Loading...
HomeMy WebLinkAboutTyee Lake -Wrangell-Petersburg Power System Study -Final Report 1982 Los TYEE LAKE - WRANGELL - PETERSBURG POWER SYSTEM STUDY RECEIVED AUG D2 AUTHORITY FINAL REPORT EBASCO EBASCO SERVICES INCORPORATED OCTOBER 8, 1982 ALASKA POWER AUTHORITY 1984 as / A UW J x / TYEE HYDROELECTRIC PROJECT © LINE 1 PEAK LOAD CHART LAST EIVE YEARS Sezusesszssssszeszzs=s2222 PEAK LOAD EACH YEAR 11.73 15:06 FM -17-JUL-1990 PEAK LOAD LAST FIVE YEARS wanna nn anna fname an nanan ne] anne ne] Dann nnnne | Jonna Ga 18 MW MW MW KW HW KW AW MW MW PEAK TIME DATE =~ AV PER/HR 7.03 08:00 «8 7.28 11:00 = 20 6.60 17:00 24 6.43 16:00 28 6.73 11:20 9 6.9% 17:37 10 7.08 09:58 24 6.84 10:42 3 7.48 12:10 1 6.25 10:56 § 7.89 15:45 | 28 7.21 13330 6 7.92 16:20 28 7.36 © «6009:15 5 8.21 10:03 18 8.54 11:39 15 8.93 16:00 18 5.39 8.70 17:38 ll 5.60 8.86 10:26 28 — 5.19 9.18 10:10 14 4.0 9.98 08:18 20 .. 4.66 8 12:29 10 _. | 4.75 iL rPaeele-. WA. xemetobh 09:27 «16 6.02 W775 215242 5 4.98 1443 -2¢>-5.29- Mier 7. | 5.88 10:37 17 «G15 140 17 6.0T 14348 (28 6.16 08:31 26 = §.27 08:18 «ll 5.76 10:18 29 05.29 14:42 (27 3094 15:24 14 7.00 08:18 1 5.78 10:02 19 5.88 03:50 14 = 5.99 08:09 1 5240 ‘SBBeeees 90 1617 16 6.15 FEB 90 Mise 6 6.02 b “HAR 30 ag:55 275.82 APR 90 03:24 «10553 HAY 90 09:00 16 = 4.39 TUN 99 10:3 28 5112 WL 40 15:08 17 © 6.28 AUG 90 13:59 7 6.97 SEP 90 10:55 19 8.75 OCT 99 15:10 195.85 nov 40 14:29 21 BIS DEC 90 1455 § 5.74 aN 91 1046 25 «5.93 Mak al fas 22 a3 . . Jsead Wh APR 9] 1462 31 MAY 91 anise 307 JUN 931 857 3°39 WL 91 16 3105116 AUG 31 1353 28 $295 TYEE LAKE HYDROELECTRIC PROJECT MILL PEAK LOAD CHART LAST FIVE YEARS Sssssseesszsssss=ss=s2222222=22 PEAK LOAD EACH YEAR 5.51 12:29 aM 30 NOV 1990 PEAK LOAD LAST FIVE YEARS sonennene [annnnenenQennnn nna n Janna ncaa a den enennn Geena HW rf HW rn HW Mw PEAK TIME DATE AV PER/HR SEP 86 1.67 10:22 23 $2 OCT 986 1.52 10:02 14 43 NOV 86 1.42 15:24 1 44 DEC 86 1.72 08:53 «15 3d JAN 87 1.43 14:55 30 34 FEB 87 1.59 08:30 7 33 MAR 87 1.38 = 07:57:13 39 APR 87 1.46 15:10 17 Al MAY 87 1.33 14:19 6 38 JUN 87 1.79 01538 = 27 43 JUL 87 1.29 08:57. 12 37 AUG 87 1.32 12:10 5 036 SEP 987 2.40 09:23 28 49 OCT 87 1.34 13:04 28 34 NOY 87 2.62 12:38 24 1.10 DEC 87 2.93 14:55 15 75 2.33 = 18:06 «925 63 2.70 - 11:55 15 1.22 3.15 07:58 5-22.95. £10250 07337 12:43 =29 hE ASS16: 2x09 Fae 14:22 10 1.88 «pf 3838 222 ST” = 15:25 29. 7 Ea = “21331619 Reg = 104. 20-1598 peepee SSIBAIssH nih pa Ee pine f = —-——- a “AST. 08:49 «13 1.81 RSS SS BER BS EL A 10S IT OI MAR 89 4.78 14345 9 1.81 APR 89 4.23 13:50 = 28 92 HAY = 89 4.41 07:23 16 1.82 JUN 89 4.42 08:53 15 1.73 JUL = 89 ae 4.23, 10:08 6 1.37 AUG 89 eee 4.06 14:38 31 1.54 SEP 89 Ce 4.09 12:16 18 1.44 caw OCT 89 4.68 11536 13°. 1.70 nov 89 4.61 13345 27 1.68 7 DEC 89 SSSssssssssessssssssssesssssssssssssssssssss=zs2 4.83 10:27} 3.27 JAN 90 5.45 1420810 1,99 FEB 90 ~ 5-08 08:58 26 ~~. 1.91 MAR 90 5.04 = 15324 20 1.81 APR 90 5-01 08345 = 02 1.77 MAY = =90 4.94 11:12 07 1.69 JUN 90 5.03 08358 = 25 1.5 JUL 90 4.91 15306 17 1.73 AUG 4.75 10:15 OL 1.74 SEP 90 4.34 0831724 1.29 oct 90 4.99 15:10 19 2.05 nov 690 S-5l 12:29:30 2.29 DEC 90 5.04 = 1423613 1.03 JAN 91 4.03. 1352517 +67 , Bi Hb . : a a rd APR 91 3.29 14:56 2 ell MAY «91 3.13 07246 21 +2 JUN 91 3.11 10515) *o JUL 91 2.70 1430415 +07 AUG 91 3.45 13552 28 +2 TYEE HYDROELECTRIC PROJECT WRANGELL PEAK LOAD CHART LAST FIVE YEARS SeSssssssssssessesss22s2s=2s2222 PEAK LOAD EACH YEAR 3.38 16:52 PM 20-1EC-1990 PEAK LOAD LAST FIVE YEARS -------- [nnwnnnannJonnnnnnnn Juana nanan dnnnnnnn nnn nanan Ha HW MW MW MW HW PEAK TIKE DATE AV.PER/HR 96 2.2 10:30 11 1.59 86 2-20 «17:11 «28 1.55 96 2.34 «16:51 = 18 1.64 86 2.49 16:28 2: 1.72 87 2.60 16:05 19 1.65 87 2.36 17:11 2 1.66 87 2.52 11:30 24 1.66 87 2.32 095292 1.61 87 2.35 «093437 1.58 87 215 11:44 18 1.50 87 2.21 11:45 (30 1.48 87 2.15 10:46 27 1.50 87 2.36 =12:04 17 1.67 87 2.32 09:50 1 1.63 87 2.39 1633917 1.68 87 2.54 17:21 15 1.81 88 2.75 10:13 7 1.89 88 2.65 17:31 4 1.82 88 2.38 . 11:04 3 1.69 88. 7 7: 44-1108 7 1.58 88 10:44 In. 138 88 “ " -l4 -10 1.43 2.88 N07 7e Ga dees Z 88 08:17 4 88 11:06 - 15 88 S - 17:00 3 28 15:28 <29 eo OBY Serace See er —— os Bie 8 - ae Rr guest heme uta nerereta BS ep Seabee ot stemaver, a . fess 89” 17:32, 31 89 “2.99 17:27 “1 3 2.56 09:09 7 2.30 09:04 «13 89 2.43 09:03 11 . 89 2.2 10:54 29 1.54 89 2.34 = 095292 1.62 89 2.32 09:25 22 1.61 89 2.47 10:44 2 1.69 89 2.53 17:23 (30 1.82 89 2.66 17:01 30 1.96 89 3.03 17:09 15 2.04 90 3.12 17:29 31 2.21 ~ 90 2.97 = 17527 1 2.16 30 2. 09:48 «13 1.95 90 2.66 09:18 19 1.86 90 2.58 10:55 4 1.85 90 2.42 «10:30 7 1.74 90 2.60 12:07 31 1.85 90 2.69 15:29 9 1.94 90 2662 =10815 27 1.91 90 2.80 11:28 = 23 1.98 90 3.03 17:28 12 2.15 30 3.38 = 16:52 2 2.30 JAN 91 3.2 741 8 2.35 FEB 91 3.04 163555 2.16 wi MAR 91 2.78 «10811 «12 2.07 APR 91 2.80 10:21 1.% MAY = 91 2.75 10:21 21 1.96 JUN 91 2.64 10:27 § 1.83 JUL 91 2.73 =:10327 22 2.01 AUG 91 2.77) lsh 9 2.08 TYEE LAKE HYDROELECTRIC PROJECT PETERSBURG PEAK LOAD CHART LAST FIVE YEARS PEAK LOAD EACH YEAR PEAK LOAD LAST FIVE YEARS fpccmereree ennai Ce a es 5 MW MW MW MW Mi KW PEAK TIME DATE AV.PER/HR 4.08 08:52 8 2.08 3.72 11:31 20 1.44 3.23. 1730524 1.75 3.56 16:47 2 1.84 4.13 10:22 18 1.52 3.83 17:37 10 1.34 3.04 11:14 24 1.70 2.85 09:47 3 1.42 3.30 9 11:35 (1 1.28 2.86 10:45 21 1.26 4.02 14:57 28 1.80 3.25 18:08 5 1.65 3.07 2131322 1.74 3.13 17:04 = 26 1.23 3.02 08:01 2 1.15 3.03 11:04 15 1.35 3.48 17:43 8 2.16 3.03. 17:07 9 1.76 - 207% . 12517 .. 28 1.39 ~ 2.83 10828 TT 7-140 arode42 08298... 20-1032 22 2.79 12:14. 10 1.36 ~ S448 21203 14 : 4.05 13:47 16 2.89 18357 22 - eoeal whaehO olor oe Jeo °-3627 3214508 =28 ~~ 1636-2 198 -1Ol 7 4.27 14d “RIE OAT -20- 3.34 18:38 28 3:95 10:19 13 3:19 1034212 3.27 i233 2 4.08 14:41 31 2.40 4.53 10:27. 7 3.11 3.41 16:24 3 2.16 3.33 19:53 6 1.91 3.65 14:10 19 1.90 2.76 16:25 21 1.70 JAN 90 4.11 16:59 27 2.19 “FEB 3.37 14556 6 2.15 MAR = 90 3.42 09:50 2) 1.95 APR 90 3.15 09:14 10 1.80 MAY 90 3.34 09:00 16 1.45 JUN 90 3.07 08:29 9 1.81 WL 4.30 12:45 17 2.50 AUG 90 4.19 16:39 19 2.89 SEP 90 3.70 13:19 18 2.31 ocr 90 3.05 15:15 24 1.75 Noy 890 3.93 14:54 21 2.01 DEC 90 3.33 16:58 17 2.22 JAN 91 4.44 10:56 = 25 2.48 FEB 91 3.70 14:42 28 2.11 y MAR O91 4.05 10:54 1 2ell APR 91 3.76 09555 9 1.93 MAY = 91 3.27 10:57) 1.79 JUN 91 3.61 16:36 27 1.63 JUL 91 4.31 10:23 27 2607 AUG 91 4.91 11529 3 3.04 TYEE LAKE - WRANGELL - PETERSBURG POWER SYSTEM STUDY RECEIVED AUG 7? 1984 ALASKA FO.VE2 AUTHORITY FINAL REPORT EBASCO EBASCO SERVICES INCORPORATED OCTOBER 8, 1982 | ALASKA POWER AUTHORITY | TYEE LAKE-WRANGELL- PETERSBURG POWER SYSTEM STUDY FINAL REPORT Prepared By: Dr. Joseph Hulanicki Mr. Morton Kevelson Mr. Herbert Linmer Dr. Daniel Mark Mr. Robert Meredith Mr. Frank Petree Dr. John Szablya, Lead Engineer Reviewed By: Dr. George Karady, Chief Electrical Consulting Engineer Project Manager: Mr. Stephen Simmons EBASCO SERVICES INCORPORATED 400 - 112th Ave N.E. Bellevue, Washington 98004 October 8, 1982 1766B TABLE OF CONTENTS I. INTRODUCTION ....... © 1 io] © @ ie) © 0 0 © © «ie © fe A. PURPOSE AND CONTENTS OF THIS REPORT...... eee B. BACKGROUND ......2. eee om 6 « Sw 6 sw « @ Coy THE, SELECTED PEAN SS ici. 3 wo ee) 6 ee lie eo II. DISCUSSION OF ALTERNATIVES .. 2... 22 ee ee sels) As TECO W38'KV ALTERNATIVE © 3 3 6 wis 7 ws 6 sw os B. MODIFIED 138 KV ALTERNATIVE. ..... oc ee C. 69 KV OPERATION WITH ONE DYNAMIC COMPENSATOR. cee 1. Description... .. eee eccee s7 mes 2. Normal Performance of Al ternative Cre) ee tel ie) oo 3. Contingency Performance of Alternative C .... E. G. 69 KV OPERATION WITH TWO DYNAMIC COMPENSATORS ... 1. Description. .... cris eel isis cltciis) sl elisilols 2. Performance of Alternative D .......2.2.-. 69 KV OPERATION WITH LTC SWITCHED COMPENSATION .. . 1. Description. ....... COND ECHONONGNCGEOHO 2. Perfomance of Alternative E SIS SMo Moin oNonaine 69 KV OPERATION WITH LTC AND POWER FACTOR CONTROL . . 1. Description... eccercecrccevcrecvce 2. Performance of Alternative F ......2-e eee COMPARISON OF ALTERNATIVES . 2. 2. 2 ee ee ee eee III. LOAD FLOW PERFORMANCE OF THE SELECTED ALTERNATIVE... . A. Voltage Control and Flicker... . +222 eee 1. Voltage Control Philosophy ....-+-+-+-+e- 2s Flicker. «© «2 so 6 « © 6 © i © © 0 + 3. Dynamic Voltage Control ......-2 eee B. Steady State Limitations ......-.2.eee-e 1. No Load Condition. ........ 2 eee 2. 12MW Load Level . 2... 2. Goa ado a 3. 23MW Load Level ...... oe) fol iste) (el (ols C. System Energization Sequence ...-+ + sees . D. System Operation with ALP Sawnill and Crystal Lake Generation... .. + ee eee ii TABLE OF CONTENTS IV. SHORT CIRCUIT STUDIES. ... Vv. DYNAMIC BEHAVIOR A. OVERVIEW AND CONCLUSIONS B. DESCRIPTION OF SYSTEM. . 1. 2. 3. 4. VI. One Line Diagrams . Programaing Details Load Acceptance . . Load Rejection .. REVIEW OF PROTECTION. ... oe ee (Continued) oe ee A. CONCLUSIONS AND RECOMMENDATIONS . . 1. 2. 3. 4. 5. 6. B. SUMMARY OF PROTECTIVE RELAY SCHEME 1. 2. 3. 4. 5. 6. 7. VII. CONCLUSION Tyee Lake Generator Protection Tyee Lake Unit Transformer Protection Tyee Lake 69/138 kV Line and Bus Protection Wrangell Switchyard......-. Wrangell Substation. ...... Petersburg Substation. ..... Tyee Lake Generator Protection Tyee Lake Unit Transformer Protection Tyee Lake 69/138 kV Line and Bus Protection Carrier Communication Channel ..... Wrangell Switchyard Protective Relay Wrangell Substation Protective Relaying Petersburg Substation. .......e. APPENDIX A - LINE CHARACTERISTICS APPENDIX B APPENDIX C APPENDIX D APPENDIX E PER UNIT LINE IMPEDANCES TRANSFORMER CHARACTERISTICS . GENERATOR CHARACTERISTICS... . « IMPEDANCE DIAGRAMS: LOAD FLOW AND SHORT CIRCUIT... 2.22 ee eee iii . . . . . . oe ee we wo Page IV-1 V-1 V-1 V-2 V-2 V-2 V-6 V-11 VI-1 VI-1 VI-1 VI-1 VI-3 VI-3 VI-3 VI-3 VI-3 VI-3 VI-5 VI-5 VI-5 VI-5 VI-6 VI-6 VII-1 A-1 B-1 C-1 D-1 APPENDIX F APPENDIX G APPENDIX H APPENDIX I TABLE OF CONTENTS SHORT CIRCUIT CALCULATIONS (Continued) GENERATOR VOLTAGE REGULATOR SPECIFICATIONS GOVERNOR MODEL ACCORDING TO ESCHER WYSS.. . MODELING OF CHIPPER MOTOR FOR ALP SAWMILL AT WRANGELL.. 2... iv Page F-1 G-1 H-1 LIST OF TABLES Table No. Title Page III-A-1 Flicker Levels III-3 ITI-A-2 Indicative Figures Showing Relationship Between Real And Reactive Power While Maintaining Constant Voltages at Both Tyee Lake and Wrangell III-7 III-C-1 Energization Flickers III-14 III-D-1 Loading Conditions at Crystal Lake TII-16 IV-1 Tyee Lake Transmission System Short Circuit Duties (Without ALP Sawnill at Wrangell) Iv-4 IV-2 Tyee Lake Transmission System Voltages in Percent During Symmetrical Three Phase Short Circuits (Without ALP Sawmill at Wrangell) Iv-5 Iy-3 Tyee Lake Transmission System Short Circuit Duties (With ALP Sawmill at Wrangel1) IV-6 Iv-4 Tyee Lake Transmission System Short Circuit Duties (With Only Tyee Generators on the System) IV-7 V-1 Data Developed From Anderson and Fouad y-4 V-2 Load Acceptance: Conditioning Prior to Staring Motor V-7 V-3 Load Acceptance: Starting Conditions V-7 y-4 Load Rejection: Conditions Prior to Loss of Load. 50% of the Loads Shown are Dropped V-12 y-5 Load Rejection: Conditions Following Loss of Load V-12 V-6 Range of Exciter Output Voltage V-18 VI-1 List of Drawings Reviewed VI-2 Figure No. I4 1-2 II-A-1 II-A-2 II-A-3 II-C-1 II-C-2 II-C-3 11-c-4 II-C-5 II-C-6 II-C-7 II-C-8 II-C-9 II-E-1 II-E-2 II-E-3 II-E-4 LIST OF FIGURES1/ Title Tyee Lake Transmission System: Area Map Tyee Lake System: One Line Circuit Diagram, 69 kV Tyee Lake System: One Line Circuit Diagram, 138 kV Performance of Alternative A: 30 MW Load Performance of Alternative B: No Load Performance of Alternative C: No Load Performance of Alternative C: 12 MW Load Performance of Alternative C: 23 MW Load Performance of Alternative C: 33 MW Load Contingency Performance of Alternative C: No Load, Two Tyee Lake Generators, Without the Petersburg Compensator Contingency Performance of Alternative C: No Load, One Tyee Lake Generator Contingency Performance of Alternative C: 12 MW Load, One Tyee Lake Generator at 0.95 p.u. Voltage Contingency Performance of Alternative C: 12 MW Load, One Tyee Lake Generator at 1.05 p.u. Voltage Contingency Performance of Alternative C: 23 MW Load, Two Tyee Lake Generators, Without Petersburg Compensator Performance of Alternative E: No Load, With Wrangell Reactor Contingency Performance of Alternative E: No Load, Without Wrangell Reactor Performance of Alternative E: 12 MW Load, With Wrangell Reactor Contingency Performance of Alternative E: 12 MW Load, Without Wrangell Reactor V/ a figures follow the respective chapter they appear and in the sequence given. vi Figure No. II-E-5 II-E-6 LIST OF FIGURES (Continued) Title Performance of Alternative E: 23 MW Load, O MVAR at Wrangell, With Wrangell Capacitor Performance of Alternative E: 23 MW Load, 3 MVAR at Wrangell, With Wrangell Capacitor The following figures deal with the selected alternative: III-B-1 III-B-2 III-B-3 ITI-B-4 III-B-5 III-B-6 III-B-7 III-B-8 III-B-9 III-B-10 III -B-11 III-C-1 III-C-2 III-D-1 V-1 V-2 V-3 No Load, Two Tyee Lake Generators No Load, One Tyee Lake Generator Contingency: No Load, Two Tyee Lake Generators, Without Wrangell Reactor Contingency: No Load, One Tyee Lake Generator, Without Wrangell Reactor 12 MW Load, Two Tyee Lake Generators 12 MW Load, One Tyee Lake Generator 12 MW Load, 4 MVAR at Petersburg, One Tyee Lake Generator Contingency: 12 MW Load, Two Tyee Lake Generators, Without Wrangell Reactor Contingency: 12 MW Load, One Tyee Lake Generator, Without Wrangell Reactor 23 MW Load, Two Tyee Lake Generators 23 MW Load, Two Tyee Lake Generators, Reduced MVAR Flow From Petersburg to Wrangell Line Energization: Conditions Prior to Switching on the Wrangell-Petersburg Line Section Line Energization: Conditions Following Switching on the Wrangell-Petersburg Line Section Operation with Crystal Lake and ALP Sawnill Connected to the Systen Load Acceptance (LA) One Line Schematic Load Rejection (LR) One Line Schematic Computer Model of Exciter vii Figure No. V-4 V-10 V-11 LIST OF FIGURES (Continued) Title Load Acceptance (LA): System Behavior in Case of Starting Chipper Motor At ALP Sawmill In Wrangell. 500 HP motor across line start. 1 Tyee Lake generator and AVC with line compensation. Loads: Wrangell 3.5 MW, ALP 2.5 MW, and Petersburg 5 HW. Load Acceptance (LA): System Behavior in Case of Starting Chipper Motor At ALP Sawmill In Wrangell. 1 Tyee Lake generator and AVC without line compensation. Loads: Wrangell 3.5 MW, ALP 2.5 MW, and Petersburg 5 MW. Load Acceptance (LA): System Behavior in Case of Starting Chipper Motor At ALP Sawnil] In Wrangell. 350HP motor across line start. 1 Tyee Lake generator and AVC with line compensation. Loads: Wrangell 4 MW, ALP none, and Petersburg 8 MW. Load Acceptance (LA): System Behavior in Case of Starting Chipper Motor At ALP Sawmil] In Wrangell. 350HP motor 60% voltage start. 1 Tyee Lake generator and AVC with line compensation. Loads: Wrangell 4 MW, ALP none, and Petersburg 8 MW. Load Acceptance (LA): System Behavior in Case of Starting Chipper Motor At ALP Sawnill In Wrangell]. 350HP motor 60% voltage start. 3 Tyee Lake generators and AVC with line compensation. Loads: Wrangell 4 MW, ALP none, and Petersburg 8 MW. Load Acceptance (LA): Chipper Motor Perfomance During Startup: Slip and Motor Terminal Voltage and current as a Function of Time. 350HP motor across line start. 1 Tyee Lake generator and AVC with line compensation. Loads: Wrangell 4 MW, ALP none, and Petersburg 8 IW. Load Acceptance (LA): Chipper Motor Performance During Startup: Slip and Motor Terminal Voltage and current as a Function of Time. 350HP motor 60% voltage start. 1 Tyee Lake generator and AVC with line compensation. Loads: Wrangell] 4 MW, ALP none, and Petersburg 8 MW. Load Acceptance (LA): Chipper Motor Performance During Startup: Slip and Motor Terminal Voltage and current as a Function of Time. 350HP motor 60% voltage start. 3 Tyee Lake generators and AVC with line compensation. Loads: Wrangell 4 MW, ALP none, and Petersburg 8 MW. viii Figure No. V-12 V-13 V-14 V-15 V-16 V-17 LIST OF FIGURES (Continued) Title Load Acceptance (LA): Chipper Motor Performance oe Startup: Slip and Torque as a Function of Time. 350H motor 60% voltage start. 3 Tyee Lake generators and AVC with line compensation. Loads: Wrangell 4 MW, ALP none, and Petersburg 8 MW. Load Rejection (LR): System Behavior if 50% of the Loads of Wrangell and Petersburg are Dropped Simultaneously. 1 Tyee Lake generator and AVC with line compensation. Initial Loads: Wrangell 2 MW and Petersburg 3 MW. Water starting time constant Ty = 0.63 seconds. Load Rejection (LR): System Behavior if 50% of the Loads of Wrangell and Petersburg are Dropped Simultaneously. 1 Tyee Lake generator and AVC with line compensation. Initial Loads: Wrangell 2 MW and Petersburg 3 MW. Water starting time constant Ty = 1.25 seconds. Load Rejection (LR): System Behavior if 50% of the Loads of Wrangell and Petersburg are Dropped Simultaneously. 3 Tyee Lake generators and AVC with line compensation. Initial Loads: Wrangell 2 MW and Petersburg 3 MW. Water starting time constant Ty = 1.82 seconds. Load Rejection (LR): System Behavior if 50% of the Loads of Wrangell and Petersburg are Dropped Simultaneously. 3 Tyee Lake generators and AVC with line compensation. Initial Loads: Wrangell 6 MW and Petersburg 9 MW. Water starting time constant T,, = 1.86 seconds. Load Rejection (LR): System Behavior if 50% of the Loads of Wrangell and Petersburg are Dropped Simultaneously. 3 Tyee Lake generators and AVC with line compensation. Initial Loads: Wrangell 6 IW and Petersburg 9 MW. Water starting time constant T, = 1.25 seconds. ix I INTRODUCTION A - PURPOSE AND CONTENTS OF THIS REPORT The purpose of this report is to present the results of studies conducted by Ebasco, on behalf of the Alaska Power Authority (APA), regarding the Tyee Lake - Wrangell - Petersburg transmission system. The report includes a comparison of several alternative transmission plans which could be used (Section II). The plans vary in voltage level, means of voltage control and reactive compensation. All share a common transmission configuration consisting of a single circuit from Tyee Lake, to Wrangell, to Petersburg, as shown in Figure I-1 at the end of this chapter. It also includes a detailed performance analysis of the plan which has been selected for implementation (Section III) . This analysis has been used to evaluate transformer taps and to define the acceptable range of load power factors and levels. Short circuit studies were also run for the selected plan for various stages in its development (Section IV). These can be used to size circuit breakers and to aid in fuse coordination at the distribution level. B - BACKGROUND The Alaska Power Authority is constructing the first two of three possible hydro units at Tyee Lake in Southeastern Alaska. The 12.5 MVA units are schedule for completion by the end of 1983. The power produced is to be transmitted from the mainland to the cities of Wrangell and Petersburg, located on islands off the Alaskan Coast. Both cities now generate most of their electric energy by use of diesel generators. Total load is less than 10 MW. The transmission configuration selected involves four underwater crossings, totalling nearly 13 miles, and over 72 miles of overhead line. Some of the right-of-way is to follow and rebuild an existing 22.9 kV line which connects a small hydro plant to Petersburg. A tentative design and voltage level (138 kV) for the line and cables was established by International Engineering Company (IECO), the primary contractor on the power plant construction. IECO recommended and APA 0191T concurred that system studies should be conducted to confirm the voltage level selected and to refine electrical parameters for the project. EBASCO was selected to conduct those studies. EBASCO's initial studies of the tentative 138 kV plan revealed serious deficiencies and a need for either investigation of additional alternatives or substantial improvements to the original plant. These results were discussed with APA in a meeting held in April 1982. An analysis of the original 138 kV Plan and a possible means of correcting some of its problems are discussed as Alternatives A and B in Section II of this report. As a result of that meeting, APA instructed EBASCO to investigate one or More alternatives to the use of 138 kV, namely plans involving operating the line at 69 kV. This appeared to be the most promising way of reducing the costs and the potential problems of the 138 kV plans. Alternatives C, D, and E in Section II describe three 69 kV alternatives which were investigated and discussed with APA in June 1982. C - THE SELECTED PLAN Based on the performance of Alternative E, a fourth 69 kV alternative F, was developed jointly by EBASCO and APA. It was intended to be less expensive than any of the other alternatives. Because of its low cost, it has been selected for implementation. Its basic featues are described ina one-line diagram in Figure I-2 presented at the end of this chapter. In brief, it provides for initial operation of the transmission line at 69 kV. This minimizes capacitive line charging requirements of the underwater cables. A 7.5 MVAR shunt reactor is provided to allow operation of the system with only one generator in service, without excessive generator reactive loadings. Voltage control is by means of generator excitation control and load tap changers (LTC) on all step-down transformers. Operation of the system is discussed in detail in Section III. 1-2 mew VN ’ € a. 4 . ' ame OVERHEAD: LINE SUBMARINE CABLE © ot 37 SUBSTATION /\SWITCH YARD. = @ -:SYBMARINE GABLE “e A, Bote bo “* ls e* poral 4 ’ . THEE Lame prose} Ty: 138 KV TRANSM SSION SYSTEM | AREA|MAPS) ) ° i: Fie end & \; ie Bethe: 5 irk TA Ram Ls manne a voted bane Mena ; ye STATION SERVICE Ba pico 1-2 Fo- _ Sa- Tire ye TYEE LAKE SYSTEM CN Ns 25/1 SMVA it fo MAIN SINGLE-LINE DIAGRAM i ti (TYPICAL) 6aKv 69 kV ALTERNATIVE WITH 7.5 MVAR REACTOR 12. SMVA 13. 8KV PFe.9 (TYPICAL) © 7 3.91 MILES OF DOVE 2.08 MILES OF SUBMARINE CABLE 13.1 MILES OF 37 ©8 ALUMOWELD 4,52 MILES OF DOVE 7.08 MILES OF 37 ©8 ALUMOWELD 3.04 MILES OF DOVE’ 4.82 MILES OF 37 ©8 ALUMOWELD 3.04 MILES OF DOVE 3.09 MILES OF SUBMARINE CABLE a £. oO r 3.22 MILES OF WRANGELL SaW-MILL FEEDER swan polentt se ae SKV 4 MILES OF DOVE ~ Tew iawa 4 v on rR 1,5 MILES 38. 1/0ACSR SUBMARINE CABLE A os @-+-+- fr 12. 5-2. 4KV D 2.03 ures 2. 4Ky 25. 5% § OF DOVE | ¢ \- — 3MVA VP 4.s0 waives oF 8 ava _ 2, 4-, 48KV 3 SUBMARINE CABLE roars Dee @- = ct IMvA 2. SMVA STEAM 11.2 MILES % 12. 5-2. 4KV A 12, 5-2. 4Kv 0. SPF OF DOVE 3 4 225. 5% #2. 5% A 3.45 MILES 4 OF DALIA 3 | 1O00KW 1000KW 2.61 MILES rpagl FOR 56 1.56 1.5 STATION “eee 4.32 MILES FOR 1. ~ 1.56 1.56 .625 .625 NA, OF DALIA 1 2 MYA MVA MYA MVAOMVA MA SERVICE oe eee say @- Tete a 202. 5% 12/16/20MVA rag a 68-24. aR 4 ZH-L=5% ZH-Te10. 5% ZL-T97. % PETERSBURG 24, 9KV 7. S/ 10MVA a 24, 9-2. 4KV 1800KW is S FEEDERS 24, 9-2. 4KV 10 MILES MITKOF LUMBER MILL TAPPED FR OF RAVEN pus EXISTING a ax CRYSTAL : LAKE LINE 3 2. 4-. 48KV 3 —_—__.—_——_ 1250 2100 350 T STATION 2400V FEEDERS ww oOGKWté«w«‘SWY Staion 2. SMVA 24, 9-2. 4KV aw nw 2+505% 2. 4KV II DISCUSSION OF ALTERNATIVES A - IECO 138-KV ALTERNATIVE The tentative transmission plan provided by IECO provides for 138 kV operation of the entire circuit from Tyee Lake to Petersburg. A 5 MVAR shunt reactor is provided for reactive compensation at Wrangell. A one-line diagram is shown in Figure II-A-1 at the end of this chapter. Load flow studies were first conducted on this alternative by EBASCO. The results of those studies were reported to APA in April 1982. In brief the load flow results show that line charging currents fron the 138 kV cables are: ° well beyond the capability of the generators to absorb, and ° Would create large voltage gradients in flowing through the generator transformers. A load flow case was run with the system fully-loaded (30 MW) on three generators, the results of which are shown in Figure II-A-2 at the end of this chapter. It provided the maximum reactive load demand (90% power factor), maximum system losses, and the highest system capability to absorb reactive power. Nevertheless, the generator reactive loadings at approximately 11 MVAR each substantially exceeded their full load reactive capabilities of about 5 MVAR each at full load. Light load cases and cases having less than three generators would show much more excessive reactive loadings on the remaining generators and higher 138 kV voltage levels. B - MODIFIED 138 KV ALTERNATIVE The steady-state problems of Alternative A can be remedied by adding more shunt compensation to the 138 kV system. The cables and lines produce nearly 55 MVAR of charging at 138 kV. Increasing the compensation level to at least 50 MVAR would allow one generator to absorb the remaining line charging reactive power at light load. II-1 A load flow case with about 50 MVAR of reactors distributed on the 138 kV system, shown in Figure II-A-3 at the end of the chapter, indicates that loadings on the generators are light and no significant voltage gradients appear across the system. There are still several drawbacks to even this improved systen: 1 - Line reactive compensation would have to the matched closely with line charging on the Tyee-Wrangell and Wrangell-Petersburg sections, so that an outage of the Wrangell-Petersburg section would not force a large reactive unbalance on the remaining system. This would require at least two different reactor sizes. 2 - Loss of a large shunt reactor would produce a large voltage rise and excessive generator reactive loadings. Either the affected line would have to be shut down until a spare reactor (of the correct size) could be connected or many small reactors (say five MVAR) would have to be used. Another alternative would be to use dynamic reactive compensation to aid the generators. Any of these approaches would add substantial costs for reactors. 3 - Transient frequency rise, say from loss of a large amount of load at Petersburg, would change the degree of compensation of the system. A ten percent overspeed, for instance, would increase line charging currents by ten percent and decrease shunt reactor currents by ten percent. The resulting reactive unbalance of about 11 MVAR would produce additional voltage rise and would have to be absorbed by the generators. A single generator might become over-excited, unless 100% line compensation were normally achieved. 4 - During energizing of the 138 kV line, line charging currents and shunt reactor currents do not cancel, as they do in steady-state. The unbalance appears as a large magnitude transient current in the generator and as a large magnitude overvoltage on the line. Without detailed study, it appears that overvoltages could approach two per-unit and currents in the generator could exceed short circuit II-2 levels. A unique problem of this nature deserves detailed study to assure that electro-mechanical interactions with the generator would not result in excessive shaft torques, perhaps near a critical non-synchronous frequency. 5 - A138 kV line, shunt-compensated to 10%, is vulnerable to resonant voltage rises when disconnected from the remainder of the system, if excited by a parallel transmission line. The parallel location of the Petersburg-Crystal Lake 24.9 kV circuit and the Wrangell-Petersburg 138 kV circuit would provide such an opportunity for resonance. This would pose a safety hazard whenever that portion of the 138 kV line were "“denergized" for maintenance. 69 KV OPERATION WITH ONE DYNAMIC COMPENSATOR 1 - Description Alternative C requires dynamic voltage regulation at Petersburg and + 10% load-tap-changers (LTC) on both the Petersburg and Wrangell transformers. The dynamic voltage regulation may be provided by either a static compensator (Treble-Tripler) or a static var system having a range of about six MVAR lagging to ten MVAR leading. The sizing of the leading (capacitive) range could increase if distribution power factors are not maintained at nearly unity power factor at load levels above 25 MW. The alternative is designed to operate under normal conditions up to the maximum capability of three Tyee Lake generators (about 38 MW). An outage of one Tyee Lake generator or the static compensator would require reduction of load to about the capability of two Tyee Lake generators and possibly starting of the available diesel generators to assist in voltage regulation. The LTC at Petersburg would normally be blocked except for periods in which the static compensation is out of service. The forced outage rate of the compensation system is estimated at less than 0.5% of the time, whereas one or more Tyee Lake generators out of three would be expected to be forced out of service about 5.0% II-3 of the time. Thus the forced unavailability of the system would be increased only slightly by the lack of redundancy in the compensation system. Scheduled maintenance requirements on the compensation system are also likely to be less than 0.5% of the time and may easily be scheduled during low load periods when the LTC can provide adequate voltage regulation. The static compensator constitutes the major cost for voltage regulation. Contacts with General Electric, ASEA, Westinghouse and GEC (English) indicate that the material costs without shipping and installation are likely to run from $750,000 to $900,000 for a device with a -6 to +10 MVAR range. Larger or smaller devices are available at relatively low incremental costs or savings. As an example, for twice the money it is possible to obtain ten times the rating or, alternatively, a second device. 2. Normal Performance of Alternative C The normal performance of Alternative C is shown in Figures II-C-1 thru II-C-4 for load levels of 0, 12, 23 and 33-MW, respectively. These cases are discussed individually later with all figures being presented at the end of this chapter. These load levels result in maximum loading on the lagging capacity of the static compensator as well as one, two and three generator units. Only Figure II-C-4 assumes that the third Tyee Lake generator is in service. In all cases the low side taps at Tyee Lake and Petersburg are set at 1.05 per unit, which was found to give the best performance. Wrangell has an LTC and its tap position is shown in each case. The voltage regulation philosophy for Tyee Lake has been to attempt to hold 0.97 to 0.98 per unit voltage at the Wrangell Switchyard. This requires that the voltage and the real and reactive loadings be monitored at the Tyee Lake 69 kV bus so that the operator and the automatic voltage regulator can determine the voltage at the Wrangell Switchyard. II-4 The voltage schedule at Tyee Lake is not critical unless the compensator at Petersburg were to reach its upper or lower limits because of an improper Tyee Lake voltage schedule. That will always be a function of the reactive load on the system. The 0.97 to 0.98 per unit level assumes that load power factors are about unity. If greater than zero reactive load is present on the system it may be desirable to raise the Wrangell Switchyard voltage schedule so that Tyee Lake can unload the leading output of the static compensator at Petersburg. Alternatively the tap ratio at Petersburg could be changed. a. Figure II-C-1 Note that in Figure II-C-1, Tyee Lake is unable to lower the Wrangell Tap voltage to 0.98, so it is limited to operation at its lower voltage limit of 0.95 per unit. This minimizes the line charging which must be absorbed by the compensator at Petersburg. Setting a desired voltage schedule for the Wrangell Tap lower than the indicated 0.99 per unit voltage insures that Tyee Lake will operate to maximize its VAR intake in this condition. b. Figure II-C-2 This figure shows operation at the 12 MW level. Note that system losses have increased just enough to depress the Wrangell voltage to 0.97 per unit while Tyee Lake is still at 0.95 per unit. This indicates that Tyee Lake would probably remain at its lower voltage limit until greater than 12 MW of load or large reactive loads are on the systen. c. Figure II-C-3 Between the 12 and 23 MW levels, system losses increase enough that the voltage at Tyee Lake must be increased above its minimum level to hold voltage at the Wrangell Switchyard. This case shows that it will have to almost reach its upper limit of 1.05 per unit to hold the desired 0.97 to 0.98 per unit at the II-5 Wrangell Switchyard. Note also that if load power factors are corrected to nearly unity the Petersburg compensator will float and therefore its outage will not be critical even at the 23 MW load level. d. Figure II-C-4 This shows performance at the 33 MW load level. With nearly six MW of losses this represents transmission of the maximum head output of all three Tyee Lake generators. The compensator at Petersburg is required to backfeed nine MVAR into the transmission system, assuming unity power factor on the secondary at Wrangell. It would be preferable for Wrangell to backfeed VAR into the system at this load level also. The most critical problems at this load level would be loss of one Tyee Lake generator or the Petersburg compensator. Either event would require dropping load back to about the levels shown in Figure II-C-3. Both under-frequency and under-voltage load-shedding relays should be provided on the system to rapidly eliminate the excess load. 3. Contingency Perfomance of Alternative C a. Figure II-C-5 This represents no-load energizing of the system from two Tyee Lake generators without the Petersburg compensator. In this case the LTC at Petersburg would be set at about 0.925 per unit to lower the secondary voltage to 1.0 per unit. This establishes the maximum bucking tap setting. Note that 69 kV voltages are all less than the 1.10 per unit of transformer winding which is allowed. However, the taps at Tyee may not be changed another 2.5% to raise 69 kV voltages without exceeding 1.10 per unit. This establishes that the 1.05 per unit low side tap used in the cases at Tyee Lake is preferable to a 1.025 per unit tap, which would result in excessive voltages at Petersburg for this case. II-6 b. Figure II-C-6 This represents no load operation of the system with one Tyee generator unit. Because Tyee Lake cannot hold the 69 kY voltage down as well with only one unit the compensator is required to absorb more, or to allow the voltage to rise. This is the worst case lagging loading for the compensator. Some reduction of the compensator loading is possible if the tap on the LTC at Petersburg were changed from its 1.05 per unit level. That would add additional operating complexity by creating an exception to the rule that the tap changer would not operate unless the compensator were out of service. Such an exception to reduce the lagging range of the compensator by two or three MVAR was felt unwarranted. c. Figures II-C-7, 8 These figures represent full load operation of only one Tyee Lake generator unit. The Tyee Lake generator unit voltage has been varied between the normal 0.95 per unit required to hold 0.98 at the Wrangell Switchyard and 1.05 per unit, to show the reduction in reactive loading on the generator unit. If power loadings greater than those now expected for maximum head operation should be possible, the reactive capability of the generator could be quite limited. This operating procedure would allow operation at nearly unity power factor on the generator to obtain maximum energy production. However, it could increase lagging loadings on the Petersburg compensator. Keeping the lagging capability at six MVAR as indicated in Figure II-C-6 would ensure that this operating procedure would be available to relieve reactive loadings on one Tyee Lake generator. II-7 d. Figure I1-C-9 Figure II-C-9 shows one operational limit of the system at the 23 MW level without the Petersburg compensator. The LTC at Petersburg is at its limit of 1.13 per unit (206 above 0.925 per unit from case II-C-5). The system can supply only about one MVAR at Wrangell and 1.0 MVAR at Petersburg. Any additional load derand would cause severe voltage depression and must be supplied locally. However, if diesels and Crystal Lake hydro Can supply the net load reactive demand, the system would be operable. D - 69 KV OPERATION WITH TWO DYNAMIC COMPENSATORS 1 - Description Alternative D varies from Alternative C in that two static compensators would be provided at Petersburg and the LTC would be eliminated at Petersburg. Its main advantage is that excellent voltage regulation would be obtained even during on outage of one Compensator. Also by virtue of the doubled regulation capability, correction of distribution power factors would not be required, for transmission reasons, until the system load exceeded the capability of two Tyee Lake generators. Although this alternative would be required to meet single contingency outage criteria, especially at the highest load levels, it is not recommended, because of its higher cost. The equipment costs are estimated to be $500,000 to $800,000 greater than Alternative C, even with consideration of the savings from not having LTC on the Petersburg transformer. Since the generator, line, and transformer outages may cause even more severe system disruption than failure of a static compensator, it seems unnecessary to provide redundancy in this one device to avoid a low probability event. Voltage regulation provided by Crystal Lake hydro, Petersburg diesels and the Petersburg LTC in Alternative C should be able to provide enough voltage regulation during contingencies. II-8 2 - Perfomance of Alternative D Contingency cases for Alternative D are trivial in comparison to Alternative C. Loss of a compensator would leave the system in the nomal conditions of Alternative C. For any other outage Petersburg compensation would just have more reserve capability than in Alternative C. System power factors of as poor as 90% could easily be served under normal and contingency conditions at up to the 23 MW level because of the additional 10 MVAR of compensation. For load levels of up to 33 MW, unity power factor loads could be served even during a compensator contingency. 69 KV OPERATION WITH LTC & SWITCHED COMPENSATION 1 - Description Alternative E varies from Alternative C in that it has no dynamic compensation at Petersburg. Instead it attempts to extend the regulating ability of Tyee Lake by use of a switched capacitor and a switched reactor at the Wrangell Switchyard. These two devices would be connected on the line to Petersburg and would be tripped in the event of a fault on that line. Both devices are tentatively sized at 7.5 MVAR. This alternative (at a cost of approximately $300,000 for the reactor and capacitor) is several hundred thousand dollars less expensive than Alternative C, but is incapable of transmitting power from more than two Tyee Lake generators. It also would suffer fron very high flicker (about 18) when the reactor and capacitor are switched, and to a lesser degree when large loads are lost or connected. Alternative E's main advantage is its lower initial cost and its ability to delay a major investment in a reactive Compensation system, which can be deferred until the third Tyee Lake generator is added. In fact even the 7.5 MVAR capacitor bank would not be needed until loads exceeded the capability of one Tyee Lake generator. II-9 2 - Performance of Alternative E Alternative E depends upon switching of a capacitor and a reactor at the Wrangell Switchyard to extend the regulating range of the Tyee Lake generators. Within a limited range of reactive loading conditions Tyee Lake would be able to regulate the voltage at the Wrangell Switchyard. Extra voltage drop and drops beyond the Wrangell Switchyard would be corrected by Wrangell and Petersburg LTC to the limit of their ranges. In operation the reactor and capacitor would be switched on or off by either supervisory control from Tyee Lake or by voltage control at Wrangell after a time delay. When properly coordinated the Tyee Lake generators would be compensated to regulate the voltage at the Wrangell Switchyard. Switching of the reactor off, or the capacitor on, would be initiated when the Tyee Lake generator bus reached 1.05 per unit voltage, its upper limit. Switching in reverse would be done when Tyee Lake reached its lower limit of 0.95 per unit. In either case switching 7.5 MVAR size blocks would require Tyee Lake to change its generator voltage by about 9% to hold the Wrangell voltage at its pre-switching level. Thus 7.5 MVAR is the largest block which can be switched without hysteresis switching resulting. Smaller blocks would be preferable but costs would increase substantially for use of even half-size blocks. Supervisory control of the switching at the Wrangell Switchyard from Tyee Lake is preferred, but a sustained voltage drop below normal at the Wrangell Switchyard could also be used to indicate that Tyee Lake had reached its regulating limit. In the latter case a significant voltage drop (say 24) would be required at Wrangell before switching. This would ensure that Tyee Lake had actually reached its limit of regulation and what was being measured at Wrangell was not just measurement error or voltage regulator compensation error at Tyee Lake. Thus, without supervisory control over the switched facilities at the Wrangell Switchyard, the difference between pre-and II-10 post-switching voltages is likely to be larger than with supervisory control. The steady-state voltage level change which would occur at Wrangell would equal the necessary voltage drop. It would persist until taps were changed. The performance of this alternative is difficult to define because there are three reactive load conditions that are possible at the Wrangell Tap and numerous possible tap ranges which could be selected for the transformers. The following discussion attempts to define limits of operation, rather than exact operating points (all figures are presented at the end of this Chapter). a. Figure II-E-1 This shows no-load energizing of the system. Taps at Petersburg and Wrangell need provide only a slight boost to cope with this condition. If one Tyee Lake generator unit were lost, voltages would be about 3% higher on the 69 kV system and the remaining generator would carry about six MVAR instead of five. b. Figure I1-E-2 Figure II-E-2 shows the performance of Alternative E for failure of the 7.5 MVAR shunt reactor at unloaded conditions. Performance would be identical to that of Alternative C with failure of the compensator at Petersburg. As in that case a 0.925 tap would be required as the maximum buck position on the Petersburg transformer. Conditions at Wrangell are also identical. c. Figure II-E-3 This figure shows that at the 12 MW level, with the reactor in service, as much as 2 MVAR of reactive load could be served by the transmission system before Tyee Lake would lose the ability to regulate the Wrangell voltage at about the 0.97 to 0.98 per unit level. At about this real and reactive loading the reactor II-11 would be switched off. Figure II-C-2 of Alternative C shows approximately the resulting condition after switching thereactor off. The Tyee Lake generator voltage would have to be slightly higher to serve two MVAR of reactive load, so its voltage change would be slightly less than the 10% difference shown between Figures II-E-3 and II-C-2. d. Figure II-E-4 This figure, also at the 12 MW level, shows the maximum reactive demand which can be shipped to Petersburg with Wrangell at unity power factor and no reactor or capacitor at the Wrangell Switchyard. Note that the Wrangell voltage is still on schedule. Any redistribution of the reactive load between Wrangell and Petersburg would have no effect on the Wrangell voltage except for a possible reduction in reactive losses. One can conclude that more than 8 MVAR can be served at this load level. This means that neither distribution power factor correction nor the Wrangell capacitor would be required at the 12 MW load level. An outage of one generator unit would have no effect on this conclusion, since reactive loading on two units is very light. If the reactive load on the system were not at so high a level, the shunt reactor could be restored to service to produce the sane effect. e. Figures II-E-5, 6 Between the 12 and 23 MW load levels, reactive losses increase substantially. These figures show that the 7.5 MVAR capacitor will be required if one wishes to serve as much as six to seven MVAR load at Petersburg and Wrangell. If the loads on the system were at unity power factor, the capacitor would not be needed, as shown in Figure II-C-9. II-12 One can conclude that by the time the 23 MW load level is reached, any reactive load on the system must be supplied from sources other than Tyee Lake. These figures represent the limit for reactive power shipped to Petersburg from the Wrangell Switchyard. On a system-wide basis only about seven MVAR and 23 MW of load can be served by this alternative. This represents about a 96 power factor. For load levels higher than 23 MW the reactive losses increase so rapidly that it is unlikely that the system power factor could be controlled by anything other than a dynamic voltage control device, such as the static compensators of the other alternatives. EBASCO would recommend that if this alternative were pursued, dynamic voltage regulation should be added at Petersburg when the third Tyee Lake generator was added. Its dynamic range could be less than that of Alternative C - perhaps 0 to 10 MVAR - because of the additional facilities at the Wrangell Switchyard. F - 69 KV OPERATION WITH LTC & POWER FACTOR CONTROL 1 - Description Alternative F is a simplification of Alternative E in that it controls the voltage by means of a 7.5 MVAR reactor permanently Connected at the Wrangell Switchyard, LTCs at Petersburg and Wrangell, and the generator(s) at Tyee Lake. This arrangement eliminates the reactor-switching flicker by not switching either it or a large capacitor. Like Alternative E it is limited to transmitting power from not more than two generators but it requires much more careful control over power factors at the distribution level at Wrangell and Petersburg if the full capacity of two generators is to be utilized. The voltage at Wrangell will be controlled as in Alternative E by line drop compensation of the Tyee Lake generators. The largest flicker problem will occur at Wrangell when the line to Petersburg is energized. It can be reduced by synchronizing some diesel generators at Wrangell to reduce the impedance of the system during switching. EBASCO estimates that the Shunt reactor of this alternative will cost approximately $200,000. II-13 2. Performance of Alternative F The performance of Alternative F is very similar to that of Alternative E. The major difference is that even at the 23 MW load level the 7.5 MVAR reactor will be in service. This requires that the distribution power factors at Wrangell and Petersburg be Controlled to backfeed reactive power to the transmission system as a function of load level. Figure III-B-10 presented at the end of the next chapter shows a load flow case with about six MVAR being backfed. Additional details of the performance of this alternative are discussed in Section III. G - COMPARISON OF ALTERNATIVES The six alternatives discussed in this section were compared to each other in a variety of ways. Gradually all but Alternative F were eliminated. Alternative A, the original 138 kV plan could not perform acceptably even in steady-state conditions. It was eliminated from further consideration. Alternative B, a modified 138 kV plan, was one of several possible ways of improving Alternative A to eliminate its steady-state problems. All of these 138 kV plans would have required relatively-high costs for shunt compensation, including spare components or dynamically-controlled devices. They also all appear vulnerable to high transient overvoltages and possible electro-mechanical interactions in the generators. Because there was inadequate time to study these problems in the required detail, without delaying the project service date; and because the costs appeared higher than for other alternatives, the 138 kV plans were rejected. Alternatives C and D, 69 kV plans with dynamic shunt compensation, were judged to provide good steady-state and transient performance in all respects. The only significant difference between the plans was the contingency level which would cause problems. Costs for the dynamic Compensators were also relatively high. The costs of two compensators in Alternative D, for instance would probably exceed the costs of shunt II-14 reactors for a 138 kV¥ plan. APA also judged that a lower level of performance could be accepted if it would reduce or defer major expenditures. Alternative E, using a switched 69 kV shunt reactor and capacitor was shown to provide adequate steady-state performance at a much lower cost than any of the previous plans. Its major problem was that switching the 7.5 MVAR reactor or the 7.5 MVAR capacitor would produce large amounts of flicker. It also was inadequate to provide service to more than 25 MW of load. Of the two problems, the flicker was regarded as the more serious because it would occur at an earlier future date than the load limitation. Alternative F continued the cost reduction approach even further, but eliminated the major flicker problem by not switching the 7.5 MVAR reactor and by eliminating the 7.5 MVAR capacitor. Its major problem is that load power factors must be over-corrected as the load grows, to allow the 7.5 MVAR reactor to remain in service. APA judged that the Cost savings from this plan were significant enough to live with that limitation, at least initially. This alternative was, therefore, selected for implementation. II-15 FIGURE II-A-1 TYEE LAKE SYSTEM MAIN SINGLE-LINE DIAGRAM 138 kV ALTERNATIVE A CRYSTAL Lame FIGURE II-A-2 TYEE LAKE - WRANGELL - PETERSBURG LOAD FLOW CASE WITH 30 MW LOAD AT .9 PF 10.9 J:0-6 10.5 f0-6 10.9 [206 1.00 1.00 1.00 1.098 20 Mw EBASCO SERVICES INCORPORATED FIGURE II-A-3 138-kV Alertative B (No Load) EBASCO SERVICES INCORPORATED | 6.974 PETERSBURG 69 WRANGELL 69 13} fa. PETERSBURG 24 of TYEE 13 (.00 WRANGELL 12 Mw LOAD: oO LOW-SIDE PER-UNIT TAPS: _ My LOSSES: O.f PETERSBURG 1,05 MW TOTAL: ©,] WRANGELL 1,009 TYEE “J.05 FIGURE II-C-1 Performance of Alternative C: No Load EBASCO SERVICES INCORPORATED 8.0 0.858 PETERSBURG 69 PETERSBURG 24 1.00 WRANGELL 12 LOw-SIDE PER-UNIT TAPS: PETERSBURG 1.05 WRANGELL 1.031 TYEE 1.05 MW LOAD: j2. Mi Losses: 0: 2 0 3 MY TOTAL: 12.9 FIGURE I1-C-2 Performance of Alternative C: 12 MW Load EBASCO SERVICES INCORPORATED Mw los a8 23.5 ee ag PETERSBURG 69 lise Looe PETERSBURG 24 | 0 WRANGELL 69 WRANGELL 12 7.0 MW LOAD: 23.0 LOw-SIDE PER-UNIT TAPS: MI LOSSES: 205 PETERSBURG 1.05 MI TOTAL: 25.5 WRANGELL 1.022 — Los FIGURE II-C-3 Performance of Alternative C: 23 MW Load EBASCO SERVICES INCORPORATED WW MUR —1—> ra PETERSBURG 69 WRANGELL 69 Jaze 1-00 PETERSBURG 24 { 6 WRANGELL 12 MW-LOAD: 33.0 LOW-SIDE PER-UNIT TAPS: my tosses: 5.08 PETERSBURG 1.05 Mi) TOTAL: 3 8, 8° WRANGELL 1.10 TYEE Los FIGURE II-C-4 Performance of Alternative C: 33 MW Load EBASCO SERVICES INCORPORATED MW MUR —1—> |e 1.076 PETERSBURG 69 |e WRANGELL 69 100° PITERSBURG 24 | 6 WRANGELL 12 MW LOAD: © LOK-SIDE PER-UNIT TAPS: Mi LOSSES: 0.5 PETERSBURG 0.924 MY TOTAL: 6.8” WRANGELL 0.9388 TYEE 1.05 FIGURE II-C-5 Contingency Performance of Alternative C: No Load, Two Tyee Lake Generators, Without the Petersburg Compensator EBASCO SERVICES INCORPORATED WRANGELL 69 4 ° o PETERSBURG 24 et WRANGELL 12 LOw-SIDE PER-UNIT TAPS: PETERSBURG WRANGELL TYEE 1.05 0.996 1.05 MW LOAD: © My LosSES: O.1 MW TOTAL: 6©.] FIGURE I1-C-6 Contingency Performance of Alternative C: No Load, One Tyee Lake Generator EBASCO SERVICES INCORPORATED g.0 0,965 PETERSBURG 69 LOW-SIDE PER-UNIT TAPS: PETERSBURG WRANGELL TYEE i? 0 WRANGELL 69 [.00 > PETERSBURG - 24 0 WRANGELL 12 Los 1-017 1.05 Mw LOAD: (2.0 mi tosses: 0.8 MY TOTAL: 12.6 FIGURE I1-C-7 Contingency Performance of Alternative C: 12 MW Load, One Tyee Lake Generator at 0.95 p.u. Woltage EBASCO SERVICES INCORPORATED 8.0 6.584 PETERSBURG 69 WRANGELL 69 8.0 ° 24 zi WRANGELL 12 10° PETERSBURG LOW-SIDE PER-UNIT TAPS: PETERSBURG WRANGELL TYEE 1.05 0.911 1.05 Mw LOAD: 42.0 MV LOSSES: O-6 MW TOTAL: 12.6 FIGURE II-C-3 Conti ngency Performance of Alternative C: 12 MW Load, One Tyee Lake Generator at 1.05 p.u. \oltage EBASCO SERVICES INCORPORATED [te 9:8 Pons 69 WRANGELL 69 | 16.0 100 PETERSBURG 24 WRANGELL 12 ho MW LOD: 23.0 LOW-SIDE PER-UNIT TAPS: MWY LOSSES: 2.6 PETERSBURG 13 Me TOTAL: 25.6 WRANGELL 4.095 TYEE 1.05 FIGURE I1-C-9 Contingency Performance of Alternative C: 23 MW Load, Two Tyee Lake Generators, Without Petersburg Compensator. EBASCO SERVICES INCORPORATED 0.572 PETERSBURG 69 WRANGELL 69 PETERSBURG 24 WRANGELL 12 PER-UNIT TAPS: LOw-SIDE PETERSBURG 1.024 1.038 1.os WRANGELL TYEE MW LOAD: @. MW LOSSES: 0.0 8 ik TOTAL: 6.08 FIGURE II-E-1 Performance of Alternative E: No Load, With Wrangell Reactor EBASCO SERVICES INCORPORATED |e 1.076 PETERSBURG 69 WRANGELL 69 © PITERSBURG 24 { @ WRANGELL 12 Mw LOAD: © LOW-SIDE PER-UNIT TAPS: MY LOSSES: 0.5 PETERSBURG 0,929 Mi TOTAL: @.3” WRANGELL 0.9388 TYEE 1.05 FIGURE I1-E-2 Contingency Performance of Alternative E: No Load, Without Wrangell Reactor EBASCO SERVICES INCORPORATED “we |s2 0.46 PETERSBURG 69 1.06 LOW-SIDE PER-VNIT TAPS: PETERSBURG WRANGELL TYEE WRANGELL 69 [2.0 —— PETERSBURG 24 t ° WRANGELL 12 1.05 1,026 1.05 1.66 4.0 fas aot ’ 1.008 TYEE 69 va{ Ine TYEE 13 = 1,e3 Md LOAD: 42.0 MW LOSSES: 0.6 MH TOTAL: 42,6 FIGURE I1-E-3 Performance of Alternative E: 12 MW Load, With Wrangell Reactor EBASCO SERVICES INCORPORATED 1.5 MYAR |2 0.924 PETERSBURG 69 |2 0 WRANGELL 69 1.06 —— PETERSBURG 24 of WRANGELL 12 Ma LOAD: 12.0 LOW-SIDE PER-UNIT ZAPS: Mw Losses: 0.7 PETERSBURG 1.43 VW TOTAL: 12-7 WRANGELL 1.027 TYEE Los FIGURE I1-E-4 Contingency Performance of Alternative E: 12 MW Load, Without Wrangell Reactor EBASCO SERVICES INCORPORATED WwW ———_> MUR —1+—> 16.0 0. S318 PETERSBURG 69 [!6-0 1.60 PETERSBURG 24 WRANGELL 69 6 WRANGELL 12 Mi LoAD: 2.3.0 LOw-SIDE PER-UNIT TAPS: MW LOSSES: 2-6 PETERSBiRG 1.43 MW TOTAL: 25,6. WRANGELL 1.023 TYEE 10S FIGURE II-E-5 Performance of Alternative E: 23 MW Load, O MVAR at Wrangell, With Wrangell Capacitor EBASCO SERVICES INCORPORATED Mw — MUR: —1—> | 16.0 0.30P PETERSBURG 69 WRANGELL 69 be PSespurc 24 4 a4 WRANGELL 12 LOwW-SIDE PER-UNIT TAPS: Mw Losses: 2.6 PETERSBURG [13 MW TOTAL: 25.6 WRANGELL 1.09 TYEE 1.05 FIGURE II-E-6 Performance of Alternative E: 23 MW Load, 3 MVAR at Wrangell, With Wrangell Capacitor EBASCO SERVICES INCORPORATED III LOAD FLOW PERFORMANCE OF THE SELECTED ALTERNATIVE A - VOLTAGE CONTROL AND FLICKER The selected alternative owes its low cost, relative to 69 kV alternatives C and D, to the absence of dynamic voltage control equipment at any location other than Tyee Lake. Consequently, it can be expected to have poorer voltage regulation than either of those alternatives. This section discusses measures to provide the greatest possible voltage control with the available facilities. 1 - Voltage Control Philosophy The voltage control philosophy for the selected alternative relies on Proper control of three voltage control factors. They are load power factor, LTC on Petersburg and Wrangell transformers, and generator voltage at Tyee Lake. Three goals must be addressed: flicker control, dynamic voltage control, and the steady state voltage control. These refer respectively to the voltage change in the first 0.25 to 1 second following a load change, the amount of voltage change remaining after generator excitation control has responded, and the adequacy of the voltage level itself. All three voltage control factors influence the voltage level. The type of generator voltage regulator compensation influences the dynamic voltage changes and only the system configuration affects the level of flicker (for a given load change). 2 - Flicker There is very little which can be done to reduce flicker once a configuration, such as the selected alternative, has been established. For flicker calculation the internal voltages of the generator are assumed to be held constant while generator and load 16588 III-1 transient impedences are modeled. The amount of voltage change on the load for a load impedence change is a measure of the flicker level. Since the transient impedences of the generator, its step up bank, and the step down banks at Wrangell and Petersburg account for most of the system impedence, there is little difference in flicker levels between a load change on the selected 69 kV alternative and one on a 138 kV alternative. Table III-A-1 shows the amount of flicker which can be expected for various changes to the selected alternative. It can be seen that flicker levels are 3 to 5 per cent for switching even 1,000 kVAR capacitor banks at the station load buses. Also, a high proportion of all flicker events at one load station will be transferred to the other load station. Voltage level changes greater than 2 to 3 percent are generally regarded as unacceptably high for an event which will occur several times a day. EBASCO recommends that switched capacitor banks on the distribution systems be limited to 500 kVAR in size, to limit flicker to acceptable levels. It can also be seen that switching the 7.5 MVAR shunt reactor would produce very large flicker levels. That is the reason that such switching is not reconmended and why alternative E was rejected. 3 - Dynamic Voltage Control The types of events listed in Table III-A-1 can be partially compensated by regulator action at Tyee Lake and partially by LTC action. It is preferable to use the generator voltage control as much as possible, because its action can take place in roughly 1 second, as contrasted to 1 minute or more for the LTC. One possible control mode would be to allow the generators to regulate their own terminal voltages. Thus, after about 1 second, the generator terminal voltage would be restored to its original III-2 TABLE III-A-1 FLICKER LEVELS Calculated With 12 MW System Load Percentage Voltage Rise on Bus Tyee Lake Wrangell Wrangell Petersburg Eve nt generator switchyard 12.5 kV 24.9 kV Adding 1 MVAR capacitor bank at Wrangell 12.5 kV 11 2.1 3.5 2.1 bus; 2 Tyee Lake generators As above, but 1 Tyee Lake generator 2.2 4.1 5.3 4.2 Adding 1 MVAR capacitor bank at Petersburg 24.9 kV 1.1 2.0 2.1 3.0 bus; 2 Tyee Lake generators As above, but 1 Tyee Lake generator 2.1 4.0 3.9 5.0 Loss of 7.5 MVAR reactor at Wrangell Switchyard; 9.0 18.0 18.5 18.4 2 Tyee Lake generators III-3 level. Voltages at all other locations on the transmission system would be changed a nearly equal amount. From Table III-A-1, it can be seen that restoring the original generator terminal voltage (and changing the load buses a similar amount) would correct between 1/2 and 1/3 of the transient voltage change at the load buses. That leaves 1/2 to 2/3 of any transient voltage change to be corrected slowly by LTC action. A better way of responding to voltage changes is to force the Tyee Lake generators to regulate a point farther into the transmission system. This can be done accurately by providing the Tyee Lake generators with a voltage reference from a remote point in the system Over which Tyee Lake has significant voltage control. The reference voltage can be obtained by either telecommunications or by monitoring real and reactive power flow and voltage at Tyee Lake and calculating the voltage drop to a remote point. When this is done by an analog Circuit, through which scaled line currents (from the CT's) are passed, the process is called compensation of the voltage regulator. Since Tyee Lake is the most significant voltage regulation source on the system when the diesels are not operating, it exerts control over the bulk of the Tyee Lake transmission system. When no other generation is connected, almost any bus can be selected for regulation. The limitations are that the farther away it is fron Tyee Lake, the less control Tyee Lake has when another generator is operating on the system. Also, if voltage regulator compensaton is to be accurate, the controlled bus should lie on the circuit through to which the current measured at Tyee Lake flows. Considering these factors, EBASCO recommends that the voltage regulators at Tyee Lake be compensated to regulate the voltage at Wrangell Switchyard. The reason for selection of this point is that it is a central location whose voltage can be simulated accurately from Tyee Lake. It is also the common connection point for service to Wrangell and Petersburg. If the Tyee Lake regulating range is III-4 adequate, compensating to Wrangell Switchyard gives the appearance of having the generation located at Wrangell Switchyard. Voltage Changes between Tyee Lake and Wrangell will not influence voltages at the load buses, nor would voltage changes at one load bus have more than a transient infuence on the other load bus. Referring to Table III-A-1 again, it can be seen that if Tyee Lake changes its terminal voltage enough to restore the original voltage level at Wrangell Switchyard, most of the transient voltage change Caused by capacitor switching would be corrected. Roughly 2/3 to 4/5 of the normal flicker voltage change for the capacitor switching events would be eliminated after about 1 second. The remaining voltage change would not require more than one 5/8 percent tap change for switching 500 KVAR capacitor banks. The major problem to regulate the Wrangell switching voltage is that Tyee Lake may reach a terminal voltage limit (0.95 or 1.05 per unit), before restoring the desired voltage level at Wrangell Switchyard. If a limit is reached, the dynamic voltage changes (those lasting longer than 1 second) will be larger than expected. If the Tyee Lake generators are operating at a voltage limit before a voltage transient, they will be unable to regulate any farther away than their own terminals. To avoid this potential problem, the voltage schedule at Wrangell must be selected as a function of the real and reactive loading of the system, or the reactive loadings must be controlled as a function of the load level. The goal in either case is to operate Tyee Lake at nearly 1.0 per unit terminal voltage under all nomal conditions to allow it to respond up to 5% in voltage either way. The one per unit voltage at Tyee Lake can be obtained by either changing the load power factor while regulating a fixed Wrangell Switchyard voltage; or by having a Tyee Lake operator gradually (over several minutes) adjust the scheduled Wrangell switchyard voltage, at III-5 a constant reactive power load, to obtain 1.0 per unit terminal voltage at Tyee Lake. The first method requires communication from Wrangell and Petersburg to Tyee Lake and in reverse to constantly adjust reactive loads. The second just assumes that the LTC's will be able to adjust the load voltages in response to any voltage change at Tyee Lake (or Wrangell Switchyard). The transmission system is very sensitive to reactive load changes and, therefore, both methods will have to be used. The operators at Petersburg and Wrangell will have to control load power factors within a narrow range as a function of load level and the Tyee Lake operator will have to manually adjust the schedule voltage at Wrangell Switchyard to fine tune the situation. The relationship between reactive load, power level and voltage is difficult to define because the effect of load at Petersburg is different than for the load at Wrangell. The relationship can be defined well at Wrangell Switchyard, however. Table III-A-2 shows a typical relationship between real load and reactive load required to hold 0.975 per unit voltage at Wrangell Switchyard and 1.0 per unit at Tyee Lake for 1 and 2 generators in service. The change of reactive load with a real load will be about the same for any desired voltage level at Wrangell. The examples in Part B of this section provide additional information on system operating limits. III-6 TABLE III-A-2 INDICATIVE FIGURES SHOWING RELATIONSHIP BETWEEN REAL AND REACTIVE POWER WHILE MAINTAINING CONSTANT VOLTAGES AT BOTH TYEE LAKE AND WRANGELL Power Received Reactive Power Flow at Wrangell from Wrangell to Tyee Lake Switchyard MVAR MW 2 Tyee Lake 1 Tyee Lake generators generator 0 - 0.4 -1.1 4 0.8 -0.2 8 2.3 1.0 12 3.9 2.6 16 5.9 20 8.2 24 10.8 28 13.8 NOTE: A simplified model was used for these calculations, and actual changes in reactive power flows will be more than indicated above. III-7 B - STEADY STATE LIMITATIONS A discussion of the load flow with no load, a 12-MW load, and 23-MW load is presented below. The appropriate figures referred to are presented at the end of this chapter. , 1 - No load Conditions. In its unloaded condition, the line charging of the 69 kV transmission line must be absorbed by the 7.5 MVAR shunt reactor and the generator unit(s) at Tyee Lake. a. Figure III-B-1. This figure shows normal unloaded operation of the line and two generator units at Tyee Lake. The two generators need to absorb a total of only 5 MVAR. For comparison, their under excited capabilities at no load are about 10 MVAR each. The generators will operate near their lower voltage limit of 0.95 per unit to maintain a desired voltage of about 0.975 per unit at the Wrangell Switchyard (see Section III-A). Voltages at Petersburg will be about 1% higher. b. Figure III-B-2. This figure shows operation at no load with only one Tyee Lake generator. The total reactive power to be absorbed is still about 5 MVAR, but line voltages are higher than in the previous figure because of the larger voltage rise in the Tyee Lake generator's step-up transformer. Even though the generator operates at its lower limit (0.95 per unit) it is unable to lower the Wrangell Switchyard voltage below 0.99 per unit. Voltage at Petersburg is again about 1% higher. III-8 c. Figures III-B-3 and 4. Loss of the 7.5 MVAR shunt reactor results in the highest 69 kv voltage levels and the greatest amount of excess line charging for the Tyee Lake generators to absorb. In Figure III-B-3 two Tyee Lake generators must absorb all of the line charging of the system while it is operating at higher than 1 per unit voltage. The 13 MVAR of line charging in this case can easily be handled by two generators but could not be handled by one. A simultaneous outage of the shunt reactor and one of the two Tyee Lake generators cannot be tolerated unless enough diesel generators are brought on-line to absorb at least 3 to 5 MVAR of line charging. Figure III-B-4 shows one such case. The diesel reactive power requirements remain fairly constant as load increases up to the capability of one Tyee Lake generator, because line reactive losses increase as the Tyee Lake generator reactive capability decreases. Voltages for this condition reach their maximum levels. Using a 1.05 per unit low side tap at Tyee Lake and minimum operating voltage results in voltage levels of about 1.08 per unit at Petersburg and 1.07 per unit at Wrangell. The lowest high side fixed voltage taps on Petersburg and Wrangell transformers should be at least 91% of these levels so that they remain within 110% of their voltage ratings for this condition. A 69 kv high side tap would be acceptable at either location. If fixed taps are provided on the high side, the transformer voltages on both low and high sides should be set so that the lowest high side tap is rated at 69 kV. 2 - 12 MW Load Level. The 12 MW load level represents full load of one generator unit. It, therefore, represents a maximum load which can be handled during an Outage of one Tyee Lake generator. The 7.5 MVAR reactor was sized to provide low reactive loading on one generator at this load level to avoid the need to curtail power production to stay within the generator's reactive capability. III-9 a. Figure III-B-5 and 6. These figures demonstrate that having either one or two Tyee Lake generators in service has little effect on system voltage levels, as long as generator reactive loadings are small. In either case, the generator(s) would operate at their maximum voltage capability (1.05 per unit) to serve about 2 MVAR of reactive load in addition to the 12 MW real load. The addition of more reactive load would cause the voltage level at Wrangell Switchyard to fall to below 0.975 per unit and is to be avoided unless the voltage schedule for Wrangell is to be deliberately reduced as load levels increase. b. Figure III-B-7. This figure shows how little flexibility the system has to respond to increased reactive load demands. Changing the reactive load at Petersburg from about 2 MVAR in Figure III-B-5 to 4 MVAR in this same figure, depresses the Wrangell Switchyard voltage by nearly 4% and by 7% at Petersburg 24.9 kV. This drives the Petersburg low side LTC to nearly its limit (estimated 1.13-1.15 per unit) with two Tyee Lake generators. With only one Tyee Lake generator, voltages would be about 1% lower at Tyee Lake and across the systen. c. Figure III -B-8. This figure shows the consequences of loss of the 7.5 MVAR reactor. The two Tyee Lake Generators operate at their lower voltage limits unless significant reactive load is on the system. In this case, it required about 1 MVAR of reactive load at Petersburg to even allow Tyee Lake to hold the Wrangell Switchyard voltage down to 0.975 per unit schedule. III-10 d. Figure III-B-9. This shows a case with loss of both the shunt reactor and one Tyee Lake generator. Reactive loads on the system must be greater than the indicated 3 MVAR to both limit reactive loading on the Tyee Lake generator to about 4 to 5 MVAR and to restrain voltages at the Wrangell Switchyard. As in Figure III-B-4, the diesel generators may have to be operated under-excited as loads are increased to this level in order to limit Tyee Lake reactive loadings. 3 - 23-MW Load Level The 23 MW load level results in the highest possible loading of two Tyee Lake generators. It also represents a practical limit to the capability of the selected transmission alternative. EBASCO judges that voltage control on the transmission system will become increasingly difficult as loads and losses increase to this level. The addition of a third Tyee Lake generator unit should be accompanied by improvement to the transmission system either in the form of dynamic voltage control or by conversion to 138 kV operation. a. Figure II1I-B-10. This figure shows normal operation of the system. Note that in excess of 6 MVAR of reactive power must be backfed at Petersburg and Wrangell if the desired voltage schedule is to be maintained at Wrangell and if Tyee Lake is to be able to exert voltage control on the system. Note also that, if scheduled voltage of 0.975 per unit is held at Wrangell switchyard, transformer taps at Petersburg and Wrangell will operate at mid-range. b. Figure III-B-11. This figure shows the consequences of failure to backfeed adequate reactive power into the transmission system. A change of less than 4 MVAR in the amount of reactive power backfed between this case and the previous one causes the Wrangell III-11 voltage to drop more than 6% and the Petersburg LTC to reach its limit. This case represents an operational limit for the system at this load level although it is well beyond any desirable operating point because Tyee Lake is unable to regulate the Wrangell voltage. C - SYSTEM ENERGIZATION SEQUENCE Because of the its sensitivity, the Tyee Lake transmission system must be carefully energized using the following sequence: 1. 3. 4. 6. The Tyee Lake generators are energized first, with the 69 kV transmission line disconnected from Tyee Lake, Wrangell and Petersburg. The Tyee Lake - Wrangell section of the transmission line, without the 7.5 MVAR reactor connected to it, is switched to the Tyee Lake bus. The city of Wrangell, with preferably all of its diesel generators connected, is synchronized and switched to the 69 kV line. Should the ALP Savill be also connected to the systen, it should stay on during these procedures. The load of the Wrangell diesel generators, and as much as feasible of the load of the ALP Sawmill, is transferred to the Tyee Lake powerhouse. The Wrangell - Petersburg line, with the 7.5 MVAR reactor already connected to it, is switched on at Wrangell. The city of Petersburg, with its generators, is synchronized and switched to the 69 kV line. Load is distributed according to dispatcher's schedule and the diesel generators at Wrangell and/or Petersburg, if not loaded, can be switched off. III-12 The Tyee Lake - Wrangell - Petersburg line should not be energized in its full length at once, because of the voltage oscillations that may occur. The switching on and unloading of the diesel generators is an essential part of the procedures. The idling diesel generators provide some much needed dynamic reactive power supply. Transferring the Wrangell load to Tyee Lake is adding damping to the system at Tyee Lake. The beneficial effect of the Wrangell generators during the energization process can be seen from Table III-C-1. In this table the flicker voltages are shown at various buses when the Wrangell - Petersburg line section (with the 7.5 MVAR reactor connected to the latter) is switched on while 1 Tyee Lake generator is on. If the Wrangell diesel generators are not connected to the system the flicker, a voltage rise, becomes an intolerably high 14.3% on the 12.5 kV bus at Wrangell Substation. With all diesel generators on the system this value reduces to 5.1%. The large flicker occurring during this line switching is a further indication of the sensitivity of the Tyee Lake transmission and generation system. The flicker calculations were done using so called classical methods. It is our view that using load flow computer programs with transient or subtransient reactances give sufficiently accurate results and that the costs of doing studies on a transient network analyzer (TNA) are not justifiable at this stage. The results of the load flow studies concerning the energization of the Wrangell - Petersburg line section are shown in two figures. Figure III-C-1 shows conditions prior to switching on the line and Figure 111-C-2 shows conditions immediately afterward. It is assumed that 1 Tyee Lake generator supplies the system and no diesel generator is connected to it at Wrangell. III-13 TABLE III-C-1 ENERGIZATION FLICKERS Percentage Voltage Rise on Bus Tyee Lake Wrangell Wrangell Petersburg Event generator switchyard 12.5 kV 24.9 kV Energization of Wrangell Petersburg line with 1 Tyee 9.7 14.0 14.3 --- Lake generator and no diesel generator As above, but all Wrangell diesel generators on line 3.8 6.5 5.1 --- III-14 D - SYSTEM OPERATION WITH ALP SAWMILL AND CRYSTAL LAKE GENERATION Load flow studies were also made to assess the effects of the Alaska Lumber and Pulp (ALP) Sawmil1 at Wrangell and that of the Crystal Lake hydro station near Petersburg. Figure III-D-1 shows a typical load flow case. In it the following loads are assumed: ° City of Wrangell 2.0 MW ° ALP Sawnil1 3.5 MW ° City of Petersburg 9.5 MW Generation is as follows: 0 Tyee Lake (1 generator) 11.95 MW ° ALP Sawnil] 1.8 MW ° Crystal Lake (2 generators) 2.0 MW The ALP Sawmill is connected through a 69/12.5 kV transformer located at the Shoemaker Bay Switchyard. The sawnill does not seem to have considerable effect on the system, other than that of any load and generator connected to the 12.5 kV Wrangell distribution. The operational flexibility of Crystal Lake may be restricted by the 24.9 kV voltage level at Petersburg. The voltage level is too high for Crystal Lake to deliver reactive power to Petersburg. In fact, Crystal Lake will be forced to absorb reactive power at all times. Table III-D-1 shows the real and reactive loadings at the Crystal Lake generator terminals for three generation levels. Note that the under-excited reactive capabilities of the generators or the upper terminal voltage limit (1.05 per unit) constrains the operating range of the generators. Although there is as much as a 3% operating range III-15 TABLE III-D-1 LOADING CONDITIONS AT CRYSTAL LAKE V GENERATOR GEN. BUS | TRANSMISSION BUS _ TRANSFORMER MW. MVAR2/ PU @2.4 PU @24.9 PU 024.1 Pu3/ BOTH GENERATORS ON LINE 2.0 -0.95 1.05 1.036 1.070 1.06 2.0 -1.5(L) 1.019 1.018 1.052 1.04 SMALL GENERATOR ONLY 4 -0.1 1.05 1.016 1.050 1.05 4 -0.3(L) 1.035 1.008 1.041 1.04 NO GENERATOR ON LINE 0 0 1.039 1.006 . 1.039 1.04 1/ 24.9 kV @ Petersburg. No intermediate loads on line. Line charging modeled. Crystal Lake transformer on 24.1 kV tap. 2/ Negative sign indicates absorbed reactive power, j.e., underexcited generator(s). 3/ Average of voltage levels of windings. Limit is 1.1 at no load, 1.05 at 2.5 MVA and linear between. (L) Estimated lower limit; actual absorbing capability of generators may be less. III-16 at full load, it reduces in proportion to the generating capability On-line. This means that voltage rises greater than 3% at Petersburg would make it impossible for Crystal Lake to stay within generator rating limits with all generation on-line. With only the small generator on-line a 1.5% rise is the maximum tolerable. Transformer excitation is also a problem. The expected excitation level ranges from 104% to 106% at all times. A level of 110% should be tolerable at no load and 105% at full load. The full load excitation levels are marginal if the transformer has standard capabilities. Any voltage rise greater than 1% at Petersburg would cause excessive excitation. The problems at Crystal Lake prompts EBASCO to recommend that 24.9 kV be regarded as the absolute upper limit for voltage at Petersburg unless the transformer at Crystal Lake is replaced. It would be desirable to operate even somewhat (say 3% to 5%) lower than 24.9 kV so that Crystal Lake can respond to voltage flicker without reaching a generator terminal voltage or a loading limit. One factor which could reduce the apparent problems would be to serve significant amounts of real and/or reactive load from the Petersburg-Crystal Lake circuit. The locations, power factors, and amounts of load which are presently on the line were not known sufficiently well to model them in the studies, but they would help to reduce the voltage level at Crystal Lake. III-17 WRANGELL SWITCHYARD wu -_—— MVAR ——}—Sa» a PETERSBURG 69 TYEE 69 -4 PETERSBURG 24.9 TYEE 13.8 LOW SIDE PER-UNIT TAPS LOAD: O MW WRANGELL = 1.038 LOSS: o.. MW PETERSBURG: 1.029 TOTAL: 0.1 MW FIGURE: III-B-\ mie nae Oat No Load, Tel Tyee Lake Generators EBASCO SERVICES INCORPORATED WRANGELL SWITCHYARD Ww MVAR ——}—>» TYEE 69 TYEE 13.8 LOW SIDE PER-UNIT TAPS LOAD: © MW WRANGELL: 1.01 LOSS: O14 MW PETERSBURG :, 1.00») TOTAL: ©.\ MW FIGURE: III-B- 2 TYEE LAKE? 1.05 No Load, One Tyee Lake Generator EBASCO SERVICES INCORPORATED WRANGELL SWITCHYARD Ww MVAR —}—>— wo +) 4 — |= ae TYEE 69 TYEE 13.8 LOW SIDE PER-UNIT TAPS LOAD: © MW WRANGELL: 0.939 LOSS: oS MW PETERSBURG: ©.929 TOTAL: 0.S MW FIGURE: III-B- 3 TYEE LAKE : 1. 050 Contingency: No Load, Two Tyee Lake Generators, Without Wrangell Reactor EBASCO SERVICES INCORPORATED WRANGELL SWITCHYARD Ww -—— = MVAR ——}—> 6 | PETERSBURG 69 TYEE 69 col PETERSBURG 24.9 TYEE 13.8 LOW SIDE PER-UNIT TAPS LOAD: © MW WRANGELL: 0.9%6 LOSS: oO. MW PETERSBURG: (.050 TOTAL: ©.\ MW FIGURE: III-B-4 TYEE LAKE: 1.050 Contingency: No Load, One Tyee Lake Generator, Without Wrangel] Reactor EBASCO SERVICES INCORPORATED WRANGELL SWITCHYARD ww ———S MVAR ——}—sam ne | PETERSBURG 69 wf PETERSBURG 24.9 TYEE 69 WRANGELL 12.5 8 TYEE 13.8 . .omw TT Mvar, © MvaR LOW SIDE PER-UNIT TAPS LOAD: 1.0 6MW WRANGELL: \.026 LOSS: 0.6 MW PETERSBURG: 1.050 TOTAL: 12-6 MW FIGURE: III-B- 5S TYEE LAKE : \.0S0 12 MW Load, Two Tyee Lake Generators EBASCO SERVICES INCORPORATED WRANGELL SWITCHYARD “ -——— = MVAR ——}—s» 2a PETERSBURG 69 TYEE 69 1.8 + PETERSBURG 24.9 WRANGELL 12.5 B.omw Y.omw TYEE 13.8 \-BMvar Oo MwvaAR LOW SIDE PER-UNIT TAPS LOAD: 12.0 MW WRANGELL: \.02 LOSS: 01 MW PETERSBURG: 1.05 TOTAL: 12.7 MW FIGURE: III-B-6 TYEE LAKE: 1.05 : 12 MW Load, One Tyee Lake Generator EBASCO SERVICES INCORPORATED Ww -—— Se MVAR ——}—S» WRANGELL SWITCHYARD wf | [oe — PETERSBURG 69 0.905 wt |e PETERSBURG 24.9 1.06 8.omMw 4.1 mMvaAR LOW SIDE PER-UNIT TAPS WRANGELL: \.01 PETERSBURG: 1.13 TYEE LAKE : 1.05 ° { |x 1.00 WRANGELL 12.5 4.0 MW o MvaAR LOAD: 12.0 MW LOSS: on MW TOTAL: 12-1 MW ud fr 0.993 TYEE 69 wet fan 1.05 TYEE 13.8 FIGURE: III-B-9 12 MW Load, 4 MVAR at Petersburg, One Tyee Lake Generator EBASCO SERVICES INCORPORATED WRANGELL SWITCHYARD Mo ———— Se MVAR ——}-—s “4 PETERSBURG 69 TYEE 69 ved Jo PETERSBURG 24.9 WRANGELL 12.5 1% {fas gomMw er TYEE 13.8 \.omvar eo wb LOW SIDE PER-UNIT TAPS LOAD: 12.0 MW WRANGELL: \.03\ LOSS: O-% MW PETERSBURG: \.cSo TOTAL: 12.4 MW FIGURE: III-B-8 TYEE LAKE: 1.050 Contingency: 12 MW Load, Two Tyee Lake Generators, Without Wrangell Reactor EBASCO SERVICES INCORPORATED WRANGELL SWITCHYARD Ww MVAR ——}—Sep 20 PETERSBURG 69 an t PETERSBURG 24.9 TYEE 69 B.omw Lomw 0.495 TYEE 13.8 2.7 MVYAR oO MvaR LOW SIDE PER-UNIT TAPS LOAD: 12.0 MW WRANGELL : \.ovt LOSS: 0.8 MW PETERSBURG: \-0SO TOTAL: 12.6 MW FIGURE: III-B- 4 TYEE LAKE: \.oc¢g Contingency: 12 MW Load, One Tyee Lake Generator, Without Wrangell Reactor EBASCO SERVICES INCORPORATED WRANGELL SWITCHYARD Ww MVAR ——}—S» “| PETERSBURG 69 TYEE 69 ot PETERSBURG 24.9 WRANGELL 12.5 ao Vel MvA 1.8 MvA 1.05 TYEE 13.8 PF=.91Ccagacikive) PE= -A1cagarihive) LOW SIDE PER-UNIT TAPS LOAD: 23.1 MW WRANGELL : \.012 LOSS: 2.4 MW PETERSBURG: \.o15 - TOTAL: 25.1. MW FIGURE: III-B- 10 TYEE LAKE: 1.0650 23 HW Load, Two Tyee Lake Generators EBASCO SERVICES INCORPORATED WRANGELL SWITCHYARD Ww ———Se MVAR ——}—0 of PETERSBURG 69 ee PETERSBURG 24.9 TYEE 69 WRANGELL 12.5 TYEE 13.8 (5.1 MvA 1.5¢vA pt 0.95 pt= OS LOW SIDE PER-UNIT TAPS LOAD: 23... MW WRANGELL: \.\06 LOSS: 2-8 MW PETERSBURG: \.1S0 TOTAL: 25.9 MW FIGURE: III-B-\\ TYEE LAKE : (.0So0 23 MW Load, Two Tyee Lake Generators, Reduced MVAR Flo From Petersburg to Wrangell EBASCO SERVICES INCORPORATED WRANGELL SWITCHYARD Ww -—— MVAR ——}—se» ib r| | PETERSBURG 69 TYEE 69 PETERSBURG 24.9 TYEE 13.8 LOW SIDE PER-UNIT TAPS WRANGELL: -- Loss: - MW PETERSBURG: 1.039 TOTAL: 1.5 MW FIGURE: III-C-1 TYEE LAKE? \.050 Line Energi zation: Conditions Prior to Switching on th : Wrangell-Petersburg Line Section EBASCO SERVICES INCORPORATED WRANGELL SWITCHYARD PETERSBURG 69 { TYEE 69 PETERSBURG 24,9 WRANGELL 12.5 2.2 MVA 1.037 TYEE 13.8 t= 0.44 LOW SIDE PER-UNIT TAPS LOAD: 1.9% MW 6'=0.984 ’ WRANGELL: = — LOSS: 0.12 MW My 2.34 PETERSBURG : 1.037 TOTAL: 2.09 MW FIGURE: III-C-Q TYEE LAKE: \.oso0 Line Energt zation: Conditions Following Switching on the Wrangell-Petersburg Line Section EBASCO SERVICES INCORPORATED TYEE LAKE - WRANGELL - PETERSBURG - CRYSTAL LAKE - SAWMILL LOAD FLOW PERFORMANCE FOR 69 kV SYSTEM Operation with Crystal Lake and ALP Sawnill Connected to w— the Systen MVAR +> nl a 7.16 11.49 elre me | Nal 7.82 2 1.52] | 7.66 3.37} | T 11.95 11 69 reteassunc 69 (1) i 0.97 @) — 1.00 0.05 t}]2-0 o.s7 P| 1.73 1.25 | | 7.64 WRANGELL 12 1.994 | Pit.95 (1) t { 1.00 (ws) 1.00 (1) 1.00 St Lhe (2) (3) TYEE 13 0.33 Tl pis of) 12.0 0.64} | |1.73 0.95 2.00 0.72 1.70 t 1 1.05 (3) t L 1.00 MW LOAD: 15.00 Mu LOSSES: 0.75 os} T1200 LOW-SIDE_PER-UNIT TAPS MW TOTAL: 15.75 (a) (<) PETERSBURG/“1.031_- 3.5 (a) = a CRYSTAL Lack WRANCELL = 1.025 doce Ki SAWMILL 1.012 ) TYEE 1.050 Figure III-D-1 HIGH-SIDE PER-UNIT TAP Crystal Lake 0.968 EBASCO SERVICES INCORPORATED CHAPTER IV SHORT CIRCUIT STUDIES As agreed upon, EBASCO performed short circuit studies on the Tyee Lake-Wrangell-Petersburg Transmission system. The studies assume that the following generators are on the system: ° Tyee Lake all three generators ° Wrangell Powerhouse six diesel generators ° Petersburg Powerhouse five diesel generators 0 Crystal Lake two generators. The above machines represent all the machines presently operational in the Wrangel1-Petersburg area and the Tyee Lake generators under construcion and proposed. EBASCO also perfomed studies for the case when: ° Alaska Lumber and Pulp all generators are also connected to the system at Wrangell. For the latter case two versions are considered, first that the Alaska Lumber and Pulp (ALP) sawaill will be connected through a separate 69/12.5 kV transformer located at the Wrangell switchyard at Shoemaker Bay, and in the other version it is assumed that the sawnill is supplied from the substation transformer nearby the powerhouse. In both cases it is assumed that a 12.5 kV transmission line connects the supplying transfomer with the sawill; the length of the line is assumed to be 1.5 miles should it originate at the Shoemaker Bay switchyard and 5.5 miles if it originates at the substation. 1596B IV-1 Finally, we performed short circuit calculations when only the Tyee Lake plant is energizing the system; we did these for two alternatives: oO ° Three Tyee Lake generators One Tyee Lake generator only Short circuits were computed at the following locations. oO ° Tyee Lake generator 13.8 kV bus Tyee Lake 69 kV bus Wrangell Switchyard at Shoemaker Bay 69 kV Wrangell Substation nearby powerhouse 69 kV bus Wrangell Substation nearby powerhouse 12.5 kV bus Wrangell diesel generator 2.4 kV bus Petersburg substation 69 kV bus Petersburg substation 24.9 kV bus Petersburg diesel generator 2.4 kV bus. In the case when it is assumed that the ALP sawnill at Wrangell is connected to the system through a separate transformer located at the Shoenaker Bay switchyard, short circuit duties on the Oo Wrangell Switchyard 12.5 kV bus were also calculated. Iy-2 In the cases when only Tyee Lake generators energize the system, the Wrangell and Petersburg 2.4 kV diesel generator buses are not connected to the system. Tabulated values for the short circuit duties can be found in Tables I1V-1, IV-3, and IV-4. Shown are the three phase and the single line to ground fault duties in MVA and also the currents in kiloamperes. Table IV-2 shows the voltages in per cent at all key locations during symmetrical three phase short circuits, without the ALP sawnill being connected to the system. The positive, the negative and the zero sequence circuit diagrams are Presented in Appendix E. Data for the Short Circuit studies were gathered from the following sources. IECO furnished the data of the Tyee Lake generators, the 69 kV transformers, the 12.5/2.4 kV transformer at ALP's Wrangell Sawnil1 and of the 24.9/2.4 kV tranformers at the Petersburg diesel power plant and Crystal Lake. However, we assumed that the 3.5 MVA 12.5/2.4 kV transformer at the ALP Sawnill will be delta/delta connected; presently the transformers tying the sawiill with the city are also delta/delta connected; using such transformers will enable easy conversion to 4.16 kV at a later date. Data of most of the diesel generators in the powerhouses of Wrangell and Petersburg were obtained from Caterpillar, @& Electromotive, Ideal Electric, CECO Engineering (the Seattle representative of KATO Engineering). IV-3 TABLE IV-1 TYEE LAKE TRANSMISSION SYSTEM SHORT CIRCUIT DUTIES (without ALP Sawaill] at Wrangel 1 )2/ Fault in MVA (kA) Location Bus No. kV 3 ph 1 line-gd Tyee Lake 1 13.8 104.7(4.4) --- Generators Tyee Lake 4 69 141.0(1.2) 181.7(1.5) H.V. Side Wrangell 7 69 109. 9(0.9) 131.6(1.1) Switchyard Wrangell 17 69 105. 9(0. 9) 132.3(1.1) Substation Wrangell 18 12.5 78.1(3.6) 99. 5(4.6) Substation Wrangell 19 2.4 81.9(19.7) enna Generators Petersburg 13 69 90. 8(0. 8) 111.3(0.9) Substation Petersburg 14 24.9 84.9(2.0) 113.7(2.6) Substation Petersburg 20 2.4 80.5(19.4) --- Generators 1/ It was assumed that generators presently operational in the area, except for the Alaska Lumber and Pulp Company Sawnil] in Wrangell, and three Tyee Lake generators are connected to the system; which means 3 hydro generators at Tyee Lake, 6 diesel generators at Wrangell powerhouse, 5 diesel generators in Petersburg, and 2 hydro generators at Crystal Lake. Iy-4 TABLE 1V-2 TYEE LAKE TRANSMISSION SYSTEM VOLTAGES IN PERCENT DURING SYMMETRICAL THREE PHASE SHORT CIRCUITS (without ALP Sawmill at ranger 1 Location: Bus: kV. Bus No. Location of Short Circuit 17 18 19 13 14 20 Tyee Lake Gen. HV. 13.8 69 1 a 0 49 3 0 63 47 65 50 82 74 86 80 74 63 79 70 85 78 Wrangell Petersburg Swyd. Subst. Subst. Gen. Subst. Subst. Gen. 69 69 12.5 2.4 69 24.9 2.4 7 17 18 19 13 14 20 64 65 75 82 69 74 80 31 33 52 65 41 49 él 2 v 50 14 26 43 5 0 30 49 19 30 46 51 49 0 27 58 64 72 63 4 23 0 68 72 79 30 30 51 64 0 14 34 43 44 60 7 20 0 24 58 59 7 79 42 28 0 1/ It was assumed that generators presently operational in the area, except for the Alaska Lumber and Pulp Company Sawnill in Wrangell, and three Tyee Lake generators are connected to the system; which means 3 hydro generators at Tyee Lake, 6 diesel generators at Wrangell powerhouse, 5 diesel generators in Petersburg, and 2 hydro generators at Crystal Lake. Iy-5 TABLE IV-3 TYEE LAKE TRANSMISSION SYSTEM SHORT CIRCUIT DUTIES (with ALP Sawnil1 at Wrangel1)}2/ Location Tyee Lake Generators Tyee Lake H.V. Side Wrangell Switchyard Wrangell Switchyard Wrangell Substation Wrangell Substation Wrangell Generators Petersburg Substation Petersburg Substation Petersburg Generators Bus No. 17 18 19 13 14 20 kV 13.8 69 69 12.5 69 12.5 2.4 69 24.9 2.4 Fault in MVA (kA) Sawnill on 69 kV 3 ph 106.2(4.4) 146.6(1.2) 122.7(1.0) 51.5(2.4) 117.3(1.0) 81 .0(3.7) 83.5(20.1) 97.0(0.8) 88. 9(2.1) 82.6(19.9) 1 line-gd 187.9(1.6) 143.6(1.2) 53.0(2.4) 143.9(1.2) 102. 6(4.7) 117.4(1.0) 118. 5(2.7) Sawnil] on 12.5 kV 3 ph 105. 3(4.4) 143.3(1.2) 115.2(1.0) 111.3(0.9) 90.1(4.2) 88. 5(21.3) 93. 3(0.8) 86. 5(2.0) 81.4(19.6) 1 line-gd 184. 2(1.5) 136.6(1.1) 137.9(1.2) 112.2(5.2) 113.8(1.0) 115.7(2.7) 1/ It was assumed that all generators presently operational in the area and three Tyee Lake generators are connected to the system; which means 3 hydro generators at Tyee Lake, 6 diesel generators at Wrangell power house, 1 steam turbine and 3 diesel generators at Alaska Lumber and Pulp Company's Sawaill in Wrangell, 5 diesel generators in Petersburg, and 2 hydro generators at Crystal Lake. 1V-6 Location Tyee Lake Generators Tyee Lake H.V. Side Wrangell Switchyard Wrangell Substation Wrangell Substation Petersburg Substation Petersburg Substation TYEE LAKE TRANSMISSION SYSTEM SHORT CIRCUIT DUTIES TABLE IV-4 (with only Tyee generators on the system) Bus No. 7 18 13 14 kV 13.8 69 69 69 12.5 69 24.9 Fault in MVA (kA) 3 Tyee generators 3 ph 92.9(3.9) 103.9(0.9) 56.6(0.5) 54.6(0.5) 33.5(1.5) e 44.2(0.4) 37.4(0.9) IV-7 1 line-gd 139.0(1.2) 72.7(0.6) 71.1(0.6) 39.2(1.8) 58.1(0.5) 51.1(1.2) 1 Tyee generator 3 ph 50.1(2.1) 34.7(0.3) 27.3(0.2) 26. 8(0. 2) 20.4(0.9) 24.1(0.2) 21.9(0.5) 1 line-gd 47.1(0.4) 37.7(0. 3) 37.3(0.3) 26.1(1.2) 33.5(0. 3) 31.0(0.7) Data of the large Crystal Lake generator were provided by Allis Chalmers. We could not find data for some of the diesel generators, the generators at the ALP Sawnill at Wrangell and the smaller Crystal Lake generator. For all these units “educated estimates" were made based on average data available for similar sized units. We considered a 7.5 MVA 12.5/2.4 kV transfomer for Wrangell, identical to the one given by IECO for Petersburg. The power rating of the Wrangell diesel power house, combined with the outlook for growth of and full conversion to 12.5 kV in the city, justified such an assumption. Zero sequence impedences not available were developed using the methods of either General Electric, published in the instruction manual for the computer program “Phase $" or that of Westinghouse, published in the Electrical Transmission Distribution Reference Book, Fourth Edition, Appendix: Table 7. Copies of all the computer printouts are in Appendix F. In addition, following the printouts for the case when all area generation, except for the ALP Sawaill, is connected to the system, are circuit diagrams showing, for all nine locations, the short circuit duties in MVA, the currents in kiloamperes, including the contributions from the adjacent lines, and the per unit voltages at all key locations on the systen. In general, connecting the Alaska Lumber and Pulp sawnill at Wrangell to the system does not seem to increase considerably the short circuit duties. The largest increase is 15.4 percent and it occurs on the low voltage side of the Wrangell substation for the alternative when the sawmill is connected directly to the substation through a 12.5 kV line. At all other Wrangell buses the increases are less than 12 percent and at the rest of the system they are below 7 percent. IVy-8 The largest short circuit duty occurs at the Tyee Lake 69 kV bus; it is 146.6 symmetrical three phase MVA and occurs when the ALP Sawnill is Connected through a separate 69/12.5 kV transformer at the Wrangell switchyard. Taking the case when the ALP sawmill is not connected to the system the largest symmetrical three phase short circuit duty is 14] MVA occurring at the Tyee Lake 69 kV bus. All other short circuit duties are below 110 MVA. Iv-9 Y. DYNAMIC BEHAVIOR A. OVERVIEW AND CONCLUSIONS As part of this study the dynamic behavior of the Tyee Lake-Wrangell- Petersburg transmission system, including generation and loads, was also investigated. The system, as called for short, was subjected to both load acceptance (LA) and load rejection (LR) investigations. The Purpose of these studies was to: 0 find out if the system remains stable following a serious disturbance; ° estimate the frequency and voltage swings that can be expected; and ° Provide basis to establish special operating procedures if so required. In the load acceptance part of the study it was assumed that a 500 HP or 350 HP motor is started at the Alaska Lumber and Pulp (ALP) sawnill at Wrangell. Five alternatives were investigated and are discussed in detail later. The load rejection studies assumed the unlikely event that half of the load of the system is suddenly switched off. This was accomplished by Switching off 504 of the loads of both Wrangell and Petersburg simultaneously. The results of these studies indicated that even with the above described heavy load changes the system remains stable. However, with line compensation on the voltage regulator (AVC) of the Tyee Lake generators, the flicker on the Wrangell 12.5 kV bus at the substation and on the Petersburg 24.9 kV bus are tolerable only if the motors are started at 60% voltage. 18298 The load rejection studies project that the frequency may increase close to 65 Hz and the momentary voltage up to 1.16 p.u. on the Wrangell and Petersburg distribution buses for the extremely large 7.5 MW load rejection investigated. B. DESCRIPTION OF THE SYSTEM 1. One Line Diagrams The one line diagram for the load acceptance is shown in Figure V-1 and for the load rejection in Figure V-2. Both diagrams show only the essential elements of the circuit and do not indicate the details required for computer applications. In Figure V-1 the ALP sawnill is connected to the Wrangell Switchyard bus at Shoemaker Bay through a 69/12.5 kV transformer and an approximately 1.5 mile long 12.5 kV line. The motor to be started and the rest of the sawnill's load are represented separately in the computer studies. The ALP sawmill is not considered in Figure V-2 and the corresponding load rejection studies. Each city's load is represented by two loads, each 1/2 of the actual load. One of each of the half loads are switched off simultaneously by the progran. 2. Programming Details All computer studies were made using the Westinghouse Computer Aided Transient Stability Program. We selected the Westinghouse Program because it included the starting of the chipper motor, which was not possible with the corresponding EPRI and GE programs. In order to represent the dynamic characteristics of the system more data are required than were actually available. In order to overcome the difficulties two literature sources, generally 18298 1,2/ considered by the profession as very reliable, were used.——" In addition, data were obtained for a 350 HP 900 RPM induction motor. a. Tyee Lake Powerhouse Data Four separate elements of the system have to be modelled, namely, oO the turbines; o the generators; o the exciters; and oO the automatic voltage regulators (AVC). Data for the Tyee Lake generators were furnished by the International Engineering Company (IECo) and can be found in Appendix D. Data developed using the Anderson and Fouad Book are shown in Table V-1. The parameters of the Tyee Lake turbines and their governors are developed using data provided directly by Escher Wyss of Zurich-Switzerland, the manufacturer of the units.2/ These data have been reworked to make them suitable for the Westinghouse program as shown in Appendix H. Escher Wyss gives a water acceleration time constant of iT :\* 1.23 seconds for two generators. This is the time constant of the water column in the penstock/tunnel. 18298 1/ Power System Control and Stability (book), by Anderson and Fouad; Iowa State University Press, 1977. 2/ The Nature of Polyphase Induction Machines, by P.L. Alger; John Wiley and Sons; 1951. 3/ Letter by Mr. J. Regaldo of Escher Wyss addressed to Ebasco, dated 28.5.1982. V-3 wa TABLE Y-1 DATA DEVELOPED FROM ANDERSON AND FOUAD VARI ABLE VALUE DESCRIPTION S| 0.1 machine saturation at 1.0 p.u. voltage S2 1.0 Machine saturation at 1.2 p.u. To" 0.0 quadrature-axis subtransient open circuit time constant X% 0.1 leakage reactance x 0.3 Potier reactance 18298 18298 In the studies different Te values ranging from 0.63 to 1.86 are used and it can be said that the differences in the dynamic behavior are barely noticable by varying the water acceleration time constant within that range. The Westinghouse program uses the classical penstock representation for Pelton turbines, which is in the form of: This model takes into account the negative response to the rate of opening or closing of the valves, but neglects water hammer effects in the long penstock (400 meters). However, this simplification is satisfactory for the purposes of this study even though small errors in the response of the generator to relatively slow changes result . The model also neglects the effect of the deflectors, which the governor may actuate during generator overspeed conditions that occur during a load rejection condition. Therefore, the frequencies would probably not go as high as indicated in this report. This means that the computed results are conservative. Figure V-3 is a block diagram of the model that was used for the exciter. There were no data given for the exciter, except that it will be of a static type. Therefore typical values obtained from the Anderson and Fouad reference were used. Since a static exciter is very fast and linear, it does not appreciably affect the dynamic response provided that it can furnish enough excess excitation voltage to the field of the generator. For this study we allowed the excitation voltage to swing between +10 per unit. We observed the actual ranges of the excitation during several of the runs in order to fom an opinion about how much excess excitation should be provided on the Tyee Lake generators. Data for the large Crystal Lake generator were obtained from its manufacturer, Allis-Chalmers, and are presented in Appendix D. The governor data were obtained from the Woodward Governor Company, manufacturer of the governor. The data were rather sketchy and missing data were obtained using available parameters of similar units. c. Diesel and ALP Generators All of the above generators are considered off line during the dynamic system studies. d. Induction Motor There were no performance data on the induction motors at the sawnill. Therefore we used perfomance data by a manufacturer for a 350 HP, 900 rpm induction motor. We computed the impendance parameters that would produce these performance data according to the Alger book as referenced on page V-3, with the computations being shown in Appendix I. The calculations are based on the fact that the torque is equal to the power transferred through the air gap divided by the synchronous mechanical angular velocity. The iron losses are neglected in these calculations causing insignificant error. 3. Load Acceptance: Analyses and Comparisons As mentioned earlier, Figure V-1 shows the one line diagram of the load acceptance (LA) studies. Figure V-4 through V-12 show the graphs resulting from the computations. Tables V-2 and V-3 are related to load acceptance also. The cases are identified as LA-1 through LA-5. In each case the motor is switched on at t = 0.1 seconds. 18298 TABLE V-2 LOAD ACCEPTANCE: CONDITIONS PRIOR TO STARTING MOTOR No. of AVC Loads Case Tyee Lake Line Tw Wrangel] ALP Sawmill Petersburg generators _Compensator sec. MW MVAR MW MVAR MW MVAR LA-1 1 Yes 1.24 3.5 1.7 2.5 1.2 5 2.4 LA-2 1 No 1.24 3.5 1.7 2.5 1.2 5 2.4 LA-3 1 Yes 1.24 4.0 0 0 0 8 1.8 LA-4 1 Yes 0.62 4.0 0 0 0 8 1.8 LA-5 3 Yes 1.86 4.0 0 0 0 8 1.8 TABLE V-3 LOAD ACCEPTANCE: STARTING CONDITIONS Frequency Vol tagel/ Case Motor Method High Occurring Low Occurring High Occurring Low Occurring HP of start Hz at sec. Hz__at_sec. Volt p.u. at sec. volt p.u. at sec. LA-] 500s Direct’ = 60.7 1 7¥ 2¥ yo 0.93 0.15 LA-2 500 Direct «61.0.8, 2 YY 0 0.93 0.2 LA-3 350 Direct «60.6 S28 59 25 1.03 24 0.94 0.2 1/ La-4 350 as 2 G04 S38 59 34 1.01 1 0.97 25 as 500 6n 2/ g0.2 45 59.4 38 1.01 1 0.97 25 Vv Voltage shown are for the 12.5 kV Wrangell and 24.9 kV Petersburg buses, which perform alnost identically. = Switched to full voltage at 25 seconds. The lowest frequency is reached past the range of the graph plotted by the computer. V-7 18298 18298 a. Cases LA-1, LA-2, and LA-3 These cases represent direct across line startings. The motor is rated 500 HP in LA-1 and LA-2 and 350 HP in LA-3. All three cases involve 1 generator at Tyee Lake and use Ty = 1.24 sec. The results are shown in Figures V-4 through V-6 and V-9. LA-2 is the only case in the entire dynamic system study where the line compensator of the AVC is of FL’, Consequently, the voltages of the 12.5 kV Wrangell Substation and 24.9 kV Petersburg buses=/ do not return to 1.0 p.u. after the systen recovered and stabilized, but stay at a somewhat lower, around 0.96 p.u., level. The frequency stays between 59 and 61 Hz for all cases, which would be acceptable, however, the voltage on the distribution buses drops down temporarily to 0.93-0.94 p.u. which flicker is hardly acceptable on a regular basis, ruling out direct across the line starting of these sizes of induction motors. From Figure V-5 one can wrongly conclude that the frequency does not return to 60 Hz if the AVC has no line compensation. This would be far from the truth. When there is line conpensation (LA-1), the voltage at the distribution buses recover fast, restoring the electrical load of the system following a short initial slump. The restored load decelerates the system and helps to restore 60 Hz frequency. V/ The line compensator of the Automatic Generator Voltage Regulator Control (AVC) is set in such manner that the voltage on the 69 kV Wrangell Switchyard bus is Maintained constant in the steady state, regardless of generator 1oading. 2/ These two buses will be referred to as “distribution buses" for short. v-8 18298 Contrary to the preceding, when there is no line compensation (LA-2) and the sudden load, the starting of the motor, is applied to the system, the voltage regulator will restore voltage at the Tyee Lake generator bus, hence the distribution bus voltages will not fully recover after the initial drop. The lower voltages result in less electric loading leaving the frequency recovery almost entirely to the governor of the turbine. Ultimately the governor will restore the frequency to 60 Hz but it is a slow Process and will occur beyond the 3 second time range displayed in Figure V-5. b. Cases LA-3 and LA-4 By evaluating the results of these two cases the affects of the across the line and 60% voltage starts on the system can be compared. Both cases deal with a 350 HP motor. For both cases, the load at Wrangell is 4 MW, and 8 MW at Petersburg. There is a difference in Ty but, as it is denonstrated later, the difference is insignificant. The results are shown in Figures V-6, V-7, V-9 and V-10. As can be seen, there is little difference is frequency variation as both cases stay within 59 to 60.6 Hz. However, there is a significant improvement in flicker when 60% voltage start is used (LA-4) as the lowest temporary voltage at the distribution lines during start is 0.97 p.u. versus 0.94 p.u. in case of direct across line start (LA-3). Since a 3% flicker is acceptable, the starting of the induction motor at an appropriately reduced voltage is acceptable. 18298 c. Cases LA-4 and LA-5 Both cases represent 60% voltage starts. However, whereas in the case of LA-4 only 1 generator operates at Tyee Lake and the motor is rated 350 HP, in case LA-5 all 3 generators supply the system and a 500 HP motor is started. The difference in le of 0.62 and 1.86 seconds, respectively, bears no significance. Results are shown in Figures V-7, V-8, V-10, V-11 and V-12. The frequency deviations are less for the 3 generator case (LA-5), because in this case the motor size increased only by 4%, while the generating capacity increased by 200%. The frequency stays within 59.4 to 60.2 Hz range. The flicker is about the same for both cases, the lowest distribution bus voltage being 0.97 p.u. and the highest 1.01 p.u. This seeming discrepancy can be explained as follows. Increasing the number of genrators from one to three triples the mass moment of inertia of the system, therefore the frequency is more stable despite the 43% increase in motor size. Yet connecting three generators to the system will not lower significantly the system impedances at Wrangell, Petersburg, and particularly at the ALP sawnill. This is because the main source of impedances are the lines, the step down transformers, and the lowering to one third the sum of the transformer and generator transient/subtransient impedances at Tyee Lake, which do not have much effect on the resultant impedences. Consequently, the dynamic voltage Changes on the distribution buses and at the ALP Sawnill due to motor starting are barely affected by the number of Tyee Lake generators connected to the systen. d. Summary of Load Acceptance (LA-) Studies From the studies it becomes apparent that up to a 350 HP induction motor can be started with 60% voltage reduction. V-10 However, this does not necessarily mean that larger motors can be started by a further reduction in the starting voltage. This can be seen by looking at Figures V-6 through V-11 which reveal that the big jolt for the system occurs when the motor “pulls in", which means when it arrives at an RPM correspoding to about pull-out torque and is just about to achieve no load. When, on top of this condition, the motor is switched onto full voltage the effects on the power system can be more severe than when switching on the motor through a transformer with 60% secondary voltage. Therefore, starting of motors larger than 350 HP will require careful analysis. However, under certain conditions, starting the motor with even lower voltage and increasing the number of voltage steps, may not help. In such cases, wound rotor induction motors and stepless, or fine stepped, rotor starters have to be used. 4. Load Rejection: Analyses and Comparisons The one line diagram shown in Figure V-2 is used in conjunction with the load rejection (LR) studies. The loads of Wrangell and Petersburg are split into two halves, one of each is on a bus switchable by the computer. The ALP sawiill is not part of the systen. Figures V-13 through V-17 show the graphs resulting from the computations. Tables V-4 and V-5 are related to load rejection also. The cases are identified as LR-1 through LR-5. The switchable buses are opened by the program at t = 0.1 second. a. Cases LR-] and LR-2 The objective of these computer runs was to investigate load rejection with only 1 Tyee Lake generator feeding the system and a 2 MW load at Wrangell and a 3 MW load at Petersburg. Furthermore, the effect of Ty on system's behavior was looked into by using Ty = 0.63 and 1.25 seconds respectively for this parameter. V-11 v-11 18298 TABLE V-4 LOAD REJECTION: CONDITIONS PRIOR TO LOSS OF LOAD 50% of the loads shown are dropped No. of AVC Loads Case Tyee Lake Line a3 Wrangell Petersburg generators Compensator sec. MW MVAR MW MVAR LR-] 1 Yes 0.63 2 1 3. #12 LR-2 1 Yes 1.25 2 1 3° «12 LR-3 3 Yes 1.82 2 1 3 5 LR-4 3 Yes 1.86 6 3 9 4.4 LR-5 3 Yes 1.25 6 3 9 4.4 TABLE Y-5 LOAD REJECTION: CONDITIONS FOLLOWING LOSS OF LOAD Frequency Vol tagel/ Case Hi gh Occurri ng Hi gh Occurring Low Occurri ng Hz at sec. Volt p.v. at sec. voltp.v. at sec. LR-1 63.2 2.2 1.1 0.1 0.99 0.4 LR-2 63.8 2.8 1.1 0.1 0.99 0.4 LR-3 61.6 4.5 1.05 0.1 0.98 0.5 LR-4 64.6 4.5 1.16 0.1 0.88 1 LR-5 64.4 4.0 1.16 0.1 0.88 1 TT \oitac. = Voltage shown are for the 12.5 kV Wrangell and 24.9 kV Petersburg buses, which perform almost identically. V-12 18298 18298 Figures V-13 and V-14 show the results. There is a barely noticable difference between the two figures indicating that the effect of T,, upon the dynamics of the system is not significant. Immediately following the loss of loads the voltages jump to 1.1 p.u. on the distribution buses, which are the 12.5 kV bus of Wrangell and the 24.9 kV bus of Petersburg. Less than a half second later the voltages drop to 0.99 p.u. to rise to a steady value of 1.02 p.u. The reason for the steady value of the distribution bus voltages being larger than their value immediately preceding the load rejection (1.0 p.u.) is a slight deficiency in the computer program used. In the program the line compensator of the generator voltage regulator can consider only the series impedance of the line. Incase of the Tyee Lake transmission line the capacitance is very significant, but, unfortunately, the computer program is not equipped to consider the parallel Capacitance of the lines in the modeling of the generator voltage regulator. The same can be said for the Wrangell Switchyard voltage, which is also somewhat higher at steady state following the load rejection when compared to the voltage immediately preceding the loss of load. The parallel capacitance will have to be taken into account when designing the line compensation for the voltage regulator (AVC) to be delivered, to assure that the voltage at Wrangell Switchyard remains constant in the steady state. Therefore, in the computer printouts one has to be satisifed with the small error that occurs. The effects of Tw though still minute, are somewhat more noticable on the frequency versus time curves. The highest frequencies are different by a slight amount, namely 63.2 Hz in case LR-] and 63.8 Hz in Case LR-2. In addition, these peak V-13 values occur at 2.2 and 2.8 seconds, respectively. The increased sluggishness in case LR-2 is due to its larger penstock water acceleration time constant. b. Case LR-3 This case deals with the same loads as cases LR-1] and LR-2, but instead of only one, all 3 Tyee Lake generators are connected to the system. The value of Ty is 18.82, but has no significance, as previously demonstrated. Figure V-15 shows the results. The frequency reaches a high of 61.6 Hz at 4.5 seconds. The deviation from 60 Hz is about half of that of the one Tyee Lake generator cases, however, it occurs at a time about twice as long. The reason for the smaller frequency deviation is the three fold increase of the mass moment of inertia of the system. The increased sluggishness is the result of the larger value of Ty used in these computations. The voltage flicker is also improved. The highest voltage is 1.05 p.u. (against 1.1 p.u. in the one generator cases; all occur at t = 0.1 second but the low dips down to 0.97 p.u. (against 0.99 p.u.). The reason for the lower minimum is probably the combined effects of the AVCs and LTCs trying to counteract the sudden voltage rise that occurred following the dropping of the load. c. Cases LR-4 and LR-5 Here 3 generators feed the system at Tyee Lake. However, in these cases the loads were increased to 6 MW at Wrangell and to 9 MW at Petersburg, which are three times the loads used in the preceding cases. The only difference between the two cases is the value of the penstock water acceleration time constant: Ty = 1.86 for case LR-4 and T = 1.25 for case LR-5. V-14 162 18298 Figures V-16 and V-17 display the results. Close inspection of the Tyee Lake genrator voltage curves (Wlt #1) reveals that this voltage is unusually high, 1.13 p.u., immediately preceding the load rejection (t = 0 sec.). This can be explained since in the load rejection studies not only active load, but also reactive power was removed. This was done to find out if there are adverse effects of excessive reactive power dumping. To include reactive load rejection into the studies all loads are considered at 0.9 p.f lagging. This means 2.92 MVAR for Wrangell and 4.36 MVAR for Petersburg in Cases LR-4 and LR-5 under discussion. In reality the power factors of the two towns, particularly that of Wrangell, is Maintained very close to unity; this is the basic plilosophy behind the selected alternative discussed in Section II-F. Therefore, the high generator voltages prior to load rejection as shown as Figures V-16 and V-17 should be of no concern. It should be noted that the pre-1 oad-rejection voltages are also somewhat higher in Figures V-13 through V-15, when compared to the corresponding load flow studies. However, in these three cases the reactive loading is much smaller, therefore the differences are barely noticable. A glance at the results of cases LR-4 and LR-5 indicate that the system does not fall apart even for a large load rejection of 7.5 MW, if all 3 generators are connected to it. Itis hard to imagine that a partial loss of load of this magnitude would ever occur. Following the loss of load the frequency reaches its highest value of 64.6 Hz at 4.4 seconds in case of LR-4 and 64.4 Hz at 4.0 second incase of LR-5. The sluggishness of case LR-4 is due to its larger Ty V-15 18298 Though the system remains stable, the voltage flickers are very large when dropping the 7.5 MW load. On both distribution buses the voltages rise to 1.16 p.u. immediately following the loss of load and drop to 0.88 p.u. in less than a second after which the voltages stabilize at their normal value in less than 5 seconds. d. Surmary of Load Rejection Studies The load rejection studies indicate that the system is inherently stable and would not become dismembered even in case of considerable sudden load changes. As the mass moment of inertia of the system is low and, as the velocity of the water column in the penstock/tunnel cannot be changed instantly, frequency deviations larger than those generally observed in large North Anerican power systems can be anticipated. It has to be stressed once more that the studies were made with MW -and MVAR values more severe than anything that can be anticipated. It has to be mentioned also, that the Westinghouse program does not have provisions for deflectors. The deflectors, used with Pelton turbines, come into play in the case of overspeed. Should they act in case of a load rejection the frequency could rise to lower values than those obtained fron computation. The electrical behavior of the system is also very satisfactory. Though the flickers caused by the loss of loads are significant, their duration is very short, in the order of 1 second at most, because the fast acting static excitation system stabilizes the voltages within a couple of seconds. V-16 18298 In the programs the exciter ceiling voltage was set high enough not to limit the exciter voltage. Therefore the highest voltage values can be established from the computer printout: the results are shown in Table V-6. The figures Shown are per unit, the base voltage being the exciter/rotor voltage corresponding to the generator running at no load with the rotor/field winding at operational temperature. However, the ceiling voltage is customarily given as a percentage of the exciter/field voltage at rated generator load and field winding temperature. In order to stay within reasonable values and still get satisfactory electrical systen response, 400% ceiling was chosen and specified in Appendix G. Finally, as previously observed, the penstock/tunnel water acceleration time constant i. has little effect upon the dynamic behavior of the system within the ranges used in this study. V-17 TABLE V-6 RANGE OF EXCITER OUTPUT VOLTAGES Case Maximum Exciter Voltage Positive Polarity Negative Polarity Load Acceptance: LA-1 6.8 -- Load Rejection: LR-1 1.05 1.27 LR-2 1.15 1.27 LR-3 1.5 1.07 LR-4 3.6 8.4 LR-5 3.6 8.4 Voltages are in per unit based on the exciter/rotor voltage when the generator is at no load. V-18 18298 Tyee lake 13.8 kV Wrangell Switchyard 7.5 MVAR 69 kV (18) 12.5 kV 12.5 kV Wrangell @ ro a Petersburg ALP Sawmill FIGURE V-1 Load Acceptance (LA) One Line Schematic EBASCO SERVICES INCORPORATED © 1/2 of Load Wrangell Switchyard (8) 1/2 of Load 24.9 kV { 1/2 of Load Petersburg FIGURE V-2 12.5 kV { 1/2 of Load Load Rejection (LR) One Line Schematic EBASCO SERVICES INCORPORATED FD = 270 = 0.02 = 0.004 T fF] = 0-01 s = Laplace Operator (d/dt) FIGURE V-3 COMPUTER MODEL OF EXCITER EBASCO SERVICES INCORPORATED 1.1 os . Volt #1 o eo . n 1.05 Day e . wo - Gobet hp teed <oOzZmMcoman on eo . St ‘1 7 4 4 4 4 4 4 4 ? ~ o eo . w 95 oraz Moraroc aera aca ia + a t i { | ' P | i | i } oe asa fedecbbatstoaatots 85 i 59.9 eee nate e. 5 1. 1.5 e. 2.5 3. TIME (SEC) +b) “ ca BUS 1 OO pus? & pusi4 * pusig “ Tyee Lake Generator Wrangell Switchyd. Petersburg 24.9kV Wrangell 12.5kV FIGURE V-4 LOAD ACCEPTANCE (LA): SYSTEM BEHAVIOR IN CASE OF STARTING CHIPPER MOTOR AT ALP SAWMILL IN WRANGELL. SOOHP motor across line start. 1 Tyee Lake generator and AVC with line compensation. Loads: Wrangell 3.5 MW, ALP 2.5 MW, and Petersburg 5 MW. EBASCO SERVICES INCORPORATED 1.1 1.05 -95 OD2z moraroc BUS 1 + 61.2 61. 3 <OZMcoman n ta] eo ) on oo on eo of teebeenbeenbereseredeendenedeeedrondonndbeosdoode: eect TIME (SEC) MO pus? 4 pusi4 * pusigs © Tyee Lake Generator Wrangell Switchyd. Petersburg 24.9kV Wrangell 12.5kV FIGURE V-5 LOAD ACCEPTANCE (LA): SYSTEM BEHAVIOR IN CASE OF STARTING CHIPPER MOTOR AT ALP SAWMILL IN WRANGELL. 500HP motor across line start. 1 Tyee Lake generator and AVC without line compensation. Loads: Wrangell 3.5 MW, ALP 2.5 MW, and Petersburg 5 MW. EBASCO SERVICES INCORPORATED 60.6 ; 1.04 » i j : 60.4 3 i . fj 1.02 tn \ | iy i ¢ 50.2 af y , ad gn Volk # 44k 48 | nye uswiy Gy yarn iittala RIN 7 | N $L 3S ii ese iT oe rg 59.6 3G hea if “96 4 _ ia ES9.2 i@ .94 i ~ .s2 d pes an ; 5B. Tg hance eee cence cence cngeenpnepeeenungsnnetenenceengnaeter snes tnpenueneestntn & 8 5 10 15 20 25 3@ TIME (SEC) BUS 1 HO pus 7 & pusia + pusis © Tyee Lake Generator Wrangell Switchyd. Petersburg 24.9kV Wrangell 12.5kV FIGURE V-6 LOAD ACCEPTANCE (LA): SYSTEM BEHAVIOR IN CASE OF STARTING CHIPPER MOTOR AT ALP SAWMILL IN WRANGELL. 350HP motor across line start. 1 Tyee Lake generator and AVC with line compensation. Loads: Wrangell 4 MW, ALP none, and Petersburg 8 MW. EBASCO SERVICES INCORPORATED wa - . ° a> <o2zmcoman MoODArocs ze oODpD2a amx + e 10 20 38 40 Se ° TIME (SEC) Busi OO pus7 A spusi4 + pBusis oO Tyee Lake Generator Wrangell Switchyd. Petersburg 24.9kV Wrangell 12.5kV FIGURE V-7 LOAD ACCEPTANCE (LA): SYSTEM BEHAVIOR IN CASE OF STARTING CHIPPER MOTOR AT ALP SAWMILL IN WRANGELL. 350HP motor 60% voltage start. 1 Tyee Lake generator and AVC with line compensation. Loads: Wrangell 4 MW, ALP none, and Petersburg 8 MW. EBASCO SERVICES INCORPORATED 1.1 1.08 1.06 - . > a ODsz MovDAroc - ° tw ° TIME (SEC) pusi OO pus7 A pusi4 + Busis o Tyee Lake Generator Wrangell Switchyd. Petersburg 24.9kV Wrangell 12.5kV FIGURE V-8 LOAD ACCEPTANCE (LA): SYSTEM BEHAVOIR IN CASE OF STARTING CHIPPER MOTOR AT ALP SAWMILL IN WRANGELL. 350HP motor 60% voltage start. 3 Tyee Lake generators and AVC with line compensation. Loads: Wrangell 4 MW, ALP none, and Petersburg 8 MW. EBASCO SERVICES INCORPORATED i. 1.06 6B 1.04 ‘ 5 [ 1.02 T R c m 1. t¢u4 R s‘e Tu os [R L 0° E I L n3 P T 196 T aT. a] A .94 tae G G .2 -92 1 9 Oo Oo A e. -88 e @ 5 10 1S 20 2s 3° TIME (SEC) BUS 23 7 FIGURE V-9 LOAD ACCEPTANCE (LA): CHIPPER MOTOR PERFORMANCE DURING STARTUP: SLIP AND MOTOR TERMINAL VOLTAGE AND CURRENT AS A FUNCTION OF TIME. 350HP motor across line start. 1 Tyee Lake generator and AVC with line compensation. Loads: Wrangell 4 MW, ALP none, and Petersburg 8 MW. EBASCO SERVICES INCORPORATED i. 1.06 6B 8 4.08 t 6 mM Es g Pty 4.1 L 70 E I tt N3 Pd ef? 4in n A a2 G .96;+G6 “2 wat ? o lo ta e.1 gel @ “9 10 20 30 42 50 TIME (SEC) BUS 23 FIGURE V-10 LOAD ACCEPTANCE (LA): CHIPPER MOTOR PERFORMANCE DURING STARTUP: SLIP AND MOTOR TERMINAL VOLTAGE AND CURRENT AS A FUNCTION OF TIME. 350HP motor 60% voltage start. 1 Tyee Lake generator and AVC with line compensation. Loads: Wrangell 4 MW, ALP none, and Petersburg 8 MW. EBASCO SERVICES INCORPORATED 1. 1.06 1.04 8 71.02 fi 6 1. R s‘® ty R i to E r +L .o8 tn p It : “4 tm .96tm A A G G 94 2 .92 o lo A 8. 9 EE eee eee @ 10 20 30 40 50 TIME (SEC) BUS 23 FIGURE V-11 LOAD ACCEPTANCE (LA): CHIPPER MOTOR PERFORMANCE DURING STARTUP: SLIP AND MOTOR TERMINAL VOLTAGE AND CURRENT AS A FUNCTION OF TIME. 350HP motor 60% voltage start. 3 Tyee Lake generators and AVC with line compensation. Loads: Wrangell 4 MW, ALP none, and Petersburg 8 MW. EBASCO SERVICES INCORPORATED 1. 2.5G 8 MCOoOADoOA CAAOMemM - ° . ~w . uo @ 10 28 30 48 Se TIME (SEC) BUS 23 FIGURE V-12 LOAD ACCEPTANCE (LA): CHIPPER MOTOR PERFORMANCE DURING STARTUP: SLIP AND TORQUE AS A FUNCTION OF TIME. 350HP motor 60% voltage start. 3 Tyee Lake generators and AVC with line compensation. Loads: Wrangell 4 MW, ALP none, and Petersburg 8 MW. EBASCO SERVICES INCORPORATED 1.127 63.5 1.af. 63. eC pe He 1.08 ms : U 62. es 01.06 te . i = L N H 61.5 } 11.04 $6 H G 61. 7 Vo lt A% & 48 E1.02 ‘ ‘ bs bs 5 L a 60.5 # ¢ un f 60 é « & Lu 7 i Vo \t #7 159.54 nmr 5 : 96 s9. Volt #4 oO ° 4 .941f 59.5 + 8 2 4 6 8 10 ° TIME (SEC) Busi OO pus7 4 gBusi4 + pusis © Tyee Lake Generator Wrangell Switchyd. Petersburg 24.9kV Wrangell 12.5kV FIGURE V-13 LOAD REJECTION (LR): SYSTEM BEHAVIOR IF 50% OF THE LOADS OF WRANGELL AND PETERSBURG ARE DROPPED SIMULTANEOUSLY. 1 Tyee Lake generator and AVC with line compensation. Initial Loads: Wrangell 2 MW and Petersburg 3 MW. Water starting time constant Ty = 0.63 seconds. EBASCO SERVICES INCORPORATED 4.12; 64." + ye tet 1 038 - i 7R 63. MB, 1.08 JE He y 462-5 ~ 1.06 fe “oe t ir 62. ~~. ; A1-04 ty61.5 G ; Volt + 1% &418 Er.e2 it 61. j he ORAS AP 3 NIV VAI n i A 1. 7482-8 G } : 60. nao Ms a "8 i T59.5 fs ng —. Ve eas uae ES he 3 i 2 59 BG ESS Lat inn ae teenager neem + e 2 4 6 8 10 o TIME (SEC) pus1 0 pus? 4 pusi4 * BusSig &% Tyee Lake Generator Wrangell Switchyd. Petersburg 24.9kV Wrangell 12.5kV FIGURE V-14 LOAD REJECTION (LR): SYSTEM BEHAVIOR IF 50% OF THE LOADS OF WRANGELL AND PETERSBURG ARE DROPPED SIMULTANEOUSLY. 1 Tyee Lake generator and AVC with line compensation. Initial Loads: Wrangell 2 MW and Petersburg 3 MW. Water starting time constant T, = 1.25 seconds. EBASCO SERVICES INCORPORATED 1.06 i + 3 j 3 ney He ; re a i tp 61.5 3 a ro i 1.04 dp } Po i te i é 8 i 4961.25 if 55 iv fu j i $01.02 t_E Hie iL jn Gt dy Vo leat AM & 18 . i : i / aie: aa ig i. 60.75 3 A gh. D\ ppg Wee in f \ eee ae hm ee ae nee i in + 68.5 A .98 3H # le fe k ™ ek Volt #7 GR 60.25 ; Ener me ei mmr nn ce ge ace A i 4T 3 i 96 iz 4 i $68. ff ig =f} tou i& .94 4 sg9.75 Gt. Deere ESSE See ra i* i+ e 2 4 6 8 1e io TIME (SEC) 3 i i pus 1 HO pus 7 S pusi4 + pusig © Tyee Lake Generator Wrangell Switchyd. Petersburg 24.9kV Wrangell 12.5kV FIGURE V-15 LOAD REJECTION (LR): SYSTEM BEHAVIOR IF 50% OF THE LOADS OF WRANGELL AND PETERSBURG ARE DROPPED SIMULTANEOUSLY. 3 Tyee Lake generators and AVC with line compensation. Initial Loads: Wrangell 2 MW and Petersburg 3 MW. Water starting time constant Ty = 1.82 seconds. EBASCO SERVICES INCORPORATED 1.2; 65 1.15 F 64 8 1.135 ° 63 L1.05 tn 5 a. ty 2 G 1.¢ 62 E I A N m .95 A H61 sik ° T y 2606 85 Oo fe) 4 .si sg + e 2 4 6 8 10 ° TIME (SEC) pusi OO pus? A Busi4 + Busis oO Tyee Lake Generator Wrangell Switchyd. Petersburg 24.9kV Wrangell 12.5kV FIGURE V-16 LOAD REJECTION (LR): SYSTEM BEHAVIOR IF 50% OF THE LOADS OF WRANGELL AND PETERSBURG ARE DROPPED SIMULTANEOQULSY. 3 Tyee Lake generators and AVC with line compensation. Initial Loads: Wrangell 6 MW and Petersburg 9 MW. Water starting time constant T, = 1.86 seconds. EBASCO SERVICES INCORPORATED 1.2, 65 i : saet ee HE att “ og, 14 35 , 3 ge 0. iE63 PE L1.@5 3N f Po Vela dy T 7c i Shy I = Q ‘ i¥ eo j 4" PR Volt 48 ° — ae °F = Volk #71 E i et Bt m .954 A THE1L e ik ae $260 Go zo BT Sg enn eccneeeenne nner ecnepecncnnnnnnnceteenenenpegm semnapeemtegeeoee teams * @ 2 4 6 8 10 & TIME (SEC) a BUS i 0 -X>)S opus 7 &OBUS 14 *# ~~ SOBUS iB? Tyee Lake Generator Wrangell Switchyd. Petersburg 24.9kV Wrangell 12.5kV FIGURE V-17 LOAD REJECTION (LR): SYSTEM BEHAVIOR IF 50% OF THE LOADS OF WRANGELL AND PETERSBURG ARE DROPPED SIMULTANEOUSLY. 3 Tyee Lake generators and AVC with line compensation. Initial Loads: Wrangell 6 MW and Petersburg 9 MW. Water starting time constant T, = 1.25 séconds. EBASCO SERVICES INCORPORATED VI. REVIEW OF PROTECTION The proposed electrical protection schemes for Alaska Power Authority's Tyee Lake Hydroelectric Project has been reviewed and suggestions made for additions or modifications to the protection schemes. A summary of the protection schemes is provided here. This review is based on information provided in the drawings listed in Table VI-]. A. CONCLUSIONS AND RECOMMENDATIONS The Tyee Lake Hydroelectric Project electrical protection schemes in general follow industry practices and will provide satisfactory protection against faults on the electric power system. However, the following items will require additional review. Details of each item are given in sumnaries of the specific protection scheme in Section B. 1. Tyee Lake Generator Protection a. Consideration should be given to the addition of overvoltage/overfrequency protection to the generators. b. The exciter overcurrent relays should trip the generator lockout relay, device number 86G, and not just the field breaker, device number 41. c. Abnormal frequency annunication should be provided. 2. Tyee Lake Unit Transformer Protection No comments. VI-1 0204T TABLE VI-1 LIST OF DRAWINGS REVIEWED Drawing No. TitTe TY-47-003 Tyee Lake Power Plant Main Single Line Diagram TY-47-025 Tyee Lake Power Plant 480V Station Service Single Line Diagram TY-47-027 Tyee Lake Power Plant Relay Data and Protection Functional Diagram TY-57-01 Wrangell Switchyard Main Single Line Diagram and Control Switchboard Arrangement TY-57-02 Wrangell Switchyard Relay Data & Protecton Functional Diagram Ty-57-11 Wrangell Substation Main Single Line Diagram. TY-57-13 Wrangell Substaion Relay Data & Protection Functional Diagram TY-57-51 Petersburg Substation Main Single Line Diagram TY-57-53 Petersburg Substation Relay Data & Protection Functional Diagran VI-2 0204T B. 3. 4. 5. 6. Tyee Lake 69/138 kV Line and Bus Protection a. Closure of line breaker bypass switch disables the 69/138 kV bus differential relays and the line relays. Provisions are required to maintain this protection when the bypass switch is closed. b. Power line carrier on a transmission line with alternating overhead and submarine sections requires line traps and impedance matching at each overhead to submarine cable interface. Wrangell Switchyard a. The tripping function of the 7.5 MVA reactor fault pressure relay, device number 638, is not shown. Wrangell Substation a. To protect customer equipment from sustained overvoltages, the addition of overvoltage tripping may be required. Petersburg Substation a. Same as Wrangell Substation SUMMARY OF PROTECTIVE RELAY SC HEME 1. Tyee Lake Generator Protection: Tripping is through two independent lockout relays, the overall generator lockout relay (device number 86G) and the differential lockout relay (device number 87G). A generator differential relay is provided for internal generator faults and lead faults. The following protection is via the overall generator ]ockout relay. VI-3 0204T a. Stator overcurrent protection provided by voltage controlled overcurrent relays. b. Stator temperature detection. c. Stator ground protection by neutral resistor overvoltage relay. d. Overvoltage protection. e. Loss of excitation. f. Motoring or reverse power. Field ground protection. a . "Exciter overcurrent relays are provided which trip the exciter breaker. _ To be consistent with the action taken by the field ground relays, the overcurrent relays should trip the overall generator lockout relay. Voltage unbalance relays are provided for alarm only. In view of the large line charging requirements of the systen, the possibility exists of long duration overvoltages. Consideration should be given to refining the overvoltage protection with the addition of over-voltage/over-frequency relays. Consideration should be given to the addition of abnomal frequency relays for alarm only. VI-4 5. 0204T Tyee Lake Unit Transformer Protection In accordance with industry practice, the transformer protection consists of differential relays, neutral ground overcurrent relays, fault pressure sensors and over-temperature detection. Tyee Lake 69/138 kV Line and Bus Protection. The line relaying consists of three zone distance relaying with fault detectors for phase faults and directional overcurrent relays for ground faults. A bus differential is provided for the 69/138 kV bus. The line circuit breaker is provided with a bypass switch for breaker maintenance. Closure of this switch disables both the line and bus protection. Provisions are required for alternate protection of these facilities when the bypass switch is closed. One method is to supply the line relays from a third set of bushing current transformers on the unit transformer primaries. Carrier Conmunication Channel System communication is by means of power line carrier. The impedance mismatch at the interface between the overhead transmission line and the submarine cable will adversely affect operation of this channel. Proper design requires inserting line traps and matching the impedances at each interface. Wrangell Switchyard Protective Relaying The Petersburg line is protected by two zones of distance relaying supervised by fault detectors and directional ground Overcurrent relaying. The 7.5 MVAR reactor is equipped with VI-5 7. 0204T Phase and ground overcurrent protection. A fault pressure relay, device number 638, is shown on drawing TY-57-01 but its tripping function is not shown. Wrangell Substation Protective Relaying Transformer protection consists of differential relaying, phase, ground and neutral overcurrent relays, thermal relays and fault Pressure relays. Line faults are detected by reverse power relays. Overcurrent relaying is provided for the 12.5-kV bus and feeders. Station overvoltage relays are provided for alam only. There is a possibility of sustained overvoltages for certain system contingencies (i.e. failure of the 7.5 MVAR reactor when one generator is out of service at Tyee Lake). To protect customer equipment from the effects of a sustained overvoltage, these relays should be used for tripping. Greater security would be obtained with a two level scheme. Level I would trip on time delay and level II would trip instantaneously. Petersburg Substation The methods of protection and coments at Petersburg correspond to those of the Wrangell Substation. VI-6 VII - CONCLUSIONS This report described the process by which the interim alternative F was selected for initial operation of the Tyee Lake - Wrangell - Petersburg Power transmission system. Alternative F operates at 69 kV and employs a fixed 7.5 MVAR shunt reactor, located at Wrangell, to partially offset some 14 MVAR of reactive power generated by the underwater cables in the system, thereby allowing the system to operate even if only one generator is in service at Tyee Lake. The line can not transmit the power of three generators at 69 kV. Therefore, when the third generator is added, the system voltage must be raised to 138 kV and alternative means must be used for compensating the system. The report showed that Alternative F operates satisfactorily in the steady state provided that the reactive power loads are kept within rather strict limits. The study examined several cases of load acceptance, which involved starting a squirrel cage induction motor, and of load rejection, which involve the simultaneous loss of 50% of all loads on the systen. It showed that the system is stable against dynamic changes, and that it will recover from all postulated cases of load acceptance and load rejection without harmful interactions with other loads of the present system, though during the dynamic changes, considerable flicker and frequency deviation can occur for limited time periods. The use of fast static voltage regulators is justified for the hydro-generators because it reduces duration of flicker. Their exciter's ceiling should be high. The exciters should employ line drop compensation that is adjusted to regulate the voltage at the Wrangell tap. VII-1 The system is capable of accommodating squirrel cage induction motors rated up to about 350 HP with 60% voltage starting. However, it must be assumed that at no time will more than one motor over 100 HP start at any place on the system. Should larger motors be planned to operate from the system, conditions occurring during starting will have to be thoroughly investigated. Applying a three stage starting procedure to squirrel cage motors seens to have slim chance for success. A better approach is to use wound rotor motors using time-actuated current-1limited automatic starters. Finally, this report reviewed the protection of the Tyee Lake - Wrangell - Petersburg power system and gave some specific recommendations. VII-2 APPENDIX A LINE CHARACTERISTICS APPENDIX A A. Line Characteristics The transmission line between Tyee Lake, Wrangell and Petersburg is designed for 138 kV. The parameters were determined for both 138 kV and 69 kV based on the design data from IECO. Both overhead line and submarine cable parameters were calculated for each portion as designed. Characteristics for the portions using Dalia conductors were calculated based on the geometrical data received from IECO. 1.1 Tyee Lake - Wrangell Line Total length of the line is 42.75 miles. It is built of eight different segments with length, conductor type, and unit impedances given below. Line Conductor length Description Impedances Capacitance Segment miles (Type) Z) and Z) ohms C microfarads/ file mile; Y micro Mhos file a 13.1 37#8 Alumoweld Z, = -4667+j.98899 -0207 Zo = -7547+j 2.8462 b 3.91 Dove 2, = .161 + j.7564 0.2368 Zo = -4472+j 2.6352 Cc 2.08 Submarine Cable 2) = .33264+j.1584 179.52 micro Zo = +3379 +j.13728 Mho/Mile d 4.52 Dove Z] = -161 + j.7564 0.2368 Zo = -4472+j 2.6352 e 7.08 37#8 Alumoweld Z, = -4667+j.98899 -0207 Zo = -7547+j 2.8462 f 3.04 Dove Z, = -161 + j.7564 0.2368 Zo = -4472+j 2.6352 g 4.82 37#8 Alumoweld Z] = -4667+j.98899 -0207 Zo = -7547+j 2.8462 h 4.2 Dove Z} = -161 + j.7564 0.2368 Zo = -4472+j 2.6352 2 Wrangell - Petersburg Line Total length of the line is 38.91 miles. different segments. Line Conductor length Segment miles a 3.09 b 3.18 c 3.32 d 2.83 e 4.1 f 11.2 g 3.45 h 2.61 i 4.32 Description (Ty pe) Submarine Cable Dove Submarine Cable Dove Submarine Cable Dove Dalie Dove Dalia The line is built of nine Impedances Z) and Z, ois fnile Z] = -33264+j.1584 Z} = -161 + j.7564 Zo = -4472+j 2.6352 Z1 = -33264+j.1584 Z) = -161 + 5.7564 Zo = -4472+j 2.6352 2] = .33264+j.1584 Z) = -161 + 5.7564 Zo = -4472+j 2.6352 Z] = .225 + j.73 Zo = -625 + j2.543 Z] = -161 + 3.7564 Z) = -4472+j 2.6352 2) = -225 + j.73 Zo = -625 + j2.543 The length of the segments, the conductor type and the unit impedances are listed below: Capacitance C microf/Mile or Y micro Mhos Anile 179.52 micro Mho fnile 0.2368 microfarad/mile 179.52 micro Mho /nile 0.2368 nicrofarad/mile 179.52 micro Mho/nile 0.2368 nicrofarad/mile 0.2274 micro- faradfile 0.2368 nicrofarad/mile 0.2274 micro- farad/mile 3. Crystal Lake-Petersburg The line is presently operated at 22.9 kV but it will be uprated to 24.9 kV. The total length of line is 18 miles. It is equipped with 1/0 ACSR (Raven) conductor. The parameters for this line were calculated by Ebasco based on geometrical data. The capacitance of the line was neglected in the calculations. Line Conductor length Description Impedance Sedgment Miles (Type) oms/nile Capacitance as 18 Raven Z = 1.15+j.973 006 nicro- Zo = 3.428+j2.919 farad/mile APPENDIX B PER UNIT LINE IMPEDANCES APPENDIX B B. Per Unit Line Impedances All reactances are calculated in per unit on 100 MVA and 138 kV or 69 kV as applicable. The foraula used for per unit calculations is: = 2 Zou * “onms Sp / Mb Where Zohas is the impedance in ohms of the portion of line, Spb the base MVA and V, the selected base voltage. Per unit calculations for the 69 kV alternative change only the 138 kV line parameters by a factor of 4. All series elements change according to the fomula: v2 z b69 )=4Z pu 69 = 2pu 138 (Kise! pu 138 All capacitive line charging according to the formula: (ve Qu 69 = Spy 138 | “b69/ “b138 y= 0.25 Qu 138 All other values remain the same. The impedances are identified by the bus numbers shown in the one line diagram. B-1 Bus 4 to 5 13.1 miles 37#8 Alumoweld, 3.91 miles Dove a) Positive sequence 37#8 Z Dove Z -4667 +j .9899 oms/Mile. -161 +j .7564 otms/nile. Z = 6.7433 +j 15.9252. ohms total Zul 387° 035409+j .08362 p.u. 75u69 = .1416 + 5.3345 p.u. b) Zero sequence. 37#8 zy Dove Zo -7547 + 2.8462 otms/Mile -4472 + j2.6352 ohmsMmile Z total 2138 75u69 11.6351 +j 47.5889 ohms = .06109+j .249889. -24436+j.99955 p.u. c) Charging MVAR 37#8 C = .0207 micro Ffile Dove C = .02368 micro F/fmile " 6 Y = jw Cl = j 377 x (.2712 + .0926) x 10. = 137.1526 x 1075 Mho 2 Q 3g = vv = 137.1526 x 1076 138° MVAR = 2.612 MVAR. %o = .653 MVAR. B-2 Bus 5 to 6 a) b) Ci) 2.08 miles submarine cable. Positive Sequence 5.28 x 2.08 x (.063 +j .03) = .69189 +j .3295 ohms Z = .063 ++ j.03 ofms/1000 ft. Ze 75u138 = .003633 * j .00173 7 u69 = .014532 + j.00692 Zero Sequence Zz opul38 2 opu69 = .00369 + 3.001499 = .0147 + j.005996 Charging MVAR j 34 micro Mho/1000 ft. 5373.7 x 107° Mho = 0711 =v" = Qu Sb = 1.7775 MVar. Y = j 34 micro Mho. = 7.11 MVar. B-3 Bus 6 to 7 11.76 miles Dove 11.90 miles Alumoweld a) Positive sequence. Zeotay 7 (1-8934 + j 8.8953) + (5.5537 + j 11.7798) = 7.4471 + j 20.6751 ohms Zour3e = *0391 +3 . 10856 Zi yeg ~ -1564 + 5.4342 b) Zero sequence Zototar = 14:24 + J 64.8597. Z = .07477 +5 .34 opu c) Charging MVar. Y = j377 x (.02368 x 11.76 + 0.0207 x 11.9) x 107° = 197.852 x 107° Mho Q 33 7 YV = 3.768 MVar. %o = .942 Var. Bus 7 to 8 3.09 miles cable. Same unit data as before only length is different. a) Positive Sequence Zou 38 75u69 = .005397 + j .00257. = 021588 +j.01028 b) Zero Sequence = .00548 + 5.002227 = .02192 + 5.008908 zou 38 opul38 c) Charging MVar. % 38 = 10.55 MVYar. %o = 2.6375 MVar. B-4 Bus 8 to 9 3.18 miles Dove. Same unit values only length different. a) Positive Sequence N = .002688 +j.012628 pul38 7 4u69 = .010752 +j.050512 2 4pu138" -007466 +j.044 7 u69 = .029864 +j.176 b) Zero Sequence c) Charging MVar. 38 = .5406 MVar. %9 = .13515 Bus 9 to 10 3.32 miles of cable. Same unit data as before. a) Positive Sequence 75u138 = .005798 + j .002761 Zi yeg 7 “023192 + §.011044 b) Zero Sequence zopul39" -00633 +j.002392 Z 5p u69 = .02532 +j.009568 c) Charging MVar. 3g = 11-346 MYar. %o9 = 2.8365 B-5 Bus 10 to 11 2.83 miles Dove. Unit data same as before. a) Positive Sequence 75u138 = 002392 + j.011238 2469 = .009568 +j.044952 b) Zero Sequence = .006644 + 5.03915 7 opul38 Zopye9 * +026576 +j.1566 c) Charging MVar. % 38 = .4811 MVar. %o = .12027 Bus 11 to 12 4.1 miles cable. Unit data same as before. a) Positive Sequence 7u138 = .00716 + j.0034) 2u69 = .02864 +j. 01364 b) Zero Sequence zopul 38 =,0078 +j.00295 7 pu69 = 0302 +j. 0118 c) Charging MVar. 138 = 14 MVar. %o9 = 3.5 MVar. B-6 Bus 12 to 13 13.81 miles Dove and 7.77 miles Dalia. a) Positive Sequence Z = (3.462 + j 16.263) oms zm _ , pu138 ~ -01817 + j .08539 zu69 = .07268 +j7.34156 b) Zero Sequence Zototal 7 (9-615 + J 56.657) ots 2 pu138 = .0504 *J .2975 Zopueg = “2016 45-1.19 c) Charging MVar. % 38 = 3.655 MVar. %o9 = .91375 MVar. Total 21.5 miles Bus 14 to 15 (The 24.5 kV line to Crystal Lake). 18 miles of Raven conductor at 24.5 kV a) Positive Sequence tou = 3.339 + j2.824 b) Zero Sequence Zou = 9.951 + j8.475 B-7 a) b) c) Bus 7 to 17 (Wrangell) Four miles Dove overhead line. Positive Sequence 74u138 = .00338 + j .01588 7 4u69 = 0.1352 + j .06352 Zero Sequence 00939 +j.05534 .03756 +j.22136 zopul 38 1 pu69 Charging MVar. -68 MVar. -17 MVar. %38 %9 u Unit data as before. APPPENDIX C TRANSFORMER CHARACTERISTICS APPENDIX C C. Transformer Characteristics The characteristics of the main transformers are listed below. The characteristics of some of the 69 kV transformers differ somewhat from the values in IECO's original 138 kV transmission system. Therefore they are presented separately for the 138 kV and 69 kV alternatives. 1) Tyee Lake Substation. Characteristics - Rating - Voltage - Connection - Impedance 2% pu rating pu 10Q4VA - Taps on high voltage winding 2) Wrangell Substation Characteristics - Rating - Voltage - Connection - Impedance % pu rating pu 100 MVA - Taps on high voltage winding - Taps on low voltage winding 69 kV 11.25/15 MVA 13.8/69/138 kV delta/grounded star 10x! .8888 + 2.5% & + 5% 69 kV 6/8/10 (OA/FA/FA)MVA 138/69/12.47 kV Grounded star/ grounded star with tertiary in delta 7% 1.166 + 2.5% & + 5% LTC + 10% 138 kV 11.25/15 MVA 13.8/138 kV delta/grounded star 6.5% -5778 Source IECO and APA + 2.5% & + 5% 138 kV 10 MVA 138/ 2.47 kV Delta/grounded star Source APA and IECO LTC + 10% rR ay , ; L 10% as advised by IECO on June 3, 1982 was used in calculations. Actual values were not known at that time. C-1 3) 4) 5) Sawnill Feeder Transfomer Characteristics 69 kV 138 kV Source From IECO's letter on June 3, 1982 - Rating 3500 kVA - - Voltage 69/12.5 kV - - Connection delta/grounded star - - Impedance % to rating 7% p.ue 100 MVA 2 Petersburg Substation Characteri stics 69 kV 138 kV Source IECO - APA . > Rating 12/15/20 MVA 20 MVA - Voltage 138/69/24.9 kV 138/24.9 kV - Connection Grounded star/ Delta/grounded grounded star with star tertiary in delta - Impedance % to rating H-L=5%;H-T=10. 5% &% L-T=7.5% p.-u 100 MVA_ .4167 -8 - Taps on high voltage 3 taps. +10%,-2.5% - winding and -5% - Taps on low voltage LTC + 10% LTC + 10% winding Petersburg Diesel Plant (and Wrangell Diesel Plant, see P. IV-8). Characteristics 69 kV 138 kV Source IECO-APA - Rating 7.5/10 MVA 10 MVA - Voltage 24.9/2.4 kV 24.9/2.4 kV - Connection grounded star/delta grounded star/ delta - Impedance % to rating 5.5% &% pu 100 MVA_ 733 -8 C-2 Crystal Lake Station Characteristics 69 kV 138 kV Source IECO's letter on June 3, 1982 - Rating 2.5 MVA 2 MVA - Voltage 24.9/2.4 kV 22.9/2.4 kW! - Connection grounded star/ grounded star/ delta delta - Impedance % to rating 5.5% 5.3% pu 100 MVA a2 2.695 1/ The transformer was considered up-rated to 24.9 kV. It was assumed that the transfomer will not be changed. C-3 APPENDIX D GENERATOR CHARACTERISTICS D. 1) Generator Characteristics APPENDIX D The following is a listing of the generator characteristics used in the study. Tyee Lake Generators Characteristics - Rating - Voltage - Power Factor Impedances per unit on 12.5 MVA and 100 1VA base Xgs X'q unsaturated, X'q saturated Xq" unsaturated, X2, Xo Monent of inertia including turbine (Wk2) Speed Frequency Value 12,500 kVA 13.8 kV 9 12.5 MVA base/ 100 HVA base -9/7.2, «32/2.56 -28/2.24 -25/2, .25/2, .05/.4 224,567 lbs ft.2 720 RPM 60 Hz oonooom . ooCoOon no D-1 Source of data IECO's letter to APA #2145-210 dated June 3, 1982 Received from APA APA advised that it is under consideration to increase the moment of inertia to 300,000 Ibs ft.2. 2) a) Voltage regulator data. Manufacturer: Siemens-Al lis. Time required to reduce field Current from maximum to 10% of rated full load current after tripping field c.b. under 3- phase short circuit at generator stator with 105% voltage Voltage across discharge resistor (estimated) Crystal Lake Generators 2 to 4 sec. 300 V. There are two generators at Crystal Lake. One is a 2000 kVA Allis Chalmers Generator, the other a 500 kVA Westinghouse unit. Allis-Chalmers Generator Charactertistics - Rating - Voltage - Power Factor Inpedances per unit on 2.0 MVA and 100 MVA base Xq> X'a> X"ds Xo, Xo» x'q saturated Moment of inertia of motor Speed Frequency Value 2000 kVA 2400 kV 8 2 MVA/100 MVA base 1.04/52.0, .34/17, .29/14.5, .29/14.5, .03/1.5 34/17 27,500 Ibs ft. 600 RPM 60 Hz Source of Data Collected by Ebasco at the site and presented with APA documents Received by Ebasco fron Allis-Chalmers b) Westinghouse generator Characteri stic Value Source - Rating 500 kVA Collected by Ebasco at - Voltage 2400 V the site - Power Factor 8 - Speed 900 RPM - Frequency 60 Hz Impendances were considered similar to that of the 2000 kVA generator 3) a) Petersburg Diesel Generator Station There are five Diesel Generators in the Petersburg station. 2100 kW Gi-El ectromotive Diesel. Characteristics Value Source - Rating of Diesel 2100 kW Collected by Ebasco at the site. - Yitage 2400/4160 V - Power Factor -8 - Peak Capacity 2000 hours Der year 3575 kVA - Speed 900 RPM - Frequency 60 HZ Impedances on a 2.6 MVA 2.6 MVA base/100 MVA_ Received from and 100 MVA base base G@ Electronotive unit. ‘ u“ Xq> Xo X a X a Xs 1.66/63.84, 1.0/38.46, 44/16. 92, Xo, Xos -28/10. 769, .105/4.038, +22/8.46, .11/4.23 Moment of inertia of generator 12,965 1bs Ft? of engine 2,425 1bs ft? D-3 b) _c) 1250 kW Superior Diesel Characteristics - Rating of Diesel - Rating of Generator - Voltage - Power Factor - Speed - Frequency Impedances on 1.5 MVA and 100 MVA base Xg> X'qe X"qs X20 Xo Moment of inertia Value Source of data 1770 BHP Collected by Ebasco at the site 1563 kVA 2400/4160 V -8 360 RPM 60 Hz 1.563 MVA/100 MVA base 1.51/96.6, .324/2073, Received from - 2451/15. 68, Ideal Electric -246/15.739, .134/8.573 & Manuf. Co. Mans- field, Ohio. 25,200 1b ft.2 800 kW Caterpiller Diesel with KATO Generator Characteristics - Rating - Voltage - Power Factor - Speed - Frequency Impedances on 1.00 MVA and 100 MVA base. Xa» X"ds X"a> Xo, Xo» Xg, X"9, Moment of inertia Value Source of data 1000 kVA Data collected by Ebasco at the site. 2400/4160 V 8 1200 RPM 60 Hz 1.0 MVA/100 MVA base From Kato Engineering Generators Seattle 1.388 /138. 8, -24/24, .133/3.3 -121/12.1, .068/6.8, -624/62 1602.1 1b-inch@ D-4 d) Time constants T'go (direct axis transient open circuit time constant). T'y (direct axis transient short circuit time constant). Tg - (amature time constant) 600 kW Caterpillar Diesel Characteristics - Rating - Voltage - Power Factor - Speed - Frequency Impedances on .75 MVA and 100 HVA base Xq> X'ds X"ds Xa, Xo» X,, X" q X@ Monent of inertia Time constants T'do Tg Ta 2.4 sec. -42 sec. -02 sec. Values 750 kVA 2400/4160 V -8 1200 RPM 60 Hz -75 MVA/100 MVA base 1.391 /185.46, -249/33.2, -143/19, .132/17.6, 0.69/9.2, .83/110.66, -121/16.13 1250.6 1b-inch2 2.5 Sec. 0.45 Sec. 0.02 Sec. D-5 Source of data Data Collected by Ebasco at the site. Data from Kato Engineering Generators Seattle e) 4) a) 350 kW Detroit Diesel (Emerson GM Diesel) with Kato generator. Characteristics - Rating - Voltage - Power Factor - Speed - Frequency Inpedances on .438 MVA and 100 MVA base Kae Mae Xa» Kae Mos qq Moment of inertia Time constants T4o ™q Ta Va 1ue Source of data 438 kVA Data Collected by Ebasco at the site. 2400/4160 V 0.8 1800 RPA 60 Hz «438 MVA/100 MVA base Data from Kato Engineering Generators Seattle 1.063/242.69, .16/36.53 -089/20.31, .082/18. 72, -03/6.85, .64/146.11, -083/1 8.94 88.22 1b-inch@ 1.78 Sec. -27 Sec. 0.02 Sec. Wrangell Diesel Generator Station The station has eight diesel units out of which two (unit #6 and #8) are down and are not expected to be repaired. 1250 kW Worthington Units (Unit 1, 2, 3, 4 and 8 are identical) Characteristics - Rating - Voltage - Power Factor - Speed - Frequency Value Source of data 1563 kVA Data Collected by Ebasco at the site. 2400/4160 8 360 RPA 60 Hz D-6 b) c) Note: 500 kW Caterpillar Diesel Characteristics - Rating - Voltage - Power Factor - Speed - Frequency Impedances on .625 MVA and 100 MVA base Xqs xX ; X'as X"as x" xq, Xa. Xos a Time constants Monent of inertia 625 kW Ingersoll-Rand Diesel Characteristics - Rating - Voltage - Power Factor - Speed - Frequency Value 625 kVA 2400/4160 V 8 1200 RPM 60 Hz -625 MVA/100 MVA base Data received fron manufacturer. 1.25/200, .645/103.2, 1.219/35.04, -128/20.48, .109/17.44 -067/10.72, .03/4.8, -116/18.56 3.14 Sec. 0.48 Sec. 0.318 Sec. 1262.6 1b ft@ Value Data received fron manufacturer. 625 kVA 2400/4160 V -8 720 RPH 60 Hz Impedance data for the 1250 kW units and the 625 kVA Ingersol1-Rand Unit were extrapolated from the existing data on the other devices. D-7 5) Sawaill power plant The Sawnill has its own generation. Presently two (2000 kVA and 500 kVA) diesel generators and one 2250 kVA steam turbine generator are in operation. According to present assumptions the Diesel units will not operate after the Tyee-Lake transmission is completed. a) Stean-generator Characteristics Value Source of data - Rating 2250 kVA Based on on-line diagram of the Saw-Mi11 electrical distribution. - Voltage 2400/4160 V - Power factor 0.8 - Speed 3600 RPM - Frequency 60 Hz The impedance data for the 2250 kVA generator were extrapolated from typical data on similar generators. D-8 APPENDIX E IMPEDANCE DIAGRAMS: LOAD FLOW AND SHORT CIRCUIT 12.5 (8) Buses 5 to 12 are 138 kv SH @Q@QOOQoO@O © @ 12.5. MVA ©) MVA 0 + j.5777 (~) 0 + 5.5777 .0354 + 5.08362 -§.02612 -00363 + §.00173 -j.0711 .0391 + 5.10856 -§J.03768 -005397 + J.00257 -J.1056 5 MVAR -002688 + 5.0126 -§.00541 005798 + 5.002761 -§.11346 .00239 + j.0112 © -j.00481 -00716 + 5.00341 -J.1402 0817 + 5.08539 -j.0365 138 kV Petersburg O+ j.4 3.339 + 52.824 -§0.0004148 24.9 kV Crystal saue(2O 0 + j2.695 2.4 kV Crystal Lake © ), 2.5 MVA 13.8 kV Tyee Lake IMPEDANCES FOR POWER FLOW STUDY 100 MVA as indicated Base Power: Base Voltage: 0 + j.5777 138 kW Tyee lake 138 kV Wrangell Switchyard 00338 + §.01588 -j.0068 138 kV Wrangell Substation 0+ 5.8 12.5 kV 0 + §2.16 ALP Sawmi City of Wrangell 6) 5.6 MVA 24.9 kV 0+ 5.8 2.4 kV City of Petersburg (S) 6.25 MVA EBASCO SERVICES INCORPORATED C= G 5 ALTERNATIVE -1 | ALP SAWMILL | | setae? _| LAT switcuyaro _| ALP SAWMILL CONNECTED ALASKA POWER AUTHORITY TYEE LAKE SYSTEM STUDIES POSITIVE SEQUENCE DIAGRAM EBASCO SERVICES INCORPORATED ALTERNATIVE -1 TO 69 KV | TO 12.5 KV ALASKA POWER AUTHORITY _| LAT SWITCHYARD _ | LAT SUBSTATION _ | TYEE LAKE SYSTEM STUDIES CRYSTAL cond NEGATIVE SEQUENCE DIAGRAM | | | | = | | | | EBASCO SERVICES INCORPORATED 0.037135 *J022139 ALTERNATIVE -4 ALTERNATIVE-2 ALASKA POWER AUTHORITY TYEE LAKE SYSTEM STUDIES ZERO SEQUENCE DIAGRAM EBASCO SERVICES INCORPORATED APPENDIX F SHORT CIRCUIT CALCULATIONS OLD PHASES WHAT? OLD PHASES READY RUN PHASES 01: 5SEDT 09/08/82 USE MANUAL DATED JUNE 1976 NAME OF DATA FILE? LIST ALL BUSES? ADJ. CONTRIBUTIONS ONLY? WIDE PAPER? ? APAGYIZIS, YES, YES, YES INPUT DATA BUS TO BUS =R-POS,NEG X-POS,NEG ° 1 0 2 ° 2 ° 2 ° 3 ° 2 1 4 oO 0.8888 2 4 ° 0.8883 3 4 ° 0.8888 ° 4 999 9999 4 Z 0.3126 0.7784 7 17 0.0135 0.0636 17 28 0 0.0001 18 28 oO 1.1667 ° 23 IF? 9999 7 13 0.1781 0.4708 13 a7. °o 0.0001 14 27 ° 0.4167 ° 27 999 9999 ° 14 3.339 17.124 o 14 999 9999 14 20 ° 0.733 ° 20 ° 2.35 18 19 0 0.7333 ° 18 999 9999 9° 19 ° 2 BUSES AT 69 KV 4 7 13 17 BUSES AT 2.4 KV 19 20 BUSES AT 13.8 KV 1 2 3 BUSES AT 12.5 KV 13 BUSES AT 24.9 KV 14 INPUT DATA CORRECT? YES INPUT DATA LISTED IN OUTPUT? NO R-ZERO 10440 10440 10440 999 +3642 X-ZERO 0.0001 0.0001 0.0001 9999 9999 9999 0.252 2.377 0.2214 —0.1166 1.1083 0.99 1.5586 0.3333 0.0833 0.5416 0.6233 10.77 9999 9999 9999 0.6233 9999 GENERAL ELECTRIC CO INDUSTRIAL POWER SYSTEMS ENGINEERING OPERATION 50 BUS THREE PHASE & SINGLE PHASE SHORT CIRCUIT PROGRAM CASE APA69Z95 09/08/82 BASE MVA t 100 ALASKA POWER AUTHORITY ANCHORAGE » ALASKA 3 TYEE + WR+PE+CR GENS! SAW MILL OFF LINE (9/7/82) See dienrams attacned 3 PHASE E/Z= 4.38 KA ( 104.706 MVA)@ -88.664 DEG Bus 1 Tee Lake GND FAULT = 0.002 KA ( 0.043 MVA)@ -43.148 DEG 4 Z-POS= 0.022273 +J 0.954797 Z-ZERO= 5038.84 +J 4721.34 CONTRIBUTIONS ----3 PH FAULT---- ----------- L-G FAULT BUS TO BUS 3PH KA MAG ANGLE 3-10 KA MAG ANGLE POS KA MAG ANGLE 4 1 2.289 -87.967 0.001 -84.306 0 -42.451 0 1 2.092 -89.427 0.001 -0.011 1.383 -0.775 PU VOLTS --- 3 PH ---- = ------------ L-G FAULT ----------------- BUS MAG ANGLE POS ANGLE ZERO “ANGLE NEG ANGLE 1 0.0 0.0 1 -0.006 -1 -0.011 0 45.516 2 0.644 0.763 1 -0.002 0 -36.88 0 44.133 3 0.644 0.763 1 -0.002 0 -36.88 0 44.133 4 0.486 1.46 1 -0.003 0 4.26 0 44.134 7 0.643 -2.52 1 -0.002 0 10.969 0 50.039 13 0.694 -3.192 1 -0.002 0 19.557 0 52.685 14 0.735 -2.521 1 -0.002 0 18.976 0 52.47 17 0.649 -2.558 1 -0.002 0 13.687 0 50.225 18 0.754 -1.543 1 -0.002 0 13.539 0 50.225 19 0.82 -1.038 1 -0.001 0 13.232 0 50.225 20 0.798 -1.771 1 -0.001 0 19.265 0 52.47 27. (0.694 -3.192 1 -0.002 0 19.389 0 52.685 28 «40.649 -2.558 1 -0.002 0 13.661 0 50.225 BUS 2 3 PHASE E/Z= 4.38 KA ( 104.706 MVA)@ -88.664 DEG KV= 13.8 GND FAULT = 0.002 KA ( 0.043 MVA)@ -43.148 DEG 2-POS= 0.022273 +J 0.954797 — Z-ZERO= 5038.84 +J 4721.34 CONTRIBUTIONS ----3 PH FAULT---- ----------- L-G FAULT BUS TO BUS 3 PH KA MAG ANGLE 3-10 KA MAG ANGLE POS KA MAG ANGLE 4 2 2.289 -87.967 0.001 -84.306 0 -42.451 0 2 2.092 -89.427 0.001 -0.011 1.383 -0.775 PU VOLTS --- 3 PH ---- — ------------ L-G FAULT ----------------- BUS MAG ANGLE POS ANGLE ZERO ANGLE NEG ANGLE 2 0.0 0.0 1 -0.006 -1 -0.011 0 45.516 1 0.644 0.763 1 -0.002 0 -36.915 0 44.133 3 0.644 0.763 1 -0.002 0 -36.915 0 44.133 4 0.486 1.46 1 -0.003 0 4.261 0 44.134 7 0.643 -2.52 1 -0.002 0 10.996 0 50.039 13° 0.694 -3.192 1 -0.002 9 20.003 0 52.4685 14 0.735 -2.521 1 -0.002 0 19.432 0 52.47 17 0.649 -2.558 1 -0.002 0 13.738 0 50.225 18 0.754 -1.543 1 -0.002 0 13.578 0 50.225 19 0.82 -1.038 1 -0.001 0 ° 50.225 es s Sens 14.168 - 2 - CASE APA69Z95 27 0.694 -3.192 1 -0.002 0 19.553 0 52.685 28 0.649 -2.558 1 -0.002 0 13.801 0 50.225 BUS 3 3 PHASE E/Z= 4.38 KA ( 104.706 MVA)@ -88.664 DEG KV= 13.8 GND FAULT = 0.002 KA ( 0.043 MVA)@ -43.148 DEG Z-POS= 0.022273 +J 0.954797 Z-ZERO= 5038.84 +J 4721.34 CONTRIBUTIONS ----3 PH FAULT---- ----------- L-G FAULT BUS TO BUS 3PH KA MAG ANGLE 3-10 KA MAG ANGLE POS KA MAG ANGLE 4 3 2.289 -87.967 0.001 -84.306 0 -42.451 ° 3 2.092 -89.427 0.001 -0.011 1.383 -0.775 PU VOLTS --- 3 PH ---- 9 --~--------- L-G FAULT ----------------- BUS MAG ANGLE POS ANGLE ZERO ANGLE NEG ANGLE 3 0.0 0.0 1 -0.006 -1 -0.011 0 45.516 1 0.644 0.763 1 -0.002 0 -36.901 0 44.133 2 0.644 0.763 1 -0.002 0 -36.901 0 44.133 4 0.486 1.46 1 -0.003 0 4.278 0 44.134 7 0.643 -2.52 1 -0.002 0 11.093 0 50.039 13 0.694 -3.192 1 -0.002 0 19.965 0 52.685 14 0.735 -2.521 i -0.002 0 19.063 0 52.47 17 0.649 -2.558 1 -0.002 0 13.843 0 50.225 18 0.754 -1.543 1 -0.002 0 13.892 0 50.225 19 0.82 -1.038 1 -0.001 0 13.936 0 50.225 20 0.798 1.771 1 -0.001 0 21.207 0 52.47 27 0.694 --3.192 1 -0.002 0 20.246 0 52.685 28 «40.649 -2.558 1 -0.002 0 13.788 0 50.225 Bus _4_ 3 PHASE E/Z= 1.18 KA ( 141.044 MVA)@ -87.282 DEG KV= 42 Tyee lake GND FAULT = 1.521 KA ( 181.743 MVA)@ -87.463 DEG 6AKV bus Z-POS= 0.033629 +J 0.708202 _Z-ZERO= 0.005823 +J 0.232659 CONTRIBUTIONS ----3 PH FAULT---- ----------- L-G FAULT BUS TO BUS 3 PH KA MAG ANGLE 3-10 KA MAG ANGLE POS KA MAG ANGLE 1 4 0.29 -89.427 0 -40.054 0.124 -89. 609 2 4 0.29 -89.427 0 -40.054 0.124 -89. 609 3 4 0.29 -89.427 0 -40.054 0.124 -89.609 7 4 0.313 -81.326 0.118 -77.219 0.135 -81.507 ° 4 0 -84.295 1.404 -88.324 0 -85.337 PU VOLTS --- 3 PH ---- = ------------ L-G FAULT ----------------- BUS MAG ANGLE POS ANGLE ZERO ANGLE NEG ANGLE 4 0.0 0.0 0.57 04136-01141 1.104 -0.43 -0.181 1 0.308 0 0.703 0.077 -0.097 -40.053 -0.297 -0.181 2 0.308 0 0.703 0.077 -0.097 -40.053 -0.297 -0.181 3 0.308 Oo 0.703 0.077 -0.097 -40.053 -0.297 -0.181 7 0.314 -13.205 0.702 -2.439 -0.026 7.88 -0.3 5.724 13° 0.414 -12.494 0.745 -2.998 -0.007 16.68 -0.259 8.37 14 0.491 -8.824 0.78 -2.329 -0.003 16.167 -0.223 8.156 17 0.326 -12.929 0.707 -2.46 -0.018 10.636 -0.295 5.911 18 0.524 -5.59 0.795 -1.534 -0.008 10.635 -0.207 5.91 19 0.651 -3.289 0.85 -1.05 -0.004 10.635 -0.151 5.91 20 0.611 -5.4 0.832 -1.663 -0.002 16.167 -0.17 8.156 27 0.414 -12.493 0.745 -2.898 -0.004 16.359 -0.259 8.37 28 0.326 -12.928 0.707 -2.46 -0.022 10.636 -0.295 5.911 LIS 3 PHASE E/Z= 0.92 KA ( 109.914 MVA)@ -83.269 DEG KV= 49 Wranagit GND FAULT = 1.101 KA ( 131.425 MVA)@ -83.392 DEG Switchyard Z-POS= 0.106644 +1 0.903512 Z7-Z7ERO= 0.048994 +.1.0 ASTNAR CASE APA69Z9S CONTRIBUTIONS ----3 PH FAULT---- = ----------- BUS TO BUS 3 -PH KA MAG ANGLE 3-10 KA MAG ANGLE POS KA MAG ANGLE 4 7 0.473 -79.524 0.188 -77.475 0.189 -79.647 13 7 0.238 -85.427 0.227 -79.845 0.095 -85.551 17 7 0.212 -89.229 0.688 86.182 0.084 -89.353 PU VOLTS --- 3 PH ---- = ------------ L-G FAULT ----------------- BUS MAG ANGLE POS ANGLE ZERO ANGLE NEG ANGLE 7 0.0 0.0 0.601 0.082 -0.202 0.489 -0.399 -0.124 1 0.632 -5.884 0.852 -1.719 -0.013 -29.207 -0.15 9.795 2 0.632 -5.884 0.852 -1.719 -0.013 -29.207 -0.15 9.795 3 0.632 -5.884 0,852 -1.719 -0.013 -29.207 -0.15 9.795 4 0.474 -11.403 0.787 -2.689 -0.019 11.95 -0.217 9.795 13 0.143 -16.148 0.656 -1.324 -0.058 9.29 -0.345 2.52 14 0.257 -7.044 0.703 -0.975 -0.024 8.776 -0.297 2.305 17 0.016 -11.213 0.607 -0.04 -0.141 3.245 -0.393 0.063 18 0.311 -0.412 0.725 --0.024 + -0.062 3.245 -0.275 0.062 19 0.496 -0.189 0.799 -0.016 -0.031 3.245 -0.201 0.062 20 0.433 -3.185 0.774 -0.675 -0.012 8.776 -0.227 2.305 27 0.143 -16.144 0.656 -1.324 -0.027 8.968 -0.345 2.52 28 0.016 11.196 0.607 -0.04 -0.173 3.245 -0.393 0.063 BUS 13. 3 PHASE E/Z= 0.76 KA ( 90.772 MVA)@ -82.07 DEG KV= 49. Fetersvors GND FAULT = 0.931 KA ( 111.295 MVA)@ -82.942 DEG wornk- 6T (1-POS= 0.151995 +J 1.09112 Z-ZERO= 0.027236 +J 0.492879 CONTRIBUTIONS ----3 PH FAULT---- ----------- L-G FAULT BUS TO BUS 3 PH KA MAG ANGLE 3-10 KA MAG ANGLE POS KA MAG ANGLE 7 13 0.486 -78.68 0.211 -75.063 0.199 -79.552 27 13 0.275 -88.075 0.722 -85.24 0.112 -88.947 PU VOLTS --- 3 PH ---- = ------------ L-G FAULT ----------------- BUS MAG ANGLE POS ANGLE ZERO ANGLE NEG ANGLE 13 0.0 0.0 0.591 0.603 -0.183 3.895 -0.409 -0.872 1 0.742 -4.937 0.893 -1.57 -0.003 -19.956 -0.11 12.891 2 0.742 -4.937 0,893 -1.57 -0.003 -19.956 -0.11 12.891 3 0.742 -4.937 0,893 -1.57 -0,003 -19.956 -0.11 12.891 4 0.63 -8.416 0.846 -2.394 -0.005 21.201 -0.158 12.891 7 0.293 -9.401 0.709 -1.22 -0.049 9.74 -0.291 2.97 14 0.137 1.352 0.647 «0.592 -0.077 3.382 -0.353 -1.087 17 0.304 -9.319 0.714 ~-1.266 -0.034 12.496 -0.287 3.155 18 0.511 -3.875 0.799 -0.792 -0.015 12.496 -0.201 3.154 19 0.642 -2.256 0.853 -0.543 -0.008 12.496 -0.147 3.154 20 0.342 0.413 0.731004 -0.038 3.382 -0.269 -1.087 27 0 1.352 0.591 0.603 -0.087 3.574 -0.409 -0.872 28 0.304 -9.318 0.714 1.266 -0.042 12.496 -0.287 3.155 BUS 14, 3 PHASE E/Z= 1.968 KA ( 84.887 MVA)@ -83.947 DEG KY= feterrvors GND FAULT = 2.637 KA ( 113.741 MVA)@ -84.376 DEG Subeh 24 Z-POS= 0.124237 +J 1.17146 Z-ZERO= 0.010028 +J 0.281952 CONTRIBUTIONS ----3 PH FAULT---- 9 ----------- L-G FAULT BUS TO BUS 3 PH KA MAG ANGLE 3-10 KA MAG ANGLE POS KA MAG ANGLE 20 14 0.752 -89.427 0 -80.707 0.336 -89.857 27 14 1.089 -80.772 1.405 -84.482 0.486 -81.201 ° 14 0.133 -78.976 1.232 -84.255 0.062 -79.285 PU VOLTS --- 3 PH ---- — ------------ L-G FAULT BUS MAG = ANGLE POS ANGLE ZERO ANGLE NEG ANGLE 0.465 0.033 oO L-G FAULT~------------------------------------------- 0.145 4 - CASE APAS9Z95 140.0 0.0 0.553 0.347 -0.107 3.588 -0.447 -0.429 1 0.789 -3.184 0.905 -1.194 -0.001 -21.904 -0.097 11.242 2 0.789 -3.184 0.905 -1.194 -0.001 -21.904 -0.097 11.242 3 0.789 -3.184 0.905 -1.194 -0.001 -21.904 -0.097 11.242 4 0.696 -5.215 0.863 -1.809 -0.002 19.254 -0.14 11.242 7 0.425 -2.37 0.743 -0.457 -0.021 7.793 -0.257 1.322 13 0.196 8.654 0.64 1.419 -0.078 1.948 -0.36 -2.52 17 0.435 -2.522 0.747 -0.51 -0.015 10.549 -0.253 1.506 18 0.604 -1.272 0.823 -0.324 -0.006 10.549 -0.177 1.506 19 0.71 -0.791 0.87 -0.224 -0.003 10.549 -0.13 1.506 20 0.238 «#0 0.66 0.222 -0.053 3.588 -0.34 -0.429 27 «0.196 «= 8.655 (0 4 1.419 -0.09 3.334 -0.36 -2.52 28 0.435 -2.522 0.747 -0.51 -0.018 10.549 -0.253 1.506 / -BuUS 17, 3 PHASE E/Z= 0.886 KA ( 105.888 MVA)@ -83.273 DEG .KY= 69. Weengell GND FAULT = 1.107 KA ( 132.281 MVA)@ -63.865 DEG SU. CU Z-POS= 0.110629 +J 0.937894 — 2-ZERO= 0.021139 +J 0.37912 CONTRIBUTIONS ----3 PH FAULT---- ----------- L-G FAULT BUS TO BUS 3 PH KA MAG ANGLE 3-I0 KA MAG ANGLE POS KA MAG 7 17 0.673 “81.313 0.291 -76.488 0.28 28 17 0.215 -89.424 0.819 -86.483 0.09 PU VOLTS --- 3 PH ---- — ------------ L-G FAULT ----------------- BUS MAG ANGLE POS ANGLE ZERO ANGLE NEG ANGLE 170.0 0.0 0.584 0.422 -0.167 2.944 -0.416 -0.592 1 0.652 -5.51 0.854 -1.647 -0.009 -26.924 -0.149 9.509 2 0.652 -5.51 0.854 -1.647 -0.009 -26.924 -0.149 9.509 3 0.652 -5.51 0.854 -1.647 -0.009 -26.924 -0.149 9.509 4 0.501 -10.397 0.789 -2.575 -0.013 14.234 -0.215 9.509 7 0.052 -3.297 0.605 0.267 -0.141 2.773 '-0.395 -0.41 13. 0.187 -12.447 0.66 -1.153 -0.04 11.573 -0.341 2.232 14. 0.296 -6.229 0.706 -0.84 -0.017 11.06 -0.294 2.017 18 0.299 0.001 0.708 0.244 -0.074 2.944 -0.292 -0.592 19 0.487 0 0.786 0.161 -0.037 2.944 -0.214 -0.592 20 0.463 -3.036 0.776 -0.583 -0.008 11.06 -0.224 2.019 27. (0.187 -12.451 0.66 -1.154 -0.019 11.252 -0.341 2.234 28 «#0 0.004 0.584 0.422 -0.205 2.944 -0.416 -0.592 Bus 18, 3 PHASE E/Z= 3.609 KA ( 78.139 MVA)@ -87.2 DEG KY= Wrange\t GND FAULT = 4.598 KA ( 99.543 MVA)@ -87.472 DEG fab 10.6 KV 2-POS= 0.062517 +J 1.27824 Z-ZERO= 0.007929 +J 0.454364 CONTRIBUTIONS ----3 PH FAULT---- BUS TO BUS 3 PH KA MAG ANGLE 3-10 KA MAG ANGLE POS KA MAG 19 18 1.69 -89.427 0 -82.766 0.718 28 18 1.921 -85.242 1.246 -86.324 0.816 0 18 ° -84.295 3.352 -87.899 0 PU VOLTS --- 3 PH ---- 9 --~--------- L-G FAULT --- BUS MAG ANGLE POS ANGLE ZERO ANGLE NEG ANGLE 180.0 0.0 0.575 0.2 -0.151 1.529 -0.425 -0.271 1 0.817 -1.392 0.922 -0.501 -0.003 -30.531 -0.078 5.901 2 0.817 -1.392 0.922 -0.501 -0.003 -30.531 -0.078 5.901 3 0.817 -1.392 0.922 -0.501 -0,.003 -30.531 -0.078 5.901 4 0.736 -2.233 0.887 -0.751 -0.004 10.627 -0.113 5.901 7 0.512 3.586 0.793 1.054 -0.047 -0.833 -0.208 -4.017 13. 0.577. 0.81 0.82 0.301 -0.013 7.966 -0.18 -1.375 14 OARS 0.759 nN cas n 707 naar 7 Aen aA «ce sen ANGLE PHA PH B PH C -81.905 0.657 0.184 0.184 -90.016 0.452 0.184 0.184 -89.699 1.435 0.717 0.717 -85.514 2.047 0.401 0.401 84.993 3.352 ° ° - 5 - CASE APA69Z95 -80.925 -87.314 17 0.485 4.184 0.781 1.179 -0.056 -0.662 -0.22 -4.198 19 0.268 0 0.689 0.122 -0.075 1.529 -0.311 -0.271 20 0.722 0.508 0.882 0.213 -0.003 7.453 -0.118 -1.588 27 0.577. 0.809 «= 0.82-s«0 301. -0.0068 ~7.645 -0.18 1.374 28 40.485 4.184 0.781 1.179 -0.051 -1.535 -0.22 -4.198 3 PHASE E/Z= 19.692 KA ( 81.862 MVA)@ -88.178 DEG _KY= 2.4 Wrangell GND FAULT = 0.014 KA ( 0.06 MVA)@ -84.297 DEG diesel genes. Z-POS= 0.038838 +J 1.22095 Z-ZERO= 499.502 +J 4999.61 CONTRIBUTIONS ----3 PH FAULT---- ----------- L-G FAULT BUS TO BUS 3 PH KA MAG ANGLE 3-10 KA MAG ANGLE FOS KA MAG 18 19 7.673 -86.22 0.007 -84.297 0.002 ° 19 12.027 -89.427 0.007 -84.297 6.014 PU VOLTS --- 3 PH ---- L-G FAULT --- -- BUS MAG ANGLE ZERO ANGLE ANGLE 19 0.0 0.0 1 -0.001 -1 -0.002 0 3.882 1 0.859 -0.854 1 ° 0 -27.622 0 9.076 2 0.859 -0.9854 1 ° ° -27.622 0 9.076 3 0.859 -0.854 1 ° 0 -27.622 0 9.076 4 0.797 -1.33 1 oO ° 13.639 0 9.076 7 0.626 2.831 1 ° ° 2.346 0 -0.841 13 0.676 0.999 1 0 ° 11.127 0 1.8 14 0.72 = 0.893 1 ° ° 10.647 0 1.585 17 0.606 3.206 1 0 ° 2.495 0 -1.023 18 0.234 3.206 1 -0.001 ° 4.7 ° 2.904 20 0.787 0.622 1 ° ° 11.032 0 1.586 27 0.676 0.998 1 0 ° 10.879 0 1.801 28 0.606 3.206 1 0 0 1.655 0 -1.022 BUS 20, 3 PHASE E/Z= 19.371 KA ( 80.528 MVA)@ -86.41 DEG KV= 2.4 feders! GND FAULT = 0.014 KA ( 0.06 MVA)@ -84.296 DEG diesel ¢. Z-POS= 0.077771 +J 1.23936 Z-ZERO= 499.503 +J 4999.57 CONTRIBUTIONS ----3 PH FAULT---- ----------- L-G FAULT BUS TO BUS 3 PH KA MAG ANGLE 3-10 KA MAG ANGLE POS KA MAG ANGLE 14 20 9.166 -83.039 0.007 -84.296 0.002 ° 20 10.236 -89.427 0.007 -84.296 5.118 PU VOLTS --- 3 PH ---- 9 ------------ L-G FAULT ----------------- BUS MAG ANGLE POS ANGLE ZERO ANGLE NEG ANGLE 20 «0.0 0.0 1 -0.001 -1 -0.001 0 2.114 1 0.846 -1.699 1 ° 0 -21.546 0 11.322 2 0.846 -1.699 1 ° 0 -21.546 0 11.322 3 0.846 -1.699 1 ° 0 -21.546 0 11.322 4 0.777 2.669 1 -0.001 0 19.937 0 11.322 7 0.584 0.507 1 0 ° 7.947 0 1.402 13 0.421 6.321 1 ° ° 2.06 0 -2.44 14 0.279 6.388 1 0 0 3.684 0 -0.349 17 0.591 0.365 1 0 0 10.679 0 1.588 18 0.713 0.212 1 0 0 11.039 0 1.587 19 0.79 0.14 1 0 0 10.703 0 1.587 27. 0.421 &. 322 1 0 0 3.443 0 -2.44 28 «0.591 0.366 1 ° ° 10.736 0 1.586 BUS 27 3 PHASE E/Z= 90.77 MVA@ -82.07 DEG GND FAULT = 7 ope— oO 4519Re 2.1 4 121.328 MVA@ -82.707 DEG PH A oO. oO. 006 007 - 6 - CASE APA&9Z95 CONTRIBUTIONS ----3 PH FAULT---- = ----------- L-G FAULT--—------—--—--------—-—-—--—----- BUS TO BUS 3 PH MVA MAG ANGLE 3-10 MVA MAG ANGLE POS MVA MAG ANGLE PH A PH B PH C 13 27 58.107 ~78.674 13.109 -75.15 25.889 -79.311 56.138 21.534 21.534 14 27 32.877 -88.074 47.755 -82.84 14.648 -88.711 45.161 2.014 2.014 oO az 0.01 -84.295 60.6 -84.233 0.005 -86.457 60.6 ° ° PU VOLTS --- 3 PH ---- 000 --3--------- L-G FAULT ---~------------~ BUS MAG ANGLE Pos ANGLE ZERO ANGLE NEG ANGLE 27 0.0 0.0 0.555 0.512 -0.109 5.194 -0.446 -0.637 1 0.742 -4.937 0.884 -1.761 -0.002 -20.043 -0.12 13.126 2 0.742 -4.937 0.884 -1.761 -0.002 -20.043 -0.12 13.126 3 0.742 -4.937 0.884 -1.761 -0.002 -20.043 -0.12 13.126 4 0.63 -8.415 0.833 -2.7 -0.002 21.114 -0.173 13.126 Z 0.293 -9.397 0.683 -1.49 -0.025 9.653 -0.318 3.205 13 ° 10.753 0.555 0.512 -0.095 3.809 -0.446 -0.638 14 0.137 1.353 0.616 0.532 -0.096 5.002 -0.385 -0.852 a7 0.304 -9.32 0.688 -1.539 -0.018 12.409 -0.313 3.391 18 O.511 -3.876 0.781 -0.95 -0.008 12.409 -0.219 3.39 19 0.642 -2.256 0.84 -0.646 -0.004 12.409 -0.16 3.39 20 0.342 0.413 0.707 0.353 -0.048 5.002 -0.293 -0.852 28 40.304 -9.315 0.688 -1.538 -0.022 12.409 -0.313 3.389 BUS 28 3 PHASE E/Z= 105.882 MVA@ -83.274 DEG GND FAULT = 129.453 MVA@ -83.766 DEG Z-POS= 0.110624 +J 0.937946 Z-ZERO= 0.030403 +J 0.427843 CONTRIBUTIONS ----3 PH FAULT~--- ee LOU: BUS TO BUS 3 PH MVA MAG ANGLE 3-10 MVA MAG ANGLE POS MVA MAG ANGLE PHA PH B PH C 17 28 80.422 -81.313 41.815 -76.39 32.775 -81.806 79.438 18.945 18.945 18 28 25.645 89.426 32.065 -87.258 10.451 -89.919 31.583 0.545 0.545 ° 28 0.01 -84.295 56.083 -87.258 0.004 -88.279 56.083 0O ° PU VOLTS --- 3 PH ---- rr RL BUS MAG ANGLE Pos ANGLE ZERO ANGLE NEG ANGLE 28 0.0 0.0 0.592 0.339 -0.185 2.169 -0.408 -0.492 1 0.652 -5S.509 0.857 -1.623 -0.011 -26.825 -0.145 9.607 2 0.652 -5.509 0.857 -1.623 -0.011 -26.825 -0.145 9.607 3 0.652 -5.509 0.857 -1.623 -0.011 -26.825 -0.145 9.607 4 0.501 -10.395 0.794 -2.531 0.016 14.332 -0.21 9.607 7 0.052 -3.28 0.614 0.196 -0.17 2.871 -0.386 -0.311 130 0.187 -12.439 0.667 -1.165 0.049 11.672 -0.333 2.33 14 0.296 -6.226 0.712 -0.854 -0.02 11.158 -0.288 2.116 17 ° 8.113 0.593 0.339 -0.201 3.043 -0.408 -0.493 18 0.299 0.001 0.714 0.197 -0.067 2.169 -0.286 -0.493 19 0.487 oO 0.791 0.13 -0.033 2.169 -0.209 -0.493 20 0.463 -3.033 0.781 -0.594 -0.01 11.158 -0.219 2.116 ae. 0.187 -12.436 0.667 -1.165 -0.023 11.35 -0.333 2.33 THREE PHASE FAULT CURRENTS —>— IN KA AND TAGES C_J_IN PER UNIT WRANGE LI SWITCHYARD LOCATION ae) r FAULT _MVA!:_104.7 | FAULT KA: 4.4 TYEE LAKE 13.8KV o IPETERSBURG |SUBSTATION | [0.74] | os 9 2 HYDRO GENERATORS | 7h KV) eu [0.80] 2.4 ALASKA POWER AUTHORITY TYEE LAKE SYSTEM STUDIES WRANGELL POWERHOUSE- SHORT CIRCUIT CALCULATIONS SUBSTATION , EBASCO SERVICES INCORPORATED 6 DIESEL GENERATORS THREE PHASE FAULT CURRENTS —>— IN KA AND TAGES C_J IN PER UNIT RANGEL swroHNARD Pete wing | FAULT _MVA! 141.0 69KV | FAULT KA: 1.18 ___TYEE LAKE _ --- : 13.8KV | (a4) IPETERSBURG |SUBSTATION | pCerSTAL. LAKE [0.49] | | | | | | | ! 2 HYDRO L GENERATORS < a | | | | [0.65] | | | | | | | | ALASKA POWER AUTHORITY be aeeeennes TYEE LAKE SYSTEM STUDIES WRANGELL POWERHOUSE- SHORT CIRCUIT CALCULATIONS SUBSTATION EBASCO SERVICES INCORPORATED THREE PHASE FAULT CURRENTS —>— IN KA AND TAGES C_2_IN PER UNI 69KV Pune [ola], [0.26] |PETERSBURG |SUBS TATION ————4 a | i [0.43] pnANGLL SWITCHYARD | | | 6 DIESEL GENERATORS SUBSTATION LOCATION OF FAULT: @) FAULT MVA!_ 109.9 TYEE LAKE ALASKA POWER AUTHORITY TYEE LAKE SYSTEM STUDIES SHORT CIRCUIT CALCULATIONS EBASCO SERVICES INCORPORATED THREE PHASE FAULT CURRENTS —>— IN KA AND TAGES C_3 IN PER UNIT CRYSTAL LAKE rf GENERATORS WRANGELL_SWITCHYARD r TT | l 69KV re IPETERSBURG |SUBSTATION [0.14] aed ane. | | | | i [0.34] | ! | | 5 DIESEL GENERATORS SS ee PETERSBURG POWERHOUSE SUBSTATION LOCATION OF FAULT: ( ) FAULT _MVA:_ 90.8 FAULT KA: _0.76 TYEE LAKE ALASKA POWER AUTHORITY TYEE LAKE SYSTEM STUDIES SHORT CIRCUIT CALCULATIONS EBASCO SERVICES INCORPORATED THREE PHASE FAULT CURRENTS —>— IN KA AND TAGES C_1_IN PER UNIT WRANGELL_SWITCHYARD LOCATION OF aur: (4) OT r FAULT MVA! 84.9 69 KV FAULT KA: 1.97 TYEE LAKE [0.20] IPETERSBURG |SUBSTATION GENERATORS we ee ed ALASKA POWER AUTHORITY TYEE LAKE SYSTEM STUDIES PETERSBURG POWERHOUSE WRANGELL POWERHOUSE- SHORT CIRCUIT CALCULATIONS SUBSTATION EBASCO SERVICES INCORPORATED THREE PHASE FAULT CURRENTS —>— IN KA AND TAGES C_J IN PER UNIT eases)" amen Locarion or sau: 2) FAULT MVA:_ 105.9 69KV FAULT KA: 0.89 TYEE LAKE [0.19] |PETERSBURG |SUBSTATION | CRYSTAL_LAKE [0.30] | ey =) GENERATORS 1 | | | | | } 2 HYDRO L ALASKA POWER AUTHORITY TYEE LAKE SYSTEM STUDIES SHORT CIRCUIT CALCULATIONS EBASCO SERVICES INCORPORATED THREE PHASE FAULT CURRENTS —>— IN KA AND LOCATION OF FAULT: (8) TAGES C_J IN PER UNIT LL_SWITCHYARD “4 FAULT MVA!_ 78.14 69 KV FAULT KA: 3.61 TYEE LAKE eet (a.0e) |PETERSBURG |SUBSTATION | [0.64] | ooo oal GENERATORS ALASKA POWER AUTHORITY oD SED GENERATORS TYEE LAKE SYSTEM STUDIES a —— ———-—__J NIRENGETI" POWERHOUSES SHORT CIRCUIT CALCULATIONS SUBSTATION EBASCO EBASCO SERVICES INCORPORATED THREE PHASE FAULT CURRENTS —>— IN KA AND VOLTAGES C_J_IN PER UNIT 69KV (0.68) |PETERSBURG |SUBSTATION | [0.72] | eT RRANGEEL SWITCHYARD SUBSTATION LOCATION OF FAULT: © FAULT _MVA!_ 81.9 FAULT KA: 19.7 TYEE LAKE ALASKA POWER AUTHORITY TYEE LAKE SYSTEM STUDIES SHORT CIRCUIT CALCULATIONS EBASCO SERVICES INCORPORATED THREE PHASE FAULT CURRENTS —>— IN KA AND OLTAGES C_J IN PER UNIT wraMCeL suo ee ear: 2D | FAULT _MVA! 80.5 69KV FAULT KA: 19.4 TYEE LAKE 0. Coz) IPETERSBURG |SUBS TATION | “ [0.28] | | GENERATORS ALASKA POWER AUTHORITY 1° DIESEL GENERATORS | TYEE LAKE SYSTEM STUDIES PETERSBURG POWERHOUSE WRANGELL POWERHOUSE- SHORT CIRCUIT CALCULATIONS SUBSTATION EBASCO SERVICES INCORPORATED GENERAL ELECTRIC CO INDUSTRIAL POWER SYSTEMS ENGINEERIN SO BUS THREE PHASE & SINGLE PHASE SI IG OPERATION HORT CIRCUIT PROGRAM ANGLE -42.308 0.941 ----------- L-G FAULT~------------------------------------------- CASE APA69Z92 09/08/82 BASE MVA + 100 ALASKA POWER AUTHORITY ANCHORAGE, ALASKA + +PE+ i 2.5 KV__(9/7/82) -BUS 1. 3 PHASE E/Z= 4.405 KA ( 105.295 MVA)@ -&8.498 DEG KV= 13.8 Tee lake GND FAULT = 0.002 KA ( 0.043 MVA)@ -43.148 DEG Sener. Z-POS= 0.024898 +J 0.949383 Z-ZERO= 5038.84 +J 4721.34 CONTRIBUTIONS ----3 PH FAULT---- -- -- L-G FAULT--- BUS TO BUS 3 PH KA MAG ANGLE 3-10 KA MAG ANGLE POS KA MAG 4 1 2.314 -87.658 0.001 -84.306 0 0 1 2.092 -89.427 0.001 -0.011 1.383 PU VOLTS --- 3 PH ---- — ------------ L-G FAULT ----------------- BUS MAG ANGLE POS — ANGLE ZERO ANGLE NEG ANGLE 1 0.0 0.0 1 -0.006 -1 -0.011 0 45.35 2 0.648 0.929 1 -0.002. 0 -36.88 0 43.64 3 0.648 0.929 1 -0.002 0 -36.83 0 43.64 4 0.492 1.769 1 -0.003 0 4.26 0 43.641 7 0.657 -2.131 1 -0.002 0 10.988 0 49.42 13 0.706 -2.823 1 -0.002 0 19.557 0 52.065 14 0.746 -2.232 1 -0.002 0 18.976 0 51.85 17 0.664 -2.148 1 -0.002 0 13.687 0 49.578 18 0.784 -0.637 1 -0.001 0 13.539 0 47.664 19 0.842 -0.434 1 -0.001 0 13.232 0 47.664 20 0.806 -1.574 1 -0.001 0 19.265 0 51.85 27 0.706 +=-2.823 1 -0.002 0 19.389 0 52.065 28 0.664 -2.148 1 -0.002 0 13.661 0 49.578 BUS 2 3 PHASE E/Z= 4.405 KA ( 105.295 MVA)@ -88.498 DEG KV= 13.8 GND FAULT = 0.002 KA ( 0.043 MVA)@ -43.148 DEG 2-POS= 0.024898 +J 0.949383 Z-ZERO= 5038.84 +J 4721.34 CONTRIBUTIONS ----3 PH FAULT---- BUS TO BUS 3 PH KA MAG ANGLE 3-10 KA MAG ANGLE POS KA MAG 4 2 2.314 -87.658 0.001 -84.306 0 ° 2 2.092 -89.427 0.001 -0.011 1.383 PU VOLTS --- 3 PH ---- 9 -=---------- L-G FAULT ----------------- BUS MAG ANGLE POS ANGLE ZERO ANGLE NEG ANGLE 2 0.0 0.0 1 -0.006 -1 -0.011 0 45.35 1 0.648 0.929 1 -0.002 0 -36.898 0 43.64 3 0.648 0.929 1 -0.002 0 -36.998 0 43.64 4 0.492 1.769 1 -0.003 0 4.26 0 43.641 7 0.657 -2.131 1 -0.002 0 10.977 0 49.42 13. 0.706 -2.823 1 -0.002 0 19.884 0 52.045 14 0.746 -2.232 1 -0.002 0 19.155 0 51.85 17 0.664 -2.148 1 -0.002 0 13.704 0 49.578 18 0.784 -0.637 1 -0.001 o 13.503 0 47.664 19 0.842 -0.434 1 -0,001 oO 14.01 0 47.664 20 0.806 -1.574 1 -0.001 0 19.636 0 51.85 - 2 - CASE APA&9Z92 19.553 ar 0.706 -2.823 1 -0.002 ° ° 52.065 28 0.664 -2.148 1 -0.002 ° 13.774 0 49.578 BUS 3 3 PHASE E/Z= 4.405 KA ( 105.295 MVA)@ -88.498 DEG KV= 13.8 GND FAULT = 0.002 KA ( 0.043 MVA)@ -43.148 DEG Z-POS= 0.024898 +J 0.949383 Z-ZERO= 5038.84 +J 4721.34 CONTRIBUTIONS ----3 PH FAULT---- 9 ----~------- L-G FAULT~----- BUS TO BUS 3 PH KA MAG ANGLE 3-10 KA MAG ANGLE POS KA MAG 4 3 2.314 -87.658 0.001 -84.306 ° ° “3 2.092 -89.427 0.001 -0.011 1.383 PU VOLTS -——- 3 PH ---- 9 9 -----—-----—- 0 (AS BUS MAG ANGLE POS ANGLE ZERO ANGLE NEG ANGLE 3 0.0 0.0 1 -0.006 =f -0.011 ° 45.35 1 0.648 0.929 1 -0.002 ° -36.901 0 43.64 2 0.648 0.929 1 -0.002 ° -36.901 0 43.64 4 0.492 1.769 i. -0.003 ° 4.279 ° 43.641 7 0.657 -2.131 1 -0.002 ° 11.094 0 49.42 13 0.706 -2.823 1 -0.002 oO 19.965 0 52.065 14 0.746 -2.232 1 -0.002 ° 19.339 0, 51.85 17 0.664 -2.148 1 -0.002 ° 13.877 0 49.578 18 0.784 -0.637 1 -0.001 o 13.892 0 47.664 19 0.842 -0.434 1 -0.001 ° 13.936 0O 47.664 20 0.806 -1.574 1 -0.001 ° 21.828 0 51.85 27 0.706 -2.823 1 -0.002 °o 20.247 0 52.065 28 0.664 -2.148 1 -0. 002 ° 13.788 0 49.578 BUS 4 3 PHASE E/Z= 1.199 KA ( 143.266 MVA)@ -86.789 DEG KV= £9, Tyee Lake GND FAULT = 1.541 KA ( 184.203 MVA)@ -87.043 DEG CA bes Z-POS= 0.039107 +J 0.696907 Z-ZERO= 0.005823 +J 0.232659 CONTRIBUTIONS ----3 PH FAULT~--- = ----------- L-G FAULT BUS TO BUS 3 PH KA MAG ANGLE 3-10 KA MAG ANGLE POS KA MAG 1 4 0.29 -89.427 oO -39.633 0.124 2 4 0.29 -89.427 °o -39.633 0.124 3 4 0.29 -89.427 ° -39.633 0.124 iz 4 0.333 -79.892 0.12 -76.799 0.143 ° 4 ° -84.295 1.423 -87.903 ° PU VOLTS -——- 3 PH ---- ------------ = RAGA === === BUS MAG ANGLE Pos ANGLE ZERO ANGLE NEG ANGLE 4 0.0 0.0 0.571 0.191 0.143 1.524 -0.429 -0.254 1 0.308 °o 0.703 0.107 -0.098 -39.633 -0.297 0.254 2 0.308 °o 0.703 0.107 -0.098 -39.633 -0.297 -0.254 3 0.308 oO 0.703 0.107 -0.098 -39.633 -0.297 -0.254 7 0.334 -11.771 0.712 -2.247 -0.026 8.3 -0.29 3.525 13 0.431 -11.459 0.753 -2.708 0.003 17.1 -0.25 8.17 14 0.506 -3.176 0.787 -2.179 -0.003 16.587 -0.216 7.9SE a? 0.347 -11.4 0.718 -2.248 -0.018 11.054 -0.284 5.684 18 0.578 -2.953 0.819 -0.836 -0.003 11.054 -0,182 3.77 19 0.691 -1.806 0.867 -0.578 0.004 11.056 -0.133 3.77 20 0.622 -5.06 0.837 -1.56 -0.002 16.587 -0.165 7.956 27 0.431 -11.458 0.753 -2.7038 -0.004 16.779 -0.25 8.17 28 0.347 -11.399 0.718 -2.248 -0.023 11.056 -0.284 5.683 BUS 7 3 PHASE E/Z= 0.963 KA ( 115.15 MVA)@ -82.452 DEG Y= 69 Wranaelt GND FAULT = 1.143 KA ( 136.585 MVA)@ -S$2.91 DEG Swichyard Z-POS= 0.111068 +J 0.861299 Z-ZERO= 0.048994 +J 0.457033 ANGLE -89.681 -89.681 -89. 681 -80.146 -85.41 - 3 - CONTRIBUTIONS ----3 PH FAULT---- BUS TO BUS 3 PH KA MAG ANGLE 4 7 0.473 -79.52 13 7 0.238 -85.427 17 7 0.254 -85.882 PU VOLTS --- 3 PH ---- --- BUS MAG ANGLE Pos 7 0.0 0.0 0.605 1 0.632 -5.883 0.854 2 0.632 -5.883 0.854 3 0.632 -5.883 0.854 4 0.474 -11.4 0.789 13. 0.143 -16.148 0.659 14 0.257 -7.043 0.706 17 0.02 -7.866 0.612 18 0.374 2.944 0.752 19 0.542 1.486 0.819 20 0.433 -3.184 0.776 27 (0.143 -16.144 0.659 28 0.02 -7.849 0.612 BUS 12, 3 PHASE E/Z= 0.781 KA Paterbu GND FAULT = 0.952 KA sursd. ea Z-POS= 0.158199 +J 1.06014 CONTRIBUTIONS ----3 PH FAULT~--- BUS TO BUS 3 PH KA MAG ANGLE 7 13 0.508 -77.967 27 13 0.275 -88.074 PU VOLTS --- 3 PH ---- BUS MAG ANGLE 13 0.0 0.0 1 0.747 -4.791 2 0.747 -4.791 3 0.747 -4.791 4 0.637 -8.133 7 0.305 -8.688 14 0.137 1.352 17 0.319 -8.485 18 0.562 -1.58 19 0.679 -0.956 20 0.342 0.413 27 0 1.353 28 0.319 -8.484 BUS 14 3 PHASE E/Z= 2.007 KA Pederiours GND FAULT = 2.683 KA Sue WNW = Z-POS= 0.126684 +I 1.14835 CONTRIBUTIONS ----3 PH FAULT---- BUS TO BUS 3 PH KA MAG ANGLE 20 14 0.752 -89.427 27 14 1.128 -80.275 ° 14 0.133 -78.976 PU VOLTS --- 3 PH ---- 9 --------- BUS MAG ANGLE POS CASE APA69Z92 0.187 0.094 0.101 ANGLE -0.257 9.658 9.658 9.658 9.658 2.386 2.171 -0.099 -2.013 -2.013 2.171 2.386 Scerenaramnaecsnieeltal L-G FAULT-- 3-10 KA MAG ANGLE POS KA MAG 0.195 -76.992 0.236 -79.363 0.714 -85.699 L-G FAULT --- ZERO ANGLI NEG -0.209 0.972 -0.395 -0.013 -28.725 -0.149 -0.013 -28.725 -0.149 -0.013 -28.725 -0.149 -0.02 12.433 -0.215 -0.06 9.773 -0.341 -0.025 9.259 -0.295 -0.146 3.728 -0.388 -0.064 3.728 -0.248 -0.032 3.728 -0.131 -0.013 9.259 -0.225 -0.028 9.451 -0.341 -0.179 3.728 -0.388 -0.099 ( 93.294 MVA)@ -81.513 DEG KY= 69. ( 113.824 MVAD@ -82.509 DEG Z-ZERO= 0.027236 +J 0.492879 Gasmuauianmamnmieian L-G FAULT 3-10 KA MAG ANGLE POS KA MAG 0.216 -74.63 0.207 0.739 -84.807 0.112 Se OS ZERO ANGLE NEG ANGLE -0.187 4.329 -0.407 -0.996 -0.003 -19.523 -0.107 12.704 -0.003 -19.523 -0.107 12.704 -0.003 -19.523 -0.107 12.704 -0.005 21.634 -0.155 12.704 -0.05 10.173 -0.284 2.786 -0.078 3.815 -0O.351 -1.211 -0.035 12.929 -0.279 2.943 -0.015 12.929 -0.173 1.029 -0.008 12.929 -0.13 1.029 -0.039 3.815 -0.268 -1.211 -0.089 4.007 -0.407 -0.996 -0.043 12.929 -0.279 2.943 ( 86.539 MVA)@ -83.606 DEG KV= 24,9 ( 115.719 MVA)@ -84.08 DEG Z-ZERO= 0.010028 +J 0.281952 ----------- L-G FAULT 3-10 KA MAG = ANGLE POS KA MAG o -80.412 0,335 1.43 -84.186 0.503 1.253 -83.96 0.062 --- L-G FAULT ----------------- 7EReN Ancr e& are awe -85.684 -86.14 ANGLE -78.963 -89.07 PH A 0.485 0.47 PH B 0.135 0.135 0.135 0.135 -0.474 10.918 10.918 10.918 10.918 1 -2.782 1.157 -0.757 -0.757 -0.474 -2.781 1.157 0.278 0.107 iS KA MAG 0.702 0.798 0.421 oo OL - 4 - CASE APA69Z92 14 0.0 0.0 0.554 0.381 -0.109 3.883 -0.446 1 0.794 -3.005 0.908 -1.123 -0.001 -21.608 -0.094 2 0.794 -3.005 0.908 -1.123 -0.001 -21.608 -0.094 3 0.794 -3.005 0.908 ~-1.123 -0.001 -21.608 -0.094 4 0.704 -4.901 0.867 ~-1.699 -0.002 19.549 -0,136 a 0.44 -1.874 0.75 -0.333 -0.021 8.088 -0.25 13 0.203 9.151 0.644 1.541 -0.08 2.244 -0.357 17 0.451 -1.983 0.755 -0.375 -0.015 10.844 -0.245 18 0.649 0.153 0.844 0.14 -0.007 10.844 -0.156 a2 0.743 0.098 0.886 0.098 -0.003 10.844 -0.114 20 0.238 O° 0.66 0.244 -0.054 3.883 -0.34 27 0.203 9.152 0.644 1.541 -0.092 3.63 -0. 357 28 0.451 -1.983 0.755 -0.375 -0.018 10.844 -0.245 ~BWS_1Z, 3 PHASE E/Z= 0.931 KA ( 111.322 MVA)@ -82.629 DEG _KV= 42. Wranae\\ GND FAULT = 1.154 KA ( 137.902 MVA)@ -83.358 DEG Seat. CI Z-POS= 0.115253 +J 0.890869 Z-ZERO= 0.021139 +J 0.37912 CONTRIBUTIONS ----3 PH FAULT---- = ----------- L-G FAULT BUS TO BUS 3 PH KA MAG ANGLE 3-10 KA MAG Z 17 0.673 -81.313 0.304 -75.981 28 17 0.26 -86.041 0.854 -85.976 PU VOLTS --- 3 PH ---- 00 ------------ L-G FALLT -—----——---<----——— BUS MAG ANGLE POS ANGLE ZERO ANGLE NEG 17 0.0 0.0 0.587 0.513 -0.175 3.451 -0.413 1 0.652 -5.508 0.855 -1.608 -0.009 -26.417 -0.147 2 0.652 -5.508 0.855 -1.608 -0.009 -26.417 -0.147 3 0.652 -5.508 0.855 -1.608 -0.009 -26.417 -0.147 4 0.501 -10.395 0.791 -2.511 -0.014 14.741 -0.213 Zz 0.052 -3.296 0.609 0.352 -0.147 3.28 0.391 13 0.187 -12.445 0.662 -1.068 -0.042 12.08 -0.338 14 0.296 -6.228 0.709 -0.773 -0.018 11.567 -0.292 18 0.362 3.385 0.736 0.947 -0.077° 3.451 -0.264 19 0.533 1.681 0.807 0.632 -0.039 3.451 -0.193 20 0.463 -3.036 0.778 -0.537 -0.009 11.567 -0.222 27 0.187 -12.45 0.662 -1.069 -0.02 11.759 -0.338 28 ° 3.387 0.587 0.513 0.214 3.451 -0.413 BUS 13. 3 PHASE E/Z= 4.159 KA ( 90.052 MVA)@ -84.642 DEG = \ GND FAULT = 5.181 KA ( 112.18 MVA)@ -85.382 DEG Bubs. 12.6 KV Z-POS= 0.103695 +J 1.10562 Z-ZERO= 0.007929 +J 0.454364 CONTRIBUTIONS ----3 PH FAULT---- 9 ----------- L-G FAULT BUS TO BUS 3 PH KA MAG ANGLE 3-10 KA MAG ANGLE PO: 19 18 1.69 -89.427 °o -80.676 28 18 1.921 -85.241 1.404 -84,234 ° 18 0.578 -68.454 3.777 -85.809 PU VOLTS --- 3 PH ---- 0 ------------ L-G FAULT ----------------- BUS MAG ANGLE Pos ANGLE ZERO ANGLE NEG 18 0.0 0.0 0.585 0.525 -0.17 3.618 -0.415 1 0.817 -1.392 0.924 -0.45 -0.003 -28.441 -0.077 2 0.817) -1.392 0.924 -0.45 -0.003 -28.441 -0.077 3 0.817 -1.392 0.924 -0.45 -0.003 -28.441 -0.077 4 0.736 -2.232 0.89 -0.674 -0,005 12.716 -O.111 Z 0.512 3.587 0.797 1.144 -0.053 1.257 -0.204 13 0.577 0.381 0.824 0.393 -0.015 10.056 -0.176 14 0.635 0.759 0.84% 0.368 -0.006 9.582 -0 159 ANGLE -82.042 -86.77 ANGLE -90.167 -85.981 -69.621 PHA 0.656 0.499 1.403 2.063 3.777 PH B 0.177 0.177 ANGLE POS KA MAG PH C 0.177 0.177 GND FAULT =- -5- 124.334 MVAe -82 7-PNS= 0.158192 +4 1 NANT CASE APAS69Z92 +223 DEG T-TERN= AN ANDMONL 410 ANGLE -81.037 -86.611 PH A 0.007 0.007 -G FAULT~------------------------------------=: ‘—------ 17 0.485 4.186 0.786 1.274 -0.063 1.428 -0.215 -4.667 19 0.268 0 0.696 0.323 -0.085 3.618 -0.304 -0.74 20 0.722 0.509 0.884 0.269 -0.003 9.542 -0.116 -2.058 27 0.577 «0.81 0.824 0.393 -0.007 9.734 -0.176 1.644 28 0.485 4.187 0.786 1.274 -0.058 0.555 -0.215 -4.667 _BUS 12. 3 PHASE E/Z= 21.285 KA ( 88.483 MVA)@ -86.912 DEG _KV= 2.4 Wranogit GND FAULT = 0.014 KA ( 0.06 MVA)@ -84.296 DEG diexel . Z-POS= 0.060885 +J 1.12852 Z-ZERO= 499.502 +J 4999.61 CONTRIBUTIONS ----3 PH FAULT~--- ----------- L-G FAULT BUS TO BUS 3 PH KA MAG ANGLE 3-10 KA MAG ANGLE POS KA MAG 18 19 9.284 -83.653 0.007 -84.296 0.002 0 19 12.027 -89.427 0.007 “84.296 . 6.014 PU VOLTS --- 3 PH ---- 9 ------------ L-G FAULT ----------------- BUS MAG ANGLE POS — ANGLE ZERO ANGLE NEG ANGLE 19 0.0 0.0 1 -0.001 -1 -0.001 0 2.616 1 0.868 -0.596 1 ° ° -27.622 0 6.516 2 0.868 -0.596 1 ° ° -27.622 0 6.516 3 0,868 -0.596 1 ° ° -27.622 0 6.516 4 0.809 -0.923 1 0 ° 13.64 0 6.516 7 0.651 3.254 1 0 ° 2.347 0 -3.398 13 0.696 1.474 1 0 oO 11.128 0 -0.758 14 0.738 1.276 1 0 oO 10.648 0 -0.973 17 0.632 3.643 1 0 0 2.496 0 -3.58 18 0.283 5.774 1 0 ° 4.701 0 0.346 20 0.8 0.897 1 0 ° 11.033 0 -0.972 27 0.696 =1.473 1 ° oO 10.88 0 -0.758 28 0.632 3.644 1 ° 0 1.656 0 -3.58 Bus 20, 3 PHASE E/Z= 19.58 KA ( 81.396 MVA)@ -86.25 DEG KV= 2.4 Peterstoors, GND FAULT = 0.014 KA ( 0.06 MVA)@ -84.296 DEG diesel gener. Z-POS= 0.080355 +J 1.22594 Z-ZERO= 499.503 +J 4999.57 CONTRIBUTIONS ----3 PH FAULT---- ----------- BUS TO BUS 3 PH KA MAG ANGLE 3-10 KA MAG ANGLE POS KA MAG 14 20 9.377 -82.782 0.007 -84.296 0.002 ° 20 10.236 -89.427 0.007 -84.296 5.118 PU VOLTS --- 3 PH ---- 9 ------------ L-G FAULT ----------------- BUS MAG ANGLE POS ANGLE ZERO ANGLE NEG ANGLE 20 0.0 0.0 1 0 -1 -0.001 0 1.954 1 0.851 -1.548 1 0 0 -21.1 0 10.702 2 0.851 -1.548 1 0 ° -21.1 0 10.702 3 0.851 -1.548 1 ° 0 -21.1 0 10.702 4 0.785 -2.424 1 -0.001 0 19.654 0 10.702 7 0.599 0.7384 1 ° 0 7.937 0 0.785 13 0.431 «6.599 1 ° 0 2.059 0 -2.997 14 0.286 6.645 1 ° 0 3.684 0 -0.689 17 0.606 0.656 1 ° ° 10.658 0 0.943 18 0.749 0.983 1 0 0 11.039 0 -0.972 19 0.816 0.66 1 0 0 10.704 0 -0.972 27 «0.431 6.599 1 ° 0 3.444 0 -2.996 28 0.606 0.658 1 oO 0 10.736 0 0.941 BUS 27 3 PHASE E/Z= 93.292 MVA@ -81.514 DEG OTD AL ANGLE -80.827 -87.473 0.007 0.007 6 - CASE APA69Z92 CONTRIBUTIONS ----3 PH FAULT---- ----------- L-G FAULT BUS TO BUS 3 PH MVA MAG ANGLE 3-10 MVA MAG ANGLE POS MVA MAG ANGLE 13 27 60.717 -77.965 13.434 -74.671 26.974 -78.68 14 27 32.877 -88.074 48.938 -82.361 14.606 -88.789 ° 27 0.01 -84.295 62.102 -83.754 0.005 -86.535 PU VOLTS --- 3 PH ---- — ------------ L-G FAULT ---- BUS MAG ANGLE POS ANGLE ZERO ANGLE NEG ANGLE 27.0.0 0.0 0.556 0.571 -0.112 5.674 -0.444 -0.715 1 0.747 -4.791 0.886 -1.699 -0.002 -19.564 -0.117 12.985 2 0.747 -4.791 0.886 -1.699 -0.002 -19.564 -0.117 12.985 3 0.747 -4.791 0.886 -1.699 -0.002 -19.564 -0.117 12.985 4 0.637 -8.131 0.836 -2.602 -0.002 21.593 -0.169 12.985 7 0.306 + -8.685 0.69 -1.381 -0.026 10.132 -0.311 3.067 13 0 11.462 0.556 0.572 -0.097 4.288 -0.444 -0.715 14 0.137 1.353 0.617 0.578 -0.099 5.481 -0.383 -0.93 17 0.319 -8.486 0,696 -1.411 -0.018 12.898 -0.305 3.225 18 0.562 -1.58 0.805 -0.317 -0.008 12.988 -0.195 1.31 19 0.679 -0.956 0.858 -0.218 -0.004 12.888 -0.143 1.31 20 0.342 0.413 0.708 0.384 -0.049 5.481 -0.292 -0.93 28 0.319 -8.481 0.696 -1.41 -0.022 12.888 -0.305 3.223 BUS 28 3 PHASE E/Z= 111.317 MVA@ -82.4629 DEG GND FAULT = 134.83 MVA@ -83.266 DEG Z-POS= 0.115251 +J 0.890914 | Z-ZERO= 0.030403 +J 0.427843 CONTRIBUTIONS ----3 PH FAULT---- ----------- L-G FAULT BUS TO BUS 3 PH MVA MAG ANGLE 3-10 MVA MAG ANGLE POS MVA MAG ANGLE 17 28 80.411 81.315 43.552 -75.89 32.465 -81.953 18 28 30.99 -86.041 33.397 -86.758 12.512 -86.678 ° 28 0.01 -84.295 58.413 -86.758 0.004 -88.424 PU VOLTS --- 3 PH ---- — ------------ L-G FAULT ----------------- BUS MAG = ANGLE POS ANGLE ZERO ANGLE NEG ANGLE 28 «(0.0 0.0 0.596 0.431 -0.193 2.669 -0.404 -0.637 1 0.652 -5.507 0.858 -1.581 -0.011 -26.325 -0.144 9.46 2 0.652 -5.507 0.858 -1.581 -0.011 -26.325 -0.144 9.46 3 0.652 -5.507 0.858 -1.581 -0.011 -26.325 -0.144 9.46 4 0.501 -10.392 0.795 -2.464 -0.017 14.832 -0.208 9.46 7 0.052 -3.28 0.617 0.283 -0.177 3.371 -0.383 -0.456 13° 0.187 -12.437 0.67 -1.077. -0.051 12.172 -0.33 2.185 14 0.296 -6.225 0.715 -0.785 -0.021 11.658 -0.285 1.97 17 0 8.111 0.596 0.432 -0.209 3.543 -0.404 -0.638 18 0.362 3.387 0.742 0.887 -0.069 2.669 -0.258 -2.551 19 0.533 1.681 0.811 0.594 -0.035 2.669 -0.189 -2.551 20 0.463 -3.032 0.783 -0.547 -0.011 11.658 -0.217 1.97 27. (0.187 -12.435 0.67 -1.077 -0.024 11.85 -0.33 2.185 62.102 PH A 79.381 36.156 58.413 PH B 18.094 1.38 ° PH C 18.094 1.38 ° - 1 - CASE APAGé97Z91 GENERAL ELECTRIC CO INDUSTRIAL POWER SYSTEMS ENGINEERING OPERATION SO BUS THREE PHASE & SINGLE PHASE SHORT CIRCUIT PROGRAM CASE APA69Z91 09/08/82 BASE MVA = 100 ALASKA POWER AUTHORITY ANCHORAGE, ALASKA + V4 9/7/82) 3 PHASE E/Z= 4.441 KA ( 106.15 MVA)@ -88.452 DEG KV= 13,8 Tyee Lave GND FAULT = 0.002 KA ( 0.043 MVA)@ -43.148 DEG . Z-POS= 0.025457 +J 0.941721 Z-ZERO= 5038.84 +J 4721.34 CONTRIBUTIONS ----3 PH FAULT---- 9 -------~--- L-G FAULT~- aa BUS TO BUS 3 PH KA MAG ANGLE 3-10 KA MAG ANGLE POS KA MAG ANGLE PH A 4 1 2.35 -87.584 0.001 -84.306 ° -42.28 0.001 ° ° ° 1 2.092 -89.427 0.001 -0.011 1.383 -0.987 0.001 ° ° PU VOLTs —— 3 Fh —— E=G JEAULT ]=e=s— aaa BUS MAG ANGLE Pos ANGLE ZERO ANGLE NEG ANGLE az 0.0 0.0 Z -0.006 il -0.011 ° 45.304 2 0.653 0.976 1 -0.002 ° -36.88 ce) 43.468 3 0.653 0.976 1 -0.002 ° -36.88 ° 43.468 4 0.499 1.843 1 -0.003 ° 4.26 ° 43.468 7 0.676 -2.246 1 -0.002 ° 10.969 O 49.971 13 0.722 -2.841 1 -0.002 ° 19.441 0 52.617 14 0.76 -2.261 1 -0.002 ° 18.976 0O 52.402 17 0.681 -2.28 1 -0.002 ° 13.687 0 S0.157 18 0.777 -1.401 1 -0.001 ° 13.539 0 50.156 19 0.836 -0.952 1 -0.001 ° 13.233 0 50.156 20 0.817 -1.603 1 -0.001 ° 19.265 0 52.402 21 0.757 -0.748 1 -0.001 ° 20.456 0 47.639 27 0.722 -2.841 1 -0.002 ° 19.389 0 52.617 28 0.681 -2.28 1 -0.002 ° 13.633 0 50.157 BUS 2 3 PHASE E/Z= 4.441 KA ( 106.15 MVA)@ -88.452 DEG KV= 13.8 GND FAULT = 0.002 KA ( 0.043 MVA)@ -43.148 DEG Z-POS= 0.025457 +J 0.941721 Z-ZERO= 5038.84 +J 4721.34 CONTRIBUTIONS ----3 PH FAULT---- = ----------- 6 ae BUS TO BUS 3 PH KA MAG) ANGLE 3-10 KA MAG ANGLE POS KA MAG ANGLE PH A PH B PH C 4 2 2.35 -87.584 0.001 -84. 306 ° -42.28 0.001 ° ° ° 2 2.092 -89.427 0.001 -0.011 1.383 -0.987 0.001 ° oO PU VOLTS --- 3 PH <--— 00 sane oe BUS MAG ANGLE PUS ANGLE ZERO ANGLE NEG ANGLE 2 0.0 0.0 1 -0,006 <a -0.011 o 45.304 1 0.653 0.976 1 -0.002 ° -36.898 0 43.468 3 0.653 0.976 1 -0.002 ° -36.898 0 43.463 4 0.499 1.843 a -0.003 ° 4.261 ° 43.468 7 0.676 -2.246 1 -0.002 0 10.996 0 49.971 13 0.722 -2.841 i -0.002 ° 20.004 0 52.617 14 0.76 -2.2461 1 -0,002 0 19.432 0 52.402 17 0.681 -2.28 1 -0,002 0 13.738 0 50.157 18 0.777 ~-1.401 1 -0.001 oO 13.578 0 50.156 19 =0.836 -0.952 1 -0.001 Qo 14.01 o 50.156 - 2 - CASE APAG69Z91 20 0.817 -1.603 1 -0.001 oO 20.219 O 52.402 21 0.757 -0.748 1 -0.001 ° -14.387 0 47.639 27 0.722 -2.841 1 -0.002 ° 19.553 0 52.617 28 40.681 -2.28 1 -0.002 ° 13.801 0 50.157 BUS 3 3 PHASE E/Z= 4.441 KA ( 106.15 MVA)@ -88.452 DEG KV= 13.8 GND FAULT = 0.002 KA ( 0.043 MVA)@ -43.148 DEG Z-POS= 0.025457 +J 0.941721 Z-ZERO= 5038.84 +J 4721.34 CONTRISUT IONS | (<-——3' PH Fa OS L-G FAULT BUS TO BUS 3 PH KA MAG ANGLE 3-10 KA MAG ANGLE POS KA MAG 4 3 2.35 -87.584 0.001 -84.306 oO ° 3 2.092 -89.427 0.001 -0.011 1.383 PU VOLTS -—- 3 PH -——- = RO OU rs BUS MAG ANGLE POS ANGLE ZERO ANGLE NEG ANGLE 3 0.0 0.0 1 -0.006 —- -0.011 ° 45.304 1 0.653 0.976 1 -0.002 ° -36.901 0 43.468 2 0.653 0.976 1 -0.002 ° -36.901 0 43.463 4 0.499 1.843 1 -0.003 ° 4.278 ° 43.468 a 0.476 -2.246 1 -0.002 ° 11.094 0O 49.971 13. 0.722 -2.841 1 -0.002 ° 19.965 0 52.617 14 0.76 -2.261 1 -0.002 0 19.063 0 + 52.402 17 0.681 -2.28 1 -0.002 0 13.843 0 50.157 18 0.777 -1.401 1 -0.001 ° 13.893 0 50.156 19 0.836 -0.952 1 -0.001 oO 13.936 0 S50. 156 20 0.817 -1.603 1 -0.001 ° 21.208 0 52.402 21 0.757 -0.748 1 -0.001 ° 89.989 O 47.639 27 0.722 -2.841 1 -0.002 ° 20.247 0 52.617 28 0.681 -2.28 1 -0.002 ° 13.788 O 50.157 BUS 4 3 PHASE E/Z= 1.227 KA ( 146.603 MVA)@ -86.616 DEG KYV= 69. Tyee Lake GND FAULT = 1.572 KA ( 187.871 MVA)@ -86.9 DEG cr bes Z-POS= 0.040273 +J 0.680923 Z-ZERO= 0.005823 +J 0.232659 CONTRIBUTIONS ----3 PH FAULT---- 3 BUS TO BUS 3 PH KA MAG ANGLE 3-10 KA MAG ANGLE POS KA MAG 1 4 0.29 -89.427 ° 39.491 0.124 2 4 0.29 -89.427 ° -39.491 0.124 3 4 0.29 -89.427 0 -39.491 0.124 7 4 0.361 -79.84 0.122 -76.656 0.154 ° 4 ° -84.295 1.452 -87.761 ° CU VOCTS) e-= 16 (PH ieee) ||) | panne C=C) EAS jaan een BUS MAG ANGLE POS ANGLE ZERO = =ANGLE NEG ANGLE 4 0.0 0.0 0.573 0.212 0.146 1.667 -0.427 -0.284 1 0.308 Oo 0.704 0.119 -0.1 -39.491 -0.296 -0.284 2 0.308 O 0.704 0.119 -O.1 -39.491 -0.296 -0.284 3 0.308 #O 0.704 0.119 -0.1 -39.491 -0.296 -0.284 uy 0.362 -11.72 0.725 -2.377 -0.027 8.443 -0.277 6.219 13° 0.455 -11.299 0.764 -2.769 -0.008 17.243 -0.24 8.865 14 0.527 -8.196 0.796 -2.238 -0.003 16.73 -0.207 8.65 17 0.373 -11.52 0.729 -2.393 0.019 11.199 -0.273 6.405 18 0.558 -5.368 0.81 -1.509 -0.008 11.198 -0.191 6.404 19 0.676 -3.239 0.861 -1.039 -0.004 11.198 -0.14 6.404 20 40.638 -5.151 0.845 -1.608 -0.002 16.73 -0.158 8.65 21 0.518 -3.9 0.794 -1.013 ° 13.572 -0.207 3.887 27 0.455 -11.298 0.764 -2.769 -0.004 16.922 -0.24 8.365 28 0.373 -11.519 0.729 -2.393 -0.023 11.199 -0.273 6.405 PH A 0.247 0.247 0.247 0.349 1.452 RUS 7, 3 PHASE E/Z= 1.027 KA ( 122.724 MVA)@ -83.203 DEG KY= 69 Ww M GND FAULT = 1.201 KA ( 143.591 MVA)@ -83.352 DEG owl 3 Z-POS= 0.096448 +J 0.809105 Z-ZERO= 0.048992 +J 0.457012 CONTRIBUTIONS ----3 PH FAULT---- = ----------- LO FAULT nn nn rrr nnn nnn nna = BUS TO BUS 3 PH KA MAG ANGLE 3-10 KA MAG ANGLE POS KA MAG) ANGLE PH A PH B PH C 4 7 0.473 -79.521 0.205 -77.435 0.184 -79.67 0.437 0.116 0.116 13 Of 0.238 -85.427 0.248 -79.805 0.093 -85.576 0.268 0.013 0.013 17 7 0.211 -89.235 0.75 -86.142 0.082 -89.384 0.415 0.1468 0.168 21 7 0.107 -82.637 °o ~83.766 0.042 -82.786 0.084 0.042 0.042 PU VOLTS —<- 3 PH ——— L-G FAULT ----------------- Bus MAG ANGLE Pos ANGLE ZERO ANGLE NEG ANGLE 7 0.0 0.0 0.61 0.096 -0.22 0.53 -0.39 -0.149 1 0.632 -5.883 0.856 -1.668 -0.014 -29.167 -0.147 9.767 2 0.632 -5.883 0.856 -1.668 -0.014 -29.167 -0.147 9.767 3 0.632 -5.883 0.856 -1.668 -0.014 -29.167 -0.147 9.767 4 0.474 ~-11.401 0.792 -2.604 -0.021 11.99 -0.212 9.767 13 0.143 16.148 0.664 ~-1.265 -0.063 9.33 -0.337 2.494 14 0.258 -7.044 0.71 -0.933 -0.026 8.817 -0.291 2.28 17 0.016 -11.219 0.616 -0.023 -0.153 3.286 -0.384 0.037 18 0.311 -0.412 0.731 -0.013 -0.068 3.285 -0.269 0.036 19 0.495 -0.189 0.803 -0.009 -0.034 3.285 -0.197 0.036 20 0.433 -3.185 0.779 -0.648 -0.013 8.817 -0.222 2.28 21 0.257 6.791 0.71 1.017 ° 5.659 -0.291 -2.481 ae 0.143 -16.144 0.664 -1.265 -0.03 9.009 -0.337 2.494 28 0.016 -11.201 0.616 ~-0.023 -0.188 3.286 -0.384 0.037 3 PHASE E/Z= 0.811 KA ( 96.953 MVA)@ -81.587 DEG .KV= 62, t GND FAULT = 0.983 KA ( 117.426 MVA)@ -82.6 DEG Sued 64 Z-POS= 0.150914 +J 1.02032 Z-ZERO= 0.027237 +J 0.492877 CONTRIBUTIONS ----3 PH FAULT---- - - BUS TO BUS 3-PH KA MAG ANGLE 3-10 KA MAG ANGLE POS KA MAG ANGLE PHA PH B PH C 7 13 0.538 -78.28 0.223 -74.721 0.217 -79.293 0.509 0.143 0.143 27 13 0.275 -88.07 0.762 -84.898 0.111 -89.083 0.476 0.144 0.144 PU VOLTS --- 3 PH ---- — ------------ L-G FAULT ----------------- BUS MAG ANGLE POS ANGLE ZERO ANGLE NEG ANGLE 13.0.0 0.0 0.596 0.686 -0.193 4.237 -0.404 -1.013 1 0.754 -4.787 0.899 ~-1.504 -0.003 -19.614 -0.104 13.165 2 0.754 -4.787 0.899 -1.504 -0.003 -19.614 -0.104 13.165 3 0.754 -4.787 0.899 -1.504 -0.003 -19.614 -0.104 13.165 4 0.647 -8.074 0.855 -2.286 -0.005 21.543 -0.15 13.165 7 0.324 -9.001 0.725 -1.232 -0.051 10.082 -0.275 3.246 14 0.137 1.352 0.652 0.656 -0.081 3.724 -0.348 -1.228 17 0.335 -8.928 0.73 -1.273 -0.036 12.838 -0.271 3.43 18 0.532 -3.924 0.811 -0.803 -0.016 12.838 -0.19 3.429 19 0.657 -2.324 0.861 -0.553 -0.008 12.838 -0.139 3.429 20 0.342 0.413 0.735 0.444 -0.04 3.724 -0.266 ~-1.228 21 0.492 -1.991 0.795 -0.236 ° 15.211 -0.205 0.912 27 ° 1.357 0.596 0.686 -0.092 3.916 -0.404 ~-1.013 28 40.335 -8.928 0.73 -1.273 -0.044 12.838 -0.271 3.43 BUS 14, 3 PHASE E/Z= 2.06 KA ( 88.85 MVA)@ -83.724 DEG y= 24.2 Petersburg GND FAULT = 2.747 KA ( 118.464 MVA)@ -84.196 DEG Sulwh. daa Z-POS= 0.123034 +J 1.11874 Z-ZERQ= 0.010026 +I 0, 281952 CONTRIBUTIONS ----3 PH FAULT---- ----------- L-G FAULT-------------------------------------------- - 4 - CASE APA69Z91 BUS TO BUS 3PH KA MAG ANGLE 3-10 KA MAG ANGLE POS KA MAG 20 14 0.752 -89.427. 0 -80.528 0.334 27 14 1.181 -80.631 1.464 -84.302 0.525 0 14 0.133 -78.976 1.283 -84.076 0.062 PU VOLTS --- 3 PH ---- — ----~-~----- L-G FAULT ----------------- BUS MAG ANGLE POS — ANGLE ZERO ANGLE NEG ANGLE 14-040 0.0 0.556 0.377 -0.111 3.767 -0.444 -0.472 1 0.802 -2.973 0.912 -1.117 -0.001 -21.724 -0.09 11.354 2 0.802 -2.973 0.912 -1.117 -0.001 -21.724 -0.09 11.354 3 0.802 -2.973 0.912 1.117 -0.001 -21.724 -0.09 11.354 4 0.715 -4.82 0.873 -1.685 -0.002 19.433 -0.13 11.354 7 0.461 -2.231 0.76 -0.453 -0.022 7.972 -0.24 1.435 13° 0.212 8.795 = «0.649 1.529 -0.082 2.128 -0.351 -2.824 17 0.47 -2.361 0.764 -0.5 -0.015 10.728 -0.236 1.619 18 0.628 -1.237 0.835 -0.32 -0.007 10.728 -0.165 1.618 19 0.728 -0.781 0.879 -0.223 -0.003 10.728 -0.121 1.618 20 0.238 «0 0.661 0.242 -0.056 3.767 -0.339 -0.472 21 0.598 0.287 0.821 0.196 0 13.096 -0.179 -0.899 27 (0.212 «8.795 0.649 1.528 -0.094 3.514 -0.352 -2.823 28 40.47 -2.361 0.764 -0.5 -0.019 10.728 -0.236 1.619 BUS 17 3 PHASE E/Z= 0.981 KA ( 117.3 MVA)@ -83.172 DEG Ky= 69° Wrenae\\ GND FAULT = 1.204 KA ( 143.947 MVA)@ -83.834 DEG Crk. 69 Z-POS= 0.101357 +J 0.846468 § Z-ZERO= 0.021139 +J 0.37911 CONTRIBUTIONS ----3 PH FAULT---- ----------- L-G FAULT BUS TO BUS 3PH KA MAG ANGLE 3-10 KA MAG ANGLE POS KA MAG Z 17 0.768 -81.428 0.317 -76.458 0.314 28 17 0.215 -89.42 0.891 -86.453 0.088 PU VOLTS --- 3 PH ---- — --~--------- L-G FAULT ----------------- BUS MAG ANGLE POS = ANGLE ZERO ANGLE NEG ANGLE 170.0 0.0 0.591 0.458 -0.182 2.975 -0.409 -0.662 1 0.654 -5.461 0.857 -1.592 -0.01 -26.893 -0.145 9.47 2 0.654 -5.461 0.857 -1.592 -0.01 -26.893 -0.145 9.47 3 0.654 -5.441 0.857 -1.592 -0.01 -26.893 -0.145 9.47 4 0.505 -10.268 0.794 -2.483 -0.014 14.264 -0.209 9.47 7 0.06 -3.412 0.615 0.279 -0.154 2.803 -0.385 -0.446 13 0.193 -12.084 0.668 -1.091 -0.044 11.604 -0.332 2.196 14 0.302 -6.146 0.714 -0.795 -0.018 11.09 -0.287 1.981 18 0.299 0.001 0.713 0.266 -0.08 2.974 -0.287 -0.662 19 0.487 0 0.79 0.176 +=-0.04 2.974 -0.21 -0. 663 20 0.467 -3.025 0.782 -0.554 -0.009 11.09 -0.218 1.983 21 0.3 4.946 0.714 1.116 0 7.935 -0.287 -2.777 27 0.193 -12.092 0.668 -1.092 -0.021 11.282 -0.332 2.198 28 #20 0.008 0.591 0.458 -0.224 2.974 -0.409 -0.662 3 PHASE E/Z= 3.741 KA ( 80.991 MVA)@ -87.31 DEG KV= 12,5 Weanael\ GND FAULT = 4.739 KA ( 102.411 MVA)@ -87.572 DEG Subst. (2-64 7-POS= 0.057963 +J 1.23334 Z-ZERO= 0.007929 +J 0.454362 CONTRIBUTIONS ----3 PH FAULT---- ----------- L-G FAULT BUS TO BUS 3 PH KA MAG ANGLE 3-10 KA MAG ANGLE POS KA MAG 19 18 1.69 -89.427 0 -82.867 0.714 28 18 2.053 -85.567 1.284 86.424 0.867 ° 18 0 84.295 3.455 -87.999 0 PU VOLTS --- 3 PH ---- ------------ L-G FAULT ----------------- ANGLE -89.899 -81.103 -79.327 ANGLE -82.09 -90.082 PH A 0.668 1.537 1.283 PH A 0.734 0.473 PH B 0.334 0.046 ° PH B 0.209 0.209 PH C 0.334 0.046 PH C 0.209" 0.209 - 5 - CASE APA69Z91 BUS MAG ANGLE POS ANGLE ZERO ANGLE NEG ANGLE 18 0.0 0.0 0.578 0.192 -0.155 1.428 -0.422 -0.263 1 0.83 -1.2385 0.928 -0.446 -0,003 -30.631 -0.072 5.732 2 0.83 -1.235 0.928 -0.446 -0.003 -30.631 -0,072 5.732 3 0.83 -1.235 0.928 -0.446 -0.003 -30.4631 -0.072 5.732 4 0.754 -1.963 0.896 -0.667 -0.005 10.526 -0.104 5.732 7 0.547 3.261 0.808 0.993 -0.048 -0.933 -0.192 -4.183 13. 0.607 0.828 0.834 0.307 -0.014 7.866 -0.166 -1.543 14 0.661 0.767 0.857. 0.294 «= -0,006 7.352 -0.143 -1.758 17 0.519 3.86 0.796 1.128 -0.057 -0.762 -0.204 -4.4 19 0.268 0 0.691 0.118 -0.078 1.428 -0.309 -0.263 20 0.742 «0.52 0.891 0.215 -0.003 7.352 -0.109 -1.755 21 0.664 3.192 0.858 1.086 0 4.19 -0.143 -6.515 27 0.607 0.826 0.834 0.306 -0,007 7.544 -0.166 -1.541 28 «(0.519 «= 3.86 0.796 1.128 -0.053 -1.636 -0.204 -4.399 3 PHASE E/Z= 20.089 KA ( 83.51 MVA)@ -88.258 DEG KV= 2.4 Wrange\\ GND FAULT = 0.014 KA ( 0.06 MVA)@ -84.297 DEG diese) gener. Z-POS= 0.0364 +J 1.19691 Z-ZERO= 499.502 +J 4999.61 CONTRIBUTIONS ----3 PH FAULT---- 9 ----------- L-G FAULT BUS TO BUS 3PH KA MAG ANGLE 3-10 KA MAG ANGLE POS KA MAG 18 19 8.068 -86.516 0.007 -84.297 ' 0.002 ° 19 12.027. -89.427 0.007 -84.297 6.014 PU VOLTS --- 3 PH ---- = ------------ L-G FAULT ----------------- BUS MAG ANGLE POS ANGLE ZERO ANGLE NEG ANGLE 19 0.0 0.0 1 -0.001 1 -0.002 0 3.962 1 0.871 --0.747— 1 0 ° -27.622 0 9.007 2 0.871 -0.747° 1 ° ° -27.622 0 9.007 3 0.871 -0.747 1 0 0 -27.622 0 9.007 4 0.814 -1.155 1 0 0 13.639 0 9.008 7 0.659 2.536 1 0 ° 2.346 0 -0.907 13. 0.704 0.938 1 0 ° 11.127 0 1.733 14 0.745 0.8391 0 ° 10.647 0 1.518 17 0.637 2.911 1 ° 0 2.495 0 -1.124 18 0.246 2.911 1 -0.001 0 4.7 ° 3.013 20 0.805 0.591 1 0 0 11.032 0 1.52 21 0.7479 «2.46301 ° o 89.998 0 -3.238 27 0.704 0.937 1 0 ° 10.879 0 1.735 28 «0.6370 2.911 1 0 0 1.655 0 -1.123 3 PHASE E/Z= 19.861 KA ( 82.563 MVA)@ -86.352 DEG KY= 2.4 Peders! GND FAULT = 0.014 KA ( 0.06 MVA)@ -84.296 DEG dievel gener. Z-POS= 0.077073 +J 1.20873 — Z-ZERO= 499.503 +J 4999.57 CONTRIBUTIONS ----3 PH FAULT---- ----------- L-G FAULT BUS TO BUS 3 PH KA MAG ANGLE 3-10 KA MAG ANGLE POS KA MAG 14 20 9.656 -83.091 0.007 -84.296 0.002 ° 20 10.236 -89.427 0.007 -84,296 5.118 PU VOLTS --- 3 PH ---- = ------------ L-G FAULT ----------------- BUS MAG ANGLE POS ANGLE ZERO ANGLE NEG ANGLE 20 «0.0 0.0 1 ° -1 -0.001 0 2.056 1 0.858 -1.535 1 0 ° -21.546 0 11.254 2 0.858 -1.535 1 0 o -21.546 0 11.254 3 0.858 -1.535 1 0 0 -21.546 0 11.254 4 04796 ~-2.392 1 -0.001 0 19.654 0 11.254 7 0.618 0.445 1 ° oO 7.948 0 1.336 ANGLE -82.554 -85. 466 ANGLE -81.035 -87.371 PH A 0.007 0.007 - 6 - CASE APA69Z91 -79.002 -88.805 -86.551 13 0.445 6.278 1 ° ° 2.06 ° -2.923 14 0.294 6.335 1 ° ° 3.684 oO -0.571 47 0.624 0.322 1 ° Qo 10.658 0O 1.522 18 0.737 0.191 1 fe) ° 11.039 0 1.521 19 0.807 0.128 1 0 ° 10.704 0 1.521 21 0.716 1.216 1 ° ° 89.999 O 0.999 27 0.445 6.279 1 ° ° 3.443 ° -2.923 28 0.624 0.323 1 ° fe) 10.736 0 1.519 BUS 21 3 PHASE E/Z= 2.379 KA ( 51.518 MVA)@ -85.105 DEG KV= 12.5 GND FAULT = 2.447 KA ( 52.972 MVA)@ -86.465 DEG 2-POS= 0.165658 +J 1.93398 Z-ZERO= 0.017875 +J 1.78468 CONTRIBUTIONS ----3 PH FAULT=---- 9 ----------- L-G FAULT BUS TO BUS 3 PH KA MAG ANGLE 3-10 KA MAG ANGLE POS KA MAG Z 21 1.589 -87.503 ° -81.334 0.545 ° 21 0.795 -80.305 2.446 86.466 0.794 PU VOLTS --- 3 PH ---- 00 ------------ L-G FAULT ----------------- BUS MAG ANGLE POS ANGLE ZERO ANGLE NEG ANGLE 21 0.0 0.0 0.657 0.709 0.315 2.961 -0.343 -1.361 1 0.883 -0.757 0.96 -0.182 ° -27.014 -0.04 4.322 2 0.883 -0.757 0.96 -0.182 ° -27.014 -0.04 4.322 3 0.883 -0.757 0.96 -0.182 ° -27.014 -0.04 4.322 4 0.831 -1.163 0.942 -0.267 ° 14.134 -0.058 4.322 Zz 0.688 1.925 0.893 0.671 ° 2.564 -0.107 -5.595 13. 0.73 0.59 0.907 0.301 ° 11.375 -0.093 -2.953 14 0.767 0.55 0.92 0.275 ° 11 -0.08 -3.168 17 0.693 1.798 0.895 0.637 ° 5.322 -0.106 -5.408 18 «600.785 1.113 0.926 0.431 ° 5.327 -0.074 -5.409 19 0.843 0.758 0.946 0.309 ° 5.391 -0.054 -5.409 20 0.822 0.391 0.939 0.205 ° 10.99 -0.061 -3.168 27 0.73 0.589 0.907 0.301 ° 11.102 -0.093 -2.953 28 840.693 1.798 0.895 0.637 ° 5.323 -0.106 -5S.41 BUS 27 3 PHASE E/Z= 96.95 MVA@ -81.588 DEG GND FAULT = 128.646 MVA@ -82.319 DEG Z-POS= 0.150906 +J 1.02036 Z-ZERO= 0.009906 +J 0.270346 CONTRIBUTIONS ----3 PH FAULT---- ----------- L-G FAULT BUS TO BUS 3 PH MVA MAG ANGLE 3-10 MVA MAG ANGLE POS MVA MAG ANGLE 13 27 64.315 -78.271 13.9 -74.761 28.447 14 27 32.877 -88.074 50.635 -82.451 14.542 ° 27 0.01 -84.295 64.255 -83.844 0.005 PU VOLTS --- 3 PH ---- L-G FAULT —- BUS MAG ANGLE ZERO ANGLE NEG ANGLE 27 0.0 0.0 -0.116 5.583 -0.442 -0.731 1 0.754 -4.786 -0.002 -19.654 -0.114 13.446 2 0.754 -4.786 -0.002 -19.654 -0.114 13.446 3 0.754 -4.786 -0.002 -19.654 -0.114 13.446 4 0.647 -8.073 -0.003 21.503 -0.164 13.446 Z 0.324 -8.998 -0.027 10.042 -0.302 3.528 13 o 11.156 -0.101 4.197 -0.442 -0.732 14 0.137 1.353 0.618 0.584 -0.102 5.391 -0.382 -0.946 17 0.335 -8.93 0.704 -1.565 -0.019 12.798 -0.297 3.714 18 0.532 -3.925 0.793 -0.974 -0.003 12.798 -0.208 3.713 19 0.657 -2.324 0.848 -0.666 -0.004 12.798 -0.152 3.713 20 0.342 0.413 0.709 0.388 -0.051 S.3291 -0.291 -0.946 PH B ° -7- CASE APA69Z91 21 0.492 -1.991 0.775 -0.347 ° 15.173 -0.225 1.194 28 «40.335 -8.925 0.704 -1.564 -0.023 12.798 -0.297 3.711 BUS 28 3 PHASE E/Z= 117.292 MVA@ -83.173 DEG GND FAULT = 140.604 MVA@ -S3.728 DEG Z-POS= 0.101353 +J 0.846524 Z-ZERO= 0.030403 +J 0. ealocee CONTRIBUTIONS ----3 PH FAULT---- ee monrewer, Ets) FAN BUS TO BUS 3 PH MVA MAG ANGLE 3-10 MVA MAG ANGLE POS MVA mac ANGLE PHA PH B PH C 17 28 91.835 -81.428 45.42 -76.352 36.696 -81.984 88.471 21.68 21.68 18 28 25.645 -89.426 34.825 -87.22 10.247 -89.982 32.094 1.459 1.459 ° 28 0.01 -84.295 60.912 -87.22 0.004 -88.342 60.912 O ° PU VOLTS --- 3 PH -——-- L-G FAULT = BUS MAG ANGLE ZERO ANGLE NEG ANGLE 28 0.0 0.0 -0.201 2.207 -0.4 -0.55S 1 0.654 -5S.46 -0.012 -26.787 -0.141 9.577 2 0.654 -5S.46 -0.012 -26.787 -0.141 9.577 3 0.654 -5.46 -0.012 -26.7387 -0.141 9.577 4 0.505 -10.265 -0.017 14.37 -0.204 9.577 th 0.06 -3.395 -0.184 2.91 -0.376 -0.339 13 0.193 -12.076 -0.053 11.71 -0.324 2.302 14 0.302 -6.143 -0.022 11.197 -0.28 2.087 17 ° 7.998 -0.218 3.081 -0.4 -0.556 18 0.299 0.001 -0.072 2.207 -0.28 -0.556 Se 0.487 ° 0.795 0.143 -0.036 2.207 -0.205 -0.556 20 0.467 -3.021 0.787 -0.566 0.011 11.197 -0.213 2.087 21 0.3 4.949 0.72 1.039 oO 8.044 -0.28 -2.672 27 0.193 -12.073 0.676 -1.104 0.025 11.389 -0.324 2.302 READY EDI LIS 320 320 0» - 21, 0.979, 5.7301, 999, DY BB Y sOhoSt? 0-979 5-7301. Oo, 320 0s -21, 0.979, 5.7301, oO, READY REP READY LIST APAS9Z91 OOrSSEDT 09/08/82 100 R+JUX, CHECK, ALL, 100 110 ALASKA POWER AUTHORITY, 120 APA69Z91, 3 TYEE + WR+PE+CR GENS$ 130 0, 1, oO, 2, 10440, 131 0, 2 0, 2, 10440, 132 0, 3 0, 2. 10440, 140 1, 4s 0, .8888, 999, 141 2, 4 oO, .88e8e, 999, 14203 4, 0, .9883, 999, 150 0, 4, 999, 9999, 0, 160 4, 7, .3126, .7784, -558, 170 7+ 17, .0135, .0636, -0376, 180 17, 28 0, .0001, 0, 190 18, 28, 0, 1.1667, oO, 200 0, 28; 999, += 99995 0, 210 + =7, 13, .1781, .4708, -3642, 220 13, 27, 0, .0001, 0, 230 27) 145 0, .4167, o 240 0, 27, «999, 9999, 0, 250 0:14, 3.339, 17.124, oO, 252. 0, 14, 999, 9999, 9.955 260 14, 20; 0, .733, 999, 270 0-20, 0, 2.355 999, 280 18, 19, 0, .7333, 999, 290 0, 18 999, 9999, 0, 300 Os _ 195 0. 2.0, 999, 310-7, 214, Oo, 2.0, 999, 320-0, -21, 0.979, 5.7301, 0, 540 0,0 600 69.0, 4, 7, 13, 17, 0 610 2.4, 19, 20, 0 620 13.8, 1, 2, 3, 0 630 12.5, 21, 18, 0 640 24.9, 14, 0 650 0, READY 9IOD 11788 1.785 “ANCHORAGE, ALASKA" SAW MILL 69 -0001 -0001 +0001 9999 IIDD POOP +252 2.377 «2214 —21166 1.1083 799 1.5586 +3333 - 0833 - 5416 - 6233 10.77 9999 9999 9I9O +6233 9999 9999 1.785 KV (9/7/82) GENERAL ELECTRIC CO CASE APA69Z93 INDUSTRIAL POWER SYSTEMS ENGINEERING OPERATION 50 BUS THREE PHASE & SINGLE PHASE SHORT CIRCUIT PROGRAM CASE APA&9Z93 09/08/82 BASE MVA s 100 ALASKA POWER AUTHORITY ANCHORAGE, ALASKA 3 TYEE + NO OTHER GENS: SAW MILL OFF LINE (9/7/82) -BUS 1 3 PHASE E/Z= 3.886 KA ( 92.894 MVA)@ -89.427 DEG \KV= 13.8 Tyee Lave GND FAULT = 0.002 KA ( 0.043 MVA)@ -43.15 DEG Qenec, Z-POS= 0.010776 +J 1.07644 Z-ZER 5038.85 +J 4721.34 CONTRIBUTIONS ----3 PH FAULT---- =e --- L-G FAULT BUS TO BUS 3 PH KA MAG ANGLE 3-10 KA MAG ANGLE POS KA MAG 4 i. 1.795 -89.426 0.001 -84.308 ° ° 1 2.092 -89.427 0.001 -0.013 1.383 PU VOLTS --- 3 PH ---- —--~ L-G FAULT --— aN BUS MAG ANGLE POS ANGLE ZERO ANGLE NEG ANGLE 1 0.0 0.0 1 -0.006 -1 -0.013 ° 46.277 2 0.572 0.001 1 -0.003 ° -36.825 0 46.276 3 0.572 0.001 1 -0.003 ° -36.825 0 46.276 4 0.381 0.001 1 -0.004 ° 4.348 ° 46.276 a 0.382 -0.024 1 -0.004 oO 11.051 0 46.291 13 0.382 -0.032 1 -0.004 ° 19.188 0 46.297 14 0.382 -0.032 1 -0.004 0 19.049 0 46.297 17 0.382 -0.024 1 -0.004 ° 12.92 ° 46.292 18 0.382 -0.024 1 -0.004 °o 12.955 0 46.292 27 0.382 -0.032 1 -0.004 ° 19.049 0 46.297 28 0.382 -0.024 1 -0.004 oO 12.955 0 46.292 BUS 2 3 PHASE E/Z= 3.886 KA ( 92.894 MVA)@ -89.427 DEG KV= 13.8 GND FAULT = 0.002 KA ( 0.043 MVA)@ -43.15 DEG Z-POS= 0.010776 +J 1.07644 Z-ZERO= 5038.85 +J 4721.34 CONTRIBUTIONS ----3 PH FAULT~--- BUS TO BUS 3 PH KA MAG ANGLE 3-10 KA MAG ANGLE POS KA MAG 4 2 1.795 -89.426 0.001 -84. 308 ° ° 2 2.092 -89.427 0.001 -0.013 1.383 PU'VOLTS. ==-3 FS SS t=G FAULT ese SesSsse==== BUS MAG ANGLE Pos ANGLE ZERO ANGLE NEG ANGLE 2 0.0 0.0 1 -0.006 =. -0.013 o 46.277 1 0.572 0.001 1 -0.003 ° -36.803 0 46.276 3 0.572 0.001 1 -0.003 ° -36.803 0 46.276 4 0.381 0.001 1 -0.004 ° 4.347 ° 46.276 7 0.382 -0.024 1 -0.004 0 11.057 0 46.291 13 0.382 -0.032 1 -0.004 ° 19.465 0 46.297 14 0.382 -0.032 1 -0.004 ° 19.381 0 46.297 a7 0.382 -0.024 1 -0.004 °o 13.036 0 46.292 16 0.382 -0.024 1 -0.004 0 13.038 0 46.292 27 0.382 -0.032 1 -0.004 0 19.381 0 46.297 28 0.382 -0.024 1 -0.004 0 13.038 0 46.292 BUS 3 3 PHASE E/Z= 3.886 KA ( 92.994 MVA)@ -89.427 DEG KV= 13.8 ANGLE -43.149 -0.014 ANGLE -43.149 -0.014 0.001 0.001 CASE APAS69Z93 GND FAULT = 0.002 KA ( 0.043 MVA)@ -43.15 DEG Z-POS= 0.010776 +J 1.07644 Z-ZERO= 5038.85 +J 4721.34 - - L-G FAULT-------------------------------------------- ANGLE -43.149 -0.014 ANGLE -89.344 -89.344 -89.344 -88. 287 -84.981 PHC | 0.129 0.129 0.129 0.028 ~ L-G FAULT~------------------------------------------- CONTRIBUTIONS ----3 PH FAULT---- = ---------- BUS TO BUS 3 PH KA MAG ANGLE 3-10 KA MAG ANGLE POS KA MAG 4 3 1.795 -89.426 0.001 -84. 308 ° ° 3 2.092 -89.427 0.001 -0.013 1.383 PU VOETS ——— "SRN oma = L-G FAULT ——— BUS MAG ANGLE Pos ANGLE ZERO ANGLE NEG ANGLE 3 0.0 0.0 1 -0.006 | -0.013 ° 46.277 1 0.572 0.001 1 -0.003 ° -36.822 0 46.276 2 0.572 0.001 1 -0.003 ° -36.822 0 46.276 4 0.381 0.001 1 -0.004 ° 4.345 0 46.276 7 0.382 -0.024 1 -0.004 0 11.133 0 46.291 13 0.382 -0.032 1 -0.004 oO 19.441 0 46.297 14 0.382 -0.032 1 -0.004 ° 19.342 0 46.297 17 0.382 -0.024 1 -0.004 ° 13.025 0 46.292 18 0.382 -0.024 1 -0.004 ° 13.048 0O 46.292 27 0.382 -0.032 1 -0.004 ° 19.342 0 46.297 28 0.382 -0.024 1 -0.004 ° 13.048 0 46.292 bus 4 3 PHASE E/Z= 0.87 KA ( 103.946 MVA)@ -89.426 DEG KV= 49. Tyee Lake GND FAULT = 1.163 KA ( 139.024 MVA)@ -89.343 DEG 64 ev bus Z-POS= 0.009644 +J 0.961987 Z-ZERO= 0.005478 +J 0.233779 CONTRIBUTIONS ----3 PH FAULT---- pee L-G FAULT--- BUS TO BUS 3 PH KA MAG ANGLE 3-10 KA MAG ANGLE POS KA MAG 1 4 0.29 -89.427 ° -41.842 0.129 2 4 0.29 -89.427 ° -41.842 0.129 3 4 0.29 -89.427 ° -41.842 0.129 Z 4 0.001 -88.37 0.085 -79.57 ° ° 4 ° -84.295 1.079 -90.112 ° PU VOLTS --- 3 PH ---- 99 ------------ L-G FAULT ----------------- BUS MAG ANGLE POS ANGLE ZERO ANGLE NEG ANGLE 4 0.0 0.0 0.554 -0.067 -0.108 -0.685 -0.446 0.083 1 0.308 ° 0.691 -0.037 -0.074 -41.842 -0.309 0.083 2 0.308 +O 0.691 -0.037 -0.074 -41.842 -0.309 0.083 3 0.308 ° 0.691 -0.037 -0.074 -41.842 -0.309 0.083 7 0.001 -20.25 0.555 -0.079 -0.026 6.07 -0.445 0.099 13 0.001 -20.001 0.555 -0.083 0.009 14.211 -0.445 0.104 14 0.001 -19.998 0.555 -0.083 0.006 14.211 -0.445 0.104 17 0.001 -19.929 0.555 -0.079 -0.021 7.921 -0.445 0.099 18 0.001 -19.925 0.555 -0.079 -0.023 7.921 -0.44S 0.099 27 0.001 -20.001 0.555 -0.083 0.006 14.211 -0.445 0.104 28 40.001 -19.928 0.555 -0.079 -0.023 7.921 -0.445 0.099 Fuse 3 PHASE E/Z= 0.473 KA ( 56.562 MVA)@ -79.518 DEG = Wrangell GND FAULT = 0.608 KA ( 72.686 MVA)@ -80.154 DEG Switdhyerd Z-POS= 0.32166 +J 1.73845 Z-ZERG= 0.062474 +J 0.539645 CONTRIBUTIONS ----3 PH FAULT---- ---------- BUS TO BUS 3 PH KA MAG ANGLE 3-10 KA MAG ANGLE PCIS KA MAG 4 7 0.473 -79.529 0.134 -74.166 0. 202 13 he 0 -80. 483 0.146 -77.489 °o 17 7 oO -80.93 0.329 -63.779 Qo PU VOLTS --- 3 PH ---- 9 ------------ L-G FAULT ----------------- BUS MAG ANGI F POs ANGE 7ERN anere nce Ane e 3 - CASE APA69Z93 7 0.0 0.0 0.572 0.477 -0.144 3.798 -0.428 -0.636 1 0.633 -5S.887 0.841 -1.773 -0.009 -25.898 -0.161 9.287 2 0.633 -5.887 0.841 -1.773 -0.009 -25.898 -0.161 9.287 3 0.633 -5S.887 0.841 -1.773 -0.009 -25.898 -0.161 9.287 4 0.474 -11.409 0.771 -2.794 -0.013 15.259 -0.233 9.287 13° 0 -11.204 0.572 0.474 -0.051 11.938 -0.428 -0.634 14 0 “11.196 0.572 0.474 -0.032 11.938 -0.428 -0.634 17. 0 -2.964 0.572 0.477 -0.115 5.649 -0.428 -0.636 18 0 -2.917 0.572 0.477 -0.13 5.649 -0.428 -0.636 27. 0 “11.203 0.572 0.474 = -0.032 11.938 -0.428 -0.634 28 «(0 -2.946 0.572 0.477 -0.13 5.649 -0.428 -0.636 BUS 12. 3 PHASE E/Z= 0.37 KA ( 44.169 MVA)@ -77.256 DEG KV= 469. Rerersburq = GND FAULT = 0.486 KA ( 58.12 MVA)@ -78.43 DEG tolnk. GU Z-POS= 0.499433 +J 2.20826 — Z-ZERO= 0.036394 +J 0.64036 CONTRIBUTIONS ----3 PH FAULT---- ----------- L-G FAULT BUS TO BUS 3 PH KA MAG ANGLE 3-10 KA MAG ANGLE POS KA MAG 7 13 0.369 -77.262 0.131 “71.135 0.162 27 13 ° 13.316 0.356 “81.11 ° PU VOLTS --- 3 PH ---- — ------------ L-G FAULT ----------------- BUS MAG ANGLE POS ANGLE ZERO ANGLE NEG ANGLE 13.0.0 0.0 0.562 0.917 -0.124 8.317 -0.439 -1.174 1 0715 4.976 =—-00874 -1.615 — -0, 003 -16.034 -0.129 11.016 2 0.715 -4.976 0.874 -1.615 -0.003 -16.034 -0.129 11.0146 3 0.715 -4.976 0.874 -1.615 -0.003 -16.034 -0.129 11.016 4 0.592 -8.71 0.818 -2.493 -0.004 25.123 -0.186 11.016 7 0.222 -7.983 0.658 -0.568 -0.041 13.662 -0.342 1.09 140 5.619 0.562 0.917 -0.077 8.317 -0.439 -1.174 17 0.222 -7.975 0.658 -0.566 -0.033 15.513 -0.342 1.088 18 0,222 -7.975 0.658 -0.566 -0,037 15.513 -0.342 1.088 27. «0 102.744 0.562 0.917 -0.077 8.317 -0.439 -1.174 28 0.222 -7.975 0.658 -0.566 -0.037 15.513 -0.342 1.088 BUS 14, 3 PHASE E/Z= 0.867 KA ( 37.412 MVA)@ -79.14 DEG _KV= ferersbues GND FAULT = 1.184 KA ( 51.063 MVA)@ -79.962 DEG Sula. WAWW ——-Z-POS= 0.503601 +J 2.62506 — Z-ZERO= 0.016843 +J 0.535021 CONTRIBUTIONS ----3 PH FAULT---- | ----------- L-G FAULT BUS TO BUS 3 PH KA MAG ANGLE 3-10 KA MAG ANGLE POS KA MAG 27 14 0.867 -79.14 1.184 -79.962 0.395 PU VOLTS --- 3 PH ---- 9 ------------ L-G FAULT ----------------- BUS MAG ANGLE POS ANGLE ZERO ANGLE NEG ANGLE 14 0.0 0.0 0.545 0.686 -0.091 8.235 -0.455 -0.922 1 0.756 -3.376 0.888 -1.204 -0.001 -17.566 -0.113 9.484 2 0.756 -3.376 0.888 -1.204 -0.001 -17.566 -0.113 9.484 3 0.756 -3.376 0.888 -1.204 -0,001 -17.566 -0.113 9.484 4 0.649 -5.685 0.839 -1.841 -0.002 23.591 -0.164 9.484 7 0339-0742 0699 0419-0022 12.13 -0.301 -0.442 13° 0.156 10.287 0.615 1.694 -0.068 6.786 -0.385 -2.704 17 0.339 -0.738 = 069904191 -0.018 13.981 -0.301 -0.444 18 0.339 -0.73@ 0.699 0.191 -0.02 13.981 -0.301 -0.444 27. 0.156 «10.287, 0.615 1.694 -0.077 8.008 -0.3385 -2.705 28 0.339 -0.738 0.699 0.191 -0.02 13,981 -0.301 -0.444 BUS 17 3 PHASE E/Z= 0.457 KA ( 54.559 MVA)@ -79.464 DEG KV= 69 w Nie e\N shee GND FAULT = 0.595 KA ( 71.126 MVA)@ -80.31 DEG ANGLE -78.436 12.142 - 4 - CASE APA&9Z93 - L-G FAULT------------------------------~------------- Z-POS= 0.33514 +J 1.80196 Z-ZERO= 0.039685 +J 0.553774 CONTRIBUTIONS ----3 PH FAULT---- ----------- L-G FAULT-------------------------------------------- BUS TO BUS 3 PH KA MAG ANGLE 3-10 KA MAG ANGLE POS KA MAG ANGLE iz 17 0.456 -79.464 0.219 -74.206 0.198 -80.31 28 17 0 -82.977 0.378 -83.836 0 -83.823 PU VOLTS --- 3 PH ---- 9 ------------ L-G FAULT ----------------- BUS MAG ANGLE POS ANGLE ZERO ANGLE NEG ANGLE 17.0.0 0.0 0.566 0.65 -0.132 5.591 -0.435 -0.846 1 0.645 -5.594 0.845 -1.699 -0.007 -24.204 -0.158 9.132 2 0.645 -5.594 0.845 -1.699 -0.007 -24.204 -0.153 9.132 3 0.645 -5.594 0.845 -1.699 -0.007 -24.204 -0.158 9.132 4 0.492 -10.645 0.776 -2.672 0.011 16.954 -0.228 9.132 7 0.035 -1.448 0.581 0.572 -0.112 5.493 -0.419 -0.792 13 0.036 -1.458 0.581 0.571 -0.04 13.633 -0.419 -0.792 14 0.036 -1.458 0.581 0.571 -0.025 13.633 -0.419 -0.792 18 0 3.411 0.566 0.65 -0.149 5.591 -0.435 -0.846 27 0.036 -1.516 0.581 0.569 -0.025 13.633 -0.419 -0.789 28 0 6.45 0.566 0.65 -0.149 5.591 -0.435 -0.846 -BUS_18. 3 PHASE E/Z= 1.545 KA ( 33.457 MVA)@ -83.337 DEG KV= 12,5 Wrangell GND FAULT = 1.808 KA ( 39.152 MVA)@ -84.35 DEG Subst. \LSWW = -7-POS= 0.346808 +J 2.96876 Z-ZERO= 0.06075 +J 1.68763 CONTRIBUTIONS ----3 PH FAULT~--- ----------- BUS TO BUS 3 PH KA MAG ANGLE 3-10 KA MAG ANGLE POS KA MAG ANGLE 28 18 1.545 -83.337 1.808 -84.35 0.603 -84.35 PU VOLTS --- 3 PH ---- 9 ------------ L-G FAULT ----------------- BUS MAG ANGLE POS = ANGLE ZERO ANGLE NEG ANGLE 18 90.0 0.0 0.41 0.648 -0.22 3.588 -0.39 -1.013 1 0.779 -1.742 0.914 -0.483 -0.005 -28.244 -0.087 5.091 2 0.779 -1.742 0.914 -0.483 -0.005 -28.244 -0.087 5.091 3 0.779 -1.742 0.914 -0.483 -0.005 -28.244 -0.087 5.091 4 0.681 -2.878 0.875 -0.729 -0.007 12.913 -0.125 5.091 7 0.412 5.492 0.77 1.446 -0.07 1.452 -0.231 -4.833 13° 0.412 5.487 0.77 1.445 -0.025 9.593 -0.231 -4.832 14 0.412 5.487 0.77 1.445 -0.015 9.593 -0.231 -4.832 17 0.39 6.09 0.762 1.532 -0.082 1.551 -0.239 -4.886 27 0.412 «5.484 3890477 1.445 -0.015 9.593 -0.231 -4.83 28 40.39 = 6.09 0.762 1.532 -0.076 0.75 -0.239 -4.885 BUS 27 3 PHASE E/Z= 44.167 MVA@ -77.257 DEG GND FAULT = 60.325 MVA@ -78.225 DEG Z-POS= 0.499434 +J 2.20836 Z-ZERO= 0.01601 +J 0.451721 CONTRIBUTIONS ----3 PH FAULT---- ---------- BUS TO BUS 3 PH MVA MAG ANGLE 3-10 MVA MAG ANGLE POS MVA MAG ANGLE 13 27 44.135 -77.252 10.08 -70.93 20.094 -78.22 14 27 ° -97.24 0 -79.442 0 -98. 208 0 27 0.01 -84.295 50.343 -79.682 0.008 -86.72 PU VOLTS --- 3 PH ---- ------------ L-G FAULT ----------------- BUS MAG ANGLE POS ANGLE ZERO ANGLE NEG ANGLE 27.0.0 0.0 0.545 0.809 -0.091 9.745 -0.455 -0.968 1 0.715 -4.976 0.869 -1.717 -0.002 -15.829 -0.134 11.221 2 0.715 -4.976 0.869 -1.717 -0.002 -15.829 -0.134 11.221 3 0.715 -4.976 0.869 -1.717 -0.002 -15.829 -0.134 11.221 4 0.592 -8.709 0.811 -2.657 -0.002 25.328 -0.193 11.221 -S- CASE APAS9Z93° -0.026 -0.08 -0.091 -0.021 -0.024 -0.024 13.867 8.523 9.745 15.718 15.718 15.718 -0.355 -0.455 -0.455 -0.355 -0.355 -0.355 1.295 -0.969 -0.968 1.296 1.296 1.293 Z-ZERG= 0.049667 +J 0.579336 7, 0.222 -7.98 0.645 -0.714 13 («OO 12.175 0.545 0.809 14 ° -7.813 0.545 0.809 17. 0.222 -7.979 0.645 -0.714 18 0.222 -7.979 0.645 -0.714 28 0.222 -7.972 0.645 -0.713 BUS 28 3 PHASE E/Z= 54.557 MVA@ -79.465 DEG GND FAULT = 70.672 MVA@ -80.236 DEG Z-POS= 0.335141 +J 1.80206 CONTRIBUTIONS ----3 PH FAULT---- BUS TO BUS 3 PH MVA MAG ANGLE 17 28 54.557 -79.464 18 23 ° -83.656 o 23 0.01 -84.295 CO VOETS 10) Pt BUS MAG ANGLE POS ANGLE 28 0.0 0.0 0.568 0.586 1 0.645 -5S.593 0.846 -1.7 Z 0.645 -5.593 0.846 -1.7 3 0.645 -5.593 0.846 ~-1.7 4 0.492 ~-10.644 0.777 -2.672 Z 0.035 -1.431 0.584 0.512 13. 0.036 -1.441 0.584 0.512 14 0.036 -1.441 0.584 0.512 17 ° 9.963 0.568 0.586 18 ° 5.772 0.568 0.586 27 0.036 -1.441 0.584 0.512 THe L-G FAULT 3-10 MVA MAG ANGLE POS MVA MAG ANGLE 29.451 -74.132 23.558 -80.235 °o -85.61 ° 84.426 41.506 -84.563 0.006 -89.393 L=-G FAULT -—----------—----— ZERO ANGLE NEG ANGLE -0.137 4.865 -0.432 -0.771 -0.008 -24.129 -0.157 9.206 -0.008 -24.129 -0.157 9.206 -0.008 -24.129 -0.157 9.206 -0.012 17.028 -0.226 9.206 0.126 5.567 -0.416 -0.718 -0.045 13.707 -0.416 -0.717 -0.028 13.707 -0.416 -0.717 0.148 5.666 -0.432 -0.771 0.137 4.865 -0.432 -0.771 -0.028 13.707 -0.416 -0.717 PHA 56.887 ° 41.506 PH B 13.836 oO ° OLD RHASES READY RUN PHASES 01: 27EDT 09/08/82 USE MANUAL DATED JUNE 1976 NAME OF DATA FILE? LIST ALL BUSES? ADJ. CONTRIBUTIONS ONLY? WIDE PAPER? ? APAS9Z93, YES, YES,» YES INPUT DATA BUS TO BUS =R-POS,NEG X~POS,NEG R-ZERO X-ZERO ° 1 ° 2 10440 0.0001 ° 2 ° 2 10440 0.0001 ° 3 oO 2 10440 0.0001 1 4 ° 0.8888 999 IIOP 2 4 ° 0.8888 999 9999 3 4 ° 0.8888 999 9999 ° 4 999 99D ° 0.252 4 7 0.3126 0.7784 0.558 2.377 7 17 0.0135 0.0636 0.0376 0.2214 17 28 ° 0.0001 ° 0.1166 18 28 ° 1.1667 ° 1.1083 ° 28 999 9999 ° 0.99 7 13 0.1781 0.4708 0.3642 1.5586 13 27 ° 0.0001 ° 0.3333 14 27 ° 0.4167 ° 0.0833 ° 27 999 IIIP oO 0.5416 BUSES AT 69 KV 4 7 13 17 BUSES AT 13.8 KV 1 2 3 BUSES AT 12.5 KV 18 BUSES AT 24.9 KV 14 INPUT DATA CORRECT? YES INPUT DATA LISTED IN OUTPUT? NO GENERAL ELECTRIC CO INDUSTRIAL POWER SYSTEMS ENGINEERING OPERATION SO BUS THREE PHASE & SINGLE PHASE SHORT CIRCUIT PROGRAM BASE MVA ® 100 CASE APA69Z94 ALASKA POWER AUTHORITY ANCHORAGE » IS + 09/08/82 ALASKA 1 - CASE APA69Z94 gL 3 PHASE E/Z= 2.096 KA ( 50.107 MVA)@ -89.424 DEG KY= 13.3 -41.807 -0.027 Tyee Lake GND FAULT = 0.002 KA ( 0.043 MVA)@ -43.16 DEG oener. Z-POS= 0.02006 +J 1.99563 Z-ZERO= 5039.02 +J 4721.35 CONTRIBUTIONS ----3 PH FAULT~--- ----------- L-G FAULT BUS TO BUS 3 PH KA MAG ANGLE 3-10 KA MAG ANGLE POS KA MAG ANGLE 4 1 0.005 -68.072 0.001 -84.319 0 ° 1 2.092 -89.427 0.001 -0.024 1.383 PU VOLTS --- 3 PH ---- 9 ------------ L-G FAULT ----------------- BUS MAG . ANGLE POS ANGLE ZERO ANGLE NEG ANGLE 1 0.0 0.0 1 -0.012. -1 -0.024 0 46.265 4 0.001 1.355 1 -0.012. 0 3.097 0 46.263 7 0,002 -8.648 1 -0.012. 0 9.828 0 46.28 13 0.002 -10.035 1 -0.012. 0 17.96 0 46.285 14 0,002 -10.035 1 -0.012 0 17.914 0 46.285 17 0.002 -8.676 1 -0.012 0 11.687 0 46.28 18 0.002 -8.675 1 -0.012 0 11.705 0 46.28 27 0.002 -10.035 1 -0.012. 0 17.914 0 46.285 28 0.002 -8.676 1 -0.012 0 11.705 0 46.28 Bus 4. 3 PHASE E/Z= 0.291 KA ( 34.724 MVA)@ -89.423 DEG KY= 469 Tyee lake = GND FAULT = 0.394 KA ( 47.079 MVA)@ -89.23 DEG 6T EV bus Z-POS= 0.029012 +J 2.87968 § Z-ZERO= 0.027661 +J 0.612292 CONTRIBUTIONS ----3 PH FAULT---- ----------- L-G FAULT BUS TO BUS 3PH KA MAG ANGLE 3-10 KA MAG ANGLE POS KA MAG 1 4 0.29 -89.427 0 -42.974 0.131 7 4 0.001 -88.447 0.076 -80.702 0 ° 4 0 -84.295 0.319 -91.244 0 PU VOLTS --- 3 PH ---- = ------------ L-G FAULT ----------------- BUS MAG ANGLE POS ANGLE ZERO ANGLE NEG ANGLE 4 0.0 0.0 0.548 -0.159 -0.096 -1.816 -0.452 0.193 1 0.308 0 0.687 -0.088 -0.066 -42.973 -0.313 0.193 7 0.001 -20.326 0.548 -0.173 -0.023 4.939 -0.452 0.21 13. 0.001 -20.072 0.549 -0.177 -0.008 13.079 -0.451 0.215 14 0.001 -20.07. 0.549 -0.177 -0.005 13.079 -0.451 0.215 17 0.001 -19.979 0.548 -0.173 -0.018 6.789 -0.452 0.21 18 0.001 -19.976 0.548 -0.173 -0.021 6.789 -0.452 0.21 27. 0.001 + -20.072 0.549 -0.177 -0.005 13.079 -0.451 0.215 28 0.001 -19.978 0.548 -0.173 -0.021 6.789 -0.452 0.21 BUS 7. 3 PHASE E/Z= 0,228 KA ( 27.257 MVA)@ -84.678 DEG _KV= 69 Wrangell GND FAULT = 0.316 KA ( 37.73 MVA)@ -84.665 DEG twikhyerd —-7-POS= 0.340305 +U 3.65299 Z-ZERO= 0.058696 +J 0.610735 COMITO TOL Tae 2 ©u FAULT---- oe rams ANGLE POS KA MAG 0.105 ° ° ANGLE 0.013 4.775 4.775 0.017 0.017 0.013 0.013 0.017 - 2 - CASE AFAE9Z94 BUS TO BUS 3 PH KA MAG ANGLE 3-10 KA MAG 4 7 0.227 -84.722 0.061 ° -79 922 13 7 0 -84.685 0.079 -81.442 17 7 ° -84.682 0.177 -87.731 PU VOETS —— 3h =———— LE=6 FAL -—---——--—---——=—= BUS MAG ANGLE Pos ANGLE ZERO ANGLE NEG 7 0.0 0.0 0.539 -0.011 -0.077 -0.155 -0.461 1 0.461 -5.611 0.751 -1.592 -0.013 -31.651 -0.251 4 0.228 -16.602 0.64 -2.698 -0.018 9.504 -0.362 13 0 -15.406 0.539 -0.015 -0.027 7.986 -0.461 14 ° -15.398 0.539 -0.015 -0.017 7.986 -0.461 17 ° -6.666 0.539 -0.011 -0.062 1.696 -0.461 18 ° -6.624 0.539 -0.011 -0.07 1.696 -0.461 27 ° -15.405 0.539 -0.015 -0.017 7.986 -0.461 28260 -6.652 0.539 -0.011 -0.07 1.696 -0.461 3 PHASE E/Z= 0.201 KA 0.013 ( 24.072 MVA)@ -82.839 DEG KV= 62. soe GND FAULT = 0.28 KA ( 33.517 MVA)@ -83.129 DEG subst. 64 Z-POS= 0.517873 +J 4.12183 Z-ZERO= 0.035189 +J 0.642783 CONTRIBUTIONS ----3 PH FAULT---- 9 ----------- L-G FAULT BUS TO BUS 3 PH KA MAG ANGLE 3-10 KA MAG ANGLE POS KA MAG 7 13 0.201 -82.861 0.075 -76.057 0.093 27 13 ° -89.391 0.206 -85. 689 ° PU VOLTS --- 3 PH ---- 99 ------------ L-G FAULT -- BUS MAG ANGLE Pos ANGLE ZERO = ANGLE NEG ANGLE 13 0.0 0.0 0.536 0.251 -0.072 3.738 -0.464 -0.289 1 0.527 -6.011 0.779 -1.8 -0.004 -21.977 -0.223 6.316 4 0.322 -14.319 0.681 -2.974 -0.006 19.181 -0.321 6.316 7 0.121 -13.582 0.59 -1.078 -0.024 9.522 -0.41 1.554 14 0 0.821 0.536 0.251 -0.045 3.738 -0.464 -0.289 17. 0.121 -13.557 0.59 -1.076 -0.019 11.373 -0.41 1.551 18 0.121 -13.557 0.59 -1.076 -0.022 11.373 -0.41 1.551 27 «oO 0.036 0.536 0.251 -0.045 3.738 -0.464 -0.289 28 0.121 -13.557 0.59 -1.076 -0.022 11.373 -0.41 1.551 -BUS_14, 3 PHASE E/Z= 0.508 KA ( 21.889 MVA)@ -83.439 DEG KV= 24.2 ete GND FAULT = 0.719 KA ( 31.019 MVA)@ -83.705 DEG weak. WAV =: Z-POS= 0.522041 +J 4.53863 Z-ZERO= 0.016381 +J 0.53595 CONTRIBUTIONS ----3 PH FAULT---- ----------- L-G FAULT BUS TO BUS 3 PH KA MAG ANGLE 3-I0 KA MAG ANGLE POS KA MAG 27 14 0.508 -83. 439 0.719 -83.705 0.24 PU VOLTS --- 3 PH ---- 9 ------------ L-G FAULT ----------------- BUS MAG ANGLE Pos ANGLE ZERO ANGLE NEG ANGLE 14 0.0 0.0 0.528 0.238 -0.055 4.544 -0.472 -0.266 1 0.568 -4.604 0.795 -1.484 -0.002 -22.554 -0.206 5.74 4 0.38 -9.998 0.705 -2.419 -0.003 18.604 -0.297 5.74 7 0.198 -5.045 0.621 -0.597 -0.014 8.946 -0.379 0.977 13. 0.091 «5.989 0.571 0.652 -0.041 3.162 -0.43 -0.866 17. 0.198 -5.031 0.621 -0.595 -0.011 10.796 -0.379 0.974 18 0.198 -5,031 0.621 -0.595 -0.013 10.796 -0.379 0.974 27 0.091 5.989 0.571 0.652 -0.047 4.328 -0.43 -0.866 28 40.198 -5.031 0.621 -0.595 -0.013 10.796 -0.379 0.974 US 3 PHASE E/Z= 0.224 KA ( 26.787 MVA)@ -34.563 DEG KV= 62 Wranaels Tuberk CIV ANGLE PH A -84.709 0.23 -84.672 0.027 -84.669 0.059 ANGLE PH A -83.151 0.211 -89.681 0.069 ANGLE PH A -83.705 0.719 PH B 0.085 0.026 0.059 PH C 0.085 0.026 0.059 CASE APA GND FAULT = 0.312 KA ( 37.34 Z-POS= 0.353769 +J 3.71637 CONTRIBUTIONS ----3 PH FAULT---- BUS TO BUS 3 -PH KA MAG ANGLE 7 17 0.224 -84.571 28 17 ° -86.035 PU VOLTS --- 3 PH ---- 9 ---------- BUS MAG ANGLE POS = ANGLE a7 ||| |:o00 0.0 0.535 0.108 1 0.47 -5.534 0.753 -1.563 4 0.241 -15.774 0.644 -2.642 7 0.017 -6.555 0.543 0.007 13 0.018 -6.503 0.542 0.007 14 0.018 -6.503 0.543 0.007 18 0 1.505 0.535 0.108 27 0.018 -6.676 0.543 0.004 28 0 3.392 0.535 0.108 -BUS 13. 3 PHASE E/Z= 0.943 KA ( 20.42 Wears it GND FAULT = 1.205 KA ( 26.09: Sut ASW 7Z-POS= 0.365437 +J 4.88317 CONTRIBUTIONS ----3 PH FAULT---- - BUS TO BUS 3 PH KA MAG ANGLE 28 18 0.943 -85.721 PU VOLTS --- 3 PH ---- 9 ---------- BUS MAG ANGLE POS = ANGLE 18 0.0 0.0 0.574 0.262 1 0.595 -2.544 0.827 -0.705 4 0.415 -5.266 0.75 -1.122 7 0.251 3.109 0.681 0.654 13 0.251 3.103 0.681 0.653 14 0.251 3.103 0.681 0.653 17 0.238 3.707 0.675 0.726 27 (0.251 «3.094 0.4810. 651 28 0.238 3.707 0.675 0.726 BUS 27 3 PHASE E/Z= 24.071 MVA@ -82. GND FAULT = 34.247 MVAe@ -83. Z-POS= 0.517874 +J 4.12193 CONTRIBUTIONS ----3 PH FAULT---- BUS TO BUS 3 PH MVA MAG ANGLE 13 27 24.032 -82.848 14 27 0 -96. 303 ° 27 0.01 -84.295 PU VOLTS --- 3 PH ---- --- BUS MAG ANGLE POS ANGLE 27 0.0 0.0 0.526 0.242 1 0.527 -6.011 0.774 -1.857 4 0.322 -14.318 0.4675 -3.081 7 0.121 -13.57@ 0.582 -1.134 120 6.58 0.526 0.242 14 0 -6.875 0.526 0. 242 17 0.121 -13.575 0.582 -1.134 180.121 -13.575 0.582 -1.134 IZP4 MVA)@ -84.687 DEG Z-ZERO= 0.036425 +J 0.566991 ----------- L-G FAULT~------------------------------------------- 3-10 KA MAG ANGLE POS KA MAG ANGLE PHA PH B PH C O.11 -78.95 0.104 -84.696 0.244 0.068 0.068 0.203 -87.79 0 -86.16 0.068 0.068 0.068 -- L-G FAULT ----------------- ZERO ANGLE NEG ANGLE -0.071 1.637 -0.465 -0.125 -0.01- -29.822 -0.248 4.753 -0.014 11.332 -0.358 4.753 -0.061 1.674 -0.457 -0.009 -0.022 9.814 -0.457 -0.008 -0.013 9.814 -0.457 -0.008 -0.08 1.637 -0.465 -0.125 -0.013 9.814 -0.457 -005 -0.08 1.637 -0.465 -0.125 1 MVA)@ -85.721 DEG .KV= 12,5 2 MVA)@ -86.073 DEG Z-ZERO= 0.056561 +J 1.70462 ~---------- L-G FAULT-------------------------------------------- 3-10 KA MAG = ANGLE POS KA MAG ANGLE PH A PH B PH C 1.205 -86.073 0.402 -86.073 1.205 0 ° -- L-G FAULT ----------------- ZERO ANGLE NEG ANGLE -0.148 2.027 -0.426 -0.353 -0.008 -31.211 -0.173- 3.367 -0.011 9.946 -0.25 - 3.367 -0.048 0.288 -0.319 '-1.395 -0.017 8.428 -0.319 -1.394 -0.011 8.428 -0.319 -1.394 -0.056 0.251 -0.325 -1.511 -0.011 8.428 -0.319 -1.391 -0.052 -0.434 -0.325 -1.511 839 DEG 107 DEG Z-ZERO= 0.015548 +J 0.45265 ----------- L-G FAULT-------------------------------------------- 3-10 MVA MAG ANGLE POS MVA MAG ANGLE PHA PH B PH C 5.661 -76.036 11.397 -83.116 24.668 9.528 9.528 0 -84.324 0 -96.571 0 0 o -: 28.638 -84.502 0.008 -85.957 28.638 0 o L-G FAULT ---------- ZERO. ANGLE —NEG -0.082 4.926 -0.474 -0.268 -0.003 -21.956 -0.227 6.337 -0.004 19.202 -0.328 6.337 -0.015 9.543 -0.419 1.575 -0.045 3.759 -0.474 -0.052 4.926 -0.474 -O.01Z 11.394 -0.419 -0.014 11.394 -0.419 - 4 - CASE APA69Z94 28 0.121 -13.554 0.582 -1.131 -0.014 BUS 28 3 PHASE E/Z= 26.786 MVA@ -84.563 DEG GND FAULT = 37.2 MVA@ -84.643 DEG Z-POS= 0.35377 +J 3.71647 Z-ZERO= 0.045478 +J 0.596317 11.394 -0.419 1.572 -84.631 -86.932 -88.163 CONTRIBUTIONS ----3 PH FAULT---- ----------- L-G FAULT BUS TO BUS 3 PH MVA MAG ANGLE 3-10 MVA MAG ANGLE POS MVA MAG ANGLE 17 28 26.783 -84,.551 14.853 -78.906 12.398 18 28 ° -86.852 0 -87.646 0 ° 28 0.01 -84.295 22.471 -88.431 0.006 PU VOLTS --- 3 PH ---- 9 ------------ L-G FAULT ----------------- BUS MAG ANGLE POS ANGLE ZERO ANGLE NEG ANGLE 28 40.0 0.0 0.537 0.069 -0.074 0.997 -0.463 -0.08 1 0.471 -5S.534 0.754 -1.57 -0.011 -29.777 -0.247 4.798 4 0.241 -15.772 0.645 -2.651 -0.016 11.377 -0.357 4.798 7 0.017 -6.537 0.545 -0.03 -0.069 1.719 -0.455 0.036 13 0.018 -6.486 0.545 -0.03 -0.024 9.859 -0.455 0.037 14 0.018 -6.486 0.545 -0.03 -0.015 9.859 -0.455 0.037 17. 0 4.876 0.537 0.069 -0.08 1.682 -0.463 -0.08 18 0 2.575 0.537 0.069 -0.074 0.997 -0.463 -0.08 27 0.018 -6.486 = 0.545 -0.03— -0.015 9.859 -0.455 0.037 PH A 29.727 oO 22.471 PH B 7.489 ° ° PH C 7.489 ° ° OLD PHASES WHAT? OLD PHASES READY RUN PHASES 01! 33EDT 09/08/82 USE MANUAL DATED JUNE 1976 NAME OF DATA FILE? LIST ALL BUSES? ADJ. CONTRIBUTIONS ONLY? WIDE PAPER? ? APA69Z94, YES, YES, YES INPUT DATA BUS TO BUS =R-POS,NEG X-POS,NEG R-ZERO X-ZERO ° 1 ° 2 10440 0.0001 1 4 ° 0.8888 999 9999 ° 4 999 9999 ° 0.756 4 Z 0.3126 0.7784 0.558 2.377 7 17 0.0135 0.0636 0.0376 0.2214 17 28 ° 0.0001 ° -0.1166 18 28 ° 1.1667 ° 1.1083 ° 238 999 9999 ° 0.99 7 13 0.1781 0.4708 0.3642 1.5586 13 27 ° 0.0001 ° 0.3333 14 27 ° 0.4167 ° 0.0833 ° 27 999 9999 ° 0.5416 BUSES AT 69 KV 4 Z 13 17 BUSES AT 13.8 KV 1 BUSES AT 12.5 KV 18 BUSES AT 24.9 KV 14 INPUT DATA CORRECT? YES INPUT DATA LISTED IN OUTPUT? NO APPENDIX G GENERATOR VOLTAGE REGULATOR SPECIFICATIONS Generator Voltage Regulator (AVC) Specifications// Generator. Rating: 12.5 MVA 11.25 MW 0.9 p.f. 13.8 kV 520 A 60 Hz 720 RPA Parameters: X, = 0.9 p.u. (12.5 MVA base) Xq = 0.32 p.u. unsaturated xy = 0.28 p.u. saturated xy" = 0.25 p.u. unsaturated Ry = / ohm at 20/ °c 's Tao second Ty = second TY = second qd, 2 Wk” = 224, 567 lbs x ft", incl. turbine Exciter. Rating: V A RPM, direct coupled Field data: Rp = at i Tp = second Generator rotor current: At 13.8 kV open circuit: A At rated full load: A At 520 A steady state short circuit: A l/ The data given here should be checked and the missing data completed by IECO. G-1 Parallel operation: Up to three identical generators, each connected to unit transformers. Line compensation: Voltage shall be maintained constant at Wrangell, 43 circuit miles from powerhouse. Transformer and line data: Initially the system will operate at 69 kV, but the transformers will be reconnected to 138 kV operation at a later date. Transformer: MVA 138-69/13.8 kV Y gd/delta Impedance: % ( MVA base) No LTC Line: series impedance 14.9 + j36.9 otm/phase parallel admittance j708.4 x 107 *tho/phase. The unusually large admittance is due to the underwater cable section. - Performance Data. Compounding: In case of fault the voltage regulator shall maintain at least twice rated generator stator current. Ceiling of Excitation: the maximum voltage applied to the generator rotor shall be at least 400% of the voltage required at rated full load and °C rotor winding temperature, but shall not be less than the voltage required for compounding .L/ Response time: shall not exceed 0.1 second.1/ Reserve: 2/ = IZ The exciter has to be able to furnish the ceiling voltage at the specified response time as defined by the approximate standards. Should be specified if parallel thyristor bridges are used for excitation, in order to provide service should one branch fail. G-2 APPENDIX H GOVERNOR MODEL ACCORDING TO ESCHER WYSS GOVERNOR MODEL ACCORDING TO ESCHER WYSS 1) Escher Wyss' equation beittn. Regalado ZuG 1 (1 + Ths) Mp- ns o Tey 2 4 Tg + (4S) yy o o where - Ts = 0.1 sec Tr = 0-30 sec (use 6) o = 0-0.1 (use 0.04) 5 =0.3-0.8 (use 0.6) 2. Solution Tp = Tp = 6.0 1113 = T? = ToTr/e = 0.1 x 6/0.04 = 15.0 2DT = (Ts + (9 +8)Tp)/o = (0.1 + 0.64 x 6)/0.04 = 98.5 D = 98.5/2/(15)% = 12.72 T3 = T/(D + (D2 - 1)% = 0.152 Ty = T2/T3 = 15/0.152 = 98.35 therefore ZuG 1 1 + 6.0s Np - Ng 0.04 (1 + 98.35s)(1 + 0.152s) 3. @ Model P. ai K,(1 + sTa) i S aeeaamEnnaT ail ns (1 + sTj)(1 + sT3) Ky = megawatts rating : 1 : 1 - 12.5 x 1 = p.u. requlation 377 system base 0.04 sgh x Tog «= (0.0083 where Tq = 0 K2 = 3 Tw/2 = 1.23/2 = 0.62 APPENDIX I MODELING OF CHIPPER MOTOR FOR ALP SAWMILL AT WRANGELL MODELING OF CHIPPER MOTOR FOR ALP SAWMILL AT WRANGELL 1) 2) Assumptions Double-bar squirell-cage induction motor 350 Hp (ref. Alger, The Nature of Polyphase Induction Machines pp253-7) R X X X 1 1 2 3 Notation is that used in Whse Stability Program. xX Ro/S Ra/s Alger notation is the same m 2/ af except Rp=Ro, Xa=X3, and Ra=R3. At rated speed Ro/SDX3 and R3/SMX3 Use data for Reliance Electric 900rpm 350Hp motor full load locked rotor no load pull-up stator current(amp) 85 447 #427 ~~ torque (1b-ft) 2076 2404 2042 power factor (%) 82.6 rpm 888 From ref. above figure 8.10 on page 257 and infer the factor "m" to be 2, because the pull-up speed is low (0.06p.u.) and the locked rotor torque is low (1.158p.u.) Calculations from Full Load Impedance 2 from assumptions above Saecaanese + —i . —1_, arn) (1 - S¢1) Ro/S#1 R3/S#y Re/S#1 Pry T¢jp = 85 / -cos-!0.826 + j27 = 70.21 - j20.91 = 73.26/-16.6° therefore 2 Rp = .0133 x 350 x 746/(3 x 73.26 x(1 - .0133)) = 0.2170 starting resistance R, = 350 x 746. T = 350 x 746 x 2404 _ 32 3x 447¢ x mn" from ref. above, assuming m = 3, R, -Rp = eet Xo3 Xo = (.5044-.219)3¢41 a = 0.951 (Xq=) X3 = Xo(1 + Rp/(mXg))2 = 1.101 (Ra=) R3-= Rp(l + Rp/(mMXg) = 0.2335 (Rp=) Ro = mXg(1 + Rp/mXy) = 3.070 Calculation from Locked Rotor Impedance Zin = V/Iyp_ = 2300/(3)%(447) = ((Ry + Rg)? + (Xp + Xp + X5)2)% neglecting Xm Rs + jXg = 1/((1/3.070) + (1/.2335 + §1.101)) = 0.5022 + j0.8558 Assume Ry = 0.15a(somewhat less than R3) then (X; + X2 + X,)* = 23002/3 x 4772 - (.5022 + .15) = 2.8982, Xx, + Xp = 2.898 -.8558 = 2.042, assume that Xy = Xq = 2.042/2 = 1,021 4) Per Unit Calculations Xm = I¢1/In1 = 85/27 = 3.15 pu base impedance Zp = 2300/((3)% x 85) = 15.620 Ry = 0.15/15.62 = 0.00960 Xj = Xo = 1.021/15.62 = 0.0654 Ro = 3.070/15.62 = 0.1965 R3 = 0.2335/15.62 = 0.01495 X3 = 1.101/15.62 = 0.0705 -0096pu .0654pu .0705pu -1965pu -01495 R3/S 5) Calculation of Base MVA and H MVA = horsepower x 746 w/hp/eff x pf = 350 x 746/0.935 x 0.836 = 0.334 x 106 volt-amperes Energy of Synchronous Speed E = kdw2 = & x 82,435 1b/ft? x 1kg/2.21bs (12m/39.37 ft)? 450rev 2 rad min 60 rev sec = 3.865 x 108 joules H = E/VA = 3.865/0.334 = 11.57 seconds )