CIGRÉ Training Day
2nd December 2013 EI, Dublin
Slide 1 CIGRÉ - Irish National Committee
Session 3
Managing Voltage Control on a Power
System with High Renewable Penetration
Simon Tweed
Tony Hearne
Andrew Keane
Steve Gough
Douglas Cheung
CIGRÉ Training Day
2nd December 2013 EI, Dublin
Slide 2 CIGRÉ - Irish National Committee
Managing Voltage Control on a Power
System with High Renewable Penetration
Simon Tweed
Tony Hearne
PROBLEM DESCRIPTION
Session 3: Managing Voltage on a Power
System with High Renewable Penetration
- TSO Issues
Simon Tweed, EirGrid
CIGRE Ireland Training Day
2nd December 2013
Technical Analysis of the Issues
Detailed Technical Analysis
2008 - All Island Grid Study
2010 - Facilitation of Renewables
2011 - Ensuring a Secure Sustainable System
Issue: Reactive Power Availability (Sync)
0
1,000
2,000
3,000
4,000
5,000
6,000
0% 10% 20% 30% 40% 50% 60% 70% 80% 90% 100%
Re
acti
ve P
ow
er
Cap
abili
ty
(Mva
r)
Percentage of hours in the year
Reactive Power Duration Curves (Lagging)
2010 outturn
2020 base case
Issue: Wind Farm Location &
Reactive Controllability
(2013 Data)
Transmission
Connected 37% (791 MW)
T – not under voltage control
8% (67 MW)
Distribution
Connected 63% (1360 MW)
D – actively controlled
3% (39 MW)
D – not actively controlled
97% (1321 MW)
T – under voltage Control
92% (724 MW)
Issue: Dynamic Stability
Issue: Voltage Dip-Induced Frequency Dip
P Conventional / Wind
t
Managing Voltage Control on a Power
System with
High Renewable Penetration
Problem Description: DSO Perspective
Tony Hearne,
Manager IVADN Project, ESB Networks
10 esbnetworks.ie
Presentation Structure
What makes Distribution Connection different
Degrees of embedding within Distribution System
Traditional voltage-rise
New tools at our disposal
Reactive Range and visibility
Example of inter-windfarm interaction for Cluster scenario
11 esbnetworks.ie
What makes Distribution Connection different
• DSO License obligations
– Must keep all customers terminal voltage within limits [EN 50160] at all times
– Must keep all network voltages within operational limits
– Must minimise distribution network losses
• Varying degrees of embedding in Distribution System
• Varying topologies
• Interaction with existing Distribution Plant
• Interaction with demand
• Voltage Range differences
12 esbnetworks.ie
Type B Type C Type D Type E Type A
Effectiveness of reactive power
for TSO Voltage control
Effectiveness of reactive power
for local DSO Voltage control
Degree of embedding within the Distribution System
Electrical impedance between Generator and Tx System
G G
G G G
G
G
G
G
Varying degrees of embedding in Distribution System
“Traditional” Voltage Rise
14 esbnetworks.ie
Traditional Voltage Rise
If Windfarm operates at unity Power Factor
– there is voltage rise along the feeder
Windfarm
HV station
MW
Voltage
rise
15 esbnetworks.ie
Traditional Voltage Rise
If Windfarm operates such as to import VArs
– Voltage drop due to MVAr offsets voltage rise due to MW
Windfarm
HV station
MW
Voltage
rise
MVar
16 esbnetworks.ie
Traditional Voltage Rise
If Windfarm operates such as to export VArs
– Voltage rise due to MVAr adds to voltage rise due to MW
Windfarm
HV station
MW
Voltage
rise
MVar
17 esbnetworks.ie
Traditional Voltage Rise
Limit 1 at load station dictated by tapping range on transformers
Limit 2 at Windfarm location can be higher
Windfarm
HV station
Limit 1 Limit 2
Existing 38kV Station
New tools at our disposal Now and being contemplated for future use
19 esbnetworks.ie
Grid / Distribution Code Changes : Capability
Referring to Figure WFPS1.4:
Point A represents the minimum Mvar absorption capability of the Controllable WFPS at 100% Registered Capacity and is equivalent to 0.95 power factor leading;
Point B represents the minimum Mvar production capability of the Controllable WFPS at 100% Registered Capacity and is equivalent to 0.95 power factor lagging;
Point C represents the minimum Mvar absorption capability of the Controllable WFPS at 12% Registered Capacity and is equivalent to the same Mvar as Point A;
Point D represents the minimum Mvar production capability of the Controllable WFPS at 12% Registered Capacity and is equivalent to the same Mvar as Point B;
Point E represents the minimum Mvar absorption capability of the Controllable WFPS at the cut-in speed of the individual WTGs;
Point F represents the minimum Mvar production capability of the Controllable WFPS at the cut-in speed of the individual WTGs;
The TSO accepts that the values of Points E and F may vary depending on the number of WTGs generating electricity in a low-wind scenario;
MW
Q/Pmax
Registered
Capacity
(Pmax)
A B
C D12% of Registered
Capacity
-0.33 0.33
E F
20 esbnetworks.ie
Changes pending: Control modes
-Q +Q
P
+Qmax -Qmax
21 esbnetworks.ie
Q mode
-Q +Q
P
+Qmax -Qmax
Q set P max
22 esbnetworks.ie
Power Factor mode
-Q +Q
P
+Qmax -Qmax
23 esbnetworks.ie
Voltage Control
-Q +Q
V
+Qmax -Qmax
V reference 1
V reference 2
24 esbnetworks.ie
-Q
+Q
P
+Qmax
-Qmax
P max
25 esbnetworks.ie
-Q
+Q
P
+Qmax
-Qmax
P max
Reactive Range and visibility
27 esbnetworks.ie
G
38 kV DSO Connection
Point
G
38 kV
110 kV
TSO-DSO
operational
boundary
WF 2
WF 1
V
V
Can this be applied to a
distribution wind cluster?
28 esbnetworks.ie
2 + 2 may not equal 4
+ Q - Q
P
WF 1
+ Q - Q
P
WF 2
- Q + Q
P
Composite at
TSO-DSO
Interface
Idealised total
capability Actual total
capability
29 esbnetworks.ie
Interaction with Demand Load
-80
-40
0
-50 -40 -30 -20 -10 0 10
P [MW]
Q [MVAr]
29% load
100% load
∆qmax
P
+
Q
-
Q
P
1
P
2
P
’
Voltage Range differences
31 esbnetworks.ie
Tx KV % TX KV
112 123.2
111 122.1
110 121
109 119.9
108 118.8
107 117.7
106 116.6
105 115.5
104 114.4
103 113.3
102 112.2
101.5 111.65
101 111.1
100.5 110.55
100 110
99.5 109.45
99 108.9
98.5 108.35
98 107.8
97 106.7
96 105.6
95 104.5
94 103.4
93 102.3
92 101.2
91 100.1
90 99
89 97.9
88 96.8
87 95.7
86 94.6
85 93.5
84 92.4
83 91.3
82 90.2
81 89.1
80 88
79 86.9
78 85.8
77 84.7
MV KV % MV KV
113 22.6
112 22.4
111 22.2
110 22
109 21.8
108 21.6
107 21.4
106 21.2
105 21
104 20.8
103 20.6
102 20.4
101 20.2
100 20
99 19.8
98 19.6
97 19.4
Tap 9
Example of inter-windfarm
interaction for Cluster scenario
33 esbnetworks.ie
Case 3: Strong and weak on same trafo
+ / - 12 MVAr
Tap
Strong
110kV/38kV trafo Standard
Taps Sincal Tap
1 122.5 40.9 5
2 120 40.9 4
3 117.5 40.9 3
4 115 40.9 2
5 112.5 40.9 1
6 110 40.9 0
7 107.5 40.9 -1
8 105 40.9 -2
9 102.5 40.9 -3
10 100 40.9 -4
11 97.5 40.9 -5
12 95 40.9 -6
13 92.5 40.9 -7
14 90 40.9 -8
15 87.5 40.9 -9
16 85 40.9 -10
+ / - 5 MVAr
Weak
Action- 8.4 MVAr
Action- 3.5 MVAr
Reset 3.6 MVAr
S C 2 3
0 . 0 0 M W
1 . 2 8 M v a r
AAG 2 2
1 5 . 0 0 M W
- 0 . 0 0 M v a r
L 2 0
1 4 . 6 1 M W
0 . 1 2 M v a r
1 4 . 6 1 M V A
0 . 2 3 k A
- 1 5 . 0 0 M W
- 1 . 2 9 M v a r
1 5 . 0 6 M V A
0 . 2 3 k A
L 1 6
3 5 . 9 0 M W
2 . 2 3 M v a r
3 5 . 9 7 M V A
0 . 5 5 k A
- 3 6 . 0 0 M W
- 2 . 1 8 M v a r
3 6 . 0 7 M V A
0 . 5 5 k A
AAG 1 5
3 6 . 0 0 M W
0 . 0 0 M v a r
2 T 1 4
- 1 . 0
5 0 . 3 6 M W
- 6 . 6 5 M v a r
5 0 . 7 9 M V A
0 . 3 0 k A
- 5 0 . 5 1 M W
- 2 . 3 4 M v a r
5 0 . 5 6 M V A
0 . 7 8 k A
S C 1 2
0 . 0 0 M W
2 . 1 6 M v a r
I 1 0
- 5 0 . 3 6 M W
6 . 6 5 M v a r
3 8 . 6 2 k V
1 0 1 . 6 2 %
3 7 . 5 8 k V
9 8 . 9 0 %
3 7 . 4 6 k V
9 8 . 5 8 %
9 8 . 9 1 k V
8 9 . 9 2 %
Reset 1.5 MVAr
34 esbnetworks.ie
80
81
82
83
84
85
86
87
88
89
90
91
92
93
94
95
96
97
98
99
100
101
102
103
104
105
106
107
108
109
110
111
112
113
114
115
116
117
118
-17 -16 -15 -14 -13 -12 -11 -10 -9 -8 -7 -6 -5 -4 -3 -2 -1 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17
Q [MVAr]
V [%
nom
]Case 3: Strong and weak on same trafo
35 esbnetworks.ie
80
81
82
83
84
85
86
87
88
89
90
91
92
93
94
95
96
97
98
99
100
101
102
103
104
105
106
107
108
109
110
111
112
113
114
115
116
117
118
119
120
121
122
-17 -16 -15 -14 -13 -12 -11 -10 -9 -8 -7 -6 -5 -4 -3 -2 -1 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17
Q [MVAr]
V [%
nom
]Case 3: Strong and weak on same trafo
36 esbnetworks.ie
Case 3: Strong and weak on same trafo
80
81
82
83
84
85
86
87
88
89
90
91
92
93
94
95
96
97
98
99
100
101
102
103
104
105
106
107
108
109
110
111
112
113
114
115
116
117
118
119
120
121
122
-17 -16 -15 -14 -13 -12 -11 -10 -9 -8 -7 -6 -5 -4 -3 -2 -1 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17
Q [MVAr]
V [%
nom
]
37 esbnetworks.ie
Case 3: Strong and weak on same trafo
80
81
82
83
84
85
86
87
88
89
90
91
92
93
94
95
96
97
98
99
100
101
102
103
104
105
106
107
108
109
110
111
112
113
114
115
116
117
118
119
120
121
122
-17 -16 -15 -14 -13 -12 -11 -10 -9 -8 -7 -6 -5 -4 -3 -2 -1 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17
Q [MVAr]
V [%
nom
]
38 esbnetworks.ie
80
81
82
83
84
85
86
87
88
89
90
91
92
93
94
95
96
97
98
99
100
101
102
103
104
105
106
107
108
109
110
111
112
113
114
115
116
117
118
119
120
121
122
-17 -16 -15 -14 -13 -12 -11 -10 -9 -8 -7 -6 -5 -4 -3 -2 -1 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17
Q [MVAr]
V [%
nom
]Case 3: Strong and weak on same trafo
Tx V [%]
88
90
92
94
96
98
100
102
0 1 2 3 4 5 6 7 8
Tx voltage drops
Both operating
points move
along their droop
slope
39 esbnetworks.ie
80
81
82
83
84
85
86
87
88
89
90
91
92
93
94
95
96
97
98
99
100
101
102
103
104
105
106
107
108
109
110
111
112
113
114
115
116
117
118
119
120
121
122
-17 -16 -15 -14 -13 -12 -11 -10 -9 -8 -7 -6 -5 -4 -3 -2 -1 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17
Q [MVAr]
V [%
nom
]Case 3: Strong and weak on same trafo
Tx V [%]
88
90
92
94
96
98
100
102
0 1 2 3 4 5 6 7 8
“Strong” hits Q action
AVR intervention
triggered
Strong V-ref lowered
Action stops when
“Strong” goes below Q
reset
40 esbnetworks.ie
80
81
82
83
84
85
86
87
88
89
90
91
92
93
94
95
96
97
98
99
100
101
102
103
104
105
106
107
108
109
110
111
112
113
114
115
116
117
118
119
120
121
122
-17 -16 -15 -14 -13 -12 -11 -10 -9 -8 -7 -6 -5 -4 -3 -2 -1 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17
Q [MVAr]
V [%
nom
]Case 3: Strong and weak on same trafo
Tx V [%]
88
90
92
94
96
98
100
102
0 1 2 3 4 5 6 7 8
“Weak” now close to it’s Q
action
Tx V drops
“Weak” hits it’s Q action
AVR intervention triggered
Weak V-ref lowered
Action stops when “Weak” goes
below Q reset
41 esbnetworks.ie
80
81
82
83
84
85
86
87
88
89
90
91
92
93
94
95
96
97
98
99
100
101
102
103
104
105
106
107
108
109
110
111
112
113
114
115
116
117
118
119
120
121
122
-17 -16 -15 -14 -13 -12 -11 -10 -9 -8 -7 -6 -5 -4 -3 -2 -1 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17
Q [MVAr]
V [%
nom
]Case 3: Strong and weak on same trafo
Tx V [%]
88
90
92
94
96
98
100
102
0 1 2 3 4 5 6 7 8
110kV/38kV trafo Standard
Taps Sincal Tap
1 122.5 40.9 5
2 120 40.9 4
3 117.5 40.9 3
4 115 40.9 2
5 112.5 40.9 1
6 110 40.9 0
7 107.5 40.9 -1
8 105 40.9 -2
9 102.5 40.9 -3
10 100 40.9 -4
11 97.5 40.9 -5
12 95 40.9 -6
13 92.5 40.9 -7
14 90 40.9 -8
15 87.5 40.9 -9
16 85 40.9 -10
Tx V drops further
“strong” once again hits Q action
AVR intervention triggered
V ref lowered but hits V min
Tap change initiated
Tap until either or both come
below Q reset
42 esbnetworks.ie
Q /V at TSO-DSO Interface
Tx V against Q at TSO-DSO Interface
88
90
92
94
96
98
100
102
-10 -8 -6 -4 -2 0 2
Q at TSO-DSO Interface [MVar]
Tx V
[%
of
No
m]
Questions ?
CIGRÉ Training Day
2nd December 2013 EI, Dublin
Slide 44 CIGRÉ - Irish National Committee
Managing Voltage Control on a Power
System with High Renewable Penetration
Andrew Keane
RANGE OF SOLUTIONS
Managing reactive power on power
systems with high renewable
penetration
Range of Possible Solutions
December 2013
Dr Andrew Keane
University College Dublin
46
• Function traditionally taken care of by synchronous generators and capacitor banks
– In some cases FACTs devices also employed
• At distribution level tap changers play a big role
Reactive Power/Voltage Control
47
1. Renewable generation causing displacement of conventional generators
2. Renewable generation connecting to distribution system
Changing Circumstances
48
Synchronous Machine Capability
0
10
20
30
40
50
-35 -15 5 25 45
Act
ive
Po
we
r (M
W)
Reactive power (MVAr)
Sync Machine
49
Wind P-Q Capability
0
0.2
0.4
0.6
0.8
1
-0.7 -0.5 -0.3 -0.1 0.1 0.3 0.5
ActivePower (pu)
Reactive Power (pu)
50
• Grid code requirements
• Const. PF
• Const. V
• Const. Q
What can wind do?
MW
Q/Pmax
Registered
Capacity
(Pmax)
A B
C D12% of Registered
Capacity
-0.33 0.33
E F
51
Distributed Generation
PowerFactory 14.0.514
Project:
Graphic: Grid
Date: 4/26/2012
Annex:
Nodes Branches
Sub-sea cable
33 kV
132 kV
Gen. D(8 MW)
Gen. B(12.5 MW)
Gen. C(15 MW)
Gen. A(16 MW)
336
323 325
322
326
328
314&315
301
321&320
313&312
335
334
309
307&308
305&306
304
311
310
339
100
302&303
327
330
329
G~
G~
G~
G~
52
Distribution/Transmission Interface
0
10
20
30
40
50
-35 -25 -15 -5 5 15 25
Act
ive
Po
wer
(M
W)
Reactive Power (MVAr)
Raw (P,Q)
99% Reliability
Cuffe, P., Smith, P. And Keane A., “Capability Chart for Distributed Reactive Power Resources”, IEEE Transactions on Power
Systems, 2013
53
• Provision of additional MVAr capacity
Possible Solutions
54
• Better utilisation of existing capacity
– Software based solution providing enhanced controllability
– Optimised controller settings requiring no operational change
Possible Solutions
55
Test system
132 kV
33 kV
DxCGen: 29 MW
Load: 52 MW
DxBGen: 40 MW
Load: 35 MW
DxAGen: 22 MW
Load: 17 MW
2926
23
1614
28
7
22
24 15
10
3
2
18
30
12
19
20
6
8
17
27
1
5
4
21
25
DG-B318 MW
DG-B115 MW
DG-C325 MW
G~
Gen1200 MW
G~
Gen280 MW
11
DG-B27 MW
DG-A115 MW
11
DG-C29 MW
G~
Gen1130 MW
G~
Gen
835 M
W
00
DG-C120 MW
G~
Gen550 MW
G~
Gen1340 MW
DG
-A2
7 M
W
56
Unity Power Factor
57
Wind Q-V Response
Keane, A., Diskin, E., Cuffe, P, Harrington, P., Hearne, T., Brooks, D., Rylander, M., and Fallon, T., “Evaluation of Advanced
Operation and Control of Distributed Wind Farms to Support Efficiency and Reliability for High Penetrations of Wind Power”,
IEEE Transactions on Sustainable Energy, vol. 3, Oct 2012.
58
Non optimised voltage control
59
• Desired response is given by simultaneously:
– Maximising the aggregate reactive power injection for the lower-voltage periods and the absorption for higher-voltage periods
• Utilise multi scenario ACOPF with embedded models of voltage control and tap changer
• Determines fixed voltage set-points, droops and tap setting
Possible Desired Response
60
Optimised settings
Cuffe, P., and Keane A., “Voltage Responsive Distribution Networks Using Enhanced Generator and Transformer Settings”, IEEE
Transactions on Power Systems, (in review) 2013
61
• Optimised fixed settings for DG and trafo
• Deliver desirable voltage response at transmission
• Distribution constraints all respected
• Real time control could deliver more
Result
62
• Question of capacity and location
• Scope for improvement in control of existing resources
• A lot can be achieved with optimised settings
• Real time control has potential for further benefits
Summary
63
Acknowledgements
CIGRÉ Training Day
2nd December 2013 EI, Dublin
Slide 64 CIGRÉ - Irish National Committee
Managing Voltage Control on a Power
System with High Renewable Penetration
Steve Gough
Douglas Cheung
SOLUTION CASE STUDY
HV Voltage Control
Hitachi’s D-SVC integration onto the 11kV distribution network
Steven Gough – WPD
Douglas Cheung – Hitachi Europe
Customers
Testing innovative solutions to make
it simple for customers to connect Low
Carbon Technologies
Performance
Developing new solutions to
improve network and business performance
Networks
Demonstrating alternative investment strategies to
facilitate the UK’s Low Carbon Transition
Stakeholder Engagement and Knowledge Management
Innovation Strategy
Super Conducting Fault Current
Limiter
Isentropic Energy Storage
Carbon Tracing
Project Specifics
• Two phases
• A 400kVar D-SVC on the end of a 11kV feeder adjacent to a 1.8MW windfarm
• Three 400kVar D-SVCs spread across two feeders of a Primary Substation’s network with a centralised control system D-QVC
• Looking to investigate effectiveness of using reactive power for controlling voltage at feeder ends
• Specifically looking to help the integration for further DG across rural networks
HV Voltage Control
© Hitachi Europe Ltd. 2013. All rights reserved.
LCNF Project Overview
68
Substation
11kv OH line
Wind Farm
D-STATCOM
4 Project Locations
Agreed
Tentative
LCNF Tier 1 project • As DG (Distributed Generation) becomes more common, the growing number of renewable connections to distribution lines is expected to cause voltage fluctuations (specifically high or low voltage) due to the variable power output of the DG. In turn this can affect the efficiency and capacity of the distribution network.
• Determine the effectiveness of D-STATCOM as a dynamic voltage control system in rural 11kV networks to address voltage fluctuation.
• Optimise control by using a D-VQC (Voltage and Reactive Power Control System) to network multiple D-STATCOMs.
Goals
• 2 Strand project, initially 1 D-STATCOM as proof of concept, then 3 additional units as well as a D-VQC server.
Scope
• Improvement of power quality and mitigation of voltage spikes issues, thereby increasing network stability, efficiency and load capacity in distribution networks.
• Learning from project will be beneficial for informing DNOs business case for alternative responses to network rebuild.
Expected Benefits
Background
© Hitachi Europe Ltd. 2013. All rights reserved.
© Hitachi Europe Ltd. 2013. All rights reserved.
Power Quality Problems Created by RE
69
shine
cloud
rain
3.2kW PV
1200kW Wind-Power
Fluctuated power output from RE
(a) Reverse Power Flow from RE
(b) Generator Cut Off SVR: Step Voltage Regulator RE: Renewable Energy
Violation of Voltage management level
Line distance
Reverse Power
Violation
voltage
RE SVR
Management level
voltage
P
Drop P
SVR tap change
RE
time Voltage violation
RE cut off
P
P
P
SVR
Management level
Voltage fluctuation
voltage
time
Voltage fluctuation
Management level
© Hitachi Europe Ltd. 2013. All rights reserved. 70
What is a STATCOM?
© Hitachi Europe Ltd. 2013. All rights reserved.
Control Block Diagram of D-SVC/D-STATCOM
71
Mode Block Diagram Target
AVR
All fluctuations
ARV
Long-term fluctuation (minutes)
SFV
Short-term fluctuation (seconds)
s
KK I
PsT11
1
referenceV
V I
pKsT11
1
Moving Average
V I
sT11
1
sT
sT
3
2
1 pKIV
HPF
AVR : Automatic Voltage Regulation, ARV : Average Reference Voltage SFV : Short-term Fluctuation of Voltage, VSC : Voltage Source Converter
© Hitachi Europe Ltd. 2013. All rights reserved.
Using Reactive Power to Control Voltage
72
5600
5800
6000
6200
6400
6600
6800
7000
0 60 120 180 240 300
Time (sec)
Dis
trib
ution L
ine V
oltage (
V)
-450
-300
-150
0
150
300
450
600
Q (
kva
r)
Line Voltage with D-STATCOM
D-STATCOM Q
SVR2 tap
Line Voltage without D-STATCOM (estimation)
-195kVar
-100kVar
60 sec 6250V
6515
V tap 4
tap 3 tap 2
D-STATCOM operation
SVR operation
RE sudden power change
Reactive power can be used to control the distribution line voltage against sudden power change of RE between taps of SVR
Phase 1
HV Voltage Control
• D-SVC is installed on site adjacent to a 1.8MW windfarm in Cornwall
• Protection was installed on the LV side of the transformer as there was not a metering unit
• Monitoring equipment was installed along the feeder
• D-SVC has been running on various modes for nearly a year and a half
D-SVC
G
Summerheath
Roskrow WF
Kernick Industrial Estate
Bickland Hill Primary
Phase 1 Output Graphs (1)
Real and Reactive Power at Windfarm
-200
0
200
400
600
800
1000
1200
1400
1600
1800
00:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00 16:00 18:00 20:00 22:00 00:00
Time
Po
we
r
Average kW
Max kW
Min kW
Average kVar
Max kVar
Min kVar
Real and Reactive Power at SVC
-500
-400
-300
-200
-100
0
100
200
300
400
500
00:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00 16:00 18:00 20:00 22:00 00:00
Time
Po
we
r
Average kW
Max kW
Min kW
Average kVar
Max kVar
Min kVar
Voltage at D-SVC
225
230
235
240
245
250
00:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00 16:00 18:00 20:00 22:00 00:00
TimeP
ha
se
to
Lin
e V
otla
ge
Va
Va(max)
Va(min)
Vb
Vb(max)
Vb(min)
Vc
Vc(max)
Vc(min)
Phase 1 Output Graphs (2)
Voltage at D-SVC
225
230
235
240
245
250
00:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00 16:00 18:00 20:00 22:00 00:00
Time
Ph
ase
to
Lin
e V
otla
ge
Va
Va(max)
Va(min)
Vb
Vb(max)
Vb(min)
Vc
Vc(max)
Vc(min)
Voltage at Windfarm
6000
6050
6100
6150
6200
6250
6300
6350
6400
6450
00:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00 16:00 18:00 20:00 22:00 00:00
TimeP
ha
se
to
Lin
e V
otla
ge
Va
Va(max)
Va(min)
Vb
Vb(max)
Vb(min)
Vc
Vc(max)
Vc(min)
Voltage at Bickland Hill Primary
5950
6000
6050
6100
6150
6200
6250
6300
6350
6400
6450
00:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00 16:00 18:00 20:00 22:00 00:00
Time
Ph
ase
to
Lin
e V
otla
ge
Va
Va(max)
Va(min)
Vb
Vb(max)
Vb(min)
Vc
Vc(max)
Vc(min)
Phase 1 Output Graphs (3)
Voltage at Windfarm with D-SVC Switched In
6050
6100
6150
6200
6250
6300
6350
6400
6450
6500
6550
00:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00 16:00 18:00 20:00 22:00 00:00
Time
Ph
ase
to
Lin
e V
otla
ge
Va
Va(max)
Va(min)
Vb
Vb(max)
Vb(min)
Vc
Vc(max)
Vc(min)
Voltage at Windfarm with D-SVC Switched Out
6050
6100
6150
6200
6250
6300
6350
6400
6450
6500
6550
00:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00 16:00 18:00 20:00 22:00 00:00
Time
Ph
ase
to
Ea
rth
Vo
tla
ge
Va
Va(max)
Va(min)
Vb
Vb(max)
Vb(min)
Vc
Vc(max)
Vc(min)
Plans for Phase 2 • Three D-SVCs will be used on one primary two on a feeder
with multiple small generators and the other a feeder with one larger generator
• A D-VQC (Voltage and Reactive Power (Q) Control System) will be used at the primary to control all three D-SVCs and the tap changer at the primary substations
• This will demonstrate cohesive voltage optimisation across the primary
D-SVC
D-SVC G
D-SVC G G G G G G
Learning so far
• Sizing and impedance the transformer is import to get right for a D-SVC.
• The D-SVC can help smooth the voltage
• The D-SVC can help reduce the voltage range seen on the 11kV
• D-SVC over and under voltage protection needs to be on the HV side of the transformer
Any Questions?
Steven Gough – WPD
Douglas Cheung – Hitachi Europe
CIGRÉ Training Day
2nd December 2013 EI, Dublin
Slide 80 CIGRÉ - Irish National Committee
Questions & Answers
Managing Voltage Control on a
Power System with High Renewable Penetration
PUBLICATIONS
Paris 2012 & 2014
• 2012 - SC B4 HVDC and Power Electronics – PS2 > HVDC and FACTS Technology Developments
• FACTS equipment
– PS3 > Applications of HVDC and FACTS • FACTS equipment for increased AC network performance
• Use of Power Electronics to facilitate the integration of large renewable energy sources into AC networks
• 2014 - SC B4 HVDC and Power Electronics – PS2 > FACTS Systems and Applications
• Renewable Resources Integration
• Increased network performance
Publications • Technical Brochures
– TB 523 System Complexity and Dynamic Performance – TB 310 Coordinated Voltage Control in Transmission Networks. – TB 371 Static Synchronous Series Compensator
• Session Papers / Electra
– Comparison of the dynamic response of wind power generators of different technologies in case of voltage dips
– Voltage and VAr Support in System Operation – Development and testing of ride-through capability solutions for
a wind turbine with doubly fed induction generator using VSC t – Real time dynamic security assessment and control by
combining FACTS and SPS – FACTS for enabling wind power generation
