📄 sx.ras
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* *
* *
* Voltage Security Assessment Tool *
* (V S A T) *
* *
* Remedial Action (Sensitivity Method) *
* *
* Version 5.1 Release 15/05/05 *
* *
* Developed and maintained by *
* Powertech Labs Inc. *
* 12388 - 88TH Avenue *
* Surrey, British Columbia *
* Canada V3W 7R7 *
* *
* Copyright BC Hydro *
* All rights reserved *
* *
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RUN TIME: 07-JUN-05 14:34:36
1
Data file names read from the Scenario file: _temp_sx.snr
Scenario description:
BCH 1400-bus case: East transfer limit
End of description
PFB file= "_temp_sx.psn"
Parameter file= "t.prm"
Transfer file= "t-x.trf"
Criteria file= "t.crt"
Monitored Variable file= "t.mon"
Margin file= "t.mrg"
Contingency file= "t-x.ctg"
Interface and Circuit file= "t.itf"
Remedial Control file= "t.rmc"
Sensitivity Parameter file= "t.spr"
PFB (base power flow) file: _temp_sx.psn
Base powerflow case:
Test Case A
FROM VSAT: Point no. 8
Created/modified on: 07-JUN-05 14:34:36
Buses 1397
Areas 5
Zones 35
Generating units 233
Loads 604
Fixed shunts 390
Switched shunts / SVCs 150
Lines 1512
Fixed transformers 398
Adjustable transformers 383
Three winding transformers 0
Fixed series compensators 0
Adjustable series comp. 0
Static tap-ch./phase-reg. 0
DC records 14
1
Parameter file: t.prm
Transfer analysis = To Limit
Contingency analysis = To first insecure
Generation dispatch for contingencies = None
VQ curve interval = 0
Modal Analysis = F
Convert load models = F
Use generator capability curves = F
Check branch flows = F
Line rating no. = 0
Transformer rating no. = 0
Post-contingency line rating no. = 0
Post-contingency transformer rating no. = 0
Threshold for flow check = 0.0 %
Threshold for post-contingency flow check = 0.0 %
Exclude branches below kV level = -1.0
Limit generator VArs = Always
Remote control by generators = Always
Adjust ULTCS for voltage control = In Pre-Contingency
Adjust ULTCS for MVAr flow control = Never
Adjust phase-shifters for MW flow control = Never
Adjust static tap-changers for voltage control = Never
Adjust static tap-changers for MVar control = Never
Adjust static phase-shifters for MW control = Never
Adjust static series compensators = Never
Adjust SVC / continuous switched shunts = Always
Adjust discrete switched shunts = Never
Adjust area interchanges = Never
Maximum iterations for PF solution = 90
Convergence tolerance for PF solution = 1.00 MW
Acceleration for PV bus voltage = 0.90
Tolerance for PV bus voltage = 0.10E-3
Blow up voltage = 1.000
Maximum iterations for adjustments = 70
Adjustments threshold = 0.0100
Low impedance threshold = 0.10E-3
Shunt voltage band threshold = 0.10E-1
FDPF solution method = 1
Report bus information = F
Report generator information = F
Report VAr-limited generator information = F
Report interface flows = F
Report circuit flows = F
Report branch flows = F
Report adjusted transformers for voltage control = F
Report transformers for flow control = F
Report static tap-changers/phase-shifters = F
Report series compensators = F
Report adjusted switchable shunts = F
Report area interchange information = F
Report AGC information = F
Report DC network solutions = None
Name option = No
Flat start = F
Show ULTC adjustments during PF solution = T
Voltage correction tolerance for base case = 0.9000
Output volume = 0
1
Criteria file: t.crt
Criteria description:
7% voltage decline in area 1
12% Q reserve in each of zones 1, 4, 5, 6
10% Q reserve in zone 30
15 MVAr reserve in SVC
End of description
Criteria name= Criteria
Voltage criteria group 1:
Decline limit = 0.07000
Rise limit = 0.99000
Include area= 1
Number of buses: 860
VAr reserve criteria group 1:
Reserve limit = 12.00 %
Include generators of zone = 1
Number of gen. units: 10
Number of shunt units: 0
VAr reserve criteria group 2:
Reserve limit = 12.00 %
Include generators of zone = 4
Number of gen. units: 17
Number of shunt units: 0
VAr reserve criteria group 3:
Reserve limit = 12.00 %
Include generators of zone = 5
Number of gen. units: 15
Number of shunt units: 0
VAr reserve criteria group 4:
Reserve limit = 12.00 %
Include generators of zone = 6
Number of gen. units: 15
Number of shunt units: 0
VAr reserve criteria group 5:
Reserve limit = 10.00 %
Include generators of zone = 30
Number of gen. units: 9
Number of shunt units: 0
VAr reserve criteria group 6:
Reserve limit = 15.00 MVAr
Include variable shunts of bus = 2816
Number of gen. units: 0
Number of shunt units: 1
Margin file: t.mrg
Margin description:
200 MW load/gen increase in area 1
End of description
Margin name= 200MW LD
Load scale group 1:
Scale load= P and Q
Increase by= 200.00 MW/MVAr
Include area= 1
Number of loads: 291
Initial MW load: 7917.39
Initial MVAR load: 3823.39
Generation scale group 2:
Increase by= 200.00 MW
Include area= 1
Number of generators: 101
Initial MW generation: 8269.11
Contingency file: t-x.ctg
7 Contingencies:
CC41 CC42 CC81 CC82 CC87
A 4 A 8
1
Remedial Control data file: t.rmc
Remedial Control description:
Switch shunts and shed load
End of description
Remedial Control name= Sh,Ld
Control generator voltage settings= No
Control SVC/shunt voltage settings= No
Control switchable shunts= Yes
Control transformer tap settings= No
Control load shedding= Yes
Switchable shunt control:
Priority= 2
Control Mode= Preventive and Corrective
Include bus= 1300:2000
Load shedding control:
Load shedding group name= LSG 1
Priority= 5
Include area= 1
Load Shedding Percentage= 3.00 5.00 10.00 20.00
1
Sensitivity Parameter file: t.spr
Remedy margin violations= Yes
Remedy voltage violations= Yes
Remedy VAr reserve violations= Yes
Apply corrective control= Yes
Voltage setting upper limit= 1.15000
Voltage setting lower limit= 0.85000
Threshold for load sensitivity= 0.00001
Threshold for shunt sensitivity= 0.00001
Threshold for tap sensitivity= 0.00001
Threshold for voltage sensitivity= 0.00001
Threshold for voltage improvement= 0.00010
Maximum trials for ineffective controls= 3
Step size for contingency parameter= 0.03000
Step size for stress= 5.00 %
Weighting factor for shunt sensitivity= 0.5000 1/MVAr
Weighting factor for tap sensitivity= 0.0100
Weighting factor for voltage sensitivity= 0.0100
#Notice# Generater Group file is not specified
Number of low-impedance lines (Z< 0.00010) : 5
Number of increased reactances (X= 0.00010) : 0
Reduced number of buses : 1311
Ordering the matrix
>> Starting Preventive Control
>> Solving the base powerflow
Pre-contingency
===============
Load flow solved in 3 iterations
>> Checking generator voltages after solving the base powerflow
Pre-contingency
===============
Load flow solved in 2 iterations
>> Making pre-stress contingency cases solve
>> Continuation parameter: -0.00300
Contingency CC41
====================
Load flow solved in 8 iterations
Contingency CC42
====================
Load flow solved in 14 iterations
Contingency CC81
====================
Load flow solved in 13 iterations
Contingency CC82
====================
Load flow solved in 15 iterations
Contingency CC87
====================
Load flow solved in 7 iterations
Contingency A 4
====================
Load flow solved in 14 iterations
Contingency A 8
====================
Load flow solved in 14 iterations
>> Controls succeeded in solving the contingencies before stress
>> Removing voltage violations
Pre-contingency
===============
Load flow solved in 2 iterations
Contingency CC41
====================
Load flow solved in 8 iterations
Contingency CC42
====================
Load flow solved in 13 iterations
Contingency CC81
====================
Load flow solved in 13 iterations
Contingency CC82
====================
Load flow solved in 14 iterations
Contingency CC87
====================
Load flow solved in 6 iterations
Contingency A 4
====================
Load flow solved in 13 iterations
Contingency A 8
====================
Load flow solved in 14 iterations
>> All contingency cases before stress are solved
Controls succeeded in removing voltage violations
>> Removing stability margin violations
>> Stress level: 102.00 %
Pre-contingency
===============
Load flow solved in 8 iterations
Contingency CC41
====================
Load flow solved in 25 iterations
Contingency CC42
====================
** Solution diverged after 10 iterations **
Contingency CC81
====================
** Solution diverged after 12 iterations **
Contingency CC82
====================
** Solution diverged after 10 iterations **
Contingency CC87
====================
Load flow solved in 7 iterations
Contingency A 4
====================
** Solution diverged after 10 iterations **
Contingency A 8
====================
** Solution diverged after 10 iterations **
>> Stress level: 51.00 %
Pre-contingency
===============
Load flow solved in 8 iterations
Contingency CC42
====================
** Solution diverged after 19 iterations **
Contingency CC81
====================
** Solution diverged after 36 iterations **
Contingency CC82
====================
** Solution diverged after 20 iterations **
Contingency A 4
====================
** Solution diverged after 19 iterations **
Contingency A 8
====================
** Solution diverged after 20 iterations **
>> Stress level: 25.50 %
Pre-contingency
===============
Load flow solved in 6 iterations
Contingency CC42
====================
Load flow solved in 16 iterations
Contingency CC81
====================
Load flow solved in 16 iterations
Contingency CC82
====================
Load flow solved in 19 iterations
Contingency A 4
====================
Load flow solved in 17 iterations
Contingency A 8
====================
Load flow solved in 19 iterations
>> Stress level: 38.25 %
Pre-contingency
===============
Load flow solved in 6 iterations
Contingency CC42
====================
** Solution diverged after 39 iterations **
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