der involvement in distribution network voltage control
TRANSCRIPT
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Flexible Electricity Network to Integrate the eXpected energy evolution 1
DER involvement indistribution network voltage
control
Outil de gestion des DER leurpermettant de participer au
rglage de la tension
Sbastien Grenard
EDF R&D
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Increased deployment of DER expected
Technical issues
DSOs anticipate that they can integrate only a limited
capacity of DER without a major reinforcement.Limiting factors in many European distribution networks: voltage rise
effect
DSOs anticipate that they can integrate only a limited
capacity of DER without a major reinforcement.Limiting factors in many European distribution networks: voltage rise
effect
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The voltage control issue with DER
PGMV
Voltage
Feederlength
Vmax
Vmin
Cos=1
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What are the solutions?
Approach with existing practise (fit and forget)
No control over DER / Worst case scenarios used for connection sizing
Active distribution network: Local and coordinated control of voltage
and flows (VVC: Volt VAr Control function) to: Maintain voltage within limits and Optimise other parameters (Reactive power
transit between DSO and TSO / Distribution network losses / .)
Increase DER hosting capacity
VVC
A
P,-Q
CHPS
P Q
LV
P Q
MV
NOP
MV
LV
LV
PV
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Architecture of control centre tools for an
active network
Distribution
State
Estimation
(DSE)
VVC
Substation local
measurements
Commercial
Aggregator 1
Commercial
Aggregator 2 Network Data,
Pseudo
measurements
Constraints
Contracts
(with TSO)
Capacitor
banks
DER set
points
Transformers
tap changer
HMI
SCADA
Two possibilities of use:
Preventive studies
Real-time decisions
D t A i iti
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Data Acquisition
and
state estimation
P(t)
Q(t)
V(t)
P(t)
Q(t)
V(t)
P(t)
Q(t)V(t)
P(t)
Q(t)
V(t)
- Use of Fenix Boxesfor metering
- Retrieval of data
by commercialaggregator SCADA
- DER outputs sent to
DSO SCADA
- Distribution State
Estimation (DSE)
Remote metering CHP_2
Remote metering CHP_1
Remote metering CHP_3
Remote metering CHP_4
DERs remote monitoring ofAggregator portfolio
DistributionState
Estimation
(DSE)2
M m
m=1m
min J(x)=
SCADA in
CVPP2
SCADA inCVPP1
SCADAof DSOSCADAof DSOSCADA of
DSO
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Advanced
monitoring
Results of DSE can
be monitored
Preventive studies
can be performed
to make sure the
day ahead
(or hour ahead)
operating point iswithin limits
Advanced Monitoring
State Estimation
CalculatedNetwork operatorMonitored
criterias
Advanced Monitoring
State Estimation
CalculatedNetwork operatorMonitored
criterias
Sudden change
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Warning 1
Cos < Lim
ALARM 2
Under voltage
ALARM 1
Under voltage
Sudden change
of network
operating point
Consequences:
1) Undervoltagesoccur in the network
2) Power factor below
agreed threshold withTSO
3) Alarms in the DSO
control center
Event: loss of DER
Optimisation study
made by VVC
Network
Operator
Validate
New set points for
-DER
-Transformer tap-Capacitor bank
S t i t
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SCADA of DSO
Set point of DERs
Set pointorder for
Capacitor Bank
Transformer Tap
Set points
modification
by the VVC
VVC provides new
set points to:
Network elements
-tap changer-capacitor banks
Commercial
Aggregatorsnew set points for DER
active/reactive power
Commercial
Aggregator 1
Volt VAr control settings
-DER
-Transformer tap changer
-Capacitor bank
DER
CommercialAggregator 2 DER
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Benefits and main challenges
Main benefit of active management of distributionnetwork: Find the right balance between network
reinforcement and active management to reduceconnexion cost and increase DER hosting capacity
However, the main challenges may not only betechnical but also contractual and regulatory
with consequences on connexion rules