall be sixty (60) minutes before the day-ahead market gate closure time.

The Energy Agency approved the proposal on 13.6.2017.

Common Grid Model Methodology (CGMM)

The purpose of the methodology is to describe the requirements and procedures for the preparation of the so-called Individual Grid Model (IGM) by each individual transmission system operator, which will facilitate the calculation of cross-border capacities and operational security analyses. Target time-frames subject to these models are: “D-2”, ”D-1” and “ID”. In individual grid models (IGM) the elements of the transmisison system have to be modelled on the 220 kV or higher voltage levels. For the preparation of IGM models, generation forecast, forecast of load and planned outages for the target date must be considered. ELES already considers and uses the requirements of the methodology at the preparation of “D-2”, ”D-1” and “ID” models. Until now, model preparation and consideration of input data was left to the judgement of each individual system operator, the new methodology lays down detailed standards that must be considered by all system operators.

With current models, ELES already fulfils the methodology requirements, therefore, additional harmonisation of our current processes is not required with regard to the proposed methodology.

In June 2017 ENTSO-E released Common Grid Model methodology as requested in FCA GL on the basis of methodology requested in CACM GL, that has already been approved by national regulatory authorities.

Generation and load data provision methodology (GLDPM)

The GLDPM methodology is closely connected with the CGM methodology, since it stipulates the requirements and procedures with regard to input data for the preparation of IGM models. The methodology lays down a requirement that all generators connected to the 220 kV level or higher voltage levels, must be modelled in detail in the IGM model. Other generators on lower voltage levels can be modelled on an aggregate basis. Production units, modelled in detail and aggregated, must be separately modelled with regard to the primary energy source.

The methodology also determines that all loads connected to the 220 kV level or higher must be modelled in detail. Other loads are modelled as aggregated loads. Because the Slovenian transmission system has no loads that would be directly connected to 220 or 400 kV voltage level, loads are modelled as the aggregation by individual substations. The connecting point in the model as well as active and reactive power must be provided for such loads.

This methodology does not bring significant changes for ELES in already established daily processes.

Slovenian NRA approves the submitted GLDPM methodology on 11 Januray 2017.

In June 2017 ENTSO-E released Generation and Load Data Provision methodology as requested in FCA GL on the basis of methodology requested in CACM GL, that has already been approved by national regulatory authorities.

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