📄 sz.prg
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*********************************************************
* *
* *
* Voltage Security Assessment Tool *
* (V S A T) *
* *
* Security / Transfer Limit Computation *
* *
* 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 *
* *
*********************************************************
RUN TIME: 07-JUN-05 11:12:07
1
Data file names read from the Scenario file: t-z.snr
Scenario description:
BCH 1400-bus case: East + North export limit
End of description
PFB file= "tc1.pfb"
Parameter file= "t.prm"
Transfer file= "t-z.trf"
Criteria file= "t.crt"
Monitored Variable file= "t.mon"
Margin file= "t.mrg"
Contingency file= "t-z.ctg"
Interface and Circuit file= "t.itf"
PFB (base power flow) file: tc1.pfb
Base powerflow case:
Test Case A
Created/modified on: 28-APR-05 13:16:20
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
Interface file: t.itf
Interfaces
--------------------------------------------------------------------------------------
Interface name No. < From bus > Name No. < To bus > Name Circuit id
--------------------------------------------------------------------------------------
NORT-CEN
4511 B4511 500. 5512 B5512 500. 1
4511 B4511 500. 5512 B5512 500. 2
4511 B4511 500. 5512 B5512 500. 3
EAST-CEN
5501 B5501 500. 5511 B5511 500. 1
5501 B5501 500. 5511 B5511 500. 2
5510 B5510 500. 5511 B5511 500. 1
5510 B5510 500. 5511 B5511 500. 2
Circuits
--------------------------------------------------------------------------------------
Circuit name No. < From bus > Name No. < To bus > Name Circuit id
--------------------------------------------------------------------------------------
5L41
1544 B1544 500. 5512 B5512 500. 1
1
Transfer file: t-z.trf
Transfer description:
Transfer from East(%40) and North(%60) to Area5
End of description
Transfer name= Export
Step size= 100.000 MW
Cutoff step size= 25.000 MW
Source X:
Source name= E+N GEN
Decrease limit= 500.00 MW
Increase limit= 1500.00 MW
Set 1 - Generation Scale group 1:
Group share= 40.00
Include zone= 5
Include zone= 6
#Notice# 8 swing, negative or out of service generations in this group will not be scaled
Set 2 - Generation Scale group 2:
Group share= 60.00
Include zone= 4
#Notice# 2 swing, negative or out of service generations in this group will not be scaled
Source D:
Source name= A5 GEN
Decrease limit= 9999.00 MW
Increase limit= 9999.00 MW
Set 3 - Generation Scale group 3:
Group share= 100.00
Include area= 5
#Notice# 4 swing, negative or out of service generations in this group will not be scaled
Source D:
Set Group %Share No <Load/Gen> MW Max < MW > Min
--- ------------- ------ ---------------- ----------------
3 Gen.-Scale 3 100.0 90 78259.84 142329.0*********
Original gen.-load: 78259.84 MW
Minimum value: 68260.84 MW
Maximum value: 88258.84 MW
Source Y is not specified
Source X:
Set Group %Share No <Load/Gen> MW Max < MW > Min
--- ------------- ------ ---------------- ----------------
1 Gen.-Scale 1 40.0 22 3500.00 4215.0 0.00
2 Gen.-Scale 2 60.0 15 2849.98 3547.0 0.00
Original gen.-load: 6349.98 MW
Minimum value: 5849.98 MW
Maximum value: 7511.68 MW
Maximum value is limited by set 2
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
1
Monitored Variable file: t.mon
Monitor description:
Monitor bus voltages, interface flows,
and Criteria reactive reserves
End of description
Monitor name= TestMon
Voltage of bus= 7799
Voltage of bus= 5512, 5511, 501
Voltage of bus= 7798, 6207
Voltage of bus= 201, 203, 1201, 101
MW flow of interface= NORT-CEN
MW flow of interface= EAST-CEN
MVAr flow of interface= NORT-CEN
MVAr flow of interface= EAST-CEN
Criteria MVAr reserves= Yes
Number of monitored bus voltages = 10
Number of monitored interface flows = 4
Number of monitored circuit flows = 0
Number of monitored bus Q reserves = 0
Number of monitored zone Q reserves = 0
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: 7217.39
Initial MVAR load: 3525.26
Generation scale group 2:
Increase by= 200.00 MW
Include area= 1
Number of generators: 101
Initial MW generation: 7569.11
Contingency file: t-z.ctg
9 Contingencies:
CC41 CC42 CC81 CC82 CC87
A 4 A 8 A 19 A 20
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
1
Base point (1)
==============
E+N GEN : 6350.0 MW A5 GEN : 78259.8 MW
Powerflow solved in 3 iterations
Contingency CC41 in Base point (1)
Powerflow solved in 7 iterations
Contingency CC42 in Base point (1)
Powerflow solved in 7 iterations
Contingency CC81 in Base point (1)
Powerflow solved in 7 iterations
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