Synchronized Phasor Measurement - Epcc-workshop.net
Synchronized Phasor Measurement - Epcc-workshop.net
Synchronized Phasor Measurement - Epcc-workshop.net
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<strong>Synchronized</strong> <strong>Phasor</strong> <strong>Measurement</strong> System at<br />
Southern California Edison Co. for Monitoring<br />
and Recording Power System Operation /<br />
Disturbances<br />
By<br />
Bharat Bhargava<br />
Consulting Engineer<br />
Southern California Edison Co.<br />
Rosemead, CA 91770<br />
Eighth Electric Power Control Center Meeting,<br />
June 5-8, 5<br />
2005, Les Diablerets, , Switzerland<br />
1
Maximizing power import capability<br />
into California and its reliability<br />
is essential for<br />
improving power system operations<br />
‣ power availability (adequate resources)<br />
‣ power system reliability<br />
‣ price stability<br />
helping maintaining price stability essential for<br />
‣ sustained California’s economic growth<br />
‣ avoiding repeat of 2000-2002 power shortages<br />
and high price scenarios.<br />
2
Presentation outline:<br />
Presentation outline:<br />
SCE <strong>Phasor</strong> <strong>Measurement</strong> system<br />
SCE <strong>Phasor</strong> <strong>Measurement</strong> system capabilities<br />
Off-line<br />
On-line (Real-time)<br />
Some interesting recorded events<br />
June 14, 2004 (Three Palo Verde units trip)<br />
October 9, 2003 (Colstrip controls system)<br />
August 4, 2000 (Stressed system oscillations)<br />
DC Probing tests (August 7, 2003)<br />
WAMS / WACS applications<br />
Phase angle monitoring<br />
Voltage support and Capacitor controls<br />
Modal oscillation and their damping<br />
System loading / path loading<br />
3
<strong>Phasor</strong> <strong>Measurement</strong> Unit<br />
4
SCE <strong>Phasor</strong> <strong>Measurement</strong> Units<br />
Vincent (8)<br />
Antelope (5)<br />
Big Creek (5)<br />
Kramer (5)<br />
Devers 230 kV (5)<br />
Alamitos GS (5)<br />
Devers (5)<br />
Mohave (5)<br />
San Onofre (10)<br />
Data Concentrator<br />
System Protection<br />
GO3, 3rd Floor<br />
Eldorado (5)<br />
Lugo (10)<br />
Valley 115kV (5)<br />
Control (5)<br />
Magunden (10)<br />
5
<strong>Phasor</strong> <strong>Measurement</strong> System Network<br />
Big<br />
Creek 3<br />
Vincent<br />
500kV<br />
Songs<br />
Devers<br />
500kV<br />
Kramer<br />
230kV<br />
Mohave<br />
500kV<br />
Alamitos<br />
230kV<br />
Devers<br />
115kV<br />
Antelope<br />
66kV<br />
Magunden<br />
230kV<br />
Valley<br />
115kV<br />
<strong>Phasor</strong><br />
Data<br />
Concentrator<br />
PDC<br />
Lugo<br />
500kV<br />
Control<br />
115kV<br />
Eldorado<br />
500kV<br />
SCE Net<br />
NT<br />
Server<br />
User<br />
1<br />
User<br />
2<br />
User<br />
3<br />
User<br />
n<br />
6
WECC System and Its Operation<br />
SHASTA<br />
G M SHRUM<br />
KEMANO<br />
MICA<br />
GRAND<br />
COULEE<br />
Major interaction path<br />
"Index" generator<br />
HOOVER<br />
MEAD<br />
PALO<br />
VERDE<br />
SUNDANCE<br />
COLSTRIP<br />
FOUR<br />
CORNERS<br />
MEXICO<br />
WECC SYSTEM DYNAMICS INTERACTION MAP<br />
jfh<br />
<br />
<br />
<br />
<br />
<br />
<br />
WECC is a large system<br />
with fourteen Western US<br />
States extending from<br />
Canada to Mexico<br />
About 130,000 MW<br />
generation and load<br />
Over 2200 generators<br />
Extensive 500kV, 230 kV<br />
and HVDC Transmission<br />
lines and <strong>net</strong>work<br />
Transmission paths with<br />
capacity of 4800 MW and<br />
over 1000 miles long<br />
Requires very careful<br />
coordinated planning and<br />
operation<br />
7
WECC System and Its Operation<br />
SHASTA<br />
G M SHRUM<br />
KEMANO<br />
MICA<br />
GRAND<br />
COULEE<br />
Major interaction path<br />
"Index" generator<br />
HOOVER<br />
MEAD<br />
PALO<br />
VERDE<br />
SUNDANCE<br />
COLSTRIP<br />
FOUR<br />
CORNERS<br />
MEXICO<br />
WECC SYSTEM DYNAMICS INTERACTION MAP<br />
jfh<br />
Events in one area<br />
impact other remote areas<br />
Southern California mostly<br />
receives power from Arizona<br />
and Northwest<br />
Events in Northwest on<br />
August 10, 1996 resulted in a<br />
massive blackout and loss of<br />
load in California<br />
<strong>Phasor</strong> <strong>Measurement</strong><br />
Technology can enable SCE<br />
to keep track of the WECC<br />
events and monitor the<br />
stability of the system<br />
System often operates at<br />
angles exceeding 90 degrees<br />
between Grand Coulee and<br />
SCE system<br />
8
WECC System and Its Operation<br />
SHASTA<br />
G M SHRUM<br />
KEMANO<br />
MICA<br />
GRAND<br />
COULEE<br />
Major interaction path<br />
"Index" generator<br />
HOOVER<br />
MEAD<br />
PALO<br />
VERDE<br />
SUNDANCE<br />
COLSTRIP<br />
FOUR<br />
CORNERS<br />
MEXICO<br />
WECC SYSTEM DYNAMICS INTERACTION MAP<br />
jfh<br />
Ideally, would like and can<br />
monitor<br />
‣ Static and dynamic<br />
phase angle separation<br />
/swings between Grand<br />
Coulee and Vincent or<br />
Devers substations<br />
‣ Voltage/Var<br />
Var support at<br />
Intermediate substations<br />
‣ Power flows on major<br />
AC and DC Inter-ties<br />
ties<br />
‣ Dynamics of interaction<br />
on major interaction<br />
paths<br />
‣ Oscillation modal<br />
frequencies, and damping<br />
9
<strong>Synchronized</strong> <strong>Phasor</strong> <strong>Measurement</strong><br />
Off-line Applications:<br />
Monitoring system stress (Phase angle separations)<br />
Monitoring voltage support at critical locations<br />
Post disturbance analysis (what operated correctly or<br />
incorrectly)<br />
Monitoring modal oscillations and modal damping<br />
Monitoring dynamic power swings<br />
Model validation/establishing limits using off-line<br />
analysis tools<br />
Monitoring machine excitation and governor systems<br />
System Voltage and reactive power management<br />
Pattern recognition and AI tools for quick event analysis<br />
System load response to voltage and frequency variations<br />
10
562.062<br />
0<br />
Loss of Palo Verde Units 1, 2 & 3<br />
on June 14 th , 2004<br />
Relative Phase Angle Display before disturbance<br />
06/14/04 Event at 07:40 Pacific Time (06/14/04 at 14:40 GMT )<br />
Vincent 500kV<br />
330<br />
0<br />
30<br />
Devers 500kV<br />
Eldorado 500kV<br />
Lugo 500 kV<br />
300<br />
60<br />
Grand Coulee 2<br />
John Day<br />
Malin N<br />
270<br />
90<br />
Colstrip<br />
Big Eddy 500<br />
Keeler 500 kV<br />
240<br />
120<br />
Capt Jack N. Bus<br />
Capt Jack S. Bus<br />
Olinda 500 kV<br />
210<br />
180<br />
150<br />
Summer Lake N. Bus<br />
Slatt W. Bus<br />
Devers 500 kV<br />
Angle Reference is Grand Coulee 2<br />
11
562.062<br />
0<br />
Loss of Palo Verde Units 1, 2 & 3<br />
on June 14 th , 2004<br />
Peak Relative Phase Angle Display during disturbance<br />
06/14/04 Event at 07:40 Pacific Time (06/14/04 at 14:40 GMT )<br />
Vincent 500kV<br />
330<br />
0<br />
30<br />
Devers 500kV<br />
Eldorado 500kV<br />
Lugo 500 kV<br />
300<br />
60<br />
Grand Coulee 2<br />
John Day<br />
Malin N<br />
270<br />
90<br />
Colstrip<br />
Big Eddy 500<br />
Keeler 500 kV<br />
240<br />
120<br />
Capt Jack N. Bus<br />
Capt Jack S. Bus<br />
Olinda 500 kV<br />
210<br />
180<br />
150<br />
Summer Lake N. Bus<br />
Slatt W. Bus<br />
Devers 500 kV<br />
Angle Reference is Grand Coulee 2<br />
12
Loss of Palo Verde Units 1, 2 & 3<br />
on June 14 th , 2004<br />
Voltage plots for 500 kV<br />
06/14/04 Event at 07:40 Pacific Time (06/14/04 at 14:40 GMT )<br />
562.0<br />
528.6<br />
495.2<br />
461.8<br />
428.4<br />
395.0<br />
14:40:34.00 14:40:44.00 14:40:54.00 14:41:04.00 14:41:14.00 14:41:24.00 14:41:34.00<br />
Pacific Time<br />
Vincent 500kV<br />
Lugo 500 kV<br />
Grand Coulee 1<br />
John Day<br />
Malin N<br />
Colstrip<br />
Big Eddy 500<br />
Keeler 500 kV<br />
Capt Jack N. Bus<br />
Olinda 500 kV<br />
Summer Lake N. Bus<br />
Slatt W. Bus<br />
Slatt E. Bus<br />
Devers 500 kV<br />
13
Loss of Palo Verde Units 1, 2 & 3<br />
on June 14 th , 2004<br />
Total power flow on Midway-Vincent lines<br />
06/14/04 Event at 07:40 Pacific Time (06/14/04 at 14:40 GMT )<br />
3000.0<br />
2430.0<br />
1860.0<br />
1290.0<br />
Sum of MW<br />
720.0<br />
150.0<br />
14:40:03.00 14:40:33.00 14:41:03.00 14:41:33.00 14:42:03.00 14:42:33.00 14:43:03.00<br />
Pacific Time<br />
Sum of MW = VC-Midway1 + VC-Midway2 + VC-Midway3<br />
14
Loss of Palo Verde Units 1, 2 & 3<br />
on June 14 th , 2004<br />
Phase Angle Deviation Plot<br />
06/14/04 Event at 07:40 Pacific Time (06/14/04 at 14:40 GMT )<br />
150<br />
125<br />
100<br />
75<br />
50<br />
25<br />
0<br />
14:40:34.00 14:40:44.00 14:40:54.00 14:41:04.00 14:41:14.00 14:41:24.00 14:41:34.00<br />
Pacific Time<br />
Vincent 500kV<br />
Devers 500kV<br />
Lugo 500 kV<br />
Grand Coulee 1<br />
John Day<br />
Malin N<br />
Colstrip<br />
Big Eddy 500<br />
Keeler 500 kV<br />
Capt Jack N. Bus<br />
Olinda 500 kV<br />
Summer Lake N. Bus<br />
Slatt W. Bus<br />
Slatt E. Bus<br />
Devers 500 kV<br />
Angle Reference is Colstrip<br />
15
Loss of Palo Verde Units 1, 2 & 3<br />
on June 14 th , 2004<br />
Apparent Line impedance plots<br />
---- Impedance in Ohms ---- Estimated Zone 3 setting<br />
----<br />
line phase angle<br />
800.00<br />
700.00<br />
600.00<br />
500.00<br />
400.00<br />
300.00<br />
200.00<br />
100.00<br />
0.00<br />
1 128 255 382 509 636 763 890 1017 1144 1271 1398 1525<br />
16
Loss of about 2300 MW generation in<br />
Northwest by RAS – July 15, 2002<br />
Expanded frequency plot<br />
07/15/02 Event at 13:04 Pacific Time (07/15/02 at 20:04 GMT )<br />
60.053<br />
59.995<br />
59.937<br />
59.880<br />
59.822<br />
VINC<br />
MOGS<br />
DEVR<br />
ALAM<br />
SONG<br />
KRMR<br />
DEV2<br />
VLLY<br />
BPA1<br />
59.764<br />
13:03:59.00 13:04:01.47 13:04:03.93 13:04:06.40 13:04:08.87 13:04:11.33 13:04:13.80<br />
Pacific Time<br />
17
<strong>Synchronized</strong> <strong>Phasor</strong> <strong>Measurement</strong> System<br />
Monitoring modal oscillations and their damping<br />
Can monitor Modal oscillation frequency and their<br />
damping using SCE software<br />
Software can calculate oscillatory modes and their<br />
damping at any PMU location<br />
Oscillations calculated from power flows on different<br />
monitored lines<br />
Can track the path of oscillations<br />
Cases shown:<br />
‣ August 4, 2000 – Bulk Power system<br />
‣ Colstrip Power plant control operation – October 9, 2003<br />
‣ Big Creek 230 kV system oscillations<br />
‣ DC Probe tests – August 7, 2003<br />
18
WECC System Oscillations under<br />
stressed conditions – August 4, 2000<br />
Voltage magnitude Plot from SCE and BPA files<br />
08/04/00 Event at 12:55 Pacific Time (08/04/00 at 19:55 GMT )<br />
558.0<br />
546.4<br />
534.8<br />
523.2<br />
511.6<br />
500.0<br />
19:56:14.00 19:56:28.93 19:56:43.87 19:56:58.80 19:57:13.73 19:57:28.67 19:57:43.60<br />
Pacific Time<br />
Vincent 500kV<br />
Devers 500kV<br />
Grand Coulee 500kV<br />
Grand Coulee<br />
John Day<br />
Malin N<br />
Colstrip<br />
Big Eddy 500<br />
Keeler 500 kV<br />
Vincent<br />
Devers 500 kV<br />
Vincent 500kV<br />
Devers 500kV<br />
Grand Coulee 500kV<br />
19
WECC System Oscillations under<br />
stressed conditions – August 4, 2000<br />
Phase Angle Plot from SCE & BPA files<br />
08/04/00 Event at 12:55 Pacific Time (08/04/00 at 19:55 GMT )<br />
135<br />
113<br />
90<br />
68<br />
45<br />
23<br />
0<br />
19:56:14.00 19:56:28.93 19:56:43.87 19:56:58.80 19:57:13.73 19:57:28.67 19:57:43.60<br />
Pacific Time<br />
Vincent 500kV<br />
Devers 500kV<br />
Grand Coulee 500kV<br />
Grand Coulee<br />
John Day<br />
Malin N<br />
Colstrip<br />
Big Eddy 500<br />
Keeler 500 kV<br />
Vincent<br />
Devers 500 kV<br />
Vincent 500kV<br />
Devers 500kV<br />
Grand Coulee 500kV<br />
Angle Reference is Colstrip<br />
20
557.928<br />
0<br />
WECC System Oscillations under<br />
stressed conditions – August 4, 2000<br />
Phase Angle Display<br />
08/04/00 Event at 12:55 Pacific Time (08/04/00 at 19:55 GMT )<br />
0<br />
330<br />
30<br />
Vincent 500kV<br />
300<br />
60<br />
Mohave 500kV<br />
Devers 500kV<br />
Grand Coulee 500kV<br />
Grand Coulee<br />
270<br />
90<br />
John Day<br />
Malin N<br />
Colstrip<br />
Big Eddy 500<br />
240<br />
120<br />
Keeler 500 kV<br />
Vincent<br />
210<br />
180<br />
150<br />
Devers 500 kV<br />
Angle Reference is Grand Coulee 500kV<br />
21
WECC System Oscillations under<br />
stressed conditions – August 4, 2000<br />
Modal Frequencies and Damping<br />
at SCE Vincent substation<br />
22
WECC System Oscillations under<br />
stressed conditions – August 4, 2000<br />
FFT Plot of Power Flows at Vincent substation<br />
08/04/00 Event at 12:55 Pacific Time (08/04/00 at 19:55 GMT ) Bandwidth 0 - 1.5<br />
10.00000<br />
0.00000<br />
-10.00000<br />
-20.00000<br />
-30.00000<br />
Midway1<br />
Midway2<br />
Midway3<br />
Lugo1<br />
Lugo2<br />
Pardee<br />
-40.00000<br />
0 0.2490234 0.4980469 0.7470703 0.9960938 1.245117 1.494141<br />
Frequency (Hz)<br />
Most Dominant Mode is 0.286 Hz ; Damping (%) = 2.6 ; Time Const = 22.21 sec<br />
23
WECC System Oscillations from Colstrip<br />
controls – October 9, 2003<br />
Voltage Magnitude plots from BPA file<br />
10/09/03 Event at 13:25 Pacific Time (10/09/03 at 20:25 GMT )<br />
555.0<br />
548.2<br />
541.4<br />
534.6<br />
527.8<br />
521.0<br />
13:25:00.00 13:25:50.00 13:26:40.00 13:27:30.00 13:28:20.00 13:29:10.00 13:30:00.00<br />
Pacific Time<br />
Grand Coulee 1<br />
Grand Coulee 2<br />
John Day<br />
Malin N<br />
Colstrip<br />
Big Eddy 500<br />
Keeler 500 kV<br />
Capt Jack N. Bus<br />
Capt Jack S. Bus<br />
Olinda 500 kV<br />
Summer Lake N. Bus<br />
Summer Lake S. Bus<br />
Slatt W. Bus<br />
Slatt E. Bus<br />
Vincent<br />
Devers 500 kV<br />
24
WECC System Oscillations from<br />
Colstrip controls – October 9, 2003<br />
FFT of power flows at Colstrip Power plant<br />
10/09/03 Event at 13:25 Pacific Time (10/09/03 at 20:25 GMT ) Bandwidth 0 - 1.5<br />
10.00000<br />
0.00000<br />
-10.00000<br />
-20.00000<br />
-30.00000<br />
Broadview 1<br />
Broadview 2<br />
Generator 3<br />
Generator 4<br />
-40.00000<br />
0 0.2490234 0.4980469 0.7470703 0.9960938 1.245117 1.494141<br />
Frequency (Hz)<br />
Most Dominant Mode is 0.583 Hz ; Damping (%) = 0.3 ; Time Const = 96.32 sec<br />
25
WECC System Oscillations from<br />
Colstrip controls – October 9, 2003<br />
Oscillatory modes and their<br />
damping at Colstrip Power plant<br />
26
WECC System Oscillations from<br />
Colstrip controls – October 9, 2003<br />
FFT of power flows at Vincent substation<br />
10/09/03 Event at 13:24 Pacific Time (10/09/03 at 20:24 GMT ) Bandwidth 0 - 1.5<br />
10.00000<br />
0.00000<br />
-10.00000<br />
-20.00000<br />
-30.00000<br />
VC-Midway1<br />
VC-Midway2<br />
VC-Midway3<br />
VC-Lugo1<br />
VC-Lugo2<br />
VC-Pardee<br />
-40.00000<br />
0 0.2490234 0.4980469 0.7470703 0.9960938 1.245117 1.494141<br />
Frequency (Hz)<br />
Most Dominant Mode is 0.583 Hz ; Damping (%) = 0.7 ; Time Const = 44.87 sec<br />
27
WECC System Oscillations from<br />
Colstrip controls – October 9, 2003<br />
Oscillatory modes and their damping<br />
at Vincent substation<br />
28
WECC System Oscillations from<br />
DC Probing Tests- August 7, 2003<br />
Voltage magnitude plots from BPA file<br />
08/07/03 Event at 11:20 Pacific Time (08/07/03 at 18:20 GMT )<br />
562.0<br />
554.0<br />
546.0<br />
538.0<br />
530.0<br />
522.0<br />
11:20:00.00 11:20:50.00 11:21:40.00 11:22:30.00 11:23:20.00 11:24:10.00 11:25:00.00<br />
Pacific Time<br />
Grand Coulee 1<br />
Grand Coulee 2<br />
John Day<br />
Malin N<br />
Colstrip<br />
Big Eddy 500<br />
Keeler 500 kV<br />
Capt Jack N. Bus<br />
Capt Jack S. Bus<br />
Olinda 500 kV<br />
Summer Lake N. Bus<br />
Summer Lake S. Bus<br />
Slatt W. Bus<br />
Slatt E. Bus<br />
Vincent<br />
Devers 500 kV<br />
29
WECC System Oscillations from DC<br />
probing Tests- August 7, 2003<br />
Oscillatory modes and their damping<br />
at Big Eddy 500 kV<br />
30
WECC System Oscillations from<br />
Probe tests – August 7, 2003<br />
FFT of power flows at Big Eddy 500 kV<br />
08/07/03 Event at 11:20 Pacific Time (08/07/03 at 18:20 GMT ) Bandwidth 0.05 - 4.5<br />
10.00000<br />
0.00000<br />
-10.00000<br />
-20.00000<br />
-30.00000<br />
-40.00000<br />
4.394531E-02 0.7836914 1.523438 2.263184 3.00293 3.742676 4.482422<br />
Frequency (Hz)<br />
Celilo 3<br />
Celilo 4<br />
Dalles PH 3<br />
Dalles PH 4<br />
Dalles PH 5<br />
Dalles PH 6<br />
Banks 2&5<br />
Midway 1<br />
Troutdale 1<br />
Most Dominant Mode is 0.217 Hz ; Damping (%) = 14 ; Time Const = 5.3 sec<br />
31
Big Creek system Oscillations under<br />
stressed conditions –<br />
September 13, 2000<br />
Voltage magnitude Plot<br />
09/13/00 Event at 14:44 Pacific Time (09/13/00 at 21:44 GMT )<br />
248.0<br />
238.4<br />
228.8<br />
219.2<br />
209.6<br />
Vincent 230kV<br />
Devers 230kV<br />
Big Creek 230kV<br />
Alamitos 230kV<br />
SO-SCE 230kV<br />
SO-SDGE 230kV<br />
Kramer 230kV<br />
Antelope 220kV<br />
200.0<br />
14:44:25.00 14:45:25.00 14:46:25.00 14:47:25.00 14:48:25.00 14:49:25.00 14:50:25.00<br />
Pacific Time<br />
32
Big Creek system Oscillations under<br />
stressed conditions –<br />
September 13, 2000<br />
FFT Plot of Power Flows at Big Creek<br />
09/13/00 Event at 14:44 Pacific Time (09/13/00 at 21:44 GMT ) Bandwidth 0 - 1.5<br />
10.00000<br />
0.00000<br />
-10.00000<br />
-20.00000<br />
-30.00000<br />
Big Creek2<br />
Rector<br />
Springville<br />
Big Creek4<br />
-40.00000<br />
0 0.2490234 0.4980469 0.7470703 0.9960938 1.245117 1.494141<br />
Frequency (Hz)<br />
Most Dominant Mode is 0.564 Hz ; Damping (%) = 0.6 ; Time Const = 49.66 sec<br />
33
Big Creek system Oscillations under<br />
stressed conditions –<br />
September 13, 2000<br />
Modal Frequencies and Damping<br />
34
Seattle Earthquake - February 28, 2001<br />
at 10:54 AM<br />
Voltage plots for 500 kV<br />
02/28/01 Event at 10:54 Pacific Time (02/28/01 at 18:54 GMT )<br />
553.0<br />
545.4<br />
537.8<br />
530.2<br />
522.6<br />
Grand Coulee<br />
John Day<br />
Malin N<br />
Colstrip<br />
Big Eddy 500<br />
Keeler 500 kV<br />
Vincent<br />
Devers 500 kV<br />
515.0<br />
10:53:12.00 10:53:42.00 10:54:12.00 10:54:42.00 10:55:12.00 10:55:42.00 10:56:12.00<br />
Pacific Time<br />
35
Control sub-system system line fault operation on<br />
June 3, 2005 at 6:20 AM Pacific time<br />
Voltage plots for Control 115 kV<br />
06/03/05 Event at 06:20 Pacific Time (06/03/05 at 13:20 GMT )<br />
121.8<br />
120.5<br />
119.2<br />
117.9<br />
Control<br />
116.6<br />
115.3<br />
06:20:25.00 06:20:55.00 06:21:25.00 06:21:55.00 06:22:25.00 06:22:55.00 06:23:25.00<br />
Pacific Time<br />
36
Control sub-system system line fault operation on<br />
June 3, 2005 at 6:20 AM Pacific time<br />
Power Flows on 115 kV circuits at Control<br />
06/03/05 Event at 06:20 Pacific Time (06/03/05 at 13:20 GMT )<br />
80.0<br />
48.0<br />
16.0<br />
-16.0<br />
CT-Inyo<br />
Haiwee-Inyokern1<br />
Haiwee-Inyokern2<br />
CT-Oxbow<br />
-48.0<br />
-80.0<br />
06:20:25.00 06:20:55.00 06:21:25.00 06:21:55.00 06:22:25.00 06:22:55.00 06:23:25.00<br />
Pacific Time<br />
37
Control sub-system system line fault operation on<br />
June 3, 2005 at 6:20 AM Pacific time<br />
Phase angle plot 115 kV voltages<br />
06/03/05 Event at 06:20 Pacific Time (06/03/05 at 13:20 GMT )<br />
360<br />
345<br />
330<br />
315<br />
300<br />
Kramer 115kV<br />
Devers 115kV<br />
Antelope 66<br />
Valley<br />
Control<br />
285<br />
270<br />
06:20:25.00 06:20:55.00 06:21:25.00 06:21:55.00 06:22:25.00 06:22:55.00 06:23:25.00<br />
Pacific Time<br />
Angle Reference is Valley<br />
38
130<br />
0<br />
Control sub-system system line fault operation on<br />
June 3, 2005 at 6:20 AM Pacific time<br />
Voltage Phase angle replay plots<br />
06/03/05 Event at 06:20 Pacific Time (06/03/05 at 13:20 GMT )<br />
0<br />
330<br />
30<br />
300<br />
60<br />
Kramer 115kV<br />
Devers 115kV<br />
270<br />
90<br />
Antelope 66<br />
Valley<br />
Control<br />
240<br />
120<br />
210<br />
180<br />
150<br />
Angle Reference is Valley<br />
39
Control sub-system system line fault operation on<br />
June 3, 2005 at 6:20 AM Pacific time<br />
Modal Frequencies and Damping<br />
40
Control sub-system system line fault operation on<br />
June 3, 2005 at 06:20 Pacific time<br />
FFT Plot of Power Flows at Control<br />
06/03/05 Event at 06:20 Pacific Time (06/03/05 at 13:20 GMT ) Bandwidth 0 - 1.5<br />
10.00000<br />
2.00000<br />
-6.00000<br />
-14.00000<br />
-22.00000<br />
CT-Inyo<br />
Haiwee-Inyokern1<br />
Haiwee-Inyokern2<br />
CT-Oxbow<br />
-30.00000<br />
0 0.2490234 0.4980469 0.7470703 0.9960938 1.245117 1.494141<br />
Frequency (Hz)<br />
Most Dominant Mode is 0.682 Hz ; Damping (%) = 2.3 ; Time Const = 10.2 sec<br />
41
<strong>Synchronized</strong> <strong>Phasor</strong> <strong>Measurement</strong><br />
Real-time Applications:<br />
Monitoring system stress (Phase angle separations)<br />
Monitoring critical voltage support<br />
Monitoring frequency and df/dt<br />
Monitoring critical line status and outages<br />
Monitoring modal oscillations and modal damping<br />
Monitoring dynamic power swings<br />
Integration with SCADA, EM & State Estimator systems<br />
Real-time control such as on HVDC Modulation and<br />
FACTS devices<br />
Monitoring machine excitation and governors<br />
Voltage and reactive power management<br />
AI and Pattern recognition tools for quick event analysis<br />
42
Real-time <strong>Phasor</strong> <strong>Measurement</strong> system<br />
display developed at SCE<br />
43
Real-time <strong>Phasor</strong> <strong>Measurement</strong> system<br />
display developed at SCE<br />
Power flow on Midway -Vincent lines<br />
44
<strong>Synchronized</strong> <strong>Phasor</strong> <strong>Measurement</strong>s<br />
Conclusions:<br />
<strong>Synchronized</strong> <strong>Phasor</strong> <strong>Measurement</strong><br />
‣ is a maturing and accepted Technology<br />
‣ can provide Real-time system monitoring,<br />
for reliability and post event analysis<br />
‣ can be used for active system component control<br />
like SPS, FACTS, HVDC Modulation etc.<br />
‣ can be integrated with existing SCADA systems<br />
‣ can avoid disturbances like the Northeast-2003<br />
blackouts<br />
Post event data analysis can provide information<br />
on event locations and severity<br />
SCE is working with WECC members and SCE<br />
neighbors like APS, SRP, PG&E , LA DWP and<br />
WAPA etc. for data/information exchange<br />
45
We just can’t afford this !<br />
46
Thank you, any questions ?<br />
47
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