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Commission Regulation (EU) 2017/1485 of 2 August 2017 establishing a guideline on electricity transmission system operation (Text with EEA relevance. )

Type Regulation

Publication 2017-08-02

Last updated 2021-03-15

State In force

Department European Commission, ENER

Source EUR-Lex

articles 193

Reform history JSON API

Each TSO shall include in its training program for the employees in charge of real-time operation of the transmission system the frequency of the trainings and the following components:

(a) a description of the transmission system elements;

(b) operation of the transmission system in all system states including restoration;

(d) coordination of inter-TSO operations and market arrangements;

(e) recognition of and response to exceptional operational situations;

(f) relevant areas of electrical power engineering;

(g) relevant aspects of the Union internal electricity market;

(h) relevant aspects of the network codes or guidelines adopted according to Articles 6 and 18 of Regulation (EC) No 714/2009;

(i) safety and security of persons, nuclear and other equipment in transmission system operation;

(j) inter-TSO cooperation and coordination in real-time operation and in operational planning at the level of main control rooms which shall be given in English unless otherwise specified;

(k) joint training with transmission-connected DSOs and SGUs, where appropriate;

(l) behavioural skills with particular focus on stress management, human acting in critical situation, responsibility and motivation skills; and

(m) operational planning practices and tools, including those used with the relevant regional security coordinators in the operational planning.

Article 59

Training conditions

Article 60

Training coordinators and trainers

The training coordinator's responsibilities shall include the designing, monitoring and updating of the training programs, as well as the determination of:

(a) the qualifications and selection process for TSO employees to be trained;

(b) the training required for certification of the system operator employees in charge of real-time operation;

(d) the process for certification of system operator employees in charge of real-time operation; and

(e) the process for extension of a training period and certification period for the system operator employees in charge of real-time operation.

Article 61

Certification of system operator employees in charge of real-time operation

Article 62

Common language for communication between the system operator employees in charge of real time operation

Article 63

Cooperation between TSOs on training

PART III

OPERATIONAL PLANNING

TITLE 1

DATA FOR OPERATIONAL SECURITY ANALYSIS IN OPERATIONAL PLANNING

Article 64

General provisions regarding individual and common grid models

To perform operational security analysis pursuant to Title 2 of this Part, each TSO shall prepare individual grid models in accordance with the methodologies established in application of Article 17 of Regulation (EU) 2015/1222 and Article 18 of Regulation (EU) 2016/1719 for each of the following time-frames, applying the data format established pursuant to Article 114(2):

(a) year-ahead, in accordance with Articles 66, 67 and 68;

(b) where applicable, week-ahead, in accordance with Article 69;

(d) intraday, in accordance with Article 70.

Article 65

Year-ahead scenarios

All TSOs shall jointly develop a common list of year-ahead scenarios against which they assess the operation of the interconnected transmission system for the following year. Those scenarios shall allow the identification and the assessment of the influence of the interconnected transmission system on operational security. The scenarios shall include the following variables:

(a) electricity demand;

(b) the conditions related to the contribution of renewable energy sources;

(d) the generation pattern, with a fully available production park;

(e) the year-ahead grid development.

When developing the common list of scenarios, TSOs shall take into account the following elements:

(a) the typical cross-border exchange patterns for different levels of consumption and of renewable energy sources and conventional generation;

(b) the probability of occurrence of the scenarios;

(d) the amount of power generated and consumed by the power generating facilities and demand facilities connected to distribution systems.

Where TSOs do not succeed in establishing the common list of scenarios referred to in paragraph 1, they shall use the following default scenarios:

(a) Winter Peak, 3rd Wednesday of January current year, 10:30 CET;

(b) Winter Valley, 2nd Sunday of January current year, 03:30 CET;

(d) Spring Valley, 2nd Sunday of April current year, 03:30 CET;

(e) Summer Peak, 3rd Wednesday of July previous year, 10:30 CET;

(f) Summer Valley, 2nd Sunday of July previous year, 03:30 CET;

(g) Autumn Peak, 3rd Wednesday of October previous year, 10:30 CET;

(h) Autumn Valley, 2nd Sunday of October previous year, 03:30 CET.

Article 66

Year-ahead individual grid models

When defining its year-ahead individual grid model, each TSO shall:

(a) agree with the neighbouring TSOs upon the estimated power flow on HVDC systems linking their control areas;

(b) balance for each scenario the sum of: (i) net exchanges on AC lines; (ii) estimated power flows on HVDC systems; (iii) load, including an estimation of losses; and (iv) generation.

Each TSO shall include in its year-ahead individual grid models the aggregated power outputs for power generating facilities connected to distribution systems. Those aggregated power outputs shall:

(a) be consistent with the structural data provided in accordance with the requirements of Articles 41, 43, 45 and 48;

(b) be consistent with the scenarios developed in accordance with Article 65; and

Article 67

Year-ahead common grid models

By 6 months after entry into force of this Regulation, all TSOs shall jointly develop a proposal for the methodology for building the year-ahead common grid models from the individual grid models established in accordance with Article 66(1) and for saving them. The methodology shall take into account, and complement where necessary, the operational conditions of the common grid model methodology developed in accordance with Article 17 of Regulation (EU) 2015/1222 and Article 18 of Regulation (EU) 2016/1719, as regards the following elements:

(a) deadlines for gathering the year-ahead individual grid models, for merging them into a common grid model and for saving the individual and common grid models;

(b) quality control of the individual and common grid models to be implemented in order to ensure their completeness and consistency; and

(c) correction and improvement of individual and common grid models, implementing at least the quality controls referred to in point (b).

Article 68

Updates of year-ahead individual and common grid models

Article 69

Week-ahead individual and common grid models

Article 70

Methodology for building day-ahead and intraday common grid models

By 6 months after entry into force of this Regulation, all TSOs shall jointly develop a proposal for the methodology for building the day-ahead and intraday common grid models from the individual grid models and for saving them. That methodology shall take into account, and complement where necessary, the operational conditions of the common grid model methodology developed in accordance with Article 17 of Regulation (EU) 2015/1222, as regards the following elements:

(a) definition of timestamps;

(b) deadlines for gathering the individual grid models, for merging them into a common grid model and for saving individual and common grid models. The deadlines shall be compatible with the regional processes established for preparing and activating remedial actions;

(c) quality control of individual grid models and the common grid model to be implemented to ensure their completeness and consistency;

(d) correction and improvement of individual and common grid models, implementing at least the quality controls referred to in point (c); and

(e) handling additional information related to operational arrangements, such as protection setpoints or system protection schemes, single line diagrams and configuration of substations in order to manage operational security.

When creating the day-ahead or intraday individual grid models referred to in paragraph 2, each TSO shall include:

(a) up-to-date load and generation forecasts;

(b) the available results of the day-ahead and intraday market processes;

(d) for power generating facilities connected to distribution systems, aggregated active power output differentiated on the basis of the type of primary energy source, in line with data provided in accordance with Articles 40, 43, 44, 48, 49 and 50;

(e) up-to-date topology of the transmission system.

Article 71

Quality control for grid models

When defining the quality controls in accordance with Articles 67(1)(b) and 70(1)(c), all TSOs shall jointly determine controls aimed at least to check:

(a) the coherence of the connection status of interconnectors;

(b) that voltage values are within the usual operational values for those transmission system elements having influence on other control areas;

(d) that active power and reactive power injections or withdrawals are compatible with usual operational values.

TITLE 2

OPERATIONAL SECURITY ANALYSIS

Article 72

Operational security analysis in operational planning

Each TSO shall perform coordinated operational security analyses for at least the following time-frames:

(a) year-ahead;

(b) week-ahead, when applicable in accordance with Article 69;

(d) intraday.

Article 73

Year-ahead up to and including week-ahead operational security analysis

Each TSO shall perform year-ahead and, where applicable, week-ahead operational security analyses in order to detect at least the following constraints:

(a) power flows and voltages exceeding operational security limits;

(b) violations of stability limits of the transmission system identified in accordance with Article 38(2) and (6); and

Article 74

Day-ahead, intraday and close to real-time operational security analysis

Article 75

Methodology for coordinating operational security analysis

By 12 months after entry into force of this Regulation, all TSOs shall jointly develop a proposal for a methodology for coordinating operational security analysis. That methodology shall aim at the standardisation of operational security analysis at least per synchronous area and shall include at least:

(a) methods for assessing the influence of transmission system elements and SGUs located outside of a TSO's control area in order to identify those elements included in the TSO's observability area and the contingency influence thresholds above which contingencies of those elements constitute external contingencies;

(b) principles for common risk assessment, covering at least, for the contingencies referred to in Article 33: (i) associated probability; (ii) transitory admissible overloads; and (iii) impact of contingencies;

(c) principles for assessing and dealing with uncertainties of generation and load, taking into account a reliability margin in line with Article 22 of Regulation (EU) 2015/1222;

(d) requirements on coordination and information exchange between regional security coordinators in relation to the tasks listed in Article 77(3);

(e) role of ENTSO for Electricity in the governance of common tools, data quality rules improvement, monitoring of the methodology for coordinated operational security analysis and of the common provisions for regional operational security coordination in each capacity calculation region.

The methods referred to in point (a) of paragraph 1 shall allow the identification of all elements of a TSO's observability area, being grid elements of other TSOs or transmission-connected DSOs, power generating modules or demand facilities. Those methods shall take into account the following transmission system elements and SGUs' characteristics:

(a) connectivity status or electrical values (such as voltages, power flows, rotor angle) which significantly influence the accuracy of the results of the state estimation for the TSO's control area, above common thresholds;

(b) connectivity status or electrical values (such as voltages, power flows, rotor angle) which significantly influence the accuracy of the results of the TSO's operational security analysis, above common thresholds; and

The methods referred to in point (a) of paragraph 1 shall allow the identification of all elements of a TSO's external contingency list with the following characteristics:

(a) each element has an influence factor on electrical values, such as voltages, power flows, rotor angle, in the TSO's control area greater than common contingency influence thresholds, meaning that the outage of this element can significantly influence the results of the TSO's contingency analysis;

(b) the choice of the contingency influence thresholds shall minimize the risk that the occurrence of a contingency identified in another TSO's control area and not in the TSO's external contingency list could lead to a TSO's system behaviour deemed not acceptable for any element of its internal contingency list, such as an emergency state;

(c) the assessment of such a risk shall be based on situations representative of the various conditions which can be expected, characterised by variables such as generation level and pattern, exchange levels, asset outages.

The principles for common risk assessment referred to in point (b) of paragraph 1 shall set out criteria for the assessment of interconnected system security. Those criteria shall be established with reference to a harmonised level of maximum accepted risk between the different TSO's security analysis. Those principles shall refer to:

(a) the consistency in the definition of exceptional contingencies;

(b) the evaluation of the probability and impact of exceptional contingencies; and

(c) the consideration of exceptional contingencies in a TSO's contingency list when their probability exceeds a common threshold.

The principles for assessing and dealing with uncertainties referred to in point (c) of paragraph 1 shall provide for keeping the impact of the uncertainties regarding generation or demand below an acceptable and harmonised maximum level for each TSO's operational security analysis. Those principles shall set out:

(a) harmonised conditions where one TSO shall update its operational security analysis. The conditions shall take into account relevant aspects such as the time horizon of the generation and demand forecasts, the level of change of forecasted values within the TSO's control area or within the control area of other TSOs, location of generation and demand, the previous results of its operational security analysis; and

(b) minimum frequency of generation and demand forecast updates, depending on their variability and the installed capacity of non-dispatchable generation.

Article 76

Proposal for regional operational security coordination

By 3 months after the approval of the methodology for coordinating operational security analysis in Article 75(1), all TSOs of each capacity calculation region shall jointly develop a proposal for common provisions for regional operational security coordination, to be applied by the regional security coordinators and the TSOs of the capacity calculation region. The proposal shall respect the methodologies for coordinating operational security analysis developed in accordance with Article 75(1) and complement where necessary the methodologies developed in accordance with Articles 35 and 74 of Regulation (EU) 2015/1222. The proposal shall determine:

(a) conditions and frequency of intraday coordination of operational security analysis and updates to the common grid model by the regional security coordinator;

(b) the methodology for the preparation of remedial actions managed in a coordinated way, considering their cross-border relevance as determined in accordance with Article 35 of Regulation (EU) 2015/1222, taking into account the requirements in Articles 20 to 23 and determining at least: (i) the procedure for exchanging the information of the available remedial actions, between relevant TSOs and the regional security coordinator; (ii) the classification of constraints and the remedial actions in accordance with Article 22; (iii) the identification of the most effective and economically efficient remedial actions in case of operational security violations referred to in Article 22; (iv) the preparation and activation of remedial actions in accordance with Article 23(2); (v) the sharing of the costs of remedial actions referred to in Article 22, complementing where necessary the common methodology developed in accordance with Article 74 of Regulation (EU) 2015/1222. As a general principle, costs of non-cross-border relevant congestions shall be borne by the TSO responsible for the given control area and costs of relieving cross-border-relevant congestions shall be covered by TSOs responsible for the control areas in proportion to the aggravating impact of energy exchange between given control areas on the congested grid element.

Article 77

Organisation for regional operational security coordination

The proposal of all TSOs of a capacity calculation region for common provisions for regional operational security coordination pursuant to Article 76(1) shall also include common provisions concerning the organisation of regional operational security coordination, including at least:

(a) the appointment of the regional security coordinator(s) that will perform the tasks in paragraph 3 for that capacity calculation region;

(b) rules concerning the governance and operation of regional security coordinator(s), ensuring equitable treatment of all member TSOs;

(c) where the TSOs propose to appoint more than one regional security coordinator in accordance with subparagraph (a): (i) a proposal for a coherent allocation of the tasks between the regional security coordinators who will be active in that capacity calculation region. The proposal shall take full account of the need to coordinate the different tasks allocated to the regional security coordinators; (ii) an assessment demonstrating that the proposed setup of regional security coordinators and allocation of tasks is efficient, effective and consistent with the regional coordinated capacity calculation established pursuant to Articles 20 and 21 of Regulation (EU) 2015/1222; (iii) an effective coordination and decision making process to resolve conflicting positions between regional security coordinators within the capacity calculation region.

When developing the proposal for common provisions concerning the organisation of regional operational security coordination in paragraph 1, the following requirements shall be met:

(a) each TSO shall be covered by at least one regional security coordinator;

(b) all TSOs shall ensure that the total number of regional security coordinators across the Union is not higher than six.

The TSOs of each capacity calculation region shall propose the delegation of the following tasks in accordance with paragraph 1:

(a) regional operational security coordination in accordance with Article 78 in order to support TSOs fulfil their obligations for the year-ahead, day-ahead and intraday time-frames in Article 34(3) and Articles 72 and 74;

(b) building of common grid model in accordance with Article 79;

(c) regional outage coordination in accordance with Article 80, in order to support TSOs fulfil their obligations in Articles 98 and 100;

(d) regional adequacy assessment in accordance with Article 81 in order to support TSOs fulfil their obligations under Article 107.

Article 78

Regional operational security coordination

Each TSO shall provide the regional security coordinator with all the information and data required to perform the coordinated regional operational security assessment, including at least:

(a) the updated contingency list, established according to the criteria defined in the methodology for coordinating operational security analysis adopted in accordance with Article 75(1);

(b) the updated list of possible remedial actions, among the categories listed in Article 22, and their anticipated costs provided in accordance with Article 35 of Regulation (EU) 2015/1222 if a remedial action includes redispatching or countertrading, aimed at contributing to relieve any constraint identified in the region; and

Each regional security coordinator shall:

(a) perform the coordinated regional operational security assessment in accordance with Article 76 on the basis of the common grid models established in accordance with Article 79, the contingency list and the operational security limits provided by each TSOs in paragraph 1. It shall deliver the results of the coordinated regional operational security assessment at least to all TSOs of the capacity calculation region. Where it detects a constraint, it shall recommend to the relevant TSOs the most effective and economically efficient remedial actions and may also recommend remedial actions other than those provided by the TSOs. This recommendation for remedial actions shall be accompanied by explanations as to its rationale;

(b) coordinate the preparation of remedial actions with and among TSOs in accordance with Article 76(1)(b), to enable TSOs achieve a coordinated activation of remedial actions in real-time.

Article 79

Common grid model building

Article 80

Regional outage coordination

Each TSO shall provide the regional security coordinator with the information necessary to detect and solve regional outage planning incompatibilities, including at least:

(a) the availability plans of its internal relevant assets, stored on the ENTSO for Electricity operational planning data environment;

(b) the most recent availability plans for all non-relevant assets of its control area which are: (i) capable of influencing the results of the outage planning incompatibility analysis; (ii) modelled in the individual grid models which are used for the outage incompatibility assessment;

(c) scenarios on which the outage planning incompatibilities have to be investigated and used to build the corresponding common grid models derived from the common grid models for different time-frames established in accordance with Articles 67 and 79.

Article 81

Regional adequacy assessment

Each TSO shall provide the regional security coordinator with the information necessary to perform the regional adequacy assessments referred to in paragraph 1, including:

(a) the expected total load and available resources of demand response;

(b) the availability of power generation modules; and

TITLE 3

OUTAGE COORDINATION

CHAPTER 1

Outage coordination regions, relevant assets

Article 82

Outage coordination objective

Each TSO shall, with the support of the regional security coordinator for the instances specified in this Regulation, perform outage coordination in accordance with the principles of this Title in order to monitor the availability status of the relevant assets and coordinate the availability plans to ensure the operational security of the transmission system.

Article 83

Regional coordination

All TSOs of an outage coordination region shall jointly develop a regional coordination operational procedure, aimed at establishing operational aspects for the implementation of the outage coordination in each region, which includes:

(a) frequency, scope and type of coordination for, at least, the year-ahead and week-ahead time-frames;

(b) provisions concerning the use of the assessments carried out by the regional security coordinator in accordance with Article 80;

(c) practical arrangements for the validation of the year-ahead relevant grid element availability plans, as required by Article 98.

Article 84

Methodology for assessing the relevance of assets for outage coordination

The methodology referred to in paragraph 1 shall be based on qualitative and quantitative aspects that identify the impact on a TSO's control area of the availability status of either power generating modules, demand facilities, or grid elements which are located in a transmission system or in a distribution system including a closed distribution system, and which are connected directly or indirectly to another TSO's control area and in particular on:

(a) quantitative aspects based on the evaluation of changes of electrical values such as voltages, power flows, rotor angle on at least one grid element of a TSO's control area, due to the change of availability status of a potential relevant asset located in another control area. That evaluation shall take place on the basis of year-ahead common grid models;

(b) thresholds on the sensitivity of the electrical values referred to in point (a), against which to assess the relevance of an asset. Those thresholds shall be harmonised at least per synchronous area;

(d) qualitative aspects such as, but not limited to, the size and proximity to the borders of a control area of potential relevant power generating modules, demand facilities or grid elements;

(e) systematic relevance of all grid elements located in a transmission system or in a distribution system which connect different control areas; and

(f) systematic relevance of all critical network elements.

Article 85

Lists of relevant power generating modules and relevant demand facilities

For each internal relevant asset which is a power generating module or demand facility, the TSO shall:

(a) inform the owner of the relevant power generating module or relevant demand facility about its inclusion in the list;

(b) inform DSOs about the relevant power generating modules and the relevant demand facilities which are connected to their distribution system; and

(c) inform CDSOs about the relevant power generating modules and the relevant demand facilities which are connected to their closed distribution system.

Article 86

Update of the lists of relevant power generating modules and relevant demand facilities

Article 87

Lists of relevant grid elements

For each internal relevant asset which is a grid element, the TSO shall:

(a) inform the owner of the relevant grid element about its inclusion in the list;

(b) inform DSOs about the relevant grid elements which are connected to their distribution system; and

Article 88

Update of the list of relevant grid elements

Article 89

Appointment of outage planning agents

Article 90

Treatment of relevant assets located in a distribution system or in a closed distribution system

CHAPTER 2

Development and update of availability plans of relevant assets

Article 91

Variations to deadlines for the year-ahead outage coordination

All TSOs within a synchronous area may jointly agree to adopt and implement a time-frame for the year-ahead outage coordination that deviates from the time-frame defined in Articles 94, 97 and 99, provided that the outage coordination of other synchronous areas is not impacted.

Article 92

General provisions on availability plans

The availability status of a relevant asset shall be one of the following:

(a) ‘available’ where the relevant asset is capable of and ready for providing service regardless of whether it is or it is not in operation;

(b) ‘unavailable’ where the relevant asset is not capable of or ready for providing service;

The ‘testing’ status shall only apply in case of a potential impact on the transmission system and for the following time periods:

(a) between first connection and final commissioning of the relevant asset; and

(b) directly following maintenance of the relevant asset.

The availability plans shall contain at least the following information:

(a) the reason for the ‘unavailable’ status of a relevant asset;

(b) where such conditions are identified, the conditions to be fulfilled before applying the ‘unavailable’ status of a relevant asset in real-time;

(c) the time required to restore a relevant asset back to service where necessary in order to maintain operational security.

Article 93

Long-term indicative availability plans

Article 94

Provision of year-ahead availability plan proposals

The TSO(s) referred to in paragraph 1 shall examine the requests for amendment of an availability plan after the year-ahead outage coordination has been finalised:

(a) following the order in which the requests were received; and

(b) applying the procedure established in accordance with Article 100.

Article 95

Year-ahead coordination of the availability status of relevant assets for which the outage planning agent is not a TSO taking part in an outage coordination region, nor a DSO or a CDSO

When a TSO detects outage planning incompatibilities, it shall implement the following process:

(a) inform each affected outage planning agent of the conditions it shall fulfil to mitigate the detected outage planning incompatibilities;

(b) the TSO may request that one or more outage planning agents submit an alternative availability plan fulfilling the conditions referred to in point (a); and

(c) the TSO shall repeat the assessment pursuant to paragraph 1 to determine whether any outage planning incompatibilities remain.

Following a TSO's request in accordance with point (b) of paragraph 2, if the outage planning agent fails to submit an alternative availability plan aimed at mitigating all outage planning incompatibilities, the TSO shall develop an alternative availability plan which shall:

(a) take into account the impact reported by the affected outage planning agents as well as the DSO or CDSO where relevant;

(b) limit the changes in the alternative availability plan to what is strictly necessary to mitigate the outage planning incompatibilities; and

(c) notify its regulatory authority, the affected DSOs and CDSOs if any, and the affected outage planning agents about the alternative availability plan, including the reasons for developing it, as well as the impact reported by the affected outage planning agents and, where relevant, the DSOs or CDSOs.

Article 96

Year-ahead coordination of the availability status of relevant assets for which the outage planning agent is a TSO taking part in an outage coordination region, a DSO or a CDSO

When establishing the availability status of relevant grid elements in accordance with paragraphs 1 and 2, the TSO, DSO and CDSO shall:

(a) minimize the impact on the market while preserving operational security; and

(b) use as a basis the availability plans submitted and developed in accordance with Article 94.

Where the ‘unavailable’ status of a relevant grid element has not been planned after taking the measures in paragraph 4 and the absence of such planning would threaten operational security, the TSO shall:

(a) take the necessary actions to plan the ‘unavailable’ status while ensuring operational security, taking into account the impact reported to the TSO by affected outage planning agents;

(b) notify the actions referred to in point (a) to all affected parties; and

(c) notify the relevant regulatory authorities, the affected DSOs or CDSOs if any and the affected outage planning agents of the actions taken, including the rationale for such actions, the impact reported by affected outage planning agents and the DSOs or CDSOs where relevant.

Article 97

Provision of preliminary year-ahead availability plans

Article 98

Validation of year-ahead availability plans within outage coordination regions

Where no solution is found for an outage planning incompatibility each concerned TSO, subject to approval by the competent regulatory authority where the Member State so provides, shall:

(a) force to ‘available’ status all the ‘unavailable’ or ‘testing’ statuses for the relevant assets involved in an outage planning incompatibility during the period concerned; and

(b) notify to the relevant regulatory authorities, the affected DSOs or CDSOs, if any, and the affected outage planning agents of the actions taken including the rationale for such actions, the impact reported by affected outage planning agents and the DSOs or CDSOs where relevant.

Article 99

Final year-ahead availability plans

Before 1 December of each calendar year, each TSO shall:

(a) finalise the year-ahead outage coordination of internal relevant assets; and

(b) finalise the year-ahead availability plans for internal relevant assets and store them on the ENTSO for Electricity operational planning data environment.

Article 100

Updates to the final year-ahead availability plans

In case of a request for amendment pursuant to paragraph 2, the following procedure shall be applied:

(a) the recipient TSO shall acknowledge the request and assess as soon as reasonably practicable whether the amendment leads to outage planning incompatibilities;

(b) where outage planning incompatibilities are detected, the involved TSOs of the outage coordination region shall jointly identify a solution in coordination with the outage planning agents concerned and, if relevant, the DSOs and CDSOs, using the means at their disposal;

(c) where no outage planning incompatibility has been detected or if no outage planning incompatibility remains, the recipient TSO shall validate the requested amendment, and the TSOs concerned shall consequently notify all affected parties and update the final year-ahead availability plan on the ENTSO for Electricity operational planning data environment; and

(d) where no solution is found for outage planning incompatibilities the recipient TSO shall reject the requested amendment.

When a TSO taking part in an outage coordination region intends to amend the final year-ahead availability plan of a relevant asset for which it acts as the outage planning agent, it shall initiate the following procedure:

(a) the requesting TSO shall prepare a proposal for amendment to the year-ahead availability plan, including an assessment of whether it could lead to outage planning incompatibilities and shall submit its proposal to all other TSOs of its outage coordination region(s);

(b) where outage planning incompatibilities are detected, the involved TSOs of the outage coordination region shall jointly identify a solution in coordination with the concerned outage planning agents and, if relevant, the DSOs and the CDSOs, using the means at their disposal;

(c) where no outage planning incompatibility has been detected or if a solution to an outage planning incompatibility is found, the concerned TSOs shall validate the requested amendment and consequently they shall notify all affected parties and update the final year-ahead availability plan on the ENTSO for Electricity operational planning data environment;

(d) where no solution to outage planning incompatibilities are found, the requesting TSO shall retract the procedure for amendment.

CHAPTER 3

Execution of availability plans

Article 101

Management of the ‘testing’ status of relevant assets

The outage planning agent of a relevant asset the availability status of which has been declared as ‘testing’ shall provide the TSO, and, if connected to a distribution system, including closed distribution systems, the DSO or the CDSO within 1 month before the start of the ‘testing’ status, with:

(a) a detailed test plan;

(b) an indicative generation or consumption schedule if the concerned relevant asset is a relevant power generating module or a relevant demand facility; and

(c) changes to the topology of the transmission system or distribution system if the concerned relevant asset is a relevant grid element.

Article 102

Procedure for handling forced outages

When notifying the forced outage, the outage planning agent shall provide the following information:

(a) the reason for the forced outage;

(b) the expected duration of the forced outage; and

(c) where applicable, the impact of the forced outage on the availability status of other relevant assets for which it is the outage planning agent.

Article 103

Real-time execution of the availability plans

TITLE 4

ADEQUACY

Article 104

Forecast for control area adequacy analysis

Each TSO shall make any forecast used for control area adequacy analyses pursuant to Articles 105 and 107 available to all other TSOs through the ENTSO for Electricity operational planning data environment.

Article 105

Control area adequacy analysis

When performing a control area adequacy analysis pursuant to paragraph 1, each TSO shall:

(a) use the latest availability plans and the latest available data for: (i) the capabilities of power generating modules provided pursuant to Article 43(5) and Articles 45 and 51; (ii) cross-zonal capacity; (iii) possible demand response provided pursuant to Articles 52 and 53;

(b) take into account the contributions of generation from renewable energy sources and load;

(c) assess the probability and expected duration of an absence of adequacy and the expected energy not supplied as a result of such absence.

Article 106

Control area adequacy up to and including week-ahead

Article 107

Control area adequacy in day-ahead and intraday

Each TSO shall perform a control area adequacy analysis in a day-ahead and intraday time-frame on the basis of:

(a) schedules referred to in Article 111;

(b) forecasted load;

(d) active power reserves in accordance with the data provided pursuant to Article 46(1)(a);

(e) control area import and export capacities consistent with cross-zonal capacities calculated where applicable in accordance with Article 14 of Regulation (EU) 2015/1222;

(f) capabilities of power generating modules in accordance with the data provided pursuant to Article 43(4) and Articles 45 and 51 and their availability statuses; and

(g) capabilities of demand facilities with demand response in accordance with the data provided pursuant to Articles 52 and 53 and their availability statuses.

Each TSO shall evaluate:

(a) the minimum level of import and the maximum level of export compatible with its control area adequacy;

(b) the expected duration of a potential absence of adequacy; and

TITLE 5

ANCILLARY SERVICES

Article 108

Ancillary services

With regard to active power and reactive power services, and in coordination with other TSOs where appropriate, each TSO shall:

(a) design, set up and manage the procurement of ancillary services;

(b) monitor, on the basis of data provided pursuant to Title 2 of Part II, whether the level and location of available ancillary services allows ensuring operational security; and

Article 109

Reactive power ancillary services

In order to increase the efficiency of operation of its transmission system elements, each TSO shall monitor:

(a) the available reactive power capacities of power generating facilities;

(b) the available reactive power capacities of transmission-connected demand facilities;

(d) the available transmission-connected equipment dedicated to providing reactive power; and

(e) the ratios of active power and reactive power at the interface between the transmission system and transmission-connected distribution systems.

Where the level of reactive power ancillary services is not sufficient for maintaining operational security, each TSO shall:

(a) inform neighbouring TSOs; and

(b) prepare and activate remedial actions pursuant to Article 23.

TITLE 6

SCHEDULING

Article 110

Establishment of scheduling processes

Article 111

Notification of schedules within scheduling areas

Each scheduling agent, except scheduling agents of shipping agents, shall submit to the TSO operating the scheduling area, if requested by the TSO, and, where applicable, to third party, the following schedules:

(a) generation schedules;

(b) consumption schedules;

(d) external commercial trade schedules.

Each scheduling agent of a shipping agent or, where applicable, a central counterparty shall submit to the TSO operating a scheduling area covered by market coupling, if requested by the concerned TSO, and where applicable to third party, the following schedules:

(a) external commercial trade schedules as: (i) multilateral exchanges between the scheduling area and a group of other scheduling areas; (ii) bilateral exchanges between the scheduling area and another scheduling area;

(b) internal commercial trade schedules between the shipping agent and central counter parties;

Article 112

Coherence of schedules

Article 113

Provision of information to other TSOs

At the request of another TSO, the requested TSO shall calculate and provide:

(a) aggregated netted external schedules; and

(b) netted area AC position, where the scheduling area is interconnected to other scheduling areas via AC transmission links.

When required for the creation of common grid models, in accordance with Article 70(1), each TSO operating a scheduling area shall provide any requesting TSO with:

(a) generation schedules; and

(b) consumption schedules.

TITLE 7

ENTSO FOR ELECTRICITY OPERATIONAL PLANNING DATA ENVIRONMENT

Article 114

General provisions for ENTSO for Electricity operational planning data environment

Article 115

Individual grid models, common grid models and operational security analysis

For the year-ahead time-frame, the following information shall be available on the ENTSO for Electricity operational planning data environment:

(a) year-ahead individual grid model per TSO and per scenario determined in accordance with Article 66; and

(b) year-ahead common grid model per scenario defined in accordance with Article 67.

For the day-ahead and intraday time-frames, the following information shall be available on the ENTSO for Electricity operational planning data environment:

(a) day-ahead and intraday individual grid models per TSO and according to the time resolution defined pursuant to Article 70(1);

(b) scheduled exchanges at the relevant time instances per scheduling area or per scheduling area border, whichever is deemed relevant by the TSOs, and per HVDC system linking scheduling areas;

(d) a list of prepared and agreed remedial actions identified to cope with constraints having cross-border relevance.

Article 116

Outage coordination

Article 117

System adequacy

The information referred to in paragraph 1 shall include at least:

(a) the season-ahead system adequacy data provided by each TSO;

(b) the season-ahead pan-European system adequacy analysis report;

(d) information about a lack of adequacy in line with Article 105(4).

PART IV

LOAD-FREQUENCY CONTROL AND RESERVES

TITLE 1

OPERATIONAL AGREEMENTS

Article 118

Synchronous area operational agreements

By 12 months after entry into force of this Regulation, all TSOs of each synchronous area shall jointly develop common proposals for:

(a) the dimensioning rules for FCR in accordance with Article 153;

(b) additional properties of FCR in accordance with Article 154(2);

(c) the frequency quality defining parameters and the frequency quality target parameters in accordance with Article 127;

(d) for the Continental Europe (‘CE’) and Nordic synchronous areas, the frequency restoration control error target parameters for each LFC block in accordance with Article 128;

(e) the methodology to assess the risk and the evolution of the risk of exhaustion of FCR of the synchronous area in accordance with Article 131(2);

(f) the synchronous area monitor in accordance with Article 133;

(g) the calculation of the control program from the netted area AC position with a common ramping period for ACE calculation for a synchronous area with more than one LFC area in accordance with Article 136;

(h) if applicable, restrictions for the active power output of HVDC interconnectors between synchronous areas in accordance with Article 137;

(i) the LFC structure in accordance with Article 139;

(j) if applicable, the methodology to reduce the electrical time deviation in accordance with Article 181;

(k) whenever the synchronous area is operated by more than one TSO, the specific allocation of responsibilities between TSOs in accordance with Article 141;

(l) operational procedures in case of exhausted FCR in accordance with Article 152(7);

(m) for the GB and IE/NI synchronous areas, measures to ensure the recovery of energy reservoirs in accordance with to Article 156(6)(b);

(n) operational procedures to reduce the system frequency deviation to restore the system state to normal state and to limit the risk of entering into the emergency state in accordance with Article 152(10);

(o) the roles and responsibilities of the TSOs implementing an imbalance netting process, a cross-border FRR activation process or a cross-border RR activation process in accordance with Article 149(2);

(p) requirements concerning the availability, reliability and redundancy of the technical infrastructure in accordance with Article 151(2);

(q) common rules for the operation in normal state and alert state in accordance with Article 152(6) and the actions referred to in Article 152(15);

(r) for the CE and Nordic synchronous areas, the minimum activation period to be ensured by FCR providers in accordance with Article 156(10);

(s) for the CE and Nordic synchronous areas, the assumptions and methodology for a cost-benefit analysis in accordance with Article 156(11);

(t) if applicable, for synchronous areas other than CE, limits for the exchange of FCR between the TSOs in accordance with Article 163(2);

(u) the roles and responsibilities of the reserve connecting TSO, the reserve receiving TSO and the affected TSO as regards the exchange of FRR and RR defined in accordance with Article 165(1);

(v) the roles and responsibilities of the control capability providing TSO, the control capability receiving TSO and the affected TSO for the sharing of FRR and RR defined in accordance with Article 166(1);

(w) the roles and responsibilities of the reserve connecting TSO, the reserve receiving TSO and the affected TSO for the exchange of reserves between synchronous areas, and of the control capability providing TSO, the control capability receiving TSO and the affected TSO for the sharing of reserves between synchronous areas defined in accordance with Article 171(2);

(x) the methodology to determine limits on the amount of sharing of FCR between synchronous areas defined in accordance with Article 174(2);

(y) for the GB and IE/NI synchronous areas, the methodology to determine the minimum provision of reserve capacity on FCR in accordance with Article 174(2)(b);

(z) the methodology to determine limits on the amount of exchange of FRR between synchronous areas defined in accordance with Article 176(1) and the methodology to determine limits on the amount of sharing of FRR between synchronous areas defined in accordance with Article 177(1); and

(aa) the methodology to determine limits on the amount of exchange of RR between synchronous areas defined in accordance with Article 178(1) and the methodology to determine limits on the amount of sharing of RR between synchronous areas defined in accordance with Article 179(1).

Article 119

LFC block operational agreements

By 12 months after entry into force of this Regulation, all TSOs of each LFC block shall jointly develop common proposals for:

(a) where the LFC block consists of more than one LFC area, FRCE target parameters for each LFC area defined in accordance with Article 128(4);

(b) LFC block monitor in accordance with Article 134(1);

(d) where the LFC block is operated by more than one TSO, the specific allocation of responsibilities between TSOs within the LFC block in accordance with Article 141(9);

(e) if applicable, appointment of the TSO responsible for the tasks in Article 145(6);

(f) additional requirements for the availability, reliability and redundancy of technical infrastructure defined in accordance with Article 151(3);

(g) operational procedures in case of exhausted FRR or RR in accordance with Article 152(8);

(h) the FRR dimensioning rules defined in accordance with Article 157(1);

(i) the RR dimensioning rules defined in accordance with Article 160(2);

(j) where the LFC block is operated by more than one TSO, the specific allocation of responsibilities defined in accordance with Article 157(3), and, if applicable, the specific allocation of responsibilities defined in accordance Article 160(6);

(k) the escalation procedure defined in accordance with Article 157(4) and, if applicable, the escalation procedure defined in accordance with Article 160(7);

(l) the FRR availability requirements, the requirements on the control quality defined in accordance with Article 158(2), and if applicable, the RR availability requirements and the requirements on the control quality defined in accordance with Article 161(2);

(m) if applicable, any limits on the exchange of FCR between the LFC areas of the different LFC blocks within the CE synchronous area and the exchange of FRR or RR between the LFC areas of an LFC block of a synchronous area consisting of more than one LFC block defined in accordance with Article 163(2), Article 167 and Article 169(2);

(n) the roles and the responsibilities of the reserve connecting TSO, the reserve receiving TSO and of the affected TSO for the exchange of FRR and/or RR with TSOs of other LFC blocks defined in accordance with Article 165(6);

(o) the roles and the responsibilities of the control capability providing TSO, the control capability receiving TSO and of the affected TSO for the sharing of FRR and RR defined in accordance with Article 166(7);

(p) roles and the responsibilities of the control capability providing TSO, the control capability receiving TSO and of the affected TSO for the sharing of FRR and RR between synchronous areas in accordance with Article 175(2);

(q) coordination actions aiming to reduce the FRCE as defined in Article 152(14); and

(r) measures to reduce the FRCE by requiring changes in the active power production or consumption of power generating modules and demand units in accordance with Article 152(16).

Article 120

LFC area operational agreement

By 12 months after entry into force of this Regulation, all TSOs of each LFC area shall establish an LFC area operational agreement that shall include at least:

(a) the specific allocation of responsibilities between TSOs within the LFC area in accordance with Article 141(8);

(b) the appointment of the TSO responsible for the implementation and operation of the frequency restoration process in accordance with Article 143(4).

Article 121

Monitoring area operational agreement

By 12 months after entry into force of this Regulation, all TSOs of each monitoring area shall establish a monitoring area operational agreement that shall include at least the allocation of responsibilities between TSOs within the same monitoring area in accordance with Article 141(7).

Article 122

Imbalance netting agreement

All TSOs participating in the same imbalance netting process shall establish an imbalance netting agreement that shall at least include the roles and responsibilities of the TSOs in accordance with Article 149(3).

Article 123

Cross-border FRR activation agreement

All TSOs participating in the same cross-border FRR activation process shall establish a cross-border FRR activation agreement that shall include at least the roles and responsibilities of the TSOs in accordance with Article 149(3).

Article 124

Cross-border RR activation agreement

All TSOs participating in the same cross-border RR activation process shall establish a cross-border RR activation agreement that shall include at least the roles and responsibilities of the TSOs in accordance with Article 149(3).

Article 125

All TSOs participating in the same sharing process of FCR, FRR or RR shall establish a sharing agreement that shall include at least:

(a) in case of sharing FRR or RR within a synchronous area, the roles and responsibilities of the control capability receiving TSO and of the control capability providing TSO and the affected TSOs in accordance with Article 165(3); or

(b) in case of sharing reserves between synchronous areas, the roles and responsibilities of the control capability receiving TSO and of the control capability providing TSO in accordance with Article 171(4) and the procedures in case the sharing of reserves between synchronous areas is not executed in real-time in accordance with Article 171(9).

Article 126

Exchange agreement

All TSOs participating in the same exchange of FCR, FRR or RR shall establish an exchange agreement that shall include at least:

(a) in case of exchange of FRR or RR within a synchronous area, the roles and responsibilities of the reserve connecting and reserve receiving TSOs in accordance with to Article 165(3); or

(b) in case of exchange of reserves between synchronous areas, the roles and responsibilities of the reserve connecting and reserve receiving TSOs in accordance with Article 171(4) and the procedures in case the exchange of reserves between synchronous areas is not executed in real-time in accordance with Article 171(9).

TITLE 2

FREQUENCY QUALITY

Article 127

Frequency quality defining and target parameters

The frequency quality defining parameters shall be:

(a) the nominal frequency for all synchronous areas;

(b) the standard frequency range for all synchronous areas;

(d) the maximum steady-state frequency deviation for all synchronous areas;

(e) the time to restore frequency for all synchronous areas;

(f) the time to recover frequency for the GB and IE/NI synchronous areas;

(g) the frequency restoration range for the GB, IE/NI and Nordic synchronous areas;

(h) the frequency recovery range for the GB and IE/NI synchronous areas; and

(i) the alert state trigger time for all synchronous areas.

All TSOs of CE and Nordic synchronous areas shall have the right to propose in the synchronous area operational agreement values different from those set out in Tables 1 and 2 of Annex III regarding:

(a) the alert state trigger time;

(b) the maximum number of minutes outside the standard frequency range.

All TSOs of the GB and IE/NI synchronous areas shall have the right to propose in the synchronous area operational agreement values different from those set out in Tables 1 and 2 of Annex III regarding:

(a) time to restore frequency;

(b) the alert state trigger time; and

The proposal for modification of the values pursuant to paragraph 6 and 7 shall be based on an assessment of the recorded values of the system frequency for a period of at least 1 year and the synchronous area development and it shall meet the following conditions:

(a) the proposed modification of the frequency quality defining parameters in Table 1 of Annex III or the frequency quality target parameter in Table 2 of Annex III takes into account: (i) the system's size, based on the consumption and generation of the synchronous area and the inertia of the synchronous area; (ii) the reference incident; (iii) grid structure and/or network topology; (iv) load and generation behaviour; (v) the number and response of power generating modules with limited frequency sensitive mode — over frequency and limited frequency sensitive mode — under frequency as defined in Article 13(2) and Article 15(2)(c) of Regulation (EU) 2016/631; (vi) the number and response of demand units operating with activated demand response system frequency control or demand response very fast active power control as defined in Articles 29 and 30 of Regulation (EU) 2016/1388; and (vii) the technical capabilities of power generating modules and demand units;

(b) all TSOs of the synchronous area shall conduct a public consultation concerning the impact on stakeholders of the proposed modification of the frequency quality defining parameters in Table 1 of Annex III or the frequency quality target parameter in Table 2 of Annex III.

Article 128

FRCE target parameters

All TSOs of the CE and Nordic synchronous areas shall endeavour to comply with the following FRCE target parameters for each LFC block of the synchronous area:

(a) the number of time intervals per year outside the Level 1 FRCE range within a time interval equal to the time to restore frequency shall be less than 30 % of the time intervals of the year; and

(b) the number of time intervals per year outside the Level 2 FRCE range within a time interval equal to the time to restore frequency shall be less than 5 % of the time intervals of the year.

All TSOs of the GB and IE/NI synchronous areas shall endeavour to comply with the following FRCE target parameters of a synchronous area:

(a) the maximum number of time intervals outside the Level 1 FRCE range shall be less than or equal to the value in the Table of Annex IV as a percentage of the time intervals per year;

(b) the maximum number of time intervals outside the Level 2 FRCE range shall be less than or equal to the value in the Table of Annex IV as a percentage of the time intervals per year.

Article 129

Criteria application process

The criteria application process shall comprise:

(a) the collection of frequency quality evaluation data; and

(b) the calculation of frequency quality evaluation criteria.

Article 130

Frequency quality evaluation data

The frequency quality evaluation data shall be:

(a) for the synchronous area: (i) the instantaneous frequency data; and (ii) the instantaneous frequency deviation data;

(b) for each LFC block of the synchronous area, the instantaneous FRCE data.

Article 131

Frequency quality evaluation criteria

The frequency quality evaluation criteria shall comprise:

(a) for the synchronous area during operation in normal state or alert state as determined by Article 18(1) and (2), on a monthly basis, for the instantaneous frequency data: (i) the mean value; (ii) the standard deviation; (iii) the 1-,5-,10-, 90-,95- and 99-percentile; (iv) the total time in which the absolute value of the instantaneous frequency deviation was larger than the standard frequency deviation, distinguishing between negative and positive instantaneous frequency deviations; (v) the total time in which the absolute value of the instantaneous frequency deviation was larger than the maximum instantaneous frequency deviation, distinguishing between negative and positive instantaneous frequency deviations; (vi) the number of events in which the absolute value of the instantaneous frequency deviation of the synchronous area exceeded 200 % of the standard frequency deviation and the instantaneous frequency deviation was not returned to 50 % of the standard frequency deviation for the CE synchronous area and to the frequency restoration range for the GB, IE/NI and Nordic synchronous areas, within the time to restore frequency. The data shall distinguish between negative and positive frequency deviations; (vii) for the GB and IE/NI synchronous areas, the number of events for which the absolute value of the instantaneous frequency deviation was outside of the frequency recovery range and was not returned to the frequency recovery range within the time to recover frequency, distinguishing between negative and positive frequency deviations;

(b) for each LFC block of the CE or Nordic synchronous areas during operation in normal state or alert state in accordance with Article 18(1) and (2), on a monthly basis: (i) for a data-set containing the average values of the FRCE of the LFC block over time intervals equal to the time to restore frequency: — the mean value, — the standard deviation, — the 1-,5-,10-, 90-,95- and 99-percentile, — the number of time intervals in which the average value of the FRCE was outside the Level 1 FRCE range, distinguishing between negative and positive FRCE, and — the number of time intervals in which the average value of the FRCE was outside the Level 2 FRCE range, distinguishing between negative and positive FRCE; (ii) for a data-set containing the average values of the FRCE of the LFC block over time intervals with a length of one minute: the number of events on a monthly basis for which the FRCE exceeded 60 % of the reserve capacity on FRR and was not returned to 15 % of the reserve capacity on FRR within the time to restore frequency, distinguishing between negative and positive FRCE;

(c) for the LFC blocks of the GB or IE/NI synchronous area, during operation in normal state or alert state in accordance with Article 18(1) and (2), on a monthly basis and for a data-set containing the average values of the FRCE of the LFC block over time intervals with a length of one minute: the number of events for which the absolute value of the FRCE exceeded the maximum steady-state frequency deviation and the FRCE was not returned to 10 % of the maximum steady-state frequency deviation within the time to restore frequency, distinguishing between negative and positive FRCE.

Article 132

Data collection and delivery process

The data collection and delivery process shall comprise the following:

(a) measurements of the system frequency;

(b) calculation of the frequency quality evaluation data; and

Article 133

Synchronous area monitor

Article 134

LFC block monitor

Article 135

Information on load and generation behaviour

In accordance with Article 40, each connecting TSO shall have the right to request the information necessary from SGUs to monitor the load and generation behaviour related to imbalances. That information may include:

(a) the time-stamped active power setpoint for real-time and future operation; and

(b) the time-stamped total active power output.

Article 136

Ramping period within the synchronous area

All TSOs of each synchronous area with more than one LFC area shall specify in the synchronous area operational agreement a common ramping period of aggregated netted schedules between the LFC areas in the synchronous area. The calculation of the control program from the netted area AC position for ACE calculation shall be performed with the common ramping period.

Article 137

Ramping restrictions for active power output

All TSOs of an LFC block shall have the right to determine in the LFC block operational agreement the following measures to support the fulfilment of the FRCE target parameter of the LFC block and to alleviate deterministic frequency deviations, taking into account the technological restrictions of power generating modules and demand units:

(a) obligations on ramping periods and/or maximum ramping rates for power generating modules and/or demand units;

(b) obligations on individual ramping starting times for power generating modules and/or demand units within the LFC block; and

(c) coordination of the ramping between power generating modules, demand units and active power consumption within the LFC block.

Article 138

Mitigation

Where the values calculated for the period of one calendar year concerning the frequency quality target parameters or the FRCE target parameters are outside the targets set for the synchronous area or for the LFC block, all TSOs of the relevant synchronous area or of the relevant LFC block shall:

(a) analyse whether the frequency quality target parameters or the FRCE target parameters will remain outside the targets set for the synchronous area or for the LFC block and in case of a justified risk that this may happen, analyse the causes and develop recommendations; and

(b) develop mitigation measures to ensure that the targets for the synchronous area or for the LFC block can be met in the future.

TITLE 3

LOAD-FREQUENCY CONTROL STRUCTURE

Article 139

Basic structure

The load-frequency control structure of each synchronous area shall include:

(a) a process activation structure in accordance with Article 140; and

(b) a process responsibility structure in accordance with Article 141.

Article 140

Process activation structure

The process activation structure shall include:

(a) a FCP pursuant to Article 142;

(b) a FRP pursuant to Article 143; and

The process activation structure may include:

(a) a RRP pursuant to Article 144;

(b) an imbalance netting process in accordance with Article 146;

(d) a cross-border RR activation process in accordance with Article 148; and

(e) for synchronous areas other than CE, a time control process pursuant to Article 181.

Article 141

Process responsibility structure

When specifying the process responsibility structure, all TSOs of each synchronous area shall take into account at least the following criteria:

(a) the size and the total inertia, including synthetic inertia, of the synchronous area;

(b) the grid structure and/or network topology; and

By 4 months after entry into force of this Regulation, all TSOs of a synchronous area shall jointly develop a common proposal regarding the determination of the LFC blocks, which shall comply with the following requirements:

(a) a monitoring area corresponds to or is part of only one LFC area;

(b) a LFC area corresponds to or is part of only one LFC block;

(d) each network element is part of only one monitoring area, only one LFC area and only one LFC block.

All TSOs of each LFC area shall:

(a) continuously monitor the FRCE of the LFC area;

(b) implement and operate a FRP for the LFC area;

(d) have the right to implement one or several of the processes referred to in Article 140(2).

All TSOs of each LFC block shall:

(a) endeavour to fulfil the FRCE target parameters of the LFC block as defined in Article 128; and

(b) comply with the FRR dimensioning rules in accordance with Article 157 and the RR dimensioning rules in accordance with Article 160.

All TSOs of each synchronous area shall:

(a) implement and operate a FCP for the synchronous area;

(b) comply with FCR dimensioning rules in accordance with Article 153; and

Article 142

Frequency containment process

Article 143

Frequency restoration process

The control target of the FRP shall be to:

(a) regulate the FRCE towards zero within the time to restore frequency;

(b) for the CE and Nordic synchronous areas, to progressively replace the activated FCR by activation of FRR in accordance with Article 145.

The FRCE is:

(a) the ACE of an LFC area, where there is more than one LFC area in a synchronous area; or

(b) the frequency deviation, where one LFC area corresponds to the LFC block and the synchronous area.

The ACE of a LFC area shall be calculated as the sum of the product of the K-Factor of the LFC area with the frequency deviation plus de subtraction of:

(a) the total interconnector and virtual tie-line active power flow; and

(b) the control program in accordance with Article 136.

Article 144

Reserve replacement process

The control target of the RRP shall be to fulfil at least one of the following goals by activation of RR:

(a) progressively restore the activated FRR;

(b) support FRR activation;

Article 145

Automatic and manual frequency restoration process

The aFRP shall be operated in a closed-loop manner where the FRCE is an input and the setpoint for automatic FRR activation is an output. The setpoint for automatic FRR activation shall be calculated by a single frequency restoration controller operated by a TSO within its LFC area. For the CE and Nordic synchronous areas, the frequency restoration controller shall:

(a) be an automatic control device designed to reduce the FRCE to zero;

(b) have proportional-integral behaviour;

(c) have a control algorithm which prevents the integral term of a proportional-integral controller from accumulating the control error and overshooting; and

(d) have functionalities for extraordinary operational modes for the alert and emergency states.

In addition to the aFRP implementation in the LFC areas, all TSOs of an LFC block which consists of more than one LFC area shall have the right to appoint one TSO of the LFC block in the LFC block operational agreement to:

(a) calculate and monitor the FRCE of the whole LFC block; and

(b) take the FRCE of the whole LFC block into account for the calculation of the setpoint value for aFRR activation in accordance with Article 143(3) in addition to the FRCE of its LFC area.

Article 146

Imbalance netting process

TSOs shall implement the imbalance netting process in a way which does not affect:

(a) the stability of the FCP of the synchronous area or synchronous areas involved in the imbalance netting process;

(b) the stability of the FRP and the RRP of each LFC area operated by participating or affected TSOs; and

TSOs shall implement the imbalance netting power interchange between LFC areas of a synchronous area in at least one of the following ways:

(a) by defining an active power flow over a virtual tie-line which shall be part of the FRCE calculation;

(b) by adjusting the active power flows over HVDC interconnectors.

Article 147

Cross-border FRR activation process

TSOs shall implement the cross-border FRR activation process in a way which does not affect:

(a) the stability of the FCP of the synchronous area or synchronous areas involved in the cross-border FRR activation process;

(b) the stability of the FRP and the RRP of each LFC area operated by participating or affected TSOs; and

TSOs shall implement the frequency restoration power interchange between LFC areas of the same synchronous area through one of the following actions:

(a) defining an active power flow over a virtual tie-line which shall be part of the FRCE calculation where FRR activation is automated;

(b) adjusting a control program or defining an active power flow over a virtual tie-line between LFC areas where FRR activation is manual; or

Article 148

Cross-border RR activation process

TSOs shall implement the cross-border RR activation process in a way which does not affect:

(a) the stability of the FCP of the synchronous area or synchronous areas involved in the cross-border RR activation process;

(b) the stability of the FRP and the RRP of each LFC area operated by participating or affected TSOs; and

TSOs shall implement the control program between LFC areas of the same synchronous area by carrying out at least one of the following actions:

(a) determining an active power flow over a virtual tie-line which shall be part of the FRCE calculation;

(b) adjusting a control program; or

Article 149

General requirements for cross-border control processes

All TSOs participating in the same imbalance netting process, in the same cross-border FRR activation process or in the same cross-border RR activation process shall specify in the respective agreements, the roles and responsibilities of all TSOs including:

(a) the provision of all input data necessary for: (i) the calculation of the power interchange with respect to the operational security limits; and (ii) the performance of real-time operational security analysis by participating and affected TSOs;

(b) the responsibility of calculating the power interchange; and

Article 150

TSO notification

TSOs who intend to exercise the right to implement an imbalance netting process, a cross-border FRR activation process, a cross-border RR activation process, an exchange of reserves or a sharing of reserves shall, 3 months before exercising such right, notify all other TSOs of the same synchronous area about:

(a) the TSOs involved;

(b) the expected amount of power interchange due to the imbalance netting process, cross-border FRR activation process or cross-border RR activation process;

(d) the timeframe of exchange or sharing of reserves.

The affected TSO shall have the right to:

(a) require the provision of real-time values of imbalance netting power interchange, frequency restoration power interchange and control program necessary for real-time operational security analysis; and

(b) require the implementation of an operational procedure enabling the affected TSO to set limits for the imbalance netting power interchange, frequency restoration power interchange and control program between the respective LFC areas based on operational security analysis in real-time.

Article 151

Infrastructure

All TSOs of a synchronous area shall specify, in the synchronous area operational agreement, minimum requirements for the availability, reliability and redundancy of the technical infrastructure referred to in paragraph 1 including:

(a) the accuracy, resolution, availability and redundancy of active power flow and virtual tie-line measurements;

(b) the availability and redundancy of digital control systems;

(d) communication protocols.

Each TSO of a LFC area shall:

(a) ensure a sufficient quality and availability of the FRCE calculation;

(b) perform real-time quality monitoring of the FRCE calculation;

(d) where the FRCE is determined by the ACE, perform an ex-post quality monitoring of the FRCE calculation by comparing FRCE to reference values at least on an annual basis.

TITLE 4

OPERATION OF LOAD-FREQUENCY CONTROL

Article 152

All TSOs of each synchronous area shall specify a real-time data exchange in accordance with Article 42 which shall include:

(a) the system state of the transmission system in accordance with Article 18; and

(b) the real-time measurement data of the FRCE of the LFC blocks and LFC areas of the synchronous area.

The LFC block monitor shall be responsible for identifying any violation of the limits in paragraphs 12 and 13 and:

(a) shall inform the other TSOs of the LFC block; and

(b) together with the TSOs of the LFC block shall implement coordinated actions to reduce the FRCE which shall be specified in the LFC block operational agreement.

TITLE 5

FREQUENCY CONTAINMENT RESERVES

Article 153

FCR dimensioning

All TSOs of each synchronous area shall specify dimensioning rules in the synchronous area operational agreement in accordance with the following criteria:

(a) the reserve capacity for FCR required for the synchronous area shall cover at least the reference incident and, for the CE and Nordic synchronous areas, the results of the probabilistic dimensioning approach for FCR carried out pursuant to point (c);

(b) the size of the reference incident shall be determined in accordance with the following conditions: (i) for the CE synchronous area, the reference incident shall be 3 000 MW in positive direction and 3 000 MW in negative direction; (ii) for the GB, IE/NI, and Nordic synchronous areas, the reference incident shall be the largest imbalance that may result from an instantaneous change of active power such as that of a single power generating module, single demand facility, or single HVDC interconnector or from a tripping of an AC line, or it shall be the maximum instantaneous loss of active power consumption due to the tripping of one or two connection points. The reference incident shall be determined separately for positive and negative direction;

(c) for the CE and Nordic synchronous areas, all TSOs of the synchronous area shall have the right to define a probabilistic dimensioning approach for FCR taking into account the pattern of load, generation and inertia, including synthetic inertia as well as the available means to deploy minimum inertia in real-time in accordance with the methodology referred to in Article 39, with the aim of reducing the probability of insufficient FCR to below or equal to once in 20 years; and

(d) the shares of the reserve capacity on FCR required for each TSO as initial FCR obligation shall be based on the sum of the net generation and consumption of its control area divided by the sum of net generation and consumption of the synchronous area over a period of 1 year.

Article 154

FCR technical minimum requirements

Each TSO of the CE synchronous area shall ensure that the combined reaction of FCR of a LFC area comply with the following requirements:

(a) the activation of FCR shall not be artificially delayed and begin as soon as possible after a frequency deviation;

(b) in case of a frequency deviation equal to or larger than 200 mHz, at least 50 % of the full FCR capacity shall be delivered at the latest after 15 seconds;

(c) in case of a frequency deviation equal to or larger than 200 mHz, 100 % of the full FCR capacity shall be delivered at the latest after 30 seconds;

(d) in case of a frequency deviation equal to or larger than 200 mHz, the activation of the full FCR capacity shall rise at least linearly from 15 to 30 seconds; and

(e) in case of a frequency deviation smaller than 200 mHz the related activated FCR capacity shall be at least proportional with the same time behaviour referred to in points (a) to (d).

Each reserve connecting TSO shall monitor its contribution to the FCP and its FCR activation with respect to its FCR obligation, including FCR providing units and FCR providing groups. Each FCR provider shall make available to the reserve connecting TSO, for each of its FCR providing units and FCR providing groups, at least the following information:

(a) time-stamped status indicating if FCR is on or off;

(b) time-stamped active power data needed to verify FCR activation, including time-stamped instantaneous active power;

(c) droop of the governor for type C and type D power generating modules as defined in Article 5 of Regulation (EU) 2016/631 acting as FCR providing units, or its equivalent parameter for FCR providing groups consisting of type A and/or type B power generating modules as defined in Article 5 of Regulation (EU) 2016/631, and/or demand units with demand response active power control as defined in Article 28 of Regulation (EU) 2016/1388.

Article 155

FCR prequalification process

The qualification of FCR providing units or FCR providing groups shall be re-assessed:

(a) at least once every 5 years;

(b) in case the technical or availability requirements or the equipment have changed; and

Article 156

FCR provision

All TSOs of a synchronous area shall determine, at least on an annual basis, the size of the K-factor of the synchronous area, taking into account at least the following factors:

(a) the reserve capacity on FCR divided by the maximum steady-state frequency deviation;

(b) the auto-control of generation;

(c) the self-regulation of load, taking into account the contribution in accordance with Articles 27 and 28 of Regulation (EU) 2016/1388;

(d) the frequency response of HVDC interconnectors referred to in Article 172; and

(e) the LFSM and FSM activation in accordance with Articles 13 and 15 of Regulation (EU) 2016/631.

All TSOs of a synchronous area consisting of more than one LFC area shall, in the synchronous area operational agreement, determine the shares of the K-factor for each LFC area, which shall be based on at least:

(a) the initial FCR obligations;

(b) auto-control of generation;

(d) frequency coupling via HVDC between synchronous areas;

(e) exchange of FCR.

Each TSO shall ensure, or shall require its FCR providers to ensure that the loss of a FCR providing unit does not endanger the operational security by:

(a) limiting the share of the FCR provided per FCR providing unit to 5 % of the reserve capacity of FCR required for each of the whole CE and Nordic synchronous areas;

(b) excluding the FCR provided by the unit defining the reference incident of the synchronous area from the dimensioning process for GB, IE/NI and Nordic synchronous areas; and

(c) replacing the FCR which is made unavailable due to a forced outage or the unavailability of an FCR providing unit or FCR providing group as soon as technically possible and in accordance with the conditions that shall be defined by the reserve connecting TSO.

By 6 months after entry into force of this regulation, the TSOs of the CE and Nordic synchronous areas shall propose assumptions and methodology for a cost-benefit analysis to be conducted, in order to assess the time period required for FCR providing units or groups with limited energy reservoirs to remain available during alert state. By 12 months after approval of the assumptions and methodology by all regulatory authorities of the concerned region, the TSOs of the CE and Nordic synchronous areas shall submit the results of their cost-benefit analysis to the concerned regulatory authorities, suggesting a time period which shall not be greater than 30 or smaller than 15 minutes. The cost-benefit analysis shall take into account at least:

(a) experiences gathered with different timeframes and shares of emerging technologies in different LFC blocks;

(b) the impact of a defined time period on the total cost of FCR reserves in the synchronous area;

(c) the impact of a defined time period on system stability risks, in particular through prolonged or repeated frequency events;

(d) the impact on system stability risks and total cost of FCR in case of increasing total volume of FCR;

(e) the impact of technological developments on costs of availability periods for FCR from its FCR providing units or groups with limited energy reservoirs.

A FCR provider using FCR providing units or FCR providing group with an energy reservoir that limits their capability to provide FCR shall ensure the recovery of the energy reservoirs in the positive or negative directions in accordance with the following criteria:

(a) for the GB and IE/NI synchronous areas, the FCR provider shall use the methods specified in the synchronous area operational agreement;

(b) for the CE and Nordic synchronous areas, the FCR provider shall ensure the recovery of the energy reservoirs as soon as possible, within 2 hours after the end of the alert state.

TITLE 6

FREQUENCY RESTORATION RESERVES

Article 157

FRR dimensioning

The FRR dimensioning rules shall include at least the following:

(a) all TSOs of a LFC block in the CE and Nordic synchronous areas shall determine the required reserve capacity of FRR of the LFC block based on consecutive historical records comprising at least the historical LFC block imbalance values. The sampling of those historical records shall cover at least the time to restore frequency. The time period considered for those records shall be representative and include at least one full year period ending not earlier than 6 months before the calculation date;

(b) all TSOs of a LFC block in the CE and Nordic synchronous areas shall determine the reserve capacity on FRR of the LFC block sufficient to respect the current FRCE target parameters in Article 128 for the time period referred to in point (a) based at least on a probabilistic methodology. In using that probabilistic methodology, the TSOs shall take into account the restrictions defined in the agreements for the sharing or exchange of reserves due to possible violations of operational security and the FRR availability requirements. All TSOs of a LFC block shall take into account any expected significant changes to the distribution of LFC block imbalances or take into account other relevant influencing factors relative to the time period considered;

(c) all TSOs of a LFC block shall determine the ratio of automatic FRR, manual FRR, the automatic FRR full activation time and manual FRR full activation time in order to comply with the requirement of paragraph (b). For that purpose, the automatic FRR full activation time of a LFC block and the manual FRR full activation time of the LFC block shall not be more than the time to restore frequency;

(d) the TSOs of a LFC block shall determine the size of the reference incident which shall be the largest imbalance that may result from an instantaneous change of active power of a single power generating module, single demand facility, or single HVDC interconnector or from a tripping of an AC line within the LFC block;

(e) all TSOs of a LFC block shall determine the positive reserve capacity on FRR, which shall not be less than the positive dimensioning incident of the LFC block;

(f) all TSOs of a LFC block shall determine the negative reserve capacity on FRR, which shall not be less than the negative dimensioning incident of the LFC block;

(g) all TSOs of a LFC block shall determine the reserve capacity on FRR of a LFC block, any possible geographical limitations for its distribution within the LFC block and any possible geographical limitations for any exchange of reserves or sharing of reserves with other LFC blocks to comply with the operational security limits;

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