elia's stakeholders' day 2013 morning-part1

22/11/2013 Stakeholders' Day

Stakeholders’ Day 2013


Stakeholders’ Day 2013

Axelle Pollet – Barbara VerhaegenCommunication@ELIA

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#skh2013

“square-guest ”Login : eliaPassword : elia13!

Englishtranslation on:

Channel 1


Welcome & Introduction

Frank VandenbergheDirector Energy & System Management ELIA


Specific Product & ServicesinformationJan Van Roost - ELIAHans Vandenbroucke - ELIAValéry Stembert - ELIA


System operations @ the limits ?

Jan Van RoostNational Control Center - ELIA

System operations OVER the limits?

22/11/2013 Stakeholders' Day 7

822/11/2013 Stakeholder‘s Day

Key issue in maximizing SoS is the capability to anticipate

TSO challenge: Security of Supply

Y-2 Y-1System AdequacyForecast,European Outageplanning,Generation planning

W-x D-1Reserve Control,Outage planningreview,Generationconstraints

Real timePlanning

Y-20 Y-2Grid Development

Blackout

Emerg

ency

Secu

re

Alarm

New grid infrastructure (2-10y to be commissioned)Create political consciousness of adequacy issues new power plants (2-10y to be commissioned)

No time to reinforce the infrastructureGeneration & Grid planningMitigation measures

Force starting/stoppingof power plant(s)Cancel grid outage(s)

CongestionMgt,Loadshedding,EuropeanEmergencyprocedures,Emergencyplan,Restorationplan

Lesson’s learned & actions taken


Simulator Training

Coordination Initiatives

Markets: Coupling & Flow Based

Better IT tools: New EMS, forecasting tools, Cybersecurity …

(Grid) Investments remains Key!

Joint operator Training

Operation closer to the limits – stability

Challenges• Dynamic Studies: lead to winter import limits of

3500MW

• Decrease in system inertia; due to imports &renewables: Requires additional challenge & ad-hocdetailed study

• Limit forecast errors: avoid large deviations & reachingsystem limits (i.e 50,2 Hz treshold)

Case: Volatility – case of 28.10.2013


ChallengeToday: 400 MW offshore2020: 2000 MW offshore

> How to handle?

Frequency deviation: coordination & follow up


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Ready for winter / Summer in balance

Ready for winter behind the scenes


Belgian (physical) import:November 1st – end of Jan (max. MW of the day)

• If > 3500 MW: accepted case by case, only after security check byexperts.

• 29 days > 3000 MW import; partly for economic reasons (e.g.19/11/2012 max. 3864 MW).

Incompressibility• Importance of accurate forcasting & nomination• Elia will check for sufficient export capacity• Elia can call for additional D-bids

• Opportunity for Stakeholders:• Any additional flexible bids welcome• Offer downward volume• Use the available export capacity


Elia challenges load forecast:

Tools & Prototypes@ National Control Center

• EAS (Enstoe awareness System)

• Frequency - ACE tool


Closer monitoring @ NCC

1824/09/2013

Emergency monitoring @ NCC

What are solutions? combinations of1. Grid development is KEY

2. Flexible & advanced grid operation

- Controllable devices: PST’s and HVDC

- Dynamic Line Rating (DLR) active network management

3. Participation of Market Players

- Active use of Intraday information- balance portfolio both Up- and Downward- Flow Based

08/10/2013

What can you do ?

• Use of intraday programs: Flexibility & firmness.• Importance of forecasting at market side with focus on limiting

forecast errors• Operators preparedness: know what to do when Elia sends

specific messages: call for bids / shortage / warnings



FlexibilitySurvey on existing & future products

Hans VandenbrouckeEnergy Management – Architecture ELIA

Content• Belgian context for balancing

• In search for flexibility…

• Demand Side Response vs Demand Side Management

• Primary reserve contract for frequency regulation from TSO clients– R1 Load

• Fast interruptible load contract for TSO clients - ICH

• Interruptible load contract for DSO clients – R3 Dynamic Profile

• Free bids via Aggregated Power Plant – APP

• Project Bidladder platform

22/11/2013 ELIA Stakeholders Day 22

Context - Supply of ancillary services Very high level of market concentration in Belgium

- 1 large player owning almost ¾ of production capacity- Only 5 producers able to deliver ancillary services, some of them with single

sites only Limited flexible fossil plants

- 5500MW inflexible Nuclear (biggest 1076 MW)- 3700MW CCGTs but non-spinning for economic reasons Green energy inflexible by subsidy schemes (€/MWh)


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500

1000

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3500

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2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020

Installed capacitywind and PVBelgium [MW]

Wind [MW] Total

Solar [MW] Total

Context - Demand for ancillary services

Monitored Wind Capacity = 1482MWMonitored PV Capacity = 2501MW

Evolution of System Imbalance towardslarger and bigger(positive and negative)imbalances…


Visit our website !

“ Reserves Study 2018: Evolutionof ancillary services needs tobalance the Belgian control areatowards 2018”http://www.elia.be/en/grid-data/balancing/Reserves-Study-2018

In search for flexibility…

R1 loadAPP

Energy system is changing rapidly and need for flexibility is urging!

ELIA addresses this need by conceiving specific products in closecooperation with stakeholders.

Demand Side Response and Demand Side Management are important tools

for ELIA and the DSOs in managing the system security for BRPs in self-balancing.

R3 DP ICH

Bidladder

DSM

DSR


Demand Side Response (DSR):market parties react on price signals Based on an external price signal (Belpex price, imbalance price,…) market parties,

both on TSO and on DSO-level, may choose to consume less curtail load during critical peaks shift consumption self generate

On Jan 1st 2012, ELIA has introduced single marginal imbalance pricing.

Moreover, BRP-contract in 2014 will allow BRPs to deviate in real time from theirbalanced position in order to support the restoration of the system imbalance.


Some owners of decentralizedproduction with pass-throughcontracts deviate in real timefrom their D-1 nominationsin function of imbalanceprices using ELIA website info

Currently +/-300 MW ofdecentralized productionparticipating to DSR.

Demand Side ManagementR1 load: primary reserves through load on TSO grid

Elia developed a combination of asymmetric and symmetric primary reservesproducts in order to allow a demand side participation.Currently Elia has contracted 30,5MW of R1 load.

R1load = tailored to industrial consumers + compliant with Entso-Erequirements Activated for only deviations > 100mHz leads to a limited number of activations per

year = limited impact on the industrial processes. Linear modulation of the off-take on the frequency with a max activation time of

30seconds for the entire volume. Grid users or a pool of grid users (aggregator) connected to the ELIA grid can

participate in the yearly tendering. The supplier receives capacity fee. No remuneration for the activation.


Demand Side Management:Interruptible load on TSO Grid - ICH

Elia has contracted 261MW tertiary reserves via ICH product. This ancillary service is directly provided by industrial consumers with flexible

processes and/or aggregators The impact on the perimeter of the BRP is neutralized by replacing per client the

metering data by the nomination in case of activation.

Highly flexible and fast product Elia activates this reserve by remote control Grid user’s offtake must drop below shedding limit within 3 minutes No notification prior to activation

This product is the most efficient solution to deal with sudden outages of big powerplants: requires limited number of quick reactions per year.

Product is adapted to load constraints: Max 4 activations per year and at least 24 hours

between 2 interruptions Limited total duration of interruption over the

contractual period (16 or 24hrs) Use of a predefined load floor = shedding limit


Demand Side Management:R3 Dynamic Profile (as from 2014)

Elia is procuring currently 10MW of tertiary reserves sourced from large DSOcustomers as a pilot project. Based on this experimentation and supported byCREG, ELIA has contracted for 2014 50MW of R3 Dynamic Profile.

This ancillary service is directly providedby aggregators; aggregation is allowed overdifferent DSOs and different BRPs/supplierscovering both load and generation with 100%availability.

A pragmatic solution was elaborated in close cooperation with stakeholders(Expert WG) avoiding a negative impact on the concerned stakeholders

Further enhancements under analysis, in close cooperation with stakeholders.


Additional complexity when developing aDSO- oriented product as no nominations,what is exact activation split per BRP,impact on supplier,…

As from 2013, ELIA allows BRPs to sign a contract for an “Aggregated PowerPlant” which is constituted by a portfolio of different flexible generation unitsand loads connected to TSO and/or DSO grid that are part of the concernedBRP portfolio.

Elia can activate this extra flexibility in itsdaily balancing activations when available

The provider is remunerated for the activation atthe offered price. These free (negative) pricesallow RES to recuperate their opportunity costsin case of output reduction.

Demand Side Management:Free bids via APP (Aggregated Power Plant)


Bidladder platform= platform where market players can bid in all

available flexibility via explicit portfolio biddingwith locational information.

allow free bids from load and RES flexibility; flexibility connected to the distribution grid.

3 different balancing energy products: Fast Standard product Slow Standard products Emergency products

“block”-products which do not reflectnecessarily the physical constraints ofunderlying resources. Differences between the product and physicalreality need to be considered in the price when bidding to Elia.


Demand Side Management @ ELIAOverview

DSM contracted ProductR1 Load Instant load modulation in case of

large frequency dips (<49,9Hz)ICH Fast decrease of load to a predefined

off-take level, within 3 minsFRR – R3 Dynamic Profile(from 2014)

decrease of load with a predefinedvolume, within 15 mins

Strategic DemandReserves

decrease of load with a predefinedvolume while respecting a longnotification time

30MW

261MW

Max 50MW


DSM free bids ProductCurrently via APP… Up/down wards regulationIn future via Bidladder Block bids of up/downwards regulation,

with possibility of 15 mins delay andmax 45 mins activation duration


Information for grid users

Valéry StembertCustomer Relation ELIAKAM ARP

Specific product and services information



Coffee break

elia's stakeholders' day 2013 morning-part1

Technology