chas sin
TRANSCRIPT
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6Nov98
Power System Dynamics Analysis
Complexity in the WSCC
August 10, 1996 System Disturbance
David P. Chassin, October 16, 2002
Contact: [email protected]
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August 1996 West Coast BlackoutSummary of Events
WSCC 8-10-96 15:48 PAST major disturbance
4 islands, 7.5M customers out up to 9 hours
Initiating event: 500 kV Keeler-Allston flashover to trees
Trip cause: poor right-of-way maintenance Numerous supporting events
Follow-up events
COI limit lowered to 3200 MW (Aug 11)
Account for limits at McNary (exciter) and The Dalles (fish) Raised Aug 12-14 to 3600 MW to avoid blackouts in CA
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PNNL and Power Systems
DOE Transmission Reliability Program Real-Time Grid Reliability Management
Reliability and Markets, Load as a Resource
Distributed Energy Resources Integration
Infrastructure Assurance Outreach Program Utility vulnerability assessments
Interaction with NERC, others on security topics
Interest in SCADA security
Energy System Transformation Initiative Integrated econophysics modeling and simulation
Next generation power technology development
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Wide-Area Measurement SystemDynamic monitor network supports advanced
analysis
Better information supports better
- and faster - decisions.
System planning
Observedresponse
Power
System
Unobservedresponse
Information
Automatic control
System operation
Disturbances
DecisionProcesses
Measurement
Based
Information
System
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Real-Time System DataCollected from various monitors throughout the grid
Bonneville Power Administration Phasor Data Concentrator
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Power System Measurement ToolsTools for managing data & signal analysis
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Ringdown Analysis ToolAdvanced dynamic analysis
model fitting w indow
Time in Seconds
165 170 175 180
Malin MW
Unfiltered signals
Brake insertion #2, 09/04/97(Alberta strong ly connected)
Reference time 09-04-97 23H42m35s
PACI Mode: 0.294 Hz @ 5.3% dampingAlberta : 0.418 Hz @ 5.1% damping
900
1000
1100
1200
Data collected on Dittmer P PSMsample rate = 60/second
Extracting a linear modelfrom measured data
Dynamic analysis
Model validation
Control design
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Advanced Dynamic SystemAnalysis and Model Validation
4000
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4600
0 10 20 30 40 50 60 70 80 90
4000
4200
4400
4600
Time in Seconds
Simulated COI Power (initial WSCC base case)
Observed COI Power (Dittmer Control Center)
August 10, 1996 post-disturbance analysis
Determine if model
calibration is needed.
Currently working with western utilities to improve power grid models
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Abstract
Transactive
Machine
Power System Econophysics
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Quantity (MWh/h)
Pro
ba
bility
0%
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$10 $100 $1,000
Price ($/MWh)
Pro
ba
bility
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$1,000
20000 30000 40000 50000
Quantity (MWh/h)
Price($
/MWh)
Controlprocess
State m
Thermodynamicprocess
State x
Qwaste
Qin
QoutCin
Cout
Cprofit
control
data
85.026.12
2
3
2
85.02
6.14
Q
eQ
QPPJM 1999 Load/Price Probability Distributions
Q= Qmax (11/P2)4.54
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Overview of WSCC August 10, 1996
15:48 PAST Disturbance
Based on WSCC Disturbance Report
Approved by WSCC OperationsCommittee on October 18, 1996
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High northwest transmission loading
High imports to CA
Heavy imports from Canadaand Idaho
COI at 4750 MW
Similar to conditions prior to7/2/96 disturbance
Warning signs visible
Previous high-load issues
Small power/large voltageswings
Suggested voltage supportproblems in NW
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Equipment out of service
Lines 500 kV: Big Eddy-Ostrander,
John Day-Marion, and Marion-Lane (reactive support aroundPortland) flashover to trees
115 kV: Allston-Rainer degraded
hdwr, Longview-Lexington cableinstallation.
Breakers 500 kV: Marion, Keeler
(modifications)
Transformers
500/230 kV: Keeler (modification)Static VAR Comp (SVC) Keeler reduced support to
500 kV(tied to 230 kV side)
xxx
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Triggering Events
15:42:37 Keller-Allston Sags into trees, flashes, trips Overload par-lines hold 5 min McNary react-power at max
15:47:29 St. Johns-Merwin Lines trip on relay malfunc.
KA par-line loads increase15:47:36 Ross-Lexington Tree flashover and trip 207 MW from Swift lost System voltage sags
15:47:36 McNary Units trip, exciter problem
System power/voltage osc. beginsID-UT-CO-AZ-NM-NV Surge COI power flows down east side Out-of-step trips CA-AZ remain tied together
! ! !
!
!
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Final Result
28,000 MW of under-frequency load shedding20,000 MW of undesired generation lossFour major islands Northern California (North of LA to Oregon border)
Losses: 11,600 MW load; 7,900 MW generation Frequency excursions: 58.5460.758.3, restored in 2.5 hrs.
Southern California (SoCal, NV, AZ, NM, El Paso, Baja) Losses: 15 820 MW load; 13,500 MW generation Frequency excursions: 61.358.5, restored in 70 min.
Northern (BC, OR, WA, MT, WY, ID) Losses: 2,100 MW load; 5,700 MW generation Frequency excursions: 60.4, restored in 7 minutes
Alberta Losses: 970 MW load; 146 MW generation Frequency excursions: 60.459.0, restored in 6 minutes
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Open Questions re. Complexity
Report only identifies the incontrovertible pointsand fails to address more controversial questions: Why was line maintenance inadequate?
Why was system operated in single-contingency mode?
Why did AZ-CA separation scheme fail to operate? Why did models fail to predict oscillations?
Why did system damping fail?
Lesson for us: Dont go just by the official reports. Much more is not
reported or discussed because of sensitivities. Thesocial dynamics of a tightly knit community factors intowhat is knowable. We have to look deeper.
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Problems PersistWECC Oct 8 2002 15:31 PDT
59.550
59.600
59.650
59.700
59.750
59.800
59.850
59.900
59.950
60.000
60.050
22:3
0:4
3.2
0GMT
22:3
0:5
1.8
4GMT
22:3
1:0
0.4
8GMT
22:3
1:0
9.1
2GMT
22:3
1:1
7.7
6GMT
22:3
1:2
6.4
0GMT
22:3
1:3
5.0
4GMT
22:3
1:4
3.6
8GMT
22:3
1:5
2.3
2GMT
22:3
2:0
0.9
6GMT
22:3
2:0
9.6
0GMT
Time
Freq
2900 MW generation tripped
1400 MW Chief Joe brake inserted
~86 MW UFLS
~350 MW load loss
480 MW generation dropped
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Questions and Comments