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Home My WebLink AboutVol4 AppendixC-EDonlin Creek Mine Power Supply Feasibility Study Nuvista Light & Power, Co. 301 Calista Ct. Anchorage, AK 99518-2038 Volume 4 Appendix C-E Final Report June 11, 2004 Bettine, LLC 1120 E. Huffman Rd. Pmb 343 Anchorage, AK 99501 907-336-2335 APPENDIX C-E Appendix C – Preliminary Transmission Line Design Documents 1. Sample Transmission Line Design Calculations 2. EMF Calculations 3. Transmission Line Alternatives, Pre-Design Cost Estimates by Dryden & LaRue, Inc. Appendix D – Power System Studies by EPS, Inc. Appendix E – Site Development, EarthWorks, Foundations, Bulk Fuel and Coal Storage 1. Coal-Fired Plant at Bethel 2. Combustion Turbine Plant at Bethel Appendix C – Preliminary Transmission Line Design Documents 1. Sample Transmission Line Design Calculations 2. EMF Calculations 3. Transmission Line Alternatives, Pre-Design Cost Estimates by Dryden & LaRue 1. Sample Transmission Line Design Calculations Summary of Maximum Horizontal Span for Specified Pole Class and Length Structure Type B Conductor: 954 ACSR - Cardinal Pole Height AGL= Pole Height Above Ground Line Wood Pole Extreme Wind Loading (100 mph) NESC Heavy Loading Pole Height AGL Pole Height AGL H1 H2C2C1C1H1H2C2 129 157 189 234 123 156 186 229 118 149 185 217 114 143 177 216 173 207 247 301 167 208 246 297 164 203 247 287 162 199 241 289 45' Pole 50' Pole 55' Pole 60' Pole 45' Pole 50' Pole55' Pole HS = 60' Pole ftftHS= Steel Pole Extreme Wind Loading (100 mph) NESC Heavy Loading Pole Height AGL Pole Height AGL C1 H1 H2C2H2C2(;1 H1 209 201 195 191 282 338 401 488 276 341 401 484 272 334 405 469 270 329 397 474 45' Pole 50' Pole 55' Pole 60' Pole 45' Pole 50' Pole55' PoleHS = 60' Pole It1ftHS= 253 252 243 237 302 299 299 290 370 364 349 349 Bethel to Donlin Mine 138 kV Transmission Line HSLlMIT954-3SP .mcxt MAX.UM HORIZONTAL SPAN UNDER NESC HEAVY LOADING St..1 Pol. - Structure Tv" B No Conductor Damoenina Zero Degree Line Angle No Embedment - Pioe Pile Foundation ASSUMPTIONS: t1 := 4300.lb tens.,n in OPGW 27AY/59ACS t2 := 9724.lb tens.,n in 954 ACSR line anglea := O'deg 1) W.,d - 4.096 pst (40 mph) 2) Ice - 0.5 inch radial 3) OCF - 2.5 for transverse wind loads 4) Pole Embedment - 0 ft. 5) Modulus of Rupture - 8000 psi 6) length Davit Arm - 72" 7) OPGW on Upper Davit Arm 8) OCF1-1.65 fortensk>n and wrtr.alloads i:= 1..4 k:= 1..4 PoleLengthl :=TopCirCk := C2 C1 H1 H2 PoleHe~h~ := PoleLengthi Circumference 6' from pole butt: C2 C1 H1 H2 '40.5.~ 42.in 43.5.in 45.in 45' Pole 50' Pole 55' Pole 60' Pole Ci:c6 := 1 Taperi,k:= (C~,k - TopCi'Ck)' PoleLen~1 - 6.ft '0.033 0.032 0.031 0.031 Taper = 1 HSlIMIT954-3SP .mcd 43.i1 45.in 46.5.in 48.in 45.5.in 47.511 49.5 .11 51. in 48.5-., 50.5-in 52-i1 54-in 0.034 0.034 0.033 0.032 0.035 0.035 0.035 0.034 0.037 0.037 0.036 0.035 Bethel to Donlin Mine 138 kV Transmission Line HSUMIT954-3SP .moo Circumference of Pole at Groudline: GmdCirci,k:= Taperi.k.PoleHeigh~ + TopCi~ C2 C1 H1 H2 '42.885 45.462 48.038 51.192 44.318 47.455 50.023 53.159 45.765 48.888 52.01 54.571 ,47.222 50.333 53.444 56.556 45' Pole 55' Pole 60' Pole 65' Pole . GmdCWc=I" Diameter at top and groundline GmdCi'ct,kT opCirCt 7t '7.958 8.594 in 9.231 ,9.868 GrndDiai.k :=TopDiak := K 13.651 14.471 15.291 16.295 14.107 15.105 15.923 16.921 14.568 15.561 16.555 17.371 15.031 16.022 17.012 18.002 . GmdDia=. TopDia =., SecOOn Modulus at Groundlne (.)3 151 k:= 7t. GmdDl8i k .- . . 32 '249.721 297.497 351.008 424.78 275.611 338.364 396.326 475.645 303.5 369.956 445.467 514.572 ..333.418 403.754 483.346 572.765 3s=In Fb:= 8000.~ in2 Modulus of Rupture Ultimate Moment Capacity at Groundline Mg:= FboS 5' 2.832 x 10 5 5 51.665 x 10 1.983 x 10 2.34 x 10 5 5 5 51.837 x 10 2.256 x 10 2.642 x 10 3.171 x 10 5 5 5 5 2.023 x 10 2.466 x 10 2.97 x 10 3.~3 x 10 Mg=Ilb.ft 5 5 5 5,2.223 x 10 2.692 x 10 3.222 x 10 3.818 x 10 Ib Moment due to Wind on Pole: Fw~:= 4.096.- ft2 MWPi.k:= F...,.(2. TopDiak + GmdDial.k)'(POJeHeigh~)2.~ ~ 2 HSUMIT954-3SP .moo B8:heI to Donlin Mine 138 kV Transmission Line HSUMIT954-3SP .mcxi '3406.014 3647.185 3888.356 4150.683 4269.854 4592.922 4890.269 5213.337 5245.793 5635.944 6026.094 6385.502 .6337.904 6801.476 7265.048 7728.621 Ib.ftMwp= 300 Foot Span Load Points 1) OHGW - 14.5ft from top 2) Cardinal (138kV) -5',2 x2' from top 3) Cardg,al (12.47kv), 3 x 8.5', from top Height of centroMj of moments on OPGW and 138 kV conductor Distance of Load ~ts from Top of Pole:1:= 1..4 Ipdjsfl := OPGW + Telephone Conductor Conductor x 2 Conductor x 3 Height of load points from ground: Iph~.1 :== PoleHeigh~ - Ipdis~30.5 50 43 36.5 35.5 55 48 41.5 40.5 60 53 46.5 45.5 65 58 51.5 1ftIpht= Load on conductor at each point Diameter of Conductor: m:= 1..2 Weight of conductor: wtcondm :=dm := OPGW Cardinal Weight of Ice on Conductor: kj:= 57.~ ft3 Radius of Ice Density of Ice:ri:= .5.w. ~ + ri)2-~)~-,kjwticem := 1t OJ .1, HSlIMIT954-3SP .mcxt Bethef to Donlin Mine 138 kV Transmission Line HSlIMIT954-3SP .moo ~_ (0.604 )~ wb - 1.055 ft Total Weight of Conductor:Wtd8 := wtK:em + wtcondm m --. -(O.918 )~ ~ - 2.284 ft Pc_,:= Fwtxt°(dm + 2orl)Force of wind on conductor: m -+ -(0.502)~ Pc - 0.75 ft Total Transverse Load on OPGW. 138 kV conductor an Underbuild: Pt:1 := (2.Pc) + 6.Pc 1 2 IbPt:1 = 5.502- ft Moment arm of total transverse load on OPGW and 138 kV conductor: 1(2-lpht), 1-PC + (1-lpht). 2-Pc + (2-lpht). 3-PC + (3.lpht), ..'Pc ]-- . 1 I. 2 I, 2 ." 2 ~ ~i ==[ 39.014 44.014 49.014 54.014 h1 =ft oct:= 2.5 oct1:= 1.65 groundline moment do to line angle C2 C1 H1 H2 '282 276 272 .270 45' 50' 55' 60' HS=ft .. HSlIMIT954-3SP.mcd Owrload Capacity Factor: Moment arm on davit arms: s:= 72.in 338 341 334 329 401 401 405 397 488 484 469 474 Pole Pole Pole Pole HSLI MIT ew954-3SP. mcdBethel to Donlin Mine 138 kV Transmission Une MAXIMUM HORIZONTAL SPAN UNDER Extreme Wind LOADING Steel Pole - Structure TYDe B No Conductor Damoenina Zero Degree Line Angle No Embedment - Pioe Pile Foundation ASSUMPTIONS: 1) Wmd - 25.6 pst (100 mph) 2) Ice - 0.0 inch radial 3) OCF - 1.0 for transverse wind loads 4) Pole Embedment - 0 ft. 5) Modulus of Rupture - 8000 psi 6) Length Davit Arm - 72" 7) OPGW on Upper Davit Arm8) OCF1-1.0 fortensK>n and vertical loads a:= O.deg t1 := 4300.lb tensK>n in OPGW 27AY/59ACS t2 := 9724.lb tension in 954 ACSR Line angle =- 1_4 T opCirCt := k:= 1..4 PoleLengthl := C2 C1 H1 H2 PoleHeigh~ := Polelengthj Circumference 6' from pole butt C2 C1 H1 H2 40.S.in 42.in 43.S.in 4S.in 45' Pole 50' Pole 55' Pole 60' Pole Circ6 := 0.033 0.034 0.035 0.037 0.032 0.034 0.035 0.037 0.031 0.033 0.035 0.036 0.031 0.032 0.034 0.035 Taper = HSLlMITew954--3SP .mcd1 43.in 45.in 46.5.in 48.in 45.5.in 47.5in 49.5-in 51.in 48.S.in SO.S.in S2.in 54.in HSLlMIT ew954-3SP .mcdBethel to Donlin Mine 138 kV Transmission Une Circumference of Pole at Groudline: GmdCircl,k:= Taperi.k.PoleHeigh~ + TopCi~ H1 H2C2C1 '42.885 45.462 48.038 51.192 44.318 47.455 50.023 53.159 45.765 48.888 52.01 54.571 47.222 50.333 53.444 56.556 45' Pole 55' Pole 60' Pole 65' Pole ~ GmdCirc = In Diameter at top and groundline: GmdCirCj,k n TopCi~GrndDiaj ,k:=TopDiak := 13.651 14.471 15.291 16.295 14.107 15.105 15.923 16.921 14.568 15.561 16.555 17.371 15.031 16.022 17.012 18.002 ~ GmdDia= ~ TopDia = in Section Modulus at Groundline: Sj k:= 7t .(GmdDiaj k)3.~ . . 32 35= Fb:= 8OO0.!!!- . 2 11 Modulus of Rupture: Mg:= Fb'SUltimate Moment Capacity at Groundline: 52.34 x 10 52.832 x 105 51.665 x 10 1.983 x 10 5 5 5 51.837 x 10 2.256 x 10 2.642 x 10 3.171 x 10 5 5 5 52.023 x 10 2.466 x 10 2.97 x 10 3.43 x 10 Ib.ft Mg= 5 5 5 52.223 x 10 2.692 x 10 3.222 x 10 3.818 x 10 Moment due to Wind on Pole: FwjOO:= 25.6.~ ft2 := FwWMt{2. TopDiak + GmdDial.k).(pOleHeigh~)2.~ Mwp k " HSLlMIT ew954-3SP .moo2 HSLlMIT ew9~3SP .mooBethel to Donlin Mine 138 kV Transmission Line 21287.586 22794.906 24302.225 25941.766 26686.586 28705.764 30564.18 32583.357 32786.207 35224.648 37663.09 39909.39 39611.897 42509.224 45406.552 48303.879 Ib.ft Mwp= 300 Foot Span load Points 1) OHGW-14.5ftfrom top 2) Cardinal (138kV) -5', 2', 8.5', from top Height of centroid of moments on OPGW and 138 kV conductor: Distance of Load Points from Top of Pole::= 1..4 Ipdis~ := OPGW Conductor Conductor Conductor Height of load points from ground: Iph~ ,I := PoleHeigh~ - Ipdis~30.5 50 43 36.5 35.5 55 48 41.5 40.5 60 53 46.5 .45.5 65 58 51.5 ftIpht= Load on conductor at each point Diameter of Conductor: m:= 1..2 Weight of conductor: wtcondm :=dm := OPGW Cardinal Weight of Ice on Conductor: id := 57.~ ft3 Density of Ice:Radius of Ice:ri:= .C.in 2 dm ~2T+ri) -dm 2 Kiwticem : = 7t HSLlMITew954-3SP .mcd3 Bethel to Donlin Mine 138 kV Transmission Line HSlIMITew954-3SP .mcxj ~=(~)~ Total Weight of Conductor:Wtct8 := wticem + wtcondm m --+ -(0.314 )~ ~- 1.229 ft Force of wind on conductor: ~ - (1.007 )~ Pc - 2.551 ft Total Transverse Load on OPGW. 138 kV conductor an Underbuild: Moment arm of total transwrse load on OPGW and 138 kV conductor . ]1 (2.lpht) j 1 "PC + (1.lpht),2.PC + (2.lpht), 3.Pc + (3.lpht)1 ..0.. .- . 1 . 2 . 2 . .~ Pt1~I:=[ '39.706 44.706 49.706 .54.706 hi =ft Overload Capacity Factor: Moment ann on davit anns: ocf:= 1.0 ocf1:= 1.0 s:= 72... groundline moment do to line angle 4 HSLlMITew954-3SP .moo HSlIMITew954--3SP .mcdBethel to Donlin Mine 138 kV Transmission Line H1 H2C2C1 209 253 302 370 201 252 299 364 195 243 299 349 191 237 290 349 45' Pole 50' Pole 55' Pole 60' Pole ftHS= HSLlMITew954-35P .mcd5 Bethel to Donlin Creek Mine 138 kV Transmission Line H-Frame Stnacture Summary of Maximum Horizontal Span for Specified Pole Class and Length Conductor: 954 ACSR - Cardinal Pole Height AGL= Pole Height Above Ground Line Wood Pole NESC Heavy Loading Extreme Wind Loading (100 mph) Pole Height AGL Pole Height AGL C2 C1 H2H1C2 (609 1605 589 ,,582 439 418 386 361 55' Pole 65' Pole 75' Pole 85' Pole 55' Pole 65' Pole 75' Pole 85' Pole HS=ft HS=ft Steel Pole NESC Beavy Loading Extreme Wind Loading (100 mph) Pole Height AGL Pole Height AGL C2 C1 H1 H2 C2 C1 H2H1 1017 1020 1003 1001 729 712 680 659 55' Pole 65' Pole 75' Pole 85' Pole 55' Pole 65' Pole 75' Pole 85' Pole HS=1ft HS=ft 10/3/2003 Summaryhframehor .span I C1 753 740 740 725 H1 917 892 857 888 H2 1067 1063 1077 1043 556 525 505 473 689 648 598 602 812 787 776 725 1250 1238 1248 1235 1515 1486 1440 1501 1758 1764 1797 1755 909 879 867 835 1115 1070 1012 1037 1304 1284 1287 1230 Bethel to Donlin Creek Mine 138 kV Transmission line H-Frame Structure - Maximum Horizontal Soan Extreme Wind Loadina Steel Poles ASSUMPTIONS: Zero Degree Line Angle Load Points 1) OHGW - 1 ft from top 2) Cardinal (138kV) - 6', 6', 6', from top 1) Wind - 25.6 psf (100 mph) 2) NESC Heavy Ice - O. inch radial3) OCF - 1.0 for b"ansverse wind loads 4) Pole Embedment - 0 ft. 5) Modulus of Rupture - 8000 psi 6) Length Unsupported CrossArm - 6'6" 7) OCF1- 1.0 for tension loads t1 := 4300.lb tension in OPGW 27AY/59ACS t2 := 9724.lb tension in 795 ACSR Une anglea. := O.deg i:= 1..4 k:= 1..4 PoleLengthj :=TopCirCt := C1 H1 H2 H4 PoleHeigh~ := PoleLengthj Circumference 6' from pole butt C1 H1 H2 H4 51.in 52.5.in 54.in 55.in 63.5.in 65.in 66.5.in 68.in 70' Pole 75' Pole SO' Pole go' Pole Circe := '0.031 0.033 0.034 0.037 0.031 0.032 0.034 0.036 0.03 0.032 0.033 0.035 .0.028 0.029 0.03 0.033 Taper = 13/8f2O03 HframeHSLlMITewSP.mcd 54.in 55.5.in 57.in 58.5.in 57.in 59.in SO.in 61.5.in Bethel to Donlin Creek Mine 138 kV Transmission line Circumference of Pole at Groundline: GmdCirci,k:= Taperl,k.PoleHeigh~ + TopCirCt( C1 H1 H2 H4 53.25 54.717 56.189 57 70' Pole 75' Pole 80' Pole go' Pole . GmdCirc=In Diameter at top and groundline: GmdCirCl,kGmdDiai,k := K 16.95 17.935 18.92 21.063 17.417 18.4 19.555 21.521 17.886 18.866 19.847 21.981 18.144 19.292 20.27 22.395 . GmdDla=In Section Modulus at Groundline: Sj,k:= X.(GmdDiaj,k)3.~ 478.089 566.353 664.863 518.712 611.55 734.164 561.705 659266 767.517 586.374 704.891 817.58 917.425 978.494 1042.6 1102.744 3s=in Fb:= 8000.~ in2 Modulus of Rupture: Ultimate Moment Capacity at Groundline:Mg:= FboS 5 5 5 53.187 x 10 3.776x10 4.432x10 6.116x10 5 5 5 53.458 x 10 4.077 x 10 4.894 x 10 6.523 x 10 Ib.ftM = 9 5 5 5 53.745 x 10 4.395 x 10 5.117 x 10 6.951 x 10 5 5 5 53.909 x 10 4.699 x 10 5.451 x 10 7.352 x 10 2 HframeHSLlMITewSP .mcd ~ 56.344 57.804 59.27 60.607 59.438 61.435 62.351 63.679 66.172 67.609 69.054 70.357 Bethel to Donlin Creek Mine 138 kV Transmission Une 75516.368 87604.417 63411.22 73723.338 67345.176 78581.023 59477.263 69211.641 Ib.ftMwp=79813.537 84942.589 90071.642 1.007 x 105 5 5 5 5 1.018 x 10 1.087 x 10 1.152 x 10 1.287 x 10 Height of centrokJ of moments on OPGW and 138 kV conductor: Distance of Load Points from Top of Pole:1:= 1..4 Ipdjsft := OPGW Conductor Conductor Conductor Height of load points from ground: Iph~,1 := PoleHeigh~ - Ipdisft 74 79 84 ,94 4tIpht= Load on conductor at each point: Diameter of Conductor: m:~ 1..2 Weight of conductor: wtcondm :=dm := OPGW Cardinal Weight of Ice on Conductor: kj:= 57.~ ft3 Density of Ice:Radius of Ice:ri := O.O.in ~ wticem:= ~{( ~ + ~2 - (~ )2J.iI --+ -(0 )~ wtk:e - 0 ft HframeHSLlMITewSP .mcd33/6f2O03 68 73 78 88 68 73 78 88 68 73 78 88 Bethel to Donlin Creek Mine 138 kV Transmission Line Total Weight of Conductor:Wtotal := wticem + wtcondm m --+ =(0.314)~ ~ 1.229 ft Pcm:= Fwind.(dm + 2.ri)Force of wind on conductor: -. =(1.007 )~ Pc 2.551 ft '74 79 84- .94 Ipht=ft. Total Transverse Load on OPGW and 138 kV conductor: ~ := Pc + 3.Pc 1 2 Moment arm of total transverse load on OPGW and 138 kV conductor: '68.698 73.698 78.698 ,88.698 h1 =it OVerload Capacity Factor:ocf:= 1.0 ocf1:= 1.0 groundline moment do to line angle 4 HframeHSLtMITewSP.mcd3/6f2003 68 73 78 88 68 73 78 88 68 73 78 88 Bethel to Donlin Creek Mine 138 kV Transmission Line Maximum Horizontal Spans: Ma - ocf.u H~,k:= '.k "'WPi.k-MI,I"ocf1 (ocf"~"htJ 2 C1 H1 H2 H4 '871 1056 1263 1802 867 1046 1287 1769 865 1040 1237 1744 753 940 1119 1579 70' Pole ft 75' Pole SO' Pole 90' Pole Maximum Horizontal Span HS= HframeHSLlMIT ewSP. mcd5316/2003 Bethel to Donlin Creek Mine 138 kV Transmission Line H-Frame Structure. Maximum Horizontal SDan NESC Heavv Loadina Steel Poles ASSUMPTIONS: Zero Degree Line Angle Load Poin1s 1) OHGW - -4ft from top 2) Cardinal (138kV) - 2' . 2', 2', from top 1) Wind - 4.096 pst (40 mph) 2) NESC Heavy Ice - 0.5 inch radial 3) OCF - 2.5 for transverse wind loads 4) Pole Embedment - 0 ft. 5) Modulus of Rupture - 8000 psi 6) Length Unsupported CrossArm - 6'6" 7) OCF1- 1.65 for tension loads t1 := 4300.lb tension in OPGW 27AY/59ACS t2 := 9724.lb tension in 795 ACSR Une anglea := O.deg i:= 1..4 TopCir~ := k:= 1..4 PoleLengthj := C1 H1 H2 H4 PoleHeigh~ := PoleLengthj Circumference 6' from pole butt: C1 H1 H2 H4 63.5.in 65.in 66.5.in 68.in 51.in 52.5.in 54.in 55.in 70' Pole 75' Pole 80' Pole 90' Pole Circe := '0.031 0.033 0.034 0.037 0.031 0.032 0.034 0.036 0.03 0.032 0.033 0.035 0.028 0.029 0.03 0.033 Taper = HframeHSLlMITSP .mcd13I6f2003 54.in 55.5.in 57.in 58.5.in 57.in 59.in 60.in 61.5.in Bethel to Donlin Creek Mine 138 kV Transmission LIne Circumference of Pole at Groundline: GmdCirCi,k:= Taperl,k"PoleHejgh1j + TopCi~ C1 H1 H2 H4 53.25 56.344 59.438 66.172 54.717 57.804 61.435 67.609 56.189 59.27 62.351 69.054 57 60.607 63.679 70.357 70' Pole 75' Pole 80' Pole 90' Pole . GrndCirc =In Diameter at top and groundline: GmdCirCj .k T opCirCt K 8.594 9231 . 9.868 11.141 GrndDial,k := TopDiak:=x 16.95 17.935 18.92 21.063 17.417 18.4 19.555 21.521 17.886 18.866 19.847 21.981 18.144 19.292 2027 22.395 ~ GmdDia =~ TopDia = InIn Section Modulus at Groundline: (.)3 1Sj k:= x. GrndDlal k .- , , 32 '478.089 566.353 664.863 518.712 611.55 734.164 561.705 659266 767.517 .586.374 704.891 817.58 917.425 978.494 1042.6 1102.744 3s=In Fb:= 8OO0.~ in2 Modulus of Rupture: Ultimate Moment Capacity at Groundline:Mg:= Fb"S 5 5 5 53.187 x 10 3.776x10 4.432x10 6.116x10 5 5 5 53.458 x 10 4.077 x 10 4.894 x 10 6.523 x 10 Ib.ftMg=5 5 5 53.745 x 10 4.395 x 10 5.117 x 10 6.951 x 10 5 5 5 53.909 x 10 4.699 x 10 5.451 x 10 7.352 x 10 23mf2OO3 HframeHSLlMITSP. mcd Bethel to Donlin Creek Mine 138 kV Transmission Une 9516.362 10145.795 10775.228 12082.619 11073.863 11795.734 12572.964 14016.707 12770.166 13590.814 14411.463 16115.404 16281.169 17396.963 18434.18 20587.192 Ib.ftMwp= Height of centroid of moments on OPGW and 138 kV conductor: Distance of Load Points from Top of Pole::= 1..4 Ipdisft := OPGW Conductor Conductor Conductor Height of load points from ground Iph\, I := PoleHeigh\ - Ipdisft 74 79 84 94 Ipht= Load on conductor at each point: Weight of conductor: wtcondm := Diameter of Conductor: m:= 1..2 dm:= OPGW Cardinal Weight of Ice on Conductor: Ib ft3 Density of Ice:Radius of Ice:kt := 57.ri := O.5.in wticem:= x.[( ~ + 1t)2 - (~j].kI ~=(O.604 )~ 1.055 ft HframeHSLlMITSP. mcd33mf2003 68 73 78 88 68 73 78 88 68 73 78 88 Bethel to Donlin Creek Mine 138 kV Transmission Line Wt«al := wticem + wtcondmTotal Weight of Conductor: m --+- =(0.918)~ ~ 2284 ft: Pc := FwW1d-(dm + 2.ri}Force of wind on conductor: m ~ = (0.502 )~ Pc 0.75 ft 74 79 84 94 ItIpht= Total Transverse Load on OPGW and 138 kV conductor: ~ := ~ + 3.Pc 1 2 Moment arm of total transverse load on OPGW and 138 kV conductor: '69.096 74.096 79.096 89.096 fth1 = oct:= 2.5 ocf1:= 1.65Overload Capacity Factor: ground line moment do to line angleMj HframeHSLlM ITSP . mod43/6f2003 68 73 78 88 68 73 78 88 68 73 78 88 Bethel to Donlin Creek Mine 138 kV Transmission Une Maximum Horizontal Spans: ~ - ocf.u- HSt,t:= ,k "'WPI,k-~,I'ocf1 (~~ 2 H2 H4C1H1 1241 1482 1752 2447 1248 1484 1797 2423 1259 1491 1749 2407 1143 1392 1629 2231 70' Pole 75' Poleft 80' Pole 90' Pole Maximum Horizontal SpanHS= HframeHSLlMITSP. moo53I6f2003 Bethel to Donlin Creek 138 kV Transmission Line SUMMARY - POLE EMBEDMENT DEPTH H -FRAME S TR U CTURE NESC LOADING Soil Classification - Very Poor, Assumes Lateral Soil Bearing Pressure of 50 psf 600 Ft Span C2 C1 H1 H2 13.138 12.711 12.322 11.965 12.779 12.322 11.965 11.637 12.447 12.081 11.69 11.334 12.199 11.798 11.432 11.098 70' (55) Pole SO' (65) Pole go' (75) Pole 1 00' (85) Pole ft embedment depth in feed= 800 Ft Span C2 C1 H1 H2 14.722 14.239 13.8 13.397 14.316 13.8 13.397 13.027 13.942 13.528 13.087 12.685 13.662 13.209 12.796 12.42 70' (55) Pole 80' (65) Pole 90' (75) Pole 1 00' (85) Pole embedment depth in feeft d= 1000 Ft Span C2 C1 H1 H2 15.985 15.457 14.977 14.538 15.542 14.977 14.538 14.134 15.133 14.68 14.199 13.761 14.827 14.332 13.882 13.471 70' (55) Pole eo' (65) Pole 90' (75) Pole 100' (85) Pole embedment depth in feeftd= Soil Classification - Poor, Assumes Lateral Soil Bearing Pressure of 100 psf 600 Ft Span C2 C1 H1 H2 10.546 10.208 9.9 9.617 10.262 9.9 9.617 9.357 9.999 9.709 9.399 9.116 9.803 9.484 9.194 8.929 70' (55) Pole 80' (65) Pole 90' (75) Pole 100' (85) Pole ft embedment depth in feed= 13/6/2003 hframe embedment Bethel to Donlin Creek 138 kV Transmission Line 800 Ft Span H2C2C1H1 11.637 11.262 10.919 10.606 11.322 10.919 10.606 10.317 11.03 10.707 10.364 10.05 10.812 10.459 10.137 9.843 70' (55) Pole 80' (65) Pole 90' (75) Pole 100' (85) Pole embedment depth in feeft d= 1000 Ft Span H2C2C1H1 12.473 12.069 11.701 11.363 12.134 11.701 11.363 11.053 11.82 11.472 11.103 10.766 11.585 11.205 10.859 10.542 70' (55) Pole 80' (65) Pole 90' (75) Pole 100' (85) Pole ft embedment depth in fd= Soil Classification - Average, Assumes Lateral Soil Bearing Pressure of200 psf 600 Ft Span H2C2C1H1 8.328 8.064 7.824 7.603 8.107 7.824 7.603 7.4 7.902 7.675 7.433 7.212 7.748 7.5 7273 7.065 70' (55) Pole 80' (55) Pole 90' (75) Pole 100' (85) Pole embedment depth in feeftd= 800 Ft Span H1 H2C2C1 9.04 8.799 8.575 8.408 70' (55) Pole SO' (65) Pole go' (75) Pole 100' (85) Pole embedment depth in feeft d= 1000 Ft Span C2 C1 H1 H2 9.563 9.307 9.07 8.893 70' (55) Pole 80' (65) Pole 90' (75) Pole 1 00' (85) Pole embedment depth in feeftd= 23/6/2003 hftame embedment 8.753 8.49 8.328 8.137 8.49 825 8.064 7.89 8.25 8.029 7.824 7.664 9.258 8.98 8.808 8.606 8.98 8.725 8.528 8.344 8.725 8.49 8.273 8.104 Bethel to Donlin Creek 138 kV Transmission Line EXTREME WIND LOADING Soil Classification - Very Poor, Assumes Soil Bearing Pressure of 50 psf 600 Ft Span C2 C1 H1 H2 19.755 19.091 18.488 17.937 19.197 18.488 17.937 17.43 18.683 18.115 17.511 16.962 18.299 17.678 17.114 16.599 70' (55) Pole 80' (65) Pole 90' (75) Pole 1 00' (85) Pole embedment depth in feeftd= 800 Ft Span C2 C1 H1 H2 21.905 21.163 20.488 19.872 21.282 20.488 19.872 19.305 20.706 20.071 19.396 18.783 20.277 19.583 18.952 18.377 70' (55) Pole eo' (65) Pole go' (75) Pole 1 00' (85) Pole embedment depth in feeIt: d= 1000 Ft Span C2 C1 H1 H2 23.565 22.761 22.031 21.363 22.889 22.031 21.363 20.751 22.267 21.579 20.849 20.186 21.802 21.051 20.369 19.747 70' (55) Pole SO' (65) Pole go' (75) Pole 100' (85) Pole embedment depth in fee ftd= Soil Classification - Poor, Assumes Soil Bearing Pressure of 100 psf 600 Ft Span H2C2C1H1 15.436 14.928 14.466 14.042 15.009 14.466 14.042 13.653 14.615 14.179 13.716 13.293 14.32 13.844 13.41 13.014 70' (55) Pole 80' (65) Pole 90' (75) Pole 1 00' (85) Pole embedment depth in feeftd= 33/6/2003 hframe embedment Bethel to Donlin Creek 138 kV Transmission Line 800 Ft Span C2 C1 H1 H2 16.814 16.257 15.75 15.286 16.346 15.75 15.286 14.859 15.914 15.436 14.928 14.466 15.591 15.068 14.594 14.159 70' (55) Pole 80' (65) Pole 90' (75) Pole 100' (85) Pole ft embedment depth in fee" d= 1000 Ft Span C2 C1 H1 H2 18.412 17.797 17.238 16.727 17.896 17.238 16.727 16.257 17.419 16.892 16.333 15.823 17.063 16.487 15.964 15.486 70' (55) Pole 80' (65) Pole 00' (75) Pole 1 00' (85) Pole ftd=embedment depth in f Soil Classification - Average, Assumes Soil Bearing Pressure of200 psf 600 Ft Span C2 C1 H1 H2 12.051 11.661 11.306 10.98 11.724 11.306 10.98 10.681 11.421 11.086 10.729 10.404 11.194 10.828 10.494 10.189 70' (55) Pole SO' (65) Pole 00' (75) Pole 100' (85) Pole embedment depth in feeftd= 800 Ft Span C2 C1 H1 H2 13.444 13.006 12.607 12.241 13.076 12.607 12.241 11.905 12.736 12.36 11.959 11.594 12.481 12.07 11.695 11.353 70' (55) Pole SO' (65) Pole 00' (75) Pole 100' (85) Pole embedment depth in feeft d= 1000 Ft Span C2 C1 H1 H2 14.542 14.065 13.631 13234 14.142 13.631 13.234 12.869 13.772 13.363 12.928 12.531 13.495 13.048 12.641 12.269 70' (55) Pole 80' (65) Pole 90' (75) Pole 100' (85) Pole embedment depth in fee"ftd= 43/6/2003 hftame embedment Bethel to Donlin Creek Mine 138 kV Transmission line MAXIMUM HORIZONTAL SPAN LIMITED BY FOUNDATION STRENGTH H-Frame UNDER Extreme Wind LOADING Zero Degree Une Angle ASSUMPTIONS:Load Points 1) OHGW - -4ft from top 2) Cardinal (138kV) - 2', 2', 2', from top t1 := 4400.lbtensaon on ut"(..iW t2:= 10397 .Ib tension in 954 ACSR Une Angle a := U 1) Wind - 25.6 psf (100 mph) 2) Ice - 0.0 inch radial 3) OCF - 1.5 for b"ansverse wind loads 4) Pole Embedment 5) Modulus of Rupture - 8000 psi 6) Length Davit Arm - 72" 7) OPGW on lower Davit Arm 8) OCF1- 1.5 for tension and vertical loads TopClr~ :=PoleLengthj := C2 C1 H1 H2 PoleHeigh~ := PoleLengthj - 15ft Circumference 6' from pole butt: C2 C1 H1 H2 54.in 57in 59.5.in 52.in 57.in ' 60.in 63.in 65.5.in, 1 48.in 50.5.in 53in 55.in 51.in 54.in 56.in 58.5.in 70' (55) Pole 80' (65) Pole 90' (75) Pole 100' (85) Pole Circ6 := Taperi,k:= (Circ6i,k - TopCir~).pOi8lengthi - 6.ft HSfondew1 hframe. mcd13/612003 Bethel to Donlin Creek Mine 138 kV Transmission Line 0.03 0.029 0.028 0.027 Taper = Circumference of Pole at Groudline: GmdCircj,k:= Taperi,k.PoleHeigh~ + TopCir~ H1 H2C1C2 70' (55) Pole 80' (65) Pole go' (75) Pole 100' (85) Pole ~ GrndCirc = Diameter at top and groundline: GmdCirCj,k T opCirCt( x 7.958 8.594 In 9231 ! ,9.868, GmdDiaj,k :=TopDiak := 14249 15.16 16.07 16.98 15.087 16.143 17.06 17.976 15.915 16.836 17.899 18.962 16.593 17.661 18.729 19.798 . GrndDia=~ T opDia = In Section Modulus at Groundline: Si,k:= X.(GrndDiai,k)3.-i2 284.043 342.023 407.4 480.619 337.169 413.039 487.431 570.259 395.786 468.534 562.995 669.367 448.492 540.822 645.027 761.824 3s=in Ib in- Fb:= 8000Modulus of Rupture: 2 Ultimate Moment Capacity at Groundline:Mg:= Fb"S 5 52.716 x 10 3.204 x 10 5 5325 x 10 3.802 x 10 51.894 x 10 228 x 105 5 52.248 x 10 2.754 x 10 Ilb.ftMg=5 5 5 5 2.639 x 10 3.124 x 10 3.753 x 10 4.462 x 10 5 5 5 52.99 x 10 3.605 x 10 4.3 x 10 5.079 x 10 HSfondew1 hframe. moo2316/2003 0.031 0.03 0.029 0.028 0.033 0.032 0.03 0.029 0.034 0.033 0.032 0.031 Bethel to Donlin Creek Mine 138 kV Transmission line "32443.956 34792.332 37140.707 39489.082 46573.325 50072.382 53361.431 56650.48 63661.977 68050.106 72722.441 77394.775 .83510.066 89525.4 95540.7351.016x105 Ib.ftMwp= Height of centroid of moments on OPGW and 138 kV conductor: Distance of Load Points from Top of Pole::= 1..4 Ipdisft "= OPGW Conductor Conductor Conductor Height of load points from ground: Iph\,1 := PoleHeigh\ - Ipdisft 59 69 79 89 Ipht= ~ Load on conductor at each point: Diameter of Conductor: m:= 1..2 Weight of conductor: wtcondm := dm := OPGW Cardinal Weight of Ice on Conductor: kt:= 57.~ ft3 Density of Ice:n := u.u.inr"(CJUI~ UI I~; )2 J 2] dm 2) .id dm . -+n2wtiC8rn := x 33/6f2003 HSfondew1 hframe. mcd 53 63 73 83 53 63 73 83 53' 63 73 83.1 Bethel to Donlin Creek Mine 138 kV Transmission Line ~=(~)~ Total Weight of Conductor:w~ := wticem + wtcondm m --. =(0.314)~ w.., 1.229 ft := Fwjnd-(dm + 2-")Force of wind on conductor:Pc m -+ =(1.007)~ Pc 2.551 ft 59 69 79 ,89 70' (55) Pole 80' (65) Pole 90' (75) Pole 1 00' (85) Pole Ipht=ft Total Transverse Load on OPGWand 138 kV conductor: ~ := ~. + 3.~ 2 Moment arm of total transverse load on OPGW and 138 kV conductor: , 53,698 63.698 73.698 .83.698 70' (55) Pole 80' (65) Pole go' (75) Pole 100' (85) Pole h1 =1ft Circ6"k in 12- ft B. k:= I, 31'6/2003 4 HSfondew1 hframe. mcd 53 63 73 83 53 63 73 83 53 63 73 83 Bethel to Donlin Creek Mine 138 kV Transmission LIne H2C2C1H1 4 4.25 4.5 4.75 4.208 4.5 4.75 5 4.417 4.667 4.958 5.25 .4.583 4.875 5.167 5.458 70' (55) Pole 80' (65) Pole 90' (75) Pole 100' (85) Pole ftB= Soil Classification - VerY Poor. Assumes Soil BearinG Pressure of 60 psf 600 Foot Span d:= 18ft estimated embedment depth soil bearing pressure 81 = 3OOlbft-1 F = 2598.41b '5.067 4.816 4.589 .4.422 A=~.k:= 2.34 F S1.Bt.k At,k 2 1+~,k:= h1 1 4.38.A~,.k C1 H1 H2C2 19.755 19.091 18.488 17.937 19.197 18.488 17.937 17.43 18.683 18.115 17.511 16.962 18.299 17.678 17.114 16.599 70' (55) Pole 80' (65) Pole go' (75) Pole 1 00' (85) Pole embedment depth in feetft d~ 800 Foot Span (~1.800ft)F:=F = 3464.533lb 2 estimated embedment depthd := 20ft p:~ 50 ~ ~ soil bearing pressure HSfondew1 hframe. mcd53/6f2003 4.769 4.504 4.343 4.157 4.504 4.267 4.088 3.923 4.267 4.054 3.86 3.713 Bethel to Donlin Creek Mine 138 kV Transmission Line 81 = 333.333 Ib ft-1 6.08 5.723 5.405 5.12 5.779 5.405 5.12 4.864 5.507 5212 4.905 4.633 ,5.306 4.989 4.707 4.456 4..k := 2.34. - ~, ...~ - A= F At.k 2 1+~.k:= C2 C1 H1 H2 21.905 21.163 20.488 19.872 21.282 20.488 19.872 19.305 20.706 20.071 19.396 18.783 ,20277 19.583 18.952 18.377 70' (55) Pole 80' (65) Pole go' (75) Pole 1 00' (85) Pole ft embedment depth in feetd- Ib P := 50 ~ d 51 := P3 soil bearing pressure 81 = 366.667Ibft-1 6.909 6.567 6.258 6.03 4.k :=2.34. - , r"'j. ~.. - A= F At.k 2 1+~.k:- h1 4.36.--!- At,k.1ft C2 C1 H1 H2 23.565 22.761 22.031 21.363 22.889 22.031 21.363 20.751 22.267 21.579 20.849 20.186 21.802 21.051 20.369 19.747 70' (55) Pole SO' (65) Pole 90' (75) Pole 100' (85) Pole embedment depth in feetftd= 3/6/2003 6 HSfondew1 hframe. mcd 6.503 6.142 5.922 5.669 6.142 5.818 5.574 5.349 5.818 5.528 5264 5.063 Bethel to Donlin Creek Mine 138 kV Transmission Line Soil Classification - Poor. Assumes Soil Bearina Pressure of 100 Dsf 600 Foot Span d:= 14ft estimated embedment depth p:= 100~ ~ soil bearing pressure 81 = 466.667Ibft-1 (~1.60Oft)F:= .,F = 2598.41b 2 '3.257 3.066 2.895 2.743 3.096 2.895 2.743 2.606 2.95 2.792 2.628 2.482 .2.843 2.673 2.522 2.387 ~,k:= 2.34 A= F S1.B1.k A;.k 2 1+~.k:= C2 C1 H1 H2 15.436 14.928 14.466 14.042 15.009 14.466 14.042 13.653 14.615 14.179 13.716 13293 14.32 13.844 13.41 13.014 70' (55) Pole 80' (65) Pole 90' (75) Pole 100' (85) Pole ft embedment depth in feetd= 800 Foot Span (~1.800ft)F:=F = 3464.533lb 2 d := 16ft estimated embedment depth p:= 100~ ~ soil bearing pressure d 51 := P3 51 = 533.333lbft-1 3.8 3.577 3.378 3.2 3.612 3.378 32 3.04 3.4042 3.257 3.066 2.895 3.317 3.118 2.942 2.785 A;,k:= 2.34 A= F S1.~.k ~OO3 7 HSfondew1 hframe. mcd Bethel to Donlin Creek Mine 138 kV Transmission Une At.k 2 1+~.k:= C2 01 H1 H2 16.814 16.257 15.75 15.286 16.346 15.75 15.286 14.859 15.914 15.436 14.928 14.466 15.591 15.068 14.594 14.159 70' (55) Pole 80' (65) Pole 90' (75) Pole 100' (85) Pole ft embedment depth in feet d- p:= 100~ ~ soil bearing pressure d 81 := P3 51 = 566.667Ib ft-1 ~.k:= 2.34 A= F 'S1'B.,k At.k 2 1+~.k:= C2 C1 H1 H2 18.412 17.797 17.238 16.727 17.896 17238 16.727 16.257 17.419 16.892 16.333 15.823 17.063 16.487 15.964 15.486 70' (55) Pole 80' (65) Pole 90' (75) Pole 1 00' (85) Pole ft embedment depth in ftd= Soil Classification - Average. Assumes Soil Bearing Pressure of 200 Dsf 600 Foot Span d:= 11 ft estimated embedment depth p:= 200~ ~ soil bearing pressure 3I6f2003 8 HSfonde.v1 hframe. mcd Bethel to Donlin Creek Mine 138 kV Transmission Line S1 = 733.333Ibft-1 (~1.60Oft)F:= .F = 2598.4Ib 2 '2."073 1.951 1.843 1.746 1.97 1.843 1.746 1.658 1.877 1.777 1.672 1.579 1.809 1.701 1.605 1.519 At,k:= 2.34 A= F 51-s. ,k At.k 2 1+q,k:= h114 . 36 °A -:-- k ° 1 ft I, . C2 C1 H1 H2 12.051 11.661 11.306 10.98 11.724 11.306 10.98 10.681 11.421 11.086 10.729 10.404 11.194 10.828 10.494 10.189 70' (55) Pole 80' (65) Pole 90' (75) Pole 1 00' (85) Pole ft embedment depth in feetd= 800 Foot Span (~1.800ft)F:=F = 3464.533Ib 2 d:= 12ft estimated embedment depth Ib ft2 soil bearing pressurep := 200 d 81 := P3 S1 = 800 Ib ft-1 2.533 2.384 2252 2.133 2.408 2252 2.133 2.027 2.294 2.172 2.044 1.93 2211 2.079 1.961 1.857 4.k :=2.34. '"'I, ~~ - A= F At.k 2 1+q,k:= 3/6/2003 9 HSfondew1 hframe. mcd Bethel to Donlin Creek Mine 138 kV Transmission Une C2 C1 H1 H2 13.444 13.006 12.607 12241 13.076 12.607 12.241 11.905 12.736 12.36 11.959 11.594 12.481 12.07 11.695 11.353 70' (55) Pole SO' (65) Pole go' (75) Pole 100' (85) Pole embedment depth in feetft d= p:= 200~ r soil bearing pressure 81 = 866.667Ibft-1 2.923 2.751 2.598 2.462 2.778 2.598 2.462 2.339 2.647 2.506 2.358 2.227 .2.551 2.399 2.263 2.142 At,k:= 2.34. , A= F At.k 2 1+dt,k:= h1 1 4.36.~~;m C2 C1 H1 H2 14.542 14.065 13.631 13.234 14.142 13.631 13.234 12.869 13.772 13.363 12.928 12.531 13.495 13.048 12.641 12.269 70' (55) Pole 80' (65) Pole go' (75) Pole 1 00' (85) Pole ft embedment depth in feetd= 3I6f2OO3 10 HSfondew1 hframe. mcd GALLOPBethnd. mcdBethel to Donlin Creek 138 kV Transmission Line Sinale LOOD GalioD Calculations 300, 400, SOO, 600 ft spans No-Dampening Assumptions: Conductor is at 32°F and is covered with 0.5" ice. 25 mph Wind Wind load on conductor is 1.6 Ibs per sq. foot: Fw:= 1.6.~ ,.2 Weight of conductor: wtcondk := Mallard Cardinal Weight of Ice on Conductor: kj:= 57.~ ft3 Density of Ice: Radius of Ice:ri := O.S.in ~ )'].kI ~ ~2 2 + It) -wti~:= x ~=(1.004 )~ 1.055 ft Total Weight of Conductor:Wtotal := wtic8k + wtcondk k Mallard Cardinal --+ -(2239)~ ~ - 2284 ft Pc := Fw.(dt + 2.ri)Force of wind on conductor: k Mallard Cardinal -+- -(0282 )~ Pc - 0.293 ft 2/25/20031 Diameter of Conductor: .. k:= 1..2 ~:= Mallard Cardinal GALLOPBethnd. mcdBethel to Donlin Creek 138 kV Transmission Line +k:= aIan( ~. ~(7.177 )+ = 7.307 deg Swing angle: Final sag of conductor at 32°F with 1/2" ice: Sag2k := . 500 ft Span ~ Sag3k:= ,600 ft Span ~ ~ S8Qk:= .300 ft Span Sag1k:=' 400 ft Span 0 0 ~ ~ Mallard Cardinal 1. 300 FOOT SPAN Parameters of Ussajous Ellipses: Mk:= 1.25. Sa~ + 1 where M-Major Axis Lissajous ellipse in feet Bk := 0.25.Sagk See Figure page 4 °k:= 0.4.Mk where O-Minor Axis Lissajous ellipse in feet tk.1.S - deg [~~~] [:~~J +kConductor Mk= ~ ~~ ~ Dt= ~ ~ ~= ~ . deg [~~ [!~ Mallard Cardinal 2. 400 FOOT SPAN Parameters of Ussajous Ellipses: Mk:= 1.25. Sag 1 k + 1 where M=Major Axis Lissajous ellipse in feet Bk:= 0.25 .Sag 1 k See Figure page 4 Dk:= 0.4.Mk where D=MinorAxis Lissajous ellipse in feet +t.1.5 deg [~~~ ~~ +kConductor Dt= ~ [!!J Mk= ~ Bt= Q:!) ~ Sag1k = ~ ... deg [I~ [!~ Mallard Cardinal 2f1:5f20032 GALLOPBethnd.mcdBethel to Donlin Creek 138 kV Transmission Line 3. 500 FOOT SPAN Parameters of Lissajous Ellipses: Mk:= 1.25.Sag2k + 1 where M=Major Axis Ussajous ellipse in feet Bk:= 0.25.Sag2k See Figure page 4 Dk:= 0.4.Mk where D=Minor Axis Ussajous ellipse in feet +kConductor~= ~ ~ Dk= ~ Sag2k= ~ Q..?J Mk= ~ ~ . deg ~~ [!~ Mallard Cardinal 2. 600 FOOT SPAN Parameters of Lissajous Ellipses: Mk:= 1.25. Sag3k + 1 where M-Major Axis Lissajous ellipse in feet Bk:= 0.25.Sag3k See Figure page 4 Dk:= 0.4.Mk where D=Minor Axis Lissajous ellipse in feet +t.1.5 - deg +k-= deg [~~ [!~ Conductor Mk= Bk= [J~ ~ ~~~ D,= ~ ~ Sag~= ~ ~ Mallard Cardinal 2/25/20033 GALLOPBethnd. mcdBethel to Donlin Creek 138 kV Transmission Line hll.tln 17241-200 '8..6-6 n~ 6- 3: OJIDI fW PHPAlATlC* OF 1.IIWOUS IU.lPSIS Anal. "."14- 6-9 s 1-.t. 1.oop na.b1e I.aop .. .)Me .~;;~~~~ :; . . . ~~~~~~; .~~~ (Metric). . I.at 11+.*1 Iq. 6-10 (.111111) .. I.J' It . I ... 6-11 C1fetl'ic) I ~. 6-}4 I (EBall.lh) ... 6-15 "jor Axu .,... Df.8tlAe'- l I. .u I( -" ~. 6-IZ ~r Axl' "0" .. ... 14- 6-1) ~ ~r.: 1'e - v1nd loacl per unit. leDith «1 I~ conductor 111 1/8 (lb8/ft). Aas- a .~I kPa (2 ,_f) wind. v~ - wlpt. per WItt. i-ath of ~~tor pll18 12.7 - (.$ t..) of radial Ice in R/8 (1b8/fc) (for ar.-d8N aTavic, 1 q - '.81 J) L - -,.. lenatb in ..~.r. (feet). !I - _jar axis of UsaaJ- elU,... 111 ..~n (feec). It - final... of CODduct.or with 12.7 .. (.5 10.) of r"1al tee. DO wind, at O.C (32.P). D - .inor axi& of u.-J- elllp- la _~r. (feet). t.. - ere .. .fi~ ~ f1~ abO¥8. 2/25120034: I.'.. ... 6-16 I --- '~I'SC' I .. 1.1~ - .- ... 6-11 : GALLOPBethwd. mcdBethel to Donlin Creek 138 kV Transmission line SinGle LOOD GalioD Calculations 300, 400, 500, 600 ft spans With-Dampening Assumptions: Conductor is at 32°F and is covered with 0.5" ice. 25 mph Wind Wind load on conductor is 1.6 Ibs per sq. foot: Fw:= 1.6.~ Diameter of Conductor: r ~:=k:= 1..2 Mallard Cardinal Weight of conductor: wtcondk := Mallard Cardinal Weight of Ice on Conductor: kt:= 57.~ ~ Density of Ice:Radius of Ice:ri := O.5.in ~ )2}kI ~ ~22+") - wti~ := 11: ~= (1.004 )~ 1 .055 ft Wt.1 := wtiC8i( + wtcondkTotal Weight of Conductor: k Mallard Cardinal --+ =(2.239)~ w.a.. 2.284 ft Pet:= Fw.(dtt + 2.ri)Force of wind on conductor: Mallard Cardinal -+- =(0.282)~ Pc 0.293 ft 2f25/2OQ31 GALLOPBethwd. mcdBethel to Donlin Creek 138 kV Transmission Une +- =(7.177 )d + 7.307 eg Swing angle:+k:= atan Final sag of conductor at 32°F with 1(1." ice: Sag2k := , 500 ft Span Sag3k:= ,600 ft SpanSagk:= ,300 ft Span Sag1 k := . 400 ft Span Mallard Cardinal 1. 300 FOOT SPAN Parameters of Ussajous Ellipses: Mk:= 1 .25 . Sa~ + 1 where M=Major Axis Lissajous ellipse in feet Bk := 0.25.Sagk See Figure page 4 Dk := 0.4.Mk where D=Minor Axis Ussajous ellipse in feet ~Conductor S8g!(= ~ ~ Mk= Bt= [~~~ [=~ [~~ ~~ Dt= [i:!I ~ . deg [~~ [!~ Mallard Cardinal 2. 400 FOOT SPAN Parameters of Lissajous Ellipses: Mk:= 1.250 Sag 1 k + 1 where M=Major Axis Lissajous ellipse in feet ~ := 025 oSag1 k See Figure page 4 Dk := 0.4.Mk where D=Minor Axis Lissajous ellipse in feet tt.1.5 deg [~~~ [~~~~ ~Conductor Sag1 k = ~ ~ Mt= Bt= [~~~ [~~~ [~~ ~~ Dt= ~ ~ == deg [!~ [!~] Mallard Cardinal 2125120032 Bethel to Donlin Creek 138 kV Transmission line GALLOPBethwd. mcd 3. 500 FOOT SPAN Parameters of Lissajous Ellipses: Mk:= 1.25. Sag2k + 1 where M=Major Axis Lissajous ellipse in feet Bk:= 0.25.Sag2k See Figure page 4 Dk:= 0.4.Mk where D=Minor Axis Ussajous ellipse in feet +t.1.5= deg [~~~] [=~~~ ~Conductor ~= ~ ~ Mk= Bk= [==~ ~ C~ [~~~ [~~~ Ok= ~ ~ - deg [~~ [!~ Mallard Cardinal 2. 600 FOOT SPAN Parameters of Lissajous Ellipses: Mk:= 1 25. Sag3k + 1 where M-Major Axis Lissajous ellipse in feet Bk:= 0.25.Sag3k See Figure page 4 °k:= 0.4.Mk where D-Minor Axis Lissajous ellipse in feet fk.1.5= deg [~~~ [=~~~ +tConductor Sag~= [!!) ~ Mk= ~= [~~~ ~~ [~~~ [~~ Ok= ~ ~ . deg [~~] [!~ Mallard Cardinal 3 2f25f2003 Bethel to Donlin Creek 138 kV Transmission Line GALLOPBethwd.mcd 1.1 I_tin 17241-200 '8'- 6-6 PlctaI 6-3 ClltDi ~ PlEPAIATICII OF LISWWS EWPSU ,., ,~.-m-. ~:. .. .. 14. 6-16 I - -~ '"'f8"tricl I .. 1.l'" - .- ... 6-17 Cl88118h\.. J6='T ... 6-18 ~r Axl. "1)- ~.r. ¥c - vind load pel' wit 1qtt. OCt IcN conductor 11' 1/8 (1b8/ft). Aa- a .OKl kPa (2 ,ar) viM. we - velpr. "f -St ~dI of c~tor p1- 1207 - (oS t1l.) ef radial !e. 1. ./8 (lb8/fc) (fer a~ p..!t.y I q - '.11 J) L - apaa lenach in ..cer. (feec). II. ..jO1" an. of Uuaj- elll,- 1ft ~r. «Mt). 51 . final ..& of eoDductor with 12.7 .. (.5 In.) of rad181 lee. no w1nd, .t O"C (]2"F). D - 81nor u1& of UauJ- alII,... 10 _cera (fMt). t.. - are .. "fl~ 1D fll'U'e ab 4 2/2512003 Bethel to Donlin Creek Mine 138kv Transmission Line Double Looa Galloo Calculations - No Damoenina 800. and 1000. Soans Assumptions: Conductor is at 32°F and is covered with 0.5" ice. 25 mph Wind Ib Wind load on conductor is 1.6 Ibs per sq. foot: Fw:= 1.6.- Diameter of Conductor: r k:= 1 .. 2 dt := Mallard Cardinal Weight of conductor: wtcondk := Mallard Cardinal Weight of Ice on Conductor: kj:= 57.~ ft3 Density of Ice: Radius of Ice:ri := O.5.in ~ ~:= .{(~ +11)2- (~)2].iI ~= (1.~)~ 1.055 ft Wtotal := wti~ + wtcondk . Total Weight of Conductor: Mallard Cardinal -+ =(2.239)~ ~ 2.284 ft GALLOPnd.MCD13/4f1.OO3 Bethel to Donlin Creek Mine 138kv Transmission Line Pc..:= Fw'(~ + 2.ri}Force of wind on conductor: -+- =(0.282)~ Pc 0.293 ft Mallard Cardinal Pck ~ ~ =(7o177 )d . 7.307 eg Swing angle:+k:= stan .J Final sag of conductor at 32°F with 1/2" ice: Sag2k:= .1000 ft SpanSag 1 k:= I 800 ft Span 1. 800 FOOT SPAN Assmes Double Loop Gallop Parameters of Lissajous Ellipses: L:= 800 where L- span length where M=Major Axis Lissajous ellipse in feet See Figure page 4Bk:= 2.Mk where D=Minor Axis Lissajous ellipse in feet tt.1.5 deg [~~~ [~~ +t = .Qonductor ~ ~= [~~~ [~~J Dk= ~~ ~~ Mk= [~~ ~~ deg [~~ [~?J Sag1k = ~ ~ Mallard Cardinal GALLOPnd.MCD23/4/2003 Bethel to Donlin Creek Mine 138kv Transmission Line 2. 1000 FOOT SPANAssmes Dou~e Loop Gallop Parameters of lissajous Ellipses: L:= 1000 where L- span length where M=Major Axis Lissajous ellipse in feet See Figure page 4Bk:= 2.Mk where D=Minor Axis Lissajous ellipse in feet ~= d~ Condudor ~= ~ ~ Mt= [~~~] [~~~ ,= ~~ ~~ Dt= [~~ [~~ Mallard Cardinal 3/4f1.OO3 3 GAlLOPnd.MCD Bethel to Donlin Creek Mine 138kv Tr8nsmission LIne hll.tin 17241-200 '8'8 ... an.. ~ PllPAlAn~ 0' LIlSAJM a.I.lPSU n., '.3 Mal. ".".. t_-l(!&) 14.'" s C Double (~rk) . f~;~ ~ - ~. ('I8trk). - I.IS II.'" ... 6-.. .Y.'.. F - -. ~. 4 (_11111) , lo. + !l- 18. (f88lt..~ .-I.It,,+. 14. 6-11 ...JI/-"'.F--' ".6-15 . .{&j;;~ ~j« Axle "K" ~t88&.i-;:. .u " ~" \ ... 6-.1! ..0. 1406-16 i -- \*~..1c'.. 1.L.~ - 0- ... 6-17 I CE8811.') . . a..-:-t ... 6- 18 ~ ...,le "n- .. ...14. 6-12 ~('. ~c - vind lo8d per unit 18J11th WI iced cGII6acc:or i1l -/8 (1b8/ft). Aa8U88 a .0951 kPa (2 ,.f) vi... Vc - ..iSb~ per unl~ leftlth of c~tor pi.. 12.7 .. (. ~ In.) of r8d1a1 Ice in '-/8 (IN/fc) (fer a~ pawlty 1 q - '.81 J) L - .,.. 18n1th in ..cer. (feec). It . -Jor a1a of UuaJ- el11,... 1n -c.n (f-c). 11 - fln81 ... of ~ter v1~h 12.7 .. (.5 In.) of r..181 ice, no wind, at O.C (]2.r).D - ainor uta of U...J088 e11Ip... ID ..tera (feet). t.. - are .. .fI~ in flpre ab GALLOPnd. MCD43/4/2003 Bethel to Donlin Creek Mine 138 kV Transmission Une Double Looa Galloo Calculations - With Damoenina 800' and 1000' Soans Assumptions: Conductor is at 32°F and is covered with 0.5" ice. 25 mph Wind := 1.6.~rWind load on conductor is 1.61bs per sq. foot: Fw Diameter of Conductor: k:= 1 .. 2 dt := Mallard Cardinal Weight of conductor: wtcondk := Mallard Cardinal Weight of Ice on Conductor: Ib ft3 Density of Ice:Hi := 57.Radius of Ice:ri := O.5.in 2 ~)2 kI wti~ := 1t -;-+(1.004 )Ib wtice= - 1.055 ft Wtotal.. := wtiC8i( + wtcondkTotal Weight of Conductor: --. =(2239J~ WtdaI 2284 ft Mallard Cardinal GAlLOPwd. mcd13/4/2003 Bethel to Donlin Creek Mine 138 kV Transmission Une Pck:= Fw.(dt + 2.ri}Force of wind on conductor: Mallard Cardinal -+ =(0.282)~ Pc 0.293 ft +- =(7.177 )d + 7.307 eg Swing angle:+k:= atan:Pck ~ Final sag of conductor at 32°F ~ 1/2" ice: Sao2k:= ,1000ftSpan ~ ~ Sag1 k:= . 800 ft Span ~ ~ 1. 800 FOOT SPAN Assmes Double Loop Gallop Parameters of Lissajous Ellipses: L:= 800 where L- span length where M=Major Axis Lissajous ellipse in feet See Figure page 4 Bk:= .2.Mk where D=Minor Axis Lissajous ellipse in feet +t.1.5- deg [~~ Q~ +k ==Conductor Dk= [~~ ~.!J Bt = [~~~ ~~ Sag1 k = ~ ~ Mk= [~~ [!~J deg [I~ r::!:~ Mallard Cardinal GALLOPwd. moo23/4/2003 Bethel to Donlin Creek Mine 138 kV Transmission LIne 2. 1000 FOOT SPANAssmes Double Loop Gallop Parameters of Lissajous Ellipses: where L- span lengthL:= 1000 where M=Major Axis Lissajous ellipse in feetMk:= 1 + See Figure page 4 Bk:= .2.Mk where D=Minor Axis Lissajous ellipse in feet t11-1.5 deg [~~~ [~~~ Conductor = ~= [~~ [~~] Dk= [~~ @~ ~= ~ (~ Mk= [~~ [!~J Mallard GALLOPwd.mcd33/4/2003 Bethel to Donlin Creek Mine 138 kV Transmission Line hll.tin 17241-200 '..e6.6 n~ 6-3: COlD! fW "EPAlATI<* OF LISSAJOUS IU.1PSU . . t..-l (!'c)AnIle "t"14. 6-9 ~bl. ~ .. ... ..v;;~~J~ ~ . . I ~~:..~.: ~ .~~~ s ~ I.oop C'fetric) I~. 6-14 (rnali.lI)i4. 6-15 I (MftTic)w. I.U 11 +... iq. 6-1°1 I(~111.tI) I.. us It . I ... 6-111 ~.1or Ax1. "K" ! ])utllle. 'I. .at It i ..." ... 6-11 .'.. iq.6-16 \*tI'SCI.. 1.~.~ - .- ... 6-17 (z.11811) ,. . 1.«*='1' ... 6-18!~r Asis "nN D 14. 6-11 .ere: ~e - wind loed per .an1t lencth on IcR conductor 1n I,. (lb8/ft). Aa- a .0"' kPa (2 p.f) wind. we - v.l~~ pe~ ~1~ t.nith of c~tor pi.. 12.7.. (.t ta.) of radial lee 1a ./8 (lbs/fc) (for .~ IZ8Ytcy 1 kI - '.11 I) L - .PaR lenatb tn ..cer. (f..t). K - ..joT axis of LtaaaJoua elll,... la ..eera (feec). 51 - final... of conductor with 12.7 .. (.5 In.) of radial ice. no wind, at O.C (32.F). D - .inor ax1& of Lt...jOO8 el1lp... 10 ..eera (feet). t.. - are as 4af!~ iJI fll'U"8 a GALLOPwd. moo43/4(2003 Bethel to Donlin Creek Mine 138 kV Transmission LIne Conductor Blowout and R.O.W. Width Calculations Conductor - 954 ACSR (Cardinal) .229~ ft Weight Conductor wtcond :=Diameter Conductor d :=196in Fw:= 25.6~ ft2 1 00 Mph Extreme Wind p = 2.6 ~ it. p := d.Fw x:=--{~x = 64.3deg sin(x) = 0.9 Single Pole Structure Types 1 , 2, 3 & 3A Distance from Centerline to Outer Conductor dist :::= Sft Required NESC clearance to structures n~:::= 12.1ft i:= 0..6 NO DAMPENING SPaIli := Blowou~:= Sagi"sin(X) ~2.3 4.3 6.8 9.5 12.8 16.4 20.3 ftBlowoulj = Required R.O.W. wKith Rowj := (Blowou!j + dist + ~).2 SP8Di := 38.7 42.8 47.7 53.3 59.8 67 74.7 ~ 1ftRow = Condblowout954. mcd13/11f2003 Bethel to Donlin Creek Mine 138 kV Transmission line H-Fame and X-Frame Structures Distance from Centerline to Outer Conductor dist:= 15ft Required NESC clearance to structures nesc:= 12.1ft Insulator String Length Isl := Sft i:= 0..6 ~..,. 0-Sag . '- ~o- ,.-Blowou1j:= Sagi"sin(X) 12.8 16.4 20.3 24.6 29.3 34.3 .39.7 1ftBlow~ = Required R.O.W. width Rowi:= (Blow~ + dist + Des: + 1sl).2 SpSDj := 89.8 97 104.7 113.4 122.8 132.9 143.7 ftRow = Condblowout954. mcd23/11(1.003 Bethel to Donlin Creek Mine 138 kV Transmission line WITH DAMPENING Sinole Pole Structure Tvoes 1. 2. 3 & 3A Distance from Centerline to Outer Conductor dist := Sft Required NESC clearance to structures DeS):= 12.1ft SpSDi :=S88i : =BloWOU1j := Sa8i.sin(x) 1.5 3.2 5.1 7.5 10 12.9 16 1ftBlowOtItj = Required R.O.W. wKIth Rowj := (Blowou~ + dist + ~).2 SpaDj := '37.3 40.5 44.5 49.2 54.2 60 .66.3 1ftRow = H-Fame and X-Frame Structures Distance from Centerline to Outer Conductor dist:= 15ft Required NESC clearance to structures ~:= 12.1ft Insulator String Length Isl:= Sft i:=O_6 ~:=S88i : = Blowou1j := Sa8j.sin(x) '10.1 12.9 16 19.6 23.2 27.2 31.4 1ftBlowOtdj = 3/11 f2OO3 3 CondbIO\Wut954.mcd Bethel to Donlin Creek Mine 138 kV Transmission line Required R.O.W. width Rowj := (Blowo~ + dist + Des: + Js1).2 SpSDj := 84.4 90 96.3 103.3 110.7 118.6 127.1 1ftRow = Condblowout954.mcd43/11f1:OO3 ALUMINUM COMPANY OF AMERICA SAG AND TENSION DATA Bethel 138 tv Transmission Line 954 ACSR Northern & Southern Zone With Dampening CONDUCTOR CARDINAL 954.0 KCMIL 54/ 7 STRANDING ACSR AREA- .8462 SQ. IN. DATA FROM CHART NO. 1-83t ENGLISH UNITS SPAN= 200.0 FEET CREEP IS A FACTOR * DESIGN CONDITION DESIGN POINTS TEMP ICE WIND F IN PSF O. .50 4.00 32. 1.00 .00 32. .50 .00 32. .00 25.60 -70. .00 .00 -15. .00 .00 o. .00 .{)O 30. .00 .00 60. .00 .00 90. .00 .00 122. .00 .00 HEAVY LOADING FINAL SAG TENSION FT LB 1.31 10270. 2.17 9120. .1.47 7747. 1r73 8188. .4. 13828. .S7 10809. .64 9562. .86 7141. 1.23 4978. 1.83 3364. 2.40 2557. INITIAL SAG TENSION FT LB 1.25 10813. 1.99 9954. 1.26 9054. 1.52 9327. .44 13828. .55 11153.* .59 10372. .7Q e746. .87 7063. 1.14 5392. 1.61 3818. K LB/F .30 .00 .00 .00 .00 ..00 .00 .00 .00 .00 .00 WEIGHT LB/F 2.698 3.961 2.284 2.832 1.229 1.229 1.229 1.229 1.229 1.229 1.229 SPAN= 300.0 FEET CREEP IS A FACTOR * DESIGN CONDITION DESIGN POINTS TEMP ICE WIND F IN PSF O. .50 4.00 32. 1.00 .00 32. .50 .00 32. .OG 25.60 -7~. .00 .00 -15. .GO .00 o. .00 .00 30. .00 .00 60. .00 .00 90. .00 .00 122. .00 .00 HEAVY LOADING FINAL SAG TENSION ~ LB 2.83 10749. 4.27 10442. 3.08 8345. 3.52 9041. 1.00 13785. 1.31 1054.. 1.48 9360. 1.94 1143. 2.61 5291. 3.48 3970. f.48 3093. INITIAL SAG TENSION FT LB 2.69 11211. ..0. 11035. Z.10 9535. 3.18 10015. l~OO 13785. 1.24 11154.* 1.33 10392. 1.57 8830. 1.91 1251. 2.(0 5164. 3.13 4422. K LB/F .30 .00 .00 .00 .00 .00 ~OO .00 .0() .00 .00 WEIGHT LB/F 2.698 3.961 2.284 2.832 1.229 1.229 1~229 1.229 1.229 1.229 1.229 SPAN- 400.0 FEET CREEP IS A FACTOR * DESIGN CONDITION DESIGN POINTS TEMP ICE WIND F IN PSF O. .50 4.00 32. 1.00 .00 32. .50 .00 32. .00 25.60 -70. .00 .00 -15. .00 .00 O. .00 .00 30. ~OO .00 60. .00 .00 90. .00 .00 122. .00 .00 HEAVY LOADING FINAL SAG TENSION FT LB 4.78 11304. 6.79 11679. 5.10 8961. 5.13 9891. 1.19 13728. 2.39 1029.. 2.67 9194. 3.41 7~07. 4.37 5623. 5.48 4493. 6.67 3688. INITIAL SAG TENSION FT LB 4.58 11803. 6.56 1.2097. 4.5( 10061. 5.28 10735. 1.79 13728. 2.20 11154.* 2.36 10419. 2.75 8935. 3.29 748{). 4.00 6146. 4.95 4966. K LB/F .30 .00 .00 .00 .00 .00 .00 .00 .00 .00 .00 WEI( LB; 2.65 3.9E 2.2E 2.8:: 1.2~ 1.2~ 1.2~ 1.2~ 1.2~ 1.2~ 1.2~ SPAN- 500.0 FEET CREEP IS A FACTOR * DESIGN CONDITION DESIGN POINTS TEMP ICE WIND F IN PSF O. .50 4.00 32. 1.00 .00 32. .50 .00 32. .00 25.60 -70. .00 .00 -15. .00 .00 O. .00 .00 30. .00 .00 60. .00 .00 90. .00 .00 122. .00 .00 HFAVY LOADING FINAL SAG TENSION E-r LB 7.10 11887. 9~61 12829. 7.46 9576. 8.29 10695. 2.81 13657. 3.81 10088. 4.23 9084. 5.25 7324. 6~46 5953. 7.76 4956. 9.14 4207. INITIAL SAG TENSION n LB 6.84 12349. 9.46 13105. 6.74 10594. 7.75 11441. 2.81 13657. 3.44 11154.* 3.68 10451. 4.24 9052. 4.98 7714. 5.90 6514. 7.05 5453. K LB/F .30 .00 .00 .00 .00 .0() .00 .00 .00 .00 .00 WE L 2. 3. 2. 2. 1. 1. 1. 1. 1. 1. 1. SPAN= 600.0 FEET CREEP IS A FACTOR * DESIGN CONDITION DESIGN POINTS TEMP ICE WIND F IN PSF o. .50 4.00 32. 1.00 .00 32. .50 .00 32. .00 25.60 ~7(). .00 .00 ~15. .00 .00 O. .00 .00 30. .00 .00 6(). .00 .00 90. .00 .00 HFAVY LOADING FI SAG FT 9.75 12.85 10.13 lL.15 4.08 ~.57 6.13 7.41 8.83 10.31 IN SAG n 9.43 12.72 9.26 10.53 4.08 4.96 5.28 6.03 6.96 8.07 K LB/F .30 .00 .00 .00 .00 .00 .00 .00 .00 .00 WEIGHT LB/F 2.698 3.961 2.284 2.832 1.229 1.229 1.229 1.229 1.229 1.229 122..00 .00 .00 1.229 11.87 4670.9.40 5891 iHT 'F .8 ;1 I. 12 !9 !9 !g, ~9 !9 ~9 ~9 IGHT B/F 698 961 28. 832 229 229 229 229 229 229 229 NAL TD ] ] ] ] ] 9Ic. LB 2471. 3900. :>160. L453. 3572. ~935. ~O30. r474. 6268. )371. IT I. T AL EN~ 1~ 1~ 1J 1< 1~ 1J 1( ( j E iION LB !891. '°51. ll13. !118. 1512. .15(.* )486. 1176. r947. ;858. SPAN= 700.0 FEET CREEP IS A FACTOR * DESIGN CONDITION DESIGN POINTS TEMP ICE WIND F IN PSF O. .50 4.00 32. 1.00 .00 32. .50 .00 32. .00 25.60 -70. .00 .00 -15. .00 .00 O. .00 .00 30. .00 .00 60. .00 .00 90. .00 .00 122. .00 .00 HEAVY LOADING FINAL SAG TENSION n LB 12.70 13041. 16.33 14903. 13.08 10713. 14.29 12166. 5.62 133~3. 7.66 9832:. 8.35 9022. 9.86 7641. 11.48 6566. 13.12 5748. 14.83 5087. INITIAL SAG TENSION no LB 12.34 13418. 16.29 14937. 12.07 11609. 13.62 12759. 5.59 13479. 6.75 11154.* 1.16 10523. 8.10 9300. 9.22 8171. 10.50 7176. 11.99 6286. K LB/F .30 .00 .00 .00 .00 .00 .00 .00 .00 .00 .00 WEIGHT LB/F 2.698 3.961 2.284 2.832 1.229 1.229 1.229 1.229 1.229 1.229 1.229 SPAN= 800.0 FEET CREEP IS NOT A FACTOR * DESIGN CONDITION DESIGN POINTS TEMP ICE WIND F IN PSF O. .50 4.00 32. 1.00 .00 ;32. .50 .00 32. .00 25.60 -70. .00 .00 -15. .00 .00 o. .00 .00 30. .00 .00 60. .00 .00 90. .00 .00 122. .00 .00 HEAVY LOADING IN] SAG PT 15.53' 20.17 15.15 16.99 7.35 9.82 9.32 10.44 11.74 13.19 14.8) WE L 2. 3. 2~ 2. 1~ 1. 1. 1. 1. 1. 1. FI SAG FT 16.03 20.17 16.f2 17.81 7.64 10.20 11.01 12.74 14.53 16.32 18.17 K 1.B/F .30 .00 .00 .00 .00 .00 .00 .00 .00 .00 .00 SPAN= 900.0 FEET CREEP IS NOT A FACTOR * DESIGN CONDITION DESIGN POINTS TEMP ICE WIND F IN PSF O. .50 4.00 32. 1.00 .00 32. .50 .00 32. .00 25.60 -10. .00 .00 ":15. .00 .00 o. .00 .00 30. .00 .00 60. .00 .00 90. .00 .00 122. .00 .00 HEAVY LOADING FINAL SAG TENSION rr LB 19.71 13899. 24.33 16544. 20.09 11540. 21.66 13279. 10.10 12333. 13.15 9471. 14.09 8848. 16.00 7790. 17.94 6950. 19.86 6283. 21.8-4 5715. INITIAL SAG TENSION FT LB 19.01 14405. 24.33 16544. 18.51 12524. 20.64 13932. 9.38 13270. 11.17 11154.* 11.75 10598. 13.06 9540. 1..52 8580. 16.11 7736. 11~89 6969. K LB/F .30 .00 .00 .00 .00 .00 .00 .00 .00 .00 .00 WEIGHT LB/F 2.698 3.961 2.284 2.832 1.229 1.229 1.229 1.229 1.229 1.229 1.229 rIAL TEN~ l~ l! i~ 1.~ 1~ 1] t( ( E J E ; ION LB t924. )766. ~O90. 1363. ~377 . l154.* )561. .422 . ~382. '468. ;644. IGHT elF 698 961 284 832 229 229 229 229 229 229 229 NAL TEl ISION LB .3497. .5766. .1156. .2757. .2867. 9650. 8936. 7726. 6777. 6038. 5425. HEAVY LOADINGSPAN= 1000.0 FEET CREEP I S NOT A FACTOR * DESIGN CONDITION DESIGN POINTS TEMP ICE WIND F IN PSF O. .50 4.00 32. 1.00 .00 32. .50 .00 32. .00 25.60 -10. .-00 .00 -15. .00 .00 O. .00 .00 30. .00 ~OO 60. ~OO .~O 90. .00 .00 122. .00 .no FINAL SAG TENSION FT LB 23.68 14284. 28.79 17215. 24.06 11903. 25.80 13710. 12.95 11810. 16.41 93ff. 11.49 8197. 19.57 7865. 21.65 7115. 23.68 6501. 25.18 5919. INITIAL SAG TENSION F'l' LB 22.76 14863. 28.79 17275. 22.12 12942. 24.55 14468. 11.68 13159. 13.79 11154.* 14.46 10634. 15.94 9651. 11.56 $763. 19.29 7981. 21.20 7264. WEIGHT LB/F 2.698 3.961 2.284 2.832 1.229 1.229 1.229 1.229 1.229 1.229 1.229 K LB/F .30 .00 .00 .0() .00 .00 .00 .00 .00 .00 .00 SPAN= 1100.0 FEET CREEP IS NOT A FACTOR * DESIGN CONDITION DESIGl-J POINTS TEMP ICE WIND F IN PSF O. .50 4.00 32. 1.00 .00 32. .50 .00 32. .00 25.60 ...70. .00 .00 ~15. .00 .00 O. .00 .00 30. .00 .00 60. .00 .00 90. .00 .00 122. .00 .00 HEAVY LOADING FINAL SAG TENSION FT LB 27.95 14652. 33.52 17963. 28.31 12246. 30.22 14232. 1$.21 11480. 20.12 9256. 21.23 8715. 23.45 7941. 25.64 7270. 27.78 6713. 30.00 6221. INITIAL SAG TENSION FT LB 26.7.7 15296. 33.52 17963. 25.98 13335. 28.72 14971. 14.26 13047. 16.69 11154.* 17.45 10669. 19.08 9756. 20.85 8933. 22.71 8205. 24.74 .7533. K La/!' .30 .00 .00 .00 .00 .00 .00 .00 .00 .00 .00 WEIGHT LB/F 2.698 3.961 2.284 2.832 1.229 1.229 lw229 1.229 1.229 1.229 1.229 HEAVY LOADINGSPAN- 1200.0 FEET CREEP IS NOT A FACTOR * DESIGN CONDITION DESIGN POINTS TEMP ICE WIND F IN PSF O. .50 4.00 32. 1.00 .00 32. .50 .00 32. .00 25.60 -70. .cO .00 -15. .00 .00 o. ~OO .00 30. "cOO .00 60. .00 .00 90. .00 .00 122. .00 .00 FINAL SAG TENSION FT LB 32.50 15002. 38.52 18611. 32.84 12568. 34.92 1.666. 19.86 11158. 24..10 9198. 25.29 8771. 27.62 9031. 29.92 7(17. 3Z.17 6904. 34.48 6444. INITIAL SAG TENSION F'l' LB 31.03 15707. 38.52 1861.1. 30.10 13704. 33.14 15446. 11.12 12936. 19.86 11154.* 20.10 10701. 22.49 9853. 24.39 9089. 26.31 8(11. 29.52 7780. WEIGHT LB/F 2.698 3.961 2.284 2.832 1.229 1.229 1.229 1.229 1.229 1.229 1.229 K LB/F .30 .00 .00 .00 .00 .00 .00 .00 .00 .00 .00 ALUMINUM COMPANY OF AMERICA SAG AND TENSION DATA Bethel 138 kV Transmission Line 954 ACSR Northern & Southern Zone No Dampening 54/ 7 STRANDING ACSR954.0 KCMILCONDUCTOR CARDINAL AREA= .8462 SQ. IN. DATA FROM CHART NO. 1-838 ENGLISH UNITS SPAN~ 200.0 FEET CREEP IS A FACTOR * DESIGN CONDITION DESIGN POINTS TEMP ICE WIND F IN PSF O. .50 4.00 32. 1.00 .00 32. .50 .00 32. .00 25.60 -.70. .00 .00 -15. .00 .00 O. .00 .00 30. .00 .00 60. .00 .00 90. .00 .00 122. .00 .00 HEAVY LOADING INITIAL SAG TENSION FT LB 1.93 7007. 2.88 6895. 2.13 5368. 2.41 5889. .63 9708. .91 6760.* 1.03 594,. 1.39 4414. 1.93 3190. 2.57 2397. 3.24 1901. FINAL SAG TENSION FT LB 1.93 6978. 2.92 6790. 2.28 5005. 2.52 5621. .63 9708. .92 6709. 1.10 5609. 1.62 3789. 2.31 2659. 3.00 2048. 3.56 1731. WE L 2. 3. 2. 2. 1. 1. 1. 1. 1. 1. 1. K LB/F .30 .00 .00 .00 .00 .00 .00 .00 .00 .00 .00 SPAN~ 300.0 FEET CREEP IS A FACTOR * DESIGN CONDITION DESIGN POINTS TEMP ICE WIND F IN PSF o. .50 4.00 32. 1.00 .00 3.2. .50 .00 32. .00 25.60 -70. .00 .00 -15. .00 .00 o. .00 .00 30. .00 .00 60. .00 .00 90. .00 .00 122. .00 .00 HEAVY LOADING FINAL SAG TENSION FT LB 3.96 7665. 5.44 8211. ..(2 5818. 4.80 6649. 1.45 9528. 2.18 6339. 2.54 54.7. 3.40 4074. 4.33 3200. 5.22 2652. 6.10 2271. INITIAL SAG TENSION FT LB 3.90 7795. 5.38 8301. 4.14 .6213. 4..60 6935. 1.45 9528. 2.05 6760.* 2.29 6040. 2.91 4749. 3.69 3752.. 4.53 305$. 5. 4.0 25~3. WEIGHT LB/F 2.698 3.961 2.28. 2.832 1.229 1.229 1.229 1.229 1.229 1.229 1.229 K LB/F .30 .00 .00 .00 .00 .00 .PO .00 .00 .00 .00 IGHT elF 698 961 28. 832 229 229 229 229 229 229 229 HEAVY LOADINGSPAN= 400.0 FEET CREEP IS A FACTOR * DESIGN CONDITION DESIGN POINTS TEMP ICE WIND F IN PSF O. .50 4.00 32. 1.00 .00 32. .50 .00 32. .00 25.60 -70. .00 .~O -15. .00 .00 o. .00 .00 30. .00 .00 60. .00 .00 90. .00 .00 lZ2. .00 .00 INITIAL SAG TENSION FT LB 6.35 8517. 8.35 9507. 6.59 6940. 7.24 7835. 2.65 9295. 3.64 6160.* 4.01 6136. 4.87 5048. 5.85 (207. 6.86 3589. 7.91 3112. FINAL SAG TENSION FT LB 6.47 8347. 8.40 9447. 7.00 6536. 7.52 7548. 2.65 9295. 4.00 6152. 4.51 5449. 5.63 4374. 6.75 3649. 7.82 3151. 8.88 2776. WEIGHT LB/F 2.698 3.961 2.284 2.832 1.229 1.229 1.229 1.229 1.229 1.229 1.229 g LB/F .30 .00 .00 .00 .00 .00 .00 .00 .00 .00 .00 HtAVY LOADINGSPAN= 500.0 FEET CREEP IS A FACTOR * DESIGN CONDITION DESIGN POINTS TEMP ICE WIND F IN PSF O. .50 4.00 32. 1.00 .00 32. .50 .00 32. .00 25.60 -10. .00 .00 -15. .00 .00 O. .00 .00 30. .00 .00 60. .00 .00 go. .00 .00 122. .00 .00 INITIAL SAG TENSION "' LB 9.22 9158. 11.76 10559. 9.45 7565. 10.30 8613. ..25 9031. 5.69 6760.* 6.17 62.25. 7.25 5303. 8.40 .579. 9.56 4024. 10.77 3574. FINAL SAG TENSION FT LB 9.41 8977. 11.78 10536. 9.98 7165. 10.64 8336. 4.28 8973. 6.32 6083. 6.96 5523. 8.27 4650. 9.55 4028. 10.78 3573. 12.00 3210. WEIGHT LB/F 2.698 3.961 2.284 2.832 1.229 1.229 1.229 1.229 1.229 1.229 1.22.9 . LE ." .( .( .( .c .( .( .( .( .( .( HEAVY LOADINGSPAN= 600.0 FEET CREEP IS NOT A FACTOR * DESIGN CONDITION DESIGN POINTS TEMP ICE WIND F IN PSF o. .50 4.00 32. 1.00 .00 32. .50 .00 32. .00 25.60 -70. .00 .00 -15. .00 .00 o. .00 .00 30. .00 .00 60. .00 .00 90. .00 .()O 122. .00 .00 INITIAL SAG TENSION" LB 12.52 9124. 15.51 11486. 12.11 8106. 13.15 9292. 6.32 8758. 8.19 6760.* 8.78 6303. 10.04 5515. 11.34 4885. 12.64 4386. 13.99 3966. FINAL SAG TENSION FT LB 12.78 9523. 15.57 11486. 13.38 7700. 14.18 9013. 6.59 8391. 9.15 6053. 9.89 5601. 11.36 4878. 12.78 4338. 1".13 3924. 15~50 3580. K LB/F .30 .00 .00 .00 .00 .00 .00 .00 .00 .00 .00 WEI LB 2.6 3.9 2.2 2.8 1.2 1.2 1.2 1.2 1.2 1.2 1.2 ~ !/F 10 10 10 10 10 10 )0 )0 )0 )0 ~ GHT IF 98 61 84 32 29 29 29 29 29 29 29 SPAN- 700.0 FEET CREEP IS NOT A FACTOR * DESIGN CONDITION DESIGN POINTS TEMP ICE WIND F IN PSF O. .50 4.00. 32. 1.00 .00 32. .50 .00 32. ~OO 25.60 -70. .00 .00 -15. .00 .00 o. .00 .00 30. .00 .00 60. .00 .00 90. .00 .00 122. .00 .00 HEAVY LOADING FINAL SAG TENSION FT LB 16.60 9985. 19.79 12311. 17.23 8147. 18.15 9589. 9.52 7911. 12.50 6035. 13.31 5665. 14.91 5059. 16.45 4588. 17.92 4214. 19.42 3893. INITIAL SAG TENSION FT LB 16.21 10224. 19.79 12311. 16.36 8574. 17.60 9887. 8.87 84~3. 11.15 6760.* 11.84 6369. 13.25 5692. 14.68 5139."16.10 .689. .17.57 4299. K LB/F .30 .00 .00 .00 .00 .00 .00 .00 .00 .00 .00 WEI LB 2.6 3.9 2.2 2.8 1.2 1.2 1.2 1.2 1.2 1.2 1.2 SPAN= 800.0 FEET CREEP IS NOT A FACTOR * DESIGN CONDITION DESIGN POINTS TEMP ICE WIND F IN PSF O. .50 4.00 32. 1.00 .00 32. .50 .00 32. .00 25.60 -70. .00 .00 -15. .00 .00 O. .00 .00 30. .00 .00 60. .00 .00 90. .00 ~OO 122. .00 .00 HEAVY LOADING IN SAG FT 20.31 24.40 20.41 21.85 11.93 14.57 15.33 16.88 18.43 19.95 21.53 FI SAG FT 20.84 24.40 21.48 22.53 13.03 16.31 17.19 1.8.90 20.54 22.11 23.12 K LB/F .30 .00 .00 .00 .00 .00 .00 .00 .00 .00 .00 WEIGHT LB/F 2.698 3.961 2.284 2.832 1.229 1.229 1.229 1.229 1.229 1.229 1.229 HEAVY LOADINGSPAN- 900.0 FEET CREEP IS NOT A FACTOR * DESIGN CONDITION DESIGN POINTS TEMP ICE WIND F IN PSF O. .50 4.00 32. 1.00 .00 32. .50 .00 32. .00 25.60 -70. .00 .00 -15. .00 .00 O. .00 .00 30. .00 .00 60. .00 .00 90. .00 .00 122. .00 .00 FINAL SAG TENSION " LB 25.49 10764. 29.41 13712. 26.14 8887. 27.31 10551. 17.07 7302. 20.58 6062. 21.51 5802. 23.31 5356. 25.05 4988. 26.71 4680. 28.41 4403. INITIAL SAG TENSION E-r LB 24.81 11055. 29.41 13712. 24.86 9340. 26.48 10911. 15.50 9039. 18.45 6760.* 19.28 6411. 20.94 5960. 22.59 5528. 24.20 5161. 25.88 4828. K LB/F .30 .00 .00 .00 .00 .00 .00 .00 .00 .00 .00 WEIGHT LB/F 2.698 3.961 2.284 2.832 1.229 1.229 1.2.29 1.229 1.22.9 1.229 1.229 GHT IF 98 61 s. 32 29 29 29 29 29 29 29 t'tI. or AL EN~ l( l~ E 1( E ~ ~ c c ~ ~ iION LB )665. ~O49.. 19&3. "12. 1251. .760.* );f25. >838. >351. 1945. 1584. NAL TEti ] ] ] ~Iaf LB ~397. 3049. a540. 1>098. 1556. 5041. 5734. 5218. 1803. 1464. 1165. SPAN= 1000.0 FEET CREEP IS NOT A FACTOR * DESIGN CONDITION DESIGN PO!NTS TEMP ICE WIND F IN PSF O. .50 4.00 32. 1.00 .00 32. .50 .00 32. .00 25.60 -10. .00 .00 -15. .00 .00 O. .00 .00 30. .00 .00 60. .00 .00 90. .00 .00 122. .00 .00 HEAVY LOADING INITIAL SAG TENSION FT LB 29.72 11401. 34.82 14310. 29.71 9654. 31.52 11290. 19.59 7858. 22.79 6760.* 23.67 6509. 25.43 6062. 2.7.17 567/. 28.87 5346. 30.6( 5039. FIN} SAG FT 30.56 34.82 31..21 32.50 21.63 25.31 26.29 28.16 29.97 31.72 33.51 K L8/F .30 .00 .00 .00 .00 .00 .00 .00 .00 .00 .00 WEIGHT LB/F 2.698 3.961 2.284 2.832 1.229 1.229 1.229 1.229 1.229 1.229 1.229 SPAN- 1100.0 FEET CREEP IS NOT A FACTOR * DESIGN CONDITION DESIGN POINTS TEMP ICE WIND F IN PSF O. .50 4.bo 32. 1.00 .00 32. .50 .00 32. .00 25.60 .-70. .00 .00 ...15. .00 .00 o. .00 .00 30. .00 .00 60. .00 .00 90. .00 .00 122. ~no .00 HEAVY LOADING INITIAL SAG TENSION FT LB 35.05 11708. 40.63 14852. 34.98 992.9. 36.96 11658. 24.19 1705. 27.59 6760.* 28.52 6~41. 30.36 6148. 32.17 5804. 33.95 5503. 35.80 5221. FINAL SAG TENSION Fr LB 36.Q5 11387. 40.63 14852. 36.70 9468. 38.10 ll316. 26.67 6992. 30.49 6121. 31.49 5928. 33.44 5586. 35.33 5291. 37.14 5035. 39.01 4797. K LB/F .30 .00 .00 .00 .00 .00 .00 .00 .00 .00 .00 WEIGHT LB/F 2.698 3.961 2.284 2.83~ 1.229 1.229 1.229 1.229 1.229 1.229 1.229 spAN= 1200.0 FEET CREEP IS NOT A FACTOR * DESIGN CONDITION DESIGN POINTS TEMP ICE WIND F IN PSt O. .50 4.00 32. 1.00 .00 32. .50 .00 32. .00 25.60 -10. .00 .00 -15. .00 .00 o. .00 .00 30. .00 .00 60. .00 .00 90. .00 .00 122. .00 .00 HEAVY LOADING FINAL SAG TENSION FT LB 41.96 11652. 46.84 15344. 42.61 9712. 44.11 11641. 32.19 6899. 36.12 615f. 37.15 5985. 39.16 5681. f1.11 5415. 42.99 5181. 44.93 4960. INITIAL SAG TENSION FT LB 40.79 11982. 46.84 15344. 40.66 10172. 42.82 11986. 29.28 7578. 32.86 6760.* 33.82 6568. 35.73 6220. 37.62 5912. 39.46 5639. 41.38 5380. . LE ~ .~ .( .c .c .( .( .( .c .( .( .( WEIGHT LB/F 2.698 3.961 2.284 2.832 1.229 1.229 1.229 1.229 1.229 1.229 1.229 ~SION LB 11092. 1C310. 91~. 10954. 1121.. 6090. 5861. 54.78. 5150. 4869. 4612. .l kIF ~O 10 10 10 )0 )0 )0 )0 )0 )0 )0 ALUMINUM COMPANY OF AMERICA SAG AND TENSION DATA Betbel 138 tv Transmission Line 795 ACSR Nortbern Zone Wi th Dampening CONDUCTOR MALLARD 795.0 KCMIL 30/19 STRANDING ACSR AREA- .7669 SQ. IN. DATA FROM CHART NO. 1- 7 5'1 ENGLISH UNITS SPAN- 200.0 FEET CREEP IS A FACTOR * DESIGN CONDITION DESIGN POINTS TEMP ICE WIND F IN PSF O. .50 4.00 32. 1.00 .00 32. .50 .00 32. .00 25.60 -70. .00 .00 -15. .00 .00 O. .00 .00 30. .00 .00 60. .00 .00 90. .00 .00 122. .00 .00 HEAVY LOADING FINAL SAG TENSION FT LB 1.19 11204. 1.96 9929. 1.29 8718. 1.51 9050. .41 15246. .52 11804. .59 10609. .75 8265. 1.02 6~5. 1.22 5051. 1.41 4396. INITIAL SAG TENSION FT LB 1.08 12296. 1.11 11398. 1.05 10120. 1..25 10892. .41 15246. .49 12612.* .52 11959. .59 10531. .68 9110. .80 1718. .98 6299. K LB/F .30 .00 .00 .00 .00 .00 .00 .00 .00 .00 .00 WEIGHT LB/F 2.665 3.897 2.255 2.728 1.235 1.235 1.235 1.235 1.235 1.235 1.235 SPAN= 300.0 FEET CREEP IS A FACTOR * DESIGN CONDITION DESIGN POINTS TEMP ICE WIND F IN PSF O. .50 4.00 32. 1.00 .00 32. .50 .00 32. .00 25.60 -10. .00 .00 -15. .00 .00 O. .00 .00 30. ~OO .00 60. .00 .00 90. .00 .00 122. .00 .00 HEAVY LOADING FINAL SAG TENSION FT LB 2.58 11647. 3.93 11179. 2.75 9242. 3.13 9801. .91 15213. 1.20 1159~. 1.33 10448. 1.68 8247. 2.21 6287. 2.61 5327. 2.93 4749. INITIAL SAG TENS!ON FT LB 2.37 12672. 3.57 12300. 2.29 11068. 2.69 11399. .91 15213. 1.10 12672.* 1.1~ 11973. 1.31 10579. 1.51 9207. 1.16 7885. 2.11 6571. K LB/F .30 .00 .00 .00 .00 .00 .00 .00 .00 .00 .00 WE] LE 2.E J.E Z.~ 2."; 1.~ 1.~ 1.~ 1.~ 1.~ 1.~ 1.~ :GHT ~/F .65 191 !55 r28 !35 !35 !35 ~35 ~35 !35 !35 SPAN- 400.0 FEET CRE~P IS A FACTOR * DESIGN CONDITION DESIGN POINTS TEMP ICE WIND F IN PSF O. .50 4.00 32. 1.QO .00 32. .50 .00 3~. .00 25.60 -70. .00 .00 -15. .00 .00 O. ~OO .00 30. .00 .00 60. .00 .00 90. .00 .00 122. .00 .00 HEAVY LOADING FINAL SAG TENSION FT LB 4.38 12165. 6.31 12378. 4.60 9806. 5.17 10569. 1.63 15169. 2.17 11386. 2.40 10299. 2.99 8272. 3.78 6546. 4..39 5632. 4.83 5114. IN SAG FT 4.06 5.89 3.93 4.56 1.63 1.95 2.06 2.32 2.65 3.06 3.59 K LB/F .30 .00 .00 .00 .00 .00 .00 .00 .00 .00 .00 WEIGHT LB/F 2.665 3.897 2.255 2.7.28 1.235 1.235 1.235 1.235 1.235 1.235 1.235 SPAN= 500.0 FEET CREEP IS A FACTOR * DESIGN CONDITION DESIGN POINTS TEMP ICE WIND F IN PSF O. .50 4.00 32. 1.00 .00 32. .50 .00 32. .00 25.60 -10. .00 .00 -~S. .00 .00 O. .00 .00 30. .00 .00 60. .00 .00 90. .00 .00 122. .00 .00 HEAVY LOADING IN SAG FT 6.12 8.59 5.91 6.78 2.55 3.05 3.21 3.60 4.08 4.65 5.37 FINAL SAG TE;NSION FT LB 6.55 12718. 9.03 13509. 6.80 lG317. 7.54 11319. 2.55 :1511... 3.45 11196. 3.19 10184. 4.63 8344. 5.66 6822. 6.50 5941. 7.06 5472. K LB/F .30 .00 .00 .00 .00 .00 .00 .00 .00 .00 .00 WEIGHT LB/F 2.665 3.897 2.255 2.728 1.235 1.235 1,,235 1.235 1.235 1.235 1.235 SPAN= 600.0 FEET CREEP IS A FACTOR * DESIGN CONDITION DESIGN POINTS TEMP ICE WIND F IN PSF o. .50 4.00 32. 1.00 .00 32. .50 .00 3'2. .00 25.60 -10. .00 .00 -15. .00 .00 O. .00 .00 30. .00 .00 60. .00 .00 90. .00 .00 122. .00 .00 HEAVY LOAD ING FINAL SAG TENSION FT LB 9.04 13282. 12.06 14572. 9.29 10935. 10.21 12039. 3.74 14863. 5.03 11043. 5.$0 10112. 6.58 8451. 7.83 1100. 8.91 6246. 9.57 5814. IN SAG FT 8.51 11.62 8.20 9.32 3.69 4.39 4.62 5.15 5.78 6.51 7.41 K LB/F .3& .00 .00 .00 .00 .00 .00 .00 .00 .00 .00 WEIGHT LB/F 2.665 3.897 2.255 2.728 1.235 1.235 1.235 1.235 1.235 1.235 1.235 ITI T AL EN~ 1~ 1~ l~ 1J 1~ 1~ 1~ lC 5 E E aON LB J122. ~253 . l4el. 1916. .169. !611.* L990. )640. 1330. 1081. .879. IT!. T AL EN~ 1~ 1~ 1] l.~ 1~ 1 ~ ~ .l~ 1( c . i 1 1100 LB .611. 1200. ,926. !579. .114. !672.* ~Oll. "713. ..69. 1309. '196. ITI. T AI. EMf l~ l~ .14 1~ .1~ l ~ 4 i~ 1( ~ E 1 ;1ON LB 1115. )117. !381. ~182. ~049 . !672.* !035. )794. 1619. 1536. '508. SPAN= 100.0 FEET CREEP IS A FACTOR * DESIGN CONDITION DESIGN POINTS TEMP ICE WIND F IN PSF O. .50 4.00 32. 1.00 .00 32. .50 .00 32. .00 25.60 -10. .00 .00 -15. .00 .00 O. .00 .00 30. .00 .00 60. .00 .00 90. .00 .00 122. .00 .00 HEAVY LOADING FINAL SAG TENSION FT LB 11.81 13841. 15.37 15575. 12.06 11.75. 13.15 12725. 5.21 1.513. 6.92 10932. 7.51 10082. 8.82 8585. 1.0.27 7373. 11.58 6540. 12.3. 6138. INITIAL SAG TENSION FT LB 11.18 14619. 14.96 15996. 10.78 12833. 12.15 13772. 5.05 14976. 5.97 12672.* 6.27 12061. 6.96 10880. 7.74 9174. 8.64 8763. 9.10 1809. K Lair .30 .00 .00 .00 .00 .00 .00 .00 .00 .00 .00 WEIGHT LB/F 2.665 3.897 2.255 2.728 1.235 1.235 1.235 1.235 1.235 1.235 1.235 SPAN= 800.0 FEET CREEP IS A FACTOR * DESIGN CONDITIONDESIGN POINTS TEMP ICE WIND F IN PSF O. .50 4.00 32. 1.00 .00 32. .50 .00 32. .00 25.60 -70. .00 .00 -15. .00 .00 o. .00 .00 30. .00 .00 60. .00 .00 90. .00 .00 122. .00 .00 HEAVY LOADING FINAL SAG TENSION FT LB 14.85 14388. 18.93 16523. 15.07 11992.. 16.35 13318. 6.91 14190. 9.10 10861. 9.80 1G096. 11.32 8134. 12.95 7638. 14.51 6821. 15_36 6445. INITIAL SAG TENSION n LB 14.13 15113. 18.57 16836. 13.61 13215. 15.24 14343. 6.64 14895. 1.80 12672.* S.lS 12()88. 9.01 10968. 9.96 9928. 11.01 8984. 12.22 8094. K LB/F .30 .00 .00 .00 .00 .00 .00 .00 .00 .00 .00 WEIGHT LB/F 2.665 3.897 2.255 2.128 1.235 1.235 1.235 1.235 1.235 1.235 1.235 SPAN= 900.0 FEET CREEP IS A FACTOR * DESIGN CONDITION DESIGN POINTS TEMP ICE WIND F IN PSF O. .50 4.00 32. 1.00 .00 32. .50 .00 32. .00 25.60 -70. .00 .00 -15. .00 .00 O. .00 .00 30. .00 .00 60. .QO .00 90. .00 .00 122. .00 .00 HEAVY LOADING FINAL SAG TENSION FT LB 18.13 14919. 22.73 17421. 18.33 12487. 19~78 13999. 9.00 13900. 13..56 10823. 12.37 10118. 14.08 8891. 15.87 7892. 17.67 70894 18461 6735. INITIAL SAG TENSION fT LB 17.34 15595. 22.45 17635. 16.69 13702. 18.$9 14892. 8.45 14909. 9.87 12672.* 10.33 12117. 11.32 11057. L2.42 10079. 13.6;1. 9196. 1..97 8364. K LB/F .30 .00 .00 .00 .00 .00 .00 .00 .00 .00 .00 WE L 2. 3. 2~ 2. 1. 1. 1. 1. 1. 1. 1. IGRT B/F 665 891 255 128 235 235 235 235 235 235 235 SPAN= 1000.0 FEET CREEP IS A FACTOR * DESIGN CONDITION DESIGN POINTS TEMP ICE WIND F IN PSF O. .50 4.00 32. 1.00 .00 32. .50 .00 32. .00 25.60 -70. .00 .00 -15. .00 .00 O. .00 .00 30. .00 .00 60. .00 .00 90. .00 .00 122. .00 .00 HEAVY LOADING FI SAG n 21.65 26.76 21.81 23.44 11.32 1..29 15.20 17.08 19.02 20.96 22.08 IN SAG FT 20.79 26.58 20.02 22.17 10.49 12.19 12.72 13.87 1~.12 16.45 1.'7.95 WEIGHT LB/F 2.665 3.897 2.255 2.728 1.235 1.235 1.235 1.235 1.235 1.235 1.235 K LB/F .30 .00 .00 .00 .00 .00 .00 .00 .00 .00 .00 SPAN= 1100.0 FEET CREEP IS A FACTOR * DESIGN CONDITION DESIGN POINTS TEMP ICE WIND F IN PSF O. .50 4.00 32. 1.00 .00 32. .50 .00 32. .00 25.60 ~10. ~OO .00 -IS. .00 .00 O. .00 .00 30. .00 .00 60. .00 .00 90. .00 .0:0 122. .00 .00 HEAVY LOADING IN] SAG FT 24.49 30.95 23.57 25.99 12.78 14.75 15.36 16.66 18.05 19.51 21.1. FI SAG FT 25.39 31.01 25.51 27.32 13.93 17.28 18.28 20.32 22.38 24.44 25.78 K LB/F .30 .00 .00 .00 .00 .00 .00 .00 .00 .00 .00 WE L 2. 3. 2. 2." 1. 1. 1. 1. 1. 1. 1. SPAN= 1200.0 FEET CREEP IS NOT A FACTOR * DESIGN CONDITION DESIGN POINTS TEMP ICE WIND F IN PSF O. .50 4.00 32. 1.00 .00 32. .50 .00 32. .00 25.60 -.70. .00 .00 -15. .00 .00 o. .00 .00 30. .00 .00 60. .00 .00 90. .00 .00 122. .00 .00 HEAVY LOADING FINAL SAG TENSION FT LB 29.45 16340. 35.57 19815. 29.54 13787. 31.51 15638. 16~92 13155. 20.64 1.0187. 21.12 10255. 23.90 9321. 26.09 8541. 28.26 7889. 29.59 7538. INITIAL SAG TENSION n LB 28.41 16936. 35.57 19815. 27.36 14880. 30.04 16397. 15.31 14533. 17.56 12672.* 18.24 12200. 19.68 11310. 21.21 10499. 22.80 9769. 24.55 9076. K LB/F .30 .00 .00 .00 .00 .00 .00 .00 .00 .0() .00 WEIGHT LB/F 2.665 3.897 2.255 2.728 1.235 1.235 1.235 1.235 1.235 1.235 1.235 NAL TEti ] ] ] ] ] ] ] 3 ION LB 5430. a275. 2.958. 1589. 3644. )812. l>170. ~052. a134. 7384. 7009. ~Tl T AL EN~ If lE l~ l! l~ l~ 1~ 1J 1( c E ;rON LB ;060. 1397. ~112. >417. 1120. !612.* !145. L144. )226. 1398. 1611. rIAL TEN~ lE l~ lA ~ 1~ U ~ ~ 1J 1( ~ ~ ; ION LB ;507. ~123. 1505. )918. 1627. !672.* ~113. Ln9. )366. .589. ~8S5. NAL TEl IS ION LB .5921. .9087. .3406. .5150. .3424. .0823. ,0236. 9211. e3~3. 1662. 7267. IGHT elF 665 897 255 128 235 235 235 235 235 235 235 ALUMINUM COMPANY OF AMERICA SAG AND TENSION DATA Bethel 138 tv Transmission Line 795 ACSR Northern Zone No Dampening 795.0 KCMIL 30/19 STRANDING ACSR CONDUCTOR MALLARD AREA= .7669 SQ. IN. DATA FROM CHART NO. 1-751 ENGLISH UNITS SPAN= 200.0 FEET CREEP IS A FACTOR * DESIGN CONDITION DESIGN POINTS TEMP ICE WIND F IN PSF O. .50 4.00 32. 1.00 .00 32. .50 .00 32. .00 25.60 -70. .00 .00 -15. .00 .00 O. .00 .00 30. .00 .00 60. .00 .00 90. .00 .00 122. .00 .00 HEAVY LOADING IN] SAG "' 1.71 2.56 1.78 2.04 .6D .80 .98 1.09 1.38 1.16 2.25 FINAL SAG TENSION FT LB 1.12 7759. 2.65 7372. 1.99 5680. 2.21 6189. .60 10283. .80 7680. .93 6607. 1.33 4640. 1.92 3226. 2.22 ~782. 2.56 2415~ K LB/F .30 .00 .00 .00 .00 .00 .00 .00 .00 .00 .00 WEIGHT LB/F 2.665 3.897 2.255 2.728 1.235 1.235 1.235 1.235 1.235 1.235 1.235 SPAN- 300.0 FEET CREEP IS A FACTOR * DESIGN CONDITION DESIGN POINTS TEMP ICE WIND F IN PSF O. .50 4.00 32. 1.00 .00 32- .50 .00 32. .00 25.60 ..10. .00 .00 -15. .00 .00 O. .00 .00 30. .00 .00 60. .00 .'00 90. .00 .00 122. .00 .00 HEAVY LOMING INITIAL SAG TENSION rr LB 3.53 8499. 4.93 8915. 3.61 7026. 4.05 7588. 1.31 10156. 1.91 1680.* 1.91 1044. 2.37 586.. 2.87 4846. 3.(5 4029. 4..12 3372. FI~ SAG For 3.61 5.03 3.98 4.33 1.37 1.92 2.20 2.92 3.11 4.Z2 4.67 K LB/F .30 .00 .00 .00 .00 .00 .00 .00 .00 .00 .00 WE L 2. 3. 2. 2. 1. 1. 1. 1. 1. 1. 1. rIAL TEN~ , j E E 1( , E c ~ , ~ lION LB 'e07. '619. .332 . .702. )283. '680.* .991. .672. ~.86. ~S10 . ~1"'. ~ TEN~ E E E . 1( , E ~ .. ~ ;ION LB 1320. 1724. .383. '098. )156. '253. ;310. 1755. ~688. 1298. ~977. IGRT 8/T 665 897 255 728 235 235 235 235 235 235 235 SPAN= 400.0 FEET CREEP IS A FACTOR * DESIGN CONDITION DESIGN POINTS TEMP ICE WIND F IN PSF O. .50 4.00 32. 1.00 .00 32. .50 .00 32. .00 25.60 -70. .00 .00 -15. .00 .00 O. .00 .00 30. .00 .00 00. .00 .00 90. .00 .00 122. .00 .00 HEAVY LOADING FINAL SAG TENSION FT LB 5.97 8936. 7.86 9931. 6.41 7050. 6.89 7935. 2.47 9991. 3.55 6970. 3.99 6199. 4.98 4965. 6.03 4102. 6.61 3741. 7.1'7 3450. INITIAL SAG TENSION n LB 5.82 9116. 7.75 10080. 5.88 1611. 6.50 8404. 2.47 9991. 3.22 7680.* 3.48 1106. 4.08 6063. 4.77 5185. 5.52 4411. 6.36 3891. K LB/F .30 .00 .00 .00 .00 .00 .00 .00 .00 .00 .Go WEI LB 2.6 3.8 2.2 2.7 1.2 1.2 1.2 1.2 1.2 1.2 1.2 SPAN= 500.0 FEET CREEP IS A FACTOR * DESIGN CONDITION DESIGN POINTS TEMP ICE WIND F IN PSF O. .50 4.00 32. 1.00 .00 32. .50 .00 32. .00 25.60 -70. .00 .00 "'l~. .00 .00 O. .00 .00 30. .00 .00 60. .00 .00 ~. .00 .00 122. .00 .00 HEAVY LOADING FINAL SAG TENSION FT LB 8.74 9540. 11.08 11017. 9.22 7661. 9.83 8692. 3.94 9800. 5.65 6830. 6.23 6202. 7.43 5198. 8.65 4468. 9.37 4125. 10.02 3858. INITIAL SAG TENSION FT LB 8.51 9806. 10.97 11127. 8.54 8267. 9.34 9140. 3.94 9800. 5.03 7680.* 5.39 7168. 6.18 6252. 7.04 5486. 7.95 4862. 8.93 4332. WEIGHT LS/F 2.665 3.897 2.255 2.728 1.235 1.235 1.235 1.235 1.235 1.235 1.235 K LB/F .30 .00 .00 .00 .00 .00 .00 .00 .00 .00 .00 SPAN= 600.0 FEET CREEP IS A FACTOR * DESIGN CONDITION DESIGN POINTS TEMP ICE WIND F IN PSF O. .50 4.00 32. 1.00 .00 32. .50 .00 32. .00 25.60 ...70. .00 .00 -15. .00 .00 O. .00 .00 30. .00 .00 60. .00 .00 90. .00 .00 122. .00 .00 HEAVY LOADING FINAL SAG TENSION FT LB 11.89 10107. 14.66 11999. 12.38 8213. 13.13 9315. 5.95 9339. 8.20 6781. 8.88 6263. 10.26 5423. 11.62 4791. 12.48 ..62. 13.22 .215. INITIAL SAG TENSION FT LB 11.58 10381. 14.57 12072. 11.56 8191. 12.55 9901. 5.79 9597. 7.24 7680.* 7.70 7228. 8.66 6423. 9.68 5749. 10.72 5193. 11.83 4108. K LB/F .30 .00 .00 .00 .00 .00 .00 .00 .00 .00 .00 WEIGHT LB/F 2.665 3.897 2.255 2.728 1.235 1.235 1.235 1.235 1.235 1.235 1.235 GHT IF 65 97 55 28 35 35 35 35 35 35 35 SPAN= 700.0 FEET CREEP IS A FACTOR * DESIGN CONDITION DESIGN POINTS TEMP ICE WIND F IN PSF o. .50 4.00 32. 1.00 .00 32. .50 .00 32. .00 25.60 -10. .00 .00 -15. ~OO' .00 o. .00 .00 30. .00 .00 60. .00 .00 90. .00 .00 ~22. .00 .00 HEAVY LOADING FINAL SAG TENSION rr LB 15.40 10630. 18.59 12892. 15.90 8711. 16.77 9993. 8.49 8922. 11.17 6784. 11.93 6350. 13,.45 5633. 14.94 5075. 15.94 4758. 16.75 (529. INITIAL SAG TENSION For LB 15.01 10903. 18.53 12928. 14.94 9270. 16.12 10395. 8.06 9392. 9.86 7680.* 10.40 7282. 11.52 6573. 12.68 5976. 13.94 5477. 15.01 5033. K LB/F .30 .00 .00 .00 .00 .00 .00 .00 .00 .00 .00 WEIGHT LB/F 2.665 3.897 2.255 2.728 1.235 1.235 1.235 1.235 1.235 1.235 1.235 SPAN~ 800.0 FEJ:T CREEP IS A FACTOR * DESIGN CONDITION DESIGN POINTS TEMP ICE WIND F IN PSF o. .50 4.00 32. 1.00 .00 32. .50 .00 32. .00 25.60 -70. .00 .00 ~lS. .00 .00 O. ~Oo .00 30. .00 .00 60. .00 .00 90. .00 .00 122. .00 .00 HEAVY LOADING FINAL SAG TENSION FT LB 19.25 11109. 22.85 13706. 19.76 9160. 20.75 10552. 11.49 &607. 1..52 6815. 15.36 64.6. 17.00 582f. 18.60 5327. 19.7f 5021. 20.63 4807. INITIAL SAG TENSION F'l' LB 18.80 11374. 22.84 13707. 18.66 9694. 20.03 10931. 10.75 9197. 12.98 7680.* 13.50 1329. 1(.16 6104. 16.04 6173. 17.31 5722. 18.6. 5315. K LB/F .30 .00 .00 .00 .00 .00 .00 .00 .00 .00 .00 WEIGHT LB/F 2.665 3.897 2.2552.729 . 1.235 3..235 1.235 1.235 1.2~5 1.235 1.235 SPAN- 900.0 FEET CREEP IS NOT A FACTOR * DESIGN CONDITION DESIGN POINTS TEMP ICE WIND F IN PSF O. .~O 4.00 32. 1.00 .00 32. .~O .00 32. .00 25.60 ...70. .00 .00 "'15. .00 .00 O. .00 .00 30. .00 .00 60. .00 .00 90. ~OO .00 122. .00 .00 REA VY LOADING FINAL SAG TENSIC»f rr L8 23.53 11511. 27.50 14418. 24.03 9531. 25.14 11029. 15.05 8323. 18.36 6827. 19.25 6512. 21.00 5972. 22.69 5529. 23.84 526~. 24.79 5065. INITIAL SAG TENSION FT LB 22.95 11800. 27.50 14418. 22.75 10013. 24.29 11413. 13.88 9018. 16.31 7680.'* 17..00 7371. 18.38 6818. 19.71 63'2. 21.14 5934. 22.57 5560. WEIGHT LB/F 2.665 3.897 2.255 2.728 1.235 1.235 1.235 1.235 1.235 1.235 1.235 K LaIr .30 .00 .00 .00 .00 .00 ~oo .00 .00 .00 .00 SPAN- 1000.0 FEET CREEP IS NOT A FACTOR * DESIGN CONDITION DESIGN POINTS TEMP ICE WIND F IN PSF O. .50 4.00 32. 1.00 .00 32. .50 .00 32. .00 25.60 ~70. .00 .00 -15. .00 .00 O. .00 .00 30. .00 .00 60. .00 .00 90, .00 .00 HEAVY LOADING FINAL SAG TENSION FT LB 28.17 11877. 32.51 15069. 28.67 9976. 29.89 11460. 19.06 8114. 22.59 6a51. 23.53 6579. 25.37 6105. 27.15 5101. 28.34 5470. K LB/F .30 .00 .00 .00 .00 .00 .00 .00 .00 .00 WEIGHT LB/F 2.665 3.897 2.255 2.728 1.235 1.235 1.235 1.235 1.235 1.235 INITIAL SAG TENSION no LB 21.45 12185. 32.51 15069. 21.18 1.0412. 28.90 11849. 17.46 8851. 20.14 7680.* 20.89 ;407. 22.38 6916. 23.86 6«$9. 25.32 61.18. 122 00 00 00 1.235 29.36 5283 26.84 5773 SPAN= 1100.0 FEET CREEP IS NOT A FACTOR * DESIGN CONDITION DESIGN POINTS TEMP ICE WIND F IN PSF O. .50 4.00 3~. 1.00 .00 32. .50 .00 32. .00 25.60 -10. .00 .00 -15. .00 .00 O. .00 .00 30. .00 .00 60. .00 .00 90. .00 .00 122. .00 .00 HEAVY LOADING FINAL SAG TENSION FT LB 33.17 12211. 37.86 15666. 33.66 10183. 35.00 11852. 23.52 7962. 27.23 6983. 28.21 6645. 30.13 6225. 31.99 5867. 33.21 5652. 34.28 5477. INITIAL SAG TENSION FT LB 32.31 12533. 37.86 15"6. 31.97 10715. 33.87 12243. 21.43 8715. 24.39 7680.* 25.18 7.38. 26.77 7000. 28.34 6616. 29.87 6277. 31.48 5960. WEI( LB! 2.6E 3.BS 2.2~ 2.7~ 1.2~ 1.2~ 1.2~ 1.2~ 1.2~ 1.2~ 1.2~ K LB/F .30 .00 .00 .00 .00 .00 ..00 .00 .00 .00 .00 SPAN- 1200.0 FEET CREEP I S NOT A FACTOR * DESIGN CONDITION DESIGN POINTS TEMP ICE WIND F IN PSF O. .50 4.00 32. 1.00 .00 32. .50 .00 32. .00 25.60 -10. .00 .00 -15. .00 .00 O. .00 .00 30. .00 .00 60. .00 .00 90. .00 .00 122. .00 .00 HEAVY LOADING IN SAG FT 31.54 43.57 31.13 39.19 Z5.94 29.04 29.88 31.55 33.19 34.80 36.48 FIW SAG FT 38.54 43.57 39.02 40.46 28.40 32.25 33.27 35.26 37.18 39.44 39.56 K LB/F .30 .00 .00 .00 .00 ..00 .00 .00 .00 .00 .00 WE L 2. 3. 2. 2. .1. 1. 1. .1. 1. 1. 1. ;HT 'F ;5 17 ~S ~8 15 15 I~ 15 15 15 15 TIAL TENSION La 12847. 16214. 10988. 12600. 8593. 1680.* 7465. 7073. 6126. 6411. 612.. ~SION LB 12516. 16214. 10(61. 12209. 7850. 6919. 6709. 6334. 6009. ~815. 5651. IGHT 8/F 665 897 255 728 235 235 235 235 235 235 235 2. EMF Calculations Nuvista Light & Power, Co. – Donlin Creek Mine Power Supply Alternatives Feasibility Study Draft 9/19/03 Ground level magnetic field strengths, associated with the single pole Structure Type B, were calculated using a simplified form of the equations contained in the article titled, “Accurate Formulae of Power Line Magnetic Fields,” which is attached at the end of this appendix sub-section. Magnetic field strengths, for both the 138 kV transmission circuit and the 13.8 kV underbuild circuit were calculated separately and then added vectorally to obtain the resultant magnetic field. Calculations assume a 150 degree phase- shift between the 138 kV circuit and the 13.8 kV circuit. The results of the calculations, with graphs, are contained in the subsequent pages. Magnetic Field Calculations Sturcture Type B Assume 50 feet to top of pole height u:= .00000126 75000 138.1.732 Max current in amps in 138 kv Circuit~ = 313.787~:= 15000 13.8.1.732 Max current in amps in 13.8 kv Circuit ~ = 627.573100 := 0 25 50 75 100 125 150 175 200 distance from centerline in feet 1:- 16.<XX> 17.728 22.104 27.911 34.434 41.335 48.452 55.703 63.041 ~:=~;!..:':.iL 3.28 slant distance from 138kv center conductor in metersRcr=1 13.72 15.695 20.509 26.666 33.432 40.504 47.745 55.089 62.5 slant distance from 13.8 kv center conductor in meters ~= 52.103 42.472 27.321 17.134 11.258 7.813 5.686 4.302 3.359 magnetic field strength at ground level in MG from 138 kV circuit 3 ...fi . &lct . 24.3. 1416-Rci 101Bd:=Bd= 115.808 88.495 51.826 30.655 19.502 13.287 9.562 7.183 5.58 nag netic field strength at ground level in MG rom 13.8 kv circuit.J'3.u.Iw . 2-3.1416-Rw2 101B.:= Underbuild Magnetic Field ~= ~ .s "0 :i B.., It. u- 'i J Bdi:= .S.BdBdr:= -.866-Bd Bres := 4 (B. + ~)2 + Bdi2 '15.335. 55.904 31.303 11.988 11.26 1.601 5.44 4.012 \. 3.156 Combined magnetic strength of 138 kV and 13.8 kv circuits at ground level in MG Bres= ~ .s "U u BIQ io: - .. -'6 Q ~ Magnetic Field Calculations Sturcture Type B Assume 60 feet to top of pole height u:= .00000126 75000 138.1.732 Max current in am ps in 138 kv Circuit~ = 313.181~:= 15000 13.8.1.732 Max current in amps in 13.8 kv Circuit ~ = 627.573Iw:= 0 25 50 75 100 125 150 175 200. distance from centerline in feet s:- "19.055 20.523 24.402 29.765 35.953 42.~ 49.543 56.654 .63.884 ~:= (62.s2 + s1)-' 3.28 slant distance from 138kv center conductor in meters~= 16.768 18.419 22.662 28.355 34.795 41.636 48.709 55.927 63.239 Rw := ~~~~ 3.28 slant distance from 13.8 kv center condudor in meters ~= '36.764 31.693 22.417 15.~7 10.327 7.353 5.438 4.159 3.271 magnetic field strength at ground level in MG from 138 kV circuit 3..fi.Uoica 4.3.1416-~2 to'Bd:=B.= 77.524 64.249 42.445 27.111 18.005 12.574 9.187 6.969 5.451 magnetic field strength at ground level in MG from 13.8 kv circuit..[3-0-1..,. 2.3.1416-R.,2 10'B.:= ~= -.866.Bd Bm:= .S-Bd 4(8.+ o.f + B.2 49.246 40.07 25.615 15.954 10.429 7.214 5.239 3.958 3.087 Comtjned magnetic strength of 138 kVand 13.8 kv circuits at ground level in MG Bres= ACCURATE FORMULAE OF POWER LINE MAGNETIC FIELDS ACCURATE FORMULAE OF POWER LINE MAGNEnC FIELDS G. FILIPPOPOUWS gfi~~~8.ariadne-t.8[ D. TSANAKAS Tsaoakas_. JIIIm. &r DEPARTMENT OF ELEcrRICAL AND COMPUTER ENGINEERING UNIVI:RS ITY 0 F P A TRAS 26500, RlON, GREECE Abstract A<Xur8e u.~4 formulae of die u.pric field ~ so~ commonly ~ CODfigIntiooa of powa' tinea 8'C ~ This is achieved by die 1me of two oopies of the complex numbers.. The me~. D8med Ci. is used to ~t the vectms in the vertical plane (where die magnetic flux density vector is considered). The ocba: ~. D8med Cp is ~ 10 "'jw-..m die 8ial8>id8I ValYiDg <PJ8Dtities - P-I<n. The rotating vectm of die D»pbc t1ux dmsity ocx:un as a combination of the two complex number sets, belonging 10 die set of die c..ian ~ Ci X Cjt I8D.cJ ~uble compIa manben. The D81Detic flux dcoaity ~. as a dooble complex oumber is described tmougb remarkably simple relations, making die develop~t of accmate mathematical formulae for it poI81ole. TheBe formulae exJX'e8S die magDCtic flux density vectm as a ftDIctioD of die line goo~trical parameta'S and the relative distalx:e from it. Similar f(X1Dll)ae for the resultant value of the magnetic field, . ~y ~ CP81titY 10 ~ die m8gDetjc field, ~ al8O ds'ived. As eumpIes -=curate formu1~ of the magnetic field ~ single circuit power 1ines in flat. vertical aDd delta configurations aDd bexagOO 1ines in vanom coofiguratioos 8'C plelellted. Introduction1 The last ~ tile magIIetic fields produced anxmd power lines are CODsidcred. 8D a1~~1 factor. The calcuJation of b IIapetic fiekl values at grotmd Ievel1mder . pow« Ijoe is UIUaJIy made 8riduDeticany with the use ofa computer [I]. However, the arithmetic calculation doa not allow 8D insight at the Imgnetic fiekl..-~~ 8M! its depelXlencies of tile v8rioUl p8'8meten of tile leaing. For example, b mapdic field at groa level is calculated at . specific dist8)Ce {r(XD the line axis and considaing . specific height of the ~~~ m the gro1BKi.This ~CX1 is Iq)e8fed f« v.KxIS dj8I8Jces in 0Ida- m get the aagnetic fiekl profile. For different conductor heights (X" if there is a change in the line 8IT8Dgeoxnt, the wJx>1e process must be repeated. Also the results refer to . specific line am cannot be euiIy gen«a1ized. However, computational investigaticms are made in order to ~ some geDeral conclusioos aboot tile ability of some power line CCX1fi~ m ~ the ~ ~ fiekla. Fm ~e, domle ciraJit IiDes in low ~ CODfigmatioo am compact lines were f(MJnd to ~ce the magootic fields in [2,3]. In [4] ~~ a~xiII81c fi)nDuIae of b m8gDetic fieki wae JXe8eIIted. These mrmuJ8e wac b8Ied m b ImIltipole expansion of the magnetic field and are JXCCise at ~1ative big distances from the line in com.-riSOD to the djst8Dce8 between its ~. These f(X1Dll)ae ~ very useful in the determiMtioo of the way the magnetic field decays away from a power line. F<X" example, the fast reductim of the magDetic field away from . cblble ciraIit Iiae in low ie&..~ pbMiJI8 was exp1aiocd: pl8CiDg b oooGJCtcn in IUd1 a way tb8t the tint tenDs of the multiJX>le ex.-usioD is zeroed, the magnetic field far from the line is minimized. However, these formulae do P sfM)w the bebavio- of the aagoetic field Imder the line, where tbae 1IB18l1y is 811 iI-=I'eUed interest. In most cases it is important to know the magnetic field maximum value uDder the line and where it ~. In this p8pa' Mx:ur8te ~ bDD1I8e of the 08petic fiekI ~ 80~ commonly used coofiguratioos of JX>w~ lines are derived. 83 D. TSANAKAS G. FILIPPOPOULOS In [1.2,3,4] the complex mDnben were p'e~ed as phasms to tep'eseDt the sinusoidal varyjng quantities. In this paper, complex numbers are also used to represent the vectors in the traverse plane to the cooductors, where the magnetic field is coosi~ This is possible if a system with two imaginary units is used. In [5] many imaginary 1mits are used, reaching to systems of hypercomplex n~. So the innovation of this approach is the simuItaoeous use of complex numbers to represent plane vectors and phason. After this rep-esentatioo the magnetic field rotating vector is represented by a new set of numbers, named double complex numbers. These numbers are a combination of the complex numbers repoeseDtiDg plane vectors with the complex numbers representing sinusoidal varying quantities. The double complex numbers and their basic properties, from a mathematical point of view, are briefly discussed in the AAJeDdix. As to denotation bold letters are used for vectors, underlined letters for phasors am bold UIklerlined letters for double complex numbers. Also small letters indicate iostaotaoeous values and capitalletteIS nos values. Magnetic field calculation using double complex numbers2 Figme I shows the space arrangement of the conductCI'S of a power line in relarion to the xyz axes system The line route is considered straight and parallel to the z-axis. The line conductors are not straight ~t they are sagged by their weight. The curve that is dIawn by each conductm- at a span between two sequential suspension points is known as the caterJary curve. In order to simplify tile calculations and the analysis of the magnetic field produced by the line; the model of an assembly of OOrizontal cooductm in z-axis is used. This model is precise in the prediction of the nmgoebc fields if the conductm- sag is su.lll in comparison to the span. A typical value for high voltage line conductor sag is 10m for a span of 350m. Figure 1. SpKe arrangement of the condudors of a power line. Figme 2 shows a trava-se section of a power line modelled as an assembly of three conduct(X"8 parallel to z-axis. This section is actually the xy plane, where the conductors are shown as single points. The conductor k is caring die CmTent it towards die positive z-axis direction. The magnetic flux density bt which is created by die k conductor, is given by the Ampere law: (2-1)l1oit (i. x Rt) 2xR~ .~=~ where 110 = 4K 10-7 ~ is the magnetic permeability of free space, et is the unit vector in the directim ofz- Am axis, Rt is the vector distance from the k coOOuctor to the point of interest P and the symbol x denotes the cross product of the vectors et and Rt . Equation (2-2) could be simplified if the vector distances on ~ xy plane were represented as complex numbers. On the other baOO, for ac lines the cond\K:tor CU1Tent8 are sinusoidal quantities ~ by pbasors, which are aJso (2-2~plex numbers. It is clear that having only one set of complex numbers does In the geneml case a line with D 0000uct01's may be considered Using the SUpel1X>sition thoorem, the magnetic flux density b produced by the line is the vector sum of the fields prodoced by each conductor separately: b=tbt =~t.!!~~ t=1 2KpI R1 t 84 ACCURATE FORMULAE OF POWER LINE MAGNETIC FIELDS ~ aJkJw the simuJ18IecKIs 1.~l8tj(.ii of the ~ in the xy pJaoe and the current phasors. In order to solve this problem two ~iea of the oomplex numben set are used: I) The set Cj of the oomplex mImben with the imagiD8y 18rit i (i' = -I ) 8J.I 2) the set Cj of the oompJex oumben with the illBgimry unitj and (jl = -I ).It is DOted that i ~ j. The let Cj is used for the represeotation of ~ 00 the xy plane. Each vectCX' on the xy plaDe a S xe. +)ti '1 (e. 8Dd e, 8C the unit vectcn on x - y axi.) i. i"...~Dted by die complex Dumber a = x + iy. V.iDg d1is leJX'eIeD1abon, die factCX' (e. x at }/R: iD (2-2) is writtm .. i/Rt, where Rt is the conjugate complex Dumber of at (Rt S x - iy) - the &cfDr i i. 18ed m alter . .:12 roC8ticm iD-.d of the outer product with the uDit vector e. . TI8 et C; i. 18d b die tepr_tation of IilnlmMkl quaitiea - E8dI liIaJ8Oidal qu81tjty it - .[ilt coI(a)t+~t) is represented by die complex number !t = Ite~ through the re1ation it - Ji ~eJ8t). U8iDI tbeIe repam18tioos, (2-2) giv~: b=J2"Rej(@e;") B=~:tlL- 2K tool Rtw~ The vector b is ii:fli,,8eIJted by I.. which is a double romplex noomer (dea:n"bed in 1be AppaIdix). The 1erm Re J is an expansioo of the real ftmction, meaning the real part of the double complex number as to the im8giDary mOt j: Rei (a + ib + jc + ijd) = a + ib . The double complex numbu ~ may be wrinen in the foDowing forma: ~ =~. +i~y = B, + jBj = BD +iB,,+ jBu +ijByi The pbasors ~. and ~y .~~t die comlX>Dents of b on x aud y-axis, respectively, which are sinusoidal quaurities. The v~ B, aud B, 8e refa- to die rQi 81d imagiD8y J*t of b, ~ by die relations: (1-6) w~ It., ... It,; ~ the real aIxI the iu.girary J*1 of die current !t . The va:tor b as a fimctim of time (2-3), tI8Ces an ellipse. Figure 3 shows tms ellipse defined by its major 85 FiI8re 2. TraveIR IeCOOO of a power line model. G. FILlPPOPOULOS D. TSANAKAS gelDi.,.xjs B. 8IXI its mimr semi..xis B.,. The factor I / J; is used to convert the maximum instant values to ~ valUtS. However, a very signi&~ p8r8IDeter of the u.gDetic flux deosity is its resuIIaDt vaI~ B, which is equal to the I18gnitude of the d«MJble co~1ex number !: Filwe 3. The elli)Me ~"bed by die vector ~. (1-1) 3 Multipole expansion of the magnetic flux density Fillft 4 8IMJws apio die tI8~ IectioD of. powa: m.. The amattB 8C c~ by their pb8Ims !t aod the place of die k conductor is cbuacterized by its vector distBnce dt; from 8 referax:e point 0, which is 8 cenml point of the line. The point 0 is cloee 10 bm not oeceaarily die centre of the cuxbr;tor arrmgement. The vect<K R defines the djSf8k:e from the point 0 to ~ point of interest P. Replacing die dj8f8Dc:e of ~ point of interest P from die c<XJductor k: Rt = R -dt, and using die equation (R-dt)-' =fd;-'/R1 (valid for R >dt) in (2-4), itresuJtl 1=1 the muJtipole expansion of~ ~gnerlc field flux dellSity: . ~ = L~(l) 1=1 Fipre 4. Travene secbOO of a pow~ Hoe ~ pating die reference point o.where: and (3-3) ~ tams 1b8t inVaBely depend with 81 iJx:IaIiug fon:e of the dilt8Dce R. Each term ~(A) of this sum is called ).. orderThe muItipole expaosi(B1 is die ex.-essioD of the magnetic flux density as a sum of 86 ACCURATE FORMULAE OF POWER LINE MAGNE'nC FIELDS tenD of the mas-tic: fbJX density atxI i. expressed through (3-2). The factor !La is called the ). order mo~ of the magDetic fbJX deosity. Both able complex numbers ~(l) aDd ~ eXpaI elliptical rotating vectors. The term ~1) may be cak:uJated ~ the cakulatioo of the mo~ Ml atxI the di8t8Dce from the line R. FigtR S shows the relation betweal the ellipse traced by MI aDd the ellipse traced by ~l) at def~ pI-=a ar<Xmd the tine . ~ The ~ expression of the ~ flux density A. order term is due to the capabilities of the double complex to ~R8 the elliptical nDDng vectors. It should be ~ that in [4] only the tint four tenDS of the magnetic flux deDSity multipole expansion WeIe derived. Also in [4] the magnetic field away from the powa- line was approxinmsed with the tint noo-~ term of the omItipole expansion. Fig8re S. ReI8tioD betw~ the ellipses defioed by M2 am ~(2) . 4 Single circuit lines The D8gDetic flux deosity aroUI.J. single circuit tine OODsisting oftbree pb88e ~ (a. b mid c) is ~ from (2-4) 88 B=~ - 2x I I I ~+~+--3.- R-d. R-d~ R-d. Making M)OX maDipJJa~ (4-1) ia writtaI as: :@ = ~ + L)R~~ [(db + d.]-o ~ (d~: d.)!b ~ (d~ +_db~~ + ~bd~~ +!.d.!b +a.db!. 2. R - d. +db +d.)R + dbd. +d.d. +d.db +d.dbd. Coosidering die pt.8es aIx: coosist a positive sequeuce system, their CIKrm1B are related according to: 1. -!.!~ =!2! !. =!! where ! = eJ28/J Replacing these equ8tioI8 in (4-2), it becomes: 87 D. TSANAKAS G. Fll.IPPOPOULOS 1- - -- 1-- -- ~= ~-3 d. +! db_+~~C +~bdc!~ d.~c_+~.d~ -- 2. R - d. +db +d.)R + dbd. +d.d. +d.db~-d.dbdc The resultant value of the magnetic flux density is calcuJated by (4-3) as B = II Ji.. !(d. +!2 db +!d.. +dbd. +!2 d.d. +!d.dbl B=-""2;1R3 -(d. +db +d..2 + dbd. +d.d. +d.db --d.dbd.1 Equations (4-4) and (4-5) get much simpler f0rD)8 when they refer to specific coofigln'ations of lines. Table I gives the exp-essions for the magnetic flux density vector and its resultant value for the three most commonly used configurations of single circuit lines. Table 1. Accurate fOrlmJ1ae of the magnetic flux deDsity vector '- aIxl resultant value B for single circuit lines Accmate formulaeLine configuration B =~jJ3R-8 - 2d "{R'1-:;1J FJataJTaDgement B=~jJ3R-is- 2& ~~ Vertical arrangement b Delta arrangement Hexagon line5 Figure 6 shows die tnav~ sectjon of a hexagon JiM. The amductors of this line are placed on die com~ of a regular hexagon. The advantage of hexagon lines for the magnetic field calculatjon is their symmetry. 88 ACCURATE FORMULAE OF POWER LINE MAGNEDC FIELDS Coosidering the reference point 0 at the ceDtre of the hexagoo, the vector distances of the comers from 0 is given by simiJar expressions: i(t-l~,(5-1)Ie ) a ~ J \ ~ Figure 6. A hexagon line Equation (3-3) giws the '" order DX)ment. Replacing (5-1) in (3-3) it results: This relation results that there is a general ~ursive relation betw~ the '" +6v and the '" order moment of the maptic flux density. So, ca1culating the 6 first moments, the rest are derived: M6¥+1 = 860M. The recursiveness of the mooxnts results similar relations betw~ the magnetic flux density terms. The A. order tenn oftbe ffi-~C flux density id given by (3-2). Equation (3-2) in combination with (5-3) results: iJloMl S ~(6Y+l) = ~ 6w Fi" So an the tenns of the multipoJe expansion of the magnetic flux density in (3-1). may be separated in 6 groups. as shown in the following relation: Each of die 6 sums appearing as terms in the former equab(Xl are caJcuJated as: iJ1 M ji"~1 -!- -1 2~ ji"6 -86 ~~6~1) = Replacing this in (5-6) it gives: -, -. -3 -1 - B =~M,R +M1R +M!.-R +M.R +M5R+M6 =~~ - 2. R6 -S6 2. R6 -S6 89 G. FILIPPOPOULOS D. TSANAKAS 6 ~ = LM.R6-1 1-1 where The ~ value of the D8pbc flux deDIity ocaus .. the D8gnihx1e of ~ 8IxJw ~ N118- H= 2; (It 12 - 21. ~.~ CG~ + S12)i ~ the distaJx:e 8 aIKl the angle . Ee DJwD m figme 6. The calculation of the u.gDetjc field flux daIsity ~ cmsists in the caIcu1atioD of ~ from the 6 tint DX>ments. The calcu1atioo of the ~gnetic field flux density rms value consists in the calculatioo of N = ~ . The value of ~ depaIck on die line configmation. In table 2 three OODHDOD configuratiooa of a hexagOO line 8'e examined It sbooJd be ooted that even ~ the JXe8eDted medM>d aauma that R>a, these fonnuJae are also valid for R:S s . 6 Conclusions Accurate fmmu1as of the magnetic field vector am its resul1aDt value for oomrmnly used contigmations of power IiDeI have been developed. TheBe fixTmI]as nay be used in the 8CCUJ8te estimation 8Id the analysis of the magnetic field values around tbe8e liDes. As an example, for a flat power line, it is possible to calculate for the magDdic field pofiJc at grot8Id level. its u.xjmum value 8Id the exact dis88Ic:Ie from the line axis ~ it awean. keeping the disIaoces betw~ the phase coodIx:tm'8 8IKIthe dis1aIx:e from the coIMI1-=tOIS to grolDJd .. p88IDeIen. AJBO the ~ field lewla of diffamt poWa' line ooofi~ caD be ~. Double oomplex numbers JXOved to be VefY efficialt for the Jep'eseDtatioo of the IU8ptic field vecton. Their OR simplified die eXpRAK;jJS of die nagneric field pOOuced by fKJWa- )iDes 8Dd allowed the deve~ of the accumte fonnuJae. Also the magnetic field multipole expansion teIms were simplified and a general expreSlim ofdle)"-onfer tam W88 presaI~ Howeva-, it ~U.iD8 fcx-. futIDe.-per to show bow the ~ of the ellipse dcsat"bed by the magnetic field vector, such as the najor semi..xjs, ae ~Iated to the double ~Iex mmber .- "i'~ the field 8Dd bow d1ese paI8meten C8I be ~ ftom this ammer. It raD8im f(K futme work to examine M)IDe ~ co~lic:aaed ~ of power Jj~ ~ fi~. A true double cmJit line ~ ~ 08Y dectiDc IigDificmdy from tile e~mined cue of bexagoDa1lines. FUI'dler more the currents might not be well balanced or 80~ significant bannoDics levels may have been in~ 7 References (IJ D. W. Deao, L. E. ZaffaoeUa: "FiI«i effects of o\/el'lle8d tIanImi_ion linea 8Id 188tioo8" CbapR:r 8 of the "flammi_ion Line Refermce Book- 34SkV aOO Above", 2- ed. Electtic Power ReIe81:h Dtitute, California 1982. (2]D. TsaD8k:aI, G. Filippopoulos, J. Voya~s, G. ~: C<XDIJ8Ct 8IId optimum pbaee coIxIudOr arraugeJJaJt for the reduction of elecbic 8IId magnetic fieJds of overbead 1iues, CIGRE Report 36-103, Sellion 2000. {3]G. FiJiAJopoub, D. T---, G, KoovW8kja: ~ 8Id ~~u1BJd power line electric 8Id ~c fi~ reductjon ~ MiIlemium IntemationaI Workshop 00 Biological Effects of EIec~ Fields, Crete, Greece, October 2000. [4]W. T. KaIaIe. L. E. Zafr8DeI]a: AIaIy8is of masDetic fiekk produced £. from electric power tioea, IEEE TrBDS8ctioos 00 Powa' Delivery, VoL 7, No 4, pp. 2082 - 2091, October 1992. 90 ACCURATE FORMULAE OF POWER LINE MAGNETIC FIELDS I. L. Kantor, A. S. SolodovDikov: "HyperoompJex Numbers - An Elementary Introd1M:tion to Algebras" Springer-Verlag 1989, ISBN: 0-387-96980-2, ISBN: 3-540-96980-2 (Translated from Russian to English langtage by A. SbeDit7er). [5] 91 D. TSANAKAS G. FILIPPOPOULOS Table 1. Accurate fOrlmlIae of the magnetic flux density va;tDr , aOO resultant valtE B for hexagon lines. Accurate formulaeLine configmation b.b. ae I .jB=.c super-bundle double circuit line b.c. a8 1 R u -2R 6,6 ~n)2 3.Jil1oIs2~ R. +8. B. ~.c low-reac1aDCe double circuit line b.c. .. .e six phase line Appendix: Double Complex Numbers and their properties General The ooubJe complex nay be used wba1 d1ere is a need to use sioml1aneousiy two ~ts of oomplex numbers. In this case, two ~ies of the oomplex numben set is used the set Ci widi the imaginary unit i, and die set Cj widi the imaginary Imit j (i 2 = -I, j2 = -I and i - j ). The set of double oomplex numbers D is the Cartesian product oftbe set Ci to the Cj (D - CixCJ=R~. A double oomplex number! may be written in the forms: (A-1)=Zt+jzz =~ +i~ .a+ib+jc+ijd _I _z 92 ACCURATE FORMULAE OF POWER LINE MAGNETIC FIELDS ~ Zt - a + ib MOd Z2 ~ c + id are oomplex n\DnbeIB in the set C~ I; ~ a + jc and I; ~ b + jd are complex -1 -1 n\Dnbers in the set Cj and a, b, c and d are real numbers (in the set R). Considering a second double complex 01Bnber r = a' + ib' + je' + ijd' the pood1JCt of! with r occ:ms as shown in (A-2). Assuming dte usual operations of real numbers aAJIy and replacing i 1 = -I, j1 = -1 where they appear). OC = -'+iab' + jac' +ijad'+im'-bb' +ijbc'- jbd' + . "'-'-' ,icd 'ijda. ,jdb' :"-' ' + JCa + J~ -cc, - + - +~ This relation shows dlat die product of two double complex numbers is also a double complex number. Equation (A-2) is used as a multiplication rule, allowing die axiomatic definition of double complex numbers as a commu1ative ring. Axiomatit: definition Double complex numbers are ordered quadnJplets of real numbers with some operation roles. Considering the quadruplets (a.b,c,d) aDd (a',b',c',d') w~ the .. b, c, d, a', b', c' and d' are real DUmbeN the roles for equality, ~on are compment like and the multiplication role are defined as: (..b,<;d) = (a',b',c'.d') <=> (a - a', b =b', c - c' add =d' (a, b,c,d) + (a', b',c',d') = (a + a', b + b',c +c',d +d')(.4-4) (..b,~,dXa',b',~',d') = = (u'-1i»' -cc' +dd',ab' +~' -='-c)c',8C'-bd' +ca'-db',8d' +1.:' +cb' +-') Defining 1=(1.0,0,0), i=(O,l,o,O) and j=(O,o,l,o), the pooduct ij oa:ID'8 ij=(O,o,o,I). Baaed on these equalities, and considering dte product of any real m1mber r with (a,b,c,d) as r(a,b,c,d)=(m.rb,n:,rd) any double complex number (a,b,c,d) may be written in the familiar fmm a+bi+cj+dij. The subset ofD for c = 0 and d = 0, isdte set Cj. Similarly, the subset ofB for b =0 and d = 0 is the set q. Further more, the subset ofD for b =0, c = 0 and d = 0 is the set of the real nmnbers R. The defined operation rules are consistent with the well known operatioos in the two sets of complex and the realnumhen C;, Cjand R. Based on the roles for addition and muhiplication it can be easily derived that the set of double complex nwnbers is a commutative ring (additioo is commutative: !. +!z =!2 +!., multiplication is commutative: !.!z =!Z!1 , addition is associative: !I +(!Z+!3)=(!. +!z)+!3' multiplication is associative: !1(!Z!3)=(!'!Z)!3' ImIltiplication is distn"bubve with tespect to addition: !1 (!z +!3) = !1!Z +!, !Z' the zero element is the real number 0: ! + 0 =! and the unitary e~t is the real number 1: !.l =!, where ! l' ! Z and L stand for double complex numbers). That IM8IlS that tbe basic operatioo roles for double complex numbers addition and multiplication an: the ~ as the koown ones (as for real numbers). So there is no need to ~morize special operation roles. Also, there is no need to remember the multiplication role; it is enough to replace iz = -1 and j2 = -1 where they appear. Inversion of double complex numben However, there is a significant difference between the set of double complex numbers and the sets of complex aM real numbers. Double oomplex numbers is not a division system i.e. there are so~ double oomplex numbers without an inverse (called non-ioverbble numbers). An inverse of a double oomplex number! is any double complex number ~ for which the following relation is valid {!!!!. = 1. It can be proven that if !. bas an inverse this is a unique double oomplex number. The cancellation low does not apply for non-inVerbble 93 D. TSANAKAS G. FILIPPOPOULOS D1Dnbers, i.e. if ! is a noo-invertlole numb«, equatioo !! =!! ~y be tme and for ! *!. This would be impossible if ! had an inverse. So the expression II! is not valid, unless it is known that ! is invertible (for example if it is a ~ or a oomplex number). The magnitude of a double complex number The magnitude I!:J of a double complex number! expressed in the fol1DS of (A-I) is a real number that occurs according to the relations: (.4-6) This relation is consistent with the definitioo of tOO magoittlde of complex numbers. A useful ~ for the calcuJa6oDofthe product of two oouble complex nUlDbeft !I aOO !2 is the following: (..4-7)Kt!21=KII~1 However, this relarion is valid only if at least one of!l and !1 is a real number or a complex number in Ci or Cj or a product of a complex number in Ci with a complex number in Cj. 94 3. Transmission Line Alternatives, Pre-Design Cost Estimates by Dryden & LaRue CONSULTING ENGINEERS .rctic Blvd.. Suite 20 I. Anchorage. Alaska 99SO3:-~S7: ~hone: (907) 349-6653. Fax (907) 522-253i Email: office@drydenlarue.com July 17, 2003 Frank Bettine. 229 Whitney Road Anchorage, AK99511-2265 Donlin Creek Transmission Lines Pre-Design Cost Estimates Reference: We have completed our estimates of construction costs for the transmission line options to serve the Donlin Creek Mine. In our June 10 letter we had estimated the 190 mile-long transmission line from Bethel would cost approximately $140.42 million. This estimate was based on using all steel H-frame structures outside Bethel with driven or grouted pipe-pile foundations. In our last meeting, you asked that the transportation costs not be included in the estimate, and that our driven pile lengths be shorten by about 10 feet to better reflect pile lengths used on other transmission projects. Making these revisions resulted in a cost estimate of $133.14 million for the 138 kV transmission line. The estimated cost of the substations and distribution lines remains unchanged from our June 10 letter. Their combined cost is $13.78 million. We looked at using steel X-towers with H-pile foundations and anchors in the lowland area between Bethel and Kalskag. Using the same assumptions as the above estimate, i.e. no transportation costs and reduced pile lengths, resulted in this estimate being $136.61 million. Our conclusion from this is that two H-pile foundations, two H-pile anchors, four guys and a X-tower cannot beat the cost of two pipe piles and a H-frame. We estimate $12.74 million can be saved if the stroctures between Kalskag and Donlin Creek are direct buried instead of supported on pile foundations. The project estimate for the all H-frame option thus becomes $120.40 million. As an alternative to serving the mine from Bethel, we estimated the cost to build a D/C line from Nenana to Donlin Creek. We have some serious concerns about the logistics of building this line due to access, weather, environmental restraints, etc. We believe the most likely scenario for building this line is via ice roads constructed from both Nenana JUly 17, 2003 Page 2 Bettine & Associates Donlin Creek Transmission Lines and Donlin Creek over several (we've estimated four) winters. Finding adequate water sources along the route for the ice roads could be problematic. Setting up and operating work camps along the route will also create some challenges. Our estimate is based on all these logistic concerns being resolved favorably. After re-evaluating the conductor size, we concluded that it should be of similar size as the 138 kV NC options. Therefore our D/C estimate assumes the same fiber optic and conductor size (Cardinal) as the NC options. Structure type for the D/C option is assumed to be single shaft steel poles with either suspension insulators hanging from davit arms or horizontal- V ee insulator assemblies. Loading criteria, average span lengths, percentage of angle and dead end structures, and clearing requirements are assumed to be similar to the NC options. We assumed two thirds of the foundations would be on driven piles and the other one third would be direct buried. Our estimate to construct the 385 mile-long D/C line from Nenana to Donlin Creek is $246.5 million, or approximately $640,200 per mile. This estimate includes about $44 million for ice road construction and transporting materials along the ice roads. We have not included any costs for NC to D/C conversions at either end of the line. We've assumed at least half of the materials for the D/C line would be delivered to Nenana and the remaining would be barged to Crooked Creek. Like the AlC options, the barge costs are not included in our estimates. We estimate approximately 1,000 tons of materials will need to be barged to Crooked Creek for the D/C option. For the AlC options, approximately 1,200 tons of materials will be needed for the portion between Bethel and Donlin Creek. As with our previous estimates, our costs include a 15% planning-type contingency. They do not include environmental studies, permitting, land acquisition, surveying, engineering, or construction management costs. We have enclosed back up for our cost estimates. If you have any questions, do not hesitate to call " BETHEL - DONLIN CREEK 138 KV TRANSMISSION LINE PRE~DESIGN CONSTRUCTION COST ESTiMATE ~x. ~ Extended .w!:. OPTION A: ALL STEEL H-FRAMES OUTSIDE BETHEL. PILE FOUNDAnONS. NO BARGE COSTS Unit Price !.l!1i! No. of Units DescriDtion YQQr Materials Labor & Materials Extended Price Clearina Lt. Clear Md. Clear Hvy. Clear 85 mi. 38 mi. 67 mi. Light Clearing Medium Clearing Heavy Clearing $8,000 $20,000 $30,000 $0 $0 $P $8,000 $20,000 $30,000 $680,000 $760,000 $1,995,000 Driven Piles. Lowlands 10-3x40 215 18-5x40 357 2Q-5x40 357 22-5x40 133 24-5x40 46 Pile anchor. 10" dia. x 40' long Pipe foundation. 18" die. x 40' Pipe foundation. 20" dia. x 40' Pipe foundation. 22" dia. x 40' Pipe foundation. 24" dia. x 40' $7,500 $9,500 $10,500 $11,600 $12,100 $618 $1,860 $2,072 $2.288 $2,500 $8, $11 $12 $13 $14 $1,745,370 $4,055.520 $4,488,204 $1,847,104 $671.600 1545 4650 5180 5720 6250 332175 1660050 1849260 760760 287500 Foundations. Non-lowlands (cre-drill and drive or auaer and arout) 18-5x20 496 Pipe foundation, 18" dia. x 20' $13,000 2Q-5x20 496 Pipe foundation,20. dia. x 20' $14,500 22-5x20 186 Pipe foundation, 22. dia. x 20' $16,200 24-5x20 62 Pipe foundation, 24. dia. x 20' $18,000 $926 $1,036 $1,144 $1,248 $13.928 $15,536 $17,344 $19,248 $6,908,288 $7,705,856 $3,225,984 $1,193,376 2320 2590 2860 3120 1150720 1284640 531960 193440 Anchors. Non-Lowlands Anch 237 237 100 Plate or screw anchor, x-country grouted anchor, x-country Plate or screw anchor, in-town $1,500 $3.000 $1,000 $200 $400 $200 $1,700 $3,400 $1,200 100 500 23700 118500 Steel H-frames $16,000 $17,000 $18,000 $19.000 $21.000 $16,200 $17,200 $18,200 $19,200 $21,200 50' I-string 60' I-string 70' I-string 80' I-string 90' I-string 50' V-string 60' V-string 70' V-string 80' V-string 90' V-string $8,400 $10,050 $12,000 $14,250 $17,100 $9.000 $10,650 $12,600 $14,850 $17,700 $24,400 $27,050 $30,000 $33,250 $38,1 00 $25,200 $27,850 $30,800 $34,050 $38.900 $2,586,400 $4,814,900 $8,520,000 $3,524,500 $1,447,800 $856,800 $1,587,450 $2,833,600 $1,157,700 $505,700 5600 6700 8000 9500 11400 6000 7100 8400 9900 11800 593600 1192600 2272000 1007000 433200 204000 404700 772800 336600 153400 106 178 284 106 38 34 57 92 34 13 3-Pole Steel Structures (Guyed) 12 20 37 12 2 50' 60' 70' 80' 90' $14,500 $15,500 $16.500 $17.500 $19.500 $10,050 $12,600 $15,450 $18,900 $22,200 $24 $28 $31 $36 $41 $294,600 $562,000 $1,182,150 $436,800 $83,400 6700 8400 10300 12600 14800 80400 168000 381100 151200 29600 $25,000 $22,000 $4,500 $4,500 $29,500 $26,500 $1,534,000 $132,500 3000 3000 $24,000 $22,000 $3.300 $3.900 $27,300 $25,900 $982,800 $181,300 2200 2600 Sinale Steel Poles w/o underbuild (direct embed) 52 75' tangent (61' AG) 5 80' dead end (guyed, 70' AG) Sinale Steel Poles wi underbuild (direct embed) 36 60' tangent (47' AG) 7 70' dead end (guyed, 60' AG) Pole top assemblies 642 (3) 138 kV I-string 230 (3) 138 kV V-string 95 (3) 138 kV running angle 70 (6) 138 kV dead end 52 (3) 138 kV horizontal Vee 36 (3) 138 kV posts 36 12.5 kV tangent arm 14 12.5 kV dead end arm $680 $1,550 $750 $2,500 $1,800 $1,500 $400 $800 $2,600 $4,000 $2,600 $22,000 $2,800 $1,800 $1,000 $1,800 $3,280 $5,550 $3,350 $24,500 $4,600 $3,300 $1,400 $2,600 $2,105,760 $1,276,500 $318,250 $1,715,000 $239,200 $118,800 $50,400 $36,400 400 800 400 850 256800 184000 38000 59500 7/29/2003 Dr)oden laRue, Inc.1of2 ,118 ,360 ,572 ,888 ,600 $402,900 $805,800 $120,000 ..550 ,100 ,950 ,400 ,700 Approx. ~ Extended ~ 1!!!i! No. of Units Miscellaneous Descriction L.§QQr. Unit Price Materials Labor & Materials Extended Price 215 1125 191 OPGW assemblies 1027 98 83 $50 $150 $150 $30 $40 $40 $80 $190 $190 $17.200 $213,750 $36.290 10 2 5 2150 2250 955 Pile covers Structure signs (danger and #) Aerial patrol signs tangent or running angle dead end splice $500 $1,500 $4,000 $80 $100 $1.200 $580 $1,600 $5,200 $595,660 $156.800 $431,600 40 50 200 41080 4900 16600 124 739 Wire accessories 4100 250 2000 insulated guy (in-town) un-insulated guy $500 $800 $150 $100 $650 $900 $80,600 $665,100 50 36950 dampers aerial balls bird flight diverters $150 $1.500 $300 $45 $650 $6 $195 $2,150 $306 $799,500 $537,500 $612,000 15 50 5 61500 12500 10000 89.2 2928.8 1006 41.5 1000' Cardinal, short span 1000' Cardinal, long span 1000' OPGW (48 singlemade) 1000' 336 ACSR $5,000 $6,500 $5,000 $3.500 $1.400 $1.400 $1,500 $750 $6,400 $7,900 $6,500 $4,250 $570,880 $23,137,520 $6,539,000 $176,375 1a!O 600 3953880 603600 Subtotal:$110,259.487 10,829 tons 11,912 tonsx 1.1 = Mobilization, staging, work camps, etc. Planning-level contingency: 5% 15% $5,512,974 $17,365,869 Total: Average cost per mile: $133,138,331 $698,889 7/29/2003 Dryden LaRue, Inq.2 of2 BETHEL .DONLIN CREEK 138 KV TRANSMISSION LINE BBE~DESIGN CONSTRUCTION COSUSIIMA TE Approx. ~ Extended ~ OPTION B: ALL STEEL X-TOWERS & H-FRAMES OUTSIDE BETHEL, PILE FOUNDATIONS, NO BARGE COSTS Unit Price !:!!)j! No. of Units Materials Labor & Materials Extended Price Clearina Lt. Clear Md. Clear Hvy. Clear ~ DescriDtioo 85mi, 38 mi. 67 mi. Ught Clearing Medium Clearing Heavy Clearing $8,000 $20,000 $30,000 $0 $0 $0 $8.000 $20,000 $30,000 $680,000 $760,000 $1.995.000 Driven Piles. Lowlands HP8x40 1019 HP10x40 712 HP12x40 181 H-Pile anchor, 8" wide. x 40' long H-Pile fdn., 10" wide. x 40'Iong H-Pile fdn., 12" wide. x 4Q'long $5,500 $6,200 $6,500 $576 $672 $848 $6,076 $6,872 $7,348 1440 1680 2120 1467360 1196160 383720 foundations. Non-Lowlands (Dre-drill and drive or auaer and aroutl 18-5x20 496 Pipe foundation, 18" dia. x 20' $13,000 20-5x20 496 Pipe foundation, 20. dia. x 20' $14,500 22-5x20 186 Pipe foundation, 22" dia. x 20' $16,200 24-5x20 62 Pipe foundation, 24" dia. x 20' $18,000 $928 $1,036 $1,144 $1,248 $13.928 $15,536 $17,344 $19,248 $6,908,288 $7.705,856 $3,225,984 $1,193,376 2320 2590 2860 3120 1150720 1284640 531960 193440 Anchors. Non-Lowlands Anch 237 237 100 $1,500 $3,000 $1,000 $200 $400 $200 Plate or screw anchor, x-country grouted anchor, x-country Plate or screw anchor, in-town $1,700 $3,400 $1,200 $402,900 $805,800 $120,000 100 500 23700 118500 Steel X-towers 52 88 140 52 20 9 15 24 9 3 SO' I-string 60' I-string 70' I-string 80' I-string 90' I-string 50' V-string 60' V-string 70' V-string 80' V-string 90' V-string $17.500 $18.500 $19,500 $20,500 $22,500 $17.700 $18,700 $19,700 $20.700 $22,700 $11,250 $12,750 $13,875 $15,375 $16.875 $11,850 $13,350 $14,475 $15,975 $17,475 $28.750 $31.250 $33,375 $35,875 $39,375 $29,550 $32,050 $34,175 $36.675 $40.175 $1.495.000 $2,750.000 $4,672,500 $1,865.500 $787.500 $265.950 $480,750 $820.200 $330,075 $120,525 7500 8500 9250 10250 11250 7900 8900 9650 10650 11650 390000 748000 1295000 533000 225000 71100 133500 231600 95850 34950 412 Steel H-frames 51 85 136 51 17 28 47 76 28 11 50' I-string 60' I-string 70' I-string 80' I-string 90' I-string 50' V-string 60' V-string 70' V-string 80' V-string 90' V-string $16,000 $17,000 $18,000 $19,000 $21,000 $16,200 $17,200 $18,200 $19,200 $21,200 $8,400 $10,050 $12,000 $14,250 $17,100 $9,000 $10,650 $12,600 $14,850 $17,700 $24 $27 $30 $33 $38 $25 $27 $30 $34 $38 $1,244,400 $2,299,250 $4,080.000 $1,695,750 $647,700 $705,600 $1,308,950 $2,340,800 $953,400 $427.900 5600 6700 8000 9500 11400 6000 7100 8400 9900 11800 285600 569500 1088000 484500 193800 168000 333700 638400 277200 129800 3-Pole Steel Structures (Guved} 12 20 37 12 2 50' 60' 70' 80' 90' $14,500 $15,500 $16,500 $17,500 $19.500 $10.050 $12.600 $15,450 $18.900 $22,200 $24,550 $28,100 $31,950 $36,400 $41,700 $294,600 $562,000 $1,182,150 $436,800 $83,400 6700 8400 10300 12600 14800 80400 168000 381100 151200 29600 $25,000 $22,000 $4,500 $4,500 $29,500 $26,500 $1,534,000 $132,500 3000 3000 Sina(e Steel Poles w/o underbuild (direct embed) 52 75' tangent (61' AG) 5 80' dead end (guyed, 70' AG) Sinqle Steel Poles wI underbuild (direct embed) 7/29/2003 Dryden LaRue, Inc.1 of 2 $6,191,444 $4,892,864 $1,329,988 .,400 ,050 ,000 ,250 ,100 ,200 ,850 ,800 ,050 ,900 Approx. W!:o 2200 2600 Extended W1. !l!1!! No. of Units 36 7 Pole tOD assemblies 642 250 75 DescriDtion 60' tangent (47' AG) 70' dead end (guyed. 60' AG) YQQ.!: $24.000 $22.000 Unit Price Materials Labor & Materials Extended Price $27,300 $982,800 $25,900 $181,300 $3,300 $3,900 (3) 138 kV I-string (3) 138 kV V-string (3) 138 kV running angle (6) 138 kV dead end (3) 138 kV horizontal Vee (3) 138 kV posts 12.5 kV tangent arm 12.5 kV dead end arm $2,600 $4,090 $2,600 $22,000 $2,800 $1,800 $1,000 $1,800 $680 $1,550 $750 $2,500 $1,800 $1,500 $400 $800 $3,280 $5,550 $3,350 $24,500 $4,600 $3.300 $1,400 $2,600 $2,105,760 $1,387,500 $251,250 $1,715,000 $239,200 $118,800 $50,400 $36,400 400 800 400 850 256800 200000 30000 5950052 36 36 14 Misce"aneo~§ 0 1125 191 OPGWassemblies 1027 98 83 $50 $150 $150 $30 $40 $40 $80 $190 $190 $0 $213.750 $36.290 10 2 5 0 2250 95$ Pile covers Structure signs (danger and #) Aerial patrol signs tangent or running angle dead end splice $500 $1,500 $4,000 $80 $100 $1,200 $580 $1,600 $5,200 $595,660 $156,800 $431,600 40 50 200 41080 4900 16600 124 1648 707 Wire accessories 4100 250 2000 insulated guy (in-town) un-insulated guy. shear release un-insulated guy. all other $500 $900 $800 $150 $200 $100 $650 $1,100 $900 $80,600 $1,812,800 $636,300 70 50 115360 35350 dampers aerial balls bird flight diverters $150 $1,500 $300 $45 $650 $6 $195 $2,150 $306 $799,500 $537,500 $612,000 15 50 5 61500 12500 10000 89.2 2928.8 1006 41.5 1000' Cardinal, short span 1000' Cardinal, long span 1000' OPGW (48 singlemode) 1000' 336 ACSR $5.000 $6,500 $5.000 $3,500 $1,400 $1,400 $1,500 $750 $6,400 $7,900 $6,500 $4,250 $570,880 $23,137,520 $6,539,000 $176,375 1350 600 3953880 603600 Subtotal:$113.133.685 10,246 tons 11,270 tonsxu= Mobilization, staging, work camps, etc. Planning-level contingency: 5% 15% $5.656,684 $17,818,555 Total: $136,608,925 Average cost per mile: $717,107 7/29/2003 Dryden LaRue, Inc.2 of2 Approx. W:. Extended Wt. - - -~ - -- OPTION C: ALL STEEL H-FRAMES OUTSIDE BETHEL. DIRECT BURIED & PILE FOUNDATIONS, NO BARGE COSTS .. " ~ . ~ Unit I-'nce !l!!.!! No. of Units Descrictior] J..W.r Materials Labor & Materials Extended Price Clearina Lt. Clear 85 mi. Ught Clearing $8,000 $0 $8,000 $680,000 Md. Clear 38 mi. Medium Clearing $20,000 $0 $20,000 $760,000 Hvy. Clear 67 mi. Heavy Clearing $30,000 $0 $30,000 $1,995,000 Driven Pile 10-3x40 18-5x40 20-5x40 22-5x40 24-5x40 Pile anchor, 10" dia. x 4O'long Pipe foundation, 18" dia. x 40' Pipe foundation, 20" dia. x 40' Pipe foundation, 22" dia. x 40' Pipe foundation, 24" dia. x 40' $7,500 $9,500 $10,500 $11,600 $12,100 $618 $1,860 $2.072 $2,288 $2,500 $8,118 $11.360 $12.572 $13,888 $14,600 $1.745.370 $4.055.520 $4,488.204 $1.847,104 $671.600 1545 4650 5180 5720 6250 332175 1660050 1849260 760760 287500 Anchors. Non-lowlands Anch 237 Plate or screw anchor, x-countlY 237 grouted anchor, x-countlY 100 Plate or screw anchor, in-town Steel H-frames on Piles-- --- - 55 50' I-string 93 60' I-string 148 70' I-string 55 80' I-string 21 90' I-string 6 50' V-string 10 60' V-string 16 70' V-string 6 80' V-string 2 90' V-string 3-Pole Steel Structures (GUyed) on Piles 3 50' 5 60' 10 70' 3 80' 2 90' Steel H-frames. Direct-Embed 51 50' I-string 85 60' I-string 136 70' I-string 51 80' I-string 17 90' I-string 28 50' V-string 47 60' V-string 76 70' V-string 28 80' V-string 11 90' V-string ~Pole Steel Structures (Guved). Direct-Embe~ 9 50' 15 60' 27 70' 9 80' 0 90' Sinale Steel Poles wlo underbuild (direct embed) 52 75' tangent (61' AG) 5 80' dead end (guyed, 70' AG) Sinale Steel Poles wI underbuild (direct embed) 36 60' tangent (47' AG) $1,500 $3,~ $1,000 $200 $400 $200 $1,700 $3,400 $1,200 $402,900 $805,800 $120,000 100 500 23700 118500 $16.000 $17,000 $18.000 $19,000 $21,000 $16,200 $17,200 $18,200 $19.200 $21.200 $8,400 $10,050 $12,000 $14,250 $17,100 $9,000 $10,650 $12,600 $14,850 $17,700 $24,400 $27,050 $30,000 $33,250 $38,100 $25,200 $27,850 $30,800 $34,050 $38,900 $1,342,000 $2,515,650 $4,440,000 $1,828,750 $800.100 $151,200 $278,500 $492,800 $204,300 $77,800 5600 6700 8000 9500 11400 6000 7100 8400 9900 11800 308000 623100 1184000 522500 239400 36000 71000 134400 59400 23600 $14,500 $15,500 $16,500 $17,500 $19,500 $10,050 $12.600 $15,450 $18,900 $22.200 $24,550 $28,100 $31,950 $38,400 $41,700 $73,650 $140,500 $319,500 $109,200 $83,400 6700 8400 10300 12600 14800 20100 42000 103000 37800 29600 $26,000 $27,500 $29,000 $30,500 $33,000 $26,200 $27,700 $29,200 $30,700 $33,200 $10,500 $12,600 $15,000 $17,850 $21,375 $11,100 $13,200 $15,600 $18,450 $21,975 $36.500 $40.100 $44,000 $48,350 $54,375 $37,300 $40,900 $44,800 $49,150 $55.175 $1.861.500 $3.408,500 $5.984,000 $2.465.850 $924.375 $1.044,400 $1.922.300 $3,404,800 $1,376.200 $606.925 7000 8400 10000 11900 14250 7400 8800 10400 12300 14650 357000 714000 1360000 606900 242250 207200 413600 790400 344400 161150 $29,500 $31,250 $33,000 $34,750 $37,500 $12,600 $15,750 $19,350 $23,625 $27,750 $42,100 $47,000 $52.350 $58,375 $65,250 $378,900 $705,000 $1,413,450 $525,375 $0 8400 10500 12900 15750 18500 75600 157500 348300 141750 0 $25,000 $22,000 $4,500 $4,500 $29,500 $26,500 $1,534,000 $132,500 3000 3000 $24,000 S3.~$27,300 $982.800 2200 7/29/2003 Dryden LaRue, 100.1 of 2 PRE-QESIGN CQNSTRUCTJQNCOSLESTIMATE ;. Lowlands 215 357 357 133 46 Approx. ~ 2600 Extended W1.!J.Qj! No. of Units 7 Pole too assemblies 642 230 95 70 52 36 36 14 YQQr $22,000 Unit Pric~ Materials labor & Materials Extended Price $3,900 $25,900 $181,300 Descriction 70' dead end (guyed, 60' AG) (3) 138 kV I-string (3) 138 kV V-string (3) 138 kV running angle (6) 138 kV dead end (3) 138 kV horizontal Vee (3) 138 kV posts 12.5 kV tangent arm 12.5 kV dead end ami $2.600 $4.000 $2.800 $22.000 $2.800 $1.800 $1.000 $1,800 $680 $1,550 $750 $2,500 $1,800 $1,500 $400 $800 $3,280 $5,550 $3.350 $24,500 $4,600 $3.300 $1,400 $2,600 $2,105.760 $1,276,500 $318,250 $1,715,000 $239,200 $118.800 $50.400 $36,400 400 800 400 850 256800 184000 38000 59500 Miscellaneous 215 1125 191 OPGWassemblies- - 1027 98 83 $50 $150 $150 $30 $40 $40 $80 $190 $190 $17,200 $213,750 $36,290 10 2 5 2150 2250 955 Pile covers Structure signs (danger and #) Aerial patrol signs tangent or running angle dead end splice $500 $1,500 $4,000 $80 $100 $1,200 $580 $1,600 $5,200 $595,660 $156,800 $431,600 40 50 200 41080 4900 16600 124 739 Wire accessories 4100 250 2000 Insulated guy (in-town) un-insulated guy $500 $800 $150 $100 $650 $900 $80,600 $665.100 50 36950 dampers aerial balls bird flight diverters $150 $1,500 $300 $45 $650 $6 $195 $2,150 $306 $799,500 $537,500 $612,000 15 $0 5 61500 12500 1CDJO 89.2 2928.8 1006 41.5 $5,000 $6,500 $5 , 000 $3,500 1000' Cardinal, short span 1000' CardinaJ.long span 1000' OPGW (48 singlemode) 1000' 336 ACSR $1,400 $1,400 $1,500 $750 $6,400 $7,900 $6.500 $4,250 $570,880 $23,137,520 $6,539,000 $176,375 1350 600 3953S80 603600 Subtotal:$99,711,108 9,835 tons 10,819 tonsx 1.1 = Mobilization, staging, work camps, etc. Planning-level contingency: 5% 15% $4,985,555 $15,704.500 Total: Average cost per mile: $120,401,163 $632,027 7~Dryden LaRue, Inc.2012 w Z wI ::il- z~ o~ -I- cncn cn W I~I- cncn Zo <Co (I:z 1-0 u- c t3 1~:) Wa: wI- CI:cn Uz zo -U ..J zz O(,!) 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I~~{\;~coCO)1"-0) II ~ "C ~ ~ '0 ~ nyo.-x 100(\110 000.-(\1G)r C'!.- - .0 100,",= '-'-.10=r--(\I.. . -(OJ r--r--=10 **** " " U " 1::D.ci;'8.Eoc .,~;GI c ~ ae-c=.E-0--- .cC '" ~ 0 0 -c Eo GI - - GIGI '" =!2 > E c.£ 0 . .- a -c "'- N C :=c .c'" 0- ~Q. '"~£U)a.U)a.II~e0"i.¥~0.9~~ ~~ ~In N 0,-. M~ -= - - -~ 00) 0) CD ,.:lR- CD N ... .:i II <GI 1-= O..§ I- III 0 OJ GI i' .. GI > < J N Q) CD CV a. i. 0Egi ~g0( ~ CONSULTING ENGINEERS October 7, 2003 Frank Bettine 1120 E Huffman Rd.Pmb 343 Anchorage, AK 99516 Reference:Donlin Creek Transmission Lines Pre-Design Cost Estimate for 230 kV A.C. Option We have estimated the cost to construct a 230 kV A.C.line from Nenana to Donlin Mine. Our estimate is based on using steel H-frame structures. Like our D.C. estimate, two thirds of the structures are assumed to be on pile foundations and the remaining structures are assumed to be direct embedded. We have also assumed the same route, conductor type, OPGW type, construction methods, and contingencies as were used on our D.C. estimate. Our estimate for the 385 mile-long, 230 kV A.C. line is $340.9 million, or approximately $885,500 per mile. The tonnage required to be barged to Crooked Creek for the 230 kV D.C. option is about 14,500 tons. Attached is our estimate for the 230 kV D.C. option. If you have any questions, do not hesitate to call. Dryden & LaRue, Inc GDH:sc/clientslbet/betdnln/frankl 0-7-03 .doc w z ~ Zw Q'o;( ~~ ~~ u>U> ZW <"" a:U> 0 00 <Z >Q ~ 00 M=> C\la: ~ wU> wZ a:0 00 ZZ ~<.? Z- 0U> C~ I I <W Za: <0.. Z W Z .,; ~ O~o ~~~ ~ (')Q)~~- " " " " " .c:E.GI~... ~~e"O-§ ~~ .8'" ~.!! ~c 0 .-8...!!e~ -I0>-~1U . ~"C.2 i ~ GI 0"0 Gll!o aGIO e> ~.O( .0( d ~ =- ! i ~ ~ ~ "0 .5 I!.c 0; CD II ! c 0 ~ = "5 1- ~ 'C I ~il'gGI ~-g 'c~I-W:!~~ 'c.1-~ .. :g ~ c~ ~ i w~ :g~ ioG '$(:- w. ~ "g -8.! 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G)..J =OC E~ §t- ~~ ~r-- I ~ i ~ ~rnrn§§.~i~~'I"...* .q ~ II ~ i II) IDO a;2~~ ~~".11)' .. ;:"~fi~ 9;1S "GN .~ aaa! a II II II II .:J II ~g.c:>' c' 8.Eo- g 1-= (/)~,g~ oE ~~~og' I-i -~:5E 8 ~ ~~ .. ~~:ll. i0 . - -01 ""' -c: !S °c =c: :QtU 0- ~CL (I)cg~~-II10I0g~ ~~ "!'£ CO) N I i DONLIN CREEK SUBSTATION CONSTRUCTION COST ESTIMATE June 6, 2003 5% Misc covers freight (materia estimates are FOB Seattle), mob/demOO, canp costs, etc VILLAGE STEP DOWN SUBSTATION 138 KV/12.47 -7 .2 KV DescriRtion Q!Y. ~ ~ 5% MISC SUBTOTAL 15% Cantina 138 KV Circuit Switch. wI Disconnect 7 $64,000 $3,200 $470,400 $70,560 IQI& $540,960 138/13.8 kV Transformer 500 kVA 1000 kVA $ 1 7 7 7 14 21 7 7 7 7 $130,000 $135,000 $20,000 $5,000 $5,000 $500 $500 $8,000 $10,000 $7,500 $5,000 $6,500 $6,750 $1,000 $250 $250 $25 $25 $400 $500 $375 $250 $819,000 $141,750 $147,000 $36,750 $36,750 $7,350 $11,025 $58,800 $73,500 $55,125 $36,750 $122,850 $21,263 $22,050 $5,513 $5,513 $1,103 $1,654 $8,820 $11,025 $8,269 $5,513 $941,850 $163,013 $169,050 $42,263 $42,263 $8,453 $12,679 $67,620 $84,525 $63,394 $42,263 15 kV RecIoser w/ Contraler 15 kV Mota" Oper.- Disconnect Switch 15 kvT8<eoff Structure 15kVPT 15 kV CT 15 kV Overcurrent Relay Package Meter/Relay Building Station Service Site Prep/Ground Grid Foundations 1 7 J 7 $10,000 $7,500 $2,500 $10,000 $500 $375 $125 $500 $73,500 $55,125 $18,375 $73,500 Tra1sformer wI Oil Contanment 138 kV Circuit Switch~ 15 kV Rec/oser Building $11,025 $8,269 $2,756 $11,025 $84, $63, $21, $84, L~ for Station, 28 dayx12 hrx$15Ox4 mM 1 S201;S)O $10,080 $1,481,760 $222.264 $1,704,024 TOTAL fa- S- $4,135,929 Tota -=h ~.847 Bethel Po_r Plant and Substation Q!Y ~ ~ 5% MISC SUBTOTAL 15% Conting IQIAL 3 $450,000 $22,500 $1,417,500 $212,625 $1,630,125 2 $80,000 $4,000 $168,000 $25,200 $193,200 8 $8,500 $425 $71,400 $10,710 $82,110 4 $60,000 $3,000 $252,000 $37,800 $289,800 1 $45,000 $2,250 $47,250 $7,088 $54,338 12 $1,500 $75 $18,900 $2,835 $21,735 10,000 $15 $1 $157,500 $23,625 $181,125 1 $15,000 $750 $15,750 $2,363 $18,113 D~tion 138/13.8 kV 40 MVA TrC8'\sf~ 13.814.16 kV 7.5 MVA Tralsformer 138 kV ~t Switch 138 kV Circuit Breaker 138/13.8 kV T_e Off StrlJC1ure 138 kV Bus 81d Supports 13.8 kV Underground Cs>ling Site Prep/Ground Grid 12 Breaker-13.8 kV Switchgear Uneup Basic Br~ers Md Cubicles Synch PMeIs Metering/Protective Relaying PI¥:k~e Foundations 12 3 12 $35,000 $10,000 $15,000 $1,750 $500 $750 $441,000 $31,500 $189,000 $66,150 $4,725 $28,350 $10 $7 $2 $10 $1 5 8 4 1 12 $500 $375 $125 $500 $50 $52,500 $63,000 $10,500 $10,500 $12,600 $7,875 $9,450 $1,575 $1,575 $1,890 $60 $72, $12 $12 $14, TrS\8former wi Oil Containment 138 kV Disconnect Switch 138 kV Circuit Bre8<er 138/13.8 kV T~e Off Structure Bus Supports L~for StSioo, 56 dayx12 hrx$150x6 mM ~ $604,800 $30,240 $635,040 $95,256 $730.296 TOTAL $4,133,031 Page 1 525 394 131 525 $507,150 $36,225 $217,350 ,000 ,500 ,500 ,000 ,000 ,375 ,450 ,075 ,075 ,490 Donlin Creek Mine Substation Q1Y ~ ~ 5% MISC SUBTOTAL 15% Contina IQIAL 2 $450,000 $22,500 $945,000 $141,750 $1,086,750 6 $8,500 $425 $53,550 $8,033 $61,583 3 $60,000 $3,000 $189,000 $28,350 $217,350 1 $55,000 $2,750 $57,750 $8,663 $66,413 6 $1,500 $75 $9,450 $1,418 $10,868 2,400 $15 $1 $37,800 $5,670 $43,470 1 $5,000 $250 $5,250 $788 $6,038 1 $10,000 $500 $10,500 $1,575 $12,075 1 $75,000 $3,750 $78,750 $11,813 $90,563 Lot No Est No Est No Est No Est No Est No Est DescriRtioo 138/13.8 kV 40 MVA Travlsfamer 138 kV DiSca1nect Switch 138 kV Circuit BreMer 138 kV Ta<e Off Structure 138 kV Bus a1d SUppa1s 13.8 kV Underground Cabling StalionSerJice Site Prep/Ground Grid Meter/Reiay Building Rea;tiV8 Compensation 6 Breaker-13.8 kV Switchgear Uneup Basic Bre~ers aid Cubicles Synch Panels Metering/Protective Relaying Pa:k~e $1,750 $500 $750 6 1 8 $35,000 $10,000 $15,000 $220 , 500 $10,500 $94,500 $33,075 $1,575 $14,175 $253,575 $12,075 $108,675 Foundations Z $ 3 1 8 1 $10,000 $7,500 $2,500 $10,000 $1,000 $10,000 $500 $375 $125 $500 $50 $500 $21,000 $39,375 $7,875 $10,500 $6,300 $10,500 $3,150 $5,906 $1,181 $1,575 $945 $1,575 $24,150 $45,281 $9,056 $12,075 $7,245 $12,075 TrS1sform« wI 011 Cootanment 138 kV Discoonect Switch 138 kV Circuit Brea<er 138/13.8 kV Tate Off Structure Bus Supports Met«/Reiay Building $518,400 $25,920 $544,320 $81,648 $625,968LSIa" fcx- Station, 48 dayx12 hrx$150x6 men 1 TOTAl $2,705,283 Page 2 Appendix D – Power System Studies by EPS, Inc. Nuvista Power & Light Co. Donlin Creek Mine Project System Studies August 12, 2003 Dr. James W. Cote, Jr. David W. Burlingame PHONE (907) 522-1953 y 3305 ARCTIC BLVD., SUITE 201, ANCHORAGE, AK 99503-4575 y FAX (907) 522-1182 y WWW.EPSINC.COM PHONE (425) 883-2833 y 3938 150th AVE NE, REDMOND, WA 98052 y FAX (425) 883-8492 DONLIN CREEK MINE PROJECT SYSTEM STUDIES Table of Contents 1 Introduction _____________________________________________________________________________________2 2 System Description ________________________________________________________________________________2 3 Power Flows _____________________________________________________________________________________3 4 Short Circuit Analysis _____________________________________________________________________________5 5 Transient Stability Simulations ______________________________________________________________________5 5.1 Loss of Generation ___________________________________________________________________________5 5.2 Loss of Mine Load ____________________________________________________________________________6 5.3 Motor Starting _______________________________________________________________________________6 5.4 138 kV Line Energization ______________________________________________________________________6 6 Basic Relaying Schemes____________________________________________________________________________7 7 Recommendations ________________________________________________________________________________7 - 1 - DONLIN CREEK MINE PROJECT SYSTEM STUDIES 1 Introduction The Donlin Creek Mine Project is located in southwest Alaska. A transmission line interconnection at 138 kV is proposed between the mine at Donlin Creek and the Bethel Power Plant in Bethel, a line length of approximately 190 miles. Between the Bethel Power Plant and the Donlin Creek Mine there are several villages, to be served either directly off the 138 kV transmission line or from a tapped substation on the transmission line. Additionally, a short interconnection from the Bethel Power Plant to the existing Bethel Utilities Diesel Power Plant is proposed, and three single wire ground return (SWGR) feeders are proposed to serve several native villages in the region. This report documents several system studies performed by Electric Power Systems, Inc. (EPS) for the proposed Donlin mine project. These studies include power flow analyses, short circuit analysis, transient stability studies, basic relaying schemes and costs, and suggestions and recommendations. The focus of this report is the 138 kV transmission line feasibility and associated equipment. The studies represent the potential village loads as simply loads on the transmission line, without operating characteristics of the lines to serve the villages. The SWGR feeders were previously studied by EPS and were not modeled in detail in these studies, other than to represent the feeder loads where interconnected to the proposed transmission system. 2 System Description The proposed system consists of a new Bethel Power Plant, a new transmission line from the plant to the Donlin Creek Mine, several 138 / 12.47 kV substations along the transmission line, a new 13.8 kV tie to the existing Bethel Diesel Power Plant, and three Single Wire Ground Return (SWGR) feeders. Each of these components is discussed below. Oneline diagrams for the proposed system, showing two different generation options, are shown in Appendix 1. The Bethel Power Plant consists of a main 13.8 kV bus with generation connected at 13.8 kV. Two generation options were considered, labeled Coal-Fired and Combined Cycle on the attached onelines. The Coal-Fired alternative consists of two 45 MW coal fired steam turbines and one 42 MW combustion turbine. The Combined Cycle alternative consists of three 42 MW combustion turbines and one 25 MW steam turbine. The Bethel Power Plant also consists of several transformers connected to the 13.8 kV bus, plus one feeder. The transformers include two station service transformers rated at 13.8 / 4.16 kV, 7.5 MVA each, three step-up transformers for the transmission line to the mine, rated at 13.8 / 138 kV, 40 MVA each, and two single phase transformers for two of the SWGR feeders, rated 13.8 kV line-to-line / 80 kV line-to-ground, 7.5 MVA each. The one feeder is an express feeder to the Bethel Utilities Diesel Power Plant, roughly 1.5 miles away. At the Diesel Power Plant Substation, a three winding 13.8 /12.47 / 4.16 kV, 15 / 10 / 5 MVA transformer is proposed to tie the express feeder into the existing Bethel system. The proposed 138 kV transmission line is 190.6 miles long, 954 ACSR construction on X-frame structures for all but the first 5.3 miles of the line. Along the length of the line are seven native villages to be interconnected at a voltage of 12.47 kV using three phase 138 / 12.47 kV transformers. At Aniak substation, the proposed transformer is rated at 1000 kVA. At the other six villages, the proposed transformer ratings are 500 kVA. The preliminary Donlin Creek Mine design includes 138 kV and 13.8 kV buses, with two step-down transformers rated at 138 / 13.8 kV, 40 MVA each. The transmission line interconnects to the mine through a 138 kV breaker - 2 - DONLIN CREEK MINE PROJECT SYSTEM STUDIES and bypass switch provided by the mine. The mine load is served by several 13.8 kV feeders. The mine includes a SVC system on the 13.8 kV bus which regulates voltage and is supposed to reduce voltage sags associated with both starting large loads at the mine and normal operations at the mine. EPS was responsible for system analysis of the transmission system for mine loads of 55, 70, and 85 MW, and for conditions with no mine load. 3 Power Flows Power flows were run for the proposed system with mine loads of 0, 55, 70, and 85 MW. The loads throughout the proposed system are shown in table 1 below, with the Donlin Mine load shown at 55 MW. System data for the power flow models are attached in Appendix 1. Table 1 – System Loads PSS/E Name Xfmr Load Load Load Bus #kVA kW kVAR kVA PF 111 Akiachuk 500 477 358 596 0.80 121 Akiak 500 408 306 510 0.80 131 Tuluksak 500 264 198 330 0.80 141 Kalskag 500 500 375 625 0.80 151 Aniak 1000 1054 791 1318 0.80 161 Chuathbaluk 500 80 60 100 0.80 171 Crooked Creek 500 542 407 678 0.80 20 SW GR-South 7500 5756 4317 7195 0.80 30 SW GR-W est 7500 4660 3495 5825 0.80 50 SW GR-Yukon 7500 5309 3982 6636 0.80 11 Bethel SS1 7500 3000 1450 3332 0.90 12 Bethel SS2 7500 3000 1450 3332 0.90 40 Donlin Mine 80000 55000 18078.5 57895 0.95 13 Bethel 12.47 10000 11143 8357 13929 0.80 14 Bethel 4.16 5000 5572 4179 6965 0.80 totals 96288 47445 The power flow results are shown on the oneline diagrams in Appendix 2, and a summary of various parameters is shown in Table 2 below. The initial power results indicated a need for additional voltage support along the 138 kV transmission line during heavy mine loading periods. The size of the SVC to be provided at Donlin Mine was unknown. Power flows with the mine load at 55 MW and only one SVC located at the mine showed low 138 kV voltages and a 12.47 distribution voltage at Crooked Creek of 95.7% with full tap changer control, with a SVC output of 31.7 MVAR (case 9 in Table 2). The SVC was set to regulate the 13.8 kV mine voltage to 1.0 per unit. When the mine load increased to 85 MW, with only one SVC located at the mine, all voltages decreased with the 12.47 kV voltage at Crooked Creek decreasing to 88.5%, with a Donlin Mine SVC output of 81.5 MVAR (case 10 in Table 2). Based on these results, we propose placing an additional SVC at Aniak which is roughly midway along the transmission line. A bank of switchable capacitors at Aniak may also provide acceptable steady state voltages, but a SVC provides better control of transient voltage, especially when controlling voltage during mine outages or when energizing the line. This is discussed further in the section on transient stability results (below). - 3 - DONLIN CREEK MINE PROJECT SYSTEM STUDIES The majority of the power flow results shown in Appendix 2 include two SVC systems, one at Donlin Mine on the 13.8 kV bus and one at Aniak on the 138 kV bus. The Aniak SVC would normally be connected at a lower voltage via a step-down transformer, but for study purposes, the SVC was shown connected to the 138 kV bus. Both SVC systems were sized at -50 MVAR to +50 MVAR, regulating the bus voltage to 1.0 per unit. Actual SVC outputs are shown on the power flow oneline diagrams and in Table 2 below. The maximum boost capacity of the SVC systems, 50 MVAR each, is based on the power flow results with 85 MW of load at Donlin Mine. Table 2 – Power Flow Results Summary Case Mine Load (MW ) Mine Load (MVAR) Series Comp % Bethel- Donlin Power Angle (degs) Total Generation (MW ) Losses (MW ) Losses (MVAR) Aniak SVC (MVAR) Donlin SVC (MVAR) Total SVC (MVAR) Lowest Distribution Voltage (pu) 1 0 0 none 1.5 42.3 0.5 5.2 -16.7 off -16.7 0.988 2 55 18.1 none 26.3 101.7 4.9 39.5 4.2 28.9 33.1 0.963 3 70 23.0 none 33.7 119.5 7.7 61.4 15.6 40.2 55.8 0.955 4 85 27.9 none 41.8 138.2 11.5 90.9 36.5 47.6 84.1 0.925 5 0 0 50%1.4 42.3 0.5 5 -16.4 off -16.4 0.949 6 55 18.1 50%14.8 102.3 5.5 27.5 -24.7 47.1 22.4 0.885 7 70 23.0 50%18.5 119.9 8.1 41.8 -8.9 45.9 37.0 0.888 8 85 27.9 50%22.5 138.5 11.7 60.9 9.7 44.6 54.3 0.892 9 55 18.1 none 26.6 101.7 5.0 40.2 off 31.7 31.7 0.957 10 85 27.9 none 48.8 140.8 14.1 110.9 off 81.5 81.5 0.885 11 85 27.9 none 41.8 138.2 11.5 90.9 36.5 47.6 84.1 0.925 The initial power flow results also showed a large power angle across the 138 kV line, from Bethel to Donlin mine, for the larger mine load levels. The power angle across the 138 kV line is also shown in Table 2. Large power angles between generation sources leads to classic stability problems. However, only a minimal amount of startup generation is anticipated at the mine site, and is expected to be online only when starting the mine. Under this condition, there would be small power transfers across the 138 kV transmission line, resulting in a small power angle. As the mine load increases, the on-site generation is expected to be removed and load picked up across the transmission line. This scenario should not result in stability problems associated with the large power angles. However, EPS did run several power flows with series compensation added to the 138 kV line near Aniak. These power flow results are also included in Appendix 2 and Table 2 (cases 5 through 8). A series compensation level of 50% was studied. When the series compensation is added, the power angle is reduced, and the MVAR support required by the SVC systems is also reduced due to the series capacitors which add MVARs into the system. These series compensation cases have been added to this report for completeness. EPS does not foresee the need to add series compensation to the 138 kV transmission line, as discussed above. Expected system losses are also included in Table 2. Transmission line resistance and the resulting losses vary with ambient air temperature, wind conditions, and line loading. These studies used a maximum expected line resistance value in the model, thereby yielding conservative or worst case loss totals. Actual losses should be lower than the totals given in Table 2. - 4 - The calculated voltages on the 12.47 kV buses at the remote village substations are based on using typical distribution transformer impedances (from American National Standard C57.12.10 and Industrial Power System Handbook by Beeman) and based on using a transformer with LTC capability of ±10% tap. All distribution voltages were regulated to the range from 99% to 101% voltage within available taps. Voltages could be improved further DONLIN CREEK MINE PROJECT SYSTEM STUDIES by improving the load power factor, and / or adding distribution capacitors. The loads used in these studies are worst case maximum peak scenarios, expected in the year 2040. The most significant voltage problem occurs at Crooked Creek on the 12.47 kV bus. The power flow results indicate a need to provide some corrective action or replace the transformer with a larger transformer if the mine load and Crooked Creek loads begin to approach their maximum values studied. Separate power flows were not run based on the two generation options. From a power flow standpoint, the generation bus at Bethel, the 13.8 kV bus, is a swing bus and the number of generators connected to the swing bus is irrelevant. The power flow solution distributes the real and reactive power requirements of the swing bus to whatever generators are connected at the swing bus, based on initial MW output. One power flow case was run to illustrate this. Case 11 in Table 2 has the combined cycle units running instead of the Coal Fired Generation option. Note that the power flow results are identical to case 4 in Table 2, with only the generation dispatch being different. However, different generation alternatives have an impact on both short circuit and transient stability results. It should also be noted that the power flows for a mine load of 85 MW, with the maximum substation loads, and the assumed station service and Bethel loads shows a generation total in excess of the capacity of the Bethel Power Plant using the coal fired generation alternative. The combined cycle generation alternative does have sufficient generation to meet the proposed loads. 4 Short Circuit Analysis The short circuit analysis was performed using the ETAP Powerstation software package. The power system model is identical to the power flow model used in PSS/E, except for minor differences in load models. These differences are insignificant to the short circuit calculations. Short circuit results are included in Appendix 3. Three phase to ground and single phase to ground fault currents were calculated at all appropriate three phase buses. Fault currents are not calculated for the SWGR feeders or buses. Currents are calculated with all generation online. With any generation offline, the fault currents will decrease. Fault currents in Appendix 3 are first provided for the coal-fired generation option, and then provided for the combined cycle generation option. 5 Transient Stability Simulations Transient stability simulations were conducted using the PSS/E software. Simulations included loss of generation, loss of mine load, motor starting, and line energizing. Typical dynamics data from other generators of comparable size were used for the proposed generating units at Bethel Power Plant. The dynamics data for the generators are included in Appendix 4. 5.1 Loss of Generation Transient stability case T1 represents a loss of the largest on-line unit at Bethel Power Plant. This outage was run for the maximum load case, Donlin mine at 85 MW. The transient stability results are shown in Appendix 4, with a case name of “T1-mine85”. In order to survive this outage, load shedding must occur somewhere in the system. For study purposes, load shedding relays were placed at the Donlin mine, in 3 stages. Each stage sheds 25% of the mine load, with stages set at 59.0, 58.7, and 58.4 Hz. These settings are somewhat arbitrary, but show that a unit loss can be survived with appropriate load shedding. Load may be shed on the distribution system or at the - 5 - DONLIN CREEK MINE PROJECT SYSTEM STUDIES mine. The only significant issue is to have enough load on load shedding to exceed the largest anticipated loss of generation. Transient stability results for case “T1-mine85” show a frequency decay to just below 58.4 Hz, with all three stages of load shedding picked up. The frequency then recovers to 60 Hz. Simulations also show a frequency control problem when attempting to restore frequency exactly to 60 Hz. This appears to be problem with the simulation software when modeling several units at the same plant, all in isochronous control. This is modeled by setting the machine droop to near zero, but creates a hunting problem in the software. We believe this hunting which appears near the end of the simulation to be a non-issue, caused solely by the simulation. 5.2 Loss of Mine Load The transient stability simulation for the complete loss of the mine load (case T2) represents a 138 kV breaker opening at Donlin Mine. The mine load is lost along with the Donlin SVC. Simulations were run at both 55 and 85 MW of mine load, and are shown in Appendix 4. Simulations show a transient frequency rise to around 61.5 Hz for a mine load of 55 MW, and 62.7 Hz for a mine load of 85 MW, returning to nominal in 11 seconds. The Aniak SVC regulates the 138 kV line voltage very quickly back to near 1.0 per unit. The transient frequency rise is significant due to the large percentage of total system load residing at Donlin Mine. Remedial action schemes have not been studied to reduce the over-frequency conditions, but a remedial action trip of one or more Bethel units would significantly reduce the over-frequency magnitude. Alternately, staggered over-frequency relaying of the Bethel units could be used to trip generation without a transfer trip signal from the mine. Acceptable over-frequency conditions for the generating units should be discussed with generator / turbine suppliers. 5.3 Motor Starting Transient stability simulations were run for a motor starting condition at Donlin Mine (case T3). From preliminary mine load estimates, the largest single load appears to be the Sag Mill, sized at 9.12 MW. It may be unrealistic to expect the total Sag Mill load to be a single motor, started under full load, but this case was used to define the worst case motor starting scenario. An induction motor was used to represent the Sag Mill load, and was started under full load. Typical induction motor parameters were used for the model. The initial simulations showed a prolonged under voltage condition during the motor start. A subsequent simulation was run using a reduced voltage start for the motor, at 60% nominal voltage. This simulation is provided in Appendix 4. The initial condition power flow case had a mine load of 70 MW, with the motor providing an additional 9.12 MW of load when started. The Donlin Mine SVC was included in the simulation. EPS understands that the Donlin Mine SVC is supposed to alleviate voltage dips and disturbances associated with normal mine operations. Also, we understand that our assumptions about this motor size are conservative (probably overstated). However, our simulations show a prolonged under-voltage condition in the system during the motor start. Simulations show the Donlin 138 kV bus voltage below 90% for almost 10 seconds. The motor takes near 12 seconds to reach nearly full speed. We believe that a better understanding is needed of the largest expected motor and its load at startup, in order to refine these studies and determine the actual system impact of a large mine motor start. A motor start condition at Donlin Mine may be the worst case scenario in terms of voltage, and may be the defining case for sizing the Donlin Mine SVC system. 5.4 138 kV Line Energization Transient stability simulations were run to evaluate the system voltage profile during an energizing of the 138 kV transmission line (T4 cases). These cases assume that the 138 kV line is de-energized and all load and transformers along the load are offline. The line is then energized by closing the 138 kV breaker at Bethel, picking up the line all the way to Donlin Mine on the 138 kV side. Discussions with SVC manufacturers indicated that the - 6 - DONLIN CREEK MINE PROJECT SYSTEM STUDIES usual method for starting a line with SVC systems along the line and voltage control issues was to use a small fixed reactor on the secondary of the SVC transformer, and then switch out the reactor when the SVC comes online. To simulate this, cases were run with no fixed reactor at Aniak, and then again with a 10 or 20 MVAR fixed reactor at Aniak, to determine the line voltage profile and the required size of the secondary reactor. These 3 cases are shown in Appendix 4. The case with no reactor “t4-energize0” showed a transient voltage to near 118% at Donlin on the 138 kV bus, with a steady state voltage of 114%. The case with a 10 MVAR reactor “t4-energize-10” showed a transient voltage of 110% and a steady state voltage of 108% at Donlin. The case with a 20 MVAR reactor “t4-energize-20” showed a transient voltage of 103% and a steady state voltage of 103% at Donlin. The 10 MVAR reactor should provide acceptable voltage performance for the short time before the SVC can come online and regulate voltage. 6 Basic Relaying Schemes Although the 138 kV transmission line is operated radially from the Bethel Power Plant, backfeed from various motors and on-site generation will require the system to be treated as a dual source system for protective relaying. The protective relaying is recommended to be a micro-processor-based protective relay system, with protective communications between each relaying terminal. The primary protective scheme is recommended to be line distance relaying such as the SEL-421 relay, the ABB REL-512 protective relay or the Nxtphase L-Pro relay. Each of the relay’s can provide the protection for the line and operate following the incorporation of the SWGR loads and substations. The relays are the most economical and reliable protection method available to the utility systems and can provide protection as well as control and operations. The relaying scheme will require three digital communication channels between each terminal, two for protective relaying and one for control and operations. Each transformer will utilize micro-processor based transformer differential protection. Each generator will utilize microprocessor-based protective relays. We recommend two protective relays on each generator. The recommended relays are Schweitzer, General Electric’s UR series or Beckwith Electric. 7 Recommendations Power flow, short circuit, and transient stability results were run and basic relaying schemes were provided. From these studies, recommendations were made to add a SVC system at Aniak plus a switchable fixed reactor for line energizing. No significant differences between the two generation alternatives were found, from a system viewpoint. Load shedding relays will be required to withstand a loss of generation at Bethel Power Plant. Load can be shed anywhere in the system, as long as enough load is shed to overcome the lost generation. Protective relaying can be accomplished using industry standard protective relays and communications. Fault clearing times are within normal limits and do not require special relaying or protective schemes. - 7 - DONLIN CREEK MINE PROJECT SYSTEM STUDIES - 8 - APPENDIX 1 DONLIN CREEK MINE PROJECT SYSTEM STUDIES Appendix 1 System Oneline Diagrams Power Flow Data 13.8kV-12.47kV-4.16kV12.47kV/10 MVA 13.8 kV Bus138 kV Bus13.8kV/138kV40 MVATo Bethel Power Plant13.8 kV BusMine Feeder 1Mine Feeder 2138 kV BusDonlin Creek Mine SubstationTo Be Constructed by Placer Dome55-85 MW loadAkiachak Sub.500 kVA XfmrAkiak Sub.500 kVA XfmrTuluksak Sub.500 kVA XfmrKalskag Sub.500 kVA XfmrAniak Sub.1000 kVA XfmrChuathbaluk Sub.500 kVA XfmrCrooked Creek Sub.500 kVA XfmrSystem Oneline Diagram138kV 10 L-L to 80kV 10 L-G138kVCircuitSwitcher138kVCircuitSwitcherSWGR Transmission Line Yukon River Feeder138 kV/12.47 kV XfmrTo VillageVertical Tap to 138 kV Power LineMotor OperatedDisconnect Swtch138 kV CircuitSwitcherOneline Diagram - All Village Substations Except Aniak4.16kV/12.47kV -7.5 MVAStation ServiceCombustion Turbine12.47 kV Electronic ControlledReclosure4.16/2.4KV BusTo Donlin Creek Mineand Villages13.8kV/138kV40 MVA13.8kV/138kV40 MVA13.8kV/138kV40 MVA13.8kV/138kV40 MVA4.16kV/12.47kV -7.5 MVAStation Service42 MWCoal-Fired Steam Turbine45 MWCoal-Fired Steam Turbine45 MW13.8kV 10 L-L to 80kV 10 L-G138kVCircuitSwitcher13.8kV 10 L-L to 80kV 10 L-G138kVCircuitSwitcherExpress 13.8 kV Feeder to Bethel UtilitiesExisting Diesel Power Plant Substation SWGR South Feeder SWGR West FeederFuture AdditionsFuture Addition6/24/03-FJB954 ACSR 4.16/2.4KV BusBethel Power Plantand Substation4.16kV/5 MVAConnect to BU12.47 kV BusConnect to BU 4.16 kV BusADDITIONS TO BETHEL UTILITIES SUBSTATIONNuvista Light & Power Co.Coal-Fired Generation AlternativeBETTINE, LLCFigure ??SVC System138 kV/12.47 kV XfmrTo AniakVertical Tap Motor OperatedDisconnect Switch138 kV CircuitSwitcherOneline Diagram - Aniak Substation12.47 kV Electronic ControlledReclosureInsert 1Insert 2138 kV CircuitSwitcher138 kV CircuitSwitcherReactiveCompensationas RequiredTo Donlin Creek138 kV Transmission LineTo Bethel Power Plant138 kV Breaker and Bypass SwitchUnder Nuvista Light & Power Control19 mi.6.5 mi.17.3 mi.42.1 mi.25 mi.12.9 mi.54.3 mi.13.5 mi. 13.8kV-12.47kV-4.16kV12.47kV/10 MVA 13.8 kV Bus138 kV Bus13.8kV/138kV40 MVATo Bethel Power Plant13.8 kV BusMine Feeder 1Mine Feeder 2138 kV BusDonlin Creek Mine SubstationTo Be Constructed by Placer Dome55-85 MW loadAkiachak Sub.500 kVA XfmrAkiak Sub.500 kVA XfmrTuluksak Sub.500 kVA XfmrKalskag Sub.500 kVA XfmrAniak Sub.1000 kVA XfmrChuathbaluk Sub.500 kVA XfmrCrooked Creek Sub.500 kVA XfmrSystem Oneline Diagram138kV 10 L-L to 80kV 10 L-G138kVCircuitSwitcher138kVCircuitSwitcherSWGR Transmission Line Yukon River Feeder138 kV/12.47 kV XfmrTo VillageVertical Tap to 138 kV Power LineMotor OperatedDisconnect Swtch138 kV CircuitSwitcherOneline Diagram - All Village Substations Except Aniak4.16kV/12.47kV -7.5 MVAStation Service12.47 kV Electronic ControlledReclosure4.16/2.4KV BusTo Donlin Creek Mineand Villages13.8kV/138kV40 MVA13.8kV/138kV40 MVA13.8kV/138kV40 MVA13.8kV/138kV40 MVA4.16kV/12.47kV -7.5 MVAStation ServiceCombustion Turbine42 MW13.8kV 10 L-L to 80kV 10 L-G138kVCircuitSwitcher13.8kV 10 L-L to 80kV 10 L-G138kVCircuitSwitcherExpress 13.8 kV Feeder to Bethel UtilitiesExisting Diesel Power Plant Substation SWGR South Feeder SWGR West FeederFuture AdditionsFuture Addition6/24/03-FJB954 ACSR 4.16/2.4KV BusBethel Power Plantand Substation4.16kV/5 MVAConnect to BU12.47 kV BusConnect to BU 4.16 kV BusADDITIONS TO BETHEL UTILITIES SUBSTATIONNuvista Light & Power Co.Combined-Cycle Generation AlternativBETTINE, LLCFigure ??SVC System138 kV/12.47 kV XfmrTo AniakVertical Tap Motor OperatedDisconnect Switch138 kV CircuitSwitcherOneline Diagram - Aniak Substation12.47 kV Electronic ControlledReclosureInsert 1Insert 2138 kV CircuitSwitcher138 kV CircuitSwitcherReactiveCompensationas RequiredTo Donlin Creek138 kV Transmission LineTo Bethel Power Plant138 kV Breaker and Bypass SwitchUnder Nuvista Light & Power Control19 mi.6.5 mi.17.3 mi.42.1 mi.25 mi.12.9 mi.54.3 mi.13.5 mi.Combustion Turbine42 MWCombustion Turbine42 MWSteam Turbine25 MW Load Data PSS/E Bus Name ID xfmr #kva kw kvar PF 111 Akiachuk 1 500 477 358 0.80 121 Akiak 1 500 408 306 0.80 131 Tuluksak 1 500 264 198 0.80 141 Kalskag 1 500 500 375 0.80 151 Aniak 1 1000 1054 791 0.80 161 Chuathbaluk 1 500 80 60 0.80 171 Crooked Creek 1 500 542 407 0.80 20 SWGR-South 1 7500 5756 4317 0.80 30 SWGR-West 1 7500 4660 3495 0.80 50 SWGR-Yukon 1 7500 5309 3982 0.80 11 Bethel SS1 1 7500 3000 1450 0.90 12 Bethel SS2 1 7500 3000 1450 0.90 40 Donlin Mine 1 80000 55000 18079 0.95 13 Bethel 12.47 1 10000 11143 8357 0.80 14 Bethel 4.16 1 5000 5572 4179 0.80 totals 96288 47445 Electric Power Systems, Inc. 8/12/2003 Transmission Line Data BUS#BUS#CKT Conductor D12 D23 D13 GMD Len (miles) Height (ft)kV Zbase R (pu)X (pu)B (pu)MVA-N 100 105 1 954 ACSR 7.1 7.1 10.0 7.94 5.3 50 138.0 190.4 0.0031 0.0178 0.00671 241.4 105 110 1 954 ACSR 16.0 16.0 32.0 20.16 13.7 65 138.0 190.4 0.0081 0.0543 0.01465 241.4 110 120 1 954 ACSR 16.0 16.0 32.0 20.16 6.5 65 138.0 190.4 0.0039 0.0258 0.00695 241.4 120 130 1 954 ACSR 16.0 16.0 32.0 20.16 17.3 65 138.0 190.4 0.0102 0.0685 0.01850 241.4 130 140 1 954 ACSR 16.0 16.0 32.0 20.16 42.1 65 138.0 190.4 0.0249 0.1668 0.04501 241.4 140 150 1 954 ACSR 16.0 16.0 32.0 20.16 25.0 65 138.0 190.4 0.0148 0.0990 0.02673 241.4 150 160 1 954 ACSR 16.0 16.0 32.0 20.16 12.9 65 138.0 190.4 0.0076 0.0511 0.01379 241.4 160 170 1 954 ACSR 16.0 16.0 32.0 20.16 54.3 65 138.0 190.4 0.0322 0.2151 0.05806 241.4 170 180 1 954 ACSR 16.0 16.0 32.0 20.16 13.5 65 138.0 190.4 0.0080 0.0535 0.01443 241.4 CalculatedAssumed Geometry Electric Power Systems, Inc.8/12/2003 Transformer Data BUS#BUS#CKT %Z X/R MVA R (pu)X (pu) 10 100 1 9 27.3 40 0.0082 0.2248 10 100 2 9 27.3 40 0.0082 0.2248 10 100 3 9 27.3 40 0.0082 0.2248 10 11 1 6.5 14.23 7.5 0.0608 0.8645 10 12 1 6.5 14.23 7.5 0.0608 0.8645 111 110 1 9 3.09 0.500 5.5422 17.1255 121 120 1 9 3.09 0.500 5.5422 17.1255 131 130 1 9 3.09 0.500 5.5422 17.1255 141 140 1 9 3.09 0.500 5.5422 17.1255 151 150 1 9 5.79 1.000 1.5317 8.8687 161 160 1 9 3.09 0.500 5.5422 17.1255 171 170 1 9 3.09 0.500 5.5422 17.1255 40 180 1 9 27.3 40 0.0082 0.2248 40 180 2 9 27.3 40 0.0082 0.2248 10 20 1 6.5 14.23 7.500 0.0608 0.8645 10 30 1 6.5 14.23 7.500 0.0608 0.8645 140 50 1 6.5 14.23 7.500 0.0608 0.8645 Calculatedon xfmr base Electric Power Systems, Inc.8/12/2003 PSS/E Power Flow Data Electric Power Systems, Inc. 8/12/2003 PTI INTERACTIVE POWER SYSTEM SIMULATOR--PSS/E TUE, AUG 12 2003 17:35 DONLAN MINE STUDIES BY EPS, JULY 2003 SYSTEM SUMMARY MINE LOAD 55 MW WITH SVC ------------------BUSES------------------ GENERATION AREAS ZONES OWNERS AREA TOTAL PQ<>0. PQ=0. PE/E PE/Q SWING OTHER LOADS PLANTS MACHS USED USED USED TRANS 27 15 11 0 0 1 0 15 1 7 1 4 1 0 ------------------AC BRANCHES------------------- 3WND MULTI-SECTION X---DC LINES--X FACTS TOTAL RXB RX RXT RX=0. IN OUT XFRM LINES SECTNS 2-TRM N-TRM VSC DEVS 29 9 0 20 0 29 0 1 0 0 0 0 0 0 TOTAL GENERATION PQLOAD I LOAD Y LOAD SHUNTS CHARGING LOSSES SWING MW 101.7 96.8 0.0 0.0 0.0 0.0 4.9 101.7 MVAR 33.4 47.8 0.0 0.0 -33.2 20.7 39.5 33.4 TOTAL MISMATCH = 0.00 MVA X-----AT BUS-----X SYSTEM X------SWING-----X MAX. MISMATCH = 0.00 MVA 40 DONLIN 13.8 BASE 10 BETHEL 13.8 HIGH VOLTAGE = 1.04000 PU 10 BETHEL 13.8 100.0 LOW VOLTAGE = 0.94037 PU 14 BETHEL 4.16 ADJTHR ACCTAP TAPLIM THRSHZ PQBRAK 0.0050 1.0000 0.0500 0.000100 0.700 X-------SOLV AND MSLV-------X X----------NEWTON----------X X------TYSL------X ACCP ACCQ ACCM TOL ITER ACCN TOL ITER DVLIM NDVFCT ACCTY TOL ITER BLOWUP 1.600 1.600 1.000 0.00010 100 1.00 0.100 20 0.9900 0.9900 1.000 0.000010 20 5.00 PSS/E Power Flow Data Electric Power Systems, Inc. 8/12/2003 PTI INTERACTIVE POWER SYSTEM SIMULATOR--PSS/E TUE, AUG 12 2003 17:35 DONLAN MINE STUDIES BY EPS, JULY 2003 BUS DATA MINE LOAD 55 MW WITH SVC BUS# NAME BSKV CODE LOADS VOLT ANGLE S H U N T AREA ZONE OWNER 10 BETHEL 13.800 3 0 1.0400 0.0 0.0 0.0 1 1 1 11 BETHEL 4.1600 1 1 1.0257 28.7 0.0 0.0 1 1 1 12 BETHEL 4.1600 1 1 1.0257 28.7 0.0 0.0 1 1 1 13 BETHEL 12.470 1 1 0.9587 -5.0 0.0 0.0 1 1 1 14 BETHEL 4.1600 1 1 0.9404 -6.0 0.0 0.0 1 1 1 20 SWGR-S 138.00 1 1 0.9980 -2.6 0.0 0.0 1 3 1 30 SWGR-W 138.00 1 1 1.0065 -2.1 0.0 0.0 1 3 1 40 DONLIN 13.800 1 1 1.0000 -32.6 0.0 50.0 1 4 1 50 SWGR-YUK138.00 1 1 0.9608 12.4 0.0 0.0 1 3 1 100 BETHEL 138.00 1 0 1.0347 27.3 0.0 0.0 1 1 1 105 DUMMY 138.00 1 0 1.0321 26.6 0.0 0.0 1 1 1 110 AKIACHUK138.00 1 0 1.0253 24.7 0.0 0.0 1 1 1 111 AKIACHUK12.470 1 1 0.9983 -9.1 0.0 0.0 1 2 1 120 AKIAK 138.00 1 0 1.0223 23.7 0.0 0.0 1 1 1 121 AKIAK 12.470 1 1 0.9999 -9.4 0.0 0.0 1 2 1 130 TULUKSAK138.00 1 0 1.0152 21.2 0.0 0.0 1 1 1 131 TULUKSAK12.470 1 1 1.0064 -10.8 0.0 0.0 1 2 1 140 KALSKAG 138.00 1 0 1.0010 15.0 0.0 0.0 1 1 1 141 KALSKAG 12.470 1 1 0.9854 -19.1 0.0 0.0 1 2 1 150 ANIAK 138.00 1 0 1.0000 11.6 0.0 50.0 1 1 1 151 ANIAK 12.470 1 1 0.9900 -23.5 0.0 0.0 1 2 1 160 CHUATHBA138.00 1 0 0.9982 9.9 0.0 0.0 1 1 1 161 CHUATHBA12.470 1 1 1.0078 -20.7 0.0 0.0 1 2 1 170 CROOKED 138.00 1 0 0.9926 2.8 0.0 0.0 1 1 1 171 CROOKED 12.470 1 1 0.9630 -31.9 0.0 0.0 1 2 1 180 DONLIN 138.00 1 0 0.9920 1.0 0.0 0.0 1 4 1 PSS/E Power Flow Data Electric Power Systems, Inc. 8/12/2003 PTI INTERACTIVE POWER SYSTEM SIMULATOR--PSS/E TUE, AUG 12 2003 17:35 DONLAN MINE STUDIES BY EPS, JULY 2003 LOAD DATA MINE LOAD 55 MW WITH SVC BUS# NAME BSKV ID CD ST PSI MVA-LOAD CUR-LOAD Y - LOAD AREA ZONE OWNER 11 BETHEL 4.16 1 1 1 1.000 3.0 1.5 0.0 0.0 0.0 0.0 1 1 1 12 BETHEL 4.16 1 1 1 1.000 3.0 1.5 0.0 0.0 0.0 0.0 1 1 1 13 BETHEL 12.5 1 1 1 1.000 11.1 8.4 0.0 0.0 0.0 0.0 1 1 1 14 BETHEL 4.16 1 1 1 1.000 5.6 4.2 0.0 0.0 0.0 0.0 1 1 1 20 SWGR-S 138 1 1 1 1.000 5.8 4.3 0.0 0.0 0.0 0.0 1 3 1 30 SWGR-W 138 1 1 1 1.000 4.7 3.5 0.0 0.0 0.0 0.0 1 3 1 40 DONLIN 13.8 1 1 1 1.000 55.0 18.1 0.0 0.0 0.0 0.0 1 4 1 50 SWGR-YUK 138 1 1 1 1.000 5.3 4.0 0.0 0.0 0.0 0.0 1 3 1 111 AKIACHUK12.5 1 1 1 1.000 0.5 0.4 0.0 0.0 0.0 0.0 1 2 1 121 AKIAK 12.5 1 1 1 1.000 0.4 0.3 0.0 0.0 0.0 0.0 1 2 1 131 TULUKSAK12.5 1 1 1 1.000 0.3 0.2 0.0 0.0 0.0 0.0 1 2 1 141 KALSKAG 12.5 1 1 1 1.000 0.5 0.4 0.0 0.0 0.0 0.0 1 2 1 151 ANIAK 12.5 1 1 1 1.000 1.1 0.8 0.0 0.0 0.0 0.0 1 2 1 161 CHUATHBA12.5 1 1 1 1.000 0.1 0.1 0.0 0.0 0.0 0.0 1 2 1 171 CROOKED 12.5 1 1 1 1.000 0.5 0.4 0.0 0.0 0.0 0.0 1 2 1 PTI INTERACTIVE POWER SYSTEM SIMULATOR--PSS/E TUE, AUG 12 2003 17:35 DONLAN MINE STUDIES BY EPS, JULY 2003 GENERATING MINE LOAD 55 MW WITH SVC PLANT DATA BUS# NAME BSKV COD MCNS PGEN QGEN QMAX QMIN VSCHED VACT. PCT Q REMOTE 10 BETHEL 13.8 3 7 101.7 33.4 99.0 -49.5 1.0400 1.0400 100.0 PTI INTERACTIVE POWER SYSTEM SIMULATOR--PSS/E TUE, AUG 12 2003 17:35 DONLAN MINE STUDIES BY EPS, JULY 2003 GENERATOR MINE LOAD 55 MW WITH SVC UNIT DATA BUS# NAME BSKV CD ID ST PGEN QGEN QMAX QMIN PMAX PMIN OWN FRACT OWN FRACT MBASE Z S O R C E 10 BETHEL 13.8 3 1 1 39.5 13.0 33.8 -16.9 45.0 0.0 1 1.000 56.2 0.0000 0.2100 10 BETHEL 13.8 3 2 1 39.5 13.0 33.8 -16.9 45.0 0.0 1 1.000 56.2 0.0000 0.2100 10 BETHEL 13.8 3 3 1 22.6 7.4 31.5 -15.8 42.0 0.0 1 1.000 52.5 0.0000 0.1660 10 BETHEL 13.8 3 4 0 25.0 0.0 31.5 -15.8 42.0 0.0 1 1.000 52.5 0.0000 0.1710 10 BETHEL 13.8 3 5 0 25.0 0.0 31.5 -15.8 42.0 0.0 1 1.000 52.5 0.0000 0.1710 10 BETHEL 13.8 3 6 0 25.0 0.0 31.5 -15.8 42.0 0.0 1 1.000 52.5 0.0000 0.1710 10 BETHEL 13.8 3 7 0 15.0 0.0 18.8 -9.4 25.0 0.0 1 1.000 31.2 0.0000 0.1660 PSS/E Power Flow Data Electric Power Systems, Inc. 8/12/2003 PTI INTERACTIVE POWER SYSTEM SIMULATOR--PSS/E TUE, AUG 12 2003 17:35 DONLAN MINE STUDIES BY EPS, JULY 2003 SWITCHED MINE LOAD 55 MW WITH SVC SHUNT DATA BUS# MOD VHI VLO SHUNT X-------X X-------X X-------X X-------X REMOTE VSC NAME 40 2 1.0000 1.0000 -21.07 1:-100.00 150 2 1.0000 1.0000 -45.76 1:-100.00 PTI INTERACTIVE POWER SYSTEM SIMULATOR--PSS/E TUE, AUG 12 2003 17:35 DONLAN MINE STUDIES BY EPS, JULY 2003 BRANCH DATA MINE LOAD 55 MW WITH SVC X------FROM------X X-------TO-------X Z S BUS# NAME BSKV BUS# NAME BSKV CKT LINE R LINE X CHRGING I T RATEA RATEB RATEC LENGTH OWN1 FRAC1 OWN2 FRAC2 OWN3 FRAC3 OWN4 FRAC4 100 BETHEL 138* 105 DUMMY 138 1 0.00314 0.01785 0.00671 1 241.4 0.0 0.0 0.0 1 1.000 105 DUMMY 138* 110 AKIACHUK 138 1 0.00811 0.05428 0.01465 1 241.4 0.0 0.0 0.0 1 1.000 110 AKIACHUK 138* 120 AKIAK 138 1 0.00385 0.02575 0.00695 1 241.4 0.0 0.0 0.0 1 1.000 120 AKIAK 138* 130 TULUKSAK 138 1 0.01025 0.06854 0.01850 1 241.4 0.0 0.0 0.0 1 1.000 130 TULUKSAK 138* 140 KALSKAG 138 1 0.02494 0.16679 0.04501 1 241.4 0.0 0.0 0.0 1 1.000 140 KALSKAG 138* 150 ANIAK 138 1 0.01481 0.09904 0.02673 1 241.4 0.0 0.0 0.0 1 1.000 150 ANIAK 138* 160 CHUATHBA 138 1 0.00764 0.05111 0.01379 1 241.4 0.0 0.0 0.0 1 1.000 160 CHUATHBA 138* 170 CROOKED 138 1 0.03216 0.21512 0.05806 1 241.4 0.0 0.0 0.0 1 1.000 170 CROOKED 138* 180 DONLIN 138 1 0.00800 0.05348 0.01443 1 241.4 0.0 0.0 0.0 1 1.000 PSS/E Power Flow Data Electric Power Systems, Inc. 8/12/2003 PTI INTERACTIVE POWER SYSTEM SIMULATOR--PSS/E TUE, AUG 12 2003 17:35 DONLAN MINE STUDIES BY EPS, JULY 2003 2 WINDING XFRMER MINE LOAD 55 MW WITH SVC IMPEDANCE DATA X------FROM------X X-------TO-------X XFRMER C C BUS# NAME BSKV BUS# NAME BSKV CKT NAME Z M R 1-2 X 1-2 W1BASE MAG1 MAG2 RATA RATB RATC 10 BETHEL 13.8 11 BETHEL 4.16 1 1 1 0.06075 0.86453 100.0 0.0000 0.0000 8 0 0 10 BETHEL 13.8 12 BETHEL 4.16 1 1 1 0.06075 0.86453 100.0 0.0000 0.0000 8 0 0 10 BETHEL 13.8 20 SWGR-S 138 1 1 1 0.06075 0.86453 100.0 0.0000 0.0000 8 0 0 10 BETHEL 13.8 30 SWGR-W 138 1 1 1 0.06075 0.86453 100.0 0.0000 0.0000 8 0 0 10 BETHEL 13.8 100 BETHEL 138 1 1 1 0.00824 0.22485 100.0 0.0000 0.0000 40 0 0 10 BETHEL 13.8 100 BETHEL 138 2 1 1 0.00824 0.22485 100.0 0.0000 0.0000 40 0 0 10 BETHEL 13.8 100 BETHEL 138 3 1 1 0.00824 0.22485 100.0 0.0000 0.0000 40 0 0 40 DONLIN 13.8 180 DONLIN 138 1 1 1 0.00824 0.22485 100.0 0.0000 0.0000 40 0 0 40 DONLIN 13.8 180 DONLIN 138 2 1 1 0.00824 0.22485 100.0 0.0000 0.0000 40 0 0 50 SWGR-YUK 138 140 KALSKAG 138 1 1 1 0.06075 0.86453 100.0 0.0000 0.0000 8 0 0 110 AKIACHUK 138 111 AKIACHUK12.5 1 1 1 5.54224 17.12552 100.0 0.0000 0.0000 1 0 0 120 AKIAK 138 121 AKIAK 12.5 1 1 1 5.54224 17.12552 100.0 0.0000 0.0000 1 0 0 130 TULUKSAK 138 131 TULUKSAK12.5 1 1 1 5.54224 17.12552 100.0 0.0000 0.0000 1 0 0 140 KALSKAG 138 141 KALSKAG 12.5 1 1 1 5.54224 17.12552 100.0 0.0000 0.0000 1 0 0 150 ANIAK 138 151 ANIAK 12.5 1 1 1 1.53173 8.86870 100.0 0.0000 0.0000 1 0 0 160 CHUATHBA 138 161 CHUATHBA12.5 1 1 1 5.54224 17.12552 100.0 0.0000 0.0000 1 0 0 170 CROOKED 138 171 CROOKED 12.5 1 1 1 5.54224 17.12552 100.0 0.0000 0.0000 1 0 0 PTI INTERACTIVE POWER SYSTEM SIMULATOR--PSS/E TUE, AUG 12 2003 17:35 DONLAN MINE STUDIES BY EPS, JULY 2003 2 WINDING XFRMER MINE LOAD 55 MW WITH SVC TAP & CONTROL DATA X------FROM------X X-------TO-------X S M W C X--CONTROLLED BUS-X BUS# NAME BSKV BUS# NAME BSKV CKT T T 1 W WINDV1 NOMV1 ANGLE WINDV2 NOMV2 CN RMAX RMIN VMAX VMIN NTPS BUS# NAME BSKV 10 BETHEL 13.8 11 BETHEL 4.16 1 1 T T 1 1.0000 0.000 30.0 1.0000 0.000 0 1.1000 0.9000 1.1000 0.9000 5 10 BETHEL 13.8 12 BETHEL 4.16 1 1 T T 1 1.0000 0.000 30.0 1.0000 0.000 0 1.1000 0.9000 1.1000 0.9000 5 10 BETHEL 13.8 20 SWGR-S 138 1 1 T T 1 1.0000 0.000 0.0 1.0000 0.000 0 1.1000 0.9000 1.1000 0.9000 5 10 BETHEL 13.8 30 SWGR-W 138 1 1 T T 1 1.0000 0.000 0.0 1.0000 0.000 0 1.1000 0.9000 1.1000 0.9000 5 10 BETHEL 13.8 100 BETHEL 138 1 1 T T 1 1.0000 0.000 30.0 1.0000 0.000 0 1.1000 0.9000 1.1000 0.9000 5 10 BETHEL 13.8 100 BETHEL 138 2 1 T T 1 1.0000 0.000 30.0 1.0000 0.000 0 1.1000 0.9000 1.1000 0.9000 5 10 BETHEL 13.8 100 BETHEL 138 3 1 T T 1 1.0000 0.000 30.0 1.0000 0.000 0 1.1000 0.9000 1.1000 0.9000 5 40 DONLIN 13.8 180 DONLIN 138 1 1 F F 1 1.0000 0.000 -30.0 1.0000 0.000 0 1.1000 0.9000 1.1000 0.9000 5 40 DONLIN 13.8 180 DONLIN 138 2 1 F F 1 1.0000 0.000 -30.0 1.0000 0.000 0 1.1000 0.9000 1.1000 0.9000 5 50 SWGR-YUK 138 140 KALSKAG 138 1 1 F F 1 1.0000 0.000 0.0 1.0000 0.000 0 1.1000 0.9000 1.1000 0.9000 5 110 AKIACHUK 138 111 AKIACHUK12.5 1 1 T T 1 1.0750 0.000 -30.0 1.0000 0.000 1 1.1000 0.9000 1.0100 0.9900 33 -111 AKIACHUK12.5 120 AKIAK 138 121 AKIAK 12.5 1 1 T T 1 1.0625 0.000 -30.0 1.0000 0.000 1 1.1000 0.9000 1.0100 0.9900 33 -121 AKIAK 12.5 130 TULUKSAK 138 131 TULUKSAK12.5 1 1 T T 1 1.0437 0.000 -30.0 1.0000 0.000 1 1.1000 0.9000 1.0100 0.9900 33 -131 TULUKSAK12.5 140 KALSKAG 138 141 KALSKAG 12.5 1 1 T T 1 1.1000 0.000 -30.0 1.0000 0.000 1 1.1000 0.9000 1.0100 0.9900 33 -141 KALSKAG 12.5 150 ANIAK 138 151 ANIAK 12.5 1 1 T T 1 1.1000 0.000 -30.0 1.0000 0.000 1 1.1000 0.9000 1.0100 0.9900 33 -151 ANIAK 12.5 160 CHUATHBA 138 161 CHUATHBA12.5 1 1 T T 1 1.0250 0.000 -30.0 1.0000 0.000 1 1.1000 0.9000 1.0100 0.9900 33 -161 CHUATHBA12.5 170 CROOKED 138 171 CROOKED 12.5 1 1 T T 1 1.1000 0.000 -30.0 1.0000 0.000 1 1.1000 0.9000 1.0100 0.9900 33 -171 CROOKED 12.5 PSS/E Power Flow Data Electric Power Systems, Inc. 8/12/2003 PTI INTERACTIVE POWER SYSTEM SIMULATOR--PSS/E TUE, AUG 12 2003 17:35 DONLAN MINE STUDIES BY EPS, JULY 2003 3 WINDING XFRMER MINE LOAD 55 MW WITH SVC IMPEDANCE DATA XFRMER X--WINDING 1 BUS-X X--WINDING 2 BUS-X X--WINDING 3 BUS-X S C NAME BUS# NAME BSKV BUS# NAME BSKV BUS# NAME BSKV CKT T Z R 1-2 X 1-2 R 2-3 X 2-3 R 3-1 X 3-1 OWNR FRACT 10 BETHEL 13.8 13 BETHEL 12.5 14 BETHEL 4.16 1 1 1 0.04200 0.64900 0.10600 1.29600 0.10600 1.29600 1 1.000 PTI INTERACTIVE POWER SYSTEM SIMULATOR--PSS/E TUE, AUG 12 2003 17:35 DONLAN MINE STUDIES BY EPS, JULY 2003 3 WINDING XFRMER MINE LOAD 55 MW WITH SVC WINDING DATA XFRMER X---WINDING BUS--X S C C C STAR POINT BUS NAME BUS# NAME BSKV T W Z M R WNDNG X WNDNG WBASE WIND V NOM V ANGLE RATA RATB RATC MAG1 MAG2 VOLTAGE ANGLE 10 BETHEL 13.8* 1 1 1 1 0.02100 0.32450 100.0 1.0000 0.000 0.0 15 0 0 0.00000 0.00000 0.99005 -2.9 13 BETHEL 12.5 1 0.02100 0.32450 100.0 1.0000 0.000 0.0 10 0 0 14 BETHEL 4.16* 1 0.08500 0.97150 100.0 1.0000 0.000 0.0 5 0 0 PTI INTERACTIVE POWER SYSTEM SIMULATOR--PSS/E TUE, AUG 12 2003 17:35 DONLAN MINE STUDIES BY EPS, JULY 2003 3 WINDING XFRMER MINE LOAD 55 MW WITH SVC CONTROL DATA XFRMER X--WINDING 1 BUS-X C C X--CONTROLLED BUS-X NAME BUS# NAME BSKV W Z CN RMAX RMIN VMAX VMIN NTPS BUS# NAME BSKV CR CX 10 BETHEL 13.8 1 1 0 1.1000 0.9000 1.1000 0.9000 5 APPENDIX 2 DONLIN CREEK MINE PROJECT SYSTEM STUDIES Appendix 2 Power Flow Results (Onelines) APPENDIX 3 DONLIN CREEK MINE PROJECT SYSTEM STUDIES Appendix 3 Short Circuit Oneline Diagram Short Circuit Results (Two Generation Alternatives) One-Line Diagram - OLV1 page 1 11:38:56 Aug 13, 2003 Project File: Bethel-DonlanMine Coal2 13.8 kV Coal3 13.8 kV Combustion 3 13.8 kV Combustion 2 13.8 kV Combustion 1 13.8 kV Bethel 13.8 kV Donlan Mine 13.8 kV Donlan 138 kV Crooked Creek Load 12.47 kV Crooked Creek 138 kV Chuath. Load 12.47 kV Chuathbaluk 138 kV Aniak Load 12.47 kV Aniak 138 kV Kalskag Load 12.47 kV Tuluksak Load 12.47 kV Akiak Load 12.47 kV Akiachak Load 12.47 kV SWGR South 80 kV SWGR West 80 kV Bethel Sub 1 12.47 kV Bethel Sub 2 4.16 kV Bethel SS2 4.16 kV Coal 1 13.8 kVBethel SS1 4.16 kV Bethel 138 138 kV Dummy 138 kV Akiachak 138 kV Akiak 138 kV Tuluksak 138 kV Kalskag 138 kV SWGR Yukon 80 kV T22 7.5 MVA PA1 Line7 Line5 Line4 Line2 Line1 T2 40 MVA SS1 7.5 MVA Load SS1 3.332 MVA CB1 Gen1 45 MW SS2 7.5 MVA Load SS2 3.332 MVA T1 15/10/5 MVA Load2 6.965 MVALoad1 13.929 MVA T4 40 MVA T5 40 MVA PA3 T24 7.5 MVA Load205825 kVA PA5 T26 7.5 MVA Load227195 kVA T7 500 kVA Load3 596 kVA T9 500 kVA Load7 510 kVA T12 500 kVA Load10 330 kVA T10 500 kVA Load8 625 kVA Line9 T14 1000 kVA Load13 1318 kVA Line11 T16 500 kVA Load15 100 kVA Line13 T18 500 kVA Load17 678 kVALine14 T19 40 MVA T21 40 MVA Mine Load 57.895 MVA Donlan SVC 0 MW Aniak SVC 0 MW Load18 6636 kVA SWGR Yukon 80 kV Donlan Mine 13.8 kV Donlan 138 kV Akiachak Load 12.47 kV Akiachak 138 kV Dummy 138 kV Bethel 138 138 kV Bethel Sub 2 4.16 kV Bethel Sub 1 12.47 kV Bethel SS2 4.16 kV Bethel SS1 4.16 kV Bethel 13.8 kV SS1 7.5 MVA Load SS1 3.332 MVA SS2 7.5 MVA Load SS2 3.332 MVA T1 15/10/5 MVA Load1 13.929 MVA Load2 6.965 MVA T2 40 MVA T4 40 MVA T5 40 MVA Line1 Line2 Akiak 138 kV Line4 Tuluksak 138 kV Line5 T7 500 kVA Load3 596 kVA Load7 510 kVA Akiak Load 12.47 kVT9 500 kVA Kalskag 138 kVLine7 T10 500 kVA Kalskag Load 12.47 kV Load8 625 kVA T12 500 kVA Tuluksak Load 12.47 kV Load10 330 kVA Load13 1318 kVA Aniak Load 12.47 kV T14 1000 kVA Aniak 138 kVLine9 T16 500 kVA Chuath. Load 12.47 kV Load15 100 kVA Line11 Chuathbaluk 138 kV T18 500 kVA Crooked Creek Load 12.47 kV Load17 678 kVA Line13 Crooked Creek 138 kV Line14 T19 40 MVA T21 40 MVA Mine Load 57.895 MVA Donlan SVC 0 MW Aniak SVC 0 MW PA1 T22 7.5 MVA Load18 6636 kVA SWGR West 80 kV PA3 T24 7.5 MVA Load205825 kVA SWGR South 80 kV PA5 T26 7.5 MVA Load227195 kVA CB3 Gen3 42 MW CB3 CB5 Gen5 42 MW CB6 Gen6 42 MW Combustion 1 13.8 kV Gen3 42 MW Coal 1 13.8 kV CB1 CB9 Gen9 25 MW CB8 Gen8 45 MW Gen1 45 MW Gen8 45 MW Coal2 13.8 kV CB8 Gen9 25 MW Coal3 13.8 kV CB9 Gen5 42 MW CB5 Combustion 2 13.8 kV Gen6 42 MW Combustion 3 13.8 kV CB6 Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: Coal Fired 4.7.0C Page:1 SN: ELECPOWERS Filename:Bethel-DonlanMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:08-13-2003 Revision:Base Config.: Normal Coal Fired Generation - All Units Online SHORT- CIRCUIT REPORT Fault at bus:Akiachak Nominal kV =138.000 Prefault Voltage =100.00 % of nominal bus kV Base kV =138.000 =100.00 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Akiachak Total 0.00 1.903 0.00 102.46 106.48 1.743 3.87E+000 2.78E+001 1.743 1.54E+000 2.19E+001 Dummy Akiachak 24.91 1.899 36.60 96.29 98.61 1.642 4.26E+000 3.36E+001 1.446 1.55E+000 2.20E+001 Akiak Akiachak 0.03 0.004 1.92 101.41 105.44 0.093 3.33E+001 1.78E+002 0.271 1.02E+002 9.56E+003 *Akiachak Load Akiachak 0.00 0.000 64.55 62.11 105.00 0.009 5.54E+002 1.71E+003 0.027 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: Coal Fired 4.7.0C Page:2 SN: ELECPOWERS Filename:Bethel-DonlanMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:08-13-2003 Revision:Base Config.: Normal Coal Fired Generation - All Units Online Fault at bus:Akiachak Load Nominal kV =12.470 Prefault Voltage =100.00 % of nominal bus kV Base kV =13.094 =95.24 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Akiachak Load Total 0.00 0.231 0.00 173.21 173.21 0.000 0.000 5.56E+002 1.73E+003 Akiachak Akiachak Load 94.12 0.231 95.24 95.24 95.24 0.000 0.000 5.56E+002 1.73E+003 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: Coal Fired 4.7.0C Page:3 SN: ELECPOWERS Filename:Bethel-DonlanMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:08-13-2003 Revision:Base Config.: Normal Coal Fired Generation - All Units Online Fault at bus:Akiak Nominal kV =138.000 Prefault Voltage =100.00 % of nominal bus kV Base kV =138.000 =100.00 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Akiak Total 0.00 1.703 0.00 104.01 107.96 1.515 4.88E+000 3.34E+001 1.515 1.93E+000 2.45E+001 Akiachak Akiak 10.57 1.698 14.81 101.25 104.68 1.413 5.65E+000 4.16E+001 1.217 1.94E+000 2.46E+001 Tuluksak Akiak 0.07 0.004 5.07 101.24 105.12 0.092 3.28E+001 1.87E+002 0.269 1.02E+002 9.56E+003 *Akiak Load Akiak 0.00 0.000 65.45 63.05 105.00 0.009 5.54E+002 1.71E+003 0.028 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: Coal Fired 4.7.0C Page:4 SN: ELECPOWERS Filename:Bethel-DonlanMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:08-13-2003 Revision:Base Config.: Normal Coal Fired Generation - All Units Online Fault at bus:Akiak Load Nominal kV =12.470 Prefault Voltage =100.00 % of nominal bus kV Base kV =13.094 =95.24 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Akiak Load Total 0.00 0.230 0.00 173.21 173.21 0.000 0.000 5.56E+002 1.74E+003 Akiak Akiak Load 93.99 0.230 95.24 95.24 95.24 0.000 0.000 5.56E+002 1.74E+003 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: Coal Fired 4.7.0C Page:5 SN: ELECPOWERS Filename:Bethel-DonlanMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:08-13-2003 Revision:Base Config.: Normal Coal Fired Generation - All Units Online Fault at bus:Aniak Nominal kV =138.000 Prefault Voltage =100.00 % of nominal bus kV Base kV =138.000 =100.00 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Aniak Total 0.00 0.721 0.00 99.42 101.66 0.713 9.37E+000 5.92E+001 0.713 6.86E+000 5.77E+001 Kalskag Aniak 17.15 0.716 19.22 98.33 100.49 0.570 2.34E+001 1.44E+002 0.293 6.94E+000 5.80E+001 Chuathbaluk Aniak 0.03 0.002 5.21 96.98 99.03 0.126 1.75E+001 1.13E+002 0.373 1.87E+002 1.82E+004 *Aniak Load Aniak 0.00 0.000 61.63 60.27 105.00 0.015 1.62E+002 9.36E+002 0.045 Aniak SVC Aniak 100.00 0.002 100.00 100.00 100.00 0.002 2.00E+002 2.00E+004 0.002 2.00E+002 2.00E+004 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: Coal Fired 4.7.0C Page:6 SN: ELECPOWERS Filename:Bethel-DonlanMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:08-13-2003 Revision:Base Config.: Normal Coal Fired Generation - All Units Online Fault at bus:Aniak Load Nominal kV =12.470 Prefault Voltage =100.00 % of nominal bus kV Base kV =13.094 =95.24 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Aniak Load Total 0.00 0.417 0.00 173.21 173.21 0.000 0.000 1.69E+002 9.94E+002 Aniak Aniak Load 89.76 0.417 95.24 95.24 95.24 0.000 0.000 1.69E+002 9.94E+002 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: Coal Fired 4.7.0C Page:7 SN: ELECPOWERS Filename:Bethel-DonlanMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:08-13-2003 Revision:Base Config.: Normal Coal Fired Generation - All Units Online Fault at bus:Bethel Nominal kV =13.800 Prefault Voltage =100.00 % of nominal bus kV Base kV =13.800 =100.00 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Bethel Total 0.00 57.557 0.00 100.01 100.01 57.542 1.52E-001 7.27E+000 57.542 1.51E-001 7.27E+000 Bethel SS1 Bethel 0.00 0.000 57.74 57.74 100.00 0.000 0.000 Bethel SS2 Bethel 0.00 0.000 57.74 57.74 100.00 0.000 0.000 Bethel 138 Bethel 0.08 0.015 57.76 100.00 57.77 0.010 0.000 3.10E+002 2.87E+004 Bethel 138 Bethel 0.08 0.015 57.76 100.00 57.77 0.010 0.000 3.10E+002 2.87E+004 Bethel 138 Bethel 0.08 0.015 57.76 100.00 57.77 0.010 0.000 3.10E+002 2.87E+004 Bethel Sub 2 Bethel 0.00 0.000 33.35 88.19 88.19 0.000# 0.000 Bethel Sub 1 Bethel 0.00 0.000 33.35 88.19 88.19 0.000# 0.000 Gen8 Coal2 100.00 19.607 100.00 100.00 100.00 19.607 4.44E-001 2.13E+001 19.617 4.44E-001 2.13E+001 Gen3 Combustion 1 100.00 18.300 100.00 100.00 100.00 18.300 4.76E-001 2.29E+001 18.309 4.76E-001 2.29E+001 Gen1 Coal 1 100.00 19.607 100.00 100.00 100.00 19.607 4.44E-001 2.13E+001 19.617 4.44E-001 2.13E+001 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: Coal Fired 4.7.0C Page:8 SN: ELECPOWERS Filename:Bethel-DonlanMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:08-13-2003 Revision:Base Config.: Normal Coal Fired Generation - All Units Online Fault at bus:Bethel 138 Nominal kV =138.000 Prefault Voltage =100.00 % of nominal bus kV Base kV =138.000 =100.00 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Bethel 138 Total 0.00 2.836 0.00 91.18 91.79 3.418 3.06E-001 7.21E+000 3.418 4.25E-001 1.47E+001 Dummy Bethel 138 0.02 0.004 0.82 90.90 91.57 0.047 3.61E+001 1.87E+002 0.129 1.03E+002 9.57E+003 *Bethel Bethel 138 50.77 0.944 72.64 72.14 100.00 1.124 8.24E-001 2.25E+001 1.097 1.28E+000 4.43E+001 *Bethel Bethel 138 50.77 0.944 72.64 72.14 100.00 1.124 8.24E-001 2.25E+001 1.097 1.28E+000 4.43E+001 *Bethel Bethel 138 50.77 0.944 72.64 72.14 100.00 1.124 8.24E-001 2.25E+001 1.097 1.28E+000 4.43E+001 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: Coal Fired 4.7.0C Page:9 SN: ELECPOWERS Filename:Bethel-DonlanMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:08-13-2003 Revision:Base Config.: Normal Coal Fired Generation - All Units Online Fault at bus:Bethel SS1 Nominal kV =4.160 Prefault Voltage =100.00 % of nominal bus kV Base kV =4.160 =100.00 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Bethel SS1 Total 0.00 14.776 0.00 98.60 98.81 15.167 6.08E+000 8.65E+001 15.167 6.23E+000 9.37E+001 *Bethel Bethel SS1 92.27 14.776 95.95 100.00 96.17 15.167 6.08E+000 8.65E+001 15.167 6.23E+000 9.37E+001 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: Coal Fired 4.7.0C Page:10 SN: ELECPOWERS Filename:Bethel-DonlanMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:08-13-2003 Revision:Base Config.: Normal Coal Fired Generation - All Units Online Fault at bus:Bethel SS2 Nominal kV =4.160 Prefault Voltage =100.00 % of nominal bus kV Base kV =4.160 =100.00 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Bethel SS2 Total 0.00 14.776 0.00 98.60 98.81 15.167 6.08E+000 8.65E+001 15.167 6.23E+000 9.37E+001 *Bethel Bethel SS2 92.27 14.776 95.95 100.00 96.17 15.167 6.08E+000 8.65E+001 15.167 6.23E+000 9.37E+001 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: Coal Fired 4.7.4C Page:1 SN: ELECPOWERS Filename:Bethel-DonlinMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:09-03-2003 Revision:Base Config.: Normal Coal Fired Generation - All Units Online SHORT- CIRCUIT REPORT Fault at bus:Bethel Sub 1 Nominal kV =12.470 Prefault Voltage =100.00 % of nominal bus kV Base kV =12.470 =100.00 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Bethel Sub 1 Total 0.00 3.373 0.00 173.21 173.21 0.000 0.000 1.07E+001 1.37E+002 Bethel Bethel Sub 1 94.71 1.928 100.00 100.00 100.00 0.000# 0.000 1.94E+001 2.39E+002 Bethel Sub 2 Bethel Sub 1 71.02 1.445 100.00 100.00 100.00 0.000# 0.000 2.40E+001 3.19E+002 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: Coal Fired 4.7.4C Page:2 SN: ELECPOWERS Filename:Bethel-DonlinMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:09-03-2003 Revision:Base Config.: Normal Coal Fired Generation - All Units Online Fault at bus:Bethel Sub 2 Nominal kV =4.160 Prefault Voltage =100.00 % of nominal bus kV Base kV =4.160 =100.00 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Bethel Sub 2 Total 0.00 19.188 0.00 173.21 173.21 0.000 0.000 4.35E+000 7.22E+001 Bethel Bethel Sub 2 89.96 16.444 100.00 100.00 100.00 0.000# 0.000 4.81E+000 8.43E+001 Bethel Sub 1 Bethel Sub 2 44.98 2.744 100.00 100.00 100.00 0.000# 0.000 4.02E+001 5.04E+002 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: Coal Fired 4.7.0C Page:11 SN: ELECPOWERS Filename:Bethel-DonlanMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:08-13-2003 Revision:Base Config.: Normal Coal Fired Generation - All Units Online Fault at bus:Chuath. Load Nominal kV =12.470 Prefault Voltage =100.00 % of nominal bus kV Base kV =13.094 =95.24 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Chuath. Load Total 0.00 0.226 0.00 173.21 173.21 0.000 0.000 5.62E+002 1.78E+003 Chuathbaluk Chuath. Load 92.06 0.226 95.24 95.24 95.24 0.000 0.000 5.62E+002 1.78E+003 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: Coal Fired 4.7.0C Page:12 SN: ELECPOWERS Filename:Bethel-DonlanMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:08-13-2003 Revision:Base Config.: Normal Coal Fired Generation - All Units Online Fault at bus:Chuathbaluk Nominal kV =138.000 Prefault Voltage =100.00 % of nominal bus kV Base kV =138.000 =100.00 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Chuathbaluk Total 0.00 0.662 0.00 97.59 99.58 0.681 8.98E+000 5.72E+001 0.681 7.61E+000 6.27E+001 Aniak Chuathbaluk 8.15 0.660 9.43 97.11 99.07 0.544 2.29E+001 1.41E+002 0.275 7.66E+000 6.29E+001 Crooked Creek Chuathbaluk 0.12 0.002 22.61 89.72 90.35 0.130 1.47E+001 1.02E+002 0.384 1.86E+002 1.82E+004 *Chuath. Load Chuathbaluk 0.00 0.000 60.37 59.16 105.00 0.007 5.54E+002 1.71E+003 0.022 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: Coal Fired 4.7.0C Page:13 SN: ELECPOWERS Filename:Bethel-DonlanMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:08-13-2003 Revision:Base Config.: Normal Coal Fired Generation - All Units Online Fault at bus:Coal 1 Nominal kV =13.800 Prefault Voltage =100.00 % of nominal bus kV Base kV =13.800 =100.00 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Coal 1 Total 0.00 57.557 0.00 100.01 100.01 57.542 1.52E-001 7.27E+000 57.542 1.51E-001 7.27E+000 Gen1 Coal 1 100.00 19.607 100.00 100.00 100.00 19.607 4.44E-001 2.13E+001 19.617 4.44E-001 2.13E+001 Bethel SS1 Bethel 0.00 0.000 57.74 57.74 100.00 0.000 0.000 Bethel SS2 Bethel 0.00 0.000 57.74 57.74 100.00 0.000 0.000 Bethel 138 Bethel 0.08 0.015 57.76 100.00 57.77 0.010 0.000 3.10E+002 2.87E+004 Bethel 138 Bethel 0.08 0.015 57.76 100.00 57.77 0.010 0.000 3.10E+002 2.87E+004 Bethel 138 Bethel 0.08 0.015 57.76 100.00 57.77 0.010 0.000 3.10E+002 2.87E+004 Bethel Sub 2 Bethel 0.00 0.000 33.35 88.19 88.19 0.000# 0.000 Bethel Sub 1 Bethel 0.00 0.000 33.35 88.19 88.19 0.000# 0.000 Gen8 Coal2 100.00 19.607 100.00 100.00 100.00 19.607 4.44E-001 2.13E+001 19.617 4.44E-001 2.13E+001 Gen3 Combustion 1 100.00 18.300 100.00 100.00 100.00 18.300 4.76E-001 2.29E+001 18.309 4.76E-001 2.29E+001 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: Coal Fired 4.7.0C Page:14 SN: ELECPOWERS Filename:Bethel-DonlanMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:08-13-2003 Revision:Base Config.: Normal Coal Fired Generation - All Units Online Fault at bus:Combustion 1 Nominal kV =13.800 Prefault Voltage =100.00 % of nominal bus kV Base kV =13.800 =100.00 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Combustion 1 Total 0.00 57.557 0.00 100.01 100.01 57.542 1.52E-001 7.27E+000 57.542 1.51E-001 7.27E+000 Gen3 Combustion 1 100.00 18.300 100.00 100.00 100.00 18.300 4.76E-001 2.29E+001 18.309 4.76E-001 2.29E+001 Bethel SS1 Bethel 0.00 0.000 57.74 57.74 100.00 0.000 0.000 Bethel SS2 Bethel 0.00 0.000 57.74 57.74 100.00 0.000 0.000 Bethel 138 Bethel 0.08 0.015 57.76 100.00 57.77 0.010 0.000 3.10E+002 2.87E+004 Bethel 138 Bethel 0.08 0.015 57.76 100.00 57.77 0.010 0.000 3.10E+002 2.87E+004 Bethel 138 Bethel 0.08 0.015 57.76 100.00 57.77 0.010 0.000 3.10E+002 2.87E+004 Bethel Sub 2 Bethel 0.00 0.000 33.35 88.19 88.19 0.000# 0.000 Bethel Sub 1 Bethel 0.00 0.000 33.35 88.19 88.19 0.000# 0.000 Gen8 Coal2 100.00 19.607 100.00 100.00 100.00 19.607 4.44E-001 2.13E+001 19.617 4.44E-001 2.13E+001 Gen1 Coal 1 100.00 19.607 100.00 100.00 100.00 19.607 4.44E-001 2.13E+001 19.617 4.44E-001 2.13E+001 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: Coal Fired 4.7.0C Page:15 SN: ELECPOWERS Filename:Bethel-DonlanMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:08-13-2003 Revision:Base Config.: Normal Coal Fired Generation - All Units Online Fault at bus:Crooked Creek Nominal kV =138.000 Prefault Voltage =100.00 % of nominal bus kV Base kV =138.000 =100.00 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Crooked Creek Total 0.00 0.494 0.00 88.92 88.66 0.644 3.04E+000 2.53E+001 0.644 1.08E+001 8.41E+001 Chuathbaluk Crooked Creek 25.55 0.491 26.86 90.25 90.61 0.454 3.41E+001 2.03E+002 0.079 1.09E+001 8.45E+001 Donlan Crooked Creek 0.03 0.002 8.12 87.80 86.93 0.187 3.24E+000 2.93E+001 0.556 1.83E+002 1.82E+004 *Crooked Creek Load Crooked Creek 0.00 0.000 53.75 53.90 105.00 0.003 5.54E+002 1.71E+003 0.009 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: Coal Fired 4.7.0C Page:16 SN: ELECPOWERS Filename:Bethel-DonlanMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:08-13-2003 Revision:Base Config.: Normal Coal Fired Generation - All Units Online Fault at bus:Crooked Creek Load Nominal kV =12.470 Prefault Voltage =100.00 % of nominal bus kV Base kV =13.094 =95.24 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Crooked Creek Load Total 0.00 0.223 0.00 173.21 173.21 0.000 0.000 5.65E+002 1.80E+003 Crooked Creek Crooked Creek Load 91.02 0.223 95.24 95.24 95.24 0.000 0.000 5.65E+002 1.80E+003 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: Coal Fired 4.7.0C Page:17 SN: ELECPOWERS Filename:Bethel-DonlanMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:08-13-2003 Revision:Base Config.: Normal Coal Fired Generation - All Units Online Fault at bus:Donlan Nominal kV =138.000 Prefault Voltage =100.00 % of nominal bus kV Base kV =138.000 =100.00 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Donlan Total 0.00 0.464 0.00 87.67 86.34 0.658 4.70E-001 1.07E+001 0.658 1.16E+001 8.94E+001 Crooked Creek Donlan 5.97 0.462 6.14 87.80 86.71 0.448 3.62E+001 2.00E+002 0.034 1.17E+001 8.98E+001 *Donlan Mine Donlan 0.07 0.001 52.35 53.15 105.00 0.105 8.24E-001 2.25E+001 0.312 3.64E+002 3.63E+004 *Donlan Mine Donlan 0.07 0.001 52.35 53.15 105.00 0.105 8.24E-001 2.25E+001 0.312 3.64E+002 3.63E+004 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: Coal Fired 4.7.0C Page:18 SN: ELECPOWERS Filename:Bethel-DonlanMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:08-13-2003 Revision:Base Config.: Normal Coal Fired Generation - All Units Online Fault at bus:Donlan Mine Nominal kV =13.800 Prefault Voltage =100.00 % of nominal bus kV Base kV =14.490 =95.24 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Donlan Mine Total 0.00 3.750 0.00 171.87 171.69 0.062 1.81E+002 1.81E+004 0.062 1.20E+001 1.00E+002 Donlan Donlan Mine 10.53 1.864 94.59 95.24 94.49 0.021 0.000 2.42E+001 2.02E+002 Donlan Donlan Mine 10.53 1.864 94.59 95.24 94.49 0.021 0.000 2.42E+001 2.02E+002 Donlan SVC Donlan Mine 100.00 0.021 100.00 100.00 100.00 0.021 1.81E+002 1.81E+004 0.062 1.81E+002 1.81E+004 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: Coal Fired 4.7.0C Page:19 SN: ELECPOWERS Filename:Bethel-DonlanMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:08-13-2003 Revision:Base Config.: Normal Coal Fired Generation - All Units Online Fault at bus:Kalskag Nominal kV =138.000 Prefault Voltage =100.00 % of nominal bus kV Base kV =138.000 =100.00 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Kalskag Total 0.00 0.869 0.00 103.05 105.81 0.796 9.71E+000 6.06E+001 0.796 5.40E+000 4.79E+001 Tuluksak Kalskag 34.85 0.864 39.89 99.11 101.31 0.665 1.82E+001 1.18E+002 0.409 5.45E+000 4.81E+001 Aniak Kalskag 0.11 0.004 9.78 98.14 100.55 0.123 2.09E+001 1.34E+002 0.360 9.80E+001 9.53E+003 *Kalskag Load Kalskag 0.00 0.000 64.14 62.47 105.00 0.009 5.54E+002 1.71E+003 0.027 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: Coal Fired 4.7.0C Page:20 SN: ELECPOWERS Filename:Bethel-DonlanMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:08-13-2003 Revision:Base Config.: Normal Coal Fired Generation - All Units Online Fault at bus:Kalskag Load Nominal kV =12.470 Prefault Voltage =100.00 % of nominal bus kV Base kV =13.094 =95.24 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Kalskag Load Total 0.00 0.227 0.00 173.21 173.21 0.000 0.000 5.60E+002 1.76E+003 Kalskag Kalskag Load 92.80 0.227 95.24 95.24 95.24 0.000 0.000 5.60E+002 1.76E+003 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: Coal Fired 4.7.0C Page:21 SN: ELECPOWERS Filename:Bethel-DonlanMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:08-13-2003 Revision:Base Config.: Normal Coal Fired Generation - All Units Online Fault at bus:Tuluksak Nominal kV =138.000 Prefault Voltage =100.00 % of nominal bus kV Base kV =138.000 =100.00 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Tuluksak Total 0.00 1.330 0.00 105.77 109.31 1.148 7.12E+000 4.59E+001 1.148 2.94E+000 3.13E+001 Akiak Tuluksak 21.97 1.326 28.09 100.97 103.82 1.039 9.31E+000 6.38E+001 0.827 2.96E+000 3.14E+001 Kalskag Tuluksak 0.18 0.004 13.34 98.70 101.88 0.100 2.96E+001 1.81E+002 0.291 1.01E+002 9.55E+003 *Tuluksak Load Tuluksak 0.00 0.000 66.27 64.12 105.00 0.010 5.54E+002 1.71E+003 0.030 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: Coal Fired 4.7.0C Page:22 SN: ELECPOWERS Filename:Bethel-DonlanMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:08-13-2003 Revision:Base Config.: Normal Coal Fired Generation - All Units Online Fault at bus:Tuluksak Load Nominal kV =12.470 Prefault Voltage =100.00 % of nominal bus kV Base kV =13.094 =95.24 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Tuluksak Load Total 0.00 0.229 0.00 173.21 173.21 0.000 0.000 5.57E+002 1.74E+003 Tuluksak Tuluksak Load 93.64 0.229 95.24 95.24 95.24 0.000 0.000 5.57E+002 1.74E+003 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: CombineCycle 4.7.0C Page:1 SN: ELECPOWERS Filename:Bethel-DonlanMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:08-13-2003 Revision:Base Config.: Normal Combined Cycle Generation - All Units Online SHORT- CIRCUIT REPORT Fault at bus:Akiachak Nominal kV =138.000 Prefault Voltage =100.00 % of nominal bus kV Base kV =138.000 =100.00 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Akiachak Total 0.00 1.985 0.00 103.38 107.27 1.789 3.87E+000 2.78E+001 1.789 1.53E+000 2.10E+001 Dummy Akiachak 25.98 1.981 37.55 96.88 99.09 1.684 4.26E+000 3.36E+001 1.484 1.53E+000 2.11E+001 Akiak Akiachak 0.03 0.004 1.96 102.28 106.19 0.095 3.33E+001 1.78E+002 0.278 1.02E+002 9.56E+003 *Akiachak Load Akiachak 0.00 0.000 65.03 62.67 105.00 0.009 5.54E+002 1.71E+003 0.028 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: CombineCycle 4.7.0C Page:2 SN: ELECPOWERS Filename:Bethel-DonlanMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:08-13-2003 Revision:Base Config.: Normal Combined Cycle Generation - All Units Online Fault at bus:Akiachak Load Nominal kV =12.470 Prefault Voltage =100.00 % of nominal bus kV Base kV =13.094 =95.24 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Akiachak Load Total 0.00 0.231 0.00 173.21 173.21 0.000 0.000 5.56E+002 1.73E+003 Akiachak Akiachak Load 94.17 0.231 95.24 95.24 95.24 0.000 0.000 5.56E+002 1.73E+003 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: CombineCycle 4.7.0C Page:3 SN: ELECPOWERS Filename:Bethel-DonlanMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:08-13-2003 Revision:Base Config.: Normal Combined Cycle Generation - All Units Online Fault at bus:Akiak Nominal kV =138.000 Prefault Voltage =100.00 % of nominal bus kV Base kV =138.000 =100.00 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Akiak Total 0.00 1.768 0.00 104.88 108.69 1.549 4.88E+000 3.34E+001 1.549 1.91E+000 2.36E+001 Akiachak Akiak 10.98 1.764 15.14 102.00 105.30 1.445 5.65E+000 4.16E+001 1.245 1.92E+000 2.36E+001 Tuluksak Akiak 0.07 0.004 5.18 101.99 105.75 0.094 3.28E+001 1.87E+002 0.275 1.02E+002 9.56E+003 *Akiak Load Akiak 0.00 0.000 65.89 63.58 105.00 0.010 5.54E+002 1.71E+003 0.029 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: CombineCycle 4.7.0C Page:4 SN: ELECPOWERS Filename:Bethel-DonlanMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:08-13-2003 Revision:Base Config.: Normal Combined Cycle Generation - All Units Online Fault at bus:Akiak Load Nominal kV =12.470 Prefault Voltage =100.00 % of nominal bus kV Base kV =13.094 =95.24 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Akiak Load Total 0.00 0.230 0.00 173.21 173.21 0.000 0.000 5.56E+002 1.74E+003 Akiak Akiak Load 94.03 0.230 95.24 95.24 95.24 0.000 0.000 5.56E+002 1.74E+003 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: CombineCycle 4.7.0C Page:5 SN: ELECPOWERS Filename:Bethel-DonlanMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:08-13-2003 Revision:Base Config.: Normal Combined Cycle Generation - All Units Online Fault at bus:Aniak Nominal kV =138.000 Prefault Voltage =100.00 % of nominal bus kV Base kV =138.000 =100.00 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Aniak Total 0.00 0.732 0.00 99.73 101.88 0.720 9.37E+000 5.92E+001 0.720 6.84E+000 5.67E+001 Kalskag Aniak 17.42 0.728 19.42 98.62 100.70 0.576 2.34E+001 1.44E+002 0.296 6.92E+000 5.71E+001 Chuathbaluk Aniak 0.03 0.002 5.27 97.24 99.21 0.127 1.75E+001 1.13E+002 0.377 1.87E+002 1.82E+004 *Aniak Load Aniak 0.00 0.000 61.76 60.46 105.00 0.015 1.62E+002 9.36E+002 0.045 Aniak SVC Aniak 100.00 0.002 100.00 100.00 100.00 0.002 2.00E+002 2.00E+004 0.002 2.00E+002 2.00E+004 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: CombineCycle 4.7.0C Page:6 SN: ELECPOWERS Filename:Bethel-DonlanMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:08-13-2003 Revision:Base Config.: Normal Combined Cycle Generation - All Units Online Fault at bus:Aniak Load Nominal kV =12.470 Prefault Voltage =100.00 % of nominal bus kV Base kV =13.094 =95.24 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Aniak Load Total 0.00 0.417 0.00 173.21 173.21 0.000 0.000 1.69E+002 9.93E+002 Aniak Aniak Load 89.84 0.417 95.24 95.24 95.24 0.000 0.000 1.69E+002 9.93E+002 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: CombineCycle 4.7.0C Page:7 SN: ELECPOWERS Filename:Bethel-DonlanMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:08-13-2003 Revision:Base Config.: Normal Combined Cycle Generation - All Units Online Fault at bus:Bethel Nominal kV =13.800 Prefault Voltage =100.00 % of nominal bus kV Base kV =13.800 =100.00 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Bethel Total 0.00 65.835 0.00 100.01 100.01 65.821 1.32E-001 6.36E+000 65.821 1.32E-001 6.35E+000 Bethel SS1 Bethel 0.00 0.000 57.74 57.74 100.00 0.000 0.000 Bethel SS2 Bethel 0.00 0.000 57.74 57.74 100.00 0.000 0.000 Bethel 138 Bethel 0.08 0.015 57.76 100.00 57.77 0.010 0.000 3.10E+002 2.87E+004 Bethel 138 Bethel 0.08 0.015 57.76 100.00 57.77 0.010 0.000 3.10E+002 2.87E+004 Bethel 138 Bethel 0.08 0.015 57.76 100.00 57.77 0.010 0.000 3.10E+002 2.87E+004 Bethel Sub 2 Bethel 0.00 0.000 33.35 88.19 88.19 0.000# 0.000 Bethel Sub 1 Bethel 0.00 0.000 33.35 88.19 88.19 0.000# 0.000 Gen9 Coal3 100.00 10.893 100.00 100.00 100.00 10.893 8.00E-001 3.84E+001 10.898 8.00E-001 3.84E+001 Gen6 Combustion 3 100.00 18.300 100.00 100.00 100.00 18.300 4.76E-001 2.29E+001 18.308 4.76E-001 2.29E+001 Gen5 Combustion 2 100.00 18.300 100.00 100.00 100.00 18.300 4.76E-001 2.29E+001 18.308 4.76E-001 2.29E+001 Gen3 Combustion 1 100.00 18.300 100.00 100.00 100.00 18.300 4.76E-001 2.29E+001 18.308 4.76E-001 2.29E+001 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: CombineCycle 4.7.0C Page:8 SN: ELECPOWERS Filename:Bethel-DonlanMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:08-13-2003 Revision:Base Config.: Normal Combined Cycle Generation - All Units Online Fault at bus:Bethel 138 Nominal kV =138.000 Prefault Voltage =100.00 % of nominal bus kV Base kV =138.000 =100.00 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Bethel 138 Total 0.00 3.023 0.00 91.69 92.30 3.597 3.06E-001 7.21E+000 3.597 4.06E-001 1.38E+001 Dummy Bethel 138 0.02 0.004 0.86 91.38 92.05 0.049 3.61E+001 1.87E+002 0.136 1.03E+002 9.57E+003 *Bethel Bethel 138 54.12 1.006 74.63 74.16 100.00 1.183 8.24E-001 2.25E+001 1.154 1.22E+000 4.16E+001 *Bethel Bethel 138 54.12 1.006 74.63 74.16 100.00 1.183 8.24E-001 2.25E+001 1.154 1.22E+000 4.16E+001 *Bethel Bethel 138 54.12 1.006 74.63 74.16 100.00 1.183 8.24E-001 2.25E+001 1.154 1.22E+000 4.16E+001 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: CombineCycle 4.7.0C Page:9 SN: ELECPOWERS Filename:Bethel-DonlanMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:08-13-2003 Revision:Base Config.: Normal Combined Cycle Generation - All Units Online Fault at bus:Bethel SS1 Nominal kV =4.160 Prefault Voltage =100.00 % of nominal bus kV Base kV =4.160 =100.00 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Bethel SS1 Total 0.00 14.921 0.00 98.76 98.95 15.268 6.08E+000 8.65E+001 15.268 6.21E+000 9.28E+001 *Bethel Bethel SS1 93.18 14.921 96.43 100.00 96.63 15.268 6.08E+000 8.65E+001 15.268 6.21E+000 9.28E+001 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: CombineCycle 4.7.0C Page:10 SN: ELECPOWERS Filename:Bethel-DonlanMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:08-13-2003 Revision:Base Config.: Normal Combined Cycle Generation - All Units Online Fault at bus:Bethel SS2 Nominal kV =4.160 Prefault Voltage =100.00 % of nominal bus kV Base kV =4.160 =100.00 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Bethel SS2 Total 0.00 14.921 0.00 98.76 98.95 15.268 6.08E+000 8.65E+001 15.268 6.21E+000 9.28E+001 *Bethel Bethel SS2 93.18 14.921 96.43 100.00 96.63 15.268 6.08E+000 8.65E+001 15.268 6.21E+000 9.28E+001 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: CombineCycle 4.7.4C Page:1 SN: ELECPOWERS Filename:Bethel-DonlinMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:09-03-2003 Revision:Base Config.: Normal Combined Cycle Generation - All Units Online SHORT- CIRCUIT REPORT Fault at bus:Bethel Sub 1 Nominal kV =12.470 Prefault Voltage =100.00 % of nominal bus kV Base kV =12.470 =100.00 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Bethel Sub 1 Total 0.00 3.396 0.00 173.21 173.21 0.000 0.000 1.07E+001 1.36E+002 Bethel Bethel Sub 1 95.35 1.941 100.00 100.00 100.00 0.000# 0.000 1.93E+001 2.38E+002 Bethel Sub 2 Bethel Sub 1 71.49 1.455 100.00 100.00 100.00 0.000# 0.000 2.40E+001 3.17E+002 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: CombineCycle 4.7.4C Page:2 SN: ELECPOWERS Filename:Bethel-DonlinMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:09-03-2003 Revision:Base Config.: Normal Combined Cycle Generation - All Units Online Fault at bus:Bethel Sub 2 Nominal kV =4.160 Prefault Voltage =100.00 % of nominal bus kV Base kV =4.160 =100.00 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Bethel Sub 2 Total 0.00 19.434 0.00 173.21 173.21 0.000 0.000 4.33E+000 7.13E+001 Bethel Bethel Sub 2 91.11 16.655 100.00 100.00 100.00 0.000# 0.000 4.79E+000 8.32E+001 Bethel Sub 1 Bethel Sub 2 45.55 2.779 100.00 100.00 100.00 0.000# 0.000 4.00E+001 4.98E+002 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: CombineCycle 4.7.0C Page:11 SN: ELECPOWERS Filename:Bethel-DonlanMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:08-13-2003 Revision:Base Config.: Normal Combined Cycle Generation - All Units Online Fault at bus:Chuath. Load Nominal kV =12.470 Prefault Voltage =100.00 % of nominal bus kV Base kV =13.094 =95.24 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Chuath. Load Total 0.00 0.226 0.00 173.21 173.21 0.000 0.000 5.62E+002 1.77E+003 Chuathbaluk Chuath. Load 92.11 0.226 95.24 95.24 95.24 0.000 0.000 5.62E+002 1.77E+003 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: CombineCycle 4.7.0C Page:12 SN: ELECPOWERS Filename:Bethel-DonlanMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:08-13-2003 Revision:Base Config.: Normal Combined Cycle Generation - All Units Online Fault at bus:Chuathbaluk Nominal kV =138.000 Prefault Voltage =100.00 % of nominal bus kV Base kV =138.000 =100.00 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Chuathbaluk Total 0.00 0.672 0.00 97.85 99.76 0.688 8.98E+000 5.72E+001 0.688 7.59E+000 6.18E+001 Aniak Chuathbaluk 8.27 0.669 9.52 97.37 99.25 0.550 2.29E+001 1.41E+002 0.278 7.64E+000 6.20E+001 Crooked Creek Chuathbaluk 0.12 0.002 22.83 89.81 90.40 0.131 1.47E+001 1.02E+002 0.388 1.86E+002 1.82E+004 *Chuath. Load Chuathbaluk 0.00 0.000 60.48 59.32 105.00 0.007 5.54E+002 1.71E+003 0.022 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: CombineCycle 4.7.0C Page:13 SN: ELECPOWERS Filename:Bethel-DonlanMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:08-13-2003 Revision:Base Config.: Normal Combined Cycle Generation - All Units Online Fault at bus:Coal 1 Nominal kV =13.800 Prefault Voltage =100.00 % of nominal bus kV Base kV =13.800 =100.00 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Coal 1 Total 0.00 65.835 0.00 100.01 100.01 65.821 1.32E-001 6.36E+000 65.821 1.32E-001 6.35E+000 Bethel SS1 Bethel 0.00 0.000 57.74 57.74 100.00 0.000 0.000 Bethel SS2 Bethel 0.00 0.000 57.74 57.74 100.00 0.000 0.000 Bethel 138 Bethel 0.08 0.015 57.76 100.00 57.77 0.010 0.000 3.10E+002 2.87E+004 Bethel 138 Bethel 0.08 0.015 57.76 100.00 57.77 0.010 0.000 3.10E+002 2.87E+004 Bethel 138 Bethel 0.08 0.015 57.76 100.00 57.77 0.010 0.000 3.10E+002 2.87E+004 Bethel Sub 2 Bethel 0.00 0.000 33.35 88.19 88.19 0.000# 0.000 Bethel Sub 1 Bethel 0.00 0.000 33.35 88.19 88.19 0.000# 0.000 Gen9 Coal3 100.00 10.893 100.00 100.00 100.00 10.893 8.00E-001 3.84E+001 10.898 8.00E-001 3.84E+001 Gen6 Combustion 3 100.00 18.300 100.00 100.00 100.00 18.300 4.76E-001 2.29E+001 18.308 4.76E-001 2.29E+001 Gen5 Combustion 2 100.00 18.300 100.00 100.00 100.00 18.300 4.76E-001 2.29E+001 18.308 4.76E-001 2.29E+001 Gen3 Combustion 1 100.00 18.300 100.00 100.00 100.00 18.300 4.76E-001 2.29E+001 18.308 4.76E-001 2.29E+001 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: CombineCycle 4.7.0C Page:14 SN: ELECPOWERS Filename:Bethel-DonlanMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:08-13-2003 Revision:Base Config.: Normal Combined Cycle Generation - All Units Online Fault at bus:Combustion 1 Nominal kV =13.800 Prefault Voltage =100.00 % of nominal bus kV Base kV =13.800 =100.00 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Combustion 1 Total 0.00 65.835 0.00 100.01 100.01 65.821 1.32E-001 6.36E+000 65.821 1.32E-001 6.35E+000 Gen3 Combustion 1 100.00 18.300 100.00 100.00 100.00 18.300 4.76E-001 2.29E+001 18.308 4.76E-001 2.29E+001 Bethel SS1 Bethel 0.00 0.000 57.74 57.74 100.00 0.000 0.000 Bethel SS2 Bethel 0.00 0.000 57.74 57.74 100.00 0.000 0.000 Bethel 138 Bethel 0.08 0.015 57.76 100.00 57.77 0.010 0.000 3.10E+002 2.87E+004 Bethel 138 Bethel 0.08 0.015 57.76 100.00 57.77 0.010 0.000 3.10E+002 2.87E+004 Bethel 138 Bethel 0.08 0.015 57.76 100.00 57.77 0.010 0.000 3.10E+002 2.87E+004 Bethel Sub 2 Bethel 0.00 0.000 33.35 88.19 88.19 0.000# 0.000 Bethel Sub 1 Bethel 0.00 0.000 33.35 88.19 88.19 0.000# 0.000 Gen9 Coal3 100.00 10.893 100.00 100.00 100.00 10.893 8.00E-001 3.84E+001 10.898 8.00E-001 3.84E+001 Gen6 Combustion 3 100.00 18.300 100.00 100.00 100.00 18.300 4.76E-001 2.29E+001 18.308 4.76E-001 2.29E+001 Gen5 Combustion 2 100.00 18.300 100.00 100.00 100.00 18.300 4.76E-001 2.29E+001 18.308 4.76E-001 2.29E+001 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: CombineCycle 4.7.0C Page:15 SN: ELECPOWERS Filename:Bethel-DonlanMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:08-13-2003 Revision:Base Config.: Normal Combined Cycle Generation - All Units Online Fault at bus:Crooked Creek Nominal kV =138.000 Prefault Voltage =100.00 % of nominal bus kV Base kV =138.000 =100.00 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Crooked Creek Total 0.00 0.499 0.00 88.98 88.68 0.650 3.04E+000 2.53E+001 0.650 1.08E+001 8.32E+001 Chuathbaluk Crooked Creek 25.82 0.497 27.11 90.34 90.65 0.458 3.41E+001 2.03E+002 0.080 1.09E+001 8.35E+001 Donlan Crooked Creek 0.03 0.002 8.20 87.83 86.92 0.189 3.24E+000 2.93E+001 0.561 1.83E+002 1.82E+004 *Crooked Creek Load Crooked Creek 0.00 0.000 53.76 53.94 105.00 0.003 5.54E+002 1.71E+003 0.009 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: CombineCycle 4.7.0C Page:16 SN: ELECPOWERS Filename:Bethel-DonlanMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:08-13-2003 Revision:Base Config.: Normal Combined Cycle Generation - All Units Online Fault at bus:Crooked Creek Load Nominal kV =12.470 Prefault Voltage =100.00 % of nominal bus kV Base kV =13.094 =95.24 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Crooked Creek Load Total 0.00 0.223 0.00 173.21 173.21 0.000 0.000 5.65E+002 1.80E+003 Crooked Creek Crooked Creek Load 91.06 0.223 95.24 95.24 95.24 0.000 0.000 5.65E+002 1.80E+003 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: CombineCycle 4.7.0C Page:17 SN: ELECPOWERS Filename:Bethel-DonlanMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:08-13-2003 Revision:Base Config.: Normal Combined Cycle Generation - All Units Online Fault at bus:Donlan Nominal kV =138.000 Prefault Voltage =100.00 % of nominal bus kV Base kV =138.000 =100.00 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Donlan Total 0.00 0.469 0.00 87.69 86.33 0.664 4.70E-001 1.07E+001 0.664 1.15E+001 8.85E+001 Crooked Creek Donlan 6.03 0.467 6.20 87.83 86.71 0.452 3.62E+001 2.00E+002 0.035 1.17E+001 8.89E+001 *Donlan Mine Donlan 0.07 0.001 52.34 53.16 105.00 0.106 8.24E-001 2.25E+001 0.315 3.64E+002 3.63E+004 *Donlan Mine Donlan 0.07 0.001 52.34 53.16 105.00 0.106 8.24E-001 2.25E+001 0.315 3.64E+002 3.63E+004 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: CombineCycle 4.7.0C Page:18 SN: ELECPOWERS Filename:Bethel-DonlanMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:08-13-2003 Revision:Base Config.: Normal Combined Cycle Generation - All Units Online Fault at bus:Donlan Mine Nominal kV =13.800 Prefault Voltage =100.00 % of nominal bus kV Base kV =14.490 =95.24 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Donlan Mine Total 0.00 3.783 0.00 171.88 171.71 0.062 1.81E+002 1.81E+004 0.062 1.19E+001 9.96E+001 Donlan Donlan Mine 10.62 1.881 94.60 95.24 94.50 0.021 0.000 2.41E+001 2.00E+002 Donlan Donlan Mine 10.62 1.881 94.60 95.24 94.50 0.021 0.000 2.41E+001 2.00E+002 Donlan SVC Donlan Mine 100.00 0.021 100.00 100.00 100.00 0.021 1.81E+002 1.81E+004 0.062 1.81E+002 1.81E+004 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: CombineCycle 4.7.0C Page:19 SN: ELECPOWERS Filename:Bethel-DonlanMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:08-13-2003 Revision:Base Config.: Normal Combined Cycle Generation - All Units Online Fault at bus:Kalskag Nominal kV =138.000 Prefault Voltage =100.00 % of nominal bus kV Base kV =138.000 =100.00 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Kalskag Total 0.00 0.885 0.00 103.49 106.14 0.806 9.71E+000 6.06E+001 0.806 5.38E+000 4.69E+001 Tuluksak Kalskag 35.52 0.881 40.36 99.45 101.55 0.672 1.82E+001 1.18E+002 0.414 5.44E+000 4.72E+001 Aniak Kalskag 0.11 0.004 9.90 98.46 100.78 0.124 2.09E+001 1.34E+002 0.364 9.80E+001 9.53E+003 *Kalskag Load Kalskag 0.00 0.000 64.34 62.73 105.00 0.009 5.54E+002 1.71E+003 0.027 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: CombineCycle 4.7.0C Page:20 SN: ELECPOWERS Filename:Bethel-DonlanMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:08-13-2003 Revision:Base Config.: Normal Combined Cycle Generation - All Units Online Fault at bus:Kalskag Load Nominal kV =12.470 Prefault Voltage =100.00 % of nominal bus kV Base kV =13.094 =95.24 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Kalskag Load Total 0.00 0.227 0.00 173.21 173.21 0.000 0.000 5.60E+002 1.76E+003 Kalskag Kalskag Load 92.85 0.227 95.24 95.24 95.24 0.000 0.000 5.60E+002 1.76E+003 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: CombineCycle 4.7.0C Page:21 SN: ELECPOWERS Filename:Bethel-DonlanMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:08-13-2003 Revision:Base Config.: Normal Combined Cycle Generation - All Units Online Fault at bus:Tuluksak Nominal kV =138.000 Prefault Voltage =100.00 % of nominal bus kV Base kV =138.000 =100.00 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Tuluksak Total 0.00 1.370 0.00 106.48 109.89 1.167 7.12E+000 4.59E+001 1.167 2.92E+000 3.04E+001 Akiak Tuluksak 22.62 1.366 28.56 101.52 104.26 1.056 9.31E+000 6.38E+001 0.841 2.94E+000 3.05E+001 Kalskag Tuluksak 0.18 0.004 13.56 99.19 102.26 0.101 2.96E+001 1.81E+002 0.296 1.01E+002 9.55E+003 *Tuluksak Load Tuluksak 0.00 0.000 66.61 64.55 105.00 0.010 5.54E+002 1.71E+003 0.030 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer Location:Bethel - Donlin Mine Engineer:Electric Power Systems, Inc.Study Case: CombineCycle 4.7.0C Page:22 SN: ELECPOWERS Filename:Bethel-DonlanMine Project:Nuvista Light & Power Co. ETAP PowerStation Contract:03-0094 Date:08-13-2003 Revision:Base Config.: Normal Combined Cycle Generation - All Units Online Fault at bus:Tuluksak Load Nominal kV =12.470 Prefault Voltage =100.00 % of nominal bus kV Base kV =13.094 =95.24 % of base kV ID Symm. rmsFrom BusID Va From Bus To Bus % V kA % Voltage at From Bus Contribution 3-Phase Fault Looking into "From Bus" Vb Vc Ia 3I0 R1 X1 R0 X0 kA Symm. rms % Impedance on 100 MVA base Line-To-Ground Fault Positive & Zero Sequence Impedances Tuluksak Load Total 0.00 0.229 0.00 173.21 173.21 0.000 0.000 5.57E+002 1.74E+003 Tuluksak Tuluksak Load 93.69 0.229 95.24 95.24 95.24 0.000 0.000 5.57E+002 1.74E+003 # Indicates fault current contribution is from three-winding transformers * Indicates a zero sequence fault current contribution (3I0) from a grounded Delta-Y transformer APPENDIX 4 DONLIN CREEK MINE PROJECT SYSTEM STUDIES Appendix 4 Transient Stability Dynamics Data Transient Stability Simulation Plots PSS/E Transient Stability Data Electric Power Systems, Inc. 8/13/2003 PTI INTERACTIVE POWER SYSTEM SIMULATOR--PSS/E WED, AUG 13 2003 11:59 DONLIN MINE STUDIES BY EPS, JULY 2003 MINE LOAD 85 MW WITH SVC PLANT MODELS REPORT FOR ALL MODELS AT ALL BUSES BUS 10 [BETHEL 13.800] MODELS ** GENROE ** BUS X-- NAME --X BASEKV MC C O N S S T A T E S 10 BETHEL 13.800 1 1-14 1-6 MBASE Z S O R C E X T R A N GENTAP 56.2 0.00000+J 0.21000 0.00000+J 0.00000 1.00000 T'D0 T''D0 T'Q0 T''Q0 H DAMP XD XQ X'D X'Q X''D XL 5.70 0.045 2.50 0.150 4.38 0.00 1.9500 1.8500 0.2600 0.4600 0.2100 0.1500 S(1.0) S(1.2) 0.2375 0.8485 ** EXPIC1 ** BUS X-- NAME --X BASEKV MC C O N S S T A T E S 10 BETHEL 13.800 1 99-122 43-49 TR KA TA1 VR1 VR2 TA2 TA3 TA4 0.020 2.6 5.000 1.100 -0.585 0.000 0.000 0.000 VRMAX VRMIN KF TF1 TF2 EFDMAX EFDMIN 1.100 -1.100 0.000 1.000 0.000 4.287 -4.683 KE TE E1 SE(E1) E2 SE(E2) KP KI KC 0.000 0.000 0.000 0.000 0.000 0.000 4.280 1.100 0.000 ** IEEEG1 ** BUS X-- NAME --X BASEKV MC C O N S S T A T E S V A R S 10 BETHEL 13.800 1 212-231 77-82 6-7 K T1 T2 T3 UO UC PMAX PMIN T4 K1 50.00 0.000 0.000 0.150 0.200 -0.200 0.8600 0.0000 0.350 1.000 K2 T5 K3 K4 T6 K5 K6 T7 K7 K8 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 PSS/E Transient Stability Data Electric Power Systems, Inc. 8/13/2003 ** GENROE ** BUS X-- NAME --X BASEKV MC C O N S S T A T E S 10 BETHEL 13.800 2 15-28 7-12 MBASE Z S O R C E X T R A N GENTAP 56.2 0.00000+J 0.21000 0.00000+J 0.00000 1.00000 T'D0 T''D0 T'Q0 T''Q0 H DAMP XD XQ X'D X'Q X''D XL 5.70 0.045 2.50 0.150 4.38 0.00 1.9500 1.8500 0.2600 0.4600 0.2100 0.1500 S(1.0) S(1.2) 0.2375 0.8485 ** EXPIC1 ** BUS X-- NAME --X BASEKV MC C O N S S T A T E S 10 BETHEL 13.800 2 123-146 50-56 TR KA TA1 VR1 VR2 TA2 TA3 TA4 0.020 2.6 5.000 1.100 -0.585 0.000 0.000 0.000 VRMAX VRMIN KF TF1 TF2 EFDMAX EFDMIN 1.100 -1.100 0.000 1.000 0.000 4.287 -4.683 KE TE E1 SE(E1) E2 SE(E2) KP KI KC 0.000 0.000 0.000 0.000 0.000 0.000 4.280 1.100 0.000 ** IEEEG1 ** BUS X-- NAME --X BASEKV MC C O N S S T A T E S V A R S 10 BETHEL 13.800 2 232-251 83-88 8-9 K T1 T2 T3 UO UC PMAX PMIN T4 K1 50.00 0.000 0.000 0.150 0.200 -0.200 0.8600 0.0000 0.350 1.000 K2 T5 K3 K4 T6 K5 K6 T7 K7 K8 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 PSS/E Transient Stability Data Electric Power Systems, Inc. 8/13/2003 ** GENROU ** BUS X-- NAME --X BASEKV MC C O N S S T A T E S 10 BETHEL 13.800 3 29-42 13-18 MBASE Z S O R C E X T R A N GENTAP 52.5 0.00000+J 0.16600 0.00000+J 0.00000 1.00000 T'D0 T''D0 T'Q0 T''Q0 H DAMP XD XQ X'D X'Q X''D XL 10.90 0.023 0.31 0.025 8.20 0.00 2.2000 1.7200 0.2520 0.5000 0.1660 0.1380 S(1.0) S(1.2) 0.1100 0.4100 ** EXST2A ** BUS X-- NAME --X BASEKV MC C O N S S T A T E S VAR 10 BETHEL 13.800 3 147-159 57-60 1 TR KA TA VRMAX VRMIN KE TE 0.000 70.0 0.150 1.000 -0.500 1.000 0.650 KF TF KP KI KC EFDMAX KI VAR 0.018 1.000 2.100 2.100 0.017 3.000 0.000 ** GTAKGE ** BUS NAME BSKV MACH C O N ' S STATE'S V A R ' S 10 BETHEL 13.8 3 252- 295 89- 112 10- 24 W X Y Z ETD TCD TRATE T MAX MIN ECR K3 50.00 0.000 0.050 1.00 0.040 0.200 42.00 0.00 1.0750 -0.26 0.010 0.680 A B C TF KF K5 K4 T3 T4 TT T5 1.00 0.05 1.00 0.20 0.000 0.200 0.800 15.00 3.000 450.0 3.30 AF1 BF1 AF2 BF2 CF2 TR K6 TC EMPTY CF1 TAIR 479.4 550.0 -0.470 1.470 0.500 914.0 0.320 940.0 0.0 0.0000 59.0 EXTRA CONS: 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 PMAX AT THIS AIR TEMP. (TAIR) = 45.15 MW ABSOLUTE PMAX = 45.15 MW PSS/E Transient Stability Data Electric Power Systems, Inc. 8/13/2003 ** GENROU ** BUS X-- NAME --X BASEKV MC C O N S S T A T E S 10 BETHEL 13.800 4 43-56 19-24 MBASE Z S O R C E X T R A N GENTAP 52.5 0.00000+J 0.17100 0.00000+J 0.00000 1.00000 T'D0 T''D0 T'Q0 T''Q0 H DAMP XD XQ X'D X'Q X''D XL 10.90 0.023 0.22 0.049 8.20 0.00 2.1800 2.0780 0.2100 0.5400 0.1710 0.1410 S(1.0) S(1.2) 0.1200 0.4800 ** EXST2A ** BUS X-- NAME --X BASEKV MC C O N S S T A T E S VAR 10 BETHEL 13.800 4 160-172 61-64 2 TR KA TA VRMAX VRMIN KE TE 0.000 30.0 0.100 1.000 0.000 1.000 0.350 KF TF KP KI KC EFDMAX KI VAR 0.026 1.000 1.900 1.900 0.017 3.000 0.000 ** GTAKGE ** BUS NAME BSKV MACH C O N ' S STATE'S V A R ' S 10 BETHEL 13.8 4 296- 339 113- 136 25- 39 W X Y Z ETD TCD TRATE T MAX MIN ECR K3 50.00 1.059 3.050 1.00 0.040 0.200 42.00 0.00 1.0750 -0.17 0.010 0.725 A B C TF KF K5 K4 T3 T4 TT T5 1.00 0.05 1.00 0.20 0.000 0.200 0.800 15.00 3.000 450.0 3.30 AF1 BF1 AF2 BF2 CF2 TR K6 TC EMPTY CF1 TAIR 620.4 550.0 -0.359 1.380 0.500 948.0 0.275 980.0 0.0 0.0000 59.0 EXTRA CONS: 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 PMAX AT THIS AIR TEMP. (TAIR) = 45.15 MW ABSOLUTE PMAX = 45.15 MW PSS/E Transient Stability Data Electric Power Systems, Inc. 8/13/2003 ** GENROU ** BUS X-- NAME --X BASEKV MC C O N S S T A T E S 10 BETHEL 13.800 5 57-70 25-30 MBASE Z S O R C E X T R A N GENTAP 52.5 0.00000+J 0.17100 0.00000+J 0.00000 1.00000 T'D0 T''D0 T'Q0 T''Q0 H DAMP XD XQ X'D X'Q X''D XL 10.90 0.023 0.22 0.049 8.20 0.00 2.1800 2.0780 0.2100 0.5400 0.1710 0.1410 S(1.0) S(1.2) 0.1200 0.4800 ** EXST2A ** BUS X-- NAME --X BASEKV MC C O N S S T A T E S VAR 10 BETHEL 13.800 5 173-185 65-68 3 TR KA TA VRMAX VRMIN KE TE 0.000 30.0 0.100 1.000 0.000 1.000 0.350 KF TF KP KI KC EFDMAX KI VAR 0.026 1.000 1.900 1.900 0.017 3.000 0.000 ** GTAKGE ** BUS NAME BSKV MACH C O N ' S STATE'S V A R ' S 10 BETHEL 13.8 5 340- 383 137- 160 40- 54 W X Y Z ETD TCD TRATE T MAX MIN ECR K3 50.00 1.059 3.050 1.00 0.040 0.200 42.00 0.00 1.0750 -0.17 0.010 0.725 A B C TF KF K5 K4 T3 T4 TT T5 1.00 0.05 1.00 0.20 0.000 0.200 0.800 15.00 3.000 450.0 3.30 AF1 BF1 AF2 BF2 CF2 TR K6 TC EMPTY CF1 TAIR 620.4 550.0 -0.359 1.380 0.500 948.0 0.275 980.0 0.0 0.0000 59.0 EXTRA CONS: 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 PMAX AT THIS AIR TEMP. (TAIR) = 45.15 MW ABSOLUTE PMAX = 45.15 MW PSS/E Transient Stability Data Electric Power Systems, Inc. 8/13/2003 ** GENROU ** BUS X-- NAME --X BASEKV MC C O N S S T A T E S 10 BETHEL 13.800 6 71-84 31-36 MBASE Z S O R C E X T R A N GENTAP 52.5 0.00000+J 0.17100 0.00000+J 0.00000 1.00000 T'D0 T''D0 T'Q0 T''Q0 H DAMP XD XQ X'D X'Q X''D XL 10.90 0.023 0.22 0.049 8.20 0.00 2.1800 2.0780 0.2100 0.5400 0.1710 0.1410 S(1.0) S(1.2) 0.1200 0.4800 ** EXST2A ** BUS X-- NAME --X BASEKV MC C O N S S T A T E S VAR 10 BETHEL 13.800 6 186-198 69-72 4 TR KA TA VRMAX VRMIN KE TE 0.000 30.0 0.100 1.000 0.000 1.000 0.350 KF TF KP KI KC EFDMAX KI VAR 0.026 1.000 1.900 1.900 0.017 3.000 0.000 ** GTAKGE ** BUS NAME BSKV MACH C O N ' S STATE'S V A R ' S 10 BETHEL 13.8 6 384- 427 161- 184 55- 69 W X Y Z ETD TCD TRATE T MAX MIN ECR K3 50.00 1.059 3.050 1.00 0.040 0.200 42.00 0.00 1.0750 -0.17 0.010 0.725 A B C TF KF K5 K4 T3 T4 TT T5 1.00 0.05 1.00 0.20 0.000 0.200 0.800 15.00 3.000 450.0 3.30 AF1 BF1 AF2 BF2 CF2 TR K6 TC EMPTY CF1 TAIR 620.4 550.0 -0.359 1.380 0.500 948.0 0.275 980.0 0.0 0.0000 59.0 EXTRA CONS: 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 PMAX AT THIS AIR TEMP. (TAIR) = 45.15 MW ABSOLUTE PMAX = 45.15 MW PSS/E Transient Stability Data Electric Power Systems, Inc. 8/13/2003 ** GENROU ** BUS X-- NAME --X BASEKV MC C O N S S T A T E S 10 BETHEL 13.800 7 85-98 37-42 MBASE Z S O R C E X T R A N GENTAP 31.2 0.00000+J 0.16600 0.00000+J 0.00000 1.00000 T'D0 T''D0 T'Q0 T''Q0 H DAMP XD XQ X'D X'Q X''D XL 10.90 0.023 0.31 0.025 8.20 0.00 2.2000 1.7200 0.2520 0.5000 0.1660 0.1380 S(1.0) S(1.2) 0.1100 0.4100 ** EXST2A ** BUS X-- NAME --X BASEKV MC C O N S S T A T E S VAR 10 BETHEL 13.800 7 199-211 73-76 5 TR KA TA VRMAX VRMIN KE TE 0.000 70.0 0.150 1.000 -0.500 1.000 0.650 KF TF KP KI KC EFDMAX KI VAR 0.018 1.000 2.100 2.100 0.017 3.000 0.000 ** GTAKGE ** BUS NAME BSKV MACH C O N ' S STATE'S V A R ' S 10 BETHEL 13.8 7 428- 471 185- 208 70- 84 W X Y Z ETD TCD TRATE T MAX MIN ECR K3 50.00 0.000 0.050 1.00 0.040 0.200 25.00 0.00 1.0750 -0.26 0.010 0.680 A B C TF KF K5 K4 T3 T4 TT T5 1.00 0.05 1.00 0.20 0.000 0.200 0.800 15.00 3.000 450.0 3.30 AF1 BF1 AF2 BF2 CF2 TR K6 TC EMPTY CF1 TAIR 479.4 550.0 -0.470 1.470 0.500 914.0 0.320 940.0 0.0 0.0000 59.0 EXTRA CONS: 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 PMAX AT THIS AIR TEMP. (TAIR) = 26.88 MW ABSOLUTE PMAX = 26.88 MW PSS/E Transient Stability Data Electric Power Systems, Inc. 8/13/2003 PTI INTERACTIVE POWER SYSTEM SIMULATOR--PSS/E WED, AUG 13 2003 11:59 DONLIN MINE STUDIES BY EPS, JULY 2003 MINE LOAD 85 MW WITH SVC LOAD MODELS REPORT FOR ALL MODELS AT ALL BUSES BUS 40 [DONLIN 13.800] MODELS ** LDSHBL ** BUS X-- NAME --X BASEKV LD C O N S V A R S PRIVATE ICONS 40 DONLIN 13.800 1 509-518 109-111 15-23 HZ-1 T1 FRAC-1 HZ-2 T2 FRAC-2 59.000 0.100 0.250 58.700 0.100 0.250 HZ-3 T3 FRAC-3 TB 58.400 0.100 0.250 0.083 PSS/E Transient Stability Data Electric Power Systems, Inc. 8/13/2003 PTI INTERACTIVE POWER SYSTEM SIMULATOR--PSS/E WED, AUG 13 2003 11:59 DONLIN MINE STUDIES BY EPS, JULY 2003 MINE LOAD 85 MW WITH SVC CONEC MODELS REPORT FOR ALL MODELS AT ALL BUSES CONEC MODELS *** CALL CSSCS1( 1, 472, 209, 85) *** ** CSSCS1 ** BUS X-- NAME --X BASEKV I C O N S C O N S S T A T E S V A R S 40 DONLIN 13.800 1-2 472-480 209-211 85-88 REMOTE BUS K T1 T2 T3 T4 T5 VMAX VMIN VOV 0 1000.0 0.015 0.000 0.025 0.075 0.025 0.0 0.0 99.000 *** CALL CSSCS1( 3, 481, 212, 89) *** ** CSSCS1 ** BUS X-- NAME --X BASEKV I C O N S C O N S S T A T E S V A R S 150 ANIAK 138.00 3-4 481-489 212-214 89-92 REMOTE BUS K T1 T2 T3 T4 T5 VMAX VMIN VOV 0 1000.0 0.015 0.000 0.025 0.075 0.025 0.0 0.0 99.000 PTI INTERACTIVE POWER SYSTEM SIMULATOR--PSS/E WED, AUG 13 2003 11:59 DONLIN MINE STUDIES BY EPS, JULY 2003 MINE LOAD 85 MW WITH SVC CONET MODELS REPORT FOR ALL MODELS AT ALL BUSES CONET MODELS *** CALL TSSCS1( 1, 472, 209, 85) *** ** TSSCS1 ** BUS X-- NAME --X BASEKV I C O N S C O N S S T A T E S V A R S 40 DONLIN 13.800 1-2 472-480 209-211 85-88 *** CALL TSSCS1( 3, 481, 212, 89) *** ** TSSCS1 ** BUS X-- NAME --X BASEKV I C O N S C O N S S T A T E S V A R S 150 ANIAK 138.00 3-4 481-489 212-214 89-92 Appendix E – Site Development, EarthWorks, Foundations, Bulk Fuel and Coal Storage 1. Coal-Fired Plant at Bethel 2. Combustion Turbine Plant at Bethel 1. Coal-Fired Plant at Bethel Nuvista Light & Power Co. COAL FIRED POWER PLANT BETHEL, ALASKA SITE DEVELOPMENT, EARTHWORKS, FOUNDATIONS, BULK FUEL AND COAL STORAGE CONCEPTUAL DESIGN REPORT SEPTEMBER 2, 2003 Prepared by: Mike Hendee, P.E. Voice: (907) 273-1830 Fax: (907) 273-1831 139 East 51st Avenue Anchorage, Alaska 99503 Bethel, Alaska Coal Fired Power Plant Conceptual Design Report EXECUTIVE SUMMARY This report has been prepared for Nuvista Light & Power, Co. under contract with Bettine, LLC. Its purpose is to provide a conceptual level design and budget cost estimate for site development, access roads, foundations, coal storage area, bulk fuel systems and off-loading dock for a new coal fired power generation plant located in Bethel, Alaska. The proposed power plant will consist of two 48-megawatt coal fired steam turbines and one 46- megawatt diesel fired combustion turbine. The coal storage area will be approximately 16 acres in size, and will store approximately 400,000 tons of coal. A 3,000,000 gallon bulk fuel tank farm, two 12,000 gallon intermediate/day fuel tanks, a 700,000 gallon raw water tank and an 80,000 gallon demineralized water tank also comprise the facility. The report includes basic feasibility level conceptual design drawings for the site development, access roads, coal and fuel storage, piping, and an off-loading dock for coal and fuel barges. Also included are permitting requirements for the scope of work identified above, flood hazard information, and budget cost estimates. The proposed site location for the power plant facility was provided by Bettine, LLC and is located approximately 6000 feet south of the City of Bethel Petroleum Port and 1650 feet west of the Kuskokwim River. For this report, we have assumed the site is underlain by ice-rich warm permafrost. No geotechnical nor survey information is available for the proposed site. The power plant layout is preliminary, and consists of a 100,000 square foot building housing the boilers and turbines, a maintenance building, an administration building, staff housing and cooling towers. The layout is based on information provided by Precision Energy Services, Inc. The power plant and maintenance buildings will be supported at grade with passive refrigeration designed to prevent degradation of the permafrost. An option to house the power plant on two barges, moored within an artificial harbor is included in this report. The administration building, staff housing and cooling towers shall be supported by thermo helix-piles with passive refrigeration designed to provide foundation support in permafrost. A 78-acre cooling lake south of the site may be substituted for the cooling towers, and we have included that option in this report. The coal storage area will be located east of the power plant facility, and will consist of a stockpile that encompasses approximately 16 acres. The stockpile will be covered with either an air-supported structure or a metal building, to contain fugitive dust and provide rain and snow protection. Either structure will be founded on driven steel piling. The stockpile may or may not be underlain with a containment liner, depending on permit requirements. If a liner is mandatory, the integrity of the permafrost shall be retained with a passive refrigeration system, or the site will be stabilized by pre-thawing the permafrost, depending on the thaw stability of the underlying soils. If a liner is not mandatory, the site will be leveled with a layer of compacted sand and allowed to thaw and settle. EX-1 Bethel, Alaska Coal Fired Power Plant Conceptual Design Report The 3,000,000 gallon bulk fuel tank farm will be located near the power plant modules and will consist of four tanks, each measuring 60 feet in diameter and 40 feet high, with a nominal storage capacity of 800,000 gallons each. The tanks will be filled with No. 1 diesel fuel. The bulk fuel tanks shall be founded on concrete ringwalls that bear on an insulated fill pad with a passive refrigeration thermo syphon system installed to preserve the permafrost. The thermo syphons will have hybrid condenser units that allow for connection to an active refrigeration system should the need arise in the future. Two 12,000 gallon double-walled intermediate/day fuel tanks, a 700,000 gallon raw water tank, and an 80,000 gallon demineralized water tank will be located inside the heated power plant or within a separate heated building if the power plant is barge mounted. A coal and fuel barge off-loading dock with a marine header will be located on the west bank of the Kuskokwim River. The dock design was developed by Peratrovich, Nottingham and Drage, Inc. for the Donlin Creek Mine Late Stage Evaluation Study1. The coal will be offloaded with a barge unloading system moored to the dock during the summer, and moved to a protected anchorage in the river during the winter. The coal will be transported to the storage facility by a pile supported conveyor system. The marine header will connect to a 4-inch diameter pipeline to fill the tanks at the bulk fuel facility. The barge season in Bethel runs from June through September. Budget Construction Cost Estimates for the proposed site development, building foundations, coal storage area, 3,000,000 gallon bulk fuel facility, intermediate/day fuel tanks, water tanks, access roads, pipelines and coal and fuel barge off-loading dock are as follows: y Power Plant & Buildings, Founded on Permafrost $21,000,000 y Barge Mounted Power Plant Option $13,800,000 y 3,000,000 Gallon Bulk Fuel Facility $4,125,000 y Lined Coal Storage w/ Maintaining Permafrost Integrity $19,200,000 y Lined Coal Storage w/ Pre-thaw of Permafrost $15,800,000 y Unlined Coal Storage w/ Allowing Natural Thaw of Permafrost $7,300,000 y Cooling Lake Option $5,450,000 These estimates are based on competitively bid construction costs with a 15% contingency. Additional costs for design, permitting and construction management of the site development are estimated at $1,350,000. An additional cost of $250,000 will be required for the cooling lake option. Design and construction of the power plant equipment, buildings, conveyor, stacker/reclaimer and barge unloading systems, as well as, land purchase, lease and right-of-way costs are not included in these figures. EX-2 Bethel, Alaska Coal Fired Power Plant Conceptual Design Report TABLE OF CONTENTS EXECUTIVE SUMMARY ....................................................................................................EX-1 I. INTRODUCTION..............................................................................................................1 II. APPLICABLE CODES AND REGULATIONS .............................................................1 III. SITE LOCATION ..............................................................................................................1 IV. COMMUNITY FLOOD DATA........................................................................................2 V. FILL MATERIAL, GRAVEL & ARMOR ROCK ........................................................2 VI. POWER PLANT & ASSOCIATED BUILDINGS .........................................................2 VII. BARGE MOUNTED POWER PLANT OPTION ..........................................................3 VIII. COAL STORAGE FACILITY .........................................................................................4 IX. COOLING LAKE OPTION .............................................................................................5 X. 3,000,000 GALLON BULK FUEL FACILITY...............................................................5 XI. INTERMEDIATE/DAY FUEL TANKS & WATER STORAGE TANKS ..................5 XII. ACCESS ROADS ...............................................................................................................6 XIII. COAL AND FUEL OFF-LOADING DOCK ..................................................................6 XIV. PERMITTING ...................................................................................................................6 XV. BUDGET COST ESTIMATES ........................................................................................9 XVI. REFERENCES.................................................................................................................10 APPENDICES: Appendix A: Site Locations Appendix B: Flood Hazard Data Appendix C: Conceptual Design Drawings Appendix D: Construction Budget Cost Estimates i Bethel, Alaska Coal Fired Power Plant Conceptual Design Report I. INTRODUCTION This report has been prepared for Nuvista Light & Power, Co. under contract with Bettine, LLC, to provide a conceptual level design and budgetary cost estimate for the site development, access roads, foundations, coal storage area, bulk fuel systems and offloading dock for a new coal fired power generation plant located in Bethel, Alaska. The proposed power plant will consist of two 48-megawatt coal fired steam turbines and one 46-megawatt diesel fired combustion turbine. A 16-acre coal storage area, a 3,000,000 gallon bulk fuel tank farm, two 12,000 gallon double- walled intermediate/day fuel tanks, and a 700,000 gallon raw water tank and an 80,000 gallon demineralized water tank also comprise the facility. Included with the report are basic feasibility level conceptual design drawings for the site development, access roads, coal and fuel storage, piping, and a coal and fuel barge offloading dock. Also included are permitting requirements for the scope of work identified above, flood hazard information and budget cost estimates. No site visit, fieldwork, or geotechnical investigation has been performed for this project. In addition, no geotechnical or survey information is available for the proposed location. A review of overhead aerial photographs was conducted, and engineering analyses have been made under the assumption the site is underlain by ice-rich warm permafrost. Site locations and coal and fuel quantities were provided by Bettine, LLC. The site layout, water tank sizes, and power generation equipment weight loads were provided by Precision Energy Services, Inc. (PES). Climate data was obtained from the Alaska Engineering Design Information System (AEDIS). II. APPLICABLE CODES AND REGULATIONS The design of a new power plant facility, roads, dock, foundations and fuel systems are controlled by the following State of Alaska and Federal codes and regulations: y 2000 International Fire Code as adopted by 13 AAC 50 y 2000 International Building Code as adopted by 13 AAC 50 y State of Alaska Fire and Life Safety Regulations (13 AAC 50) y ADEC Hazardous Substance Regulations (18 AAC 75) y ADEC Air Quality Regulations (18 AAC 52) y Regulatory Commission of Alaska (RCA) Certification (3 AAC 42.05.221) y EPA Oil Pollution Prevention Regulations (40 CFR Part 112) y EPA Storm Water Discharge Regulations (40 CFR Part 122) y U.S. Army Corps of Engineers Wetlands and Navigable Waters Regulations (33 CFR Part 328 and 329) III. SITE LOCATION The proposed site location for the power plant facility was provided by Bettine, LLC. The site will be approximately 6000 feet south of the City of Bethel Petroleum Port, and approximately 1650 feet west of the nearest point to the Kuskokwim River. An access road will connect to a private spur road south of Standard Oil Road. An access road, a coal conveyor transport system, and a 4-inch diameter pipeline will connect to the proposed coal off-loading dock and marine 1 Bethel, Alaska Coal Fired Power Plant Conceptual Design Report header approximately 3500 feet south of the City Petroleum Port. The proposed power generation site, access roads, dock, coal storage area and bulk fuel tank farm locations are shown in Appendix A. IV. COMMUNITY FLOOD DATA The U.S. Army Corps of Engineers – Flood Plain Management Services ALASKAN COMMUNITIES FLOOD HAZARD DATA 2000 publication indicates that the community of Bethel is participating in NFIP status, and there is a Flood Insurance Study (FIS) available. The published Flood Insurance Rate Maps (FIRM) show detailed flood information, and can be purchased from the Federal Emergency Management Agency (FEMA). The last flood event was in 1991, and the worst flood event was in 1988. A revised Flood Insurance Study (FIS) was published by FEMA in 1984. The FIS is included in Appendix B. The publication lists the 100-year flood elevation at 17.1 feet. The proposed land based power plant site elevation is around 50 feet, as interpolated from USGS Bethel (D-8), Alaska Quadrangle, 1954 (Limited Revision 1985). The proposed barge mounted power plant will be about the same elevation as the river. The actual site elevations will need to be determined by a design survey. The access roads and dock may be subject to flooding and riverbank erosion. V. FILL MATERIAL, GRAVEL & ARMOR ROCK Local fill material consists of a fine-grained silty dune sand that is mined from pits in Bethel. Material with less than 20% passing the number 200 sieve size, and a Corps of Engineers frost classification of F3 can be obtained through selective mining. The present borrow sites are near the airport, with a haul distance to the proposed site of 3 to 5 miles one way. The large quantity of fill material needed for this project may justify developing a borrow source near the site. An intensive geotechnical materials investigation will be required to identify a suitable source, and additional permitting will be needed to develop the material site. Gravel is imported to Bethel by barge. Presently, barges routinely deliver 4500 tons (approximately 2500 cubic yards) of gravel per shipment. Most of the gravel delivered is mined in Aniak, Kalskag, or Platinum. Armor rock is also imported by barge. The closest quarries are in Kalskag and Platinum. VI. POWER PLANT & ASSOCIATED BUILDINGS Since the proposed site is assumed to have thaw unstable, ice-rich soils, the buildings must be supported on foundations that maintain the thermal stability of the existing ground to prevent thaw settlement. The steam turbines and boilers have high foundation loads; therefore, the power plant building should be supported at grade on a concrete slab with grade beams connected to concrete footings. The concrete slab and footings shall bear on a compacted fill pad of the local sand. The maintenance shop will have high floor loads and should also be 2 Bethel, Alaska Coal Fired Power Plant Conceptual Design Report founded in the same manner. To maintain the frozen ground conditions and prevent thaw settlement under the heated buildings, a layer of rigid board insulation and a passive refrigeration, thermo syphon flat loop system shall be installed under the buildings to preserve the integrity of the permafrost. The system uses the phase change properties of CO2 to remove heat from the sand fill whenever the air temperature is below freezing. The thermo syphons will be fabricated with hybrid condenser units that allow for connection to an active refrigeration system should the need arise in the future. Conceptual design drawings of the power plant and maintenance shop layouts and foundations are shown in Appendix C. The administration building, staff housing, and cooling towers shall be supported by thermo helix-piles with passive refrigeration designed to provide foundation support in permafrost. The piles will also be fabricated with hybrid condenser units that allow for connection to an active refrigeration system. Conceptual design drawings of the pile supported structures are shown in Appendix C. A fill pad of the local sand will be placed under and around the buildings, and capped with an 8- inch thick sand and gravel surface. The sand fill shall be 6.5 feet thick under the power plant and maintenance buildings, and shall be 4.5 feet thick under the pile-supported buildings, except where grade changes are not desirable. The fill shall extend around the perimeter of the buildings to provide access for vehicles and equipment. The fill pad will be sloped to provide positive drainage away from the buildings. VII. BARGE MOUNTED POWER PLANT OPTION The power generation equipment could be mounted on two barges that will be moored in an artificial harbor constructed next to the Kuskokwim River. The harbor will be created by removing the underlying soils in a low area that is south of a bluff near the proposed site, and by building an earthen dike from the excavated soils to separate the harbor from the river. The harbor could be allowed to freeze each winter, or, the water could be used for supplemental cooling and discharged back into the harbor to keep it ice free. A site plan for the barge mounted power plant option is shown in Appendix A. Conceptual design drawings are shown in Appendix C. Excess soils that are excavated from the harbor and not used for the embankment construction, could be used for fill pad and road construction if they are suitable. If they are not suitable for construction, a disposal site will need to be developed. To prevent erosion of the earthen dike, the toe of the dike should be keyed into the supporting soils and toe drains should be constructed. The entire dike should be covered with a gravel surface and the riverfront should be lined with armor rock. Both the gravel and the armor rock will need to be imported to Bethel. Ice forces on the riverside of the embankment will be extensive. Articulating concrete mats may be needed in addition to armor rock at areas that receive high ice forces, such as the abutment where the dike meets the bluff, the embankment corner and within the tidal zone of the river. 3 Bethel, Alaska Coal Fired Power Plant Conceptual Design Report The barges could be moored to a center pier that is supported on driven piles. Additional moorage could be obtained by installing dolphins at the corners of the barges. If the harbor area is underlain by permafrost, as assumed, the piles will have to be driven deep enough to resist the drawdown forces as the permafrost thaws, as well as the lateral wind loads on the barges. The moorage will also need to adjust for tidal influences if the harbor and river are hydraulically connected. Separating the harbor from the river, in essence, incorporates the construction of a dam, and therefore, may need review and approval from the State of Alaska Dam Safety Office if it meets the criteria for State of Alaska jurisdiction. If surface drainage into the harbor is extensive, a hydraulic connection between the river and harbor may need to be constructed. Large culverts or a controlled spillway are two methods that could be utilized. An extensive geotechnical investigation and a hydrographic survey will be necessary to determine the design. VIII. COAL STORAGE FACILITY The coal storage facility will encompass approximately 16 acres, and will contain approximately 400,000 tons of coal. The stockpile, after the final barge has delivered for the season, will be approximately 35 feet tall. The stockpile will be covered with either an air supported fabric or metal building to protect it from rain and snow and contain the fugitive dust from the stockpile. The coal will have properties that will not make it susceptible to spontaneous combustion, according to Bettine, LLC. Since the coal will be covered and will not require continuous saturation to inhibit spontaneous combustion, very little leachate is expected to emit from the stockpile. The stockpile will bear on a fill pad of the local sand. The building and stockpile is expected to be heated to maintain a temperature of approximately 20° F during the winter. Even though that temperature is below freezing, the stockpile itself will contain enough residual heat that will cause the underlying permafrost to thaw. If the operating permit requires a containment liner be installed under the stockpile, the permafrost must be either maintained or prethawed prior to installation of the liner. If a liner is not required, the permafrost can be allowed to thaw naturally under the stockpile. Any leachate emitted from the stockpile may require collection and treatment prior to disposal, depending on the permit requirements. The air supported fabric or metal building shall be supported on steel piling driven into the underlying permafrost. The piles shall have enough frictional capacity to resist overturning and frost heave forces. Steel, 12-inch nominal pipe piles on 40-foot centers, driven to a depth of 60 feet below the top of the fill pad will support the building. A 450-metric ton bucket wheel stacker/reclaimer will be covered by the building. The stacker/reclaimer rides on rails that can only tolerate small differential movements. If a liner is required, the stacker/reclaimer will be supported on concrete footings that are 12.5 feet square and 2 feet thick. If a liner is not required, the stacker/reclaimer will need to be supported on thermo helix-piling that are connected to an active refrigeration unit to prevent settlement as the permafrost thaws. The 160 horsepower active refrigeration system will have a power requirement of 1600 kilowatt-hours per day. 4 Bethel, Alaska Coal Fired Power Plant Conceptual Design Report The coal will be transported by a conveyor system from the storage facility to the bunkers. Another conveyor system will transport the coal from the barge off-loading dock to the storage area. The conveyors shall be supported on driven steel piling. The piling shall be 8-inch nominal steel pipe, driven to a depth of 40 feet and spaced 80 feet on center. Conceptual design drawings showing the layout of the coal storage facility and conveyors are shown in Appendix C. IX. COOLING LAKE OPTION The steam generated from the power plant can be cooled either with the proposed cooling towers, or in a 78-acre cooling lake located approximately 2000 feet south of the site. Pipe size and flow rates for the cooling lake option were provided by PES. The heated water will be transported to the cooling lake in a 48-inch diameter pipe and discharged on the west shore. Cool water will be pumped from the east shore through a 48-inch diameter pipe. Two, 1000 horsepower pumps will be located at the lake, one in use, and one for backup and reserve when the primary pump is being serviced. The pumps shall be enclosed in a heated pumphouse that is founded on driven piles. The pipelines shall be supported above grade on bents supported by driven steel piling. The cooling lake and pipeline layouts are shown in Appendix A. X. 3,000,000 GALLON BULK FUEL FACILITY The bulk fuel facility will consist of four uninsulated tanks, each measuring 60 feet in diameter by 40 feet high with a nominal storage capacity of 800,000 gallons. The tanks will store No. 1 diesel, which has a lower pour point temperature than No. 2 diesel, and therefore will not require added heat. The tanks shall be welded steel in accordance with the American Petroleum Institute (API) Standard 650. The tanks will be founded on concrete ring walls that bear on a compacted fill pad of the local sand. A layer of rigid board insulation and a passive refrigeration, thermo syphon flat loop system shall be installed in the pad to preserve the underlying permafrost. Secondary containment of the fuel tanks will consist of a surface installed primary membrane liner placed on top of earthen dikes constructed from the local sand, and capped with a layer of sand and gravel. Conceptual design drawings of the bulk fuel facility are shown in Appendix C. XI. INTERMEDIATE/DAY FUEL TANKS & WATER STORAGE TANKS A transfer pump will deliver the fuel from the bulk fuel facility to two 12,000 gallon double- walled intermediate tanks housed inside the power plant building, or a separate heated building if the power plant is barge mounted. The intermediate fuel tanks shall be welded steel in accordance with UL Standard 142. A standby transfer pump is included in this design, so that a pump is always available during servicing. The delivery pipeline will be a 4-inch steel pipe supported above grade on helical piers or piling. The fuel will be heated to the specified temperature of 70° F in the intermediate tanks prior to entering the turbines. The intermediate tanks will contain glycol heat circulation loops, and will require 8600 BTU’s to heat 2800 gallons of fuel per hour per degree to 70° F. A 700,000 gallon raw water tank, and an 80,000 gallon demineralized water tank, will be located inside the power plant building or a separate heated building if the power plant is barge mounted. 5 Bethel, Alaska Coal Fired Power Plant Conceptual Design Report The sizes of the tanks were provided by PES. Both tanks shall be welded steel in accordance with AWWA Standard D100. The tanks will be founded on concrete ringwalls integrated into the power plant foundation. XII. ACCESS ROADS An access road will connect the proposed site to Bethel via a private spur road that intersects Standard Oil Road west of the City Petroleum Dock. Other roads will connect the facility with the off-loading dock on the river and with the proposed cooling lake to the south. The access roads will be constructed as an embankment of the local sand, and capped with an 8-inch thick sand and gravel surface. The embankment shall be 4.5 feet thick to limit seasonal thaw within the existing active layer. Conceptual design drawings of the access roads are included in Appendix C. XIII. COAL AND FUEL OFF-LOADING DOCK A coal and fuel barge off-loading dock and marine header will be located on the west bank of the Kuskokwim River, approximately 3500 feet south of the City of Bethel Petroleum Port. The dock design is similar to the open cell sheet pile design that was included in the 1999 Donlin Creek Mine, Late Stage Evaluation Study1 by Peratrovich, Nottingham & Drage, Inc. The cost estimate for the dock is also based on that report. The coal will be off-loaded with a barge unloading system that spans the coal barge, and uses a bucket elevator system to remove the coal. The unloader shall be moored to the dock during the barge season, and then stored in a protected area of the river during the winter to prevent ice damage. A pile supported conveyor system will transport the coal from the dock to the storage area. The marine header will connect to a 4-inch diameter pipeline for fuel transfer to the bulk fuel facility. The pipeline will be supported above grade on helical piers or piling. Conceptual design drawings of the coal and fuel barge off-loading dock, barge unloading system, conveyor and pipeline are shown in Appendix C. The barge season in Bethel runs from June through mid-September. At present, the largest barge delivering fuel to Bethel is 344 feet long, and can deliver a maximum of 2,100,000 gallons of fuel with a draft of 11.5 feet. The barge is owned by Seacoast Towing and delivers fuel to the Yukon Fuel Company. XIV. PERMITTING The power plant, coal storage facility, bulk fuel facility, access roads, and barge off-loading dock will require the following: 1. A spill contingency plan designed to satisfy Federal, Facility Response Plan (FRP) and State, Alaska Department of Environmental Conservation – Oil Discharge Prevention and Contingency Plan (ADEC C-Plan) requirements. It must be approved by the EPA, the 6 Bethel, Alaska Coal Fired Power Plant Conceptual Design Report U.S. Coast Guard and ADEC. The EPA requires an approved FRP from each facility with storage capacity of 42,000 gallons or more, and which receives oil by marine delivery. The Coast Guard must approve a FRP from each fuel facility that can transfer oil to or from vessels with oil cargo capacity of 250 barrels (10,500 gals.). ADEC requires approval of an ODPCP prior to operations at facilities with storage capacities of 420,000 gallons or more. The C-Plan must satisfy the requirements of Title 46, Chapter 04, Section 030 of the Alaska Statutes (AS 46.04.030), and meet the format requirements listed in the Alaska Administrative Code, Chapter 75, Section 425 (18 AAC 75.425). The ADEC approval process includes public comment and a Coastal Zone Management review. The plan must consist of four parts: a. The RESPONSE ACTION PLAN presents the fundamental elements of spill response. It outlines initial actions and spill reporting procedures, provides emergency phone numbers, and presents spill response strategies. b. The PREVENTION PLAN describes the facility design, maintenance and operating procedures that contribute to spill prevention and early detection. Potential spills are identified. c. The SUPPLEMENTAL INFORMATION section includes a description of the facility and its response command structure, as well as environmental data and response equipment considerations. d. The BEST AVAILABLE TECHNOLOGY section demonstrates that the facility complies with the State of Alaska requirements of 18 AAC 75.425(e)(4) and 18 AAC 75.445(k). 2. A Marine Transfer Operations Manual which demonstrates that the vessel/barge transfer procedures and dock equipment comply with Coast Guard requirements. The Manual must be approved by the U.S. Coast Guard. It confirms that the operator’s marine transfer procedures and equipment comply with the requirements listed in 33 CFR, Parts 154 and 156. The manual format and content requirements are listed in 33 CFR, Part 154, Subpart B, which lists 23 items that must be addressed. Two copies of the manual are to be submitted to the Coast Guard. Upon approval, one copy of the manual will be returned marked "Examined by the Coast Guard". Copies of the manual are to be maintained at the facility so that they are, “current, available for examination by the USCG Captain of the Port (COTP), and readily available for each facility person in charge while conducting an oil transfer operation”. 3. A Spill Prevention Control and Countermeasure Plan (SPCC) that is certified by a licensed Engineer (P.E.), and confirms that the facility complies with the EPA spill prevention and operating requirements. The oil pollution prevention regulations require the preparation of a SPCC for all facilities with aboveground oil storage of more than 1,320 gallons and which, due to their location, could reasonably be expected to discharge oil in harmful quantities into or upon the navigable waters or adjoining shorelines of the United States. The SPCC Plan must be carefully thought out and prepared in accordance with good engineering practices to prevent and mitigate damage to the environment from 7 Bethel, Alaska Coal Fired Power Plant Conceptual Design Report oil spills. It must address all oil “containers” / tanks with a capacity of 55 gallons or more. The Plan must be certified by a licensed Professional Engineer, and must also have the full approval of management at a level with authority to commit the necessary resources. Facility management is to review and evaluate the Plan at least once every five years, and update it whenever there is a change in facility design, construction, operation, or maintenance that could materially affect the potential for discharge to navigable water. EPA regulations further stipulate, in 40 CFR, Part 112.4, that a written report must be submitted to the Regional Director of the EPA when a facility has either one spill greater than 1,000 gallons, or two spills in excess of 42 gallons in a 12-month period that enter navigable waters. The SPCC Plan need not be submitted to, or approved by, the EPA, but must be maintained at the facility and available for agency inspection. 4. A Fire Marshal review requires submittal of a complete set of construction documents to the State of Alaska, Department of Public Safety, Division of Fire Prevention (Fire Marshal) for plan review and approval. The State Fire Marshall then issues a Plan Review Certificate to verify compliance with adopted Building, Fire and Life Safety codes. Final stamped drawings must be submitted along with the application fee for project review. Anticipate a minimum of one month before comments may be received from the Fire Marshall. 5. A U.S. Army Corps of Engineers Section 10, 33 U.S.C. 403 permit is required prior to the accomplishment of any work in, over, or under navigable waters of the United States, or which affects the course, location, condition or capacity of such waters. The Kuskokwim River is defined as a navigable waterway. Typical activities requiring Section 10 permits include: a. Construction of piers, wharves, breakwaters, bulkheads, jetties, weirs, dolphins, marinas, ramps, floats, intake structures and cable or pipeline crossings. b. Work such as dredging or disposal of dredged material. c. Excavation, filling, or other modifications to navigable waters of the U.S. 6. The National Marine Fisheries Service (NMFS), U.S. Fish and Wildlife Service and Alaska Department of Fish and Game or Department of Natural Resources, will review the 403 permit to determine if there is an impact on the anadromous fish population in the Kuskokwim River. They may place restrictions on construction timing or methods. The U.S. Fish and Wildlife Service will also determine if the project impacts any endangered species. 7. A U.S. Army Corps of Engineers wetlands permit is required to place fill material on existing soils before construction begins. Section 404 of the Clean Water Act requires approval prior to discharging dredged or fill material into the waters of the United States, including wetlands. Wetlands include tundra, permafrost areas, swamps, marshes, bogs and similar areas. Typical activities requiring Section 404 permits include: a. Discharging fill or dredged material in waters of the U.S., including wetlands. 8 Bethel, Alaska Coal Fired Power Plant Conceptual Design Report b. Site development fill for residential, commercial, or recreational developments. c. Construction of revetments, groins, breakwaters, levees, dams, dikes and weirs. d. Placement of riprap and road fills. 8. The Environmental Protection Agency (EPA) National Pollution Discharge Elimination System (NPDES) has jurisdiction for the following items: a. Operators of construction projects disturbing five acres or more must develop a Storm Water Pollution Prevention Plan (SWPPP), and submit the SWPPP as well as a Notice of Intent (NOI) to the EPA and ADEC for review prior to the start of construction activity. b. Non-Stormwater Discharge Assessment Certification is required to discharge any process wastewater which would include the water discharged into the proposed cooling lake or coal pile effluent. c. Approval under the Multi-Sector General Permit (MSGP) for the State of Alaska is required for storm water discharges associated with industrial activity. Steam electric power generation facilities, including coal handling sites fall under Category VII of the MSGP. 9. The Bethel City Planning Department will review the Fire Marshall, AK DEC and Army Corps of Engineers permits and may add other requirements to the project, such as access and setback from property lines. The City of Bethel also has a General Permit issued by the Corps of Engineers. 10. A review by the Federal Aviation Administration (FAA). Power plants located less than 5 miles from a runway or airport, such as this project, should complete Form 7460-1, “Notice of Proposed Construction or Alteration”, and submit all necessary elevation and height of structure information to the FAA (Alaska Region) prior to construction. The FAA reviews the power plant and determines whether the construction or project will present a hazard to air traffic in the vicinity. The FAA has typically provided project determinations within one week of the completed form submittal. 11. A review by the State Historic Preservation Office (SHPO) is required, under Section 106 of the National Historic Preservation Act, for any State or Federally funded project that has the potential of disturbing cultural resources. XV. BUDGET COST ESTIMATES Budget Construction Cost Estimates have been prepared for the construction of the proposed site development, building foundations, coal storage area, 3,000,000 gallon bulk fuel facility, intermediate fuel tanks, water tanks, access roads, pipelines, and coal and fuel barge off-loading dock. The estimates were developed based on historical pricing for similar work in Bethel with a 6.5% overhead for profit, bonding and insurance. A construction contingency of 15% has been factored into the estimates. A freight rate of $0.20 per pound to Bethel was provided by Bettine, 9 Bethel, Alaska Coal Fired Power Plant Conceptual Design Report 10 LLC. These estimates do not include costs for the buildings, power generation equipment, conveyors, stacker/reclaimer, or coal barge unloading system; their transportation to Bethel, nor their mobilization to the site and setup. The estimates do not include the costs of land purchase, leases or right-of-ways. The Budget Construction Cost Estimates are summarized below. A breakdown of the construction costs is included in Appendix D. y Power Plant & Buildings, Founded on Permafrost $21,000,000 y Barge Mounted Power Plant Option $13,800,000 y 3,000,000 Gallon Bulk Fuel Facility $4,125,000 y Lined Coal Storage w/ Maintaining Permafrost Integrity $19,200,000 y Lined Coal Storage w/ Pre-thaw of Permafrost $15,800,000 y Unlined Coal Storage w/ Allowing Natural Thaw of Permafrost $7,300,000 y Cooling Lake Option $5,450,000 Cost estimates have also been prepared for the design, permitting and project management for the proposed power plant facility, coal storage area, bulk fuel facility, intermediate fuel tank, raw water tank, access roads, pipelines, and coal and fuel barge off-loading dock. These estimates do not include costs for the power plant equipment, buildings, conveyor, stacker/reclaimer and barge unloading systems, as well as, land purchase, lease and right-of-way costs. The estimates were developed based on historical pricing for similar work in Bethel. The design, permitting and construction management cost estimates are summarized below. The cost is the same for either the power plant founded on permafrost or barge mounted option. y Estimated Design Cost $900,000 y Estimated Permitting Cost $100,000 y Estimated Project Management Cost $350,000 The cooling lake option requires additional design, permitting and project management. The following cost estimates were developed for the cooling lake option. y Estimated Design Cost $100,000 y Estimated Permitting Cost $50,000 y Estimated Project Management Cost $100,000 XVI. REFERENCES 1 Peratrovich, Nottingham and Drage, Inc., Donlin Creek Mine Late Stage Evaluation Study, prepared for Placer Dome Technical Services, Ltd., March 1, 1999. APPENDIX A SITE LOCATIONS APPENDIX B FLOOD HAZARD DATA Bethel | City Office: (907) 543-2047 | Revised: March 2000 STATUS 2nd class city LAST FLOOD EVENT 1991 POPULATION 5,471 FLOOD CAUSE BUILDINGS ELEVATION RIVER SYSTEM Kuskokwim River FLOOD OF RECORD COASTAL AREA none FLOOD CAUSE ELEVATION NFIP STATUS participating WORST FLOOD EVENT 1988 FLOODPLAIN REPORT FLOOD CAUSE FLOOD INSURANCE STUDY yes FLOOD GAUGE no Comments: Published Flood Insurance Rate Maps (FIRM) show detailed flood information. FIRM can be purchased from Federal Emergency Management Agency (FEMA) at FEMA Maps Flood Map Distribution Center 6730 (A–G) Santa Barbara Court Baltimore, MD 21227-5623 Toll free: 800 -358-9616 FIRM Panels 0008 B, 0009 B, 0012 B, 0013 B were corrected on 3 June 1994 by FEMA to correct the datum reference from the NGVD to MLLW. The Flood Insurance Rate Map (FIRM), revised February 15, 1985, for the community indicates a 100-year, or Base Flood Elevation (BFE) of 17 ft MLLW. Pagemaster | (907) 753-2622 Floodplain Manager | (907) 753-2610 Page 1 of 1Flood Hazard Data: Bethel 6/7/2003http://www.poa.usace.army.mil/en/cw/fld_haz/bethel.htm APPENDIX C CONCEPTUAL DESIGN DRAWINGS APPENDIX D CONSTRUCTION BUDGET COST ESTIMATES BUDGET COST ESTIMATE Power Plant Feasibility Study Bethel, Alaska MATERIAL UNIT MATL FREIGHT No. ITEM QTY UNITS COST TOTAL $0.20/lb TOTAL Mobilization/Demobilization ……………………………………………………………………………………………………………………………………100,000 1 Mob/DeMob 1 SUM 100,000 100,000 100,000 Earthworks ……………………………...………………………………………………………………………………………………………………………6,065,000 2 Sand Fill 195,000 CY 15 2,925,000 2,925,000 3 Gravel Surface Course 8" 20,000 CY 80 1,600,000 1,600,000 4 Access Roads 7,000 LF 220 1,540,000 1,540,000 Geotextile……………………………………………………………...…………………………………………………………………………………………292,350 5 Non-Woven Geotextile 148,000 SF 0.10 14,800 29,600 44,400 6 Woven Geotextile 826,500 SF 0.10 82,650 165,300 247,950 Thermal Protection ………………………………………………….…………………………………………………………………………………………3,136,140 7 Maint Bldg Rigid Insulation 165,000 BF 1.00 165,000 16,500 181,500 8 Maint Bldg Flat Loop Thermo Syphon w/ Hybrid Condensor 24 EA 7,000 168,000 8,640 176,640 9 Power Plant Rigid Insulation 1,800,000 BF 1.00 1,800,000 180,000 1,980,000 10 Power Plant Flat Loop Thermo Syphon w/ Hybrid Condensor 60 EA 12,500 750,000 48,000 798,000 Foundations ……………………………………………………………………………………………………………………………………………………4,081,520 11 Maint. Bldg Slab on Grade w/ Footings & Grade Beams 280 CY 1,000 280,000 30,240 310,240 12 Pwr Plant Slab on Grade w/ Footings & Grade Beams 2,600 CY 1,000 2,600,000 280,800 2,880,800 13 Stoker Slabs in Power Plant 120 CY 1,000 120,000 12,960 132,960 14 Raw Water & Demineralized Water Tank Ringwalls 20 CY 1,000 20,000 2,160 22,160 15 Admin. Bldg. Thermo Helix-Piles (Incl. Installation)24 EA 7,100 170,400 13,440 183,840 16 Cooling Tower Thermo Helix-Piles (Incl. Installation)32 EA 7,100 227,200 17,920 245,120 17 Ash Silo Thermo Helix-Piles (Incl. Installation)4 EA 7,100 28,400 2,240 30,640 18 Housing Thermo Helix-Piles (Incl. Installation)36 EA 7,100 255,600 20,160 275,760 Tanks ……………………………………………...……………………………………………………………………………………………………………532,209 19 Intermediate Fuel Tank (12,000 Gallon, Double Walled) 2 EA 26,000 52,000 9,600 61,600 20 Intermediate Tank Appurtenances 2 LS 10,000 20,000 400 20,400 21 Raw Water Tank (700,000 Gallon, Steel, Erected) 1 EA 252,000 252,000 34,539 286,539 22 Raw Water Tank Appurtenances 1 LS 10,000 10,000 200 10,200 23 Demineralized Water Tank (80,000 Gallon, Steel, Erected) 1 EA 126,000 126,000 17,270 143,270 24 Demineralized Water Tank Appurtenances 1 LS 10,000 10,000 200 10,200 Fuel & Raw Water Pipelines ………………………………..………………………………..…………………………………………………………………238,063 25 Coated 4" Sch 40 Pipe 3,700 LF 60 222,000 7,985 229,985 26 4" Plug Valve 2 EA 1,750 3,500 38 3,538 27 4" Check Valve 2 EA 360 720 24 744 28 4" Gate Valve (Water Tanks) 2 EA 495 990 44 1,034 29 3" Ball Valve (Fuel Bypass) 2 EA 400 800 20 820 30 Fill Limiting Valve 2 EA 965 1,930 12 1,942 Dock……………………………………………………………………………………………………………………………………………………………2,211,350 31 Fuel Dock 400 LF 5,500 2,200,000 2,200,000 32 Marine Header Containment 1 LS 7,500 7,500 1,000 8,500 33 Marine Header Assmbly 1 EA 2,500 2,500 350 2,850 Security Fencing ……………………………...………………………….……………………………………………………………………………………181,530 34 Chain Link Fence 9,635 LF 15 144,525 28,905 173,430 35 Vehicle Gate 2 EA 4,000 8,000 100 8,100 Electrical ………………………………………………………………………………………………………………………………………………………203,500 36 Electrical Controls 1 SUM 100,000 100,000 1,000 101,000 37 Lighting 1 SUM 100,000 100000 2500 102,500 Sub-Total:17,041,662 Contingency @ 15%2,556,249 Overhead & Profit @ 5%979,896 Bonding and Insurance @ 1.5%293,969 Total: 20,871,775 Coal Fired Plant & Buildings BUDGET COST ESTIMATE Power Plant Feasibility Study Bethel, Alaska MATERIAL UNIT MATL FREIGHT No. ITEM QTY UNITS COST TOTAL $0.20/lb TOTAL Mobilization/Demobilization ………………………………………………………………………………………………………………………………100,000 1 Mob/DeMob 1 SUM 100,000 100,000 100,000 Earthworks ……………………………...……………………………………………………………………………………………………………………5,877,000 2 Sand Fill 100,000 CY 15 1,500,000 1,500,000 3 Gravel Surface Course 8" 8,000 CY 80 640,000 640,000 4 Access Roads 7,100 LF 220 1,562,000 1,562,000 5 Harbor Excavation 65,000 CY 5 325,000 325,000 6 Breakwater Dike Fill 30,000 CY 10 300,000 300,000 7 Breakwater Dike Gravel 3,000 CY 80 240,000 240,000 8 Armor Rock (3-foot size)3,100 TON 100 310,000 310,000 9 Pier, Dolphins & Moorage 1 LS 1,000,000 1,000,000 1,000,000 Geotextile……………………………………………………………...……………………………………………………………………………………164,400 10 Non-Woven Geotextile 148,000 SF 0.10 14,800 29,600 44,400 11 Woven Geotextile 400,000 SF 0.10 40,000 80,000 120,000 Thermal Protection ………………………………………………….………………………………………………………………………………………524,090 12 Maint Bldg Rigid Insulation 165,000 BF 1.00 165,000 16,500 181,500 13 Maint Bldg Flat Loop Thermo Syphon w/ Hybrid Condensor 24 EA 7,000 168,000 8,640 176,640 14 Water Tank Building Rigid Insulation 50,500 BF 1.00 50,500 5,050 55,550 15 Water Tank Bldg Thermo Syphon w/ Hybrid Condensor 15 EA 7,000 105,000 5,400 110,400 Foundations …………………………………………………………………………………………………………………………………………………1,178,560 16 Maint. Bldg Slab on Grade w/ Footings & Grade Beams 280 CY 1,000 280,000 30,240 310,240 17 Water Tank Building Slab on Grade w/ Footings & Grade Beams 100 CY 1,000 100,000 10,800 110,800 18 Raw Water & Demineralized Water Tank Ringwalls 20 CY 1,000 20,000 2,160 22,160 19 Admin. Bldg. Thermo Helix-Piles (Incl. Installation)24 EA 7,100 170,400 13,440 183,840 20 Cooling Tower Thermo Helix-Piles (Incl. Installation)32 EA 7,100 227,200 17,920 245,120 21 Ash Silo Thermo Helix-Piles (Incl. Installation)4 EA 7,100 28,400 2,240 30,640 22 Housing Thermo Helix-Piles (Incl. Installation)36 EA 7,100 255,600 20,160 275,760 Tanks ……………………………………………...…………………………………………………………………………………………………………532,209 23 Intermediate Fuel Tank (12,000 Gallon, Double Walled) 2 EA 26,000 52,000 9,600 61,600 24 Intermediate Tank Appurtenances 2 LS 10,000 20,000 400 20,400 25 Raw Water Tank (700,000 Gallon, Steel, Erected) 1 EA 252,000 252,000 34,539 286,539 26 Raw Water Tank Appurtenances 1 LS 10,000 10,000 200 10,200 27 Demineralized Water Tank (80,000 Gallon, Steel, Erected) 1 EA 126,000 126,000 17,270 143,270 28 Demineralized Water Tank Appurtenances 1 LS 10,000 10,000 200 10,200 Fuel & Raw Water Pipelines ………………………………..………………………………..………………………………………………………………306,436 29 Coated 4" Sch 40 Pipe 4,800 LF 60 288,000 10,358 298,358 30 4" Plug Valve 2 EA 1,750 3,500 38 3,538 31 4" Check Valve 2 EA 360 720 24 744 32 4" Gate Valve (Water Tanks) 2 EA 495 990 44 1,034 33 3" Ball Valve (Fuel Bypass) 2 EA 400 800 20 820 34 Fill Limiting Valve 2 EA 965 1,930 12 1,942 Dock…………………………………………………………………………………………………………………………………………………………2,211,350 35 Fuel Dock 400 LF 5,500 2,200,000 2,200,000 36 Marine Header Containment 1 LS 7,500 7,500 1,000 8,500 37 Marine Header Assmbly 1 EA 2,500 2,500 350 2,850 Security Fencing ……………………………...………………………….…………………………………………………………………………………148,500 38 Chain Link Fence 7,800 LF 15 117,000 23,400 140,400 39 Vehicle Gate 2 EA 4,000 8,000 100 8,100 Electrical ……………………………………………………………………………………………………………………………………………………203,500 40 Electrical Controls 1 SUM 100,000 100,000 1,000 101,000 41 Lighting 1 SUM 100,000 100000 2500 102,500 Sub-Total:11,246,046 Contingency @ 15%1,686,907 Overhead & Profit @ 5%646,648 Bonding and Insurance @ 1.5%193,994 Total: 13,773,594 Barge Mounted Plant Option BUDGET COST ESTIMATE Power Plant Feasibility Study Bethel, Alaska MATERIAL UNIT MATL FREIGHT No. ITEM QTY UNITS COST TOTAL $0.20/lb TOTAL Mobilization/Demobilization …………………………………………………………………………………………………………………………100,000 1 Mob/DeMob 1 SUM 100,000 100,000 100,000 Earthworks ……………………………...………………………………………………………………………………………………………………315,000 2 Tank Farm Sand Fill 13,000 CY 15 195,000 195,000 3 Tank Farm Gravel Surface Course 8" 1,500 CY 80 120,000 120,000 Geotextile……………………………………………………………...………………………………………………………………………………26,250 4 Tank Farm Non-Woven Geotextile 15,500 SF 0.10 1,550 3,100 4,650 5 Tank Farm Woven Geotextile 72,000 SF 0.10 7,200 14,400 21,600 Thermal Protection ………………………………………………….…………………………………………………………………………………626,240 6 Tank Farm Rigid Insulation 310,000 BF 1.00 310,000 31,000 341,000 7 Tank Farm Flat Loop Thermo Syphon w/ Hybrid Condensor 30 EA 9,000 270,000 15,240 285,240 Secondary Containment ………………………………………………………………………………………………………………………………210,000 8 Tank Farm Primary Liner 50,000 SF 4.00 200,000 10,000 210,000 Tank Foundations ………………………………………………………………………………………………………………………………………83,100 9 Tank Farm (60' Dia) Foundations 75 CY 1,000 75,000 8,100 83,100 Tanks ……………………………………………...……………………………………………………………………………………………………1,384,836 10 Tank Farm (800,000 gal Insulated Tank, Erected) 4 EA 260,000 1,040,000 72,000 1,112,000 11 Tank Coating 41,469 SF 3.84 159,372 664 160,036 12 Tank Catwalks 4 EA 15,000 60,000 12,000 72,000 13 Tank Farm Appurtenances 4 LS 10,000 40,000 800 40,800 Tank Farm Walkways …………………………………………………………..………………………………………………………………………129,638 14 Walkway Supports 20 EA 2,200 44,000 4,800 48,800 15 Steel Catwalk 250 LF 175 43,750 15,000 58,750 16 Coating 5500 SF 4.00 22,000 88 22,088 Pipelines and Valves………………………………..………………………………..…………………………………………………………………209,345 17 Coated 4" Sch 40 Pipe 350 LF 60 21,000 755 21,755 18 Coated 2" Sch 40 Pipe 365 LF 15 5,475 266 5,741 19 4" Plug Valve 4 EA 1,750 7,000 296 7,296 20 4" Gate Valve 1 EA 1,255 1,255 62 1,317 21 4" Check Valve 5 EA 360 1,800 275 2,075 22 3" Ball Valve 4 EA 400 1,600 40 1,640 23 2" Ball Valve 6 EA 200 1,200 20 1,220 24 Pipe Supports 320 EA 300 96,000 12,800 108,800 25 Pig Catcher 1 EA 7,000 7,000 2,500 9,500 26 Cathodic Protection 1 EA 50,000 50,000 50,000 Pumphouse Mechanical Systems ………………………….……………………………………..……………………………………………………86,996 27 4" Sch 40 Pipe 50 LF 60 3,000 286 3,286 28 4" Plug Valve 2 EA 1,750 3,500 38 3,538 29 4" Ball Valve 2 EA 550 1,100 30 1,130 30 6" Butterfly Valve 2 EA 700 1,400 60 1,460 31 3" Sch 40 Pipe 50 LF 50 2,500 150 2,650 32 3" Ball Valve 2 EA 400 800 20 820 33 3" Check Valve 2 EA 350 700 12 712 34 30 hp Pumps (Fuel Transfer) 2 EA 20,000 40,000 120 40,120 35 Filter/Separator 2 EA 10,000 20,000 40 20,040 36 Accumulators 2 EA 1,500 3,000 40 3,040 37 Misc Accessories 1 LS 10,000 10,000 200 10,200 Pumphouse Building ……………………………………………..…………………….………………………………………………………………90,000 38 20'x30' Building 600 SF 150 90,000 90,000 Dispensing Station……………………………………………..…………………….…………………………………………………………………105,000 39 Containment Area 1 LS 65,000 65,000 65,000 40 Dispensing Pumps, Piping & Appurtenances 1 LS 40,000 40,000 40,000 Sub-Total:3,366,404 Contingency @ 15%504,961 Overhead & Profit @ 5%193,568 Bonding and Insurance @ 1.5%58,070 Total: 4,123,004 3 Mil Gal Fuel Tank Farm BUDGET COST ESTIMATEPower Plant Feasibility StudyBethel, AlaskaMATERIALUNIT MATL FREIGHTNo. ITEM QTY UNITS COST TOTAL $0.20/lb TOTALEarthworks ……………………………...………………………………………………………………………………………………………………………2,500,0001 Sand Fill 130,000 CY 15 1,950,000 1,950,0002 Access Road 2,500LF 220 550,000 550,000Geotextile……………………………………………………………...…………………………………………………………………………………………234,0003 Woven Geotextile780,000 SF 0.10 78,000 156,000 234,000Thermal Protection ………………………………………………….…………………………………………………………………………………………6,302,4004 Rigid Insulation (4 inches thick)3,120,000 BF 1.00 3,120,000 312,000 3,432,0005 Flat Loop Thermo Syphon w/ Hybrid Condensor390 EA 7,000 2,730,000 140,400 2,870,400Foundations………………………………………………………………………………………………………………………………………………………3,241,1006 Building - Thermo Helix-Pile w/ Hybrid Condensor (Installed) 110 EA7,100.00 781,000 61,600 842,6007 Conveyor - Driven 8' Piles (Installed)70 EA 3,750.00 262,500 30,800 293,3008 Stacker/Reclaimer Concrete Footings1,900 CY 1,000 1,900,000 205,200 2,105,200Secondary Containment ………………………………………………………………………………………………………………………………………3,276,0009 Primary Liner780,000 SF 4.00 3,120,000 156,000 3,276,000Electrical ………………………………………………………………………………………………………………………………………………………105,00010 Lighting 1SUM 100,000100000 5000 105,000Sub-Total:15,658,500Contingency @ 15%2,348,775Overhead & Profit @ 5%900,364Bonding and Insurance @ 1.5%270,109Total: 19,177,748Lined Coal Storage w P-Frost BUDGET COST ESTIMATEPower Plant Feasibility StudyBethel, AlaskaMATERIALUNIT MATL FREIGHTNo. ITEM QTY UNITS COST TOTAL $0.20/lb TOTALEarthworks ……………………………...………………………………………………………………………………………………………………………1,420,0001 Sand Fill 58,000 CY 15 870,000 870,0002 Access Roads 2,500 LF 220 550,000 550,000Geotextile……………………………………………………………...…………………………………………………………………………………………234,0003 Woven Geotextile 780,000 SF 0.10 78,000 156,000 234,000Pre Thaw Permafrost………………………………………………….…………………………………………………………………………………………4,570,0004 Thaw Pipes 7,000 EA 500.00 3,500,000 70,000 3,570,0005 Pumps, Piping and Appurtenances 1,000,000 LS 1 1,000,000 1,000,000Foundations………………………………………………………………………………………………………………………………………………………3,249,5006 Building - Driven 12" Steel Piling (Installed) 110 EA 7,100.00 781,000 61,600 842,6007 Conveyor - Driven 8" Steel Piling (Installed) 70 EA 3,750.00 262,500 39,200 301,7008 Stacker/Reclaimer Concrete Footings 1,900 CY 1,000 1,900,000 205,200 2,105,200Secondary Containment …………………………………………………………………………………………………………………………………………3,276,0009 Primary Liner 780,000 SF 4.00 3,120,000 156,000 3,276,000Electrical …………………………………………………………………………………………………………………………………………………………105,00010 Lighting 1 SUM100,000 100000 5000 105,000Sub-Total:12,854,500Contingency @ 15%1,928,175Overhead & Profit @ 5%739,134Bonding and Insurance @ 1.5%221,740Total: 15,743,549Lined Coal Storage w Prethaw BUDGET COST ESTIMATEPower Plant Feasibility StudyBethel, AlaskaMATERIALUNIT MATL FREIGHTNo. ITEM QTY UNITS COST TOTAL $0.20/lb TOTALEarthworks ……………………………...…………………………………………………………………………………………………………………………1,420,0001 Sand Fill 58,000 CY 15 870,000 870,0002 Access Roads 2,500LF 220 550,000 550,000Geotextile……………………………………………………………...…………………………………………………………………………………………234,0003 Module & Tank Pad Woven Geotextile 780,000 SF 0.10 78,000 156,000 234,000Foundations………………………………………………………………………………………………………………………………………………………4,187,5004 Building - Driven 12" Steel Piling (Installed) 110 EA7,100.00 781,000 61,600 842,6005 Conveyors - Driven 8" Steel Piling (Installed) 70 EA3,750.00 262,500 39,200 301,7006 Stacker/Reclaimer - Thermo-Helix Piles 320EA 7,100.00 2,272,000 179,200 2,451,2007 40 HP Active Refrigeration System4 EA 146,000.00 584,000 8,000 592,000Electrical …………………………………………………………………………………………………………………………………………………………105,0008 Lighting 1SUM 100,000100000 5000 105,000Sub-Total:5,946,500Contingency @ 15%891,975Overhead & Profit @ 5%341,924Bonding and Insurance @ 1.5%102,577Total: 7,282,976Unlined Coal Storage BUDGET COST ESTIMATEPower Plant Feasibility StudyBethel, AlaskaMATERIALUNIT MATL FREIGHTNo. ITEM QTYUNITS COSTTOTAL$0.20/lbTOTALEarthworks ……………………………...………………………………………………………………………………………………………………………396,0001 Access Roads1,800 LF 220 396,000 396,000Cooling Lake System……………………………………………………………………………………………………………………………………………3,900,7202 48" O.D. Pipe (Installed) 7,150LF 200 1,430,000 360,360 1,790,3603 Pipe Supports (60' Centers) 130 EA 7,800 1,014,000 83,200 1,097,2004 48" Gate Valve 3 EA 120,000 360,000 4,500 364,5005 Building (16 x 20) 320 SF 150 48,000 4,800 52,8006 Driven 8" Steel Piling for Building (Installed) 6 EA3,750.00 22,500 3,360 25,8607 1000 HP, 55,000 GPM Pump 2 EA 225,000 450,000 20,000 470,0008 Misc Accessories 1 LS 50,000 50,000 50,0009 Discharge Structure 1 LS 25,000 25,000 25,00010 Intake Structure 1 LS 25,000 25,000 25,000Security Fencing ……………………………...………………………….………………………………………………………………………………………157,10011 Chain Link Fence8,500 LF 15 127,500 25,500 153,00012 Vehicle Gate 1 EA4,000 4,000 100 4,100Electrical …………………………………………………………………………………………………………………………………………………………153,50013 Electrical Controls 1 LS100,000 100,000 1,000 101,00014 Lighting1 LS 50,000 50000 2500 52,500Delete Cooling Tower ……………………………………………………………………………………………………………………………………………-245,12015 Cooling Tower Thermo Helix-Piles -32EA 7,100 -227,200 -17,920 -245,120Sub-Total:4,362,200Contingency @ 15%654,330Overhead & Profit @ 5%250,827Bonding and Insurance @ 1.5%75,248Total: 5,342,604Cooling Lake Option 2. Combustion Turbine Plant at Bethel Nuvista Light & Power Co. COMBUSTION TURBINE POWER PLANT BETHEL, ALASKA SITE DEVELOPMENT, EARTHWORKS, FOUNDATIONS AND BULK FUEL CONCEPTUAL DESIGN REPORT SEPTEMBER 2, 2003 Prepared by: Mike Hendee, P.E. Voice: (907) 273-1830 Fax: (907) 273-1831 139 East 51st Avenue Anchorage, Alaska 99503 Bethel, Alaska Combustion Turbine Power Plant Conceptual Design Report EXECUTIVE SUMMARY This report has been prepared for Nuvista Light & Power, Co. under contract with Bettine, LLC. Its purpose is to provide a conceptual design and budget cost estimate for site development, earthworks, foundations and bulk fuel systems for a new combustion turbine power generation plant located in Bethel, Alaska. The proposed power plant will be a 130 megawatt combined combustion and steam turbine system. A 25,000,000 gallon bulk fuel tank farm, a 100,000 gallon intermediate fuel tank and a 700,000 gallon raw water tank also comprise the facility. The report includes basic feasibility level conceptual design drawings for the site development, access roads, fuel storage, piping and a fuel barge off-loading dock. Also included are permitting requirements for the scope of work identified above, flood hazard information, an evaluation of the heating requirements for the fuel and water tanks and budget cost estimates. The proposed site location for the power plant facility was provided by Bettine, LLC and is located approximately 6000 feet south of the City of Bethel Petroleum Port and 1650 feet west of the Kuskokwim River. For this report, we have assumed the site is underlain by ice-rich warm permafrost. No geotechnical nor survey information is available for the proposed site. The power plant layout is preliminary and consists of 14 modules. The layout is based on information provided by Precision Energy Services, Inc. Based on the weights provided for the equipment, the modules shall be supported by thermo helix-piles with passive refrigeration designed to provide foundation support in permafrost. The 25,000,000 gallon bulk fuel tank farm will be located south of the power plant modules and will consist of eight insulated tanks, each measuring 120 feet in diameter and 40 feet high with a nominal storage capacity of 3.2 million gallons. The tanks will be heated with waste heat from the combustion turbines to keep the fuel above the specified minimum temperature of 20°F. A 100,000 gallon insulated intermediate fuel tank and a 700,000 gallon insulated raw water tank will be located near the modules with both heated to the specified temperature of 70°F. The tanks shall be founded on concrete ringwalls that bear on an insulated fill pad with a passive refrigeration thermo syphon system installed to preserve the permafrost. Both the thermo helix- piles and the thermo syphons will have hybrid condenser units that allow for connection to an active refrigeration system should the need arise in the future. A fuel barge off-loading dock with a marine header will be located on the west bank of the Kuskokwim River. The dock design was developed by Peratrovich, Nottingham and Drage, Inc. for the Donlin Creek Mine Late Stage Evaluation Study1. The marine header will connect to an 8-inch diameter pipeline to fill the tanks at the bulk fuel facility. The barge season in Bethel runs from June to September. Presently, the largest fuel barge delivers a maximum of 2,100,000 gallons of fuel per trip, which will require 12 deliveries to fill the tank farm plus an additional 5 deliveries for summer consumption, based on consumption rates provided by Bettine, LLC. EX-1 Bethel, Alaska Combustion Turbine Power Plant Conceptual Design Report Budget Construction Cost Estimates for the proposed site development, module foundations, 25,000,000 gallon bulk fuel facility, intermediate fuel tank, raw water tank, access roads, pipelines and fuel barge off-loading dock are as follows: y Power Plant Modules with Dock & Intermediate Fuel & Water Tanks $8,330,000 y 25,000,000 Gallon Bulk Fuel Facility $25,000,000 y Cooling Lake Option $3,050,000 These estimates are based on competitively bid construction costs with a 15% contingency. Additional costs for design, permitting and construction management of the site development are estimated at $1,100,000. An additional cost of $250,000 will be required for the cooling lake option. Design and construction of the power plant modules and equipment, land purchase, lease and right-of-way costs are not included in these figures. EX-2 Bethel, Alaska Combustion Turbine Power Plant Conceptual Design Report TABLE OF CONTENTS EXECUTIVE SUMMARY ....................................................................................................EX-1 I. INTRODUCTION..............................................................................................................1 II. APPLICABLE CODES AND REGULATIONS .............................................................1 III. SITE LOCATION ..............................................................................................................1 IV. COMMUNITY FLOOD DATA........................................................................................2 V. LOCAL FILL MATERIAL ..............................................................................................2 VI. COMBUSTION TURBINE MODULE FOUNDATIONS .............................................2 VII. COOLING LAKE ..............................................................................................................3 VIII. 25,000,000 GALLON BULK FUEL FACILITY.............................................................3 IX. INTERMEDIATE FUEL TANK AND RAW WATER TANK ....................................4 X. ACCESS ROADS ...............................................................................................................4 XI. FUEL DOCK ......................................................................................................................5 XII. PERMITTING ...................................................................................................................5 XIII. BUDGET COST ESTIMATES ........................................................................................8 XIV. REFERENCES...................................................................................................................9 APPENDICES: Appendix A: Site Location Appendix B: Flood Hazard Data Appendix C: Conceptual Design Drawings Appendix D: Heat Requirement Summaries Appendix E: Construction Budget Cost Estimates i Bethel, Alaska Combustion Turbine Power Plant Conceptual Design Report I. INTRODUCTION This report has been prepared for Nuvista Light & Power, Co. under contract with Bettine, LLC, to provide a conceptual design and budgetary cost estimate for the site development, earthworks, foundations and bulk fuel systems for development of a new power generation facility in the community of Bethel, Alaska. The proposed power plant will be a 130 megawatt combined combustion and steam turbine system. A 25,000,000 gallon bulk fuel tank farm, a 100,000 gallon intermediate fuel tank and a 700,000 gallon raw water tank also comprise the facility. Included with the report are basic feasibility level conceptual design drawings for the site development, access roads, fuel storage, piping and a fuel barge off-loading dock. Also included are permitting requirements for the scope of work identified above, flood hazard information, an evaluation of the heating requirements for the fuel and water tanks and budget cost estimates. No site visit, field work, or geotechnical investigation has been performed for this project. In addition, no geotechnical or survey information is available for the proposed location. A review of overhead aerial photographs was conducted and engineering analyses have been made under the assumption the site is underlain by ice-rich warm permafrost. Site locations, fuel quantities and specified temperatures were provided by Bettine, LLC. Raw water tank size and power generation equipment loads were provided by Precision Energy Services, Inc. (PES). Climate data was obtained from the Alaska Engineering Design Information System (AEDIS). II. APPLICABLE CODES AND REGULATIONS The design of a new power plant facility, roads, dock, foundations and fuel systems are controlled by the following State and Federal codes and regulations: y 2000 International Fire Code as adopted by 13 AAC 50 y 2000 International Building Code as adopted by 13 AAC 50 y State of Alaska Fire and Life Safety Regulations (13 AAC 50) y ADEC Hazardous Substance Regulations (18 AAC 75) y ADEC Air Quality Regulations (18 AAC 52) y Regulatory Commission of Alaska (RCA) Certification (3 AAC 42.05.221) y EPA Oil Pollution Prevention Regulations (40 CFR Part 112) y EPA Storm Water Discharge Regulations (40 CFR Part 122) y U.S. Army Corps of Engineers Wetlands and Navigable Waters Regulations (33 CFR Part 328 and 329) III. SITE LOCATION The proposed site location for the power plant facility was provided by Bettine, LLC. The site will be approximately 6000 feet south of the City of Bethel Petroleum Port and approximately 1650 feet west of the nearest point Kuskokwim River. An access road will connect to a private spur road south of Standard Oil Road and to a new petroleum off-loading dock on the west bank of the river, approximately 3500 feet south of the City Petroleum Port. An 8-inch diameter 1 Bethel, Alaska Combustion Turbine Power Plant Conceptual Design Report pipeline will connect the proposed dock and marine header to the new bulk fuel tank farm. The site, dock and bulk tank farm locations are shown in Appendix A. IV. COMMUNITY FLOOD DATA The U.S. Army Corps of Engineers – Flood Plain Management Services ALASKAN COMMUNITIES FLOOD HAZARD DATA 2000 publication indicates that the community of Bethel is participating in NFIP status and there is a Flood Insurance Study (FIS) available. The published Flood Insurance Rate Maps (FIRM) show detailed flood information, and can be purchased from the Federal Emergency Management Agency (FEMA). The last flood event was in 1991 and the worst flood event was in 1988. A revised Flood Insurance Study (FIS) was published by FEMA in 1984. The FIS is included in Appendix B. The publication lists the 100-year flood elevation at 17.1 feet. The proposed site elevation is around 50 feet, as interpolated from USGS Bethel (D-8), Alaska Quadrangle, 1954 (Limited Revision 1985). The actual site elevation will need to be determined by a design survey. The access roads and dock may be subject to flooding and riverbank erosion. V. LOCAL FILL MATERIAL Local fill material consists of a fine-grained silty dune sand that is mined from pits in Bethel. Material with less than 20% passing the number 200 sieve size and a Corps of Engineers frost classification of F3 can be obtained through selective mining. The present borrow sites are near the airport, with a haul distance to the proposed site of 3 to 5 miles one way. The large quantity of fill material needed for this project may justify developing a borrow source near the site. An intensive geotechnical materials investigation will be required to identify a suitable source and additional permitting will be needed to develop the material site. Gravel is imported to Bethel by barge. Presently, barges routinely deliver 4500 tons (approximately 2500 cubic yards) of gravel per shipment. Most of the gravel delivered is mined in Aniak, Kalskag, or Platinum. VI. COMBUSTION TURBINE MODULE FOUNDATIONS Since the proposed site is assumed to have thaw unstable ice rich soils, the module foundations must maintain the thermal stability of the existing ground to prevent thaw settlement. The combustion turbines have small differential vertical tolerances; therefore, a pile-supported foundation is recommended. To maintain the frozen ground conditions, the modules shall be supported on passive refrigeration thermo helix-piles installed in the winter, using an ad-freeze installation method. A steel frame will be welded to the piling to provide lateral resistance to wind and seismic forces. Conceptual design drawings of the module foundations are shown in Appendix C. 2 Bethel, Alaska Combustion Turbine Power Plant Conceptual Design Report A fill pad of the local sand will be placed under the modules and capped with an 8-inch thick sand and gravel driving surface. The sand fill shall be 4.5 feet thick to limit seasonal thaw within the existing active layer. The fill shall extend around the perimeter of the modules to provide access for vehicles and equipment. The fill pad will be sloped to provide positive drainage away from the modules. The bottom of the modules shall be 4 feet above the top of the fill pad to provide a clear blow-through space. This space separates the fill from the heat of the modules and allows the fill to refreeze each winter. VII. COOLING LAKE The power plant can be cooled either with the proposed cooling towers, or in a cooling lake located approximately 2000 feet south of the site. The heated water will be transported to the cooling lake in a 24-inch diameter pipe and discharged on the west shore. Cool water will be pumped from the east shore through a 24-inch diameter pipe. Two 350 horsepower pumps will be located at the lake, one in use, and one for backup and reserve when the primary pump is being serviced. The pumps shall be enclosed in a heated pumphouse that is founded on driven piles. The pipelines shall be supported above grade on bents supported by driven steel piling. The cooling lake and pipeline layouts are shown in Appendix A. VIII. 25,000,000 GALLON BULK FUEL FACILITY The bulk fuel facility will consist of eight insulated tanks, each measuring 120-foot diameter by 40-foot high with a nominal storage capacity of 3.2 million gallons. The tanks shall be welded steel in accordance with the American Petroleum Institute (API) Standard 650. The steel shell will be covered with 6-inch thick insulated panels that can be removed for inspection. The tanks will be founded on concrete ring walls that bear on a compacted fill pad of the local sand. A layer of rigid board insulation shall be installed in the pad to limit seasonal thaw within the sand fill. Secondary containment of the fuel tanks will consist of a surface installed primary membrane liner placed on top of earthen dikes constructed from the local sand and capped with a layer of sand and gravel. Conceptual design drawings of the bulk fuel facility are shown in Appendix C. A passive refrigeration, thermo syphon flat loop system shall be installed under the bulk fuel facility to preserve the integrity of the permafrost. The system uses the phase change properties of CO2 to remove heat from the sand fill whenever the air temperature is below freezing. The thermo syphons will be fabricated with hybrid condenser units that allow for connection to an active refrigeration system should the need arise in the future. The insulated tanks will be heated with waste heat from the combustion turbines through a glycol circulation loop installed in the bottom of the tanks. Based on the average minimum monthly temperatures recorded since 1949, each tank will require 96,000,000 BTU’s per year to maintain the fuel above the specified minimum temperature of 20°F, which is 10°F above the pour point temperature for number 2 diesel. The BTU requirement is based on the heat loss through the tank walls and roof and does not include the residual heat contained in the fuel at the end of the summer. The heat requirement per tank is summarized in Appendix D. 3 Bethel, Alaska Combustion Turbine Power Plant Conceptual Design Report IX. INTERMEDIATE FUEL TANK AND RAW WATER TANK A transfer pump will deliver the fuel from the bulk fuel facility to a 100,000 gallon insulated intermediate tank near the modules. A standby transfer pump is included in this design so that a pump is always available during servicing. The fuel quantity of the intermediate tank was specified by Bettine, LLC and is based on the estimated daily fuel demand of the combustion turbines of 96,000 gallons (35 million gallons per year). The delivery pipeline will be a 4-inch steel pipe insulated with panels that can be removed for inspection. The pipeline will be supported above grade on piling or helical piers. The fuel will be heated to the specified temperature of 70°F in the intermediate tank prior to entering the turbines. The intermediate tank will contain glycol heat circulation loops similar to the bulk tanks. The tank will require 15,400,000 BTU’s to heat 100,000 gallons of fuel per day from 20°F to 70°F. The tank will require an additional 256,000 BTU’s to maintain a temperature of 70°F on an average day in December, the coldest month of record. According to the Alaska Engineering Design Information System (AEDIS) data, a total of 64,200,000 BTU’s are required to maintain a temperature of 70°F throughout the winter. Assuming the temperature of the fuel entering the intermediate tank is 20°F for 180 days of the year, the total BTU demand for the fuel is around 2,840,000,000 BTU’s. A summary of the heat requirements for the intermediate tank is included in Appendix D. A 700,000 gallon insulated raw water tank will be located next to the intermediate fuel tank. The size of the tank was specified by Precision Energy Services, Inc. (PES). The water tank can be heated with circulation loops in the same fashion as the fuel tanks. The water tank will require 188,000,000 BTU’s to maintain a temperature of 70°F throughout the winter. The heat requirement for the raw water tank is summarized in Appendix D. The intermediate fuel tank shall be welded steel in accordance with API Standard 650 . The raw water tank shall be welded steel in accordance with AWWA Standard D100. Both tanks will have external 6-inch thick insulated panels that can be removed similar to the bulk fuel tanks. The tanks will be founded on concrete ringwalls that bear on a compacted fill pad of the local sand. A passive refrigeration thermo syphon flat loop system with hybrid condenser units shall be installed in the insulated fill pad and the secondary containment for the intermediate fuel tank will consist of a surface installed primary membrane liner placed on top of the fill and attached to timber dikes. Conceptual design drawings of the intermediate and raw water tanks are shown in Appendix C. X. ACCESS ROADS An access road will connect the proposed site to Bethel via a private spur road that intersects Standard Oil Road west of the City Petroleum Dock. The access road will be constructed as an embankment of the local sand and capped with an 8-inch thick sand and gravel surface. The embankment shall be 4.5 feet thick to limit seasonal thaw within the existing active layer. Other roads will be constructed to connect with the proposed cooling lake south of the site and with the 4 Bethel, Alaska Combustion Turbine Power Plant Conceptual Design Report fuel barge off-loading dock to the east. Conceptual drawings of the access roads are included in Appendix C. XI. FUEL DOCK A fuel barge offloading dock and marine header will be located on the west bank of the Kuskokwim River, approximately 3500 feet south of the City of Bethel Petroleum Port. The dock design is similar to the open cell sheet pile design that was included in the 1999 Donlin Creek Mine, Late Stage Evaluation Study Study1 by Peratrovich, Nottingham & Drage, Inc. The cost estimate for the dock is also based on that report. The marine header will connect to an 8-inch diameter pipeline for fel transfer to the bulk fuel facility at a rate of 1400 GPM. The pipeline will be supported above grade on piling or helical piers. Conceptual design drawings of the fuel barge offloading dock and pipeline are shown in Appendix C. The barge season in Bethel runs from June until September. At present, the largest barge delivering fuel to Bethel is 344 feet long and can deliver a maximum of 2,100,000 gallons of fuel with a draft of 11.5 feet. The barge is owned by Seacoast Towing and delivers fuel to the Yukon Fuel Company. The barge can pump around 84,000 gallons per hour through an 8-inch line. XII. PERMITTING The power plant, bulk fuel facility, access road and barge offloading dock will require the following: 1. A spill contingency plan designed to satisfy Federal, Facility Response Plan (FRP) and State, AK Department of Environmental Conservation – Oil Discharge Prevention and Contingency Plan (ADEC C-Plan) requirements. It must be approved by the EPA, the Coast Guard and ADEC. The EPA requires an approved FRP from each facility with storage capacity of 42,000 gallons or more and which receives oil by marine delivery. The Coast Guard must approve a FRP from each fuel facility that can transfer oil to or from vessels with oil cargo capacity of 250 barrels (10,500 gals.). ADEC requires approval of an ODPCP prior to operations at facilities with storage capacities of 420,000 gallons or more. The C-Plan must satisfy the requirements of Title 46, Chapter 04, Section 030 of the Alaska Statutes (AS 46.04.030) and meet the format requirements listed in the Alaska Administrative Code, Chapter 75, Section 425 (18 AAC 75.425). The ADEC approval process includes public comment and a Coastal Zone Management review. The plan must consist of four parts: i. The RESPONSE ACTION PLAN presents the fundamental elements of spill response. It outlines initial actions and spill reporting procedures, provides emergency phone numbers and presents spill response strategies. 5 Bethel, Alaska Combustion Turbine Power Plant Conceptual Design Report ii. The PREVENTION PLAN describes the facility design, maintenance and operating procedures that contribute to spill prevention and early detection. Potential spills are identified. iii. The SUPPLEMENTAL INFORMATION section includes a description of the facility and its response command structure, as well as environmental data and response equipment considerations. iv. The BEST AVAILABLE TECHNOLOGY section demonstrates that the facility complies with the State of Alaska requirements of 18 AAC 75.425(e)(4) and 18 AAC 75.445(k). 2. A Marine Transfer Operations Manual which demonstrates that the vessel/barge transfer procedures and dock equipment comply with Coast Guard requirements. The Manual must be approved by the Coast Guard. It confirms that the operator’s marine transfer procedures and equipment comply with the requirements listed in 33 CFR, Parts 154 and 156. The manual format and content requirements are listed in 33 CFR, Part 154, Subpart B, which lists 23 items that must be addressed. Two copies of the manual are to be submitted to the Coast Guard. Upon approval, one copy of the manual will be returned marked "Examined by the Coast Guard." Copies of the manual are to be maintained at the facility so that they are, “current, available for examination by the USCG Captain of the Port (COTP) and readily available for each facility person in charge while conducting an oil transfer operation”. 3. A Spill Prevention Control and Countermeasure Plan (SPCC) that is certified by a licensed engineer (P.E.) and confirms that the facility complies with the EPA spill prevention and operating requirements. The oil pollution prevention regulations require the preparation of a SPCC for all facilities with aboveground oil storage of more than 1,320 gallons and which, due to their location, could reasonably be expected to discharge oil in harmful quantities into or upon the navigable waters or adjoining shorelines of the United States. The SPCC Plan must be carefully thought out and prepared in accordance with good engineering practices to prevent and mitigate damage to the environment from oil spills. It must address all oil “containers” / tanks with a capacity of 55 gallons or more. The Plan must be certified by a licensed Professional Engineer and must also have the full approval of management at a level with authority to commit the necessary resources. Facility management is to review and evaluate the Plan at least every five years and update it whenever there is a change in facility design, construction, operation, or maintenance that could materially affect the potential for discharge to navigable water. EPA regulations further stipulate, in 40 CFR, Part 112.4, that a written report must be submitted to the Regional Director of the EPA when a facility has either one spill greater than 1,000 gallons, or two spills in excess of 42 gallons in a 12-month period that enter navigable waters. The SPCC Plan need not be submitted to, or approved by, the EPA, but must be maintained at the facility and available for agency inspection. 6 Bethel, Alaska Combustion Turbine Power Plant Conceptual Design Report 4. A Fire Marshal review requires submittal of a complete set of construction documents to the State of Alaska, Department of Public Safety, Division of Fire Prevention (Fire Marshal) for plan review and approval. The State Fire Marshall then issues a Plan Review Certificate to verify compliance with adopted Building, Fire and Life Safety codes. Final stamped drawings must be submitted along with the application fee for project review. Anticipate a minimum of one month before comments may be received from the Fire Marshall. 5. A U.S. Army Corps of Engineers Section 10, 33 U.S.C. 403 permit is required prior to the accomplishment of any work in, over, or under navigable waters of the United States, or which affects the course, location, condition or capacity of such waters. The Kuskokwim River is defined as a navigable waterway. Typical activities requiring Section 10 permits include: i. Construction of piers, wharves, breakwaters, bulkheads, jetties, weirs, dolphins, marinas, ramps, floats, intake structures and cable or pipeline crossings. ii. Work such as dredging or disposal of dredged material. iii. Excavation, filling, or other modifications to navigable waters of the U.S. 6. The National Marine Fisheries Service (NMFS), U.S. Fish and Wildlife Service and Alaska Department of Fish and Game or Department of Natural Resources will review the 403 permit to determine if there is an impact on the anadromous fish population in the Kuskokwim River. They may place restrictions on construction timing or methods. The U.S. Fish and Wildlife Service will also determine if the project impacts any endangered species. 7. A U.S. Army Corps of Engineers wetlands permit is required to place fill material on existing soils before construction begins. Section 404 of the Clean Water Act requires approval prior to discharging dredged or fill material into the waters of the United States, including wetlands. Wetlands include tundra, permafrost areas, swamps, marshes, bogs and similar areas. Typical activities requiring Section 404 permits include: i. Discharging fill or dredged material in waters of the U.S., including wetlands. ii. Site development fill for residential, commercial, or recreational developments. iii. Construction of revetments, groins, breakwaters, levees, dams, dikes and weirs. iv. Placement of riprap and road fills. 8. Operators of construction projects disturbing five acres or more must develop a Storm Water Pollution Prevention Plan (SWPPP) and submit the SWPPP as well as a Notice of Intent (NOI) to the EPA and ADEC for review prior to the start of construction activity. 7 Bethel, Alaska Combustion Turbine Power Plant Conceptual Design Report 9. The Bethel City Planning Department will review the Fire Marshall, AK DEC and Army Corps of Engineers permits and may add other requirements to the project, such as access and setback from property lines. The City of Bethel also has a General Permit issued by the Corps of Engineers. 10. A review by the Federal Aviation Administration (FAA). Power plants located less than 5 miles from a runway or airport, such as this project, should complete Form 7460-1, “Notice of Proposed Construction or Alteration” and submit all necessary elevation and height of structure information to the FAA (Alaska Region) prior to construction. The FAA reviews the power plant and determines whether the construction or project will present a hazard to air traffic in the vicinity. The FAA has typically provided project determinations within one week of the completed form submittal. 11. A review by the State Historic Preservation Office (SHPO) is required, under Section 106 of the National Historic Preservation Act, for any State or Federally funded project that has the potential of disturbing cultural resources. XIII. BUDGET COST ESTIMATES Budget Construction Cost Estimates have been prepared for the construction of the proposed bulk fuel facility, module foundations, intermediate fuel tank, raw water tank, access roads, pipelines and fuel barge off-loading dock. The estimates were developed based on historical pricing for similar work in Bethel with a 6.5% overhead for profit, bonding and insurance. A construction contingency of 15% has been factored into the estimates. A freight rate of $0.20 per pound to Bethel was provided by Bettine, LLC. These estimates do not include costs for the combustion turbine modules or power generation equipment, their transportation to Bethel, nor their mobilization to the site and setup. The estimates do not include the costs of land purchase, leases or right of ways. The Budget Construction Cost Estimates are summarized below. A breakdown of the construction costs is included in Appendix E. y Estimated Construction Cost (Power Plant Facility) $8,330,000 y Estimated Construction Cost (Bulk Fuel Facility) $25,000,000 y Estimated Construction Cost (Cooling Lake Option) $3,050,000 Cost estimates have also been prepared for the design, permitting and construction management for the site development, proposed bulk fuel facility, module foundations, intermediate fuel tank, raw water tank, access roads, pipelines and fuel barge offloading dock. These estimates do not include costs for the facility design, combustion turbine modules, power generation equipment, land acquisition or leases. The estimates were developed based on historical pricing for similar work in Bethel. The design, permitting and project management cost estimates are summarized below. 8 Bethel, Alaska Combustion Turbine Power Plant Conceptual Design Report 9 Power Plant & Bulk Fuel Facilities y Estimated Design Cost $700,000 y Estimated Permitting Cost $50,000 y Estimated Construction Management Cost $350,000 Cooling Lake Option y Estimated Design Cost $100,000 y Estimated Permitting Cost $25,000 y Estimated Project Management Cost $100,000 XIV. REFERENCES 1 Peratrovich, Nottingham and Drage, Inc., Donlin Creek Mine Late Stage Evaluation Study, prepared for Placer Dome Technical Services, Ltd., March 1, 1999. APPENDIX A SITE LOCATION APPENDIX B FLOOD HAZARD DATA Bethel | City Office: (907) 543-2047 | Revised: March 2000 STATUS 2nd class city LAST FLOOD EVENT 1991 POPULATION 5,471 FLOOD CAUSE BUILDINGS ELEVATION RIVER SYSTEM Kuskokwim River FLOOD OF RECORD COASTAL AREA none FLOOD CAUSE ELEVATION NFIP STATUS participating WORST FLOOD EVENT 1988 FLOODPLAIN REPORT FLOOD CAUSE FLOOD INSURANCE STUDY yes FLOOD GAUGE no Comments: Published Flood Insurance Rate Maps (FIRM) show detailed flood information. FIRM can be purchased from Federal Emergency Management Agency (FEMA) at FEMA Maps Flood Map Distribution Center 6730 (A–G) Santa Barbara Court Baltimore, MD 21227-5623 Toll free: 800 -358-9616 FIRM Panels 0008 B, 0009 B, 0012 B, 0013 B were corrected on 3 June 1994 by FEMA to correct the datum reference from the NGVD to MLLW. The Flood Insurance Rate Map (FIRM), revised February 15, 1985, for the community indicates a 100-year, or Base Flood Elevation (BFE) of 17 ft MLLW. Pagemaster | (907) 753-2622 Floodplain Manager | (907) 753-2610 Page 1 of 1Flood Hazard Data: Bethel 6/7/2003http://www.poa.usace.army.mil/en/cw/fld_haz/bethel.htm APPENDIX C CONCEPTUAL DESIGN DRAWINGS APPENDIX D HEAT REQUIREMENT SUMMARIES Project Description : Bethel Power Plant Project Number : 03-014 Analysis by : MKH Heat Requirement: Input:Bulk Fuel Tanks, 120' Dia x 40' High Diameter=120 ft Height=40 ft V (Volume)=3200000 gal D (Density)=7.17 lb/gal Specific Heat=0.43 BTU/lb*F T (Maintained)=20 F R=16.84 Hr*Ft^2*F/BTU (6" insulation, 15 mph wind) Surface Area per Tank, A=26389 sq ft Time=24 Hours Calcs:Heat Loss per Tank = Q=(Delta T)*A/R Data from AK Engineering Design Information System (1949 to 2001) Heat Loss (Q)Heat Loss (Q)Heat Loss (Q) Month Avg Min T Delta T No/Days (BTU/Hr)(BTU/Day)BTU/Month Jan 0.8 19.2 31 30088 722104 22385213 Feb 0 20 28 31341 752191 21061357 Mar 5.2 14.8 31 23193 556622 17255269 Apr 16.9 3.1 30 4858 116590 3497690 May 32.3 0 31 0 0 0 Jun 42.8 0 30 0 0 0 Jul 47.9 0 31 0 0 0 Aug 46.5 0 31 0 0 0 Sep 38.4 0 30 0 0 0 Oct 24 0 31 0 0 0 Nov 11.6 8.4 30 13163 315920 9477610 Dec 0.6 19.4 31 30401 729626 22618393 Total 96295531 BTU/year per tank Project Description : Bethel Power Plant Project Number : 03-014 Analysis by : MKH Heat Requirement: Input:Intermediate Fuel Tank, 30' Dia x 20' High Diameter=30 ft Height=20 ft V (Volume)=100000 gal D (Density)=7.17 lb/gal Specific Heat=0.43 BTU/lb*F Ti (Initial)=20 F T (Maintained)=70 F R=16.84 Hr*Ft^2*F/BTU (6" insulation, 15 mph wind) Surface Area per Tank, A=2592 sq ft Time=24 Hours Calcs:Heat to raise temp from 20F to 70F, Q=(V*D)*(Delta T)*Specific Heat Q=15423793 BTU per 100,000 gallons Calcs:Heat Loss per Tank = Q=(Delta T)*A/R Data from AK Engineering Design Information System (1949 to 2001) Heat Loss (Q)Heat Loss (Q)Heat Loss (Q) Month Avg Min T Delta T No/Days (BTU/Hr)(BTU/Day)BTU/Month Jan 0.8 69.2 31 10650 255611 7923932 Feb 0 70 28 10774 258566 7239841 Mar 5.2 64.8 31 9973 239358 7420099 Apr 16.9 53.1 30 8173 196141 5884218 May 32.3 37.7 31 5802 139256 4316940 Jun 42.8 27.2 30 4186 100471 3014138 Jul 47.9 22.1 31 3401 81633 2530620 Aug 46.5 23.5 31 3617 86804 2690931 Sep 38.4 31.6 30 4863 116724 3501719 Oct 24 46 31 7080 169915 5267354 Nov 11.6 58.4 30 8988 215718 6471532 Dec 0.6 69.4 31 10681 256349 7946834 Total 64208158 BTU/year Project Description : Bethel Power Plant Project Number : 03-014 Analysis by : MKH Heat Requirement: Input:Raw Water Tank, 55' Dia x 40' High Diameter=55 ft Height=40 ft V (Volume)=700000 gal D (Density)=8.34 lb/gal Specific Heat=1.0 BTU/lb*F T (Maintained)=70 F R=16.84 Hr*Ft^2*F/BTU (6" insulation, 15 mph wind) Surface Area per Tank, A=9287 sq ft Time=24 Hours Calcs:Heat Loss per Tank = Q=(Delta T)*A/R Data from AK Engineering Design Information System (1949 to 2001) Heat Loss (Q)Heat Loss (Q)Heat Loss (Q) Month Avg Min T Delta T No/Days (BTU/Hr)(BTU/Day)BTU/Month Jan 0.8 69.2 31 38164 915938 28394091 Feb 0 70 28 38605 926527 25942765 Mar 5.2 64.8 31 35737 857700 26588687 Apr 16.9 53.1 30 29285 702837 21085114 May 32.3 37.7 31 20792 499001 15469035 Jun 42.8 27.2 30 0 0 0 Jul 47.9 22.1 31 0 0 0 Aug 46.5 23.5 31 0 0 0 Sep 38.4 31.6 30 0 0 0 Oct 24 46 31 25369 608861 18874685 Nov 11.6 58.4 30 32208 772988 23189655 Dec 0.6 69.4 31 38274 918586 28476155 Total 188020187 BTU/year APPENDIX E CONSTRUCTION BUDGET COST ESTIMATES BUDGET COST ESTIMATE Power Plant Feasibility Study Bethel, Alaska MATERIAL UNIT MATL FREIGHT No. ITEM QTY UNITS COST TOTAL $0.20/lb TOTAL Mobilization/Demobilization ……………………………………………………………………………………………………………………………………100,000 1 Mob/DeMob 1 SUM 100,000 100,000 100,000 Earthworks ……………………………...………………………………………………………………………………………………………………………3,066,000 2 Module & Tank Pad Sand Fill 30,000 CY 15 450,000 450,000 3 Module & Tank Pad Gravel Surface Course 8" 5,200 CY 80 416,000 416,000 4 Access Roads 10,000 LF 220 2,200,000 2,200,000 Geotextile……………………………………………………………...…………………………………………………………………………………………58,200 5 Module & Tank Pad Non-Woven Geotextile 4,000 SF 0.10 400 800 1,200 6 Module & Tank Pad Woven Geotextile 190,000 SF 0.10 19,000 38,000 57,000 Thermal Protection ………………………………………………….…………………………………………………………………………………………251,700 7 Intermediate & Water Tanks Rigid Insulation 95,000 BF 1.00 95,000 9,500 104,500 8 Int. & Water Tanks Flat Loop Thermo Syphon w/ Hybrid Condensor 20 EA 7,000 140,000 7,200 147,200 Module Foundation………………………………………………………………………………………………………………………………………………1,374,500 9 Thermo Helix-Pile w/ Hybrid Condensor 150 EA 5,500.00 825,000 84,000 909,000 10 Pile Installation (35 Foot Embedment)150 EA 1,600.00 240,000 240,000 11 W18 x 55 Beams 5,500 LF 30 165,000 60,500 225,500 Secondary Containment ………………………………………………………………………………………………………………………………………63,201 12 Intermediate Tank Primary Liner 5,700 SF 4.00 22,800 1,140 23,940 13 Intermediate Tank Dike Posts 40 EA 70 2,800 1,220 4,020 14 Intermediate Tank Dike 6x6 Wall Timbers 2,200 LF 11 24,200 2,942 27,142 15 Sheet Metal Covers 300 LF 22 6,600 1,500 8,100 Tank Foundations ………………………………………………………………………………………………………………………………………………61,440 16 Intermediate Tank (30' Dia) Foundation 20 CY 1,000 20,453 2,209 22,662 17 Water Tank (55' Dia) Foundation 35 CY 1,000 34,998 3,780 38,777 Tanks ……………………………………………...……………………………………………………………………………………………………………520,400 18 Intermediate Tank (100,000 gal Insulated Tank, Erected) 1 EA 100,000 100,000 100,000 19 Intermediate Tank Appurtenances 1 LS 10,000 10,000 200 10,200 20 Raw Water Tank (700,000 gal Insulated Tank, Erected) 1 EA 400,000 400,000 400,000 21 Raw Water Tank Appurtenances 1 LS 10,000 10,000 200 10,200 Fuel & Raw Water Pipelines ………………………………..………………………………..…………………………………………………………………128,000 22 4" x 10" Insulated Sch 40 Pipe (Issue) 350 LF 65 22,750 755 23,505 23 Coated 2" Sch 40 Pipe (Water Draw) 50 LF 15 750 37 787 24 4" Plug Valve 5 EA 1,750 8,750 95 8,845 25 4" Check Valve 2 EA 360 720 24 744 26 4" Gate Valve (Water Tank) 1 EA 495 495 22 517 27 3" Ball Valve 2 EA 400 800 20 820 28 2" Ball Valve 6 EA 200 1,200 20 1,220 29 Fill Limiting Valve 2 EA 965 1,930 12 1,942 30 Pipe Supports 20 EA 300 6,000 800 6,800 31 2" X 8" Insulated HDPE Pipe (Glycol) 1,400 LF 55 77,000 1,120 78,120 32 2" x 8" Half Shells (HDPE Joints) 30 EA 40 1,200 900 2,100 33 2" x 8" Elbows 10 EA 250 2,500 100 2,600 Dock……………………………………………………………………………………………………………………………………………………………1,045,350 34 Fuel Dock 188 LF 5,500 1,034,000 1,034,000 35 Marine Header Containment 1 LS 7,500 7,500 1,000 8,500 36 Marine Header Assmbly 1 EA 2,500 2,500 350 2,850 Security Fencing ……………………………...………………………….……………………………………………………………………………………29,700 37 Chain Link Fence 1,200 LF 15 18,000 3,600 21,600 38 Vehicle Gate 2 EA 4,000 8,000 100 8,100 Electrical ………………………………………………………………………………………………………………………………………………………103,500 39 Electrical Controls 1 SUM 50,000 50,000 1,000 51,000 40 Lighting 1 SUM 50,000 50000 2500 52,500 Sub-Total:6,801,991 Contingency @ 15%1,020,299 Overhead & Profit @ 5%391,115 Bonding and Insurance @ 1.5%117,334 Total: 8,330,739 Combustion Turbine Power Plant BUDGET COST ESTIMATE Power Plant Feasibility Study Bethel, Alaska MATERIAL UNIT MATL FREIGHT No. ITEM QTY UNITS COST TOTAL $0.20/lb TOTAL Mobilization/Demobilization ……………………………………………………………………………………………………………………………100,000 1 Mob/DeMob 1 SUM 100,000 100,000 100,000 Earthworks ……………………………...………………………………………………………………………………………………………………1,680,000 2 Tank Farm Sand Fill 80,000 CY 15 1,200,000 1,200,000 3 Tank Farm Gravel Surface Course 8" 6,000 CY 80 480,000 480,000 Geotextile……………………………………………………………...…………………………………………………………………………………142,500 4 Tank Farm Non-Woven Geotextile 125,000 SF 0.10 12,500 25,000 37,500 5 Tank Farm Woven Geotextile 350,000 SF 0.10 35,000 70,000 105,000 Thermal Protection ………………………………………………….…………………………………………………………………………………2,710,000 6 Tank Farm Rigid Insulation 1,460,000 BF 1.00 1,460,000 146,000 1,606,000 7 Tank Farm Flat Loop Thermo Syphon w/ Hybrid Condensor 150 EA 7,000 1,050,000 54,000 1,104,000 Secondary Containment ………………………………………………………………………………………………………………………………1,113,000 8 Tank Farm Primary Liner 265,000 SF 4.00 1,060,000 53,000 1,113,000 Tank Foundations ………………………………………………………………………………………………………………………………………620,480 9 Tank Farm (120' Dia) Foundations 560 CY 1,000 560,000 60,480 620,480 Tanks ……………………………………………...……………………………………………………………………………………………………12,081,600 10 Tank Farm (3.2 mil gal Insulated Tank, Erected) 8 EA 1,500,000 12,000,000 12,000,000 11 Tank Farm Appurtenances 8 LS 10,000 80,000 1,600 81,600 Tank Farm Walkways …………………………………………………………..………………………………………………………………………353,790 12 Walkway Supports 50 EA 2,200 110,000 12,000 122,000 13 Steel Catwalk 730 LF 175 127,750 43,800 171,550 14 Coating 15000 SF 4.00 60,000 240 60,240 Pipelines and Valves………………………………..………………………………..…………………………………………………………………933,310 15 Coated 8" Sch 40 Pipe (Fill) 4,200 LF 70 294,000 23,999 317,999 16 4" x 10" Insulated Sch 40 Pipe (Issue) 2,100 LF 75 157,500 4,532 162,032 17 Coated 2" Sch 40 Pipe (Water Draw) 1,000 LF 15 15,000 730 15,730 18 8" Plug Valve 9 EA 3,280 29,520 666 30,186 19 8" Gate Valve 1 EA 1,255 1,255 62 1,317 20 8" Check Valve 1 EA 1,190 1,190 55 1,245 21 4" Plug Valve 16 EA 1,750 28,000 304 28,304 22 4" Check Valve 8 EA 360 2,880 96 2,976 23 3" Ball Valve 8 EA 400 3,200 80 3,280 24 2" Ball Valve 24 EA 200 4,800 82 4,882 25 Pipe Supports 375 EA 300 112,500 15,000 127,500 26 Pig Catcher 1 EA 7,000 7,000 2,500 9,500 27 Cathodic Protection 1 EA 50,000 50,000 50,000 28 2" X 8" Insulated HDPE Pipe (Glycol) 3,000 LF 55 165,000 2,400 167,400 29 2" x 8" Half Shells (HDPE Joints) 60 EA 40 2,400 1,800 4,200 30 2" x 8" Elbows (HDPE) 26 EA 250 6,500 260 6,760 Pumphouse Mechanical Systems ………………………….……………………………………..……………………………………………………86,996 31 4" Sch 40 Pipe 50 LF 60 3,000 286 3,286 32 4" Plug Valve 2 EA 1,750 3,500 38 3,538 33 4" Ball Valve 2 EA 550 1,100 30 1,130 34 6" Butterfly Valve 2 EA 700 1,400 60 1,460 35 3" Sch 40 Pipe 50 LF 50 2,500 150 2,650 36 3" Ball Valve 2 EA 400 800 20 820 37 3" Check Valve 2 EA 350 700 12 712 38 30 hp Pumps (Fuel Transfer)2 EA 20,000 40,000 120 40,120 39 Filter/Separator 2 EA 10,000 20,000 40 20,040 40 Accumulators 2 EA 1,500 3,000 40 3,040 41 Misc Accessories 1 LS 10,000 10,000 200 10,200 Pumphouse Building ……………………………………………..…………………….………………………………………………………………90,000 42 20'x30' Building 600 SF 150 90,000 90,000 Security Fencing ……………………………...………………………….………………………………………………………………………………58,100 43 Chain Link Fence 3,000 LF 15 45,000 9,000 54,000 44 Vehicle Gate 1 EA 4,000 4,000 100 4,100 Electrical ………………………………………………………………………………………………………………………………………………203,500 45 Electrical Controls 1 SUM 100,000 100,000 1,000 101,000 46 Lighting 1 SUM 100,000 100000 2500 102,500 Sub-Total:20,173,276 Contingency @ 15%3,025,991 Overhead & Profit @ 5%1,159,963 Bonding and Insurance @ 1.5%347,989 Total: 24,707,220 25 mil Gal Bulk Fuel Tank Farm BUDGET COST ESTIMATEPower Plant Feasibility StudyBethel, AlaskaMATERIALUNIT MATL FREIGHTNo. ITEM QTY UNITSCOST TOTAL$0.20/lb TOTALEarthworks ……………………………...………………………………………………………………………………………………………………………396,0004 Access Roads 1,800 LF 220 396,000 396,000Cooling Lake System……………………………………………………………………………………………………………………………………………2,015,49434 24" O.D. Pipe (Installed) 7,400 LF 38 282,088 139,120 421,20834 Pipe Supports (60' Centers) 135 EA 7,800 1,053,000 86,400 1,139,40035 24" Gate Valve 3 EA 7,150 21,450 1,776 23,22636 Building (16 x 20) 320 SF 150 48,000 4,800 52,80036 Driven 8" Steel Piling for Building (Installed) 6 EA 3,750.00 22,500 3,360 25,86037 350 HP, 15,000 GPM Pump 2 EA 125,000 250,000 3,000 253,00038 Misc Accessories 1 LS 50,000 50,000 50,00039 Discharge Structure 1 EA 25,000 25,000 25,00040 Intake Structure 1 EA 25,000 25,000 25,000Security Fencing ……………………………...………………………….……………………………………………………………………………………167,90044 Chain Link Fence 9,100 LF 15 136,500 27,300 163,80045 Vehicle Gate 1 EA 4,000 4,000 100 4,100Electrical ………………………………………………………………………………………………………………………………………………………153,50046 Electrical Controls 1 LS 100,000 100,000 1,000 101,00047 Lighting 1 LS 50,000 50000 2500 52,500Delete Cooling Tower …………………………………………………………………………………………………………………………………………-245,12016 Cooling Tower Thermo Helix-Piles -32 EA 7,100 -227,200 -17,920 -245,120Sub-Total:2,487,774Contingency @ 15%373,166Overhead & Profit @ 5%143,047Bonding and Insurance @ 1.5%42,914Total: 3,046,901Cooling Lake Option