Post on 12-Oct-2020
Copyright © SEL 2008
Synchrophasor-Based Monitoring, Analysis, and Control
Roy Moxley Schweitzer Engineering Laboratories, Inc.
The Power System Is Changing
Photo Courtesy of Shawn Jacobs, OG&E
‘02 ’03 8/03 ‘05 ‘06 ’06 ’07 ’07+
Synch
roph
asor
s in a
Mete
r
Synch
roph
asor
s on t
he W
eb
IEEE P
rotoc
ol in
a Rela
y
Synch
roph
asor
s in a
Rela
y
Retrofi
t Syn
chro
phas
ors
In a R
elay
Utility
Grade
PDC
SCADA Syn
chro
phas
ors
Real-T
ime C
ontro
l in
a Rela
y (Mex
ico)
SEL Synchrophasor Vision
0
5
10
15
20
25
AG10AB10BCG10ABC10
AG50AB50BCG50ABC50
AG80AB80BCG80ABC80
AG90AB90BCG90ABC90
Fault Type and Distance
Tim
e (m
s)
Local side trip times WITHOUT synchrophasors Local side trip times WITH synchrophasors
Real-T
ime V
ecto
r
Proce
ssor
Synchrophasors Are StandardSEL-421
IEEE C37.118
SEL-451SEL-487ESEL-787SEL-734 SEL Fast Message
SEL-311A, B, CSEL-311LSEL-351SEL-351SSEL-351A
Protection AND Synchrophasors
0
5
10
15
20
25
AG90AB90BCG90ABC90
AG50AB50BCG50ABC50
AG20AB20BCG20ABC20
AG10AB10BCG10ABC10
Fault Type and Distance
Tim
e (m
s)
Remote side trip times WITHOUT synchrophasors Remote side trip times WITH synchrophasors
0
5
10
15
20
25
AG10AB10BCG10ABC10
AG50AB50BCG50ABC50
AG80AB80BCG80ABC80
AG90AB90BCG90ABC90
Fault Type and Distance
Tim
e (m
s)
Local side trip times WITHOUT synchrophasors Local side trip times WITH synchrophasors
Synchrophasors do not hurt relay performance
Relaying Has No Impact on PMCU Function
No lostdata
4 4.1 4.2 4.3 4.4 4.5 4.6 4.7 4.8 4.90
1
2
3
Local bus side phase A voltage synchrophasorSynchrophasor data check
Time (s)
Relays Are Right for Synchrophasors
Phasor measurement and control unit(PMCU) ≥ PMU
Minimal incremental cost
Reduced current and voltage connections
High-accuracy measurements
High reliability and availability
Future control applications
Relays are everywhere
SEL Synchrophasor Equipped Devices Worldwide !
North AmericaNorth America>20,000 units>20,000 units
South AmericaSouth America>2,000 units>2,000 units
Europe/AsiaEurope/Asia>3,000 units>3,000 units
Africa/Middle EastAfrica/Middle East>1,000 units>1,000 units
Asia Asia PacificPacific
>5,000 units>5,000 units
Application Options – Not “One Size Fits All”
SEL-5078 Visualization
SEL-5077, SEL-5078 Archiving
System Operator, Reliability Council
SEL-3306 Hardware PDC SEL-5077 Software PDC
SEL-3378 Vector Processor
PMU’s
Protection and Control Time Frame
~1.0 Second ~30 Seconds
Relay Action Human ActionControl Action
METER PM 13:22
Monitor a Gen Drop Test (New Zealand)
49.1
49.3
49.5
49.7
49.9
50.1
50.3
Timestamp 5/3/2007 3:10:18.6805/3/2007 3:11:06.6805/3/2007 3:11:54.6805/3/2007 3:12:42.6805/3/2007 3:13:30.6805/3/2007 3:14:18.6805/3/2007 3:15:06.680
Whakamaru_Frequency Huntly_Frequency
Test Shows System Remains Stable When 400 MW Dropped
Frequency recordings at both ends perfectly overlap and align in time.
Malin – Round Mt. 500 kV Trips June 18, 2007
“The MRI of Power Systems”
NERC press release on Florida outage
Feb. 26, 2008:
Synchrophasors are “Like the MRI of bulk power
systems”
Synchrophasor-Based Control – Now a Reality
Big Creek Controls Rector Static VAR Compensator
SCE Uses C37.118 From Relays and PMU
SCADAMaster
DNP3
IEEE C37.118
InformationProcessor
(Harris 5000/6000, IEC 60870-103, Modbus, SEL Fast Message, SES 92, Telegyr 8979, Conitel 2020, GETAC, Recon 1.1, CoDeSys, OPC, …)
Impact of the Rector SVC: 6-14-07 (pre-SVC) vs. 8-30-07 (post-SVC)
Magunden Substation Voltage Comparison(Rector Substation Events 6-14-07 and 8-30-07)
220
222
224
226
228
230
232
234
236
238
240
-5.00 0.00 5.00 10.00 15.00 20.00 25.00
Time (seconds)
Mag
unde
n Vo
ltage
(kV)
Rector 8-30-2007 event (POST-SVC) Rector 6-14-2007 event (PRE-SVC)
The Rector SVC had the apparent effect of reducing the magnitude & duration of the fault-induced slow voltage
recovery…
6-14-2007 (pre-SVC)
8-30-2007 (post-SVC)
NOTE: Voltages shown were measured ~70 miles south of Rector Substation (actual low voltage event was of greater
magnitude at Rector substation itself)
Effect of SVC Operation on Big Creek Before -
Effect of SVC Operation on Big Creek After -
Synchronous Vector ProcessingSystem
MeasurementFunction
CalculationOutput
Designation
Send Control to System(Application)
f(x)
Apply the
Collect synchronous phasor measurements
Collect logical inputs
Perform vector and scalar math
Make decisions
Produce outputs
Report data
Select Quantities From Each PMU
PMU1PMU2PMU3
Analogs| V1 |∠V1
| I1 |∠I1
FreqPSV42TE (time error)
Binary dataStatusTriggers
Integrate Wide-Area Protection and Control
Static Var Control
SEL-421
SEL-421
SEL-421
Apply Flexible Function Calculations
IEC 61131 engineMathTrigDifferentials
Preprogrammed blocksPowerAngle differenceModal analysisStation topology check
Combine Pre-Configured with Custom Functions
Provides Function Blocks
Map PMU Quantities to Phase Angle Difference Monitor
Improve Local Measurements
V A
Substation State and Topology Processor
Refined Is, Vs, Alarms,
and Topology52
52
52
52 52 52
Identify and Quarantine Bad Data
Measurements Measurements+
Calculate Median
Measurements+
Calculate Median+
Flag and Quarantine
Set Flag
Line Trip…Stable
System Separation
Line Trip and Generation
Loss…Unstable
Real-Time Modal Analysis Monitor Predicts System Disturbances
Use Oscillation Frequency and Damping Ratio
For the complex Eigen value pair:
Oscillation frequency is:
Damping ratio is:
djω±σ=λ
πω
=2
f dosc
d
i
ωσσς+
=2
–2
Modal Analysis Shows System Response
Develop Custom ApplicationsVoltage Collapse Detection
Instability of Distributed Generation
Complex Power Swings
Others ?
Operating Point
Bifurcation Point
Utilities Are Operating Closer to the Edge
PU Nominal Load
Operating Point
Bifurcation Point
MarginMargin
1.61.51.31.00.0
0.5
1.0
Long Island: Monitor Angles Between Transmission Distribution Buses to Detect and Prevent Voltage Collapse
( )X)θcos(2V)θsin(1S 2
2s
max−=
S = P + jQ
ZL = R + jX
δ∠rV
0VS ∠
Calculate Voltage Stability Index (VSI)
SVP calculates maxima: P, Q, and S
Calculate margins:
QQQ maxmargin −=
⎟⎠
⎞⎜⎝
⎛=
max
margin
max
margin
max
margin
SS
,PP
minVSI
PPP maxginmar −=
SSS maxmargin −=
Improve Power Swing Detection
Actual Swing from 2003 Blackout
Wide-Area Measurement Is Better than Traditional “Blinder” Methods
Impedance Loci
Wide-Area Measurement
Replace and improve on local out of step
What if load or source impedance changes?
Delta/Delta-Dot Phase Plane Analysis
-20 0 20 40 60 80 100 120 140 160 180-200
-100
0
100
200
300
400
500
Angle Difference δ (deg)
Slip
(de
g/se
c)
Delta-Dot Delta-Doubledot Phase Plane
0 0.5 1 1.5 2 2.5 3 3.5 4-40
-30
-20
-10
0
10
20
30
40
Slip (Hz)
Acc
eler
atio
n (H
z/se
c)
Use Fast Operate Control Blocks for Closed-Loop Control
Synchrophasors Are StandardSEL-421
IEEE C37.118
SEL-451SEL-487ESEL-787SEL-734 SEL Fast Message
SEL-311A, B, CSEL-311LSEL-351SEL-351SSEL-351A
Synchrophasors Provide New and Improved Capabilities
Angle measurement
Disturbance analysis
Modal analysis
Out-of-step detection
Real-time control
What Else Can They Do For You?
Thank You!Thank You!