HomeMy WebLinkAboutJuneau Greens Creek Hoonah Intertie Study
December 30, 2004
ALASKA ELECTRIC LIGHT AND POWER
Juneau/Greens Creek/Hoonah Intertie Study
Load Flow and Short Circuit Analysis Final Report Rev 1
PROJECT NUMBER:
104981
PROJECT CONTACT:
John Henning, P.E.
EMAIL: jhenning@powereng.com
PHONE: 208-788-3456
FAX: 208-788-2082
PROJECT CONTACT:
Jeff Mann
EMAIL: jmann@powereng.com
PHONE: 208-788-3456
FAX: 208-788-2082
HLY 029- 321 Rev 1 (12/30/04) 104981/ss i
TABLE OF CONTENTS
Executive Summary............................................................................................................ 1
Introduction......................................................................................................................... 3
Load Flow Analysis............................................................................................................ 3
Short Circuit Analysis....................................................................................................... 14
Energization Procedures................................................................................................... 14
Transformer Taps.............................................................................................................. 15
Results and Conclusion..................................................................................................... 16
TABLE OF TABLES
Table 1 – Highest and Lowest Voltages at 69 kV Bus....................................................... 5
Table 2A – Line Loss Summary at Light Load of 23MW (without Hoonah).................. 10
Table 2B – Line Loss Summary at Light Load of 23MW (with Hoonah) ....................... 11
Table 3A – Line Loss Summary at Load of 47.5MW (without Hoonah)......................... 11
Table 3B – Line Loss Summary at Load of 47.5MW (with Hoonah).............................. 12
Table 4A – Line Loss Summary at Peak Load of 72MW (without Hoonah)................... 12
Table 4B – Line Loss Summary at Peak Load of 72MW (with Hoonah)........................ 13
Table 5 – Fault Current Available at the New 69 kV Buses............................................. 14
APPENDICES
Appendix A - AEL&P One-Line Diagrams
Appendix B - Power Flow Cases - Power Flow Diagrams
Appendix C - Line Loss Cases
Appendix D - Short Circuit Results
Appendix E – Load and Line Impedance Data
Appendix F – Historical Data
Appendix G – Cable and Reactor Data
Appendix H – Greens Creek Data
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EXECUTIVE SUMMARY
Constructing a 69 kV transmission system between West Juneau, Greens Creek Mine and
Hoonah is technically feasible. To avoid high voltage violations at the end of the transmission
system at Greens Creek Mine and Hoonah, it is recommended to install two 2.5 MVAR reactors
at North Douglas, one 5 MVAR reactor at Hawk Inlet and one 7.5 MVAR reactor at Spasski Bay
to regulate voltages for the loads at Greens Creek and Hoonah during normal operating
conditions.
With the addition of the Greens Creek and Hoonah lines:
During lightly loaded conditions for the AEL&P electrical system, two 2.5 MVAR reactors at
North Douglas, one 5 MVAR reactor at Hawk Inlet and one 7.5 MVAR reactor at Spasski Bay
will be required to avoid overvoltage violation problems (Case203). If the entire project were to
be built without changes to the connectivity of the Annex Creek line, another 5 MVAR reactor
would be required within the existing AEL&P system if the Annex Creek generation is on-line
under this lightly loaded condition (Case 103R1 & 203R1). The Annex Creek generation
protective relaying does not operate correctly with the existing reactor at the Thane bus (on the
Annex Creek line) energized. Options that could be considered would be to relocate the existing
reactor to a different bus within the existing system, reconfiguring the Annex Creek connection
to a different location or taking the Annex Creek generation off-line during lightly loaded
conditions.
During a heavily loaded condition of 72 MW at the AEL&P electrical system, two 2.5 MVAR
reactors at North Douglas will be required when energizing the system (Case103). After the
system is tied together, these reactors will be opened to allow the system voltage levels to be in
an acceptable range (Case105).
With the addition of the Greens Creek line (without the Hoonah line):
During a lightly loaded condition of 23 MW at the AEL&P electrical system, two 2.5 MVAR
reactors at North Douglas will be required to avoid overvoltage violations (Case 402). Under
lightly loaded conditions, the issues associated with the Annex Creek reactor not being available
due to protective relaying issues, can be mitigated by installing a 5 MVAR reactor at Hawk Inlet
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(Case 402R2). Installing the reactor at Hawk Inlet would be appropriate since it will be required
if the Hoonah line is constructed in the future. With only one 2.5 MVAR reactor at North
Douglas, a minimum load of 34 MW at AEL&P system will be required (Case604). Without the
addition of the two 2.5 MVAR reactors at North Douglas, it will require a minimum load of 34
MW at the AEL&P system and 6.58 MW at Greens Creek and Hawk Inlet (Case605).
During a heavily loaded condition of 72 MW at the AEL&P electrical system, no additional
reactors will be required (Case302). The voltage level at Greens Creek is in an acceptable range.
The Greens Creek load with a power factor of 0.84:
All cases, except for a number of sensitivity cases, assumed a 0.95 power factor for the Greens
Creek load. During a lightly loaded condition of 23 MW on the AEL&P system, a 0.84 power
factor for the Greens Creek load does not negatively impact the system voltages; however,
because one of the 5 MVAR reactors at Thane is required to be out of service, a new 5 MVAR
reactor must be placed somewhere else on the system (Case 403R3). The most logical place for
this new 5 MVAR reactor to be placed is at Hawk Inlet. If the Hoonah line does get built a new
reactor will be required, and the proximity of Hawk Inlet to Hoonah will be ideal for excess
VAR mitigation.
During a heavily loaded condition of 72 MW on the AEL&P system, a 0.84 power factor for the
Greens Creek load does drop the Auke Bay voltage to 0.933 pu, which is below the minimum
acceptable level for this study (Case 302R1).
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INTRODUCTION
Alaska Electric Light and Power (AEL&P) requested POWER Engineers, Inc. (POWER) to
investigate the feasibility of constructing a new 69 kV transmission system between West
Juneau, Greens Creek Mine and Hoonah. The total length of the transmission line is 64.5 miles,
which includes approximately 34.5-miles of submarine cable and approximately 30-miles of
overhead line. The new transmission line will be used to deliver power from AEL&P to Greens
Creek and Hoonah. The object of this analysis is to determine whether the high line charging
associated with the submarine cables can cause high voltages at the end of the transmission
system at Greens Creek Mine and/or Hoonah, and then to make recommendations to mitigate the
over-voltage condition.
LOAD FLOW ANALYSIS
The PTI PSS/E database for the 69 kV system option completed for the October 16, 2003 study
was used as the base case for the load flow analysis. For the short circuit study, the PSS/E
aelpwn99.seq data file provided by AEL&P was used. Using system one-line drawings and the
structure configuration information provided by AEL&P, the positive and zero sequence values
for the eighteen 69 kV transmission line segments were calculated. The calculated values were
then compared to the values currently in the database. All of the calculated eighteen line
segment values were found different with the PTI PSS/E database values. After discussing the
findings with AEL&P, the database was updated accordingly as agreed to with AEL&P. The
transformers in the PTI PSS/E database were modified as using their present de-energized taps
provided by AEL&P.
The light and normal peak loading levels including power factors for the existing system and new
Hawk Inlet, Greens Creek, and Hoonah loads to be served by the JGCHI project were provided by
AEL&P. The loads were modeled with a power factor of 0.95 with the exception of a few
sensitivity cases where the Greens Creek load was at 0.84 power factor. The normal peak load
totaled approximately 72 MW whereas the light load totaled approximately 23 MW. The new
load totaled approximately 11 MW. Generation dispatch levels for each generator in the system
were also provided by AEL&P.
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For purposes of this study, the voltage levels at Greens Creek and/or Hoonah were examined
under light loading, normal peak load, and intermediate loading conditions with and without
Hoonah. Three groups of twenty-one models were constructed: seven models simulate the
existing system normal peak load condition, eight models simulate light load condition, and
twelve models simulate the intermediate loading condition (between light load and full load).
Based on the comments received from AEL&P seven additional sensitivity cases were run. Two
models simulate the existing system normal peak load, while the other five models simulate the
light load condition.
The first group of cases, 101-105 and 301-302, was analyzed using the system peak load of 72
MW, with and without new loads at Hawk Inlet, Greens Creek, and Hoonah to determine voltage
conditions and the need for shunt reactors at North Douglas Switchyard to avoid overvoltage
problems. Case 104 had a sensitivity analysis done (Case104R) to determine how much load could
be served at Greens Creek (result is approx. 7 MW) if 7 MW (0.95 pf) of load was at Hoonah. Case
302 also had a sensitivity analysis performed, Case302R1, which changed the 8.2 MW load at
Greens Creek to a power factor of 0.84.
The second group of cases, 201-205 and 401-403, was analyzed using the system load reduced to the
light load condition of 23 MW to determine the size of shunt reactors required to meet the acceptable
voltage range between 0.95-1.05 per unit. Case 402 had two sensitivity analysis performed
(Case402R1 and Case402R2). Case402R1 took one of the 5 MVAR reactors at Thane out-of-
service, which resulted in voltage violations. Case402R2 installed a new 5 MVAR reactor at Hawk
Inlet in place of the 5 MVAR reactor at Thane for mitigation. Case 403 had three sensitivity analysis
performed (Case403R1, Case403R2, Case403R3). Case403R1 took one of the 5 MVAR reactors at
Thane out-of-service. Case403R2 installed a new 5 MVAR reactor at Hawk Inlet in place of the 5
MVAR reactor at Thane. Case403R3 modified Case403R2 by changing the 8.2 MW load at Greens
Creek to a power factor of 0.84.
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The third group of cases, 501-602, was analyzed using the system load of 47.5 MW between light
load and full load conditions to determine the size and loading required for a second step of shunt
reactors.
Table 1 provides a summary of the highest and lowest 69 kV bus voltages for these load flow cases.
Refer to attached power flow diagrams in Appendix B for further information.
A motor starting study was analyzed to determine the motor terminal voltage condition at the 4.16
kV Greens Creek Mine bus during a heavily loaded condition of 72 MW at the AEL&P system
without the Hoonah line. A maximum induction motor of 900 hp with a starting current of five (5)
times the full load running current was modeled. The Greens Creek bus voltage should not dip more
than 20% for more than 20 cycles during the motor starting procedure. Refer to Case701 for further
information.
Table 1 – Highest and Lowest Voltages at 69 kV Bus
Highest Voltage
69 kV Bus
Lowest Voltage
69 kV Bus Case Description
Per Unit Bus Per Unit Bus
Case101
72 MW at AEL&P; no Greens Creek
or Hoonah; both of the existing Thane
5 MVAR reactors out-of-service.
0.985 Thane 0.939 Auke Bay
Case102
72 MW at AEL&P; new Greens Creek
and Hoonah lines; both of the existing
Thane 5 MVAR reactors in-service;
no new loads or reactors in service.
1.071 Hoonah 0.983 Auke Bay
Case103
72 MW at AEL&P; new Greens Creek
and Hoonah lines; both of the existing
Thane 5 MVAR reactors in-service;
no new load, 2-2.5 MVAR reactor at
North Douglas.
1.040 Hoonah 0.963 Auke Bay
Case103R1
A modification of Case103 above.
The 5 MVAR reactor at Thane on the
Annex Creek line is out-of-service.
1.058 Hoonah 0.980 Auke Bay
Case104
72 MW at AEL&P; new Greens Creek
and Hoonah lines with the addition of
11.36 MW load; no new reactors in
service; one of the existing Thane
5MVAR reactors in-service; no
generation @ Greens Creek.
1.006 Spasski
Bay 0.957 Auke Bay
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Highest Voltage
69 kV Bus
Lowest Voltage
69 kV Bus Case Description
Per Unit Bus Per Unit Bus
Case104R
A modification of Case 104 above.
7 MW at Hoonah, to see what max
load at Greens Creek can be (7 MW).
0.993 Thane 0.950 Auke Bay
Case105
72 MW at AEL&P; new Greens Creek
and Hoonah lines with the addition of
11.36 MW load; no new reactors; one
of the existing Thane 5 MVAR
reactors in-service; 3.2MW generation
@ Greens Creek.
1.038 Spasski
Bay 0.976 Auke Bay
Case201
23 MW at AEL&P without new
Greens Creek and Hoonah lines; no
new reactors; both of the existing
Thane 5 MVAR reactors in-service.
1.045 Thane 1.037 Auke Bay
Case202
23 MW at AEL&P; new Greens Creek
and Hoonah lines without new loads
or reactors; no generation @ Greens
Creek; both of the existing Thane 5
MVAR reactors in-service.
1.246 Hoonah 1.168 Auke Bay
Case203
23 MW at AEL&P; new Greens Creek
and Hoonah without new loads; no
generation @ Greens Creek; both of
the existing Thane 5 MVAR reactors
in-service; 2-2.5MVAR reactors at
North Douglas, 1-5MVAR reactor at
Hawk Inlet, and 1-7.5MVAR reactor
at Spasski Bay.
1.044 Greens
Creek 1.038 Auke Bay
Case203R1
A modification of Case203 above.
The 5 MVAR reactor at Thane on the
Annex Creek line is out-of-service.
1.070 Thane 1.062 Auke Bay
Case204
23 MW at AEL&P; new Greens Creek
and Hoonah lines with the addition of
11.36 MW load; 3.2MW generation @
Greens Creek; both of the existing
Thane 5 MVAR reactors in-service; 2-
2.5MVAR reactors at North Douglas,
1-5MVAR reactor at Hawk Inlet, and
1-7.5MVAR reactor at Spasski Bay.
1.030 Thane 1.005 Hoonah
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Highest Voltage
69 kV Bus
Lowest Voltage
69 kV Bus Case Description
Per Unit Bus Per Unit Bus
Case205
23 MW at AEL&P; new Greens Creek
and Hoonah lines with the addition of
11.36 MW load; 3.2MW generation @
Greens Creek; both of the existing
Thane 5 MVAR reactors in-service; 2-
2.5MVAR reactors at North Douglas,
1-5MVAR reactor at Hawk Inlet.
1.071 Hoonah 1.055 Auke Bay
Case206
34 MW at AEL&P; new Greens Creek
and Hoonah lines with the addition of
11.36 MW load; 3.2MW generation @
Greens Creek; both of the existing
Thane 5 MVAR reactors in-service; 2-
2.5MVAR reactors at North Douglas,
1-5MVAR reactor at Hawk Inlet.
1.041 Hoonah 1.024 Auke Bay
Case301
72 MW at AEL&P; new Greens Creek
line without Hoonah line; no new
loads or reactors; one of the existing
Thane 5 MVAR reactors in-service.
0.991 Thane 0.948 Auke Bay
Case302
72 MW at AEL&P; new Greens Creek
line with the addition of 9.78 MW
load and without Hoonah line; no new
reactors; 3.2MW generation @ Greens
Creek; both of the existing Thane 5
MVAR reactors out-of-service.
0.993 Thane 0.950 Auke Bay
Case302R1
A modification of Case302 above.
The Greens Creek load (8.2 MW) had
the power factor changed to 0.84.
0.979 Thane 0.933 Auke Bay
Case401
23 MW at AEL&P with new Greens
Creek line and without Hoonah line;
no new loads or reactors; both of the
existing Thane 5 MVAR reactors in-
service.
1.087 Greens
Creek 1.068 Auke Bay
Case402
23 MW at AEL&P with new Greens
Creek line and without Hoonah line;
no new loads; both of the existing
Thane 5 MVAR reactors in-service; 2-
2.5 MVAR reactors at North Douglas.
1.051 Greens
Creek 1.042 Auke Bay
Case402R1
A modification of Case402 above.
The 5 MVAR reactor at Thane on the
Annex Creek line is out-of-service.
1.072 Greens
Creek 1.062 Auke Bay
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Highest Voltage
69 kV Bus
Lowest Voltage
69 kV Bus Case Description
Per Unit Bus Per Unit Bus
Case402R2
A modification of Case402 above.
The 5 MVAR reactor at Thane on the
Annex Creek line is out-of-service,
and a new 5 MVAR reactor is in place
at Hawk Inlet.
1.050 Thane 1.032 Hawk Inlet
Case403
23 MW at AEL&P with new Greens
Creek line with the addition of 9.78
MW load and without Hoonah line;
3.2MW generation @ Greens Creek;
both of the existing Thane 5 MVAR
reactors in-service; 1-5 MVAR reactor
at North Douglas.
1.041 Thane 1.024 Greens
Creek
Case403R1
A modification of case403 above. The
5 MVAR reactor at Thane on the
Annex Creek line is out-of-service.
1.055 Thane 1.033 Greens
Creek
Case403R2
A modification of Case403 above.
The 5 MVAR reactor at Thane on the
Annex Creek line is out-of-service,
and a new 5 MVAR reactor is in place
at Hawk Inlet.
1.040 Thane 1.005 Greens
Creek
Case403R3
A modification of Case403R2 above.
The Greens Creek load (8.2 MW) had
the power factor changed to 0.84.
1.029 Thane 0.980 Greens
Creek
Case501
47.5 MW at AEL&P without new
Greens Creek and Hoonah lines; no
new reactors; both of the existing
Thane 5 MVAR reactors in-service.
1.008 Thane 0.988 Auke Bay
Case502
47.5 MW at AEL&P; new Greens
Creek and Hoonah lines without new
loads or reactors; no generation @
Greens Creek; both of the existing
Thane 5 MVAR reactors in-service.
1.150 Hoonah 1.071 Auke Bay
Case503
47.5 MW at AEL&P; new Greens
Creek and Hoonah without new loads;
2-2.5MVAR reactors at North
Douglas and 1-5MVAR reactor at
Spasski Bay; both of the existing
Thane 5 MVAR reactors in-service.
1.052 Hoonah 1.012 Auke Bay
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Highest Voltage
69 kV Bus
Lowest Voltage
69 kV Bus Case Description
Per Unit Bus Per Unit Bus
Case504
47.5 MW at AEL&P; new Greens
Creek and Hoonah lines with the
addition of 11.36 MW load; 3.2MW
generation @ Greens Creek; both of
the existing Thane 5 MVAR reactors
in-service; 2-2.5MVAR reactors at
North Douglas and 1-5MVAR reactor
at Spasski Bay.
1.010 Thane 0.995 Auke Bay
Case505
47.5 MW at AEL&P; new Greens
Creek and Hoonah lines with the
addition of 11.36 MW load; 3.2MW
generation @ Greens Creek; both of
the existing Thane 5 MVAR reactors
in-service; 2-2.5MVAR reactors at
North Douglas.
1.044 Spasski
Bay 1.008 Auke Bay
Case506
52.5 MW at AEL&P; new Greens
Creek and Hoonah lines with the
addition of 11.36 MW load; 3.2MW
generation @ Greens Creek; both of
the existing Thane 5 MVAR reactors
in-service; 1-2.5MVAR reactors at
North Douglas.
1.046 Spasski
Bay 1.004 Auke Bay
Case601
47.5 MW at AEL&P with new Greens
Creek line and without Hoonah line;
no new loads or reactors; both of the
existing Thane 5 MVAR reactors in-
service.
1.032 Greens
Creek 1.006 Auke Bay
Case602
47.5 MW at AEL&P; new Greens
Creek line with the addition of 9.78
MW load and without Hoonah line; no
new reactors; 3.2MW generation @
Greens Creek; both of the existing
Thane 5 MVAR reactors in-service.
1.015 Thane 0.996 Auke Bay
Case603
34 MW at AEL&P with new Greens
Creek line and without Hoonah line;
no new loads or reactors; both of the
existing Thane 5 MVAR reactors in-
service.
1.064 Greens
Creek 1.042 Auke Bay
Case604
34 MW at AEL&P with new Greens
Creek line and without Hoonah line;
no new loads; 1-2.5 MVAR reactor at
North Douglas; both of the existing
Thane 5 MVAR reactors in-service.
1.046 Greens
Creek 1.029 Auke Bay
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Highest Voltage
69 kV Bus
Lowest Voltage
69 kV Bus Case Description
Per Unit Bus Per Unit Bus
Case605
34 MW at AEL&P with new Greens
Creek line with the addition of 9.78
MW load and without Hoonah line;
3.2MW generation @ Greens Creek;
no new reactor at North Douglas; both
of the existing Thane 5 MVAR
reactors in-service.
1.038 Thane 1.025 Auke Bay
Case701
72 MW at AEL&P; new Greens Creek
line with the addition of 7.28 MW
load and without Hoonah line; (900hp
x 5) motor; no new reactors; 3.2MW
generation @ Greens Creek; both of
the existing Thane 5 MVAR reactors
out-of-service.
0.984 Thane 0.938 Auke Bay
The following tables provide the summary of line losses for the separate sections between the West
Juneau, North Douglas, Young Bay, Hawk Inlet, and Greens Creek without Hoonah Intertie under
light load, between light load and full load, and normal peak load conditions. Refer to attached
tables in Appendix C for further information.
Table 2A – Line Loss Summary at Light Load of 23MW (without Hoonah)
69 kV Transmission Line Losses
From Bus To Bus MW MVAR
West Juneau North Douglas 0.05 0.11
North Douglas Young Bay 0.02 0.03
Young Bay Hawk Inlet 0.03 0.06
Hawk Inlet Greens Creek 0.01 0.03
Total System Losses1 0.53 4.24
Total System Losses Without Project 0.26 2.66
Reactor Losses2 0.053 N/A
1Reactor losses are not included in the Total System Losses
2Niagra Transformer Corporation indicates that a 5 MVAR 69 kV reactor has
53 kW in losses. New reactor losses have been estimated using a straight line
approximation using 53 kW per 5 MVAR.
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Table 2B – Line Loss Summary at Light Load of 23MW (with Hoonah)
69 kV Transmission Line Losses
From Bus To Bus MW MVAR
West Juneau North Douglas 0.05 0.12
North Douglas Young Bay 0.04 0.05
Young Bay Hawk Inlet 0.03 0.06
Hawk Inlet Greens Creek 0.02 0.05
Hawk Inlet Spasski Bay 0.07 0.05
Spasski Bay Hoonah 0.00 0.00
Total System Losses1 0.63 4.58
Total System Losses Without Project 0.26 2.66
Reactor Losses2 0.053 N/A
1Reactor losses are not included in the Total System Losses
2Niagra Transformer Corporation indicates that a 5 MVAR 69 kV reactor has
53 kW in losses. New reactor losses have been estimated using a straight line
approximation using 53 kW per 5 MVAR.
Table 3A – Line Loss Summary at Load of 47.5MW (without Hoonah)
69 kV Transmission Line Losses
From Bus To Bus MW MVAR
West Juneau North Douglas 0.03 0.07
North Douglas Young Bay 0.02 0.02
Young Bay Hawk Inlet 0.02 0.05
Hawk Inlet Greens Creek 0.02 0.03
Total System Losses1 1.40 15.30
Total System Losses Without Project 1.07 12.19
Reactor Losses2 0.053 N/A
1Reactor losses are not included in the Total System Losses
2Niagra Transformer Corporation indicates that a 5 MVAR 69 kV reactor has
53 kW in losses. New reactor losses have been estimated using a straight line
approximation using 53 kW per 5 MVAR.
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Table 3B – Line Loss Summary at Load of 47.5MW (with Hoonah)
69 kV Transmission Line Losses
From Bus To Bus MW MVAR
West Juneau North Douglas 0.09 0.19
North Douglas Young Bay 0.03 0.04
Young Bay Hawk Inlet 0.03 0.06
Hawk Inlet Greens Creek 0.03 0.06
Hawk Inlet Spasski Bay 0.06 0.05
Spasski Bay Hoonah 0.00 0.00
Total System Losses1 1.59 16.17
Total System Losses Without Project 1.07 12.19
Reactor Losses2 0.053 N/A
1Reactor losses are not included in the Total System Losses
2Niagra Transformer Corporation indicates that a 5 MVAR 69 kV reactor has
53 kW in losses. New reactor losses have been estimated using a straight line
approximation using 53 kW per 5 MVAR.
Table 4A – Line Loss Summary at Peak Load of 72MW (without Hoonah)
69 kV Transmission Line Losses
From Bus To Bus MW MVAR
West Juneau North Douglas 0.05 0.11
North Douglas Young Bay 0.02 0.03
Young Bay Hawk Inlet 0.02 0.04
Hawk Inlet Greens Creek 0.02 0.03
Total System Losses1 3.21 31.61
Total System Losses Without Project 2.79 27.94
Reactor Losses2 None in service N/A
1Reactor losses are not included in the Total System Losses
2Niagra Transformer Corporation indicates that a 5 MVAR 69 kV reactor has
53 kW in losses. New reactor losses have been estimated using a straight line
approximation using 53 kW per 5 MVAR.
HLY 029- 321 Rev 1 (12/30/04) 104981/ss 13
Table 4B – Line Loss Summary at Peak Load of 72MW (with Hoonah)
69 kV Transmission Line Losses
From Bus To Bus MW MVAR
West Juneau North Douglas 0.21 0.46
North Douglas Young Bay 0.08 0.10
Young Bay Hawk Inlet 0.06 0.12
Hawk Inlet Greens Creek 0.02 0.04
Hawk Inlet Spasski Bay 0.06 0.05
Spasski Bay Hoonah 0.00 0.00
Total System Losses1 3.39 30.87
Total System Losses Without Project 2.79 27.94
Reactor Losses2 None in service N/A
1Reactor losses are not included in the Total System Losses
2Niagra Transformer Corporation indicates that a 5 MVAR 69 kV reactor has
53 kW in losses. New reactor losses have been estimated using a straight line
approximation using 53 kW per 5 MVAR.
HLY 029- 321 Rev 1 (12/30/04) 104981/ss 14
SHORT CIRCUIT ANALYSIS
The PSS/E aelpwn99.seq data file provided by AEL&P was used as the base case for the short
circuit analysis. The database was modified to reflect the 69 kV system used in the load flow
analysis. Short circuit cases were run and results tabulated for three-phase and single line-to-
ground fault currents. These short circuit currents are used in assessing equipment ratings and
for protective coordination studies. Table 5 provides a summary of the fault currents available at
the 69 kV Thane, North Douglas, Hawk Inlet, Greens Creek and Hoonah Substation buses. The
output report from the short circuit analysis is included in Appendix D.
Table 5 – Fault Current Available at the New 69 kV Buses
Bus Three-Phase Fault
(Amps)
Single Line-to-Ground
Fault (Amps)
Thane 2,021 2,693
North Douglas 1,373 1,084
Hawk Inlet 1,137 803
Greens Creek 1,003 650
Hoonah 822 599
ENERGIZATION PROCEDURES
Energizing the submarine cable portions of the project will require special consideration. A
transient analysis may not be necessary since the breakers are expected to be zero voltage
crossing breakers and the cables should be completely de-energized (no trapped charge) when
closing the breakers. It is recommended that the cable manufacturer specify the surge arresters
using the highest energy ratings available. No reclosing is recommended.
Energization procedures may depend on system loading conditions at the time of energization
and if the Hoonah segment is connected to the system. If Hoonah is connected to the system, the
reactors will be required to avoid overvoltages. Under most loading conditions, a normal
procedure that could be followed is:
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1. Close the grounding switch at North Douglas (Outer Point) to bleed off any charge on the
cable system. This action will likely be automated when the line breaker at North
Douglas is opened.
2. Open all grounding switches.
3. Close the reactor breakers.
4. Close the line breaker at North Douglas.
Additional study may be required when the programming of the reactor controls is initiated to
determine voltage set points and trip/close delay durations of the reactor breakers.
Please note that these recommendations are based on an assumption that the zero voltage
crossing breaker operates as designed. If the breaker control does not work perfectly, some high
transients are probable. AEL&P may consider further study, such as an EMTP switching surge
study, to have an idea of what may happen if the breaker control fails and the effects of having
reactors connected or not connected during the energization procedure.
TRANSFORMER TAPS
In the past, the transformer taps at Snettisham were changed seasonally to regulate the system
voltage. At present, the transformer taps at Snettisham and Thane are set such that adequate
voltage control can be maintained without the seasonal change by AEL&P using the voltage
regulator controls at Snettisham and at Lower Salmon to regulate the system voltage. As the
system is expanded, and depending on load growth patterns, changing of the transformer taps
may be required.
The remainder of AEL&P’s distribution transformer taps appear to be set on neutral or 2.5%
boost. We anticipate that this will remain the case. The Greens Creek transformer should be set
to 2.5% boost and the Hoonah transformer should be set at neutral.
HLY 029- 321 Rev 1 (12/30/04) 104981/ss 16
RESULTS AND CONCLUSION
Installing two 2.5 MVAR reactors at North Douglas, one 5 MVAR reactor at Hawk Inlet and one
7.5 MVAR reactor at Spasski Bay will help to regulate voltages for the loads at Hoonah and
Greens Creek during normal operating conditions. If the entire project were to be built without
changes to the connectivity of the Annex Creek line, another 5 MVAR reactor would be required
within the existing AEL&P system if the Annex Creek generation is on-line under lightly loaded
conditions. The Annex Creek generation protective relaying does not operate correctly with the
existing reactor at the Thane bus energized. Options that could be considered would be to
relocate the existing reactor to a different bus within the existing system or reconfiguring the
Annex Creek connection to a different location.
During heavily loaded conditions, with the addition of Greens Creek and Hoonah lines, two 2.5
MVAR reactors at North Douglas will be required during the energization procedure. After the
system is tied together, this reactor will be opened so the system voltage level will be in an
acceptable range. Without Hoonah line, no additional reactors, with the exception of relocation
of the Thane reactor (or new addition of 5 MVAR elsewhere in the system) will be required.
The voltage level at Greens Creek is in an acceptable range.
Motor starting analysis indicates that the 69 kV lowest voltage is 0.938 pu (65 kV) at Auke Bay.
The voltage dip at Greens Creek during the motor starting process is 6%, which does not violate
the voltage dip criteria of 20%. Therefore, the Greens Creek bus voltage is in an acceptable
range during motor start-up.
A transient analysis may not be necessary since the breakers are expected to be zero voltage
crossing breakers and the cables should be completely de-energized (no trapped charge) when
closing the breakers. It is recommended that the issue be discussed in depth with the cable
manufacturer.
APPENDIX A - AEL&P ONE-LINE DIAGRAMS
PTI INTERACTIVE POWER SYSTEM SIMULATOR--PSS/E THU, JUL 29 2004 14:10
CASE403R2 - 23 MW @ AEL&P WITH GRN CRK 9.78 MW LOAD, W/O HOONAH
5MVAR REACT @ HAWK INLET, 3.2MW GEN @ GRN CRK, 1 THANE REACT OFF
*********************** SUMMARY FOR COMPLETE SYSTEM ***********************
SYSTEM SWING BUS SUMMARY
BUS X---NAME---X X--- AREA ---X X--- ZONE ---X MW MVAR MVABASE
15051 SNET GEN13.2 1 [AREA 1] 1 [ZONE 1 ] 9.5 0.9 34.5
79 BUSES 17 PLANTS 7 MACHINES 10 LOADS
81 BRANCHES 31 TRANSFORMERS 0 DC LINES 0 FACTS DEVICES
X------ ACTUAL ------X X----- NOMINAL ------X
MW MVAR MW MVAR
FROM GENERATION 33.3 3.9 33.3 3.9
TO CONSTANT POWER LOAD 32.8 7.8 32.8 7.8
TO CONSTANT CURRENT 0.0 0.0 0.0 0.0
TO CONSTANT ADMITTANCE 0.0 0.0 0.0 0.0
TO BUS SHUNT 0.0 15.6 0.0 15.0
TO FACTS DEVICE SHUNT 0.0 0.0 0.0 0.0
TO LINE SHUNT 0.0 0.0 0.0 0.0
FROM LINE CHARGING 0.0 23.7 0.0 24.8
VOLTAGE X----- LOSSES -----X X-- LINE SHUNTS --X CHARGING
LEVEL BRANCHES MW MVAR MW MVAR MVAR
138.0 5 0.19 1.13 0.0 0.0 15.8
100.0 12 0.00 0.54 0.0 0.0 0.0
69.0 29 0.22 0.94 0.0 0.0 7.4
23.0 5 0.10 0.38 0.0 0.0 0.5
13.2 15 0.01 1.12 0.0 0.0 0.0
12.5 5 0.00 0.01 0.0 0.0 0.0
4.2 6 0.01 0.12 0.0 0.0 0.0
2.4 4 0.00 0.00 0.0 0.0 0.0
TOTAL 81 0.53 4.24 0.0 0.0 23.7
PTI INTERACTIVE POWER SYSTEM SIMULATOR--PSS/E THU, JUL 29 2004 14:11
CASE403R2 - 23 MW @ AEL&P WITH GRN CRK 9.78 MW LOAD, W/O HOONAH RATING
5MVAR REACT @ HAWK INLET, 3.2MW GEN @ GRN CRK, 1 THANE REACT OFF SET A
OUTPUT FOR AREA 9 [ ]
BUS GREEN CK69.0 20060 AREA CKT MW MVAR MVA %I 1.0049PU -36.64 X-AREA-X X---ZONE---X 20060 [GREEN CK69.0]
9 69.338KV 9 NEWMODEL LOSS MW MVAR
TO GRN CK T4.16 20065 9 1 5.0 0.4 5.0 1.0000LK 9 NEWMODEL 0.01 0.12
TO HAWK INL69.0 20020 9 1 -5.0 -0.4 5.0 8 9 NEWMODEL 0.01 0.03
BUS GRN CK T4.16 20065 AREA CKT MW MVAR MVA %I 1.0019PU -38.06 X-AREA-X X---ZONE---X 20065 [GRN CK T4.16]
GENERATION 9 3.2 2.4H 4.0 60 4.1678KV 9 NEWMODEL LOSS MW MVAR
TO LOAD-PQ 8.2 2.7 8.6
TO GREEN CK69.0 20060 9 1 -5.0 -0.3 5.0 1.0000UN 9 NEWMODEL 0.01 0.12
BUS HAWK INL69.0 20020 AREA CKT MW MVAR MVA %I 1.0082PU -36.28 X-AREA-X X---ZONE---X 20020 [HAWK INL69.0]
9 69.565KV 9 NEWMODEL LOSS MW MVAR
TO LOAD-PQ 1.6 0.5 1.7
TO SHUNT 0.0 5.1 5.1
TO GREEN CK69.0 20060 9 1 5.0 0.2 5.0 8 9 NEWMODEL 0.01 0.03
TO YOUNGS B69.0 20010 9 1 -6.6 -5.8 8.8 14 9 NEWMODEL 0.03 0.06
BUS N.DOUGLS69.0 20000 AREA CKT MW MVAR MVA %I 1.0198PU -35.96 X-AREA-X X---ZONE---X 20000 [N.DOUGLS69.0]
9 70.365KV 9 NEWMODEL LOSS MW MVAR
TO SHUNT 0.0 5.2 5.2
TO WEST JUN69.0 15068 3 1 -6.7 -5.4 8.6 13 TR 1 ZONE 1 0.05 0.11
TO YOUNGS B69.0 20010 9 1 6.7 0.2 6.7 9 NEWMODEL 0.02 0.03
BUS YOUNGS B69.0 20010 AREA CKT MW MVAR MVA %I 1.0156PU -36.08 X-AREA-X X---ZONE---X 20010 [YOUNGS B69.0]
9 70.079KV 9 NEWMODEL LOSS MW MVAR
TO HAWK INL69.0 20020 9 1 6.6 5.7 8.7 14 9 NEWMODEL 0.03 0.06
TO N.DOUGLS69.0 20000 9 1 -6.6 -5.7 8.7 9 NEWMODEL 0.02 0.03
PTI INTERACTIVE POWER SYSTEM SIMULATOR--PSS/E THU, JUL 29 2004 15:47
CASE403R2 - 23 MW @ AEL&P WITH GRN CRK 9.78 MW LOAD, W/ HOONAH RATING
5MVAR REACT @ HAWK INLET, 3.2MW GEN @ GRN CRK, 1 THANE REACT OFF SET A
OUTPUT FOR AREA 9 [ ]
BUS GREEN CK69.0 20060 AREA CKT MW MVAR MVA %I 1.0643PU -37.95 X-AREA-X X---ZONE---X 20060 [GREEN CK69.0]
9 73.439KV 9 NEWMODEL LOSS MW MVAR
TO GRN CK T4.16 20065 9 1 5.0 4.1 6.5 1.0000LK 9 NEWMODEL 0.01 0.18
TO HAWK INL69.0 20020 9 1 -5.0 -4.1 6.5 10 9 NEWMODEL 0.02 0.05
BUS GRN CK T4.16 20065 AREA CKT MW MVAR MVA %I 1.0443PU -39.18 X-AREA-X X---ZONE---X 20065 [GRN CK T4.16]
GENERATION 9 3.2 -1.2L 3.4 52 4.3441KV 9 NEWMODEL LOSS MW MVAR
TO LOAD-PQ 8.2 2.7 8.6
TO GREEN CK69.0 20060 9 1 -5.0 -3.9 6.3 1.0000UN 9 NEWMODEL 0.01 0.18
BUS HAWK INL69.0 20020 AREA CKT MW MVAR MVA %I 1.0719PU -37.73 X-AREA-X X---ZONE---X 20020 [HAWK INL69.0]
9 73.959KV 9 NEWMODEL LOSS MW MVAR
TO LOAD-PQ 1.6 0.5 1.7
TO SHUNT 0.0 5.7 5.7
TO GREEN CK69.0 20060 9 1 5.0 3.8 6.3 9 9 NEWMODEL 0.02 0.05
TO SPASSKI 69.0 20030 9 1 1.7 -12.8 12.9 9 NEWMODEL 0.07 0.05
TO YOUNGS B69.0 20010 9 1 -8.3 2.7 8.7 13 9 NEWMODEL 0.03 0.06
BUS HOONAH 69.0 20040 AREA CKT MW MVAR MVA %I 1.0773PU -38.46 X-AREA-X X---ZONE---X 20040 [HOONAH 69.0]
9 74.336KV 9 NEWMODEL LOSS MW MVAR
TO HOONAH T4.16 20045 9 1 1.6 0.6 1.7 1.0000LK 9 NEWMODEL 0.00 0.04
TO SPASSKI 69.0 20030 9 1 -1.6 -0.6 1.7 2 9 NEWMODEL 0.00 0.00
BUS HOONAH T4.16 20045 AREA CKT MW MVAR MVA %I 1.0672PU -39.69 X-AREA-X X---ZONE---X 20045 [HOONAH T4.16]
9 4.4397KV 9 NEWMODEL LOSS MW MVAR
TO LOAD-PQ 1.6 0.5 1.7
TO HOONAH 69.0 20040 9 1 -1.6 -0.5 1.7 1.0000UN 9 NEWMODEL 0.00 0.04
BUS N.DOUGLS69.0 20000 AREA CKT MW MVAR MVA %I 1.0729PU -36.99 X-AREA-X X---ZONE---X 20000 [N.DOUGLS69.0]
9 74.028KV 9 NEWMODEL LOSS MW MVAR
TO SHUNT 0.0 5.8 5.8
TO WEST JUN69.0 15068 3 1 -8.3 3.2 8.9 13 TR 1 ZONE 1 0.05 0.12
TO YOUNGS B69.0 20010 9 1 8.3 -8.9 12.2 9 NEWMODEL 0.04 0.05
BUS SPASSKI 69.0 20030 AREA CKT MW MVAR MVA %I 1.0779PU -38.42 X-AREA-X X---ZONE---X 20030 [SPASSKI 69.0]
9 74.376KV 9 NEWMODEL LOSS MW MVAR
TO HAWK INL69.0 20020 9 1 -1.6 -0.5 1.7 9 NEWMODEL 0.07 0.05
TO HOONAH 69.0 20040 9 1 1.6 0.5 1.7 2 9 NEWMODEL 0.00 0.00
BUS YOUNGS B69.0 20010 AREA CKT MW MVAR MVA %I 1.0726PU -37.32 X-AREA-X X---ZONE---X 20010 [YOUNGS B69.0]
9 74.009KV 9 NEWMODEL LOSS MW MVAR
TO HAWK INL69.0 20020 9 1 8.3 -2.9 8.8 13 9 NEWMODEL 0.03 0.06
TO N.DOUGLS69.0 20000 9 1 -8.3 2.9 8.8 9 NEWMODEL 0.04 0.05
PTI INTERACTIVE POWER SYSTEM SIMULATOR--PSS/E THU, JUL 29 2004 14:18
CASE602R1 - 47.5 MW @ AEL&P WITH GREENS CREEK & W/OUT HOONAH
9.78 MW LOAD, % MVAR MOVED FROM THANE TO H.I., 3.2MW GEN @ GRN CK
*********************** SUMMARY FOR COMPLETE SYSTEM ***********************
SYSTEM SWING BUS SUMMARY
BUS X---NAME---X X--- AREA ---X X--- ZONE ---X MW MVAR MVABASE
15051 SNET GEN13.2 1 [AREA 1] 1 [ZONE 1 ] 34.8 5.6 34.5
79 BUSES 17 PLANTS 7 MACHINES 10 LOADS
81 BRANCHES 31 TRANSFORMERS 0 DC LINES 0 FACTS DEVICES
X------ ACTUAL ------X X----- NOMINAL ------X
MW MVAR MW MVAR
FROM GENERATION 58.7 15.1 58.7 15.1
TO CONSTANT POWER LOAD 57.3 12.7 57.3 12.7
TO CONSTANT CURRENT 0.0 0.0 0.0 0.0
TO CONSTANT ADMITTANCE 0.0 0.0 0.0 0.0
TO BUS SHUNT 0.0 10.1 0.0 10.0
TO FACTS DEVICE SHUNT 0.0 0.0 0.0 0.0
TO LINE SHUNT 0.0 0.0 0.0 0.0
FROM LINE CHARGING 0.0 22.9 0.0 24.8
VOLTAGE X----- LOSSES -----X X-- LINE SHUNTS --X CHARGING
LEVEL BRANCHES MW MVAR MW MVAR MVAR
138.0 5 0.79 4.55 0.0 0.0 15.2
100.0 12 0.00 1.70 0.0 0.0 0.0
69.0 30 0.49 3.19 0.0 0.0 7.2
23.0 5 0.10 0.36 0.0 0.0 0.4
13.2 15 0.02 5.48 0.0 0.0 0.0
12.5 5 0.00 0.01 0.0 0.0 0.0
4.2 5 0.00 0.00 0.0 0.0 0.0
2.4 4 0.00 0.00 0.0 0.0 0.0
TOTAL 81 1.40 15.30 0.0 0.0 22.9
PTI INTERACTIVE POWER SYSTEM SIMULATOR--PSS/E THU, JUL 29 2004 14:18
CASE602R1 - 47.5 MW @ AEL&P WITH GREENS CREEK & W/OUT HOONAH RATING
9.78 MW LOAD, % MVAR MOVED FROM THANE TO H.I., 3.2MW GEN @ GRN CK SET A
OUTPUT FOR AREA 9 [ ]
BUS GREEN CK69.0 20060 AREA CKT MW MVAR MVA %I 0.9965PU -46.48 X-AREA-X X---ZONE---X 20060 [GREEN CK69.0]
9 68.762KV 9 NEWMODEL LOSS MW MVAR
TO GRN CK T4.16 20065 9 1 5.0 -0.9 5.1 1.0000UN 9 NEWMODEL 0.01 0.13
TO HAWK INL69.0 20020 9 1 -5.0 0.9 5.1 8 9 NEWMODEL 0.02 0.03
BUS GRN CK T4.16 20065 AREA CKT MW MVAR MVA %I 1.0000PU -47.93 X-AREA-X X---ZONE---X 20065 [GRN CK T4.16]
GENERATION 9 3.2 3.7R 4.9 74 4.1600KV 9 NEWMODEL LOSS MW MVAR
TO LOAD-PQ 8.2 2.7 8.6
TO GREEN CK69.0 20060 9 1 -5.0 1.0 5.1 1.0000LK 9 NEWMODEL 0.01 0.13
BUS HAWK INL69.0 20020 AREA CKT MW MVAR MVA %I 0.9982PU -46.07 X-AREA-X X---ZONE---X 20020 [HAWK INL69.0]
9 68.874KV 9 NEWMODEL LOSS MW MVAR
TO LOAD-PQ 1.6 0.5 1.7
TO SHUNT 0.0 5.0 5.0
TO GREEN CK69.0 20060 9 1 5.0 -1.1 5.1 8 9 NEWMODEL 0.02 0.03
TO YOUNGS B69.0 20010 9 1 -6.6 -4.4 7.9 13 9 NEWMODEL 0.02 0.05
BUS N.DOUGLS69.0 20000 AREA CKT MW MVAR MVA %I 1.0080PU -45.68 X-AREA-X X---ZONE---X 20000 [N.DOUGLS69.0]
9 69.551KV 9 NEWMODEL LOSS MW MVAR
TO WEST JUN69.0 15068 3 1 -6.6 1.1 6.7 11 TR 1 ZONE 1 0.03 0.07
TO YOUNGS B69.0 20010 9 1 6.6 -1.1 6.7 9 NEWMODEL 0.02 0.02
BUS YOUNGS B69.0 20010 AREA CKT MW MVAR MVA %I 1.0045PU -45.84 X-AREA-X X---ZONE---X 20010 [YOUNGS B69.0]
9 69.310KV 9 NEWMODEL LOSS MW MVAR
TO HAWK INL69.0 20020 9 1 6.6 4.3 7.9 12 9 NEWMODEL 0.02 0.05
TO N.DOUGLS69.0 20000 9 1 -6.6 -4.3 7.9 9 NEWMODEL 0.02 0.02
PTI INTERACTIVE POWER SYSTEM SIMULATOR--PSS/E THU, JUL 29 2004 15:54
CASE602R1 - 47.5 MW @ AEL&P WITH GREENS CREEK & W/ HOONAH RATING
9.78 MW LOAD, % MVAR MOVED FROM THANE TO H.I., 3.2MW GEN @ G SET A
OUTPUT FOR AREA 9 [ ]
BUS GREEN CK69.0 20060 AREA CKT MW MVAR MVA %I 1.0242PU -47.54 X-AREA-X X---ZONE---X 20060 [GREEN CK69.0]
9 70.670KV 9 NEWMODEL LOSS MW MVAR
TO GRN CK T4.16 20065 9 1 5.0 4.8 6.9 1.0000UN 9 NEWMODEL 0.01 0.23
TO HAWK INL69.0 20020 9 1 -5.0 -4.8 6.9 11 9 NEWMODEL 0.03 0.06
BUS GRN CK T4.16 20065 AREA CKT MW MVAR MVA %I 1.0000PU -48.88 X-AREA-X X---ZONE---X 20065 [GRN CK T4.16]
GENERATION 9 3.2 -1.8R 3.7 56 4.1600KV 9 NEWMODEL LOSS MW MVAR
TO LOAD-PQ 8.2 2.7 8.6
TO GREEN CK69.0 20060 9 1 -5.0 -4.5 6.8 1.0000LK 9 NEWMODEL 0.01 0.23
BUS HAWK INL69.0 20020 AREA CKT MW MVAR MVA %I 1.0329PU -47.34 X-AREA-X X---ZONE---X 20020 [HAWK INL69.0]
9 71.272KV 9 NEWMODEL LOSS MW MVAR
TO LOAD-PQ 1.6 0.5 1.7
TO SHUNT 0.0 5.3 5.3
TO GREEN CK69.0 20060 9 1 5.0 4.6 6.8 10 9 NEWMODEL 0.03 0.06
TO SPASSKI 69.0 20030 9 1 1.7 -11.9 12.0 9 NEWMODEL 0.06 0.05
TO YOUNGS B69.0 20010 9 1 -8.3 1.5 8.4 13 9 NEWMODEL 0.03 0.06
BUS HOONAH 69.0 20040 AREA CKT MW MVAR MVA %I 1.0379PU -48.07 X-AREA-X X---ZONE---X 20040 [HOONAH 69.0]
9 71.613KV 9 NEWMODEL LOSS MW MVAR
TO HOONAH T4.16 20045 9 1 1.6 0.6 1.7 1.0000LK 9 NEWMODEL 0.00 0.04
TO SPASSKI 69.0 20030 9 1 -1.6 -0.6 1.7 3 9 NEWMODEL 0.00 0.00
BUS HOONAH T4.16 20045 AREA CKT MW MVAR MVA %I 1.0274PU -49.40 X-AREA-X X---ZONE---X 20045 [HOONAH T4.16]
9 4.2738KV 9 NEWMODEL LOSS MW MVAR
TO LOAD-PQ 1.6 0.5 1.7
TO HOONAH 69.0 20040 9 1 -1.6 -0.5 1.7 1.0000UN 9 NEWMODEL 0.00 0.04
BUS N.DOUGLS69.0 20000 AREA CKT MW MVAR MVA %I 1.0358PU -46.59 X-AREA-X X---ZONE---X 20000 [N.DOUGLS69.0]
9 71.469KV 9 NEWMODEL LOSS MW MVAR
TO WEST JUN69.0 15068 3 1 -8.3 7.2 11.0 17 TR 1 ZONE 1 0.09 0.19
TO YOUNGS B69.0 20010 9 1 8.3 -7.2 11.0 9 NEWMODEL 0.03 0.04
BUS SPASSKI 69.0 20030 AREA CKT MW MVAR MVA %I 1.0385PU -48.03 X-AREA-X X---ZONE---X 20030 [SPASSKI 69.0]
9 71.654KV 9 NEWMODEL LOSS MW MVAR
TO HAWK INL69.0 20020 9 1 -1.6 -0.5 1.7 9 NEWMODEL 0.06 0.05
TO HOONAH 69.0 20040 9 1 1.6 0.5 1.7 3 9 NEWMODEL 0.00 0.00
BUS YOUNGS B69.0 20010 AREA CKT MW MVAR MVA %I 1.0348PU -46.92 X-AREA-X X---ZONE---X 20010 [YOUNGS B69.0]
9 71.398KV 9 NEWMODEL LOSS MW MVAR
TO HAWK INL69.0 20020 9 1 8.3 -1.6 8.5 13 9 NEWMODEL 0.03 0.06
TO N.DOUGLS69.0 20000 9 1 -8.3 1.6 8.5 9 NEWMODEL 0.03 0.04
PTI INTERACTIVE POWER SYSTEM SIMULATOR--PSS/E THU, JUL 29 2004 13:49
CASE302 - 72 MW @ AEL&P WITH GREENS CREEK & W/O HOONAH
9.78 MW LOAD, NO NEW REACTOR, 3.2MW GEN @ GRN CK
*********************** SUMMARY FOR COMPLETE SYSTEM ***********************
SYSTEM SWING BUS SUMMARY
BUS X---NAME---X X--- AREA ---X X--- ZONE ---X MW MVAR MVABASE
15051 SNET GEN13.2 1 [AREA 1] 1 [ZONE 1 ] 34.1 10.1 34.5
79 BUSES 17 PLANTS 8 MACHINES 32 LOADS
81 BRANCHES 31 TRANSFORMERS 0 DC LINES 0 FACTS DEVICES
X------ ACTUAL ------X X----- NOMINAL ------X
MW MVAR MW MVAR
FROM GENERATION 85.2 37.5 85.2 37.5
TO CONSTANT POWER LOAD 82.0 28.1 82.0 28.1
TO CONSTANT CURRENT 0.0 0.0 0.0 0.0
TO CONSTANT ADMITTANCE 0.0 0.0 0.0 0.0
TO BUS SHUNT 0.0 0.0 0.0 0.0
TO FACTS DEVICE SHUNT 0.0 0.0 0.0 0.0
TO LINE SHUNT 0.0 0.0 0.0 0.0
FROM LINE CHARGING 0.0 22.1 0.0 24.8
VOLTAGE X----- LOSSES -----X X-- LINE SHUNTS --X CHARGING
LEVEL BRANCHES MW MVAR MW MVAR MVAR
138.0 5 1.93 11.12 0.0 0.0 14.8
100.0 12 0.00 3.79 0.0 0.0 0.0
69.0 29 1.13 8.26 0.0 0.0 6.8
23.0 5 0.11 0.39 0.0 0.0 0.4
13.2 15 0.03 7.89 0.0 0.0 0.0
12.5 5 0.00 0.01 0.0 0.0 0.0
4.2 6 0.01 0.13 0.0 0.0 0.0
2.4 4 0.00 0.00 0.0 0.0 0.0
TOTAL 81 3.21 31.58 0.0 0.0 22.1
PTI INTERACTIVE POWER SYSTEM SIMULATOR--PSS/E THU, JUL 29 2004 13:49
CASE302 - 72 MW @ AEL&P WITH GREENS CREEK & W/O HOONAH RATING
9.78 MW LOAD, NO NEW REACTOR, 3.2MW GEN @ GRN CK SET A
OUTPUT FOR AREA 9 [ ]
BUS GREEN CK69.0 20060 AREA CKT MW MVAR MVA %I 0.9713PU -50.22 X-AREA-X X---ZONE---X 20060 [GREEN CK69.0]
9 67.021KV 9 NEWMODEL LOSS MW MVAR
TO GRN CK T4.16 20065 9 1 5.0 0.4 5.0 1.0000LK 9 NEWMODEL 0.01 0.13
TO HAWK INL69.0 20020 9 1 -5.0 -0.4 5.0 8 9 NEWMODEL 0.02 0.03
BUS GRN CK T4.16 20065 AREA CKT MW MVAR MVA %I 0.9682PU -51.73 X-AREA-X X---ZONE---X 20065 [GRN CK T4.16]
GENERATION 9 3.2 2.4H 4.0 60 4.0276KV 9 NEWMODEL LOSS MW MVAR
TO LOAD-PQ 8.2 2.7 8.6
TO GREEN CK69.0 20060 9 1 -5.0 -0.3 5.0 1.0000UN 9 NEWMODEL 0.01 0.13
BUS HAWK INL69.0 20020 AREA CKT MW MVAR MVA %I 0.9747PU -49.83 X-AREA-X X---ZONE---X 20020 [HAWK INL69.0]
9 67.257KV 9 NEWMODEL LOSS MW MVAR
TO LOAD-PQ 1.6 0.5 1.7
TO GREEN CK69.0 20060 9 1 5.0 0.2 5.0 8 9 NEWMODEL 0.02 0.03
TO YOUNGS B69.0 20010 9 1 -6.6 -0.7 6.6 11 9 NEWMODEL 0.02 0.04
BUS N.DOUGLS69.0 20000 AREA CKT MW MVAR MVA %I 0.9797PU -49.25 X-AREA-X X---ZONE---X 20000 [N.DOUGLS69.0]
9 67.599KV 9 NEWMODEL LOSS MW MVAR
TO WEST JUN69.0 15068 3 1 -6.6 4.4 8.0 13 TR 1 ZONE 1 0.05 0.11
TO YOUNGS B69.0 20010 9 1 6.6 -4.4 8.0 9 NEWMODEL 0.02 0.03
BUS YOUNGS B69.0 20010 AREA CKT MW MVAR MVA %I 0.9780PU -49.51 X-AREA-X X---ZONE---X 20010 [YOUNGS B69.0]
9 67.480KV 9 NEWMODEL LOSS MW MVAR
TO HAWK INL69.0 20020 9 1 6.6 0.6 6.6 11 9 NEWMODEL 0.02 0.04
TO N.DOUGLS69.0 20000 9 1 -6.6 -0.6 6.6 9 NEWMODEL 0.02 0.03
PTI INTERACTIVE POWER SYSTEM SIMULATOR--PSS/E THU, JUL 29 2004 16:01
CASE302 - 72 MW @ AEL&P WITH GREENS CREEK & W/ HOONAH RATING
9.78 MW LOAD, NO NEW REACTOR, 3.2MW GEN @ GRN CK SET A
OUTPUT FOR AREA 9 [ ]
BUS GREEN CK69.0 20060 AREA CKT MW MVAR MVA %I 1.0335PU -51.39 X-AREA-X X---ZONE---X 20060 [GREEN CK69.0]
9 71.311KV 9 NEWMODEL LOSS MW MVAR
TO GRN CK T4.16 20065 9 1 5.0 2.6 5.6 1.0000LK 9 NEWMODEL 0.01 0.15
TO HAWK INL69.0 20020 9 1 -5.0 -2.6 5.6 9 9 NEWMODEL 0.02 0.04
BUS GRN CK T4.16 20065 AREA CKT MW MVAR MVA %I 1.0200PU -52.72 X-AREA-X X---ZONE---X 20065 [GRN CK T4.16]
GENERATION 9 3.2 0.2R 3.2 48 4.2432KV 9 NEWMODEL LOSS MW MVAR
TO LOAD-PQ 8.2 2.7 8.6
TO GREEN CK69.0 20060 9 1 -5.0 -2.4 5.6 1.0000UN 9 NEWMODEL 0.01 0.15
BUS HAWK INL69.0 20020 AREA CKT MW MVAR MVA %I 1.0394PU -51.12 X-AREA-X X---ZONE---X 20020 [HAWK INL69.0]
9 71.720KV 9 NEWMODEL LOSS MW MVAR
TO LOAD-PQ 1.6 0.5 1.7
TO GREEN CK69.0 20060 9 1 5.0 2.4 5.5 8 9 NEWMODEL 0.02 0.04
TO SPASSKI 69.0 20030 9 1 1.7 -12.0 12.1 9 NEWMODEL 0.06 0.05
TO YOUNGS B69.0 20010 9 1 -8.3 9.2 12.3 19 9 NEWMODEL 0.06 0.12
BUS HOONAH 69.0 20040 AREA CKT MW MVAR MVA %I 1.0444PU -51.85 X-AREA-X X---ZONE---X 20040 [HOONAH 69.0]
9 72.067KV 9 NEWMODEL LOSS MW MVAR
TO HOONAH T4.16 20045 9 1 1.6 0.6 1.7 1.0000LK 9 NEWMODEL 0.00 0.04
TO SPASSKI 69.0 20030 9 1 -1.6 -0.6 1.7 3 9 NEWMODEL 0.00 0.00
BUS HOONAH T4.16 20045 AREA CKT MW MVAR MVA %I 1.0340PU -53.17 X-AREA-X X---ZONE---X 20045 [HOONAH T4.16]
9 4.3014KV 9 NEWMODEL LOSS MW MVAR
TO LOAD-PQ 1.6 0.5 1.7
TO HOONAH 69.0 20040 9 1 -1.6 -0.5 1.7 1.0000UN 9 NEWMODEL 0.00 0.04
BUS N.DOUGLS69.0 20000 AREA CKT MW MVAR MVA %I 1.0321PU -50.06 X-AREA-X X---ZONE---X 20000 [N.DOUGLS69.0]
9 71.213KV 9 NEWMODEL LOSS MW MVAR
TO WEST JUN69.0 15068 3 1 -8.4 14.8 17.0 26 TR 1 ZONE 1 0.21 0.46
TO YOUNGS B69.0 20010 9 1 8.4 -14.8 17.0 9 NEWMODEL 0.08 0.10
BUS SPASSKI 69.0 20030 AREA CKT MW MVAR MVA %I 1.0450PU -51.82 X-AREA-X X---ZONE---X 20030 [SPASSKI 69.0]
9 72.108KV 9 NEWMODEL LOSS MW MVAR
TO HAWK INL69.0 20020 9 1 -1.6 -0.5 1.7 9 NEWMODEL 0.06 0.05
TO HOONAH 69.0 20040 9 1 1.6 0.5 1.7 3 9 NEWMODEL 0.00 0.00
BUS YOUNGS B69.0 20010 AREA CKT MW MVAR MVA %I 1.0348PU -50.55 X-AREA-X X---ZONE---X 20010 [YOUNGS B69.0]
9 71.404KV 9 NEWMODEL LOSS MW MVAR
TO HAWK INL69.0 20020 9 1 8.3 -9.2 12.4 19 9 NEWMODEL 0.06 0.12
TO N.DOUGLS69.0 20000 9 1 -8.3 9.2 12.4 9 NEWMODEL 0.08 0.10
APPENDIX E – LOAD AND LINE IMPEDANCE DATA
APPENDIX F – HISTORICAL DATA
APPENDIX G – CABLE AND REACTOR DATA
APPENDIX H – GREENS CREEK DATA