Ancillary Services in Spain

42 Pages·2010·2.71 MB·English

Ancillary Services in Spain:
dealing with High Penetration of
RES
Ignacio de la Fuente
Brief review of Spanish Ancillary services scheme
Renewable energy in Spain today
Challenges integrating renewable energy nowadays
Wind forecast and use in reserve calculation
Influence of wind power on balancing reserves
Real time actions to restore system reserves
Control centre for renewable energies (CECRE)
Challenges integrating renewable energy for tomorrow
Conclusions
2
General scheme of the electricity market
Producers Producers under Seller Traders
Seller Traders
(Ordinary Regime) Special Regime authorized for CB Trade
FORWARD BILATERAL
DAY-AHEAD & INTRA-
MARKET(OMIP, VPPs, CONTRACTS (OTCs &
DAY MARKET (OMEL)
CESUR) OTROS)
Electric System management
Interconnection Capacity Auctions
Ancillary Services Markets(REE)
(REE, RTE)
Last Resort Retailer Buyer Traders
Direct Consumers Buyer traders
(CUR) authorized for CB Trade
Consumers with last
3
resort rate (TUR) Legend: Market Players
System balancing services
Type Definition
Action of speed regulators from
Primary generator units responding to changes in
Regulation system frequency (<30 s to 15
minutes)
Automatic and hierarchical control that
faces changes in system frequency and
Secondary
power deviations with respect to France-
Regulation
Spain exchange program. (≤100 s to 15
minutes)
Manual power variation with respect to
Tertiary a previous program in less than 15
Manual power variation with respect to a previous program in
Tertiary Regulation
Regulation minluestse thsa.n 1 5 m i n u t e s . ( < 1 5 (m<in1 t5o 2m hoiunrs )to 2
hours)
Manageable generation reserves that can be called upon within
1R5 uminnunteins tgo arpepsroexrimvaetesly o 2 fh ocuorsn. Inncelucdtee tedrt itahrye rersmervaels
Running Reserves or Hot
Slow reserve and consist on the running reserves of connected thermal units
Reserves units (30 min. to 4-5 hours)
and hydro and hydro pump storage reserves. (15 min-2 hours
to 4 hours) 4
Generation Scheduling (I)
Time interval for process performance Time horizon for schedules associated with each process
Day D-1 Day D
1 2 3 4 5 6 8 9 10 11 12 13 14 15 16 17 18 19 20 2122 23 24 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 2122 23 24
WHOLESALE ENERGY MARKET OPERATOR
Daily Market
Intraday 1
Intraday 2
Intraday 3
Intraday 4
Intraday 5
Intraday 6
RED ELÉCTRICA DE ESPAÑA, AS SYSTEM OPERATOR
Previous information published by REE
Day-Ahead capacity auction Spain-France
Day-ahead energy schedules sent to REE
Build up of base energy program
Specific constraint bids sent to REE
Day-Ahead constraints solving process
Secondary reserve market
Intraday capacity auction (I) S-F (REE)
Forecasted deviations management
process
Tertiary reserve usage
Real Time constraints solving process
Intraday capacity auction (II) S-F (REE) 5
1 2 3 4 5 6 8 9 10 11 12 13 14 15 16 17 18 19 20 2122 23 24 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 2122 23 24
Generation Scheduling (II)
Market Operator System Operator
< 9.00 h
Information previous DM
PBC
< 11.00 h
Day-Ahead Market
Schedule Nominations < 12.00 h PBF
Solving technical
14.00 h
PVP
constraints (DM)
16.00 h
Secondary regulation
18.30 h
Intraday Market:
…
Sessions 1 a 6
Solving technical
19.20 h PHF
constraints (IM)
…
Deviation management 21.00 h
…
15 min
Tertiary Reserve
before h
Solving technical T. real P48
constraints (REAL TIME)
6
Primary Regulation
Objective: Providers:
(cid:1) Maintain the frequency system stability (cid:1) Generation units: Mandatory and non-paid
service
Ancillary service provided by the automatic modification of the power generated: Generation unit
speed regulators facing frequency system deviations.
(cid:1) Load variation: 1,5% of the nominal power
(cid:1)t ≤ 15 sec. with frequency deviations ≤ 100 mHz
(cid:1)Lineal variation 15 ≤ t ≤ 30 sec. with frequency deviations between 100 y 200 mHz
Requirements
(cid:1) Established by UCTE rules
7
Secondary Regulation
General Provider remuneration and overcost
(cid:2) Bids:
(cid:2) Service remuneration prices:
• Licensed generation units: Power band to be
• Power band: Hourly marginal price
increased and reduced (MW) and power band
price (/€MW) • Penalty / Bonus depending on real time fulfilment
(cid:2) Reserve allocation: • Used energy: Marginalprice for tertiary regulation that
would have been necessary to use instead (using
• Economic merit order
tertiary bid ladder)
(cid:2) Operation:
(cid:2) Overcosts:
• The regulation deviation is measured by the
• Power band cost paid by demand proportionally to
TSO Regulation Master and the requirement
metered energy (except pumping consumption and
for each Regulation Area is distributed (every
exports)
4 sec.) according to the reserve allocation
• Energy over-cost paid by generation and demand units
(cid:2) Service fulfilment control by Regulation Area
which deviate from their programmes
Process
Reserve allocation
Marginal Band Price
SecondaryBids
(MW)
/€MW
PVP Allocation PVD Secondary bids
Marginal
Band Price
Requirements
Relation up/down Requirement MW
reserve Hour H 8
Tertiary Regulation:
Face unforeseen deviations and short term foreseen deviations
General Provider remuneraion and overcost
(cid:2) Bids: (cid:2) Service remuneration price:
• Obligation to offer available power • Marginal price of allocated bids each hour
• Bids are sent at 23:00 the day before and can be
updated till 25 min before the beginning of the
hour (cid:2) Overcost:
(cid:2) Allocation: • Service overcost paid by generation and demand units
which deviate from their programmes
• Economic merit order. Constraints must not
happen
• 15 min before the beginning of the programming
hour and, if necessary in the programming hour
Process Tertiary Allocation
Tertiary Bids /€MWh
Secondary Tertiary bids
Marginal Price
Allocation
PHF PHO
real time
Tertiary
Marginal
Price
Requirements Used Secondary
Energy
Tertiary allocations MWh 9
Hour H
Deviation management:
Face foreseen deviations maintained during several hours
General
Provider retribution and over cost
(cid:2) Process subsequent to the intraday market sessions
to balance big differences (> 300 MWh) between
scheduled generation and forecasted demand (cid:2) Service remuneration:
(cid:2) Foreseen deviations: unavailabilities or justified
• Hourly Marginal Price
changes communicated from generation
(cid:2) It covers the period between Intraday market
sessions (cid:2) Overcost :
(cid:2) Offers: Optional to Generation and pumping units • Paid by generation and demand units which deviate from
authorized their programmes
(cid:2) Allocation:
• Economic merit order
Process
Deviation Management allocation
Deviation DEVIATION MANAGEMENT
MARGINAL PRICE
management bids
/€MWh
PHF Allocation PHO Dev. Manag. Bids
Deviation
Management
Marginal
Price
Requirement > 300 MWh
Requirement MWh 10
Hour H