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Synchrophasor Applications
ERCOT STF Meeting, Feb 5, 2014
David Costello
David Costello, P.E.Technical Support DirectorSchweitzer Engineering Laboratories, Inc.Office – 509.334.5741M bil 830 377 9018
li k di /i /d id t ll /
Mobile – 830.377.9018e-mail – [email protected]
www.linkedin.com/in/davidacostello/
http://web.ecs.baylor.edu/faculty/grady/ http://web.ecs.baylor.edu/faculty/grady/ T S h h N t k ht lT S h h N t k ht lTexas_Synchrophasor_Network.htmlTexas_Synchrophasor_Network.html
“The MRI of Power Systems”“The MRI of Power Systems”
NERC l Fl id F b 26 2008NERC press release on Florida outage Feb. 26, 2008:
Synchrophasors are “Like the MRI of bulk power systems,” said Rick Sergel, President of NERC.
120V Wall Outlets Work for Synchrophasors (of course, we would prefer to have three-phase grid PMUs)
McDonald Observatory Voltage Phase Angle w.r.t U.T. Austin 120V and Harris 69kV
-10
Voltage Ringdown at McDonald Observatory Observed at the Following Two Locations in Austin: a 120V Wall Outlet on Campus, and the Harris 69kV Substation that Feeds the Campus
-11
10 seconds
20-second window
-12
Deg
rees w.r.t U.T. Austin
w.r.t Harris 69kV
-13
-141600 1700 1800 1900 2000 2100 2200
Sample (30 samples per second)
• The fixed net multiple of 30 degree phase shift between U.T. Austin 120V and Harris 69kV has been removed. The variable but steady power flow phase shift through the substation transformer has also been removed.
Modal AnalysisModal AnalysisSh S t RSh S t RShows System ResponseShows System Response
p
3
4
5
s Ph A l
Grid response to unit trip gives a measure of stability
0
1
2
Deg
rees McD
PanAm
Phase Angleyvia the normalized damping ratio, zeta
Start Sec Stop Sec A B T1 Tau1 C T2 Tau2 Tdamp Fdamp Zeta53 60 2.36 0.81 54.14 0.32 -1.29 54.55 1.96 1.44 0.696 0.116
Exponential Steady State Transition Curve Damped Sinusoidal Term
-1
U.T. Pan Am Voltage Phase Angle wrt Baylor, Sept. 10, 2013, 04:36 GMT3
ActualC Fit
1
2
egre
es
Curve Fit
1
0
D
Copyright © SEL 2013
-152 53 54 55 56 57 58 59 60 61 62
Second
Tuesday, March 31, 2009, 20 Minute Window Beginning 12:53 AM CDT Surprises. Very Unusual Events Occur and Need Investigation
60.1
Superimposed Frequency Measurements Taken at UT Austin (in black) and McDonald Observatory (in red)
60.0
20-minute window with strange 0.067 Hz oscillation
59.90 2 4 6 8 10 12 14 16 18 20
Cause - Throttle valving problem on generator under test. Slow frequency variation had gone unnoticed.
ERCOT’s graph of West-to-North P flow
This is probably the world’s first electricity market-induced grid oscillation!12 hour window
West to North P flow
Price went down, then wind gens responded, then price went up, then wind gens responded, • • •
McDonald Observatory Voltage Phase Angle Relative to Central ERCOT
40Texas Synchrophasor N k’ h f W
20
30
40
ees
Network’s graph of West-to-Central ERCOT Voltage Angle
-10
0
10
Deg
re
12-hour window
Candidate for Ripley’s Believe It or Not?
-200 1 2 3 4 5 6 7 8 9 10 11 12
Hour of March 11, 2011
12-hour window It or Not?
High Wind Generation Levels Present Challenges for Grids,but ERCOT is Handling Them Well
30
35
ERCOT Wind Gen (Percent of Load)Week Starting 00.00 GMT, Sunday, April 21, 2013
7000
8000
9000
ERCOT Wind MWWeek Starting 00.00 GMT, Sunda
15
20
25
4000
5000
6000
0
5
10
0 1 2 3 4 50
1000
2000
3000
0 1 2 3 40 1 2 3 4 5
Day of Week
50
60
Aust
in
0 1 2 3 4
Day of Week
On April 21, 2013, wind generation dropped from
10
20
30
40D
egre
es w
rt U
T A
• 35% to 4% of total generation,• 8500 MW to 1100 MW,in 12 hours
V lt h l (l dfl00
10
0 24 48 72 96
Hour of the Week, GM
Voltage phase angle (loadflow, short circuit, stability, state estimator), dropped 40° and then rose 45°
Surprises. A 2 Hz Mode in Ambient Oscillation Sometimes Forms with High Wind Generation
Big Wind (20%) with 2 Hz Cluster Small Wind (2%) without 2 Hz Cluster
March 18, 02:00 – 03:00 i d G i 20%
March 12, 02:00 – 03:00
2 Hz
Wind Generation > 20% Wind Generation ≈ 2%
Cluster
42 Major Unit Trips, 0.1 Hz or Greater. Conclusion - No Correlation Between Wind Generation and System Inertia
Estimated System H versus % Wind Generation(42 Unit Trip Events, June through November 2010)
y
6 months
10
12
6
8
imat
ed H
2
4Esti
00 5 10 15 20
Wind Generation - % of Total Generation%
Does Wind Generation Impact Grid Inertia?
EPRI Study. Purpose – to compute ERCOT System Inertia Constant H From Frequency Response During 42 Unit Trips Having 0.1 Hz or Greater Freq. Drop.
smsss PJJH
112
1 2
Drop.
ratedsratedrated PdtdPPH
/22
fPfPP smsmsm 21 dtdfP
fPdtdf
fP
PdtdP
PHsrated
sm
s
s
rated
m
s
s
rated
m/2/2
22/2
1
H has the units of seconds. The correct interpretation is that the kinetic energy in the equivalent system machine corresponds to H seconds of rated power. Thus, the machine could provide rated power for H seconds, at which time it would have spun down to zero RPMtime it would have spun down to zero RPM.
Select A DisturbanceSelect A Disturbance
776 MW Generator Tripped*776 MW Generator Tripped*
RealReal--Time PTime Pmm –– PPee CalculationCalculation
Measure Frequency ChangeMeasure Frequency Change
FrequencyFrequency Changes by 0.12
Hz
Measure Time ChangeMeasure Time Change
Ti Ch bTime Changes by 3 seconds
df/dt Calculationdf/dt Calculation
df/dt = 0.12/3
This is 40 mHz / dsecond
Estimated Generation LostEstimated Generation Lost
• df/dt = -40 milliHz/second
H 9 d• H = 9 seconds
• VAbase = 60 GWbase
• fnom = 60 Hz
• Pm – Pe = 720 MW
Already Installed PMUAlready Installed PMU--Capable SEL Capable SEL D i i E h G idD i i E h G idDevices in Each GridDevices in Each Grid
Developing Synchrophasor Solutions Developing Synchrophasor Solutions f O D df O D dfor Over a Decadefor Over a Decade
ries)
lys ys
y (SEL-
400 S
erie
er Web za
tion +
Con
trol
00 S
eries
Rela
ys
oces
sor
Clients
PDCs
00 S
eries
Rela
ys
E®
haso
rs in
a Rela
y
haso
rs in
a Mete
r
haso
rs on
the W
e
ocol
in a R
elay
ynch
roph
asor
s
PDCeiv
es S
ynch
roniz
a
haso
rs in
SEL-30
haso
r Vec
tor P
roc
ports
C37
.118 C
ation
Arch
iving
P
RAdd
s PMU
ntra
l
haso
rs in
SEL-70
RS Add
s PMU
Adds P
MU
d SYNCHROWAVE
hanc
emen
ts
Synch
roph
aSyn
chro
pha
Synch
roph
aIE
EE Pro
toc
SCADA Syn
Hardw
are P
PMU Rec
eiv
Synch
roph
a
Synch
roph
aRTA
C Sup
p2n
d Gen
era
SEL-65
1R A
Cent
Synch
roph
aSEL-
351R
SSEL-
2431
A
PDC and S
Centra
l Enh
a
’02 ’03 ’06 ’07’05 ’08 ’09 ’10 ’11 ’12 ’13
These solutions are in service today, worldwide
SEL Synchrophasor Building BlocksSEL Synchrophasor Building BlocksPh M t U itPh M t U itPhasor Measurement UnitsPhasor Measurement Units
SEL-751
SEL Synchrophasor Building BlocksSEL Synchrophasor Building Blocks
https://www.selinc.com/synchrophasors/https://www.selinc.com/synchrophasors/
PMU SnapshotsPMU Snapshots
Easily Identify ErrorsEasily Identify Errors
Check CT Polarities, Phasing, and RatioCheck CT Polarities, Phasing, and Ratio
Find Problems Find Problems With PT CVTWith PT CVTWith PTs, CVTs With PTs, CVTs
and CTsand CTs• Discover loose
connections inconnections in potential circuits
• Detect CVT drift and future failure
• Prevent future outages andoutages and misoperations
Samples Time Stamped +/Samples Time Stamped +/-- 5 5 microsecmicrosec
NERC PRCNERC PRC--002002--2 2 Di t b R diDi t b R diDisturbance RecordingDisturbance Recording
SEL-3354
SEL-487E
SEL-2401
Advanced Event AnalysisAdvanced Event Analysis
Improve Understanding of EventsImprove Understanding of EventsE lE l 10 23 J l 14 201210 23 J l 14 2012Example Example –– 10:23 p.m. July 14, 201210:23 p.m. July 14, 2012
Improper relaying on Grizzly-Ponderosa 500 kVp p y g y
Eastern Interconnection Transient Eastern Interconnection Transient 3 06 48 J l 21 20123 06 48 J l 21 20123:06:48 a.m. July 21, 20123:06:48 a.m. July 21, 2012
Generator TripGenerator Trip9 21 00 M 14 20129 21 00 M 14 20129:21:00 a.m. May 14, 2012 9:21:00 a.m. May 14, 2012
500 kV DC Line Trip 500 kV DC Line Trip A il 20 2012A il 20 2012April 20, 2012April 20, 2012
750 MW Generation Trip750 MW Generation TripJ l 8 2012J l 8 2012July 8, 2012 July 8, 2012
WideWide--Area VisualizationArea Visualization
Get Instant Feedback After Get Instant Feedback After S t ChS t ChSystem ChangesSystem Changes
Distribution Planning and ImprovementDistribution Planning and ImprovementE lE lExampleExample
Detection of loose fuse caps, ploose connections at safety switch or terminal
cabinets, and animal damage to wiring
Study the Impact of RenewablesStudy the Impact of RenewablesE lE l 7 13 J 7 20127 13 J 7 2012Example Example –– 7:13 a.m. January 7, 20127:13 a.m. January 7, 2012Sudden high frequency oscillation – cause g q y
under investigation (an inverter?)
See Information That SCADA MissesSee Information That SCADA Misses
Wind Farm
Dip
Oscillations
Vol
tage
DP
erce
nt
System Reconnection and RestorationSystem Reconnection and RestorationE lE lExampleExample
Frequencies of three islanded systemsq y
Analyze Analyze thethethe the
CommunicaCommunica--tionstions NetworkNetwork
Model VerificationModel VerificationE lE lExampleExample
Observe inertia (H) from generation rejection event( ) g j
System SettingsSystem SettingsE lE l J 18 2012J 18 2012Example Example –– January 18, 2012January 18, 2012
Modal analysis shows marginal damping prior to unusual system events led to power systemprior to unusual system events, led to power system
stabilizer settings changes
AntiAnti--Islanding ExampleIslanding Example
• Implemented with Florida Power & Light
• Required for IEEE 1547
• Must disconnect DG within 2 seconds• Must disconnect DG within 2 seconds
• Options include♦ Transfer trip
♦ Vector shift♦ Vector shift
♦ Injected signal
Architecture With SynchrophasorsArchitecture With Synchrophasors
WideWide--Area IDS Uses Slip and Area IDS Uses Slip and A l ti f I l di D t tiA l ti f I l di D t tiAcceleration for Islanding DetectionAcceleration for Islanding Detection
WideWide--Area IDS Detects Islanding During Area IDS Detects Islanding During Mi i l P E h C ditiMi i l P E h C ditiMinimal Power Exchange ConditionsMinimal Power Exchange Conditions
1(DG)
1(RMT-SRC)
• Synchrophasor data are sent from the DG y pand remote source
• SVP time aligns and makes coherent data• SVP time-aligns and makes coherent data available to logic
Responsive to All ConditionsResponsive to All Conditions
Responsive to All ConditionsResponsive to All Conditionson
dsS
eco
Big Creek Controls Rector Big Creek Controls Rector Static VAR CompensatorStatic VAR CompensatorStatic VAR CompensatorStatic VAR Compensator
ClosedClosed--Loop Control at Big Creek Loop Control at Big Creek St bili V ltSt bili V ltStabilizes VoltageStabilizes Voltage
244 50
242
240
0
238
236
–50BC 3 MaxBC 3 MinR t A
BC 3 Average
236
234
Rector AverageRector MaxRector MinSVC Average Output
–100
232
230
–150
228 –200
Transient Stability Transient Stability C t lC t lControlControl
CFE Mexico
CFE AGSS SystemCFE AGSS System
Angostura (ANG)
Sabino (SSB)
Chicoasen (MMT)
Simple Synchrophasor Simple Synchrophasor G tG t Sh ddi L iSh ddi L iGeneratorGenerator--Shedding LogicShedding Logic
WideWide--Area Protection at Relay SpeedsArea Protection at Relay Speeds
230 kV Backbone Connects Countries 230 kV Backbone Connects Countries F G t l t PF G t l t PFrom Guatemala to PanamaFrom Guatemala to Panama
Guatemala Wheels Power From Guatemala Wheels Power From M i t C t l A iM i t C t l A iMexico to Central AmericaMexico to Central America
Supplementary Control Scheme (SCS) Supplementary Control Scheme (SCS) T i I t ti t El S l dT i I t ti t El S l dTrips Interconnection to El SalvadorTrips Interconnection to El Salvador
Oscillation Stability Assessment With Oscillation Stability Assessment With R lti C t l A ti Di l dR lti C t l A ti Di l dResulting Control Action Displayed Resulting Control Action Displayed
Traditional Control to Isolate LineTraditional Control to Isolate Line
Master Control
230 kV 206 kVBus 1 Bus 2
224 kV 224 kV230 kV 206 kV224 kV 224 kV
Tap Down Close Capacitor
Traditional Method Causes DisturbancesTraditional Method Causes Disturbances
TimeTime--Synchronized Control in ActionSynchronized Control in Action
Synchronous Control to Isolate LineSynchronous Control to Isolate Line
Master ControlLocal Local
Control Control
Execute Recipe Simultaneously
Bus 1 Bus 2224 kV 224 kV
T DTap Down Close Capacitor
Recipe Method Minimizes ImpactRecipe Method Minimizes Impact
Directly Measure the State Directly Measure the State
MasterSynchronized Data
V1
V2Master Data . . .
Vn
• Detect bad dataSub 1 Sub n• Average
measurements
D t i t l
RTAC . . . SVP
V • Determine topology
• Calculate V at adjacent stations:
V1
Vn adjacent stations:V’ = V + ZI
SRP Operator Closes Tie Based on Synchrophasors, 2004
What if I Have Multiple Tie Points?What if I Have Multiple Tie Points?
Refinery Selects From 5 Breakers
Utilities Are Operating Closer to the EdgeUtilities Are Operating Closer to the EdgeMargin
Margin
1 01.0
Operating
Point
BifurcationPoint
0.5
1.0 1.3 1.5 1.7PU Nominal Load0.0
Long Island: Monitor Angles Between Long Island: Monitor Angles Between Transmission Distribution Buses toTransmission Distribution Buses toTransmission Distribution Buses to Transmission Distribution Buses to Detect & Prevent Voltage CollapseDetect & Prevent Voltage Collapse
Vr
ZL = R + jXVS 0Vr
S = P + jQ
V)θsin(1S2
s X)θcos(2V)θsin(1S 2
smax
MAKING ELECTRIC POWER SAFE POWER SAFE, RELIABLE, AND ECONOMICAL FOR ECONOMICAL FOR 30 YEARS