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A changing context…
3
Energy system is changing rapidly and need for flexibility is urging!
New players active in the market facilitating DSR: aggregators
Suppliers offering price and/or volume flex to their larger customers (dynamic supply contracts)
ELIA addresses this need by conceiving specific products in close cooperation with stakeholders (RES,
generators, consumers, DSOs, regulators and aggregators)
Demand Side Response and Demand Side Management are important tools
for ELIA & DSOs in managing the system security (residual balancing & congestion)
for BRPs in self-balancing.
With development of flexibility, existing market models and processes are impacted !
Source: EG3 REPORT SMART GRID TASK FORCE
DSR products
Febeliec, 15/6/2015 - Hans Vandenbroucke
Overview current load products @ELIA
4
Product Type Correction Sourcing Payment Availability Provider
R1 load(FCR)
linear decrease of offtake when the frequency is between 49,9-
49,8Hz
NO Monthly
Reservationprice,
no activationremuneration
100% qhavailaibility
+ continuouslyautomatic activation
large Industrial TSO gridusers (via aggregator)
ICH(mFRR)
DROP TO
Target is fixed = Shedding Limit
YES, using
NominationYearly
Reservationprice +
activationremuneration
100% avgavailability
large Industrial TSO gridusers (via aggregator)
R3DP(mFRR)
DROP BYTarget is
variable = Baseline – fixed
capacity(deltaP)
NO(last qh as reference
value)
YearlyReservation
price, no activationremuneration
100% qhAvailability
industrial T/DSO grid usersand/or emergency
generators (via aggregator)
SDR2015-2016
DROP BY/TO @ELIA
YES, using
Nomination YearlyReservation
price + activation
remuneration
Remuneration based on available capacity
(No obligation to consume nopenalty when
available capacity is <Rref
industrial TSO grid users(via aggregator)
DROP BY only@DSO NO
industrial DSO grid users(via aggregator)
Febeliec, 15/6/2015 - Hans Vandenbroucke
Overview current load products @ELIA (2)
5
Product Activation
parameters
Activation
Price
Volume
2015
Avg Reservation
Price in 2015
R1 load
half of the reserve must be deployed within 15’’
max reaction time for complete activation: 30 ‘’
must be able to be activated minimum 15’
NO
Avg 23MWTotal R1: 83MW
27MW in 2014
4,85€/MW per h
In 2014: 5-6€/MW per h
ICH
within 3’ max duration 2 - 4 - 8 hours max # : 12 - 4 - 4 /year minimum 24hours
between activations
YES261MW
Total R3: 661MW
Idem in 2014
1,41€/MW per h
Idem in 2014
R3DP
within 15’ max duration 2 hours max # : 40 /year minimum 12hours between
activations prequalification process
NO60MW
Total R3: 661MW
50MW in 2014
3,07€/MW per h
3,38€/MW per h in 2014
SDR2015-2016
YES SDR 2014-2015:
~100MW
NA
MW €/MW per h
jan/15 23 5,6
feb/15 21 5,8
mar/15 22 4,93
apr/15 23 4,17
may/15 26 3,79
Febeliec, 15/6/2015 - Hans Vandenbroucke
The different product characteristics are taken into account when defining the constraints R3 portfolio.
R3 Production is available 100% of time and will be used (in combination with R2) to cover
imbalances, especially forced outages of units (loss of max ~440MW)
R3 DP will be used in addition to R3 Prod and R2 to cover most of imbalances due to outages but
also forecasting errors of renewables and load.
ICH will be mainly used to cover imbalances resulting from outages of nuclear units
Inter-TSO will be used as last resort activation in exceptional cases only
All products will be in competition respecting the following constraints:
• Min 300MW R3 Production
• Min 470MW R3 Production + R3 DP (corresponding to max 300MW ICH)
The proposed limits for R3 products allow Elia to ensure a secure operation of the network.
Determination mFRR (R3) portfolio in 2016
6Febeliec, 15/6/2015 - Hans Vandenbroucke
As European trends is to move towards short term sourcing and this could increase liquidity in the
balancing market, the goal is to move to short term sourcing for balancing products in the next
years.
After consultation of the market, Elia will start with partial monthly sourcing in 2016:
Volumes contracted in the yearly tendering = 700MW
Minimum 300MW R3 Prod
Minimum 400MW R3 Prod + R3DP
Volumes contracted in the monthly tendering = 70MW
Full competition between R3 Production and R3 Dynamic Profile
R3 2016: yearly & monthly auctions
7Febeliec, 15/6/2015 - Hans Vandenbroucke
R3DP
- Capping (100MW) removed
- Cap # providers/volume removed
- Submetering (TSO and DSO Delivery Points)
- Binding Bidding Obligations as part of General
Framework Agreement
Evolutions for 2016 : R3DP & ICH
Febeliec, 15/6/2015 - Hans Vandenbroucke 8
ICH:
- Workshop planned on 24/6
- Binding Bidding Obligations as
part of ICH-Contract
Eligibility - SDR: introduction of 3 new „segments“:
• SDR DSO: access points to the distribution grid
• SDR Submetering : delivery point within the installations of GU connected to ELIA grid
• SDR CDS: delivery point within a CDS connected to ELIA grid
Evolution of Certification process for SDR in order to better valorize flexibility:
• Elia calculates the maximum power that can be contracted (Rref, and not anymore the candidate)
• Valorization of “usefull” consumption even when lower than Rref
• Minimum Availability rate reduced from 85% to 80%
Product design
Choice among DROP TO and DROP BY (for SDR DSO only DROP BY)
No correction of BRPs perimeter for 3 new segments
Baseline methodology developed in order to verify the activation
of SDR for 3 new segments (for SDR TSO baseline = Nomination )
Additional limit on the #hours of activations : max 60h per sliding
window of 30 days
Tender Design: Selection of offers
Total Cost (based on reservation & activation prices) will differ depending on final decision on volumes( 30/6)
o 20 activations/130 hours if volume ≥ 1500MW
o 4 activations/13 hours if volume <1500MW
Evolutions for SDR 2015 - 2016
9Febeliec, 15/6/2015 - Hans Vandenbroucke
Challenges ahead…
10Febeliec, 15/6/2015 - Hans Vandenbroucke
Evolution to short term sourcing of reserve products
How to develop effective DSR participation while preserving an efficient market?
Throughout Europe different market models for DSR participation have
emerged, acknowledging the variety in prevailing market design both in
retail and wholesale markets.
However, there is a clear demand from stakeholders to provide a stable
enduring market model.
There is a push by European and national policy makers towards a market
model facilitating DSR-participation.
Elia has already contributed to include direct DSR-participation in its product
portfolio by developing specific products. This has led to a specific
product design build on a consensus with market actors, including CREG.
What are the criteria to participate in the wholesale energy market and what are
the implications for the BRP concept as a whole?
Focus on participation of load via Standard Products but…
ICH/R3DP is not a standard product given limited # activations and avg availability (ICH)
Qualification as a specific product? Strict criteria applicable:
1. only possible for flex that cannot partake to balancing market via normal standard
products
2. CREG needs to assess this on a yearly basis
3. European reporting to regulatory authorities every 2 years on the costs and benefits, and
the possible inefficiencies and distortions of having Specific Products in terms of
competition and market fragmentation
4. By default all specific reserve products should be shared on a Common Merit Order (and
hence can be activated by other TSOs if their activation price is cheaper than other bids)
unless other TSOs of the CoBA agree that these bids can be set a s unavailable for
activation by other TSOs = unshared bids.
Standardization/simplification of ELIA product portfolio
Challenges ahead… (2)
11Febeliec, 15/6/2015 - Hans Vandenbroucke
Network Code on Balancing