Commission Regulation (EU) No 543/2013 of 14 June 2013 on submission and publication of data in electricity markets and amending Annex I to Regulation (EC) No 714/2009 of the European Parliament and of the Council Text with EEA relevance

Article 1

Subject matter

This Regulation lays down the minimum common set of data relating to generation, transportation and consumption of electricity to be made available to market participants. It also provides for a central collection and publication of the data.

Article 2

Definitions

For the purposes of this Regulation, the definitions in Article 2 of Regulation (EC) No 714/2009 shall apply. In addition, the following definitions shall apply:

(1) ‘balancing reserves’ mean all resources, if procured ex ante or in real time, or according to legal obligations, which are available to the TSO for balancing purposes;

(2) ‘balancing time unit’ means the time period for which the price for balancing reserves is established;

(3) ‘bidding zone’ means the largest geographical area within which market participants are able to exchange energy without capacity allocation;

(4) ‘capacity allocation’ means the attribution of cross zonal capacity;

(5) ‘consumption unit’ means a resource which receives electrical energy for its own use, excluding TSOs and Distribution Systems Operators (DSOs);

(6) ‘control area’ means a coherent part of the interconnected system, operated by a single system operator and shall include connected physical loads and/or generation units if any;

(7) ‘coordinated net transmission capacity’ means a capacity calculation method based on the principle of assessing and defining ex ante a maximum energy exchange between adjacent bidding zones;

(8) ‘critical network element’ means a network element either within a bidding zone or between bidding zones taken into account in the capacity calculation process, limiting the amount of power that can be exchanged;

(9) ‘cross-control area balancing’ means a balancing scheme where a TSO can receive bids for activation coming from other TSOs’ areas. It does not include re-dispatching or the delivery of emergency energy;

(10) ‘cross zonal capacity’ means the capability of the interconnected system to accommodate energy transfer between bidding zones;

(11) ‘currency’ is euro if at least one part of the bidding zone(s) concerned is part of a country in which euro is a legal tender. In any other case it is the local currency;

(12) ‘cut-off time’ means the point in time where TSOs have to confirm all matched nominations to the market. The cut-off time refers not only to daily or intra daily markets but also to the different markets that cover imbalance adjustments and reserve allocation;

(13) ‘countertrading’ means a cross zonal exchange initiated by system operators between two bidding zones to relieve physical congestion;

(14) ‘data provider’ means the entity that is sending the data to the central information transparency platform;

(15) ‘explicit allocation’ means the allocation of cross zonal capacity only, without the energy transfer;

(16) ‘flow based parameters’ mean the available margins on critical network elements with associated power transfer distribution factors;

(17) ‘generation unit’ means a single electricity generator belonging to a production unit;

(18) ‘implicit allocation’ means a congestion management method in which energy is obtained at the same time as cross zonal capacity;

(19) ‘market time unit’ means the period for which the market price is established or the shortest possible common time period for the two bidding zones, if their market time units are different;

(20) ‘offered capacity’ means the cross zonal capacity offered by the transmission capacity allocator to the market;

(21) ‘planned’ means an event known ex ante by the primary owner of the data;

(22) ‘power transfer distribution factor’ means a representation of the physical flow on a critical network element induced by the variation of the net position of a bidding zone;

(23) ‘primary owner of the data’ means the entity which creates the data;

(24) ‘production unit’ means a facility for generation of electricity made up of a single generation unit or of an aggregation of generation units;

(25) ‘profile’ means a geographical boundary between one bidding zone and several neighbouring bidding zones;

(26) ‘redispatching’ means a measure activated by one or several system operators by altering the generation and/or load pattern in order to change physical flows in the transmission system and relieve a physical congestion;

(27) ‘total load’, including losses without power used for energy storage, means a load equal to generation and any imports deducting any exports and power used for energy storage;

(28) ‘transmission capacity allocator’ means the entity empowered by TSOs to manage the allocation of cross zonal capacities;

(29) ‘vertical load’ means the total amount of power flowing out of the transmission network to the distribution networks, to directly connected final customers or to the consuming part of generation;

(30) ‘year-ahead forecast margin’ means the difference between the yearly forecast of available generation capacity and the yearly forecast of maximum total load taking into account the forecast of total generation capacity, the forecast of availability of generation and the forecast of reserves contracted for system services;

(31) ‘time’ means the local time in Brussels.

Article 3

Establishment of a central information transparency platform

The central information transparency platform shall be available to the public free of charge through the internet and shall be available at least in English.

The data shall be up to date, easily accessible, downloadable and available for at least five years. Data updates shall be time-stamped, archived and made available to the public.

Article 4

Submission and publication of data

TSOs, and where relevant data providers, shall process the data they receive and provide them to the ENTSO for Electricity in due time for publication.

Article 5

Manual of procedures

The ENTSO for Electricity shall develop a manual specifying:

(a) details and format of the submission of data laid down in Article 4(1);

(b) standardised ways and formats of data communication and exchange between primary owners of data, TSOs, data providers and the ENTSO for Electricity;

(c) technical and operational criteria which data providers would need to fulfil when providing data to the central information transparency platform;

(d) appropriate classification of production types referred to in Articles 14(1), 15(1) and 16(1).

The ENTSO for Electricity shall develop the manual following open and transparent consultation with stakeholders.

The ENTSO for Electricity shall make the manual available to the public.

The ENTSO for Electricity shall update the manual when necessary. Before publishing or updating the manual, the ENTSO for Electricity shall submit a draft to the Agency for its opinion, which the Agency shall provide within two months. The draft of the first release shall be submitted to the Agency within four month after the entry into force of this Regulation.

Article 6

Information on total load

For their control areas, TSOs shall calculate and submit the following data to the ENTSO for Electricity for each bidding zone:

(a) the total load per market time unit;

(b) a day-ahead forecast of the total load per market time unit;

(c) a week-ahead forecast of the total load for every day of the following week, which shall for each day include a maximum and a minimum load value;

(d) a month-ahead forecast of the total load for every week of the following month, which shall include, for a given week, a maximum and a minimum load value;

(e) a year-ahead forecast of the total load for every week of the following year, which shall for a given week include a maximum and a minimum load value.

The information referred to:

(a) in point (a) of paragraph 1 shall be published no later than one hour after the operating period;

(b) in point (b) of paragraph 1 shall be published no later than two hours before the gate closure of the day-ahead market in the bidding zone and be updated when significant changes occur;

(c) in point (c) of paragraph 1 shall be published each Friday no later than two hours before the gate closure of the day-ahead market in the bidding zone and be updated when significant changes occur;

(d) in point (d) of paragraph 1 shall be published no later than one week before the delivery month and be updated when significant changes occur;

(e) in point (e) of paragraph 1 shall be published no later than the 15th calendar day of the month before the year to which the data relates.

Generation units shall be considered as primary owners of the relevant information they provide.

DSOs shall be considered as primary owners of the relevant information they provide.

Article 7

Information relating to the unavailability of consumption units

For their control areas, TSOs shall provide the following information to the ENTSO for Electricity:

(a) the planned unavailability of 100 MW or more of a consumption unit, including changes of 100 MW or more in the planned unavailability of consumption units, lasting at least one market time unit, specifying: — bidding zone, — available capacity per market time unit during the event, — reason for the unavailability, — the estimated start and end date (day, hour) of the change in availability;

(b) changes in actual availability of a consumption unit with a power rating of 100 MW or more, specifying: — bidding zone, — available capacity per market time unit during the event, — reason for the unavailability, — the start date and the estimated end date (day, hour) of the change in availability.

The information laid down point (b) of paragraph 1 shall be published in aggregated form per bidding zone indicating the sum of unavailable consumption capacity per market time unit during a given period as soon as possible but no later than one hour after the change in actual availability.

The consumption units shall be considered as primary owner of the data they submit.

Article 8

Year-ahead forecast margin

The information shall be published one week before the yearly capacity allocation but no later than the 15th calendar day of the month before the year to which the data relates.

Generation units and DSOs shall be considered as primary owners of the data they submit.

Article 9

Transmission infrastructure

TSOs shall establish and provide information on future changes to network elements and interconnector projects including expansion or dismantling in their transmission grids within the next three years, to the ENTSO for Electricity. This information shall only be given for measures expected to have an impact of at least 100 MW on cross zonal capacity between bidding zones or on profiles at least during one market time unit. The information shall include:

(a) the identification of the assets concerned;

(b) the location;

(c) type of asset;

(d) the impact on interconnection capacity per direction between the bidding zones;

(e) the estimated date of completion.

The information shall be published one week before the yearly capacity allocation but no later than the 15th calendar day of the month before the year to which the allocation relates. The information shall be updated with relevant changes before the end of March, the end of June and the end of September of the year to which the allocation relates.

Article 10

Information relating to the unavailability of transmission infrastructure

For their control areas TSOs shall calculate and provide to the ENTSO for Electricity:

(a) the planned unavailability, including changes in the planned unavailability of interconnections and in the transmission grid that reduce cross zonal capacities between bidding zones by 100 MW or more during at least one market time unit, specifying: — the identification of the assets concerned, — the location, — the type of asset, — the estimated impact on cross zonal capacity per direction between bidding zones, — reasons for the unavailability, — the estimated start and end date (day, hour) of the change in availability;

(b) changes in the actual availability of interconnections and in the transmission grid that reduce cross zonal capacities between bidding zones by 100 MW or more during at least one market time unit, specifying: — the identification of the assets concerned, — the location, — the type of asset, — the estimated impact on cross zonal capacity per direction between bidding zones, — reasons for the unavailability, — the start and estimated end date (day, hour) of the change in availability;

(c) changes in the actual availability of off-shore grid infrastructure that reduce wind power feed-in by 100 MW or more during at least one market time unit, specifying: — the identification of the assets concerned, — the location, — the type of asset, — the installed wind power generation capacity (MW) connected to the asset, — wind power fed in (MW) at the time of the change in the availability, — reasons for the unavailability, — the start and estimated end date (day, hour) of the change in availability.

Article 11

Information relating to the estimation and offer of cross zonal capacities

For their control areas TSOs or, if applicable, transmission capacity allocators, shall calculate and provide the following information to the ENTSO for Electricity sufficiently in advance of the allocation process:

(a) the forecasted and offered capacity (MW) per direction between bidding zones in case of coordinated net transmission capacity based capacity allocation; or

(b) the relevant flow based parameters in case of flow based capacity allocation.

TSOs or, if applicable, transmission capacity allocators shall be considered as the primary owners of the information they calculate and provide.

Operators of direct current links shall be considered as primary owners of the updated information they provide.

TSOs or, if applicable, transmission capacity allocators, shall provide a yearly report to the ENTSO for Electricity indicating:

(a) the main critical network elements limiting the offered capacity;

(b) the control area(s) which the critical network elements belong to;

(c) the extent to which relieving the critical network elements would increase the offered capacity;

(d) all possible measures that could be implemented to increase the offered capacity, together with their estimated costs.

When preparing the report TSOs may choose not to identify the asset concerned and specify its location if it is classified as sensitive critical infrastructure protection related information in their Member States as provided for in point (d) of Article 2 of Directive 2008/114/EC.

TSOs or, if applicable, transmission capacity allocators shall be considered as primary owners of the report they provide.

Article 12

Information relating to the use of cross zonal capacities

For their control areas TSOs shall calculate and provide the following information to the ENTSO for Electricity:

(a) in case of explicit allocations, for every market time unit and per direction between bidding zones: — the capacity (MW) requested by the market, — capacity (MW) allocated to the market, — the price of the capacity (Currency/MW), — the auction revenue (in Currency) per border between bidding zones;

(b) for every market time unit and per direction between bidding zones the total capacity nominated;

(c) prior to each capacity allocation the total capacity already allocated through previous allocation procedures per market time unit and per direction;

(d) for every market time unit the day-ahead prices in each bidding zone (Currency/MWh);

(e) in case of implicit allocations, for every market time unit the net positions of each bidding zone (MW) and the congestion income (in Currency) per border between bidding zones;

(f) scheduled day-ahead commercial exchanges in aggregated form between bidding zones per direction and market time unit;

(g) physical flows between bidding zones per market time unit;

(h) cross zonal capacities allocated between bidding zones in Member States and third countries per direction, per allocated product and period.

The information laid down:

(a) in points (a) and (e) of paragraph 1 shall be published no later than one hour after each capacity allocation;

(b) in point (b) of paragraph 1 shall be published no later than one hour after each round of nomination;

(c) in point (c) of paragraph 1 shall be published at the latest when publication of offered capacity figures become due as set out in the Annex;

(d) in point (d) of paragraph 1 shall be published no later than one hour after gate closure;

(e) in point (f) of paragraph 1 shall be published every day no later than one hour after the last cut-off time and, if applicable, shall be updated no later than two hours after each intra-day nomination process;

(f) in point (g) of paragraph 1 shall be published for each market time unit as closely as possible to real time but no later than one hour after the operational period;

(g) in point (h) of paragraph 1 shall be published no later than one hour after the allocation.

Transmission capacity allocators shall be considered as primary owners of the information they provide.

Power exchanges shall be considered primary owners of the information they provide.

Article 13

Information relating to congestion management measures

For their control areas TSOs shall provide the following information to the ENTSO for Electricity:

(a) information relating to redispatching per market time unit, specifying: — the action taken (that is to say production increase or decrease, load increase or decrease), — the identification, location and type of network elements concerned by the action, — the reason for the action, — capacity affected by the action taken (MW);

(b) information relating to countertrading per market time unit, specifying: — the action taken (that is to say cross-zonal exchange increase or decrease), — the bidding zones concerned, — the reason for the action, — change in cross-zonal exchange (MW);

(c) the costs incurred in a given month from actions referred to in points (a) and (b) and from any other remedial action.

The information laid down:

(a) in points (a) and (b) of paragraph 1 shall be published as soon as possible but no later than one hour after the operating period, except for the reasons which shall be published as soon as possible but not later than one day after the operating period;

(b) in point (c) of paragraph 1 shall be published no later than one month after the end of the referred month.

Article 14

Forecast generation

For their control areas, TSOs shall calculate and provide the following information to the ENTSO for Electricity:

(a) the sum of generation capacity (MW) installed for all existing production units equalling to or exceeding 1 MW installed generation capacity, per production type;