All users of an electrical power system expect that the frequency and voltages are maintained within acceptable boundaries at all times. Some participants, mainly generating units, provide the necessary frequency and voltage control services, called ancillary services. Since these participants are entitled to receive a payment for the services provided, markets for ancillary services have been developed along with the liberalisation of electricity markets. However, current arrangements vary widely from a power system to another.
This thesis provides a comprehensive assessment of markets for frequency and voltage control ancillary services along three axes: (a) defining the needs for frequency and voltages, as well as specifying the ancillary services that can fulfil these needs; (b) assessing the cost of ancillary services for a producer; and (c) discussing the market design of an efficient procurement of ancillary services.
Such a comprehensive assessment exhibits several advantages: (a) stakeholders can quickly grasp the issues related to ancillary services; (b) participants benefit from a standardised method to assess their system; (c) solutions are proposed to improve current arrangements; and (d) theoretical limitations that need future work are identified.
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Assessment of Markets for Frequency and Voltage Control Ancillary Services
1. Assessment of
Markets for
Frequency and
Voltage Control
Ancillary Services
Leonardo Energy webinar
2 October 2009
Yann Rebours
EDF R&D
yann.rebours@ieee.org
2. Introduction
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3. Why controlling frequency and voltages?
All power system stakeholders need f and U within boundaries for:
Security of supply (e.g., by avoiding load shedding)
Behaviour and efficiency of equipments (e.g., by avoiding vibrations, overheating,
flickers…)
Security of equipments (e.g., by avoiding over-voltages or over-speeds)
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4. Frequency example
Lost of a nuclear unit (1300 MW) within the UCTE system
(disturbance from normal operation)
50 mHz
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5. Fundamentals of frequency control (f/P)
Pmax
Lmax
PL PP
50 Hz
0 49 Hz 51 Hz 0
Consumers Producers
f
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6. Voltage example
Voltage map in French Guyana
Malouin Suzini
ELA-CSG
93,9 kV 91,7 kV 91,8 kV
St Laurent
Kourou
94,6 kV 91,9 kV 92 kV
93,5 kV
93,3 kV
Etoile
Piquage
Balata Dégrad des Canes
TDF
95,5 kV
93,5 kV
Petit Saut
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7. Fundamentals of voltage control (U/Q)
voltage
U
distance
Q1 Q2 Q3 Q4
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8. Who can provide f / U control services?
Generating units
Loads
Network assets:
Lines
Transformers, …
Purpose-built devices:
Capacitor bank
FACTS
Synchronous compensator
Inertia wheel, …
These controls are called
ancillary services
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9. System services vs ancillary services
Power system
(e.g., real-time Ancillary services System services (e.g., f and U
adaptation of P AS SS within
and Q) (private goods) (public goods) boundaries)
Some users The other users
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10. Rationale for the thesis
Final goal: improve efficiency & maximise global welfare
Formulate and structure the AS issue from a global point of view
(3 axes)
Illustrate the theory by comparing systems
Increase knowledge relative to AS cost (de-optimisation cost)
Give the tools to improve current systems (e.g., give methods and
checklists)
Feed in the research: propose future work
This presentation : only an overview
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11. Summary
1. Introduction
2. Delivery of ancillary services
3. Cost of ancillary services
4. Procurement
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12. Delivery of ancillary
services
1. Quality
2. Quantity
3. Location
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13. 1. Specify the quality of AS
A perfect specification does not exist
Four definition levels are possible:
Elementary General
Functional
Practical
Standardized Precise
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14. 1. Functional definition
TSO Producer primary
f/P
Signal
secondary f/P P
Instructions
tertiary f/P operator
TSO Producer
Signal primary
secondary U/Q Q
U/Q
tertiary U/Q
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15. 1. Survey with the functional definition
Help for a common vocabulary
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16. 1. Practical definition
AS are technical products: they need more specs than energy only
The identification of the important parameters allows an inter-
system comparison
In Europe, standardisation is necessary (same recommendation
but different applications)
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17. 1. Standardised definition
Helps a practical and universal definition:
Does not rely on the input signal
Take into account dynamics
Does not depend on the type of provider (e.g. load or generating unit)
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18. 2. Define the quantity of AS
SS are a public good only the TSO can define the needs
A cost / benefit approach should be preferred
But difficult to estimate the value
because SS have a triple objective:
Security (e.g., avoid blackouts)
Quality (e.g., avoid over-voltages)
System utilisation (e.g., reduce losses)
In practice:
Inelastic demand
Minimizing provision cost (rational buyer)
Research:
Generally focused on VOLL
But VOLL does not consider quality + system utilisation
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19. 2. AS quantities in practice
Indicators have been proposed to compare systems
Give incentives to improve practices
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20. 2. Instantaneous frequency characteristic
Quality + quantity = frequency characteristic
Proposed
definition
Current
definition
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21. 3. Define the location of AS
Location is important because:
Congestions can make impossible AS delivery
An uniform distribution is desirable (in case of network islanding)
Regulation at the transmission level is more critical (meshed network)
For an optimal repartition:
Incentives to develop AS at the appropriate locations
Exchange systems to allow short term arbitrage between areas
Coordination at the owner boundaries (e.g., between distribution and transmission)
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22. Cost of ancillary
services
1. Cost components of ancillary services
2. Method to estimate the de-optimisation cost
3. Results on EDF Producer’s portfolio
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23. 1. Main cost components for a producer
Fixed costs
Investments in extra generating capacities
Workforce
Capacity reservation cost
De-optimisation
Opportunity cost
Utilisation cost
More fuel is used
Increased wear-and-tear
Very difficult to calculate precisely the AS cost
Many components
Interdependent time horizons
Hard to separate energy-only and AS costs
Costs very different from one country to another (energy-mix dependent)
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24. 2. Method to estimate the de-optimisation cost
Proposed method: easy & standard
Applied to EDF Producer over 879 days with operational data &
algorithm (from 09/2004 to 08/2007)
De-optimisation cost = CostD-1 dispatch with reserves
– CostD-1 dispatch without reserves
energy for loads
frequency control
G1 G2 G1 G2 G3 non-used capacity
without reserves with reserves
(cheaper dispatch) (more expensive dispatch)
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25. 2. The method in practice
1. APOGEE dataset with 2. APOGEE dataset with
OTESS initial constraints reserve demand = 0 MW
APOGEE
(EDF’s short-term dispatch
algorithm)
APOGEE dispatching 1 APOGEE dispatching 2
Other data for
correlation
OTESS Database
(Data management tool
developed during the thesis)
Web-based
interface
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26. 2. Advantages and limits of the method for EDF
Advantages of our study vs previous literature:
APOGEE takes into account many constraints (dynamics, hydro,
thermal…)
Actual day-ahead operational data as input
However, some limits in our study:
If hydro energy is provided, reserve is provided as well (historical constraint)
Water saving was not taken into account (days are considered as independent)
The precise management of hydro valleys was not considered
(only a global constraint for each reservoir)
Obviously, manual day-ahead re-dispatch is not modelled
Only short-term variable costs are considered
Therefore, the method gives a minimum cost (real cost is higher)
Further studies will be completed in 2009 to remove some limits
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27. 3. Results: the cost is not negligible
Up to 7,8 % of the dispatching cost
Therefore:
The reserve should be remunerated in order to avoid distortion of energy prices
An efficient procurement is essential
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28. 3. The de-optimisation cost is variable
During 54 % of the time, the cost changed by more than 20 %
from one day to the following
Allowing short-term arbitrage is thus essential
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29. 3. The cost is not seasonal
Low values from the PACF
It is difficult to apply the results over one period to another
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30. 4. Synchronous time control costs money
Because of time control, the reserve was modified by the French
TSO up to January 2009 (±150 MW)
This policy cost millions of euros/year in de-optimisation
Does the value of time control justify its cost? [Rebours et al (2009)]
ftarget = 50.01 Hz (27 days over 01/2005 - 07/2007) ftarget = 49.99 Hz (175 days over 01/2005 - 07/2007)
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31. Procurement of
ancillary services
1. Responsible entity for procurement
2. Matching supply and demand
3. Procurement methods
4. Structure of remuneration
5. Market clearing
6. Price caps
7. Give appropriate incentives
8. Metrics for market evaluation
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32. Eight fundamental features
Why a market is necessary?
AS are externalities (e.g., energy, transmission)
Cost is non negligible
So what design?
The thesis highlights eight fundamental features
Market designers (legislator, regulator, TSO…) should explain the
current choices regarding these features
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33. 1. Responsible entity for procurement
Only the TSO should be the responsible entity for procurement:
Knows the value of AS
Has enough incentive to optimize its demand
No barrier for new entrants
But :
Cost recovery problem
TSO is both consumer and provider of system services
Not necessarily enough incentives to optimize the procurement
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34. 2. Matching supply and demand
Over the long run:
Connecting conditions: not optimal, but it works
However, it is still linked to the security of supply issue (enough generating units)
How can we optimize this demand over the long run?
Over the short run:
An elastic demand is necessary
Incitation for participants to propose their capacities (e.g., with an attractive price)
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35. 3. Procurement methods
Use several methods in parallel is necessary
Trend: f/P: competition – U/Q: regulated
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36. 4. Structure of remuneration
Depends on the services because cost structures are different
An asymmetric remuneration is preferable (upward price ≠ downward price)
But if too complex, scoring can be difficult
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37. 5. Market clearing
Structure
Centralised (pool) or decentralised (exchange)?
Bidding
Sealed-bid first-price auction desirable, but under perfect competition assumption
Scoring
Difficult because multi-dimensional
Time coordination
Common clearing for energy / transmission / AS is essential
But difficult in a decentralised structure
Settlement
Always in debate: zonal or nodal?
Uniform or differentiated?
Clearing frequency
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38. 6. Price caps
Avoid price caps as much as possible
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39. 7. Give appropriate incentives
For cost allocation, the best:
Fixed cost: shared by all users (transmission tariff)
Reservation cost: based on the potential utilisation of users
Utilisation cost: “polluter” pays
Data transparency (e.g., how is the demand computed?)
Control of performance and behaviours. Give incentives to auto-
control
Penalties and rewards
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40. 8. Metrics for market evaluation
Effective: are there enough SS?
Low cost to run the AS market
Economic efficiency. One indicator:
Data for 2004-5
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41. Conclusions
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42. The thesis in a nutshell
Needs for SS = quality / quantity / location
The thesis surveys various systems + proposes how to better specify
the needs for SS
Cost of AS = fixed / capacity reservation / utilisation
The thesis improves the knowledge on the de-optimisation cost by
proposing a standardized method + applying it on EDF’s portfolio
Market design = entity responsible / supply-demand / procurement
method / structure of payment / clearing / price cap / incentives /
assessing method
The thesis identifies, describes and analyses these features +
illustrates with examples + suggests some ways of improvements
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43. Suggestions for future work
Regularly assess systems with the proposed framework
Draw the limit between negotiable and non-negotiable products
(why stability is not remunerated?)
Deepen the understanding of costs (AS cost + market cost)
Improve market design (e.g., long-term incentives, demand
elasticity, better allocation of costs, better data transmission…)
Facilitate the exchanges between areas:
Standardise products
Standardise markets
Co-ordinate energy / interconnections / AS
Develop alternative AS suppliers (e.g. loads, wind power…)
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44. For further reading…
Technique:
"A Survey of Frequency and Voltage Control Ancillary Services—Part I: Technical Features", IEEE
Transactions on Power Systems, vol. 22 (1), pp. 350-357, February 2007.
Y. Rebours, J. Pestourie, and E. Monnot, "Five Good Reasons to Abandon Synchronous Time
Control", presented at the IEEE Powertech, Bucharest, Romania, 2009.
Market design:
"A Survey of Frequency and Voltage Control Ancillary Services—Part II: Economic Features", IEEE
Transactions on Power Systems, vol. 22 (1), pp. 358-366, February 2007.
"Fundamental design issues in markets for ancillary services", The Electricity Journal, vol. 20 (6), pp.
26-34, July 2007.
Thesis:
Y. Rebours, "A Comprehensive Assessment of Markets for Frequency and Voltage Control Ancillary
Services", PhD Thesis, Faculty of Engineering and Physical Sciences, The University of Manchester,
Manchester, U.K., 2008. Available:
http://www.eee.manchester.ac.uk/research/groups/eeps/publications/reportstheses/aoe/rebours_PhD
_2008.pdf
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45. Acknowledgments
Many thanks to all my colleagues who help me during this thesis
Special thanks to:
Daniel Kirschen who supervised this thesis
and Bruno Prestat who provided some slides presented here
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