Elia Group SA/NV · EURONEXT:ELI
Elia Group SA/NV — Investor Presentation (March 2019)
23 slides from Elia Group SA/NV's investor presentation, Mar 12, 2019
Slide 1: Elia users group, WG SO EMD
Elia users group, WG SO EMD 12/03/2019
Slide 2: Agenda
1. Process overview and timeline 2. Feedback on NCER documents submitted in dec18 3. Communication requirements imposed by NCER 4. Test plan pursuant NCER 5. Risk Preparedness Regulation NC Emergency and Restoration 2
Slide 3: 1. Process overview and timeline
1. Process overview and timeline Entsoe stakeholder workshop NCER 5/7/2019 proposal for a WGSO 6/18/2019 Submission of test RSC consistency assesment proposal for a WGSO plan 7/1/2019 9/24/2019 12/18/2019 2019 Mar Apr May Jun Jul Aug Sep Oct Nov Dec 2019 Today Approval period of NCER documents 3/12/
Slide 4: 2. Feedback on NCER documents submitted in December 2018
2. Feedback on NCER documents submitted in December 2018 Elia sends SDP(v2) and RP(v1) to UG 11/16/2018 New Belgian legislation modifying FTR (approval competences) 12/17/2018 Comments Febeliec on SDP(v1) 11/12/2018 2018 Sep Oct Nov Dec 2019 Feb Mar 2019 Today 12/18/2018 Elia sends SDP and RP to min
Slide 5: 2a. Modifications SDP
2a. Modifications SDP • Legal framework according to new legislation published on 17/12/2018 changing art 312 and art 314 • High priority SGU and T&C for disconnection and re-energization: in line with FTR “priority grid connections” • Auxiliaries of nuclear power plants and important Fluxys sites h
Slide 6: 2b. Modifications market rules: full black-out in Belgium
2b. Modifications market rules General principles: full black-out in Belgium Central dispatch* Day D-1 Day D Day D+1 Day D+2 BRP responsible Notification “market suspension ON” Stop publication of imbalance prices BRP responsible Stop ID market Cancel nominations * ”TSO Controlled Dispatch” is used
Slide 7: General principles: technical
General principles: technical Central dispatch Day D-1 Day D Day D+1 Day D+2 Restoration activities by ELIA : Connect generation units ~ & connect load
Slide 8: General principles: market aspects
Notification “market restoration” General principles: market aspects Opening order books on hour H1 Closing order books on hour H2 Central dispatch Day Ahead market coupling results for Day D+2 + Reserves + schedules Day D-1 Day D Day D+1 Day D+2 NO Day Ahead Market Notification “market suspension O
Slide 9: General principles: restoration
General principles: restoration Central dispatch Start publication of imbalance prices Start ID market Day D-1 Day D Day D+1 Day D+2 Decision by Elia (in collaboration with the different stakeholders) BRP responsible + communication to BRP responsible all 6h Continuous Communication via website or o
Slide 10: During Central Dispatch, Elia decides upon
During Central Dispatch, Elia decides upon : Elia customer DSO customer 100 MW CIPU BRP2 Non-CIPU ~ 100 BRP1 MW - No imbalance settlement as in normal situation - Settlement of delivered energy : - should be financially neutral and an easy process, use existing contractual relationships - At which p
Slide 11: Submitted proposal
Submitted proposal TSO X €/MWh DSO ~ ~ BRP 1 X €/MWh BRP 2 BRP 3 PGM with power PGM without power scheduling obligation scheduling obligation AMR SLP BRP 4 BRP 1 Y €/MWh or X €/MWh if no X €/MWh Y exists Possibility to allocate volumes within Atrias processes X = restoration tariff = a ToE-like pric
Slide 12: Restoration tariff X
Restoration tariff X This restoration tariff is calculated ex-ante for each hour of the day by means of this formula : 73 % * 1/3 (Cal Y+2 + Cal Y+1 + M+1) + 27 % * AVG (EPEX spot BE DAM) Where CAL Y + 2 = the average of the daily quotations for the baseload product published by ICE INDEX two years
Slide 13: Automatic or Manual load shedding
Automatic or Manual load shedding Proposal - E&R Art 39.1 : “By 18 December 2018, each TSO shall develop a proposal for rules for imbalance settlement and settlement of balancing capacity and balancing energy which shall be applicable for imbalance settlement periods during which the market activiti
Slide 14: 3. Communication requirements imposed by the NCER
3. Communication requirements imposed by the NCER 5 notifications related to the system states and the market activities status will be sent to stakeholders System states The system is in the Emergency state and one of several measures of the System Defence Plan have been Emergency Elia activated Ac
Slide 15: 4 communication channels will be used: Scada, mail, sms, website
4 communication channels will be used : Scada, mail, sms, website • Sending notifications via Scada-to-scada with the TASE2 protocol is the most reliable way to notify stakeholders as it remains effective even in case of Blackout • Other communication channels are required as not all stakeholders ha
Slide 16: Actions are requested from the stakeholders to allow the notification reception
Actions are requested from the stakeholders to allow the notification reception • Elia is responsible to send the information but actions are requested from the stakeholders to receive the information. The requested actions depends on the communication channels used. Communication channel Requested
Slide 17: Communication systems NCER Art 41
Communication systems NCER Art 41 Optic fiber connection between SGU and Elia Elia substation Bom project 8 24h 24h Each TSO, DSO, SGU identified ~art 23(4), and RSP shall have a voice communication system implemented with sufficient equipment redundancy in case of failure of any individual communi
Slide 18: Communication systems NCER Art 41 planning
Communication systems NCER Art 41 Planning: 1. Identification of existing Elia phones at SGU locations ongoing 2. Bilateral investigation between Elia and SGU to check if Elia phones are on appropriate location and that competent personnel can answer Elia’s call in emergency situations 3. Identifica
Slide 19: 4. Test plan
4. Test plan • A test plan has to be defined by 18/12/2019 pursuant to NCER • Elia should develop a test plan in accordance to NCER art 43 to 49 to assess the proper functioning of all equipment and capabilities considered in the System Defence Plan and Restoration Plan • The test plan should be def
Slide 20: Tests for PGMs, providers of demand side response and HVDC
Tests for PGMs, providers of demand side response and HVDC should follow specific methodologies Equipment Capability Methodology Frequency Black start Article 45(5) of RfG At least every 3 years Household Article 45(6) of RfG After any change of equipment having PGM an impact on its household capabi
Slide 21: Guidelines for the test plan are being developed within ENTSO-E
Guidelines for the test plan are being developed within ENTSO-E Equipment Capability Frequency Communication System At least every year Testing of communication systems of DSO and SGUs identified in the RP, TSOs and RSP Backup power of communication system At least every 5 year Main and backup power
Slide 22: 5. Risk Preparedness Regulation
5. Risk Preparedness Regulation NC Emergency and Restoration 22
Slide 23: Risk Preparedness Regulation – Provisional timelines
Risk Preparedness Regulation – Provisional timelines (*) Consultation on methodologies Consultation on RPPs • To ensure a common approach to crisis prevention and management, each MS should draw up a risk-preparedness plan based on the regional and national electricity crisis scenarios identified. •