Pit¢@R'N E-235 VOL. 29 TRANSMISSION SYSTEM EXPANSION PROJECT NO.9 ( 41994 - 1998 ) VOLUME I DETAILED ECONOMIC ANALYSIS ELECTRICITY GENERATING AUTHORITY OF THAILAND REPORT NO. 21200-3809 SYSTEM PIANNING DEPARTMENT MARCH 1995 TRANSMISSION SYSTEM EXPANSION PROJECT NO.9 (1994-1998) VOLUME II DETAILED ECONOMIC ANALYSIS REPORT NO. 21200-3809 MARCH 1995 Prepared By Concurred By Transmission System Planning DivisionemPlanino_ (Prakob Dhienhirunya) Assistant Director, System Planning Department-Transmission Submitted By: Approved By: (Prutichai Chonglertvanichkul) (Siridat Glankwahmdee) Chief, Transmission System Director, System Planning Department Planning Division ABBREVIATIONS ACSR - Aluminum Conductor Steel Reinforced cct-klm - Circuit-Kilometer DC/ST - Double Circuit/Steel Tower DEDP - Department of Energy Development and Promotion DR. - Discount Rate EDR. - Equalized Discount Rate EGAT - Electricity Generating Authority of Thailand FBC - Fluidized Bed Combustion F.C. - Foreign Currency IDC - Interest During Construction L.C. - Local Currency MTHB - Million Baht MEA - Metropolitan Electricity Authority MCM - Thousand Circular Mils MVA - Megavolt-ampare MVAr - Megavolt-ampere Reactive MW - Megawatt NEPC - National Energy Policy Council NEPO - National Energy Policy Office NESDB - National Economic and Social Development Board NESDP - National Economic and Social Development Plan NIDA - National Institute of Development Administration PDP - Power Development Plan PEA - Provincial Electricity Authority P.V. - Present Value TDRI - Thailand Development Research Institute THB - Baht USD - US Dollar VAT - Value Added Tax W/O - Without TABLE OF CONTENTS Page 1. INTRODUCTION I 2. SUMMARY AND RECOMMENDATION 2 3. CRITERIA AND ASSUMPTIONS FOR ECONOMIC ANALYSIS OF SUBPROJECTS 7 4. DETAILED ECONOMIC ANALYSIS OF EACH SUBPROJECT 11 5T FNANCTAT. TJTIFICATION OF TS-9 PROJECT BASED ON TIME SLICE APPROACH 139 APPENDIXES 1. Load Flow Diagrams of the Proposed Plan of each Subproject 147 2. Full Name and Abbreviation ot Substation 217 tKOGRIVEn 21 I S NV- E ENIR.L-OflEN TI jI SN/-EER91S EEIALNITEN II LINE at Exstn Subsotiost lU *** I +o a{ @s§*vt f @ Eqrmn inttO~n INO OCAT_IOn HA ^; *¢gP a 9 ftY \N b*<~~~~~~~~~RGIN MicioeosSse Epnin ;- .-@ -- X~~ ~ ~~~ 6 W .E\ REGIN 2M ....... .T I h1CN ...... ... . io , W. .El-N N ~ ~ ~ ~~ N N Ir II ^ t MYCZT A^ W)L l tl * O O ~~~~~~~~~~~~~~~-. ~~ tl-s ---MM v _- z_ra i3 ~ ~ ~ ~ ~ ~ ~ ~~~~~GL Addi joTfHAILAND t t1l r> 'EEYlc ElRAICATHlll O FII at Eislig Sbstoionst~ep\\\x t ra"l rwcTxctorEz sclenOF NAI i)~~~ ~~~ Recie oe orpn. to t< > 6 I' EqlprTenl nstolatios ,_ £ , \ LtOC^IOW. (H)Misellneos yslm Epanion 0m;r i . a_ at Exstn Subs ,q : tt~Iw' '- ir i. INTRODUCT Report Volume II (Detailed Economic Analysis) presents details of the economic and financial justifications of the Transmission System Expansion Project No.9 (TS.9). The project comprises 24 subprojects for transmission line and substation expansion and reinforcement, addition of new transformers, reactive power supply and miscellaneous equipments including related communication system. The scope and purpose of each subproject are described in Volume I (Main Report). The economic justification of each subproject is performed based on the least cost solution. Each proposed subproject is the least cost alternative among other alternatives which serve the same objectives. Since TS.9 Project is an integral part of EGAT's overall development program, the economic justification of the whole project package in terms of economic and financial internal rate of return (EIRR and FIRR) has been therefore evaluated based on the time-slice study of EGAT'is overall llower Development Plan (PDP) for the period covered by the Project. -1- 2. SUMMARY AND RECOMMENDATION 2.1 Economic Analysis of each subproject is evaluated based on the least cost solution. The proposed subproject is selected from at least three other possible altematives which can satisfy the same objiectives. The -resent value of te t0o Cost of each possible alternative which include investment cost, operation and maintenance cost and the cost of system losses of each alternative, is calculated and compared. System losses of each subproject and its alternatives are obtained from the power flow studies of the whole EGAT's power system. The economic viability of each subproject is presented in terms of the Net Present Value (NPV) and benefit/cost ratio (B/C ratio) at 10 % discount rate and equalized discount Rate (EDR). 2.2 Results of economic analysis w\hich has indicated that all proposed su'bprojects in TS.9 Project are the least cost alternative, are summarized in Table 2.1. 2.3 The four years time slice study oflGA(iT'l's overall Power Development Plan (PDP) 1995-1998 is performed to represent the economic and financial rate of return (EIRR and FIRR) of the whole package of TS.9 project. The result ol the study shows the EIRR and FIRR of the Project is 11 .77 and 4.51 percent respectively. 2.4 It can be concluded from the analyses that the TS.9 Project is the least cost solution for EGAT's power system reinforcement and expansion in each subproject area and the whole package of TS.9 project for the period of 1995-1998 is also economically viable. -2- Table 2.1 Summary Result of Economic Analysis in TS. 9 No. Fiscal Description Net P.V. R/r Equelized Year @10 %DR.1 Ratio Discount __(MTHB) Rate CENTRAL REGION 1. 230/115 KV BAN PONG 2 - BAN PONG I - NAKHON CHAISI - SAM PHRAN 2 LINES AND SUBSTATIONS a. 1998 - Reconstruction ot115kV Ban Pong 2-Ban Pong 1-Nakhon Chalsl-Samn Phran 2to 2301115 kV DC/ST 2x1.272 MCM ACSR, 43 km 2006 - Installation o0 230/115 kV 1x200 MVA Transtormer at Ban Pong 2 Suostation - Construction of 230 kV Ban Pong 2-Sal Noi DC/ST 1,272 MCM ACSR, 53.6 km - Reconstruction ot 230 kV Ratchaburi 2-Ban Pon 2 to DC/ST 2x1272 MCM ACSR, 41.7 km - --- Base Ca se b. 1998 -Reconstructionot115kVBanPong2-(BanPongl)-NakhonCharsito 230kVDC/ST 2xi ,272 MCM ACSR, 38 km -FReconstruction oll 15kV Nakhon Chaisi-Sam Phran 2to 115/230 kVDC/ST 2x1,272 MOM ACSR, Skm - Installaton of 230/115 kV 3x200 MVA Transtormer at Nakhon Chaisi Sur.station 2006 - Construction of 230 kV Ban Pong 2 - Sai Noi DC/ST 1.272 MCM ACSR. 53.6 km - Reconstruction o 230 kV Ratchaburi 2-Ban Pon 2 to DC/ST 2xt 272 MCM ACSR, 41.7 km 88.56 1.0026 N.A. C. 1998 - Construction of 230 kV Sai Noi-Nakhon Chaisi DC/ST 2x1.272 MCM ACSR. 35 km and -Reconstnjctlono 115kV NakhonChaisi-Samphran2 to 1151230 kV DC/ST 2x1.272 MOM ACSR. Skm -Installation of 230/115 kV 2x200 MVA Transformer at Nakhon Chaisi Suostation 1999 - Construction of 230kV Ban Pong 2-Sal Nol DC/ST 1,272 MCM ACSR, 53.6 km 2006 - Reconstruction ot 230 kV Ratchaburi 2 -Ban Pong 2 to DC/ST 2x2 272 MCM ACSR, 41.7 km Installation ot 230/115 kV 1x200 MVA Transto rmer at Nakhon Chaisi Sibstation 501.16 1.0146 > 150.0 S6 2. 1S5 KVSBOWIN -BAN BUNG LUNEAND SUBSTATIONS a. 1997 - Construction ot tISkV Bo Win-Ban Bung DC/ST 2x795 MOM ACSR. 27 kmn 2001 - Installation ot230/115 kV 1x200 MVA Transformer at Bo Win Substation -Bae Case b. 1997 - Reconstruction of 11 SkV Ao Phai-Si Racha-Ban Bung to Ao Phal-Ban Bung DC/ST 2x795 MCM ACSR, 38 km with detour line Si Racha-Ban Bung 33 km 2004 - Installation ot 230/115kV 1 x200 MVA Transtormer at Bo Win Substation -Installatbon ot 230/115 kV 1 x200 MVA Transtormer at Ao Phai Substation 90.02 1.0036 > 150.0 c, 1997 - Construction of 230 kV Bo Win-Ban Bung DC/ST 1,272 MCM ACSR, 27 km - lnstallaton of 230/115 kV 2x200 MVA transtormer at Ban BtSng Substation ___ 2004 - Installation of 230/1 1 5 kV i x200 MVA Transtormer at Bo Win Substation 243.37 1.0096 >150.0% 3. 115 KVTHAWUNG SUBSTATION AND LINES CONNECTION a. 1898 -Construction ot The Wung Switching Substation at intersection point of 11SkV Lop Buril -Sing Burl and Ang Thong 2-Lop Bun 2 line. - Installation of 1 x200 MVA Transformer at Ang Thong I Substation 2002 - Construction of 115 kV Tha Wung-Lop Burl 1 SC on DC/ST. 795 MCM ACSR, 13 kmBase Case … b. 1998 -Reconstruction ot115 kV Ang Thong 1-Sing Burto be DC/ST 2x795 MOM ACS, 234km - Installation of 1 x200 MVA Transformer at Ang Thong I Substation - Installation o0 44.08 and 22.04 MVAr Capacitor Bank at Sing Burn and Lop Buri I Substation respectrtely. 2002 -Construction ot15WkV Sing Burl-Lop Buri 1 SC on DC/ST, 795 MCM ACSR, 27 km 20.76 1.0001 N.A. c. 1 998 - Tenmination of one cctot 230 kV Tha Tako-Ang Thong 1 to Sing Buri -Installation of 1x200 MVA Transtormer at Sing Buri Substation 2002 -Construction o115kV Sing Buri-Lop Buri SCon DC/ST. 795 MCM ACSR, 27 km 2006 -Installation ot 1x200 MVA Transformer atAng Thong 1 Substation 3_ 32.30 1.0016 | N.A. d. 1998 -TerminationofonecCtof23okVThaTako-Thalan3anc tl5kV SngBuri- LopBur 1 toThaWung - Installation of 1x200 MVA Transformer at Tha Wung 2002 - Construction of 115 kV Tha Wung - Lop Burn I SC on DC/ST. 795 MCM ACSR. 13 km 2003 - Installation o12x200 MvATranstormer at AnRThong)l Srstato-__-| 44.866 1.0022 N.A. 4. 115 KV THALAN 3 - SARABURI 1 LINE AND SUBSTATIONS a. t998 -Reconstruction of I 15 kV Thalan 1 -Saraburi I to Thalan 3-Saraburi I DC/ST 795 MCM ACSR. I1t5 km (with detour line) and 115 kV Thalan I-Thalan 3 SC on DC/ST79S5 MCM ACSR, 5 km … - - _--Base Case----- b. t998 -Reconstruction ot I1 t kV Thalan 1 -Saraburi I to DC/ST 795 MCM ACSR.t8 km (with detour line) I - Reconstruction oft Is kV Thalan 1 -Thalan 3 to DC/ST 795 MCM ACSR. 5km 10.03 1.0004| 31.36 % c. 1998 - ConStrUctionof IIskVThalan3-Saraouri I SConDC/ST795MCMACSR. 14kmank d an - Terminaton of 115 kV Thalan I -Saraburi I to Thalan 3 and - Reconstruction of I 15 kV Thalan 1 -Thalan 3 to SC on DC/ST 795 MCM ACSR,5 krn __ 2003 - -Strlnging2rtdcctof115kVThalan3-Saraburi t 795MCMACSR, 14km 10.97 1.0004 | 25.28 % 5. 115:kV RATCHASURI 2 - PHETCHABURI UNE AND SUBSATIONS a. 1998 - Reconstruction of 115 kV Ratchaburi 2-Phetchaburl to DC/ST ix795 MCM ACSR, 53 km | - Installation of 6.04 and 12.08 MVAr Capecitor Bank at Cha-Am and Phetchaburi Substation respectively. … Base Case … b. 1998 - Teminiation of 2nd Cet ot 230 kV Ratchaburl 2-Prachuap Khiri Khan line to Hua Hin 1,272 MCM ACSR. 10 kl 2006 - Construction of 115 kV Ratchaburi 2-Phetchaburi SC on DC/ST 2x795 MCM ACSR, 53 km 12.09 1.0005 12.77 % _ c. 1998 - COnstnrction o0115 IkV Ratchaburi 2-Phetchaburi SCon DC/ST 2_795 MCM ACSR. 53k | 29.12 1.0012 >150.0 % 21 -Ma,-9S 04:19 PM -3- Table 2.1 Summary Result of Economic Analysis in TS. 9 _ _LCPN~T1NUED) ________ No. Fiscal |Description Net P.V. B/C Equaiized Year @10 %DR. Ratio Discount (MTHB) Rate CENTRAL REGION (CONTINUED) S. 115 KV PRACHINBUFRi 2- WATTHANA NAKHON LINE AND SUBSTATIONS a. 1998 - Construction of I 15 kV Prachin Burl 2-Watthana Nakhon SC on DC/ST 2k795 MBCM ACSR, i7 kn - … Base Case … -. *ooe Co,-trtio.. 9. 230;11S kVP,,;ri Bu,, 2r-rrN_ihana Nagirron Sr_ on jCisi 1.272 MOM AcSR. 87 km _lUtt.UU 1 .UU3U >1150. * ! c. 1998 -Construction ot 230 kV Prachi/ni Bu 2-WatthaniaNakghonl SC on DCIST 1.272 MCM ACSR. 07 km - -Instailaton o/230/115 kV1Ix209MVA Trsnslormer at WattiaNathon Substation. 322.14 1.0173 >150.0% NORTHEASTERN REGION 7. 230/115 KV MUKDAHAN 2 SUBSTATION AND 115 KV MUKDAHAN 2 - THAT PHANOM - NAKHON PHANOM UNES. AND SLEBsTATONS a. 1998 - Construction of Mukdahan 2 Substation and - Temirnation oa one cct of 230 kV Savannakhet - Rol Et to Mukdahan 2 SubstatiOn - tnstailation of 230/115 kV 2x200 MVA Transformers at Mukdahan 2 Substation - Constnuction of 115 KV Mukdahan 2 - That Phanom DC/ST 795 MCM ACSR S8 km - Construction of 115 kV That Phanon - Nakhon Phanom SC on DCIST 795 MCM ACSR 59 km 2003 -IInstailaton ot 230/115 kV 1x200 MVA Transformer at Rog Et Substation 2005 - Stringin 2nd cct of t t5 kV That Phanom - Nakrion Phanom 795 MCM ACSR 59 km _ Base Ca se … b. 1 998 - Construction ot NaLkhon Phanom 2 Sutstation and - Terninaton of onre ct of 230 kV Thakhek - Sakon Nakhon 2 to Nakhon Phanom 2 Substation - instailalton ot 230/115 kV 2x200 MVA Transformers at Nakhon Phanom 2 Sutbstation - Constrijetlonf 1115kV Nakhon Phanom 1 -Nakhon Phanom 2 DC/ST 2x795 MCM ACSRl, 13km - Construct/on of 115 kV Nakhon Phanom I -That Phanom DC/ST 795 MCM ACSR. 59 km - Constructionof 1i5kVThatPhanom-Mukdalian SC on DC/ST 795 MCM ACSR., 45km 2001 -InstallatIon of 230/115 kV 1 x200 MVA Transformer at Roi El Substation 2004 -Stringing 2nd cct of 115 kV That Phanom - Mukdahan 795 MCM ACSR 45 km 367.72 1.0230>1 c. 1998 - Construction alt I 5 kV Sakon Nakhon - That Phanom DC/ST 795 MCM ACSR 70 km - Construction of 115 kV That Phanom - Nakhon Phanom SC on DC/ST 795 MCM ACSR 59 km - Consttnction of 115 kV That Phanom - Mukdahan SC on DC/ST 795 MCM ACSR, 45 km 2001 - Installaton of 230/115 kV 1 x200 MVA Transformer at Roi Et Substation 2004 - Stringing 2nd cct 01115 kV That Phanom - Mukdahan 795 MCM ACSR. 45 km 2005 - Stnnging 2nd cct of I I5 kV That Phanom - Nakhon Phanom 795 MGM A9SR. 59 km 263.81 1.0165 31.53% d. 1998 - Construction o t115 kV Sakon Nakhon - Tnat Phanom DC/ST 795 MCM ACSR 70 km - Construction of 115 kV That Phanom - Nakhon Phanom SC on DC/ST 795 MCM ACSR 59 km - ConstrUction o0 115 kV Phon Thong - Mukdanlan SC on DC/ST 795 MCM ACSR, 90 km -Stringing 2nd cct ot115kV Rol Et-Pion Thong 795 MOM ACSR. 45km 2001 - Installation or230/115kV 1x200 MVA Transformer at Rog Et Substation 2004 -Stringing2ndcotofll5kVPhonrThong - Mukdahan 795MCMACSR 90km 2005 -Stringing2ndoctotl115kVThatPhanom-NakhorinPnamm 795MOM.ACSR, 59km 281.971 1.0177 145.89% 1 8. t t15iV UDON 2 - NONG BUA LAM PHU UNE AND SUBSTATIONS a. 1998 - Construction of 115kV Udon Thani 2 - Nong Bua Lam Phu SC on DC/ST 795 MCM ACSR, G1 km 2001 - Construction ot 115 kV Nong Bua Lam Phu - Loeg SC on DC/ST 795 MCM ACSR, 79 km 2005 - Stringing 2nd cct of115 kV Udon Thani 2 - NongBua Lam Phu 795 MCMACSR, 81 km ------…Base Case--…-- b. 1 8 - Construction of 11 SkV Udon Than 2 - Nong Bua Lam Phu DC/ST 795 MCM AC SR. 61 km 2001 - ConstructionofIl5kVNongBuaLamPhu- Leai SConDCIST 79sMCMACSR, 79kmrn 6.04 1.0004| N.A. c. 1998 - Construction ot 230/115 kV Udon Than, 2 - Nong Bua Lam Phu DC/ST 1,272 MCM ACSR, 8I km 2001 -Construction of 115 kV Nong Bua Lam Phu- Loei SO on DC/ST 795 MCM ACSR, 79 km 63.02 1.0040 >150.0%1 9. 15 KV ROI ET- PHAYAKKHAPHUM PHISAI - SURIN UNES AND SLBSTATIONS a. 1998 -Stringing 2nd ot 115 kVRoi Et-Phayakkhaphum Phisai 795 MCM ACSR, 84km and - ConstructIon of 1115 kV Phayakkhaphum Phisai - Surin SC on DC/ST 795 MCM ACSR 80 km i 2003 - Stringing 2nd cot 0/1115 kV Phayakkhaphum Phisai - Surin 795 MCM ACSR 80 km ------Base Case … =_-- b. 1998 - Construction o0 115 kV Si Sa Ket - Surin SC on DC/ST 795 MCM ACSR 951km k - - Stringing 2nd of 115 kV Roi Et - Phayakkhaphum Phisai 795 MCM AC SR 84 km 2003 - Stringing 2nd cct o 115kV Si Sa Ket - Surin 75 MCM ACSR 95km _ 67.15 [ 1.0041 58.57 % c. 1998 - Construction of 115 kV Burram - Surin SC on DC/ST 795 MCM ACSR 47 km -Coonstructionolll5kVPhayakkhphumPhisa,- Suriri SConDC/ST 795MCMACSR. 80km |-Reconstnction ot115kV Nakhon Ratchasima I - Buriram tobe DC/ST 795 MCM ACSR. 110.4km 2003 - Stringing 2nd cot of115 kV Buriram - Surin 795 MCM ACSR. 47km 2006 |-Reconstruction ot115kV Nakhon Ratchasima I - Nakhon Ratchasima 2100 te DCIST 2x795 MCM ACSR 11.7 km _- String 2nd cot 0/115 kV Phayakkhiaphum Phisa,-Surin 795 MOM ACSR. 90km 287.38| 1.0176 50 0 I O. t1SKV CHAIYAPHUM- BAMNET NARONG UNE AND SUBSTATIONS a. 1998 -ConstructIon of 115 kV Chaeyaphum - Bamnet Narong SC on DC/ST 795 MCM ACSR 58 km - Installaeono/ 115-22-11 kV2xS0MVA Transformer at Bamnet Narong Substatlon. B------Base Case----- b. 1998 -Constructionotf 15kVNakhonFRatchasgma2 - Bamnet Narong SC on DC/ST 795 MCM ACSR 85km K | |_______ - Installation of 115-22-11 kV 2xS0 MVA Transformer at Bamnet Naron Substatlon 1 65.38| 1.00901 >150.0%| |c. 1998 i-Installation o0 Gas Turbine Powa Plants at Bamnet Narong 1_ 1,009.561 1.0458 62.81 %;I 21-Mar-95 04109 PM -4- Table 2.1 Summary Result of Economic Analysis in TS. 9 N. Fiscal DeIr jin Iin Not P.V /RC I Eaualized Year , @10 -DR.I Ratio Discount (MTHB) Rate NORTHEASTERN REGION (CONTINUED) I 11. 115 KY UBON RATCHATHANI 2 - KANTHARALAK LINE AND SUBSTATIONS a. 1998 -Construction of 11 SkV Ubon Ratchathani 2 - Kantharalak SC on DC/ST 795 MCM ACSR 55 km -Installaton of 115-22-11 kV2x50 MVA Transformer at KamtharalakSubstation_. Base Case …----- b. 1998 -Construction of 11 5kV SI Sa Ket - Kantharalak SC on DC/ST 795 MCM ACSR 65 km _ -Installaton ot1 15-22-11 kV 2xs0 MVA Transformerat Kantharalak Substation. 27.22 1.0018 >150.0 % _ c. 1998 _ Installaton ot Gas Turbine Power Plants at Kantharelak 449.55 1.02941 83.90 _ 12. 115 KV SURIN - SANGKHA LINE AND SUBSTATIONS a. 1998 - Construction of 1 15 kV Surin - Sangkha SC on DC/ST 795 MCM ACSR 49 km - Installationo '115-22-11 kV2xs5oMVATransrormeratSangqha uLbstation. -_____- Base Cas e …--__ b. 1998 -Construction o1 115 kV Si Sa Ket - Sangkha SC on DC/ST 795 MCM ACSR 74 km - Installatton o 115-22-11 kV 2x5oMVA Transo as n. 92.40 1.0061 >150.0 % c. 1998 -Constrnction of22 kV Surin - Sangkha 2xDC with AVR 185 sq.mm. AAC 66 km and - Installabon of 115-22-11 kV 2xS oMVA Transformer at Sangkha Substation. _ 2000 -Construction f 115 kV Surin-Sha _SC_ojn DC/ST 795 MCM ACSR 49 km 42.95 1.0028 30.63 S SOUTHERN REGION 13. 230:KV NAKHON Si THAMARAT - THUNG SONG - SURAT THANI LINES AND SUBSTATIONS a. 1998 - Reconstruction of 115 kV Nakhon Si Thammarat - Thung Song to 230/1 15 kV DC/ST 1272 MCM ACSR, 54 km - Reconstruction of 15s kV Surat Thani-Thung Song to 230 kV DC/ST 2xr1272 MCM ACSR. 122 km - Installation of 2x200 MVA Transformers at Thung Song Substation. 2003 - Conversion o1 115/230 kV Nakhon Si Thammarat - Thung Bon ire to energized at 230 kV B-----Base Case- b. 1995 - Reconstruction of 115 kV Nakhon Si Thammarat - Thung Song to 230 kV DC/ST 1,272 MCM ACSR. 54 m - Construction of 230 kV Surat Thani - Nakhon Si Thammara DC/ST 2x1272 MCM ACSR 145 km - Installabon of 2x200 MVA Transformers at Thung Song Substation. 2006 - -insfallationof xlooMvATransformerat suraf Than; Substation ___ 569.14 1.0172 107.18 % c. 1998 - Reconstruction of 115kV Nakhon Si Thammarat - Thung Song to 230kV DC/ST 1,272 MCM ACSR, 54km - Construction or230kV Khanom - Nakihon Si Thammarat DC/ST 2x1272 MCM ACSR 98 km - Installatonof2x200MVA Transformers at Thu.o Sonm Sibrgati.n 2006 - Installatonof1x100MVATransformer-atSurat Thani-substatior _ 64.73 1.0020 32.62 j d. 1998 - Reconsttwetion of 115 kV Surat Thani-Thung Song to 230kV DC/ST 2x .272 MCM ACSR, 122 km - Installabon of 2x200 MVA Transtormers at Thung So ng Substation. - Construction of new 230 kV Phattalung Substation and Termination of 230 kV ___________ Nakhon Si Thammarat-Fkhattalung and 230hV Thung Song-Khong Njae to Pnattlung Substation 91.47 > 150.0 9 4. 230 KV KHLONG NGAE - YALA LINES AND SUBSTATIONS a. 1998 -Construction of 230kV Khlong Ngae-Yala DC/ST 1272 MCM ACSR. 120 km I I _-(using existing Hat Yai 2-Ye a PW)and installation of 2x0OOMVA Transformer at Yala Substation.… Base Case…----- b. 1998 -Construction of 230/115 kV Khlong Ngae-Yala DC/ST 1272 MCM ACSR, 120 km (using existing HY2-YL ROW) and installation of t x200 MVA Transformer at Khlong Ngae 2006 - Conversion o1230/115 kV Khlong Ngae-YalaOC/ST 1272 MCM ACSR to be energiZed at 230kV __k _ 108.78 1.0053 41.25 % c. 1998 -Construction01230kVKflongNgae-Yala DC/ST 1272MCMACSR, 120km (using new ROW) and Installaton of 2x200 MVA Transformer at Yala Substation. 251.45 1.0122 > 150.0 % 5. 230/1 15 KV PHANGNGA - PHUKET JUNCTION - PHUKET 2 LINES AND SUBSTATIONS a. 1998 -Construction of 230/t11 kVPhangnga-PhuketJunction (Future Phuket 3 Substation) DC/ST 1.272 MCM ACSR, 76 km Initially energized at 115 kV (using ROW of existing 115 kV Phangnga-Phuket Junction 150 sqmm AAAC line) and - Construction of 1 15 kV Phuket Junction-Phuket 2 SC compact line, 2x795 MCM ACSR 12 km | and connect with one cot of new 230/115 kV Pnangnga-Phuket Junction line and - Connection of existing 1 15 kV Phuket Junction-Phuket 2 with another cot Of new 230/1i5kV Phangnga-Phuket Junction line and - Replacement of 2x1tOD MVA Transformer at R_atjp1a_ha Substation with 2x200 MVA B - -=-Base Case--…--- b. 1995 - Sameas*a.-but use2x795MCMACSR conductor for ll5kVPhangnga-PhuketJunctionline 1 2002 - Construction of 115 kV Phuket 3 Substation at Phuket Junction and Terminate 2 cots of new 115kV I I Phangrnga-Phuket Junction and existing 1 15 kV Phangnga-Phuket t to Phuket 3 Substation and reconstruction of the existing 115 kV Phangnga -Phuket 1 from Phangnga to Phuket 3 to DC/ST 2x795 MCM ACSR, 70km _ _ 108.56| 1 .0047 > 150.0 %S c. 1998 - Construction o1230 kVPhuket 3 Substation at Phuket Junction and reconstrucson of existing 11 5kV iI FRailaprabha-Phangnga and Phangnga-Phuket Junction to 230kV Rallaprabha-Phuket 3 DC/ST I 1,272 MCM ACSR, i49kmaniterminate2 cots of existing IlskVPhangnga-Phuktt I toPhuyket3 - Installation of 2x200 MVA transformer at Phuket 3 Substation 2004 - Construction of 115 kV Phuket 2-Phuket Junction SC CoTpact line, 2x795 MCM ACSR 121km 1160.74 1.0069 N.A. 1:15 KV YALA -NARATHIWAT LINE AND SUBSTATIONS a. 1998 - Constructlon of 1 15 kV Yala - Narathiwat SC on DC/ST 795 MCM ACSR, 61 km B- - ase Case- - -- … b. 1998 |-Constructionof lskvPattani - Narathlwat SC onDC/ST 795 MCM ACSR, 80km 137.031.0081 _50.0_ C. 1998 -ConstrLctionofII5kVYala-Narathiwat DC/ST 795MCMACSR 61km 23.77 1.00141 >150.0 %I 21-Mar-95 04:19 PM Table 2.1 Summary Result of Economic Analysis in TS. 9 ________ ________ ________(C9NTNUED) _ __ _ _ _ _ _ _ _ _ No. Fiscal Description Net P.V. B/C Equalizec Year @10 %DR. Ratio Discount (MTHB) Rate SOUTHERN REGION (CONTINUED) I 17. 115 KV SURAT THANI - BAN DON UNE AND SUBSTATIONS a. 1998 |-Stringing 2ndcctOtI15kVSuratThani-BanDon477MCMACSR. 13.4km 2001 -Constructionoft 5kVPbunphin-Banon SC onDC/ST 795MCM 10okm 7ae 1.se- b. 1998 - ConstrLctionof ttSkVPhunphin-BanDon SConDC/ST795MCM ACSR. I0kmand I - Reconstruction of 115 kV Surat Thnrs-Phunprhin to be SC on DC/ST 795 MCM ACSR, 6.2 km 2003 - Stringing 2nod cot of 1 I5 kV Surat thani-Phunphin795 MCM ACSR 22.20 1.0012 >150.0 9 c . 1998 - Irstallabon ot Gas Turbine Power Plants at Ban Don Substation 5164.1 1 1.2760 >150.0 9 NORTHERN REGION 18. CONVERSION OF MAE MOH 3- CHAING RAI FROM 115 KV TO 230 KV a. 1998 - Conversion of 230/115 kV Mae Moh 3-Chang Ral DC/ST 1.272 MCM ACSR,200 km to energized at 230 kV -Instaliation of 2x200 MVA Transformer at Chiang Ral Substation 2006 - Installabon of 1 x200 MVA Transformer at Mae Moh 3 Substation ------Base Case- - - - - b. 1998 - 115 kV Phayao - Chiang Rai SC on DC/ST 795 MCM ACSR,80 km -Installabon of 1 x200 MVA Transtormer at Mae Moh3 Substation 1999 - Addition of Capaotor Bank 2001 - Conversion of 230/115 kV Mae Moh 3-Chiang Rai DC/ST 1.272 MCM ACSR,200 km to be energized at 230 26.1 -Installaton of 2x200 MVA Transformer at Chiang Ral Substation ___ _ 226.96 1.0130 >_150.0___ C. 1998 - Tenmination oft I s kV Mae Moh 3 - Chiang Rai to Phayao 1,272 MCM ACSR. I km -Installabon of 11 x200 MVA Transformer at Mae Moh 3 Substation 1999 - Addition of Capackor Bank 2001 - Conversion o' 230/11 5kV Mae Moh 3-Cheang Rai DC/ST 1.272 MCM ACSR.200 km to be energmed at 230k - Installabon of 2x200 MVA Transformer at Chiang Rai Substation _ 61.591 1.0035 22.63 % 19. 115 KV LAN KRABU - KAMPHAENG PHET LINE AND SUBSTATIONS a. 1998 -Construction of 115kV Lan Krabu - Kamphaengphet DC/ST 795 MCM ACSR, 47 km 2006 - Construction o I 15kV Bhumibol - Tak I SC on DC/ST 785 MCM ACSR, 47 km ------Base Case- - - - - b. 1998 - Terminaton o115 kV Tak 1 - Kamphaengphet to Tak 2 SC/ST 477 MCM ACSR, 3 km -Installaton of 2x200 MVA Transformer at Tak 2 Substation -Construction of I 15kV Bhumibol - Tak 1 SC on DC/ST 795 MCM ACSR, 47 km - Conrstruction of 11S kV Tak 2- Kamphaengphet SC on DC/ST 795 MCM ACSR. 53 km. 246.07! 1.0140 > 150.0 9W c. 1998 - Terminarton of one cot of 230 kV Shumibol - Nakhorn Sawan lime to Kamphaengphet, 2 km - Installabon of 2x200 MVA Transformer at Kamphaengphet Substatlon 2006 - Terminatbon of 2nd cot of 230 kV Bhumibol - Nakhon Swan lIme to Kamphaengphat. 2 km 163.04 1.0093 >150.09 20. 116 KV MAE MOH 3- LAMPANG 2 UNE AND SUBSTATIONS a. 1998 - Construction of 115 kV Mae Moh 3- Lampang 2 DC/ST 2x795 MCM ACSR. 27 km (New R-O-W) - Termination of two cot of 115 kV Lamphun 2 - Mae Moh 2 line to Lampang 2 1999 - Installaton of 1x200 MVA Transformer at Chiang Mai 3 Substation 2000 -Reconstructionof 115kV MaeMoh2-Lampang 1-Lamphun 1 tobe230kV Mae,Molh3-Saraphi DC/ST 2x1,272 MCM ACSR. 124.4 km and 1 15 kV Mae Moh 3- Lampang 1 DC/ST 795 MCM ACSR. 41.4 kn and 115 kV Lampang 2-Lamphun I DC/ST 785 MCM ACSR 16 1 km -Terrninabon of 115 kV Lamphun 2 -Chiang Ma 2 line to Saraphl Substation DC/ST and Reconstruebon of0115kV Lamphun 2-Saraphiltobe DC/ST 2x795 MCM ACSR. 10km -installaton o121200 MVA Transformer at Saraphi Substation ------…Base Case- - - - - b. 1998 - Reconstnrction of 115kV Mae Moh 2-Lampang I-Lamphun ' tobe 230kV Mae Moh 3-Saraphi i DC/ST 2x1,272 MCM ACSR, 124.4 km and 115 kV Mae Moh 3- Lampang I DC/ST 795 MCM ACSR,41.4 kr and 115 kV Lamphun 2-Lamphun 1 DC/ST 795 MCM ACSR 16 1 km - Terminaton of 1115 kV Lamphun 2-Chiang Mal 2 line to Saraphi Substation DC/ST and Reconstnrction of 115 kV Lamphun 2 - Saraphi to be DC/ST 2x795 MCM ACSR. 10 km I -rInstallation of 2x200 MVA Transformer at Saraphi Substation . 2000 - Constnrction of 115 kV Mae Moh 3- Lampang 2 DC/ST 2x795 MCM ACSR. 27 km (New ROW) I I 2006 - Installaton of 1 x200 MVA Transformer at Chiang Mal 3 Substation 53.20 1.00331 N.A c. I1998 - Termtnabon of230 kV Mae Moh 3 - Chiang Mai 3 line and 115 kV Lampang 2- Lamphun 2 line to Hang Ch 0N - Installaton of 2x200 MVA Transformer at Hang Chat Substation 2000 - Reconstruction of 115 kV Mae Moh 2-Lampang I -I.amphun I to be 230 kV Mae Moh 3-Saraphi DC/ST 2x1.272 MCM ACSR, 124.4 km and 115 kV Mae Moh 3- Lampang I DC/ST 795 MCM ACSR.41 .4k ando 115 kV Lamphun 2-Lamphun I DC/ST 795 MCM ACSR 1 6. 1 km I - Termination o1115 kV Lamphun 2 -Chiang Ma 2 ine to Saraph1 Substation DC/ST and Reconstruction o1 115 kV Lamphun 2 - Sarapht to be DC/ST 2x795 MCM ACSR, 10 km - Installabon of 21200 MVA Transformer at Saraph, Substation 2006 -Reconstruction of 115 kV Saraphi - Chiang Mai 2 line to be DC/ST 2x795 MCM ACSR, 16.1 km 267.08|1. >150.0 s 21. t115 KV CHIANG MAI 2- MAE TAENG LINE AND SUBSTATION a. 1998 - Construction of 115 kV Chiang Mai 2- Mae Taeng SC on DC/ST 795 MCM ACSR. 42 km - Installation of 2x50 MVA Transforner at Mae Taeng sustation. _ _ __ |------EBase Case- - - - - b. 1998 - Installation of Diesel Power Plants at Mae Taeng _ 573.501 1.03871 52.37% C. 1998 |-Installabon of Gas Turbine Power Plants at Ma.Taeng _T __ 612.56 1.0413l 110.56X 21 -M--6 04: 19 PI -6- 3. i...t tLIiA ArN v A SSUP ivirTIONS r n r tJ1VIIC A'NALYSIS OF SUBPROJECTS 3.1 Methodology of Analysis The economic analysis is made to find out the least-cost program to serve the electricity demand in each project area. The transmission system expansion program which includes the proposed subproject is compared with the other two or three possible alternatives. The benefit/cost ratio (B/C ratio), net present value (NPV) and equalized discount rate (EDR) are calculated to indicate that the proposed subproject is included into the least-cost program. The discount rate of 10 % is used to determine the least cost solution. 3.2 Alternative Transmission System Expansion Program Details of three or four possible transmission system expansion alternatives to each subproject are described in Section 4. 3.3 Capital Cost of Alternatives All capital costs are estimated based on 1994 price level. The cost without import duties and taxes, interest during construction (IDC), and escalation are used in the study. 3.3.1 Transmission System The details of cost estimate of each proposed subproject is shown in Volume I (Main Report). The cost estimate of transmission system included in each alternative plan are based on 1994 constant price including engineering, supervision and physical contingencies using the same unit price for each subproject. -7- 3.3.2 Distribution System 'lhe capital cost of the distribution system is estimated based on the following unit price: - 22 kV 33 kV a) Construction of distribution line 185 sq.mm.AAC conductor (MTHB/km) - Single Circuit Structure 0.395 0.433 - Double Circuit Structure 0.777 0.859 - Single Circuit on D)ouble Circuit Structure 0.424 0.469 - Stringing 2nd Circuit 0.394 0.436 b) Aerial Cable (MTHB/km/cct) 0.924 1.271 c) Automatic Voltage Regulator (AVR) (MTHB/Set) 5.500 7.500 d) Switchgear (for I feeder) 2.000 2.000 e) Installation of one bank of 50 MVA Transformer at the Terminal Substation 30.300 30.300 3.3.3 Diesel Power Plant The capital cost of 2.5 MW diesel power plant used in the study is 20,600 THB/kW (USD. 792/kW). 3.3.4 Gas Turbine Power Plant The capital cost of 25 MW gas turbine unit is estimated at 15,120 THB/kW (USSD. 582/kW). -8- 3 4 Economic Life The economic lives of various project elements used in the study are Years Transmission and Distribution Line 40 Substation and Equipment 25 Diesel Power Plant 15 Gas Turbine Power Plant 15 3.5 Operation and Maintenance Cost (O&M Cost) The O&M cost for various types of project is assumed to be a fixed percentage of capital cost as follows % of Capital Cost Transmission Line 1.0 Distribution Line 1.0 Substation and Equipment 2.0 Diesel Power Plant 3.0 Gas Turbine Power lPlant 3.0 3.6 Capacity and Energy Cost of the 'T'ransmission and Distribution Alternatives Since the transmission and distribution system alternative do not produce any generating capacity to the power system so when these alternatives are compared with the installation of diesel or gas turbine power plant alternative, the cost of producing power and energy to the system must be included in the cost of transmission and distribution system alternative. The Long Run Marginal Cost (LRMC) of EGAT's overall power development plan is used to represent the cost of producing power and energy to the system. The LRMC of capacity cost is calculated by using Average Incremental Cost (AIC) concept, which is the ratio of discounted investment cost corresponding to -9 EGAT's Power Development Plan during 1995-2004 to the discounted value of incremental power of the same period. The LRMC of energy is calculated as a weighted average, with the weights depending on the share of future energy generation by the different types of power plant during the same period. The capacity and energy cost based on EGAT's Power Development Plan (PDP 95-01), at 1994 price level are: Capacity Cost = 28,255.90 THB/kW (USD. 1,108.1/kW) Energy Cost = 0.7117 THB/kW (US.d 2.791/kW) 3.7 Losses in Transmission and Distribution System Besides the difference in investment cost and O&M cost between each alternative, the difference in EGAT's power system losses is also taken into account in the least cost solution study. The capacity loss (MW) is adopted from power flow study of the respective alternative. The energy loss (GWh) is calculated from the capacity loss and loss factor using these equations as lollows: Energy Loss (GWh) = Capacity Loss (MW) x 8.76 x Loss Factor Loss Factor = 0.1 (Load Factor) + 0.9 (Load Factor)2 The cost of losses used in the study are also adopted from EGAT's LRMC as follows Cost of Capacity Loss = 2,997.40 THB/kW-yr Cost os Energy Loss = 0.7117 THB/kWh 3.8 Heat Rate and Fuel Cost of Alternative Power Plant 2.5 MW Diesel Plant = 2,508.7 kcalUkWh 2V T.V'7 G Turbiae Piatit = 3,i90.0 kcailkWh Diesel Oil Price (Without Taxes) = 4.6224 THB/Litre Heating Value of Diesel Oil = 8,959.6 kcal/Litre -10- 4. DETAILED ECONOMIC ANALYSIS OF EACH SUBPROJECT -11- SUBPROJECT NO.1 230/115 KV BAN PONG 2 - BAN PONG 1 - NAKHON CHAISI - SAM PRAN 2 LINE AND SUBSTATIONS a) Load Forecast The electricity demand in this subproject area is forecasted as shown in Table 4.1. b) Alternative Plans The three possible alternative plans to serve the same technical objectives of this subproject as described in Volume I (Main Report) are Alternative A Year 19 - Reconstruction of the existing Ban Pong 2 - Ban Pong I - Nakhon Chaisi - Sam Phran 2 from 115 kV double circuit line to 230 kV double circuit line, using 2x1272 MCM ACSR conductor, a distance of approximately 43 km, initially energized at 115 kV. The economic cost is 583.2 MTIIB. Year 2006 - Construction of 230 kV Ban Pong 2 - Sai Noi, double circuit line, using 1272 MCM ACSR conductor, a distance of approximately 53.6 km. - Reconstruction of the existing 230 kV Ratchaburi 2 - Ban Pong 2 from double circuit line using 1272 MCM ACSR conductor to double circuit line using 2x1272 MCM ACSR conductor, a distance of approximately 42 km. - Installation of lx200 MVA 230/115 kV transformer at Ban Pong 2 Substation. The economic cost is 946.8 MTHB. -12- Alternative B: Year 1998 - Reconstruction of the existing Ban Pong 2 - Ban Pong 1 - Nakhon Chaisi - Sam Phran 2 from 115 kV double circuit line to 230 kV double circuit line using 2x1272 MCM ACSR conductor, a distance of approximately 43 km, the Nakhon Chaisi - Sam Phran 2 line section will be initially energized at 115 kV. - Installation of 3x200 MVA 230/115 kV transforners at Nakhon Chaisi Substation. The economic cost is 1,046.6 MTHB. Year 2006 - Construction of 230 kV Ban Pong 2 - Sai Noi line, double circuit steel tower, using lx1272 MCM ACSR conductor, a distance of approximately 54 km. - Reconstruction of the existing 230 kV Ratchaburi 2 - Ban Pong 2 from 230 kV double circuit line using 1272 MCM ACSR conductor to double circuit line using 2x1272 MCM ACSR conductor, a distance of approximately 42 km. The economic cost is 852.4 MTHB. Alternative C Year 1998 - Construction of 230 kV Sai Noi - Nakhon Chaisi - Sam Phran 2 line, double circuit steel tower, using 2x 1272 MCM ACSR conductor, a distance of approximately 40 km, the Nakhon Chaisi - Sam Phran 2 line section will be initially energized at 115 kV. -13- - Installation of 2x200 MVA 230/115 kV transformer at Nakhon Chaisi Subtation. The econnom.ic cost is 9186 MAATHB Year 1999 - Construction of 230 kV Ban Pong 2 - Sai Noi line, double circuit steel tower, using 1x1272 MCM ACSR conductor, a distance of approximately 54 km. The economic cost is 463.9 MTHB. Year 2006 * Reconstruction of the existing 230 kV Ratchaburi 2 - Ban Pong 2 from double circuit line using 1272 MCM ACSR conductor to double circuit line using 2x1272 MCM ACSR conductor, a distance of approximately 42 km. - Installation of 1x200 MVA 230/115 kV transformers at Nakhon Chaisi Substation. The economic cost is 388.5 MTHB. c) Power Flow Diagrams The power flow diagrams for the proposed plan are given in Appendix 1. d) Results of Economic Analysis 1. Comparison of Present Value P.V. at 10 % DR. (MTHB) Alternative A 34,440.95 Alternative B 34,529.51 Alternative C 34,942.10 -14- 2. Net Present Value and B/C Ratio Net Present Value B/C Ratio EDR. (MTHB) (%_ Alternative A VS. Alternative B 88.56 1.0026 N.A. Alternative A VS. Alternative C 501.16 1.0146 >150.00 Results of the analysis have led to the conclusion that the construction of 230/115 kV Ban Pong 2 - Ban Pong I - Nakhon Chaisi - Sampran 2 transmission system project is the least cost alternative. -15- Table 4.1 Load Forecast for Ban Pong 1, Nakhon Chaisi and Sam Pran 2 Substations _________________________________________ Subproact No.1 Fiscal Peak Demand Energy Demand Load Factor Year MW % Increase GWh % Increase (%) 1994 304.18 - 1876.92 - 70.44 1995 205.22 a/ -32.53 1004.72 -46.47 al 55.89 1996 223.73 9.02 1085.25 8.02 55.37 1997 243.23 8.72 1214.36 11.90 56.99 1998 263.80 8.46 1336.80 10.08 57.85 1999 285.48 8.22 1498.58 12.10 59.92 2000 308.36 8.01 1682.78 12.29 62.30 2001 332.54 7.84 1880.99 11.78 64.57 2002 358.11 7.69 2083.89 10.79 66.43 2003 385.24 7.58 2293.73 10.07 67.97 2004 414.08 7.49 2517.70 9.76 69.41 2005 444.86 7.43 2760.59 9.65 70.84 2006 477.72 7.39 3023.78 9.53 72.26 Note: al Some loads are transfered to the PEA's 115kV systems which receive power from 230/115 kV Sam Phran 1 and Ban Pong 2 Substaton. -16- Table 4.2 Summary Result of Economic Analysis Project Transmission System Expansion Project No. 9 Region 1; Subproject No.1 Cost Stream Alternative A Benefit Stream Alternative B Discount Present Value Present Value B/C Present Value Rate of of Ratio of (%) Benefit Cost Net Benefit 4.00 81054.63 81155.40 0.9988 -100.77 6.00 59830.04 59840.40 0.9998 -10.36 8.00 45038.37 44989.05 1.0011 49.32 10.00 34529.61 34440.95 1.0026 88.56 12.00 26924.79 26810.77 1.0043 114.02 14.00 21324.71 21194.62 1.0061 130.09 16.00 17132.33 16992.63 1.0082 139.70 18.00 13944.90 13800.07 1.0105 144.83 20.00 11486.26 11339.41 1.0130 146.85 22.00 9564.14 9417.43 1.0156 146.71 24.00 8042.59 7897.51 1.0184 145.08 26Q00 6824.14 6681.72 1.0213 142.42 Equalized Discount Rate is Not Applicable Cost Stream Alternative A Benefit Stream Alternative C Discount Present Value Present Value B/C Present Value Rate of of Ratio of (%) Benefit - - Cost Net Benefit 4.00 81843.98 81155.40 1.0085 688.58 6.00 60448.42 59840.40 1.0102 608.02 8.00 45537.13 44989.05 1.0122 548.08 10.00 34942.10 34440.95 1.0146 501.16 12.00 27273.50 26810.77 1.0173 462.74 14.00 21624.72 21194.62 1.0203 430.11 16.00 17394.24 16992.63 1.0236 401.60 18.00 14176.26 13800.07 1.0273 376.19 20.00 11692.62 11339.41 1.0311 353.21 22.00 9749.64 9417.43 1.0353 332.21 24.00 8210.40 7897.51 1.0396 312.89 26.00 6976.76 6681.72 1.0442 295.04 Equalized Discount Rate is Greater Than 150% Transmission System Planning Division 21 -Mar-95 11:05AM -17- SUBPROJECT NO.2 115 KV BO WIN - BAN BUNG LINE AND SUBSTATIONS a) Load Forecast The electricity demand in this subproject area is forecasted as shown in Table 4.3. b) Alternative Plans The three possible alternative plans to serve the same technical objectives of this subproject as described in Volume I (Main Report) are Alternative A: Year 1997 - Construction of 115 kV Bo Win - Ban Bung line, double circuit steel tower, using 2x795 MCM ACSR conductor. a distance of approximately 27 km. The economic cost of the project is 206.8 MTHB. Year 2001 - Installation of lx200 MVA 230/115 kV transformer at Bo Win Substation. The economic cost is 81.6 MTHB. Alternative B Year 1997 - Rolo the existing Ao Phai - Si Racha - Ban Bung iine from 115 kV single circuit line to 115 kV Ao Phai - Ban Bung double circuit line, using 2x795 MCM ACSR conductor, a distance of approximately 38 km. -18- The economic cost of the project is 277.6 MTHB. Year 2004 - Installation of 1 x200 MVA 230/115 kV transformer at Bo Win Substation. - Installation of l x200 MVA 230/115 kV transformer at Ao Phai Substation. The economic cost is 189.0 MTHB. Alternative C Year 1997 - Construction of 230 kV Bo Win - Ban Bung line, double circuit steel tower, using 1,272 MCM ACSR conductor, a distance of approximately 27 km. - Installation of 2x200 MVA 230/115 kV transformer at Ban Bung Substation. The economic cost of the project is 531.7 MTHB. Year 2004 - Installation of Ix200 MVA 230/115 kV transformer at Bo Win Substation. The economic cost is 81.9 MTHB. -19- c) Power Flow Diagrams The power flow diagrams for the proposed plan are given in Appendix 1. d) Results of Econom..ic A.a;ivsis 1. Comparison of Present Value P.V. at 10 % DR. (MTHB) Alternative A 25,346.84 Alternative B 25,436.86 Alternative C 25,590.21 2. Net Present Value and B/C Ratio Net Present Value B/C Ratio EDR. (MTHB) (%) Alternative A VS. Alternative B 90.02 1.0036 >150.00 Alternative A VS. Alternative C 243.3.7 1.0096 >150.00 Results of the analysis have led to the conclusion that the construction of 115 kV Bo Win - Ban Bung transmission system project is the least cost alternative. -20- Table 4.3 Load Forecast for Ban Bung Substation Subprojee No.v Fiscal Peak Demand Energy Demand Load Factor Year MW % Increase GWh % Increase (%) 1994 49.62 - 281.32 - 64.72 1995 57.67 16.22 318.10 13.07 62.97 1996 68.22 18.29 373.98 17.57 62.58 1997 79.88 17.09 437.59 17.01 62.54 1998 93.05 16.49 506.65 15.78 62.16 1999 102.39 10.04 572.74 13.04 63.86 2000 110.33 7.75 620.77 8.39 64.23 2001 118.81 7.69 672.26 8.29 64.59 2002 127.84 7.60 727.29 8.19 64.94 2003 137.44 7.51 786.01 8.07 65.28 2004 147.63 7.41 848.57 7.96 65.62 2005 158.42 7.31 895.06 5.48 64.50 2006 169.85 7.21 985.76 10.13 66.25 . \~~~~~~~~~~~-1 Table 4 .4 Summary Result of Economic Analysis Project Transmission System Expansion Project No. 9 Region 1; Subproject No.2 Cost Stream A!ternative A Benefit Stream Alternative B Discount Present Value Present Value B/C Present Value Rate of of Ratio of (%) Benefit Cost Net Benefit 4.00 57805.75 57667.75 1.0024 138.00 6.00 43079.88 42959.86 1.0028 120.02 8.00 32783.09 32679.12 1.0032 103.97 10.00 25436.86 25346.84 1.0036 90.02 12.00 20093.56 20015.47 1.0039 78.10 14.00 16135.04 16067.08 1.0042 67.96 16.00 13151.03 13091.65 1.0045 59.37 i 8.00 10864.6.3 10812.54 1.0048 52.10 20.00 9085.87 9039.96 1.0051 45.92 22.00 7682.31 7641.66 1.0053 40,65 24.00 6560.18 6524.03 1.0055 36.15 26.00 5652.14 5619.85 1.0057 32.29 Equalized Discount Rate is Greater Than 150% Cost Stream Alternative A Benefit Stream Alternative C Discount Present Value Present Value B!C Present Value Rate of of Ratio of (%) Benefit Cost Net Benefit 4.00 57982.92 57667.75 1.0055 315.17 6.00 43247.37 42959.86 1.0067 287.51 8.00 32942.97 32679.12 1.0081 263.84 10.00 25590.21 25346.84 1.0096 243.37 12.00 20240.94 20015.47 1.0113 225.47 14.00 16276.76 16067.08 1.0131 209.69 16.00 13287.31 13091.65 1.0149 195.66 18.00 10995.63 10812.54 1.0169 183.10 20.00 9211.74 9039.96 1.0190 171.78 22.00 7803.19 7641.66 1.0211 161.53 24.00 6676.23 6524.03 1.0233 152.20 26.00 5763.53 5619.85 1.0256 143.68 Equalized Discount Rate is Greater Than 150% Transmission System Planning Division 21 -Mar-95 11.07 AM -22- SUBPROJECT NO.3 115 KV THA WUNG SUBSTATIONS AND LINE CONNECTION a) Load Forecast The electricity demand in this subproject area is forecasted as shown in Table 4.5. b) Alternative Plans The four possible alternative plans to serve the same technical objectives of this subproject as described in Volume I (Main Report) are Alternative A: Year 1998 - Construction of I 15 kV Tha Wung Substation at the intersection between 115 kV Lop Buri 1 - Sing Buri and 115 kV Ang Thong 2 - Lop Buri 2 lines and terminate these two 115 kV lines to Tha Wung Substation. - Installation of lx200 MVA 230/115 kV transformer at Ang Thong I Substation. The economic cost is 271.5 MTHB. Year 2002 - Construction of 115 kV Tha Wung - Lop Buri 1 line, single circuit on double circuit steel tower, using 795 MCM ACSR conductor, a distance of approximately 13 km. The economic cost is 71.8 MTHB. -23- Alternative B: Year 1998 - Reconstruction of the existing Ang Thong 1 - Sing Buri line from 115 kV single circuit line to double circuit line, using 2x795 MCM ACSR conductor, a distance of approximately 34 km. - Installation of lx200 MVA 230/115 kV transformer at Ang Thong I Substation. The economic cost is 345.7 MTHB. Year 2002 - Construction of 115 kV Sing Buri - Lop Buri line, single circuit on double circuit steel tower, using 795 MCM ACSR conductor, a distance of approximately 27 km. The economic cost is 172.6 MTHB. Altemative C: Year 1998 - Termination of one circuit of the existing Tha Tako - Ang Thong I line to Sing Buri Substation. - Installation of lx200 MVA 230/115 kV transformer at Sing Buri Substation. The economic cost is 363.1 MTHB. -24- Year 2002 - Construction of 115 kV Sing Buri - Lop Buri line, single circuit on double circuit steel tower, using 795 MCM ACSR conductor, a distance of approximately 27 km. The economic cost is 172.6 MTHB. Year 2006 - Installation of lx200 MVA 230/115 kV transformer at Ang Thong 1 Substation. The economic cost is 94.6 MTHB. AlterinaUve D Year 1998 - Construction of 230/115 kV Tha Wung Substation and terminate oine circuit of 230 kV Tha Tako - Thalan 3 and 115 kV Sing Buri - Lop Buri I to Tha Wung Substation. - Installation of 1 x200 MVA 230/115 kV transformer at Tha Wung Substation. The economic cost is 350.1 MTHB. Year 2002 - Construction of 115 kV Tha Wung - Lop Buri I line, single circuit on double circuit steel tower, using 795 MCM ACSR conductor, a distance of approximately 13 km. -25 - The economic cost is 71.8 MTHB. Year 2003 - Installation of lx200 MVA 230/115 kV transformer at Ang Thong 1 Substation. The economic cost is 94.6 MTHB. c) Power Flow Diagrams The power flow diagrams for the proposed plan are given in Appendix 1. d) Results of Economic Analysis 1. Comparison of Present Value P.V. at 10 % DR. (MTHB) Alternative A 20,395.40 Alternative B 20,416.16 Alternative C 20,427.70 Alternative D 20,440.28 2. Net Present Value and B/C Ratio Net Present Value B/C Ratio EDR. (MTHB) (%) Alternative A VS. Alternative B 20.76 1.0001 N.A. Alternative A VS. Alternative C 32.30 1.0016 N.A. Alternative A VS. Alternative D 44.88 1.0022 N.A. Results of the analysis have led to the conclusion that the construction of 115 kV Tha Wung Substation project is the least cost alternative. -26- Table 4.5 Load Forecast for Singburi and Lop Buri 1 Substations .._______________________________________ ,_____...______._ _.___ . -Subproect No.3 Fiscal Peak Demand Energy Demand Load Factor Year MW % Increase GWh % Increase (%) 1994 70.20 - 318.82 - 51.84 1995 80.29 14.37 374.04 17.32 53.18 1996 75.15 a/ -6.40 340.55 a/ -8.95 51.73 1997 79.75 6.12 369.17 8.40 52.84 1998 84.40 5.83 392.53 6.33 53.09 1999 89.17 5.65 416.99 6.23 53.38 2000 94.03 5.45 442.68 6.16 53.74 2001 98.99 5.27 469.57 6.07 54.15 2002 104.10 5.16 495.90 5.61 54.38 2003 109.40 5.09 523.96 5.66 54.67 2004 114.91 5.04 553.61 5.66 55.00 2005 120.67 5.01 585.41 5.74 55.38 2006 126.70 5.00 619.49 5.82 55.82 Note: a/ Some loads are transfered to PEA's 115 kV Systems which receive power from 115 kV Lop Buri 2 Substation. -27- Table 4.6 Summary Result of Economic Analysis Project Transmission System Expansion Project No. 9 Region 1; Subproject No.3 Cost Stream Altarnative A Benefit Stream Alternative B Discount Present Value Present Value B/C Present Value Rate of of Ratio of (%) Benefit Cost __ Net Benefit 4.00 47704.59 47760.13 0.9988 -55.54 6.00 35254.07 35270.41 0.9995 -16.34 8.00 26579.42 26572.37 1.0003 7.05 10.00 20416.16 20395.40 1.0010 20.76 12.00 15954.47 15925.99 1.0018 28.48 14.00 12666.58 12634.10 1.0026 32.47 16.00 10202.61 10168.47 1.0034 34.14 18.00 8326.74 8292.37 1.0041 34.37 20.00 6877.39 6843.69 1.0049 33.70 22.00 5742.14 5709.65 1.0057 32.50 24.00 4841.55 4810.56 1.0064 30.99 26.00 4118.69 4089.36 1.0072 29.33 Equalized Discount Rate is Not Applicable Cost Stream Alternative A Benefit Stream Alternative C Discount Present Value Present Value B/C Present Value Rate of of Ratio of (%) Benefit Cost Net Benefit 4.00 47710.32 47760.13 0.9990 -49.81 6.00 35263.45 35270.41 0.9998 -6.96 8.00 26590.43 26572.37 1.0007 18.06 10.00 20427.70 20395.40 1.0016 32.30 12.00 15965.96 15925.99 1.0025 39.97 14.00 12677.73 12634.10 1.0035 43.62 16.00 10213.30 10168.47 1.0044 44.83 18.00 8336.94 8292.37 1.0054 44.56 20.00 6887.12 6843.69 1.0063 43.42 22.00 5751.43 5709.65 1.0073 41.79 24.00 4850.46 4810.56 1.0083 39.89 26.00 4127.26 4089.36 1.0093 37.89 Equalized Discount Rate is Not Applicable Transmission System Planning Division 21 - Mar-95 11:08AM -28- Table 4.6 Summary Result of Economic Analysis (continued)I Project Transmission System Expansion Project No. 9 Region 1; Subproject No.3 Cost Stream Alternative A Benefit Stream Alternative D Discount Present Value Present Value B/C Present Value Rate of of Ratio of (%) Benefit _ Cost _ Net Benefit 4.00 47786.05 47760.13 1.0005 25.92 6.00 35307.69 35270.41 1.0011 37.29 8.00 26615.17 26572.37 1.0016 42.81 10.00 20440.28 20395.40 1.0022 44.88 12.00 15970.92 15925.99 1.0028 44.93 14.00 12677.93 12634.10 1.0035 43.82 16.00 10210.55 10168.47 1.0041 42.08 18.00 8332.39 8292.37 1.0048 40.02 20.00 6881.53 6843.69 1.0055 37.83 22.00 5745.28 5709.65 1.0062 35.63 24.00 4844.06 4810.56 1.0070 33.50 26.0u 4120.6, 4089.36 1.0077 31.45 Equalized Discount Rate is Not Applicable Transmission System Planning Division 21 -Mar-95 11:12AM -29- SUBpROJECT NO.4 115 KV THALAN 3 - SARABURI 1 LINE AND SUBSTATIONS a) Load Forecast The electricity demand in this subproject area is forecasted as shown in Table 4.7. b) Alternative Plans The three possible alternative plans to serve the same technical objectives of this subproject as described in Volume I (Main Report) are Alternative A: Year 1998 - Construction of 115 kV lhalan 3 - Saraburi I line, double circuit steel tower, using 795 MCM ACSR conductor, a distance of approximately 15 km. This transmission line will be constructed on the right-of-way of the existing 115 kV Thalan 1 - Saraburi 1 line. - Construction of 115 kV 'Ihalan I - Thalan 3 line, single circuit on double circuit steel tower, using 795 MCM AC'SR conductor, a distance of approximately 5 km. This transmission line will be constructed on1 the right-of-way of the existing 115 kY Thalan 1 - Saraburi 1 line. The economic cost is 161.8 MTIIB. Alternative B Year 1998 - Reconstruction of the existing Thalan 1 - Saraburi I from 115 kV single circui linie 'o LI . xV doubie circuit iine, using 795 MCM ACSR conductor, a distance of approximately 18 km. -30- - Reconstruction of the existing 115 kV Thalan 1 - Thalan 3 from double circuit line using 477 MCM ACSR conductor to double circuit line using 795 MCM ACSR conductor, a distance of approximately 5 km. The economic cost is 169.3 MTIIB. Alternative C Year 1998 - Construction of 115 kV Thalan 3 - Saraburi I line, single circuit on double circuit steel tower, using 795 MCM ACSR conductor, a distance of approximately 14 km. - Termination of 115 kV Thalan I - Saraburi I at Thalan 3 substation and reconstruction of the existing 115 kV Thalan I - Thalan 3 from single circuit line to single circuit on double circuit line, using 795 MCM ACSR conductor, a distance of approximately 5 km. The economic cost is 153.9 MTIIB. Year 2003 - Stringing 2nd circuit of the 115 kV Thalan 3 - Saraburi I line, using 795 MCM ACSR conductor, a distance of approximately 14 km. The economic cost is 38.6 MTHB. c) Power Flow Diagrams The power flow diagrams for the proposed plan are given in Appendix 1. -31- d) Results of Economic Analysis 1. Comparison of Present Value P.AV. i 10 % DR. (MT!5B Alternative A 25,500.61 Alternative B 25,510.64 Alternative C 25,511.58 2. Net Present Value and B/C Ratio Net Present Value B/C Ratio EDR. (MTHB) (%) Alternative A VS. Alternative B 10.03 1.0004 31.36 Alternative A VS. Alternative C 10.97 1.0004 25.28 Results of the analysis have led to the conclusion that the reconstruction of 115 kV Thalan 1 - Saraburi I to 115 kV Thalan 3 - Saraburi I transmission system project is the least cost alternative. -32- Table 4.7 Load Forecast for Saraburi 1 Substation Subp,ropct No.4 Fiscal Peak Demand Energy Demand Load Factor Year MW % Increase GWh % Increase (%) 1994 44.40 - 246.24 - 63.31 1995 62.48 40.72 369.43 50.03 67.50 1996 68.78 10.08 413.67 11.98 68.66 1997 52.57 a/ -23.57 256.82 a/ -37.92 55.77 1998 57.15 8.71 278.71 8.52 55.67 1999 61.96 8.42 308.07 10.53 56.76 2000 67.07 8.25 341.46 10.84 58.12 2001 72.51 8.11 380.31 11.38 59.87 2002 78.33 8.03 416.76 9.58 60.74 2003 84.54 7.93 457.78 9.84 61.81 2004 91.18 7.85 505.60 10.45 63.30 2005 98.27 7.78 557.60 10.28 64.77 2006 105.86 7.72 614.18 10.15 66.23 Note a/ Some loads are transfered to PEA's 115 kV systems which receive power from 230/115 kV Saraburi 2 Substation. -33- Table 4 . 8 Summary Result of Economic Analysis Project Transmission System Expansion Project No. 9 Region 1; Subproject No.4 Cost Stream Alternative A Benefit Stream Alternative B Discount Present Value Present Value B/C Present Value Rate of of Ratio of (%) Benefit Cost _ __ Net Benefit 4.00 61301.64 61281.13 1.0003 20.51 6.00 44903.78 44887.66 1.0004 16.12 8.00 33538.75 33526.05 1.0004 12.71 10.00 25510.64 25500.61 1.0004 10.03 12.00 19735.39 19727.47 1.0004 7.92 14.00 15508.08 15501.86 1.0004 6.23 16.00 12362.60 12357.73 1.0004 4.87 i8.00 9985.61 9981.84 1.0004 '3.76 20.00 8163.14 81S0.28 1.0004 2.86 22.00 6746.81 6744.70 1.0003 2.11 24.00 5632.17 5630.67 1.0003 1.50 26.00 4744.65 4743.66 1.0002 0.99 Equalized Discount Rate = 31.36% Cost Stream Alternative A Benefit Stream Alternative C Discount Present Value. Present Value B/C Present Value Rate of of Ratio of (°/9) Benefit Cost ___ _ Net Benefit 4.00 61301.92 61281.13 1.0003 20.79 6.00 44904.75 44887.66 1.0004 17.09 8.00 33539.85 33526.05 1.0004 13.81 10.00 25511.58 25500.61 1.0004 10.97 12.00 19736.04 19727.47 1.0004 8.56 14.00 15508.39 15501.86 1.0004 6.53 16.00 12362.56 12357.73 1.0004 4.83 18.00 9985.25 9981.84 1.0003 3.41 20.00 8162.51 8160.28 1.0003 2.23 22.00 6745.95 6744.70 1.0002 1.25 24.00 5631.11 5630.67 1.0001 0.44 26.00 4743.43 4743.66 1.0000 -0.22 Equalized Discount Rate 25.28% Transmission System Planning Division 21 - Mar-95 11:13AM -34- SUBPROJECT NO.5 115 KV RATCHABURI 2 - PHETCHABURI LINE AND SUBSTATIONS a) Load Forecast The electricity demand in this subproject area is forecasted as shown in Table 4.9. b) Alternative Plans The three possible alternative plans to serve the same technical objectives of this subproject as described in Volume I (Main Report) are Alternative A Year 1998 - Reconstruction of the existing 115 kV Ratchaburi 2 - Phetchaburi from single circuit line to double circuit line, using 2x795 MCM ACSR conductor, a distance of approximately 53 km. The economic cost is 287.9 MTHB. Alternative B Year 1998 - Termination of the 2nd circuit of 230 kV Ratchaburi 2 -Prachuap Khiri Khan line at Hua Hin Substation, using 1,272 MCM ACSR conductor, a distance of approximately 10 km. The economic cost is 156.3 MTHB. -35- Year 2006 - Construction of 115 kV Ratchaburi 2 - Phetchaburi line, single circuit on double circuit steel tower, using 2x795 MCM ACSR conductor, a distance of approximately 53 km. The economic cost is 278.1 MTHB. Alternative C Year 1998 - Construction of 115 kV Ratchaburi 2 - Phetchaburi line, single circuit on double circuit steel tower, using 2x795 MCM ACSR conductor, a distance of approximately 53 km. The economic cost is 306.0 MTHB. c) Power Flow Diagrams The power flow diagrams for the proposed plan are given in Appendix 1. d) Results of Economic Analysis 1. Comparison of Present. Value P.V. at 10 % DR. (MTHB) Alternative A 24,266.75 Alternative B 24,278.83 Alternative C 24,295.87 -36- 2. Net Present Value and B/C, Ratio Net Present Value B/C Ratio EDR. (MTHB) (%) Alternative A VS. Alternative B 12.09 1.0005 12.77 Alternative A VS. Alternative C 29.12 1.0012 >150.00 Results of the analysis have led to the conclusion that the reconstruction of 115 kV Ratchaburi 2 - Phetchaburi transmission system project is the least cost alternative. -37- Table 4.9 Load Forecast for Phetchaburi, Cha Am and Hua Hin Substations Subproyct No.5 Fiscal Peak Demand Energy Demand Load Factor Year MW % Increase GWh % Increase (%) 1994 71.60 - 401.85 - 64.07 1995 91.25 27.44 460.59 14.62 57.62 1996 99.57 9.12 504.38 9.51 57.83 1997 108.08 8.55 546.72 8.39 57.75 1998 116.77 8.04 584.31 6.88 57.12 1999 125.58 7.54 625.97 7.13 56.90 2000 134.58 7.17 670.21 7.07 56.85 2001 143.85 6.89 718.42 7.19 57.01 2002 153.18 6.49 762.81 6.18 56.85 2003 162.77 6.26 809.60 6.13 56.78 2004 172.64 6.06 859.76 6.20 56.85 2005 182.74 5.85 912.00 6.08 56.97 2006 193.12 5.68 966.32 5.96 57.12 -38- Table 4.10 Summary Result of Economic Analysis Project Transmission System Expansion Project No. 9 Region 1; Subproject No. 5 Cost Stream Alternative A Benefit Stream Alternative B Discount Present Value Present Value B/C Present Value Rate of of Ratio of (%) Benefit Cost Net Benefit 4.00 57338.42 57288.57 1.0009 49.85 6.00 42236.38 42200.32 1.0009 36.06 8.00 31730.24 31707.07 1.0007 23.18 10.00 24278.83 24266.75 1.0005 12.09 12.00 18895.39 18892.40 1.0002 2.99 14.00 14937.06 14941.29 0.9997 -4.23 16.00 11977.92 11987.72 0.9992 -9.80 18.00 9730.99 9744.99 0.9986 -13.99 20.00 7999.85 8016.91 0.9979 -17.06 22.00 6647.90 6667.11 0.9971 -19.21 24.00 -55787S3 5599.37 0.9963 -20.64 26.00 4723.30 4744.81 0.9955 -21.51 Equalized Discount Rate = 12.77% Cost Stream Alternative A Benefit Stream Alternative C Discount Present Value Present Value B/C Present Value Rate of of Ratio of (%) Benefit Cost Net Benefit 4.00 57326.17 57288.57 1.0007 37.60 6.00 42234.25 42200.32 1.0008 33.93 8.00 31738.26 31707.07 1.0010 31.20 10.00 24295.87 24266.75 1.0012 29.12 12.00 18919.91 18892.40 1.0015 27.51 14.00 14967.53 14941.29 1.0018 26.23 16.00 12012.91 11987.72 1.0021 25.19 18.00 9769.30 9744.99 1.0025 24.31 20.00 8040.46 8016.91 1.0029 23.55 22.00 6689.98 6667.11 1.0034 22.87 24.00 5621.64 5599.37 1.0040 22.26 26.00 4766.51 4744.81 1.0046 21.70 Equalized Discount Rate is Greater Than 150% Transmission System Planning Division 21 - Mar-95 11:16AM -39- SUBPROJECT NO.6 115 KV PRACHIN BURI 2 - WATTHANA NAKHON LINE AND SUBSTATIONS a) Load Forecast The electricity demand in this subproject area is forecasted as shown in Table 4.11. b) Alternative Plans The three possible alternative plans to serve the same technical objectives of this subproject as described in Volume I (Main Report) are Alternative Ii. Year 1998 - Construction of 115 kV Prachin Buri 2 - Watthana Nakhon line, single circuit on double circuit steel tower, using 2X795 MCM ACSR conductor, a distance of approximately 67 km. The economic cost is 345.1 MTHB. Alternative B Year 1998 - Construction of 230 kV Prachin Buri 2 - Watthana Nakhon line, single circuit on double circuit steel tower, using 1,272 MCM ACSR conductor, a distance of approximately 67 km, initially energized at 115 kV. The economic cost is 476.2 MTHB. -40- Alternative C: Year 1998 - Construction of 230 kV Prachin Buri 2 - Watthana Nakhon line, single circuit on double circuit steel tower, using 1,272 MCM ACSR conductor, a distance of approximately 67 km. - Installation of 1 x200 MVA 23 0/115 kV transformer at Watthana Nakhon Substation. The economic cost is 779.9 MTHB. c) Power Flow Diagrams The power flow diagrams for the proposed plan are given in Appendix 1. UI) AXResu'Ls ol ucor.omr.c fnaluz 1. Comparison of Present Value P.V. at 10 % DR. (MTHB) Alternative A 18,571.47 Alternative B 18,679.47 Alternative C 18,893.61 2. Net Present Value and B/C Ratio Net Present Value B/C Ratio EDR. (MTHB) (%) Alternative A VS. Alternative B 108.00 1.0058 >150.00 Alternative A VS. Alternative C 322.14 1.0173 >150.00 -41- Results of the analysis have led to the conclusion that the construction of 115 kV Prachin Buri 2 - Watthana Nakhon transmission system project is the least cost alternative. -42- Table 4.11 Load Forecast for Watthana Nakhon Substation Subprojct No.6 Fiscal Peak Demand Energy Demand Load Factor Year MW % Increase GWh % Increase (%) 1994 29.66 - 123.39 - - 1995 34.15 15.14 149.92 21.50 50.11 1996 37.29 9.19 165.70 10.53 50.73 1997 40.52 8.66 138.03 -16.70 38.89 1998 43.89 8.32 155.45 12.62 40.43 1999 47.42 8.04 173.74 11.77 41.82 2000 51.18 7.93 194.66 12.04 43.42 2001 55.15 7.76 217.11 11.53 44.94 2002 59.36 7.63 243.57 12.19 46.84 2003 63.82 7.51 274.89 12.86 49.17 2004 68.57 7.44 304.88 10.91 50.76 2005 73.61 7.35 337.41 10.67 52.33 2006 78.96 7.27 372.66 10.45 53.88 -43- Table 4.12 Summary Result of Economic Analysis Project Transmission System Expansion Project No. 9 Region 1; Subproject No.6 Benefit Stream Alternative B Discount Present Value Present Value B/C Present Value Rate of of Ratio of (%) Benefit _ Cost ___ Net Benefit 4.00 44063.65 43926.65 1.0031 136.99 6.00 32461.79 32335.35 1.0039 126.44 8.00 24396.18 24279.43 1.0048 116.75 10.00 18679.47 18571.47 1.0058 108.00 12.00 14551.81 144S1.63 1.0069 100.17 14.00 11518.41 11425.25 1.0082 93.17 16.00 9251.64 9164.76 1.0095 86.88 18.00 7530.91 7449.68 1.0109 81.23 20.00 6205.32 6129.20 1.0124 76.12 22.00 5170.01 5098.52 1.0140 71.49 24.00 4351.03 4283.76 1.0157 67.27 26.00 3695.46 3632.06 1.0175 63.41 Equalized Discount Rate is Greater Than 150% Cost Stream Alternative A Benefit Stream Alternative C Discount Present Value Present Value B/C Present Value Rate of of Ratio of (%) Benefit Cost Net Benefit 4.00 44337.90 43926.65 1.0094 411.25 6.00 32714.02 32335.35 1.0117 378.67 8.00 24628.41 24279.43 1.0144 348.98 10.00 18893.61 18571.47 1.0173 322.14 12.00 14749.57 14451.63 1.0206 297.94 14.00 11701.35 11425.25 1.0242 276.11 16.00 9421.15 9164.76 1.0280 256.39 18.00 7688.22 7449.68 1.0320 238.53 20.00 6351.53 6129.20 1.0363 222.33 22.00 5306.10 5098.52 1.0407 207.58 24.00 4477.89 4283.76 1.0453 194.13 26.00 3813.88 3632.06 1.0501 181.82 Equalized Discount Rate is Greater Than 150% Transmission System Planning Division 21 -Mar-95 11:17AM -44- SUBPROJECT NO.7 230/115 KV MUKDAHAN 2 SUBSTATIONS AND 115 KV MUKDAHAN 2 - THAT PHANOM - NAKHON PHANOM LINES AND SUBSTATIONS a) Load Forecast The electricity demand in this subproject area is forecasted as shown in Table 4.13. b) Alternative Plans The four possible alternative plans to serve the same technical objectives of this subproject as described in Volume I (Main Report) are Alternative A Year 1998Q I Lai-I i1~ - Termination of one circuit ot 230 kV Savannakhet - Roi Et at Mukdahan 2 Substation. - Installation of 2x200 MVA 230/115 kV transformers at Mukdahan 2 Substation. - Construction of 115 kV Mukdahan 2 - That Phanom line, double circuit steel tower, using 795 MCM ACSR, a distance of approximately 36 km. - Construction of 115 kV That Phanom - Nakhon Phanom line, single circuit on double circuit steel tower, using 795 MCM ACSR conductor, a distance of approximately 59 km. The economic cost is 755.5 MTHB. -45- Year 2003 - Installation of lx20( MVA 230/115 kV transformer at Roi Et Substation. The economic cost is 114.2 MTHB. Year 2005 - Stringing second circuit of 115 kV That Phanom - Nakhon Phanom line, using 795 MCM ACSR conductor, a distance of approximately 59 km. The economic cost is 6237 MTHB. Alternative B Year 1998 - Termination of one circuit of 230 kV Thakhek - Sakon Nakhon 2 at Nakhon Phanom 2 Substation. - Installation of 2x200 MVA 230/115 kV transformers at Nakhon Phanomn 2 Substation. - Construction of 115 kV Nakhon Phanom 2 - Nakhon Phanom 1 line, double circuit steel tower, using 2x795 MCM ACSR conductor, a distance of approximately 13 km. - Construction of 115 kV Nakhon Phanom 1 - That Phanom line, double circuit steel toWer, using 795 MCM ACSR conductor, a distance of approximately 59 km. - Construction of 115 kV That Phanom - Mukdahan line, single circuit on double circuit steel tower, using 795 MCM ACSR conductor, a distance of approximately 45 km. The economic cost is 865.5 MTHB. -46 - Year 2001 - Installation of lx200 MVA 230/115 kV transformer at Roi Et Substation. The economic cost is 114.2 MTHB. Year 2005 - Stringing second circuit of 115 kV That Phanom - Mukdahan line, using 795 MCM ACSR conductor, a distance of approximately 45 km. The economic cost is 45.0 MTHB. Alternative C X.TA..A._ 1 AA O IL lai 17:70 - Construction of 115 kV Sakon Nakhon - That Phanom line, double circuit line, using 795 MCM ACSR conductor, a distance of approximately 70 km. - Construction of I 15 kV That Phanom - Nakhon Phanom line, single circuit on double circuit steel tower, using 795 MCM ACSR conductor, a distance of approximately 59 km. - Construction of 115 kV That Phanom - Mukdahan line, single circuit on double circuit steel tower, using 795 MCM ACSR conductor, a distance of approximately 45 km. The economic cost is 625.0 MTHB. Year 2001 - Installation of I x200 MVA 230/115 kV transformer at Roi Et Substation. The economic cost is 114.2 MTHB. -47- Year 2004 - Stringing second circuit of 115 kV That Phanom - Mukdahan line. usine 795 MCM ACSR conductor, a distance of approximately 45 km. The economic cost is 45.0 MTHB. Year 2005 - Stringing second circuit of 115 kV That Phanom - Nakhon Phanom line, using 795 MCM ACSR conductor, a distance of approximately 59 km. The economic cost is 62.7 MTHB. Alternative D Year 1998 - Construction of 115 kV Sakon Nakhon - That Phanom line, double circuit steel tower, using 795 MCM ACSR conductor, a distance of approximately 70 km. - Construction of 115 kV That Phanom - Nakhon Phanom line, single circuit on double circuit steel tower, using 795 MCM ACSR conductor, a distancc of approximately 59 km. - Construction of 115 kV Phon Thong - Mukdahan line, single circuit on double circuit steel tower, using 795 MCM ACSR conductor, a distance ol approximately 90 km. - Stringing second circuit of 115 kV Roi Et - Phon Thong line, using 795 MCM ACSR conductor, a distance of approximately 45 km. -48- The economic cost is 847.7 MTHB. Year 2001 - Installation of lx200 MVA 230/115 kV transformer at Roi Et Substation. The economic cost is 114.2 MTHB. Year 2004 - Stringing second circuit of 115 kV Phon Thong - Mukdahan line, using 795 MCM ACSR conductor, a distance of approximately 90 km. The economic cost is 71.2 MTHB. wy.. ~nr.nr - Stringing second circuit of 115 kV That Phanom - Nakhon Phanom line, using 795 MCM ACSR conductor, a distance of approximately 59 km. The economic cost is 62.7 MTHB. c) Power Flow Diagrams The power flow diagrams for the proposed plan are given in Appendix l. d) Results of Economic Analysis 1. Comparison of Present Value P.V. at 10 % DR. (MTHB) Alternative A 15,955.30 Alternative B 16,323.02 Alternative C 16,219.11 Alternative D 16,237.27 -49- 2. Net Present Value and B/C Ratio Net Present Value B/C Ratio EDR. (MTHB) (%) Alternative A VS. Alternative B 367.72 1.0230 >150.00 Alternative A VS. Alternative C 263.81 1.0165 31.53 Alternative A VS. Alternative D 281.97 1.0177 145.89 Results of the analysis have led to the conclusion that the construction of 230/115 kV Mukdahan 2 Substation and line termination together with construction of 115 kV Mukdahan 2 - That Phanom - Nakhon Phanom transmission system project is the least cost alternative. -sn-. Tabie 4.13 Load Forecast for Nakhon Phanom, That Phanom and Mukdahan Substations __ __ __ __ __ __ __ __ __ __ __ __ __ __ __ __ __ __ __ _ Subprojccl No.7 Fiscal Peak Demand Energy Demand Load Factor Year MW % Increase GWh % Increase (%/0) 1994 55.74 - 216.28 - 44.29 1995 60.96 9.36 233.36 7.90 43.70 1996 63.62 4.36 248.33 6.41 44.56 1997 68.87 8.25 268.61 8.17 44.52 1998 74.12 7.62 289.06 7.61 44.52 1999 79.55 7.33 311.88 7.89 44.76 2000 85.18 7.08 336.07 7.76 45.04 2001 90.99 6.82 361.81 7.66 45.39 2002 97.04 6.65 386.94 6.95 45.52 2003 103.12 6.27 413.48 6.86 45.77 2004 109.90 6.57 441.43 6.76 45.85 2005 116.77 6.25 471.18 6.74 46.06 2006 123.96 6.16 503.09 6.77 46.33 -51- Table 4.14 Summary Result of Economic Analysis Project Transmission System Expansion Project No. 9 Region 2; Subproject No. 7 Cost Sirearn Alternative A Benefit Stream Alternative B Discount Present Value Present Value B/C Present Value Rate of of Ratio of (%) Benefit Cost Net Benefit 4.00 36337.10 35529.68 1.0227 807.41 6.00 27273.21 26666.22 1.0228 606.99 8.00 20898.87 20431.63 1.0229 467.24 10.00 16323.02 15955.30 1.0230 367.72 12.00 12973.19 12677.83 1.0233 295.37 14.00 10474.96 10233.26 1.0236 241.70 16.00 8579.05 8377.94 1.0240 201.12 18.00 7116.67 6946.81 1.0245 169.86 20.00 5971.56 5826.19 1.0250 145.37 22.00 5062.34 4936.48 1.0255 125.85 24.00 4331.15 4221.07 1.0261 110.08 26.00 3736.21 3639.08 1.0267 97.14 Equalized Discount Rate is Greater Than 150% Cost Stream Alternative A Benefit Stream Alternative C Discount Present Value Present Value B/C Present Value Rate of of Ratio of (%) Benefit Cost _ _ Net Benefit 4.00 36250.36 35529.68 1.0203 720.68 6.00 27176.64 26666.22 1.0191 510.42 8.00 20797.03 20431.63 1.0179 365.40 10.00 16219.11 15955.30 1.0165 263.81 12.00 12869.41 12677.83 1.0151 191.58 14.00 10372.78 10233.26 1.0136 139.52 16.00 8479.47 8377.94 1.0121 101.53 18.00 7020.29 6946.81 1.0106 73.48 20.00 5878.75 5826.19 1.0090 52.56 22.00 4973.29 4936.48 1.0075 36.81 24.00 4245.92 4221.07 1.0059 24.85 26.00 3654.80 3639.08 1.0043 15.72 EnaJi7orizedr- Discount Rate = 31r.a Transmission System Planning Division 21-Mar-95 11:20AM -52- Table 4.14 Summary Result of Economic Analysis (Continued) Project Transmission System Expansion Project No. 9 Region 2; Subproject No.7 Cost Stream Alternative A Benefit Stream Alternative D Discount Present Value Present Value B/C Present Value Rate of of Ratio of (%) Benefit Cost Net Benefit 4.00 36075.87 35529.68 1.0154 546.19 6.00 27096.99 26666.22 1.0162 430.77 8.00 20777.34 20431.63 1.0169 345.71 10.00 16237.27 15955.30 1.0177 281.97 12.00 12911.24 12677.83 1.0184 233.41 14.00 10429.07 10233.26 1.0191 195.81 16.00 8544.17 8377.94 1.0198 166.24 18.00 7089.44 6946.81 1.0205 142.63 20.00 5949.72 5826.19 1.0212 123.53 22.00 5044.35 4936.48 1.0219 107.87 24.00 4315.95 4221.07 1.0225 94.88 26.00 3723.05 3639.08 1.0231 83.98 Equalized Discount Rate = 145.89% Transmission System Planning Division 21 -Mar-95 11:22AM -53- SUBPROJECT NO.8 115 KV UDON THANI 2 - NONG BUA LAM PHU LINE AND SUBSTATIONS a) Load Forecast The electricity demand in this subproject area is forecasted as shown in Table 4.15. b) Alternative Plans The three possible alternative plans to serve the same technical objectives of this subproject as described in Volume I (Main Report) are Alternative A: Year 1998 - Construction of 1 15 kV Udon T hani 2 - Nong Bua Lam Phu line, single circuit on double circuit steel tower, using 795 MCM ACSR conductor, a distance of approximately 61 km. The economic cost is 176.7 MTHB. Year 2001 - Construction of 115 kV Nong Bua Lam Phu - Loei line, single circuit on double circuit steel tower, using 795 MCM ACSR conductor, a distance of approximately 79 km. The economic cost is 212.7 MTHB. -54- Year 2005 - Stringing 2nd circuit of 115 kV Udon Thani 2 - Nong Bua Lam Phu line, using 795 MCM ACSR conductor, a distance of approximately 61 km. The economic cost is 56.0 MTHB. Alternative B Year 1998 - Construction of 15 kV Udon Thani 2 - Nong Bua Lam Phu line, double circuit steel tower, using 795 MCM ACSR conductor, a distance of approximately 61 km. The economic cost is 226.4 MTiHB. Year 2001 - Construction of I1 5 kV Nong Bua Lam Phu - Loei line, single circuit on double circuit steel tower, using 795 MCM ACSR conductor, a distance of approximately 79 km. The economic cost is 212.7 MTHB. Alternative C Year 1998 - Construction of 230 kV Udon Thani 2 - Nong Bua Lam Phu line, double circuit steel tower, using 1,272 MCM ACSR conductor, a distance of approximately 61 km, initially energized at 115 kV. The economic cost is 319.7 MTHB. -55 - Year 2001 - Construction of 115 kV Nong Bua Lam Phu - Loei line, single circuit on double circuit steel tower, using 795 MCM ACSK conductor, a distance of approximately 79 km. The economic cost is 212.7 MTHB. c) Power Flow Diagrams The power flow diagrams for the proposed plan are given in Appendix 1. d) Results of Economic Analysis 1. Comparison of Present Value P.V. at 10 % DR. (MTHB) Alternative A 15,748.44 Alternative B 15,754.48 Alternative C 15,811.46 2. Net Present Value and B/C Ratio Net Present Value B/C Ratio EDR. (MTHB) !(% Alternative A VS. Alternative BI 6.04 1.0004 N.A. Alternative A VS. Alternative C 63.02 1.0040 >150.00 Results of the analysis have led to the conclusion that the construction of 115 kV Udon Thani 2 - Nong Bua Lam Phu single circuit on double circuit line is the least cost alternative. -56- Table 4.15 Load Forecast for Nong Bua Lam Phu and Loei Substations Subpro*ct No.S Fiscal Peak Demand Energy Demand Load Factor Year MW % Increase GWh % Increase (%) 1994 33.44 - 114.64 - 39.14 1995 55.97 a/ 67.37 196.94 a/ 71.79 40.17 1996 57.73 3.14 208.46 5.85 41.22 1997 62.20 7.74 225.51 8.18 41.39 1998 66.81 7.41 243.41 7.94 41.59 1999 71.50 7.02 263.50 8.25 42.07 2000 76.23 6.62 284.53 7.98 42.61 2001 81.05 6.32 306.84 7.84 43.22 2002 86.00 6.11 328.15 6.94 43.56 2003 91.11 5.94 350.70 6.87 43.94 2004 96.42 5.83 374.42 6.76 44.33 2005 101.98 5.77 399.88 6.80 44.76 2006 107.67 5.58 426.85 6.74 45.26 Note: a/ Highly demand increase due to transfered load from Udon Thani I Substation to newly constructed Nong Bua Lam Phu Substation. -57- Table 4.16 Summary Result of Economic Analysis Project Transmission System Expansion Project No. 9 Region 2; Subproject No. 8 Cost A;trem Aiternati-ve A Benefit Stream Alternative B Discount Present Value Present Value B/C Present Value Rate of of Ratio of (O) Benefit Cost Net Benefit 4.00 36256.30 36257.81 1.0000 -1.51 6.00 26928.60 26926.99 1.0001 1.60 8.00 20406.41 20402.29 1.0002 4.12 10.00 15754.48 15748.44 1.0004 6.04 12.00 12372.95 12365.50 1.0006 7.45 14.00 9870.27 9861.84 1.0009 8.43 16.00 7986.36 7977.30 1.0011 9.06 i8.00 6545.58 6536.15 1.0014 9.42 20.00 5427.30 5417.74 1.0018 9.57 22.00 4547.41 4537.85 1.0021 9.55 24.00 3846.28 3836.86 1.0025 9.42 26.00 3281.08 3271.88 1.0028 9.20 Equalized Discount Rate is Not Applicable Cost Stream Alternative A Benefit Stream Alternative C Discount Present Value Present Value B/C Present Value Rate of of Ratio of (%) Benefit Cost Net Benefit 4.00 36316.69 36257.81 1.0016 58.88 6.00 26989.66 26926.99 1.0023 62.67 8.00 . 20465.98 20402.29 1.0031 63.68 10.00 15811.46 15748.44 1.0040 63.02 12.00 12426.86 12365.50 1.0050 61.36 14.00 9920.94 9861.84 1.0060 59.10 16.00 8033.82 7977.30 1.0071 56.52 18.00 6589.94 6536.15 1.0082 53.78 20.00 5468.74 5417.74 1.0094 51.00 22.00 4586.10 4537.85 1.0106 48.25 24.00 3882.42 3836.86 1.0119 45.56 26.00 3314.85 3271.88 1.0131 42.97 Equalized Discount Rate is Greater Than 150% Transmission System Planning Division 21 -Mar-95 11:24AM -58- SUBPROJECT NO.9 115 KV ROI ET - PHAYAKKIAPHUM PHISAI - SURIN LINES AND SUBSTATIONS a) Load Forecast The electricity demand in this subproject area is forecasted as shown in Table 4.17. b) Alternative Plans The three possible alternative plans to serve the same technical objectives of this subproject as described in Volume I (Main Report) are Alternative A Year 1998 - Stringing 2nd circuit of 115 kV Roi Et - Phayakkhaphum Phisai line, using 795 MCM ACSR conductor, a distance of approximately 84 km. - Construction of 115 kV Phayakkhaphum Phisai - Surin line, single circuit on double circuit steel tower using 795 MCM ACSR conductor, a distance of approximately 80 km. The economic cost is 302.2 MTHB. Year 2003 - Stringing 2nd circuit of 115 kV Phayakkhaphum Phisai - Surin line, using 795 MCM ACSR conductor,. a distance of approximately 80 km. The economic cost is 66.0 MTHB. -59- Alternative B: Year 1998 - Construction of 115 kV Si Sa Ket - Surin line, single circuit on double circuit steel tower, using 795 MCM ACSR conductor, a distance of approximately 95 km. - Stringing 2nd circuit of 115 kV Roi Et - PhayakkhaphniWfiPhisai line, using 795 MCM ACSR conductor, a distance of approximately 84km. The economic cost is 335.6 MTHB. Year 2003 * Stringing 2nd circuit of 115 kV Si Sa Ket - Surin line, using 795 MCM ACSR conductor, a distance of approximately 95 km. The economic cost is 74.1 MTHB. Altenative C Year 1998 - Construction of 115 kV Buri Ram - Surin line, single circuit on double circuit steel tower, using 795 MCM ACSR conductor, a distance of approximately 47 km. - Construction of 115 kV Phayakkhaphum Phisai - Surin line, single circuit on double circuit steel tower, using 795 MCM ACSR conductor, a distance of approximately 80 km. -60- - Reconstruction of the existing 115 kV Nakhon Ratchasima 1 - Buri Ram from single circuit line to double circuit line, using 795 MCM ACSR conductor, a distance of approximately 111 km. The economic cost is 633.4 MTHB. Year 2003 - Stringing 2nd circuit of 115 kV Buri Ram - Surin line, using 795 MCM ACSR conductor, a distance of approximately 47 km. The economic cost is 49.3 MTHB. Year 2006 - Reconstruction of the existing 115 kV Nakhon Ratchasima I - Nakhon Ratchasima 2 from single circuit line to double circuit line, using 2x795 MCM ACSR conductor, a distance of approximately 12 km. - Stringing 2nd circuit of 115 kV Phayakkhaphum Phisai - Surin line, using 795 MCM ACSR conductor, a distance ofapproximately 80 km. The economic cost is 125.3 MTHB. c) Power Flow Diagrams The power flow diagrams for the proposed plan are given in Appendix 1. -61- d) Results of Economic Analysis 1. Comparison of Present Value P.V. at 10 % DR. (MTHB) Alternative A 16,341.97 Alternative B 16,409.12 Alternative C 16,629.36 2. Net Present Value and B/C Ratio Net Present Value B/C Ratio EDR. (M iITB) (%) Alternative A VS. Alternative B 67.15 1.0041 58.57 Alternative A VS. Altemative C 287.38 1.0176 >150.00 Results of the analysis have led to the conclusion that the line stringing of 2nd circuit of Roi Et - Phayakkhaphum Phisai and construction of 115 kV Phayakkhaphum Phisai - Surin transmission system project is the least cost alternative. -62- Table 4.17 Load Forecast for Phayakkhaphum Phisai and Surin Substations Subpropet NoS Fiscal Peak Demand Energy Demand Load Factor Year MW % Increase GWh % Increase (%) 1994 52.80 - 215.83 - 46.66 1995 77.05 a/ 45.93 291.53 g 35.07 43.19 1996 83.28 8.09 321.81 10.39 44.11 1997 89.17 7.07 345.36 7.32 44.21 1998 95.11 6.66 369.52 7.00 44.35 1999 101.13 6.33 396.73 7.36 44.78 2000 107.15 5.95 425.02 7.13 45.28 2001 113.28 5.72 455.02 7.06 45.85 2002 119.47 5.46 482.85 6.12 46.14 2003 125.89 5.37 512.47 6.13 46.47 2004 132.57 5.31 543.62 6.08 46.81 2005 139.52 5.24 576.84 6.11 47.20 2006 146.76 5.19 612.64 6.21 47.65 Note: e/ Highly demand increase due to transfered load from Maha Sarekham and Roi Et Substation to newly constructed Phayakkhaphum Phisai Substation. -63- Table 4.18 Summary Result of Economic Analysis Project Transmission System Expansion Project No. 9 Region 2; Subproject No. 9 Cost Stream Alternative A Benefit Stream Alternative B Discount Present Value Present Value B/C Present Value Rate of of Ratio of (%) Benefit Cost Net Benefit 4.00 37417.47 37300.41 1.0031 117.07 6.00 27873.88 27777.58 1.0035 96.31 8.00 21187.93 21107.87 1.0038 80.07 10.00 16409.12 16341.97 1.0041 67.15 12.00 12927.44 12870.72 1.0044 56.72 14.00 10344.40 10296.21 1.0047 48.19 16.00 8395.10 8353.98 1.0049 41.13 18.00 6900.46 6865.24 1.0051 35.22 20.00 5737.35 5707.11 1.0053 30.25 22.00 4819.79 4793.77 1.0054 26.02 24.00 4086.75 4064.36 1.0055 22.40 26.00 3494.33 3475.05 1.0055 19.28 Equalized Discount Rate = 58.57% Cost Stream Alternative A Benefit Stream Alternative C Discount Present Value Present Value B/C Present Value Rate of of Ratio of (%) Benefit Cost Net Benefit 4.00 37664.77 37300.41 1.0098 364.36 6.00 28116.56 27777.58 1.0122 338.98 8.00 21420.51 21107.87 1.0148 312.64 10.00 16629.36 16341.97 1.0176 287.38 12.00 13134.76 12870.72 1.0205 264.04 14.00 10539.06 10296.21 1.0236 242.85 16.00 8577.77 8353.98 1.0268 223.79 18.00 7071.93 6865.24 1.0301 206.70 20.00 5898.49 5707.11 1.0335 191.38 22.00 4971.40 4793.77 1.0371 177.63 24.00 4229.61 4064.36 1.0407 165.25 26.00 3629.13 3475.05 1.0443 154.08 Equalized Discount naie is Greater Than 150% Transmission System Planning Division 21 -Mar-95 11:26 AM -64- SUBPROJECT NO.10 115 KV CHAIYAPHUM - BAMNET NARONG LINE AND SUBSTATIONS a) Load Forecast The electricity demand in this subproject area is forecasted as shown in Table 4.19. b) Alternative Plans The three possible alternative plans to serve the same technical objectives of this subproject as described in Volume I (Main Report) are Alternative A Year 1998 * Construction of 115 I-V Chai-aphum - Bim. net NTrong line, siLng circui on double circuit steel tower, using 795 MCM ACSR conductor, a distance of approximately 58 km. The economic cost is 251.7 MTHB. Alternative B Year 1998 - Construction of 115 kV Nakhon Ratchasima 2 - Bamnet Narong line, single circuit on double circuit steel tower, using 795 MCM ACSR conductor, a distance of approximately 65 km. The economic cost is 264.1 MTHB. -65- Alternative C: Year 1998 - Installation of three units 25 MW gas turbine power plant at Bamnet Narong Substation. The economic cost is 1,134.0 MTHB. The installation schedules of Alternative A, B and C are shown in Figures 4.1 to 4.3. c) Power Flow Diagrams The power flow diagrams for the proposed plan are given in Appendix 1. d) Results of Economic Analysis 1. Comparison of Present Value P.V. at 10 % DR. (MTHB) Alternative A 22,059.14 Alternative B 22,124.52 Alternative C 23,068.70 2. Net Present Value and B/C Ratio Net Present Value B/C Ratio EDR. (MTHB) (%_ Alternative A VS. Alternative B 65.38 1.0030 >150.00 Alternative A VS. Alternative C 1,009.56 1.0458 62.81 Results of the analysis have led to the conclusion that the construction of the proposed 115 kV Chaiyaphum - Bamnet Narong transmission system project is the least cost alternative. -66- Table 4.19 Load Forecast for Bamnet Narong Substation Subprojec No.10 Fiscal Peak Demand Energy Demand Load Factor Year MW % Increase GWh % Increase (%) 1994 14.00 - 61.40 - 50.07 1995 18.00 28.57 a 70.20 14.33 at 44.52 1996 19.20 6.67 79.20 12.82 47.09 1997 35.50 84.90 a/ 116.50 47.10 a/ 37.46 1998 36.80 3.66 189.00 62.23 58.63 1999 38.10 3.53 222.30 17.62 66.61 2000 39.40 3.41 253.10 13.86 73.33 2001 40.80 3.55 260.50 2.92 72.89 2002 42.20 3.43 268.10 2.92 72.52 2003 43.60 3.32 276.00 2.95 72.26 2004 45.00 3.21 284.10 2.93 72.07 2005 46.40 3.11 292.60 2.99 71.99 2006 47.79 3.00 301.30 2.97 71.97 Note: _l Highly demand increase due to demand of Asean Potash Mine Project. -67- Table 4.20 Summary Result of Economic Analysis Project Transmission System Expansion Project No. 9 Region 2; Subproject No. 10 Cost Stream : AterMftve A Benefit Stream Alternative B Discount Present Value Present Value B/C Present Value Rate of of Ratio of (%) Benefit Cost Net Benefit 4.00 50673.11 50555.92 1.0023 117.19 6.00 37685.21 37590.60 1.0025 94.61 8.00 28603.47 28525.52 1.0027 77.95 10.00 22124.52 22059.14 1.0030 65.38 12.00 17412.91 17357.23 1.0032 55.68 14.00 13923.60 13875.55 1.0035 48.06 16.00 11294.79 11252.85 1.0037 41.94 18.00 9282.21 9245.25 1.0040 36.97 20.00 7718.22 7685.37 1.0043 32.85 22.00 6485.87 6456.47 1.0046 29.40 24.00 5502.38 5475.90 1.0048 26.48 26.00 4708.20 4684.23 1.0051 23.98 Equalized Discount Rate is Greater Than 150% Cost Stream Alternative A Benefit Stream Alternative C Discount Present Value Present Value B/C Present Value Rate of of Ratio of (%) Benefit Cost Net Benefit 4.00 52970.30 50555.92 1.0478 2414.38 6.00 39366.42 37590.60 1.0472 1775.81 8.00 29853.89 28525.52 1.0466 1328.37 10.00 23068.70 22059.14 1.0458 1009.56 12.00 18135.85 17357.23 1.0449 778.62 14.00 14484.16 13875.55 1.0439 608.61 16.00 11734.33 11252.85 1.0428 481.48 18.00 9630.25 9245.25 1.0416 385.00 20.00 7996.09 7685.37 1.0404 310.73 22.00 6709.27 6456.47 1.0392 252.80 24.00 5682.96 5475.90 1.0378 207.06 26.00 4854.78 4684.23 1.0364 170.55 Equalized Discount Rate = 62.81% Transmission System Planning Division 21-Mar-95 11:28AM -68- Capacity (MW) 120 - 110 - 115 kV Chaiyaphum - Bamnet Narong SC on DC/ST 795 MCM ACSR 100 - E 90 - Installed Capac¢v U, 80 - o 80~~~ 70 - 0 60- 50 - U3 40 0. ~~~~~~~~~Peak Demand 30 - 20- 10 0 1993 1 1994 1 1995 1 1996 1 1997 1 1998 1 1999 1 2000 2 2001 I 2002 I 2003 1 2004 1 2005 1 2006 1 2007 Fiscal Yeair Figure 4.1 Installation Schedule for Subproject No. 10 (Bamnet Narong Substation) Alternative A (Capacity (MW) 120 - 110 - 115 kV Nakhon Ratchasima 2 - Barnnet Narong SC on DC/ST 795 MCM ACSR 100 - E 90 - E t K Installed Capacity U) 80 u 70 -0 60- 50 - U .0 40 -....... Peak Demand 30- 20 - 10__________ 0 - 1993 1 1994 1 1995 1 1996 1 1997 1 1998 1 1999 1 2000 1 2001 1 2002 1 2003 1 2004 r 2005 Fiscal Year Figure 4.2 Installation Schedule for Subproject No. 10 (Bamnet NarongSubstation) Altemative B 4 4 Capacity (MW) 120 - 110 - Gas Turbine 3x25 MW 100 - 90- 0 I Installed Crapacity 80 70 - 60- - *. Firm Capacily 50 - 40 - 3 _ Peak Dernand 0. 30- 20- 10 0 1993 1 1994 1 1995 1996 1 1997 1 1998 1 1999 1 2000 1 2001 2002 1 2003 1 2004 1 2005 1 2006 7 2007 Fiscal Year Figure 4.3 Installation Schedule for Subproject No. 10 (Bamnet Narong Substation) Alternative C SUBPROJECT NO.11 115 KV UBON RATCHATHIANI 2 - KANTHARALAK LINE AND SUBSTATIONS a) Load Forecast The electricity demand in this subproject area is forecasted as shown in Table 4.21. b) Alternative Plans The three possible alternative plans to serve the same technical objectives of this subproject as described in Volume I (Main Report) are Alternative A: Year 1998 - Construction of 115 kV Ubon Ratchathani 2 - Kantharalak line, single circuit on double circuit steel tower, using 795 MCM ACSR conductor, a distance of approximately 55 km. The economic cost is 247.0 MTHB. Alternative B Year 1998 - Construction of 115 kV Si Sa Ket - Kantharalak line, single circuit on double circuit steel tower, using 795 MCM ACSR conductor, a distance of approximately 65 km. The economic cost is 267.2 MTHB. -72- Alternative C Year 1998 - Installation of two units 25 MW gas turbine power plant at Kantharalak Substation. The economic cost is 756.0 MTHB. Year 2001 - Installation of one unit 25 MW gas turbine power plant at Kantharalak Substation. The economic cost is 378.0 MTHB. The installation schedules of Alternative A, B and C are shown in Figures 4.4 to 4.6. c) Power Flow Diagrams The power flow diagrams fQr the proposed plan are given in Appendix 1. d) Results of Economic Analysis 1. Comparison of Present Value P.V. at 10 % DR. (MTHB) Alternative A 15,305.51 Alternative B 15,332.73 Alternative C 15,755.06 -73- 2. Net Present Value and B/C Ratio Net Present Value B/C Ratio EDR. (MHB ______ s o Altemative A VS. Alternative B 27.22 1.0018 >150.00 Alternative A VS. Alternative C 449.55 1.0294 83.90 Results of the analysis have led to the conclusion that the construction of the proposed 115 kV Ubon Ratchathani 2 - Kantharalak transmission system project is the least cost alternative. -74- Table 4.21 Load Forecast for Kantharalak Substation Subpro*ct No.l I Fiscal Peak Demand Energy Demand Load Factor Year MW % Increase GWh % Increase (%) 1994 13.50 - 48.60 - 41.10 1995 15.00 11.11 54.70 12.55 41.63 1996 16.60 10.67 61.10 11.70 42.02 1997 18.20 9.64 67.30 10.15 42.21 1998 19.90 9.34 74.70 11.00 42.85 1999 21.70 9.05 82.00 9.77 43.14 2000 23.50 8.29 89.60 9.27 43.52 2001 25.30 7.66 97.60 8.93 44.04 2002 27.30 7.91 103.10 5.64 43.11 2003 29.80 9.16 114.60 11.15 43.90 2004 31.20 4.70 123.70 7.94 45.26 2005 33.40 7.05 133.30 7.76 45.56 2006 35.60 6.59 143.40 7.58 45.98 -75- Table 4 .22 Summary Result of Economic Analysis Project Transmission System Expansion Project No. 9 Region 2; Subproject No. 11 r(riqt Stream : Altema` A Benefit Stream Alternative B Discount Present Value Present Value B/C Present Value Rate of of Ratio of (%) Benefit __- Cost Net Benefit 4.00 35190.32 35144.81 1.0013 45.52 6.00 26152.80 26115.06 1.0014 37.74 8.00 19836.45 19804.63 1.0016 31.82 10.00 15332.73 15305.51 1.0018 27.22 12.00 12059.40 12035.80 1.0020 23.60 14.00 9636.66 9615.97 1.0022 20.69 16.00 7812.47 7794.15 1.0024 18.32 18.00 6416.71 6400.35 1.0026 16.36 20.00 5332.66 5317.95 1.0028 14.71 22.00 4478.95 4465.63 1.0030 13.32 24.00 3797.97 3785.85 1.0032 12.12 26.00 3248.34 3237.25 1.0034 11.08 Equalized Discount Rate is Greater Than 150% Cost Stream Alternative A Benefit Stream Alternative C Discount Present Value Present Value B/C Present Value Rate of of Ratio of (%) Benefit --Cost Net Benefit 4.00 36183.06 35144.81 1.0295 1038.25 6.00 26886.55 26115.06 1.0295 771.49 8.00 20388.41 19804.63 1.0295 583.78 10.00 15755.06 15305.51 1.0294 M9.55 12.00 12387.75 12035.80 1.0292 351.94 14.00 9895.73 9615.97 1.0291 279.76 16.00 8019.62 7794.15 1.0289 225.47 18.00 6584.31 6400.35 1.0287 183.96 20.00 5469.68 5317.95 1.0285 151.73 22.00 4591.96 4465.63 1.0283 126.33 24.00 3891.89 3785.85 1.0280 106.04 26.00 3326.89 3237.25 1.0277 89.63 Equalized Discount Rate 83.90% Transmission System Planning Division 21 -Mar-95 11:29 AM -76- Capacity (MW) 150 - 140 - 130 - 120 - 115 kV Ubol Ratchathani 2 - Kantharalak 110 - 1 SC on DC/ST 795 MCM ACSR 100 - o 90 - 4 Installed Capacity 80 _ 70- 60 - . 50 - 'O 40 - 30- 20 -Peak Demand 1 0 0-° 1993 1994 1995 1996 1997 1998 1999 2000 1 2001 1 2002 1 2003 1 2004 1 2005 1 2006 I 2)07 Fiscal Year Figure 4.4 Installation Schedule For Subproject No. 11 (Kantharalak Substation) Alternative A Capacity (MW) 150 - 140 - 130 - 120 - E 115 kV Si Sa Ket - Kantharalak 110 - I SC on DC/ST 795 MOM ACSR 100 Cl)_ 90 - Installed Capacity 80 - co 70 - 60 - 50- 40- 30- 20 --~ekDmn 1 0 0 - l1993 1 1994 1 1995 1 1996 1 1997 ! 1998 1 19991 2000 1 2001 1 2002 1 2003 1 20047 12005l12006 1 2007 Fiscal Year Figure 4.5 Installation Schedule for Subproject No. 11 (Kantharalak Substation) Alternative B Capacity (MW) 100 - 90 - GasTurbine 1x25MW 80 - Installed Capacity E Gas Turbine 70 - ,l 2x25 MW 70 - > CD 60 s n l 2 60~~~~. t5- .a Firm Capacity 30 A! 20 - T _ mand 20 10 l 0 1993 1 1994 1 1995 1 1996 1 1997 1 1998 1 1999 2000 1 2001 1 2002 2003 1 2004 1 2005 1 2006 1 2007 Fiscal Year Figure 4.6 Installation Schedule for Subproject No.11 (Kantharalak Substation) Alternative C SUBPROJECT NO.12 115 KV SURIN - SANGKIIA LINE AND SUBSTATIONS a) Load Forecast The electricity demand in this subproject area is forecasted as shown in Table 4.23. b) Alternative Plans The three possible alternative plans to serve the same technical objectives of this subproject as described in Volume I (Main Report) are Alternative A: Year 1998 - Construction of 115 kV Surin - Sangkha line, single circuit on double circuit steel tower, using 795 MCM ACSR conductor, a distance of approximately 49 km. The economic cost is 230.7 MTHB. Alternative B xYear 1998 - Construction of 115 kV Si Sa Ket - Sangkha line, single circuit on double circuit steel tower, using 795 MCM ACSR conductor, a distance of approximately 74 km. The economic cost is 291.6 MTHB. -80 - Alternative C Year 1998 - Construction of 22 kV Surin - Sangkha distribution line with automatic voltage regulators (AVR), using 185 sq.mm AAC conductor, a distance of approximately 66 km. The economic cost is 111.58 MTHB. Year 2000 - Construction of 115 kV Surin - Sangkha line, single circuit on double circuit steel tower, using 795 MCM ACSR conductor, a distance of approximately 49 km. The economic cost is 230.7 MTIHB. The installation schedules of Alternative A, B and C are shown in Figure 4.7 to 4.9. c) Power Flow Diagrams The power flow diagrams for the proposed plan are given in Appendix 1. d) Results of Economic Analysis 1. Comparison of Present Value P.V. at 10 % DR. (MTHB) Alternative A 15,138.38 Alternative B 15,230.78 Altemative C 15,181.33 -81- 2. Net Present Value and B/C Ratio Net Present Value B/C Ratio EDR. (MTIHB! _ _ _ Alternative A VS. Alternative B 92.40 1.0061 >150.00 Alternative A VS. Alternative C 42.95 1.0028 30.63 Results of the analysis have led to the conclusion that the construction of the proposed 115 kV Surin - Sangkha transmission system project is the least cost alternative. -82- Tabie 4.23 Load Forecast for Sangkha Substation Subvqfd tNo.12 Fiscal Peak Demand Energy Demand Load Factor Year MW % Increase GWh % Increase (%) 1994 9.80 - 35.20 - 41.00 1995 11.10 13.27 40.10 13.92 41.24 1996 12.40 11.71 45.40 13.22 41.80 1997 13.80 11.29 51.00 12.33 42.19 1998 15.30 10.87 56.90 11.57 42.45 1999 16.80 9.80 63.10 10.90 42.88 2000 18.40 9.52 69.50 10.14 43.12 2001 20.00 8.70 76.20 9.64 43.49 2002 21.70 8.50 83.20 9.19 43.77 2003 23.40 7.83 90.60 8.89 44.20 2004 25.10 7.26 98.10 8.28 44.62 2005 26.90 7.17 106.00 8.05 44.98 2006 28.80 7.06 114.10 7.64 45.23 -83- Table 4 .24 Summary Result of Economic Analysis Project Transmission System Expansion Project No. 9 Region 2; Subproject No. 12 Cost Stream Alternative A Benefit Stream Alternative B Discount Present Value Present Value B/C Present Value Rate of of Ratio of (%) Benefit Cost Net Benefit 4.00 35053.84 34870.91 1.0052 182.94 6.00 26028.19 25885.72 1.0055 142.47 8.00 19723.51 19609.98 1.0058 113.53 10.00 15230.78 15138.38 1.0061 92.40 12.00 11967.54 11890.88 1.0064 76.66 14.00 9553.93 9489.22 1.0068 64.70 16.00 7737.92 7682.47 1.0072 55A5 18.00 6349.47 6301.32 1.0076 48.16 20.00 5271.94 5229.62 1.0081 42.31 22.00 4424.02 4386.47 1.0086 37.55 24.00 3748.20 3714.58 1.0091 33.63 26.00 3203.16 3172.83 1.0096 30.34 Equalized Discount Rate is Greater Than 150% Cost Stream Alternative A Benefit Stream Alternative C Discount Present Value Present Value B/C Present Value Rate of of Ratio of (%) Benefit Cost Net Benefit 4.00 34938.77 34870.91 1.0019 67.86 6.00 25945.46 25885.72 1.0023 59.73 8.00 19661.13 19609.98 1.0026 51.15 10.00 15181.33 15138.38 1.0028 42.95 12.00 11926.37 11890.88 1.0030 35.49 14.00 9518.12 9489.22 1.0030 28.89 16.00 7705.62 7682.47 1.0030 23.14 18.00 6319.50 6301.32 1.0029 18.19 20.00 5243.56 5229.62 1.0027 13.93 22.00 4396.77 4386.47 1.0023 10.31 24.00 3721.80 3714.58 1.0019 7.22 26.00 3177.43 3172.83 1.0015 4.61 Equalized Discount Rate 30.63% Transmission System Planning Division 21-Mar-95 11.31 AM -84- Capacit (MW) ISO 140 130 120 10 E .9115kv Sunn - Sangkha 100 C1 SC on DCIST 795 MCM ACSR 90 1l 00 80 Q0 70 60 dl s0 40 -a. 30 20 10 I Peak Demand °~~~~~~~9 5997 999i Fiscal Ye Noar FigUre 4. Installation Schedule for Subprojlect No. 12 (Sangqkha Substation) Afternative A CaPaCitY (I\mwl) 150 - 130 -; t100 d EV 115kV S'SaKet - Sangkha l c c SC On DC/ST 795 MCM ACSR 90- ,.9 , 80 -1 XE lA lIstalledCa ac I 1 701 9 1 I 9 9 8 1 0 60s a e f o o n0 b a B 20-i1 I 10-l 0 d 0 Fl9lr 4-8 angkhallttn Schedule for -Subproiect No. 12 (SankhaSubstation) AlternativeB Capacity (MW) 150 - 140 - 130 - 120 - E 115 kV Surin - Sangkha 110 - SC on DC/ST 795 MCM ACSR 100 - . 0. X 90 - OInstalled Capacity 80 - CD CD) 70 , CD 60 UlFca 50 -c 40 -C 30~~~~~~: 20 PeakDemand 1 0 0 993 1 1994 1995 1 1996 I1997 I1998 I1999 I2000 12001 12002 1 2003 12004 12005 12006 I7 2007 Fiscal Year Figure 4.9 Installation Schedule for Subproject No. 12 (Sangkha Substation) Alterrative C SUBPROJECT NO.13 230 KV NAKHON SI THAMMARAT - THUNG SONG - SURAT THANI LINES AND SUBSTATIONS a) Load Forecast The electricity demand in this subproject area is forecasted as shown in Table 4.25. b) Alternative Plans The four possible alternative plans to serve the same technical objectives of this subproject as described in Volume 1 (Main Report) are Alternative A: Year 1998 - Reconstruction of the existing Nakhon Si Thammarat -Thung Song from 115 kV single circuit line to 230 kV double circuit line, using 1,272 MCM ACSR conductor, a distance of approximately 54 km, initially energized at 115 kV. - Reconstruction of the existing Surat Thani - Thung Song from 115 kV double circuit line to 230 kV double circuit line. using 2x1,272 MCM ACSR conductor, a distance of approximately 122 km. - Installation of 2x200 MVA 230/115 kV transformer at Thung Song Substation. The economic cost is 1,561.2 MTHB. Year 2003 - Conversion of 230/115 kV Nakhon Si Thammarat - Thung Song line to energized at 230 kV. -88- The economic cost is 95.8 MTHB. Alternative B Year 1998 - Reconstruction of the existing Nakhon Si Thammarat - Thung Song from 115 kV single circuit line to 230 kV double circuit line, using 1,272 MCM ACSR conductor, a distance of approximately 54 km. - Construction of 230 kV Surat Thani - Nakhon Si Thammarat line, double circuit steel tower, using 2x1,272 MCM ACSR conductor, a distance of approximately 145 km. - Installation of 2x200 MVA 230/115 kV transformer at Thung Song Substation. The economic cost is 2,291.9 MTHB. Year 2006 - Installation of xlO0 MVA 230/115 kV transformer at Surat Thani Substation. The economic cost is 67.8 MTHB. Alternative C Year 1998 - Reconstruction of the existing Nakhon Si Thammarat - Thung Song from 115 kV single circuit line to 230 kV double circuit line, using 1,272 MCM ACSR conductor, a distance of approximately 54 km. -89- - Construction of 230 kV Khanom - Nakhon Si Thammnarat line, double circuit line, using 2x1,272 MCM ACSR conductor, a distance of approximately 98 km. - Installation of 2x200 MVA 230/115 kV tmnsformer at Thung Song Substation. The economic cost is 1,815.3 MTHB. Year 2006 - Installation of lxlOO MVA 230/115 kV transformer at Surat Thani Substation. The economic cost is 72.1 MTHB. Alternative D Year 1998 - Reconstruction of the existing Surat Thani - Thung Song from 115 kV double circuit line to 230 kV double circuit line, using 2x1272 MCM ACSR conductor, a distance of approximately 122 km. - Installation of 2x200 MVA 230/115 kV transformers at Thung Song Substation. - Termination of 230 kV Nakhon Si Thammarat - Phatthalung and 230 kV Thung Song - Khlong Ngae lines at Phatthalung 2 Substation. The economic cost is 1,696.8 MTHB. c) Power Flow Diagrams The power flow diagrams for the proposed plan are given in Appendix 1. -90- d) Results of Economic Analysis 1. Comparison of Present Value P.V. at 10 % DR. (MTHB) Alternative A 33,050.00 Alternative B 33,619.14 Alternative C 33,114.72 2. Net Present Value and B/C Ratio Net Present Value B/C Ratio EDR. (MTHB) _ _ _ Alternative A VS. Alternative B 569.14 1.0172 107.18 Alternative A VS. Alternative C 64.73 1.0020 32.62 Results of the analysis have led to the conclusion that the construction of 230 kV Nakhon Si Thammarat - Thung Song - Surat Thani transmission system project is the least cost alternative. -91- Table 4.25 Load Forecast for Lower Southern Region SubproFct No.13 Fiscal Peak Demand Energy Demand Load Factor Year MW % Increase GWh % Increase (%) 1994 489.79 - 2738.64 - 63.83 1995 556.30 13.58 2985.10 9.00 61.26 1996 644.99 15.94 3441.59 15.29 60.91 1997 711.87 10.37 3801.86 10.47 60.97 1998 771.42 8.37 4089.85 7.57 60.52 1999 828.65 7.42 4384.66 7.21 60.40 2000 888.19 7.19 4687.14 6.90 60.24 2001 946.69 6.59 5000.04 6.68 60.29 2002 1008.55 6.53 5283.50 5.67 59.80 2003 1068.39 5.93 5575.11 5.52 59.57 2004 1130.51 5.81 5883.77 5.54 59.41 2005 1192.03 5.44 6198.27 5.35 59.36 2006 1255.76 5.35 6527.41 5.31 59.34 -92- Table 4 . 2 6 Summary Result of Economic Analysis Project Transmission System Expansion Project No. 9 Region 3; Subproject No.13 Cost Stream Alternative A Benefit Stream Alternative B Discount Present Value Present Value B/C Present Value Rate of of Ratio of (%) Benefit Cost Net Benefit 4.00 72755.72 71923.23 1.0116 832.49 6.00 55162.17 54431.47 1.0134 730.70 8.00 42671.54 42027.94 1.0153 643.60 1 0.'' '00 0 l00033619.14, '33050.00 :1.017 569.14 12.00 26929.38 26424.08 1.0191 505.30 14.00 21894.41 21444.09 1.0210 450.32 16.00 18039.86 17637.17 1.0228 402.69 18.00 15042.21 14681.02 1.0246 361.20 20.00 12677.03 12352.18 1.0263 324.85 22.00 10786.00 10493.15 1.0279 292.85 24.00 9255.70 8991.15 1.0294 264.54 26.00 8003.59 7764.20 1.0308 28903 Equalized Discount Rate = 107.18% Cost Stream Alternative A Benefit Stream Alternative C Discount Present Value Present Value B/C Present Value Rate of of Ratio of (%) Benefit Cost Net Benefit 4.00 71986.19 71923.23 1.0009 62.96 6.00 54501.02 54431.47 1.0013 69.55 8.00 42096.97 42027.94 1.0016 69.03 it00000010.0S,-0 3314.2 33050.00 1-0020: 04.73 12.00 26482.61 26424.08 1.0022 58.53 14.00 21495.64 21444.09 1.0024 51.54 16.00 17681.55 17637.17 1.0025 44.38 18.00 14718.42 14681.02 1.0025 37.40 20.00 12382.97 12352.18 1.0025 30.79 22.00 10517.78 10493.15 1.0023 24.63 24.00 9010.12 8991.15 1.0021 18.97 26.00 7778.00 7764.20 1.0018 13.81 Equalized Discount Rate = 32.62% Transmission System Planning Division 21-Mar-95 11:34 AM -93- Table 4.26 Summary Result of Economic Analysis (Continued) Project Transmission System Expansion Project No. 9 Region 3; Subproject No.13 Cost Stre;am : A;te,nFa,,v6e A Benefit Stream Alternative D Discount Present Value Present Value B/C Present Value Rate of of Ratio of (%) Benefit Cost Net Benefit 4.00 72086.62 71923.23 1.0023 163.39 6.00 54562.08 54431.47 1.0024 130.61 8.00 42135.81 42027.94 1.0026 107.87 10.00 33141.47 33050.00 1.0028 91.47 12.00 26503.27 26424.08 1.0030 79.19 14.00 21513.76 21444.09 1.0032 69.67 16.00 17699.22 17637.17 1.0035 62.05 18.00 14736.80 14681.02 1.0038 55.78 20.00 12402.70 12352.18 1.0041 50.52 22.00 10539.16 10493.15 1.0044 46.01 24.00 9033.25 8991.15 1.0047 42.10 26.00 7802.85 7764.20 1.0050 38.66 Equalized Discount Rate is Greater Than 150% Transmission System Planning Division 21 - Mar-95 11:36 AM -94- SUBPROJECT NO.14 230 KV KHLONG NGAE - YALA LINE AND SUBSTATIONS a) Load Forecast The electricity demand in this subproject area is forecasted as shown in Table 4.27. b) Alternative Plans The three possible alternative plans to serve the same technical objectives of this subproject as described in Volume I (Main Report) are Alternative A: Year 1998 - Construction of 230 kV Khlong Ngae - Yala line, double circuit steel tower, ising 1 j272 MCM ACSR rnuictor, a itanc osf a 120 km. (usicn existing right-of-way of existing 115 kV Hat Yai 2 - Yala line). - Construction of 230 kV Yala Substation with 2x200 MVA 230/115 kV transforners. The economic cost is 934.4 MTHB. Alternative B Year 1998 - Construction of 230 kV Khlong Ngae - Yala line, double circuit steel tower, using 1,272 MCM ACSR conductor, a distance of approximately 120 km (using existing right-of-way of 115 kV Hat Yai 2 - Yala line), initially energized at 115 kV. - Installation of 2x200 MVA 230/115 kV transformer at Khlong Ngae Substation. The economic cost is 896.6 MTHB. -95- Year 2006 - Installation of 1 x200 MVA 230/115 kV transformer at Hat Yai 2 a-abstationl. The economic cost is 89.4 MTHB. Alternative C: Year 1998 - Construction of 230 kV Khlong Ngae - Yala line, double circuit steel tower, using 1,272 MCM ACSR conductor, a distance of approximately 120 km. - Construction of 230 kV Yala Substation with 2x200 MVA 230/115 kV transformer. The economic cost is 1,258.0 MTHB. c) Power Flow Diagrams The power flow diagrams for the proposed plan are given in Appendix 1. d) Results of Economic Analysis 1. Comparison of Present Value P.V. at 10 % DR. (MTHB) Alternative A 20,548.56 Alternative B 20,657.35 Alternative C 20,891.41 Alternative D 20,800.02 -96- 2. Net Present Value and B/C Ratio Net Present Value B/C Ratio EDR.- (MTHB) Alternative A VS. Alternative B 108.78 1.0053 41.25 Alternative A VS. Alternative C 251.45 1.0122 >150.00 Results of the analysis have led to the conclusion that the construction of 230 kV Khlong Ngae - Yala transmission system project is the least cost alternative. -97- Table 4.27 Load Forecast for Yala, Pattani, Narathiwat, and Sugai Kolok Substations Subprojc No.14 Fiscal Peak Demand Energy Demand Load Factor Year MW % Increase GWh % Increase (%) 1994 98.82 - 533.05 - 61.58 1995 119.84 21.27 600.50 12.65 57.20 1996 129.29 7.89 645.69 7.53 57.01 1997 139.02 7.53 692.00 7.17 56.82 1998 149.11 7.26 732.94 5.92 56.11 1999 159.58 7.02 779.98 6.42 55.80 2000 170.43 6.80 830.36 6.46 55.62 2001 181.63 6.57 885.99 6.70 55.68 2002 193.33 6.44 938.56 5.93 55.42 2003 205.46 6.27 994.43 5.95 55.25 2004 218.30 6.25 1054.69 6.06 55.15 2005 231.44 6.02 1118.38 6.04 55.16 2006 245.03 5.87 1184.97 5.95 55.21 -98- Table 4.28 Summary Result of Economic Analysis Project Transmission System Expansion Project No. 9 Region 3; Subproject No.14 Cost Stream Alternative A Benefit Stream Alternative B Discount Present Value Present Value B/C Present Value Rate of of Ratio of (%) Benefit Cost Net Benefit 4.00 45971.56 45701.70 1.0059 269.85 6.00 34513.39 34316.49 1.0057 196.89 8.00 26449.60 26304.06 1.0055 145.54 10.00 20657.35 20548.56 1.0053 108.78 12.00 16414.78 16332.73 1.0050 82.05 14.00 13249.43 13187.09 1.0047 62.34 16.00 10846.56 10798.94 1.0044 47.62 18.00 8992.85 8956.36 1.0041 36.49 20.00 7541.29 7513.28 1.0037 28.01 22.00 6388.87 6367.40 1.0034 21.47 24.00 5462.33 5445.93 1.0030 16.40 26.00 4708.71 4696.27 1.0026 12.44 Equalized Discount Rate = 41.25% Cost Stream Alternative A Benefit Stream Alternative C Discount Present Value Present Value B/C Present Value Rate of of Ratio of (M) Benefit Cost Net Benefit 4.00 45983.12 45701.70 1.0062 281.42 6.00 34590.93 34316.49 1.0080 274.44 8.00 26567.75 26304.06 1.0100 263.69 10.00 20800.02 20548.56 1.0122 251.45 12.00 16571.62 16332.73 1.0146 238.90 14.00 13413.70 13187.09 1.0172 226.61 16.00 11013.82 10798.94 1.0199 214.68 18.00 9160.16 8956.36 1.0228 203.80 20.00 7706.70 7513.28 1.0257 193.42 22.00 6551.12 6367.40 1.0289 183.72 24.00 5620.58 5445.93 1.0321 174.66 26.00 4862.46 4696.27 1.0354 166.19 Equalized Discount Rate is Greater Than 150% Transmission System Planning Division 21 -Mar-95 11:42 AM -99- SUBPROJECT NO.15 230/115 KV PHANGNGA - PHUKET JUNCTION - PHUKET 2 LINES AND SUBSTATIONS a) Load Forecast The electricity demand in this subproject area is forecasted as shown in Table 4.29. b) Alternative Plans The three possible alternative plans to serve the same technical objectives of this subproject as described in Volume I (Main Report) are Alternative A Year 1998 - Reconstruction of the existing Phangnga - Phuket Junction (Proposed Site of future Phuket 3 Substation) from 115 kV single circuit line to 230 kV double circuit line, using 1,272 MCM ACSR conductor a distance of approximately 76 km, initially energized at 115 kV. - Construction of 115 kV Phuket Junction - Phuket 2 line, single circuit compact line, using 2x795 MCM ACSR conductor, a distance of approximately 12 km. - Connecting of the Phangnga - Phuket Junction line with the existing 1 15 kV Phuket Junction - Phuket 2 and the new 115 kV compact line. - Replace the existing 2x100 MVA 230/115 kV transforrners with 2x200 MVA transformers at Rajjaprabha Substation. The economic cost is 652.0 MTHB. -100- Alternative B Year 1998 - Reconstruction of the existing 115 kV Phangnga - Phuket Junction from single circuit line to double circuit line, using 2x795 MCM ACSR conductor, a distance of approximately 76 km. - Construction of 115 kV Phuket Junction - Phuket 2 line, single circuit compact line, using 2x795 MCM ACSR conductor, a distance of approximately 12 km. - Connecting of the Phangnga - Phuket Junction line with the existing 115 kV Phuket Junction - Phuket 2 and the new 115 kV compact line. - Replace the existing 2xlO0 MVA 230/115 kV transformers with 2x200 MVA transformers at Rajjaprapha Substation. The economic cost is 628.4 MTHB. Year 2002 - Construction of 115 kV Phuket 3 Substation at Phuket Junction and terminate 230/115 kV Phangnga - Phuket Junction lines to Phuket 3 Substation. - Termination of 115 kV Phangnga - Phuket 1 line to Phuket 3 Substation and reconstruction of the line section from Phangnga to Phuket 3 from double circuit line using 477 MCM ACSR to double circuit line using 2x795 MCM ACSR conductor, a distance of approximately 70 km. The economic cost is 429.2 MTHB. -101- Alternative C Year 1998 - Reconstruction of the existing Phangnga - Phuket Junction from 115 kV single circuit line to 230 kV double circuit line, using 1,272 MCM ACSR conductor, a distance of approximately 76 km. - Construction of 230 kV Phuket 3 Substation with 2x200 MVA 230/115 kV transformers. - Construction of 230 kV Rajjaprabha - Phangnga line, double circuit steel tower, using 1,272 MCM ACSR conductor, a distance of approximately 73 km and connected with the 230 kV Phangnga - Phuket 3 line. The economic cost is 1,381.1 MTHB. Year 2004 - Construction of 115 kV Phuket 3 - Phuket 2 line, single circuit compact line, using 2x795 MCM ACSR conductor, a distance of approximately 12 km. The economic cost is 60.1 MTHB. c) Power Flow Diagrams The power flow diagrams for the proposed plan are given in Appendix 1. -102- d) Results of Economic Analysis 1. Comparison of Present Value P.V. at 10 % DR. (MTHB) Alternative A 23,235.26 Alternative B 23,343.82 Alternative C 23,396.00 2. Net Present Value and B/C Ratio Net Present Value B/C Ratio EDR. (MTHB) 0(°') Alternative A VS. Aiternative B i08.56 1.0047 >15D.0 V%/ Alternative A VS. Alternative C 160.74 1.0069 N.A. Results of the analysis have led to the conclusion that the construction of 230 kV Phangnga - Phuket Junction initially energized at 115 kV and 115 kV Phuket 2 - Phuket Junction transmission system project is the least cost alternative. -103- Table 4.29 Load Forecast for Phuket Province Fiscal Peak Demand Energy Demand Load Factor Year MW % Increase GWh % Increase (%) 1994 86.74 - 514.20 - 67.67 1995 100.48 15.84 603.91 17.45 68.61 1996 109.56 9.04 650.42 7.70 67.77 1997 119.07 8.68 713.32 9.67 68.39 1998 128.94 8.29 762.42 6.88 67.50 1999 139.27 8.01 818.47 7.35 67.09 2000 150.09 7.77 878.84 7.38 66.84 2001 161.30 7.47 945.14 7.54 66.89 2002 173.14 7.34 1009.06 6.76 66.53 2003 185.61 7.20 1077.95 6.83 66.30 2004 198.97 7.20 1152.89 6.95 66.14 2005 212.88 6.99 1232.99 6.95 66.12 2006 227.54 6.89 1318.09 6.90 66.13 -104- Table 4 . 3 0 Summary Result of Economic Analysis Project : Transmission System Expansion Project No. 9 Region 3; Subproject No.15 Cost Stream Alternative A Benefit Stream Alternative B Discount Present Value Present Value B/C Present Value Rate of of Ratio of (%) Benefit Cost Net Benefit 4.00 52369.38 52303.71 1.0013 65.67 6.00 39220.44 39124.41 1.0025 96.04 8.00 29976.16 29868.67 1.0036 107.49 10.00 23343.82 23235.26 1.0047 108.56 12.00 18492.51 18388.39 1.0057 104.12 14.00 14878.48 14781.52 1.0066 96.96 16.00 12139.62 12050.93 1.0074 88.69 18.00 10030.57 9950.37 1.0081 80.20 20.00 8382.30 8310.32 1.0087 71.99 22.00 7076.46 7012.17 1.0092 64.29 24.00 6n28.R7 5971.64 1.0096 57,23 26.00 5178.76 5127.92 1.0099 50.84 Equalized Discount Rate is Greater Than 150% Cost Stream Alternative A Benefit Stream Alternative C Discount Present Vaiue Present Value B/C Present Value Rate of of Ratio of (%) Benefit Cost Net Benefit 4.00 52029.59 52303.71 0.9948 -274.11 6.00 39063.83 39124.41 0.9985 -60.58 8.00 29943.58 29868.67 1.0025 74.91 10.00i 23396.00 23235.26 1.0069 160.74 12.00 18602.89 18388.39 1.0117 214.50 14.00 15028.81 14781.52 1.0167 247.29 16.00 12317.14 12050.93 1.0221 266.22 18.00 10226.25 9950.37 1.0277 275.88 20.00 8589.67 8310.32 1.0336 279.35 22.00 7290.82 7012.17 1.0397 278.65 24.00 6246.79 5971.64 1.0461 275.16 26.00 5397.74 5127.92 1.0526 269.82 Equalized Discount Rate is Not Applicable Transmission System Planning Division 21 -Mar-95 01:05 PM -105- SUBPROJECT NO.16 115 KV YALA - NARATHIWAT LINE AND SUBSTATIONS a) Load Forecast The electricity demand in this subproject area is forecasted as shown in Table 4.31. b) Alternative Plans The three possible alternative plans to serve the same technical objectives of this subproject as described in Volume I (Main Report) are Alternative A: Year 1998 - Construction of 115 kV Yala - Narathiwat line, single circuit on double circuit steel tower, using 795 MCM ACSR conductor, a distance of approximately 61 km. The economic cost is 383.1 MTHB. Alternative B Year 1998 - Construction of 115 kV Pattani - Narathiwat line, single circuit on double circuit steel tower, using 795 MCM ACSR conductor, a distance of approximately 80 km. The economic cost is 495.3 MTHB. -106- Alternative C Year 1998 - Construction of 115 kV Yala - Narathiwat line, double circuit steel tower, using 795 MCM ACSR conductor, a distance of approximately 61 km. The economic cost is 435.7 MTHB. c) Power Flow Diagrams The power flow diagrams for the proposed plan are given in Appendix 1. d) Results of Economic Analysis 1. Comparison of Present Value P.V. at 10 % DR. (MTHB) Alternative A 16,882.43 Alternative B 17,019.45 Alternative C 16,906.19 2. Net Present Value and B/C Ratio Net Present Value B/C Ratio EDR. (MTHB) (%_ Alternative A VS. Alternative B 137.03 1.0081 >150.00 Altemative A VS. Alternative C 23.77 1.0014 >150.00 Results of the analysis have led to the conclusion that the construction of 115 kV single circuit on double circuit Yala - Narathiwat transmission system project is the least cost alternative. -107- Table 4.31 Load Forecast for Narathiwat and Sungai Kolok Substations Subprotecl Nol16 Fiscal Peak Demand Energy Demand Load Factor Year MW % Increase GWh % Increase (%) 1994 31.80 - 146.21 - 52.49 1995 37.55 18.08 165.76 13.37 50.39 1996 40.68 8.34 177.15 6.87 49.71 1997 43.90 7.92 191.10 7.87 49.69 1998 47.23 7.59 203.61 6.55 49.21 1999 50.70 7.35 217.95 7.04 49.07 2000 54.27 7.04 232.69 6.76 48.95 2001 57.96 6.80 248.94 6.98 49.03 2002 61.80 6.63 264.34 6.19 48.83 2003 65.78 6.44 280.67 6.18 48.71 2004 69.93 6.31 297.97 6.16 48.64 2005 74.15 6.03 316.16 6.10 48.67 2006 78.45 5.80 334.89 5.92 48.73 -108- Table 4.32 Summary Result of Economic Analysis Project Transmission System Expansion Project No. 9 Region 3; Subproject No.16 Cost Stream Alternative A Benefit Stream Alternative B Discount Present Value Present Value B/C Present Value Rate of of Ratio of (%) Benefit Cost Net Benefit 4.00 38302.46 38085.97 1.0057 216.49 6.00 28646.20 28463.45 1.0064 182.75 8.00 21870.90 21713.87 1.0072 157.03 10.00 17019.45 16882.43 1.0081 137.03 12.00 13477.46 13356.29 1.0091 121.16 14.00 10843.42 10735.09 1.0101 108.34 16.00 8850.39 8752.60 1.0112 97.79 18.00 7317.76 7228.78 1.0123 88.98 20.00 6121.34 6039.83 1.0135 81.51 22.00 5174.31 5099.22 1.0147 75.09 24.00 4415.05 4345.53 1.0160 69.51 26.00 3799.14 3734.52 1.0173 64.62 Equalized Discount Rate is Greater Than i50% Cost Stream Alternative A Benefit Stream Alternative C Discount Present Value Present Value B/C Present Value Rate of of Ratio of (%) Benefit Cost Net Benefit 4.00 38100.47 38085.97 1.0004 14.50 6.00 28483.25 28463.45 1.0007 19.80 8.00 21736.43 21713.87 1.0010 22.56 10.00 16906.19 16882.43 1.0014 23.77 12.00 13380.33 13356.29 1.0018 24.04 14.00 10758.82 10735.09 1.0022 23.74 16.00 8775.70 8752.60 1.0026 23.10 18.00 7251.06 7228.78 1.0031 22.28 20.00 6061.18 6039.83 1.0035 21.35 22.00 5119.60 5099.22 1.0040 20.38 24.00 4364.94 4345.53 1.0045 19.41 26.00 3752.97 3734.52 1.0049 18.44 Equalized Discount Rate is Greater Than 150% Transmission System Planning Division 21 - Mar-95 01:07 PM -1oo- SUBPROJECT NO.17 115 KV SURAT TIANI - BAN DON LINE AND SUBSTATIONS a) Load Forecast The electricity demand in this subproject area is forecasted as shown in Table 4.33. b) Alternative Plans The three possible alternative plans to serve the same techllical objectives of this subproject as described in Volume I (Main Report) are Alternative A: Year 1998 - Stringing 2nd circuit of 115 kV Surat Thani - Ban Don lin,c using 477 MCM ACSR conductor, a distance of approximately 13 km. The economic cost is 30.6 MTHB. Year 2001 - Construction of 115 kV Phun Phin - Ban Don line, single circuit on double circuit steel tower, using 795 MCM ACSR conductor, a distancc oI approximately 10 km. The economic cost is 140.5 MTHB. Alternative B Year 1998 - Construction of 115 kV Phunphin - Ban Don line, singie circuit on double circuit steel tower, using 795 MCM ACSR conductor. a distance of approximately 10 km. -110- - Reconstruction of the existing 115 kV Surat Thani - Phunphin from single circuit line using 150 sq.mm AAAC conductor to single circuit on double circuit line using 795 MCM ACSR conductor, a distance of approximately 6.2 km. The economic cost is 170.3 MTHB. Year 2003 - Stringing of the 2nd circuit of 115 kV Surat Thani - Phun Phin line, using 795 MCM ACSR conductor, a distance of approximately 6.2 km. The economic cost is 22.1 MTHB. Alternative C Year 1998 I nstallation of three units of 25 MW gas turbine power plant at Ban Don Substation. The economic cost is 1,134.0 MTHB. Year 2000 - Installation of one unit of 25 MW gas turbine power plant at Ban Don Substation. The economic cost is 378.0 MTHB. Year 2004 - Installation of one unit of 25 MW gas turbine power plant at Ban lDon Substation. -111- The economic cost is 378.0 MTHB. c) Power Flow Diagrams The power flow diagrams for the proposed plan are given in Appendix 1. d) Results of Economic Analysis 1. Comparison of Present Value P.V. at 10 % DR. (MTHB) Alternative A 18,710.26 Alternative B 18,732.46 Alternative C 23,874.37 2. Net Present Value and B/C Ratio Net Present Value B/C Ratio EDR. (MTHB) (%) Alternative A VS. Alternative B 22.20 1.0012 >150.00 Alternative A VS. Alternative C 5,164.11 1.2760 >150.00 Results of the analysis have led to the conclusion that the 115 kV Surat Thani - Ban Don Line Stringing project is the least cost alternative. -112- Table 4.33 Load Forecast for Ban Don Substation Subprojel No. 7 Fiscal Peak Demand Energy Demand Load Factor Year MW % Increase GWh % Increase (%) 1994 52.36 - 298.04 - 64.98 1995 53.37 1.93 305.97 2.66 65.45 1996 57.37 7.49 328.88 7.49 65.44 1997 42.12 a -26.58 240.25 J -26.95 65.11 1998 45.34 7.64 254.91 6.10 64.18 1999 48.61 7.21 271.27 6.42 63.70 2000 51.98 6.93 289.06 6.56 63.48 2001 55.45 6.68 308.62 6.77 63.54 2002 59.00 6.40 326.71 5.86 63.21 2003 62.68 6.24 345.87 5.86 62.99 2004 66.53 6.14 366.33 5.92 62.86 2005 70.42 5.85 387.66 5.82 62.84 2006 74.39 5.64 409.63 5.67 62.86 Note p/ Some loads are transfered to the PEA's 115 kV systems which receive power from 230/115 kV Thung Song Substabon. -113- Table 4 .34 Summary Result of Economic Analysis Project Transmission System Expansion Project No. 9 Region 3; Subproject No.17 Cost Stream Alternative A Benefit Stream Alternative B Discount Present Value Present Value B/C Present Value Rate of of Ratio of (%) Benefit Cost Net Benefit 4.00 43270.21 43253.55 1.0004 16.65 6.00 32097.62 32078.30 1.0006 19.32 8.00 24293.26 24272.17 1.0009 21.09 10.00 18732.46 18710.26 1.0012 22.20 12.00 14694.39 14671.56 1.0016 22.83 14.00 11708.82 11685.73 1.0020 23.10 16.00 9463.70 9440.60 1.0024 23.10 18O.00 7748.37 7725.47 1.0030 22.91 20.00 6418.32 6395.75 1.0035 22.57 22.00 5372.80 5350.67 1.0041 22.13 24.00 4540.47 4518.86 1.0048 21.61 26.00 3870.11 3849.07 1.0055 21.05 Equalized Discount Rate is Greater Than 150% Cost Stream Alternative A Benefit Stream Alternative C Discount Present Value Present Value B/C Present Value Rate of of Ratio of (%) Benefit Cost ___ Net Benefit 4.00 54277.49 43253.55 1.2549 11023.94 6.00 40466.54 32078.30 1.2615 8388.24 8.00 30790.61 24272.17 1.2686 6518.44 10.00 23874.37 18710.26 1.2760 5164.11 12.00 18834.87 14671.56 1.2838 4163.31 14.00 15095.24 11685.73 1.2918 3409.52 16.00 12272.08 9440.60 1.2999 2831.48 18.00 10106.19 7725.47 1.3082 2380.72 20.00 8419.49 6395.75 1.3164 2023.73 22.00 7087.63 5350.67 1.3246 1736.96 24.00 6022.44 4518.86 1.3327 1503.59 26.00 5160.49 3849.07 1.3407 1311.42 Equalized Discount Rate is Greater Than 150% Transmission System Planning Division 21 - Mar-95 01 08 PM -114- SUBPROJECT NO.18 CONVERSION OF MAE MOH 3 - CHIANG RAI LINE FROM 115 KV TO 230 KV a) Load Forecast The electricity demand in this subproject area is forecasted as shown in Table 4.35. b) Alternative Plans The three possible alternative plans to serve the same technical objectives of this subproject as described in Volume I (Main Report) are Alternative A Year 1998 - Conversion of Mae Moh 3 - Chiang Rai line from 115 kV to 230 kV and installation of 2x200 MVA transformer at Chiang Rai Substation. The economic cost is 397.7 MTHB. Alternative B Year 1998 - Construction of 115 kV Phayao - Chiang Rai line, single circuit on double circuit steel tower, using 795 MCM ACSR conductor, a distance of approximately 80 km. - Installation of lx200 MVA 230/115 kV transformer at Mae Moh 3 Substation. The economic cost is 344.9 MTHB. -115- Year 2001 - Conversion of Mae Moh 3 - Chiang Rai line from 115 kV to at 230 kV ariA -- n-in ' '.1A 1.ffx r 11')AI1 I IAT r - ,f PI- ID.; and installatuion of4vU LVI V 3A 2,0./11 kxV trans1U1%.Ae atL Chiar.g, RA i "uWs-o. The economic cost is 341.7 MTHB. Alternative C: Year 1998 - Termination of the existing 115 kV Mae Moh 3 - Chiang Rai line at Phayao Substation, using 1,272 MCM ACSR conductor, a distance of approximately I km. - Installation of lx200 MVA 230/115 kV transformer at Mae Moh 3 Substation. The economic cost is 134.1 MTHB. Year 2001 - Conversion of Mae Moh 3 - Chiang Rai line from 115 kV to 230 kV and installation of 2x200 MVA 230/115 kV transformers at Chiang Rai Substation. The economic cost is 341.7 MTHB. c) Power Flow Diagrams The power flow diagrams for the proposed plan are given in Appendix 1. -116- d) Results of Economic Analysis 1. Comparison of Present Value P.V. at 10 % DR. (MTHB) Alternative A 17,425.56 Alternative B 17,652.52 Alternative C 17,487.15 2. Net Present Value and B/C Ratio Net Present Value B/C Ratio EDR. (MTHB) _ _ _ Alternative A VS. Alternative B 226.96 1.0130 >150.00 Alternative A VS. Alternative C 61.59 1.0035 22.63 Results of the analysis have led to the conclusion that the conversion of Mae Moh 3 - Chiang Rai line from 115 kV to 230 kV pfoject is the least cost alternative. -117- Table 4.35 Load Forecast for Chiangrai, Mae Chan and Thoeng Substations Subpro.cl No.18 Fiscal Peak Demand Energy Demand Load Factor Year MW % Increase GWh % Increase (%) 1994 81.78 - 319.35 - 44.58 1995 99.80 22.03 391.84 22.70 44.82 1996 114.94 15.17 464.46 18.53 46.13 1997 123.20 7.19 495.49 6.68 45.91 1998 131.88 7.05 532.81 7.53 46.12 1999 140.92 6.85 573.01 7.54 46.42 2000 150.33 6.68 616.93 7.66 46.85 2001 160.10 6.50 664.32 7.68 47.37 2002 170.22 6.32 708.46 6.64 47.51 2003 180.77 6.20 756.58 6.79 4778 2004 191.76 6.08 808.11 6.81 48.11 2005 203.13 5.93 863.88 6.90 48.55 2006 214.93 5.81 924.19 6.98 49.09 -118- Table 4.36 Summary Result of Economic Analysis Project : Transmission System Expansion Project No. 9 Region 4; Subproject No.18 Cost Stream Alternative A Benefit Stream Alternative B Discount Present Value Present Value B/C Present Value Rate of of Ratio of (%) Benefit Cost Net Benefit 4.00 39811.53 39507.44 1.0077 304.09 6.00 29764.71 29486.98 1.0094 277.72 8.00 22'08.87 22457.30 1.0112 251.56 10,00 17652.52 17425.56 1.0130 226.96 12.00 13958.65 13754.21 1.0149 204.43 14.00 11210.56 11026.44 1.0167 184.12 16.00 9130.88 8964.94 1.0185 165.94 18.00 7531.79 7382.04 1.0203 149.75 20.00 6283.94 6148.61 1.0220 135.33 22.00 5296.83 5174.32 1.0237 122.51 24.00 4506.14 439E5.04 1.0253 111.11 26.00 3865.47 3754.53 1.0268 100.95 Equalized Discount Rate is Greater Than 150% Cost Stream Alternative A Benefit Stream Alternative C Discount Present Value Present Value B/C Present Value Rate of of Ratio of (%) Benefit Cost __ Net Benefit 4.00 39626.33 39507.44 1.0030 118.89 6.00 29584.12 29486.98 1.0033 97.13 8.00 22535.39 22457.30 1.0035 78.09 10.00 17487.15 17425.56 1.0035 61.59 12.00 13801.58 13754.21 1.0034 47.37 14.00 11061.60 11026.44 1.0032 35.16 16.00 8989.66 8964.94 1.0028 24.73 18.00 7397.86 7382.04 1.0021 15.82 20.00 6156.85 6148.61 1.0013 8.24 22.00 5176.12 5174.32 1.0003 1.80 24.00 4391.39 4395.04 0.9992 -3.64 26.00 3756.29 3764.53 0.9978 -8.24 Equalized Discount Rate - 22.63% Transmission System Planning Division 21 - Mar-95 01:11 PM -119- SUBPROJECT NO.19 115 KV LAN KRABU - KAMPHAENGPHET LINE AND SUBSTATIONS a) Load Forecast The electricity demand in this subproject area is forecasted as shown in Table 4.37. b) Alternative Plans The three possible alternative plans to serve the same technical objectives of this subproject as described in Volume I (Main Report) are Alternative A Year 1998 - Construction of 115 kV Lan Krabu - Kamphaengphet line, double circuit steel tower, using 795 MCM ACSR conductor, a distance of approximately 47 km. The economic cost is 238.5 MTHIB. Year 2006 - Construction of 115 kV Bhumibol - Tak 1 line, single circuit on double circuit steel tower, using 795 MCM ACSR conductor, a distance of approximately 47 km. The economic cost is 157.2 MTHB. Alternative B Year 1998 - Te..rn-fion of thei txisting 1 !s V Taik I - T-(-amnh enonhet line at Tak 2 Substation, using 477 MCM ACSR conductor, a distance of approximately 3 km. -120- - Installation of 2x200 MVA 230/115 transformers at Tak 2 Substation. - Construction of 115 kV Bhumibol - Tak 1 line, single circuit on double circuit steel tower, using 795 MCM ACSR conductor, a distance' of approximately 47 km. - Construction of 115 kV Tak 2 - Kamphaengphet line, single circuit on double circuit steel tower, u'sing 795 MCM ACSR conductor, a distance of approximately 53 km., The economic cost is 642.8 MTHB. Alternative C Year 1998 - Termination 'of the existing 230 kV Bhumibol - Nakhon Sawan line at Kamphaengphet Substation, using 1,272 MCM ACSR conductor, a distance of approximately 2 km. - Construction of 230 kV Kamphaengphet Substation with 2x200 MVA 230/115 kV transformers. The economic cost is 404.0 MTHB. Year 2006 - Termination of the second circuit of 230 kV Bhumibol - Nakhon Sawan line at Kamphaengphet Substation, using 1272 MCM ACSR conductor, a distance of approximately 2 km. The economic cost is 123.5 MTHB. -121 - c) Power Flow Diagrams The power flow diagrams for the proposed plan are given in Appendix 1. d) Results of Econo...ic A ; 1. Comparison of Present Value P.V. at 10 % DR. (MTHB) Alternative A 17,599.85 Alternative B 17,845.92 Alternative C 17,762.88 2. Net Present Value and B/C Ratio Net Present Value B/C Ratio EDR. (MTHB) (__ __ Alternative A VS. Alternative B 246.07 1.0140 >150.00 Alternative A VS. Alternative C 163.04 1.0093 >150.00 Results of the analysis have led to the conclusion that the construction of 115 kV Lan Krabu - Kamphaengphet transmission system project is the least cost alternative. -122- Table 4.37 Load Forecast for Tak 1, Mae Sot and Kamphangphet Substations Subproect No.1 9 Fiscal Peak Demand Energy Demand Load Factor Year MW % Increase GWh % Increase (%) 1994 55.85 - 262.35 - 53.62 1995 65.31 16.94 305.36 16.39 53.37 1996 72.02 10.27 332.84 9.00 52.76 1997 78.99 9.68 370.09 11.19 53.48 1998 86.28 9.23 404.09 9.19 53.46 1999 93.85 8.77 440.27 8.95 53.55 2000 101.80 8.47 479.76 8.97 53.80 2001 110.18 8.23 522.63 8.94 54.15 2002 119.03 8.03 563.79 7.88 54.07 2003 127.95 7.49 606.89 7.64 54.15 2004 138.46 8.21 658.32 8.47 54.28 2005 149.14 7.71 712.59 8.24 54.54 2006 160.53 7.64 772.33 8.38 54.92 -123- Table 4 . 3 8 Summary Result of Economic Analysis Project Transmission System Expansion Project No. 9 Region 4; Subproject No.19 Cros+ Q+r: rnt A - A tS WLutIAu - fl ttA. u....- w Benefit Stream Alternative B Discount Present Value Present Value B/C Present Value Rate of of Ratio of (%) Benefit Cost Net Benefit 4.00 40449.61 40174.40 1.0069 275.22 6.00 30183.46 29917.40 1.0089 266.06 8.00 22989.57 22733.28 1.0113 256.29 10.00 17845.92 17599.85 1.0140 246.07 12.00 14096.67 13861.06 1.0170 235.61 14.00 11313.44 11088.34 1.0203 225.10 16.00 9211.48 8996.80 1.0239 214.68 18.00 7598.31 7393.82 1.0277 204.49 20.00 6341.62 6147.01 1.0317 194.60 22.00 5348.97 5163.89 1.0358 185.08 24.00 4554.84 4378.88 1.0402 175.96 26.00 3912.00 3744.75 1.0447 167.26 Equalized Discount Rate is Greater Than 150% Cost Stream Alternative A Benefit Stream Alternative C Discount Present Value Present Value BIC Present Value Rate of of Ratio of ) Benefit Cost ___ Net Benefit 4.00 40426.93 40174.40 1.0063 252.53 6.00 30130.92 29917.40 1.0071 213.53 8.00 22918.17 22733.28 1.0081 184.89 10.00 17762.88 17599.85 1.0093 163.04 12.00 14006.83 13861.06 1.0105 145.77 14.00 11220.05 11088.34 1.0119 131.71 16.00 9116.77 8996.80 1.0133 119.97 18.00 7503.78 7393.82 1.0149 109.96 20.00 6248.30 6147.01 1.0165 101.29 22.00 5257.57 5163.89 1.0181 93.68 24.00 4465.81 4378.88 1.0199 86.93 26.00 3825.64 3744.75 1.0216 80.89 Equalized Discount Rate is Greater Than 150% Transmission System Planning Division 21-Mar-95 01:12 PM -124- SUBPROJECT NO.20 115 KV MAE MOH 3 - LAMPANG 2 LINE AND SUBSTATIONS a) Load Forecast The electricity demand in this subproject area is forecasted as shown in Table 4.39. b) Alternative Plans The three possible alternative plans to serve the same technical objectives of this subproject as described in Volume I (Main Report) are Alternative A Year 1998 - Construction of 115 kV Mae Moh 3 - Lampang 2 line, double circuit steel tower, using 2x795 MCM ACSR conductor. a distance of approximately 27 km. The economic cost is 274.6 MTHB. Year 1999 - Installation of 1x200 MVA 230/115 kV transformer at Chiang Mai 3 Substation. The economic cost is 129.7 MTHB. Year 2000 - Reconstruction of the existing Mae Moh 2 - Lampang 1 - Lamphun 1 from 115 kV single circuit line to 230 kV Mae Moh 3 - Saraphi double circuit line. using 2x1,272 MCM ACSR conductor, a distance of approximately 124 km. - Construction of 115 kV Mae Mob 3 - Lampang I line, double circuit steel tower, using 795 MCM ACSR conductor, a distance of approximately 41 km. -125- - Construction of 115 kV Lamphun 2 - Lamphun 1 line, double circuit steel tower, using 795 MCM ACSR conductor, a distance of approximately 16 km. - Construction of 230 kV Sarapni Substation wi'uh 2-00 MVIA 230/115 kV transformers. The economic cost is 1,943.5 MTHB. Alternative B Year 1998 - Reconstruction of the existing Mae Moh 2 - Lampang 1 - Lamphun I from 115 kV single circuit line to 230 kV Mae Moh 3 - Saraphi double circuit line, using 2x1,272 MCM ACSR conductor, a distance of approximately 124 km. - Construction of 115 kV Mae Moh 3 - Lampang 1 line, double circuit steel tower, using 795 MCM ACSR conductor, a distance of approximately 41 km. - Construction of 115 kV Lamphun 2 - Lamphun 1 line, double circuit steel tower, using 795 MCM ACSR conductor, a distance of approximately 16 km. - Construction of 230 kV Saraphi Substation with 2x200 MVA 230/115 kV transformers. The economic cost is 1,975.7 MTHB. Year 2000 - Construction of 115 kV Mae Moh 3 - Lampang 2 line, double circuit steel tower, using 2x795 MCM ACSR conductor, a distance of approximately 27 km. Te economic CU0L iS 3O. IVI2 IMTH. -126- Year 2006 - Installation of lx200 MVA 230/115 kV transformer at Chiang Mai 3 Substation. The economic cost is 129.7 MTHB. Alternative C Year 1998 - Termnination of the existing 230 kV Mae Moh 3 - Chiang Mai 3 and 115 kV Lampang 2 - Lamphun 2 at Hang Chat Substation and installation of 2x200 MVA 230/115 kV transformers at Hang Chat Substation. The economic cost is 519.3 MTHB. Year 2000 - Reconstruction of the existing Mae Moh 2 - Lampang 1 - Lamphun I from 115 kV single circuit line to 230 kV Mae Moh 3 - Saraphi double circuit line, using 2x1,272 MCM ACSR conductor, a distance of approximately 124 km. - Construction of 115 kV Mae Moh 3 - Lampang 1 line, double circuit steel tower, using 795 MCM ACSR conductor, a distance of approximately 41 km. - Construction of 115 kV Lamphun 2 - Lamphun 1 line, double circuit steel tower, using 795 MCM ACSR conductor, a distance of approximately 16 km. - Construction of 230 kV Saraphi Substation with 2x200 MVA 230/115 kV transformers. The economic cost is 1,975.7 MTHB. -127- Year 2006 - Reconstruction of 115 kV Saraphi - Chiang Mai 2 from double circuit line using 477 MCM ACSR conductor to doublc circuit line usinLg 2Lx179151 ACSR conductor, a distance of approximately 16 km. The economic cost is 193.7 MTHB. c) Power Flow Diagrams The power flow diagrams for the proposed plan are given in Appendix 1. d) Results of Economic Analysis 1. Comparison of Present Value P.V. at 10 % DR. (MTHB) Alternative A 15,908.04 Alternative B 15,961.24 Alternative C 16,175.12 2. Net Present Value and B/C Ratio Net Present Value B/C Ratio EDR. (MTHB! -_ _ _ Alternative A VS. Altemative B 53.20 1.0033 N.A. Alternative A VS. Alternative C 267.08 1.0168 > 150.00 Results of the analysis have led to the conclusion that the construction the proposed construction of 115 kV Mae Moh 3 - Lampang 2 transmission system project is the least cost alternative. -128- Table 4.39 Load Forecast for Lampang 2 Substation Subpro*ct No.20 Fiscal Peak Demand Energy Demand Load Factor Year MW % Increase GWh % Increase (%) 1994 25.20 - 108.31 - 49.06 1995 25.65 1.79 109.02 0.66 48.52 1996 67.30 aX 162.38 267.82 a/ 145.66 45.43 1997 69.05 2.60 334.34 24.84 55.27 1998 70.89 2.66 342.36 2.40 55.13 1999 72.84 2.75 351.12 2.56 55.03 2000 114.89 a/ 57.73 510.81 a/ 45.48 50.75 2001 117.05 1.88 521.39 2.07 50.85 2002 119.33 1.95 531.28 1.90 50.82 2003 121.73 2.01 542.16 2.05 50.84 2004 124.26 2.08 553.92 2.17 50.89 2005 126.92 2.14 566.80 2.33 50.98 2006 129.72 2.21 580.90 2.49 51.12 Note a/ Highly demand increase due to demand of Siam Cement Factory. -129- Table 4 .4 0 Summary Result of Economic Analysis Project Transmission System Expansion Project No. 9 Region 4; Subproject No. 20 Cost Stream Alternative A Benefit Stream Alternative B Discount Present Value Present Value B/C Present Value Rate of of Ratio of (%) Benefit Cost Net Benefit 4.00 34608.37 34559.70 1.0014 48.67 6.00 26198.18 26150.55 1.0018 47.63 8.00 20252.76 20203.01 1.0025 49.74 10.00 15961.24 15908.04 1.0033 53.20 12.00 12801.26 12744.25 1.0045 57.01 14.00 10430.21 1036956 1.0058 60.65 16.00 8619.41 8555.54 1.0075 63.87 18.00 7213.53 7146.97 1.0093 66.56 20.00 6105.28 6036.59 1.0114 68.69 22.00 5219.34 5149.05 1.0137 70.30 24.00 4501.99 4430.59 1.0161 71.40 26.00 3914.31 3842.24 1.0188 72.07 Equalized Discount Rate is Not Applicable Cost Stream Alternative A Benefit Stream Alternative C Discount Present Value Present Value B/C Present Value Rate of of Ratio of (%) Benefit Cost . Net Benefit 4.00 35007.84 34559.70 1.0130 448.14 6.00 26521.32 26150.55 1.0142 370.77 8.00 20515.21 20203.01 1.0155 312.20 10.00 16175.12 15908.04 1.0168 267.08 12.00 12976.02 12744.25 1.0182 231.77 14.00 10573.25 10369.56 1.0196 203.69 16.00 8736.59 8555.54 1.0212 181.05 18.00 7309.50 7146.97 1.0227 162.54 20.00 6183.80 6036.59 1.0244 147.21 22.00 5283.43 5149.05 1.0261 134.38 24.00 4554.10 4430.59 1.0279 123.51 26.00 3956.45 3842.24 1.0297 114.21 Equalized Discount Rate is Greater Than 150% Transmission System Planning Division 21 - Mar-95 0114 PM -130- SUBPROJECT NO.21 115 KV CHIANG MAI 2 - MAE TAENG LINE AND SUBSTATIONS a) Load Forecast The electricity demand in this subproject area is forecasted as shown in Table 4.41. b) Alternative Plans The three possible alternative plans to serve the same technical objectives of this subproject as described in Volume I (Main Report) are Alternative A: Year 1998 - Construction of 115 kV Chiang Mai 2 - Mae Taeng line, single circuit on double circuit steel tower, using 795 MCM ACSR conductor, a distance of approximately 42 km. The economic cost is 259.6 MTHB. Alternative B Year 1998 - Installation of eighteen units of 2.5 MW diesel power plant at Mae Taeng Substation. The economic cost is 927.0 MTHB. Year 2001 - Installation of six units of 2.5 MW diesel power plant at Mae Taeng Substation. -131 - The economic cost is 309.0 MTHB. Year 2005 - Installation of three units of 2.5 MW diesel power plant at Mae Taeng Substation. The economic cost is 154.5 MTHB. Alternative C Year 1998 - Installation of three units of 25 MW gas tturbine power plant at Mae Taeng Substation. The economic cost is 1,134.0 MTHB. The installation schedules of Alternative A, B and C are shown in Figures 4.10 to 4.12. c) Power Flow Diagrams The power flow diagrams for the proposed plan are given in Appendix 1. d) Results of Economic Analysis 1. Comparison of Present Value P.V. at 10 % DR. (MTHB) Alternative A 14,818.93 Alternative B 15,392.43 Alternative C 15,431.49 -132- 2. Net Present Value and B/C Ratio Net Present Value B/C Ratio EDR. (MTHB! (%) Altemative A VS. Alternative B 573.50 1.0387 52.37 Alternative A VS. Alternative C 612.56 1.0413 110.56 Results of the analysis have led to the conclusion that the construction of the proposed 115 kV Chiang Mai 2 - Mae Taeng transmission system project is the least cost alternative. -133- Table 4.41 Load Forecast for Mae Taeng Substation Subprojwct Noll Fiscal Peak Demand Energy Demanu Load Factor Year MW % Increase GWh % Increase (%) 1994 23.50 - 75.00 - 36.43 1995 26.10 11.06 84.60 12.80 37.00 1996 28.80 10.34 94.70 11.94 37.54 1997 31.60 9.72 105.20 11.09 38.00 1998 34.40 8.86 116.00 10.27 38.49 1999 37.20 8.14 126.90 9.40 38.94 2000 39.90 7.26 138.10 8.83 39.51 2001 42.60 6.77 149.30 8.11 40.01 2002 45.30 6.34 160.70 7.64 40.50 2003 47.90 5.74 172.10 7.09 41.01 2004 50.50 5.43 183.70 6.74 41.53 2005 53.10 5.15 195.50 6.42 42.03 2006 55.70 4.90 207.40 6.09 42.51 -134- Tabl e 4.42 Summary Result of Economic Analysis Project Transmission System Expansion Project No. 9 Region 4; Subproject No. 21 Cost Stream Alternative A Benefit Stream Alternative B Discount Present Value Present Value B/C Present Value Rate of of Ratio of (%) Benefit Cost Net Benefit 4.00 35139.63 33638.85 1.0446 1500.79 6.00 26162.84 25088.44 1.0428 1074.39 8.00 19879.27 19099.46 1.0408 779.81 10.00 15392.43 14818.93 1.0387 573.50 12.00 12126.83 11699.78 1.0365 427.05 14.00 9706.56 9384.85 1.0343 321.72 16.00 7881.81 7636.85 1.0321 244.96 18.00 6483.78 6295.46 1.0299 188.32 20.00 5396.54 5250.52 1.0278 146.02 22.00 4539.17 4425.12 1.0258 114.04 24.00 3854.35 3764.74 1.0238 89.60 26.00 3300.86 3230.14 i.02i9 70.72 Equalized Discount Rate = 52.37% Cost Stream Alternative A Benefit Stream Alternative C Discount Present Value Present Value B/C Present Value Rate of of Ratio of (%) Benefit Cost Net Benefit 4.00 35176.84 33638.85 1.0457 1537.99 6.00 26201.78 25088.44 1.0444 1113.34 8.00 19918.55 19099.46 1.0429 819.09 A10.00 15431.49 14818.93 1.0413 612.56 12.00 12165.47 11699.78 1.0398 465.68 14.00 9744.67 9384.85 1.0383 359.82 16.00 7919.31 7636.85 1.0370 282.46 18.00 6520.60 6295.46 1.0358 225.13 20.00 5432.58 5250.52 1.0347 182.06 22.00 4574.35 4425.12 1.0337 149.23 24.00 3888.60 3764.74 1.0329 123.86 26.00 3334.11 3230.14 1.0322 103.98 Equalized Discount Rate = 110.56% Transmission System Planning Division 21-Mar-95 O1:16 PM -135- Capacity (MW) 150 -.._ 140 - 130 - 120 - E 115 kV Chiang Mai 2 - Mae Taeng Val SC on DC/ST 795 MCM ACSR 110 - c 100 - ,o 90 B0 90 - _.c K Installed Capacity - IL . 80 70 60- 50 - | 40- 30 - PeakDemand 20- 10 - 0 - 1993 1 1994 1 1995 1 1996 1 1997 1 1998 1 1999 1 2000 2001 1 2002 1 2003 2004 1 2005 l 2006 1 2007 Fiscal Year Figure 4.10 Installation Schedule for Subproject No.21 (Mae Taeng Substation) Alternative A Capacity (MW) 150 -_ 140 - 130 -t 120- E 'xi > 8~~~~0 -.IntleCa ai 7 0 -) A)|pty C~~~~~~~ ~OCd) 110 i ]F lCwt 100 - 90- 70iguI Installed Capaly a 60 __Sti) eni .0 _________ ~~~~~~~~~~~~Firm Capacity 50- 5 a. 40PekDmn 30 20 1 0 1993 1994 11995 11996 1997 1998 1 i999 2000 2001 2002 2003 1 2004 2005 2006 2007- Fiscal Year Figure 4.11 installation Schedule for Subproject No.21 (Mae Taeng Substation) Alternative B Capacity (MW) 140 - 130 - 120 - E Gas Turbine 3x25 MW 110 - X C 100 _ _______________________ 90 - Installed Capacity 80 0) 00 70 -. 60 - Firm Capacity 40 30 20 10 0 - 1993 1994 1 1995 1 i996 1 1997 1 1998 1 1999 1 2000 ! 2001 1 2002 1 2003 1 2004 1 2005 1 2006 1 2007 Fiscal Year Figure 4.12 Installation Schedule for Subproject No.21 (Mae Taeng Substation) Alternative C 5. FINANCIAL JUSTIFICATION OF TS.9 PROJECT BASED ON TIME SLICE APPROACH -139- 5. FINANCIAL JUSTIFICATION OF TS.9 PROJECT BASED ON TIME SLICE APPROACH 5.1 Methodology of Analysis First part of this report is the studies to prove that each proposed subproject is the least cost among all of the technical viable alternatives to meet the system requirements in each subproject area. The financial justification of the whole package of the TS.9 Project is the second part of the economic viability study of the project. The purpose of this study is to evaluate the economic and financial internal rate of return (EIRR and FIRR) of the whole package of TS.9 project. However the benefit accrued from the transmission system project cannot be directly calculated as the power generation project, the technique of time slice analysis of the EGAT's overall PDP has been therefore applied to calculate the EIRR and FIRR of the project. Although the feasibility study of TS.9 project was started from 1994 and the construction of the project will be completed in 1998, the period of 1995-1998 is selected for the time slice study since the disbursement of the project started from 1995 and the study period should be extended to cover the effect of implementing various types of power plant into the PDP. The EIRR or FIRR is the discount rate which equalizes the present value of the economic or financial costs estimated for the EGAT's PDP to the benefit expected from implementing this PDP over the period of 1995 to 1998. The incremental revenue, incremental capital, fuel and O&M cost used for the analysis are based on the PDP 95-01. All costs and benefits in terms of money value are based on 1994 price level. Costs without taxes, IDC and escalation are used for the EIRR study while the current cost with IDC and escalation are used for the FIIUt study. -140- 5.2 Capital Investment Costs The capital costs are the investment costs of the power generation and transmission projects which are involved in the EGAT least-cost Power Development Plan during the study period (1995-1998). 5.3 Operation and Maintenance Costs (O&M Costs) The O&M costs are assumed to be a fixed percentage of capital investment costs as follows % of Capital Cost Oil/Gas-Fired Plant 2.5 Lignite-Fired Plant 3.0 Hydro Power Plant 1.0 Transmission System 1.5 5.4 Fuel Cost Fuel prices, in real term at 1997 price, used in the EIRR study are the same as used in the optimization of the latest EGAT's PDP (PDP 95-01); and the fuel prices in current term used in the FIRR study are taken from the EGAT's financial projection corresponding to PDP 95-01. Details of the prices for various types of fuel are shown in Tables 5.1 to 5.2. 5.5 Revenues The benefit of TS.9 project is obtained from the incremental energy sale from the base year (1994). The EGAT average selling prices resulted from EGAl's financial analysis to meet the financial covenant are used to calculate the incremental revenues during the study period. -141- 5.6 Results of the Studies The results of eronomic and financial internal rate of return can be summarized as follows EIRR Stud FIRR Study Internal Rate of Return (%) 11.77 4.51 -14,- TABLE 5.1 FUEL PRICE FOR OPTIMIZATION OF EGAT'S PDP 95-01 (CONSTANT 1994 PRICE) _ a/ _ b/ c/ c/ pi Fiscal | Lignite (Mae Moh) Imported Coal Heavy Oil Diesel Oil Natural Gas Natural Gas Year (0.5 % Sul hur (Myanmar USD/MBtu USD/Ton % Inc. USD/MBtu USD/Ton % Inc. USD/MBtu THB/Litre % Inc. USD/MBtu THB/Utre % Inc. USDIMBtu THB/MBtu % Inc. USD/MBtu THB/MBtu % Inc. 1994 1.12 12.56 - 1.89 50.00 - 2.96 2.92 - 3.86 3.50 - 2.40 61.09 - - - - 1995 1.12 12.63 0.56 1.94 51.10 2.20 3.04 3.00 2.74 4.00 3.63 3.71 2.35 59.82 -2.08 - - - 1996 1.13 12.68 0.40 1.97 52.10 1.96 3.07 3.03 1.00 4.09 3.71 2.20 2.36 60.26 0.74 - - - 1997 1.14 12.75 0.55 1.99 52.60 0.96 3.15 3.11 2.64 4.24 3.84 3.50 2.38 60.74 0.80 - - - 1998i 1 14 12.82 0.55 2.02 53.20 1.14 3.23 3. 181 2.25 4.39 3.98 3.65 2.44 62.25 2.49 3.28 83.54 - 19991 1 15 12.89 0.55 2.03 53.70 0.94 3.21 3.261 2.52 4.56 4.13 3.77 2.50 63.66 2.27 3.28 83.54 0.00 2000 1 15 12.97 0.62 2.05 54.20 0.93 3.40 3.35 2.76 4.72 4.28 3.63 2.54 64.77 1.741 3.28 83.61 0.08 2001 1 16 13.01 0.31 2.06 54.40 0.37 3.37, 3.321 -0.90 4.69 4.25 -0.70 2.54 64.65 -0.19 ! 3.35, 85.43 2.18 2002 1.16 13.06 0.38 2.07 54.60 0.37 3.341 3.29. -0.90 1 4.65 4.22 -0.71 2.51 63.92! -1.13 3.37 86.05 0.73 2003 1.17 13.11 0.38 2.08 54.80 0.37 3.31 3 26 -0.91 4.62 4.19 -0.71 2.51 63.941 0.03! 3.39 8657 0.60 2004 1 17 13.16 0.38 2.09 55.10 0.55 3.28 3.23 -0.92 4.59 4.16 -072, 2.51 63.881 -0.09 3.421 87.10 0.61 2005 1.18 13.22 0.46 2.09 55.30 0.36 3.24 3.191 -1 24 4.56 4.13 -0.72 2.50 63.84 -0.06! 3.441 87.631 0.61 2006 1 18 13.30 0.61 2.09 55.30 0.00 3.24 3.19 0.00 4.56 4.13 0.00 2.51 63.94 0.161 3.45 88.10 0.54 2007 1,19 13.38 0.60 2.09 55.30 0.00 3.24 3.19 0.00 4.56 4.13 0.00 2.51 64.06 0.19 3.45 88.10 0.00 2008 1.20 13.48 0.75 2.09 55.30 0.00 3.24 3.19 0.00 4.56 4.13 0.00 2.51 64.07 0.02 3.45 88.10 0.00 2009 1.21 13.58 0.74 2.09 55.30 0.00 3.24 3.19 0.00 4.56 4.13 0.00 2.51 64.07 0.00 3.45 88.10 0.00 2010 1.22 13.69 0.81 2.09 55.30 0.00 3.24 3.19 0.00 4.56 4.13 0.00 2.51 64.07 0.00 3.45 88.10 0.00 2011 1 23 13.81 0.88 2.09 55.30 0.00 3.24 3.19 0.00 4.56 4.13 0.00 2.51 64.07 0.00 3.45 88.10 0.00 Notes: I Based on producion costotUSD1 2.3/ton (estmated by Mine Engineering Departmnenton May 3,1994) January 11,1995 2j Based on FOB price estimated by IBRD (June 1994) and included treight and insurance cost of USD 7.0/ton and inland transportation cost of USD 6.0/ton. c/ Estimated by PTT on Novenber 15,1994. Souroe: EGAT's Power Developmnent Plan 95-01 (Volume I : Main Report). TABLE 5.2 FUEL PRICE FOR OPTIMIZATION OF EGAT'S PDP 95-01 (CURRENT PRICE) Fiscal Lignite (Mae Moh) Imported Coal Heavy Oil Diesel Oil Natural Gas Natural Gas Year (0.5 %Sul ( Manmart USD/MBtu USD/Ton % Inc. USD/MBtu USD/Ton % Inc. USD/MBtu |THB/Litre % Inc. USD/MBtu TIHB/Lilre % Inc. USD/MBtu THB/MBtu % Inc. USD/MBtu THB/MBtu % Inc. 1994 1.98 19.67 - 1.91 50.44 - 3.62 3.57 - 6.43 5.83 - 2.71 69.12 - - - - 1995 1.75 17.39 -11.59 2.00 52.84 4.76 3.77 3.72 4.20 6.66 6.04 3.60 2.68 68.29 -1.20 - - - 1996 1.84 18.27 5.06 2.09 55.29 4.64 3.92 3.87 4.03 6.89 6.24 3.31 2.78 70.77 3.63 - - - 1997 1.93 19.22 5.20 2.18 57.46 3.92 4.12 4.07 5.17 7.16 6.50 4.17 2.88 73.45 3.79 - - - 1998 2.03 20.20 5.10 2.26 59.65 3.81 4.33 4.27 4.91 7.46 6.77 4.15 3.02 77.12 5.00 3.77 96.17 - 1999 2.14 21.25 5.20 2.34 61.85 3.69 4.55 4.49 5.15 7.77 7.05 4.14 3.16 80.56 4.46 3.77 96.24 0.071 2000, 2.25 22.34 5.13 2.43 64.27 3.91 4.80 4.73 5.35 8.12 7.36 4.40 3.27 83.50 3.65 3.97 101.11 5.06 2001 2.37 23.50 5.19 2.50 66.08 2.82| 4.86l 4.79 1.27 8.23 7.46 1.36 3.33 85.01 1.81 4.11 104.81 3.661 2002 2.49 24.71 5.15 2.58 68.01 2.92 4.92 4.85 1.25 8.33 7.55 1.21 3.37 85.86 1.00 4.18 106.71 1.81j 2003 2.61 25.98 5.14 2.65 69.96 2.87 4.98 4.92 1.441 8.44 7.65 1.32 3.43 87.51 1.92 4.25 108.47 1.65 2004 2.75 27.33 5.20 2.72 71.92 2.80 5.06 4.99 1.421 8.56 7.76 1.44 3.49 89.10 1.82| 4.33 110.31 1.70 2005 2.89 28.75 5.20 2.80 74.01 2.91 5.13 5.06 1.40 8.67 7.86 1.29 3.56 90.81 1.92 4.40 112.14; 1.66 2006 3.04 30.24 5.18 2.831 74.601 0.80 5.14 5.07 0.20 8.70 7.89 0.38 3.63 92.60 1,97 4.46 113.85 1.521 2007 3.20 31.81 5.19 2.85 75.20 0.80 5.141 5.07 0.00 8.74 7.93 0.51 3.75 95.58 3.22 4.51 115.02 1.03 2008 3.37 33.47 5.22 2.87 75.83 0.84 5.15| 5.07 0.00 8.77 7.95 0.25 3.80 96.84 1.32 4.56 116.19 1.02 2009 3.54 35.21 5.20 2.90 76.48 0.86 5.15 5.07 0.00 8.81 7.99 0.50 3.84 97.60 0.78 4.62 117.88 1.45 2010 3.73 37.04 5.20 2.92 77.15 0.88 5.16 5.08 0.20 8.85 8.02 0.38 3.96 100.96 3.44 4.65 118.59 0.60 2011 3.92 38.98 5.24 2.95 77.85 0.911 5.16 5.09 0.20 8.89 8.06 0.50 4.08 104.01 3.02 4.70 119.85 1.06 Notes a/ Transfer price of lignite estimated by Account Department. January 1 i,t995 b/ Based on FOB price estimated by IBRD (June 1994) and included freight end insurance cost of USD 7.0/ton, import duty of 1% of FOB price and inland transportation cost of USD 6.0/ton. c/ Estimated by PTT on November 15,1994. Source: EGAT's Powar Development Plan 95-01 (Volume li: Financial Analysis). TABLE 5.3 CALCULATION OF EIRR OF EGAT'S PDP 95-01 (1995-1998) TRANSMISSION SYSTEM EXPANSION PROJECT NO.9 Fiscal Cost Stream Benefit Stream Net Year Capital O&M Incremental Total Total Incremental Average Selling Price Sale Benefit Cost Cost Energy Cost Energy Energy Sale THE/kWh) Revenue (MTHB) Cost Sale (GWh) (GWh) Current Price 1994 Price (MTHB) 1991 387.98 387.98 -387.98 1992 1403.43 1403.43 --1403.43 1993 5911.93 5911.93 -5911.93 -1994 15628.98 15628.98 63643.3 -15628.98 1995 23521.00 632.77 8604.67 32758.44 71577.1 7933.81 1.3603 1.3080 10377.27 -22381.17 1996 18629.71 1461.53 1655936 36650.59 78786.4 15143.04 1.4363 1.3279 20109.05 -16541.54 1997 9831.66 1771.95 22386.74 33990.34 85524.8 21881.42 1.5334 1.3632 29828.47 -4161.88 1998 5611.30 1978.09 24873.59 32462.98 92472.8 28829.45 1.5556 1.3297 38335.48 5872.51 1999 1978.09 24873.59 26851.68 92472.8| 28829.45 1.5556 1.3297 38335.48 11483.81 1 2000 1978.09 1 24873.59 26851.68 92472.8 ! 28829.45 1.5556 1.3297 38335.48 11483.81 2001 1978.09 1 24873.59 26851.68 92472.8 28829.45 1.5556 1.3297 38335.48 11483.81 20021 1978.09 24873.591 26851 68 92472.8 28829.45 1.55561 1.3297 38335.48) 11483.81 2003 1978.091 24873.59 26851.68 92472.81 28829.45 1.5556 1.3297 38335.48 11483.81 2004 | 1978.09 24873.59 26851.68 92472.8 28829.45 | .55S6 1.3297 38335.48 11453.81 2005 1 1978.091 24873.591 26851.68 92472.08 28829.451 1.5556 1.3297 38335.48! 11483.81 2006 1978.091 24873.59 26851.68 92472.8 28829.45) 1.5556 1.3297 38335.48 11483.81 2007 1978.09| 24873.59 26851.68 92472.8 28829.45 1.5556 1.3297 3833548! 11483.81 2008 1978.09 24873.59 26851.68 92472.8 28829.45 1.5556 1.3297 38335.48 11483.81 2009 1978.09 24873.59 26851.68 92472.8 28829.45 1.5556 1.3297 38335.48 11483.81 2010 1978.09 24873.59 26851.68 92472.8 28829.45 1.5556 1.3297 38335.48 11483.81 2011 1978.09 24873.59 26851.68 92472.5) 28829.45 1.5556 1.3297 38335.48 11483.81 2012 1978.09 24873.59 26851.68 92472.8 28829.45 1.5556 1.3297 38335.48 11483.81 2013 1978.09 24873.59 26851.68 92472.8 28829.45 1.5556 1.3297 38335.48 11483.81 2014 1978.09 24873.59 26851.68 92472.E; 28829.45 1.5556 1.3297 38335.48 11483.81 2015 1978.09 24873.59 26851.68 92472.8 28829.45 1.5556 1.3297 38335.48 11483.81 2016 1978.09 24873.59 26851.68 92472,1 28829.45 1.5556 1.3297 38335.48 11483.81 2017 1978.09 24873.59 26851.68 92472.8| 28829.45 1.5556 1.3297 38335.48 11483.81 2018 1978.09 24873.59 ! 26851.68 92472.8 28829.45 1.5556 1.3297 38335.48 11483.81 2019| -8264.69 1978.09 24373.591 18586.99 92472,8 | 28829.45 1.5556 1 1.3297 38335.48 19748.50 Total 72661.30 47384.18 594769.71 714815.19 - - - - 903695.40 188880.22 P.V. 5o%OR s37808e4 1 _12134.02 151952.64 217867.50 _ j - _ - 226222.04 8354.54 Economic Internal Rate of Return - 11.77% 30-Mar-95 TABLE 5.4 CALCULATION OF FIRR OF EGAT'S PDP 95-01 (1995-1998) TRANSMISSION SYSTEM EXPANSION PROJECT NO. 9 Fiscal Cost Stream Benefit Stream Net Year Capital O&M Incremental Total Total Incremental Average Selling Price Sale Benefit Cost Cost Energy Cost Energy Energy Sale (TH /kWh Revenue (MTHB) 1991 397.58 Cost Sale (GWh) (GWh) Current Prce 1994 Prce (MTHB) _ 9. 1991 397.58 397.58 -397.58 1992 1439.83 1439.83 -1439.83 1993 6499.23 6499.23 -6499.23 1994 17332.00 17332.00 63643.3 -17332.00 1995 27553.26 726.57 9335.67 37615.50 71577.1 7933.81 1.3603 1.3080 10792.36 -26823.14 1996 24292.65 1743.33 20515.44 46551.42 78786.4 15143.04 1.4363 1.3279 21749.95 -24801.47 1997 13028.85 2118.87 31305.83 46453.55 85524.8 21881.42 1.5334 1.3632 33552.97 -12900.58 1 998 7423.70 2381.37 35121.17 44926.25 92472.8 28829.45 1.5556 1.3297 44847.09 -79.15 1999 2381.37 35121.17 37502.55 92472.8 28829.45 1.5556 1.3297 44847.09 7344.55 2000 2381.37 35121.17 37502.55 92472.8 28829.45 1.5556 1.3297 44847.09 7344.55 2001 2381.37 35121.17 37502.55 92472.8 28829.45 1.5556 1.3297 44847.09 7344.55 2002 2381.37 35121.17 37502.55 92472.8 28829.45 1.5556 1.3297 44847.09 7344.55 2003 2381.37 35121.17 37502.55 92472.8 28829.45 1.5556 1.3297 44847.09 7344.55 2004 2381.37 35121.17 37502.55 92472.8 28829.45 1.5556 1.3297 44847.09 7344.55 4o- 2005 2381.37 35121.17 37502.55 92472.8 28829.45 1.5556 1.3297 44847.09 7344.55 2006 2381.37 35121.17 37502.55 92472.8 28829.45 1.5556 1.3297 44847.09 7344.55 2007 2381.37 35121.17 37502.55 92472.8 28829 45 1.5556 1.3297 44847.09 7344.55 2008 2381.37 35121.17 37502.55 92472.8 28829.45 1.5556 1.3297 44847.09 7344.55 2009 2381.37 35121.17 37502.55 92472.8 28829.45 1.5556 1.3297 44847.09 7344.55 2010 2381.37 35121.17 37502.55 92472.8 28829.45 1.5556 1.3297 44847.09 7344.55 2011 2381.37 35121.17 37502.55 92472.8 28829.45 1.5556 1.3297 44847.09 7344.55 2012 2381.37 35121.17 37502.55 92472 8 28829.45 1.5556 1.3297 44847.09 7344.55 2013 2381.37 35121.17 37502.55 92472.8 28829.45 1.5556 1.3297 44847.09 7344.55 2014 2381.37 35121.17 37502.55 92472.8 28829.45 1.5556 1.3297 44847.09 7344.55 2015 2381.37 35121.17 37502.55 92472.8 28829.45 1.5556 1.3297 44847.09 7344.55 2016 2381.37 35121.17 37502.55 92472.8 28829.45 1.5556 1.3297 44847.09 7344.55 2017 2381.37 35121.17 37502.55 92472.8 28829.45 1.5556 1.3297 44847.09 7344.55 2018 2381.37 35121.17 37502.55 92472.8 28829.45 1.5556 1.3297 44847.09 7344.55 2019 - 10319.98 _ 2381.37 35121.17 _ 27182.57 92472.8 _ 28829.45 1.5556 1.3297 44847.09 17664.53 Total 87647.12 56978.96 833822.74 978448.82 - - - - 1052731.31 74282.49 P.V. @00%Drt 64451.00 14565.67 210681.85 289698.53 _ _ _ - 261867.78 -27830.74 Financial Internal Rate of Return 4.51% 26- May-95 APPENDIX 1 LOAD FLOW DIAGRAMS OF THE PROPOSED PLAN OF EACH SUBPROJECT -147- TO SAI NOI 14 -140 204 -199-25 1541 390 14.3 2 40 0 39 0 _IZ2 5 -40.0~~~~~~~~~~~~~Al0.9 202~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~4 ) H 1.0) 1)4.0 I 251 1 l 772 8 6vovl l . i 7804 2 _ 102 5 1953 2 3xl9+X3 MN N '_ 706701 0 1MW -23 11.2 KSi 14 -t _$11 If2 1 _ 7702 5 r sr Xrr 789 SOUTH THON BURI I CDOO 0 528. 25~~~~~~~~~~~~~~~~~~~~uprjetNo TO~~ ~ lXANG SAAN O CHAMHN o2v raCl 01A7-T59 DR CAS NCS-98P-1O |r ll L.~ ~ ~~~~~~~7 -4 XC-| 235C1 1T9 1.0_ S21 124 |1. .-7°'1 |13 1 1421o RHB3 6. ;2 i. 026X . Vu 102} 031. 1~~ ~ ~~~~ ~ ~~~~~~~~~~~~~~ 1 .031 X |13 j 77 8 7lV lV R 1 7. I 77 0 .I . 'I . .2. 771 . -23.0 3X(X20 .20)M 7. 2 3E t' -4.8172 THAOAN SAPHAN NA SRINAGARND_ g~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~7 0_ 7 DIA7 9ZDW| 19 TO SAI NOI 205 -20i = . -198 11.7 0 .3 9 5. .8 . i 2 - 2 0 'IO -290 11.7 -39.3 45.8 203 _199 Y,HL 1.046 ~~~~~~~11.5 KHA LJ-i I1 .1 77Sl|t5 "I) - - MTI HI KS.0191 o7 oo_ ,4l0 3,,9 THA THJNG NA_ . SRINAGARIND ° 5f 13 _ 5 . 52 5 L _9.7053 SNR 106045 lX(2X200+2001132 ' l 1 tW 1 1 115189 -726 11j j .THA THUNii NA SRINAGARIND~ ~ ~ ~ ~ ~ ~ ~~~~~~~~~~~~~~71 SOT TONBU~ TO BANG S APNAN KTOCHAMHN aupoec o 2X|9-X30 W R2 7 82 6 1 -19.8 7705 -2. 7704 -26 5 7703 - 7730 -26.0 p?6 1.00~~~-8.48 P81 DP .009 3 3X 4-20 .2 00 0 M TO BANG SAPHAN TO CHIJMPNON~~~~~~~~~~~~ SI 099 K~~~' I [JiA7.1S9 DRW I 1998 -7!4115k- TO SAI NOI 204 -200 14: -147 13 . 7 -1.9 -39. 39. 3 204 -200 149 -147 3. -19 -39.V5 3 9.3 202 -199 2X19elX35 MW 7713 l t 1. 046 3Sx327o+2xlso MW 94 >13.4 -2.0 (4;) i) 3436-2 426 71 vS ~ ~ ~~229a 2 -1 8BP7 ! -f i 77127724 . v 1jO3 -19.8 10 29 _ 0 1 ra k -9 8 H3.4-2.0 1- 9r s -137 6 _ 77411 | -i7.7 1.99 -KHAO ~ ~ ~ ~ KEN KRACHA B3P2^~iU 3XI00 HW ~~~~~~~~~~~~~~7801 * 1. 3001.05 141.9 1. 19 6 -191 S_R 7; r 0 0 7 0 _5 .5 RS380 1 1.025 plll rm . 1.0227804 16043 |I| 7720 M ralX -i°s 63 7t7798 -14.032 3X12X2' 00 02C 2M 4 5 e4er ° THA THUNG NA I CHUAGHONI | I 101 % 2X19a 1230 I 4W 004S ! 1E46 L3 I29.2X180 MW BA 'I 1 T | C 2.7 -27:0 770 17.9~~~~~~~~~~~~~~~~~~~~Al0.9 77 -19.0 17.2~~~~~~~~~~~~~~~~~~~~~~~~~~~~71 173T 4-. 59.9~~~~~~~~~~~~1.9Sl .9 -17.B 1.018~~~~~~~~~~~~~~~~~~~~~~I 6 r7l'4 -17.9 7816 -17.3 =11TO -3.6 SAl~~~~~~~~~~CS097 0.2977 SOUTH THON BURl -24 7716~~~~~~ ~7062. - 302 KB 1.015 TM 1.012 -1601.30 . .. ~ . 9 - 395 9. 7711 -14 3 77 - 4. CP7 .5 37 9SM .93 5420.94 04 0.64 504 096 0~~0~ ~ ~ 0 .r ~~0 ~~0 7 ~~ 2 05 -23.2 7704 -20.66 . 7703-249 730-2. -T- TOBA SPHN TOCUMHNSOUTHpTojet No.R1 1 4 2 -2~EM PLN6N DETLA AN 3PP3 3 5 7 P2 EA LOAD 771. OIA? ~S9 DRWI ~ 15kV BA PONG -BAN ONG2 INE TRPPED ASE NC-98R7 TO SAI NOI 203 -19 147 -106 1772 -5.6 -42.6 38.6 233 -MW 107 -17_ 17.2 -5.6 -42.6 38.6 201 - 97 (;) L 1.(p6 q) ! 1 _ O 25 75q ~ 16.91-5.7 4 146201 -9 7724 045 16.9 -5.7 _K__A_O~ olEN n c _ n r eBP2r 1.015 00AO IIW 70 -11.7 (T ) -51.4 _-6 6 30. -82 9 - 3 5 0 3.2 Pioa m K S 0o997 770 °174 123 cJ l . = n I-;i 1 _ 77i4 15 | -i7 9 S 1. 200]. 25 A1 oir 22.7 41 9 -41.4 OL1 I050 I0NR 1.045 26. -25.6 o ~ ~~~ ~ ~ 04 -33 6.2 -6 - 26. 25 12 124 0.023 0 0~~~~~~~~~~~~~~~~~~~70 713 6 6 3 -35.0 LOWE(R2 C29ENw2L 15. ~~ 53I529 I _ _ _ _ _ _ _ _1.31_ 712 92 1 O9 SA__ _ SP00A -17.1 16.2~~~oo2 101 - 1 .0 04 0 o 0519931 OUT TI-ON rn R6~~~~~~~~~92 02 I k(S 0 AA7-TS9DSW | 1qX 1 MM PN2 I70: 1 3.2 08 ,., 10067a59 7 0164 %Cp1I ITO -2' sAl 1 001 SOUTH THON BURI~~~~~SA 122 7 22 i1x 3. KAENG KRACHM 1.ti.L. -~~~~~~~~1.8 3.0SA2 2. 903 1025 PillS 1022 1.000 002 0.09727004215 692 72 122 7903 -. .. 242 eqm 1 02 1220 -6)1. 711~~~~~~~~~~~~~.~4. -. 4. 4. Lzz9. -9. 0' J]~~~~-9 27 5 224 774 24170. 22 B30 (30223PK3SN30099 fIT9A7.T~~~9 DR 7t3 4.2SAM 1PHRAN2 099 i2.2~~~~ ~~ 020 SN TO SAI NOI 205 -2 -S 53. 6 17.0 -48 561 4. 205 - 0 53.3 17.0 -4.B -56.1 49.3 2 0 3 -19_ 16.7 -4.9 g K7lL o .023 203 -319 7724z -31l.8 7 0_7301 1 i IOD _11.0 16.7 -4.9 K21AO LAEM 7801 (F)o (5) 43.7. 770 _ . -27.539g07'r |l92 352e100>1 Mi° -3 _§ 0. 28. 28. 25 38. MH eoeo .00 10045 7eO6..I XP -1. 78I00 M 1040 -G. - . .0 ;70 O2w m t tt3 AGO O I0 .0 1- _" P .3 % 2 _ - 2 548 _ 3-i4 275.1 11 03 ' SAI 0.999 TO -11.8 2 I 5 THA THONG NA SRINAGARIND 2X19.1X30 9*9 014 1.049 SA -W 12~~~~~~~~71 7-4S 1 040 4 ________________30 781 w T O6 (p9 . 22. -4.8 15.6~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~-5 581.3 S040I-O BR i 4 i S-STEM7 P 0EP LAP | b DIGS9DR | 997 l BA POGIoNKHO CHISi-AMPRSN DEOU UNE 5 BANGKO NCS97-1 -28.5~~ ~~~~~~~~~~~~~~~~~~~~~~~~~~~~-162. 21 - 5 -27.51~~~~~~~~~~~~~~~~~~~~~~~~~~ -. 1.010 TM 1,010 ~~~~~~~~119 o 12. 1TO 9210601 .. 105 04 .1 7 11 5. 7 7t ~ ~ ~ ~ ~ ~ ~~ ~729 ~ ..~ 700-2 0542 . 703I 3. 0 7730 UT-THONBUR -7 . 7 4... 527 2. 7 Su715ojec77No. TO BANG SAPHAN TOFN CHUMPHN S'~~1EMS PLMJMNG DEPT. LOAD JUN93, POP 94-01 NTS9-P 3 PEAK 2OD P7 7N ON2 7 -A OG OCT WIH3 1 DIA4-S9 DW 197 BA PONG - NKHONCHA~I - SMPI-RAN~DETOR UNECASENCS-7P-1 TO NONG CHOK 20I4 -26.9 6702 -17 5 6703 3 2 9 a 36 0 36'S 2 I _ 329 0. 9- -6.. 679 -667 TO ON NUCH 76 34. - BMIG PAKONG 60 1. 70S . -~~~~~~~~~~~~~~~~~~~~449 _ ( 2X55G).2X(2X6g .P2AKONG SP _W _ _ 06 --66334 _ _ _ TO BANG PHLI .; | - T -63. B 1 1 v - 1 6134 1.046 9°1 -14it 690 - 0~~~~~~~~~.4 680T -' * 6905-4 - >~~~~~I 30 1-t 0 07 rQ (I I 2J -. - ' ,134 ,. 132 1 - 4740 ~ ~ ~ ~ _,O ,!Og -22. -4ts . 40. -2^ '910 q° - i2 |.1 033 S C I 1 3i3i li°i4, 0.19rsoo 0~~~~4.0 -49.3^ 40.0| 2 t_- 3 1 U.'~~~~~~~~~~~~~~~~~~~~~~~~~~~~~5. I COS W- 1.009 l l 1 . 23 ' -2Z 10 -14S 6 1 -t.3 6.1. M W 31.1 -22.7~~~~~~~~~~~~~~~~~~~~~73 . 2. 09h2 005 ,l 1.001 6013 R1.l9 271 5i637 61 | 1.040 Cl . 1 09 0.9i5 41so9 61 P .nr do I k 4d TTm X1 xx1,el , tt 4 [30351 0 ;t -2731 .9 73.9 '9 ¢t 29.932§os -29.713! tS 117325 _ __ , __;_ __ 3 -43Fiq] erti lol,t;_261N 33 ILl -l2~~~~~~~~~~~~~~ 064 3~~~~0 0 -D . D . 4. S-° 0. -FSLSubproject No. 2 |SYSTEMS PLANNiNG OE>-T V OAD JL.N 33 .O FCF C- ' 9P11BSG |PEAK LOAD| ALCs|CSEBG9P1 . I I OIAs- DRW 1 1997 NORMAL CASE CASE .BG-11 . I 26. TO NONG CHOK TO RS . .66.6 72.= -64 3663. 62. 67 -667 _ _ _ 7TO ON NUCH 76. 6.4 679 BANG PAKONG 670 S 16 673 -71 6 .634 4412XSSOh.2XIM0O.120) Kw6 TO BANG PHLI 66 . I K b , i M I 0 1 1 0D Sj - i t t 6U a I _.066 6622 r6 .6 --9S 690555 00 7. .2.6 61 B B 2 |* S " 1. 1. - C 3 -6.5 6740 I, 2. .45. 000 ~ ~ ~ ~ ~ 0 00 0 R -6.5 1 1 1 .4.~~~~~~~~~~~~~~~~~~~~~~~7 -0,6.5 3 4 -6, .0 ~~~~~~~~~~~~~~~~~~~10937.1ID3 i737 sYo | |'% s e t ~~~~~~~ol w 1- - '. 4 2 -72 261F 665 0.226~~~~~~~~~~~~~~~~~~~~~~~~-3 1 Ir t t too to661 -262 CS <0 2.03 I- =ui__ 3-.- 1, - * ,0 01 -23J ~ ~ ~ ~~~LJ 6734 -77.7 -27.627 |6 . 2 | O I A S T S D P W 1 9 9 7 1 - 0 I. 2 , -0 7 0 0..~~~~~~~~~~~~~607. 0. 21-~~~~0.6 670 -is.0~~~1 660003 601.3 6707 -26.1 6706 -16.6~~~~~~~~~X6. M 66 0 030 . -I--~~~~~~~~~~~~~~~~~~~.. 09 o 9~ 60 365 70.9 -00.2 302~~~is T5 O - 11 6 -12.0~~~~~, 1 63 0. `360.700.9 00 6.7 -6. 22.6 -22.0~~~~~~~~~~~~~~~~~~~~~~~~2. 60 - ~~~~~~~~.1.7 -7.2 0.06 6709 -36.0 6904 2 -129 I ,.,000 0 0 00 *'0~~~~~~~~~~~~~7. 6 .10216195 SH21 lic 6 SH'i 'J", 'RY3 1 0. 50. 50.9209 52. 503 E .4 C .1 .9 67i 5 2 ~~6710 1. 6713 , ,, ,7 - 5 401322.20 ?16 9354 673 71o 0 22.1679 2. 26.4 27 9 -1, 2 0 -7.3 61~~~~~~3. 3. ub rje tNo 1962 2.206NG EPT LODJU662 PP 4 0.16 P973 1PE 42 LOAD3 6. 6 C 2200 623 J I - I I i~~~~~~~~~~~~~~~~~~~~7 .. __-. TO THA TABO TO TAXHLI 2 TO THA TAXO LB1 0.975 5710O -29.4 C3D 1.004 5704 ~~~-31.5 TO NAXH AWAN 0R3 1 042 TO NR2 -7=77 1792 1.021PC TOSI 502 m-9.5 TO PCH T- 2.I 9 79 70 1 021 57709 w > -27 .9 1*] -31.32 6 5 r S 0.99o 23.0 -24.3s F W 805 1 1 .r _ t | -i7 3 l 7v8 il3 141 - 4- Nf . ,r 23. :o 1.1 || 0136o 6-- -29.6 _ 5716 ri r i~~~~~Ti ; 07401 -0' - -2. _ T<1.3 039 1 ; _w t 720 _r2 03 -730 141 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 4 570 rd -32 9 5704 -32 2 5 700 -3.2 517fl l co c iiS. o.';! QZ- 1 04 ~ ~ ~ ~ ~ ~~0 1 2 5sM7 57 1 5 - -33.6 Ul 1.014 1.047 1 57-~~~~~~~~~~~~~~~~~~~~~~~~~~~~1.4 I 2I01 20s2x2002001 99I T209 S0 TO RS N ____ ____________ ________________________________________________________ SubprojecSubpoject No..33 - r SYSlEMS PLANNING DEPT . LO 93 PP 9-01 PTS9 PEAK LOAD NORMAL CASE | CASE A97P-tO W w DIA7-TS9CRW 1 t997 1 1 3 ,S1 .2. 571 -28.7 TO THA TARO TO TAKHLI 2 TO THk TARO . .L91 D.904 I 5105 -35.0 CBD 1.003 5714 93. V_ TO NAKH NAWAN 1 040 LB3 2. 020I 4 5712 e -209.9 I I TO PCH TO SKI 5033 -009 ST 'I1 0.93 1 5709 r ' -33.4 SR2 1 042 1159~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~50- _i3 .a ttr __s_, 4' 4_ 41'=;_i 5713 l1 24.0 1.022 019 1.010~~~~~~~~~~~~~~~~:12 :!t~~~ ~ ~ ~~~~~~~~~~ ~ ~ ~ ~~~~~~~~~~~ . .. .so 3 l 2. a u 57^$ - |-I I I WANG I ~~J1T TOO RS 0 >to 4'. -.053 TL~~TL4 ATI ~ ~~~~~~~~~~~~~~~~~~~~~~~~~~~ 1upoec Io 3 03| Ln ATI 570 3 -32.2~~~~~~~~~~~~~~~~~~~~~~573 '-3. z | SYSEM6 PLANING DET.LOAD lNci3.PP94 01 7P11SI PEAK LAI:-332 § 4;} 8 DIA5TS9.ORW | 1997 1 115kV TAKHU2-SING BUsAI LINE04 TRIPP0EO139 TI.C;ASE66000-97P.01 DBN 1.013 1.046 5601~~~~~~~~~~~~~~~~~~102 5715 -29.9 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~~~~~~~~~~~~~52 S7130 2 -29.6 3 J2 1 WAJ1G02OI 7 .6 57 9.1~~~~~~~~~~~~~~~~~~~~~0220 0094 SP, Oil~59 TO6 DIAS-1S9 DRW I 1997 I~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~09 1 TO THA TAKO TO TAIKHLI 2 TO THA TARO Le8 o. a98 5710 -25.9 CBD 0.983 0j 5714 -;27.6 TO NAINHN ;AWAN 081 1.03o 4|PE ~ ~~~~~~ ~ ~ ~ ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ 3393 1 .. 2 -29.4 29.5 5706 -8.3 3 2-14.1 19.5 TO .R2 LA2 . . __r0 1.010 i 5712 .52 -2 I2l TO PCH8 TO SoI_ 0 - 0C.9000 r m i r ; S 1 1.007 33.9 3 -33.4 13 9 - _ w 25. 3 -25.1 35.3 -23.1 s 2o 10 0 0.00.1 0IO 1.009 I. .3 575717 -24.0 Ii. 0 o 025 090 . 57 27 0.0;w|; T fflt ffl: ffl 3 5805 . T 5713 2 00IT .0o . 2.4 100 -'9' 0720 . . 20 5715~ ~~~ -25N 4l 5711wN Sw S .t. -2. ..2 00I0 -33.5 34.I I~I I _ _009 _ I_ I __ 571 -S -32.1 33.0 . 0 50. 5061 011 ., 1 030 801 .. _____ 0 00 - 0.2 ___ _ _ | B 1|0Y 0 AT2 D 00 09 5719 -25. 5711 O I -23.2 9 577. __ 6____ -29- 1 5704B -2 35087 27. 90 1 044 - . - ______________66-1 ~ -6 . o~~~~~~ooooo 02 0~~~~~~~~~~~~~~~~10 50 F 8 13.9~~~~~~~~~~~~~~~~~~ 8. 9 SP 1,~~~107 Ay90 'I~ 044 99100.00 ~~~2 5~~~~~~~ j 000~~~~~~~~255 5727 . J J 22 ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~505 - 6.7 ~ ~ ~ ~ ~ ~ ~ - -7 ..... - .12 lj~~~~~~~~~~~22202 0295 TO2 so 10 TO1.RS D'A3-1S9 ~~ PEAK LOAD -I SYSTMS LANINGDEP LOD JN~3PD727O 22.3O 0698 INRALCS IH11k H UG USAINCAET-8 9 S~~~~~~~~~~~ 1,11" -A-4~~~~~~~~~~~~~~~~~~~~~~~~~~~~ TO THiA TAKO TO TAKHLI 2 TO THA 1AXO L B1 0.992 S710 -27.1 CAD 0.976 5714 ~~~-28. TO NA0HA N AWAN -0 1034 -29.4 29.55706 . -14.1 W321e ri 6 S _ _ -iS T0 NR2:4.0 TO ERR T 1-5 129.4 129.1 97. -1. 1 4-'S 0mt LE 1 004 T C T SD r 5712 -72 -- -26.3 r r 7 SKI i00 _ I oe o 10 3 _ < r 9 4 w0 __ * $ 17.3 6 . 25.3 3 47.3 5.3 -.1 D 00 0!30 Si 0 95 5709 6.1 1 036 11 9611"'"'.'""* 2 993 -i34371 59. 00 T0 SDRS- SD0 . S 75 ATI - 3.3 IrL I I . 03 3~~~~~~570 | .n D V9EM PIANNiN DEAT2 LA J9,D9-19'1S 1 KLOD 15kV TAHI2 - SIG UIL7TIPDCS 1 r | 5715 DIA;-259 5711DRW3 - 6 _ 6710 04 919 * 1.040~~~~.4 1 226 -~~~~~~~~~L- -91 . 13. 02 -20.~~~~~2290000M ~~ DIAS.TS9 DRW I 1998~~~~-103 .07 RI02 TO THA TAKO TO TAXHLI 2 TO THA TAKO LEI 0.3338| CBD 1. 003 5714 -31.8 TO NAltHA N AWAN -O r 03 2 N 5706 -335 LB2 1.017 To PCH TO SKI 00 r.r 1 0 ..030 5 _ r S000 . ! o 0CD .i0 0 5708 - -33.1~~~~~~~~~~~~~~5 0 -9 O _ 07.9 3 r er r O 133 ~ 0.;629.; 2SL _ o X s rv N rs AT2~8. 631 -37~ ~~~~~2 2 _177 ro8o 4 lo 5 il sr l i3 94 ~ ~ ]H] DEN 0. ,,,9 .i2 5601 _:K1 1 ;n I°1 000 All 5701 u7 25 7 _ _ r 6 rl lo 9I 5716 1.011 -707l _-28.6r -ii 7 Wi23i3 < Oj o ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~~~. 00io 0007 000 -2778.0 ° 29.0 o,. 0 -18.1 17.8~~~~~~~~~~~~~~~~~A1 7 1a T -BN 7.21 AT21 1.0 -5 1.L 31. -17.1 17.7 Al T0 -3. Op.0.4 3 2 8 _ s i7 0 3 5715 -30.0 S71 . -29.1 0 ~~~~~~~~~~~~~0 000 ~ ~ ~ ~~~~~~~~~~~~~~. r.J41.04% - 1 1 .2 ~ 0 0 0 0 5.9 _2 _ _ _ 2 _ _ _ _ _ _ _ _T__ _ _ _ _ _ _ _ _3 2__ _ 1.145720 39. SP,_ 0.9 A I I io" 104I 57 9 -~-30. 00 11 512 024 884 1.030~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~IO3 L 100SR 3- J 20 2020 200 984 WANG NOI roSO 890T RS Subproject No. 4 SYSTEW PLANNING DEPT LCAD JUN993 PDP94-0o 96PO PEAK LOAD |NORMAL CASE rACF QD)1 Orn -in DIA5-TS9 DRW .^^-A TO THOK TAJCO TO TAKHLI 2 TO THJO TAKO LBI 0.997 5710 .26.0 050 0. 982 * 5714 -27.7 r TO NAKH N AWANA0 -29.4 _ 9-5 5 9. r 81 3 -14.1 14.0 TO A 23 -29.4 ___ 2. e 1+ ~~~~~~~~~~-14. 1.004 WL4*_ 1. 1~~~~~~~~~~~~~~9 OaXb' S7 1" t'I ,, : '4 'jt i:'^ 5712 -25. 7 2 TO PC _ Ski . _ ' , l'4.1 _____ 33. ~~5j ~ 20.1 X 20.3 -25.1 ro ,~ - . _1. 00_ 509 2 |4. 1 s 1.036 -97.9 SI P09 1.0il =1 3 ik~~~~~~~~~~T . 14 0.01. OIL 751 DRN 1.01a AT2 1.045~~~~~~~~AT 5701157 J - ~~~~~~~~ rn ___ ____~~~~~~~~~~~~~~~--7 41- II~~~~~~4 -20.4 20.9 j~~~~~~~~~~~~01 660I.2 ATI.10 270 ATI -0.~~ 08 0 997I Sp 1.007 AYl , .4 _ __ _ _ _ _ _ _ _ __ _ _ _ _ _ _ S7t -23.S~~~~~~~~~~~~~~~~~~~1 -2 S719 6 .040 I'v~~~~~~~1 439~ 00 4 ;2S.2 1 126~~~~~~~~~2 46 TO 1000 Y08S Subproject No. 4~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~02 L20.8 S"~~1EMS PLAMIING DEPT ,LQAD JJN~~~~3.POP94-O1 ~~~P11SRI ~ ~ LOAD NORMAL CASE CASE SRI-98.P-12O. D~~~AS-1~~~~~BCRW I 1998~ ~ ~ ~ ~ ~ ~~4 TO THA TAXO TO TAOI 2 TO TfA TARO 1B8 0.998 5780 -21.5 5714 -.3 TO NA S S'AWAN I. 8 -14.1 _4.8 T_ 900 n '52_ w T r ^ 2, g j -29.4 ___ . -14.1 0 T i '; : - C, 52, TO PCH TO SI-,: - a aC 82 1.00 *77~~~4. r ' _ 104.3 e 3. _t *e > r tt~~~~~S l Oil 249 24.4 24.9 -24.6 0.,f57;88 920. 53.'889 . a 570$ 7 r0. 7.2 .~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~9 *-7 I IS 3 tO > ) 10 5 Subproject No. 4~~~~~~~~~~~~~~~~10 AT2 1.809 8 998 8571 8.54 4.5~~~~~~~~~~~~~T AT 5'7 3 -44 DM | .011 AT21 . 1.04| 5601 ' -2_7 571 5 21.0 5781 ,-89.5 27.2 -27- oo-3.5 34.8 CC a 1 ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ .*- ~~~~~~.6.6 -2 -20.9 289 1*7 274 o 0 5 0 58 0 54 m 21 - .030 -28.7 57 4 a -~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~T . -- - 7.4 - 4~~~~~~~~~~~Tit. 5 i13 -1.~ ~ ~ ~ ~~~~-0. 131 7 _;.2 0.7 S71, ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~S -- -1273.2 098 2 4717 -6 .102 .12~~~~2 382.... ~~~~~~~~~~1 044 8W ~~~~~~~1.048 TO RS ~~~~~~~~~~~~~~~~Subproject No. 4 ~' SYSTEMS PLANNiING DEPT. LOAD JN3. POP 94-01 a6io PEA LOAD NORMAL CASE, WITH I115kV LrNE THALAN3 - SARABUP11 CASE SRI-98P-20 DIAS-TS9 ORW 1998~~~9 TO SAI NOT 2703 7032 - -1-9 56 106 -105 17.2 -5. -~~~~~~42.5 38.4 7 2 4 1 0 46 203 -199 116 0105 2 8 063: -5t . n 0 6 7804 _ _ _ 1 025 38 4 2X19 | lX30 MS 'nR SR~~~~~~~ ~~~ ~~IlAAIN .19 (T 5 3HL 7-67 3 8 1.4 *. -35 1 , 7[P1 av,r i 0.4 201 N l-li 1 _ 77iO 15 1 1 1i7 8 9 SA1 I. TO So f S; llissi l oRt 1~~~~~~1< of at ffi X C 4 0T liisi m T O 17~O -5 BP2 ~~~~~~~~~~12 8 KHAO~~~~~~~ LAE 7BO | - 2_1. |77 r 2;L _ 3 7.903 ^ q- o NW3 --T7 4 1 019 > 1 K°°° SW2 0. 991 i |-7 -i2. 7709 -17.5 28a 25 IIi.5 7.0 1. (2 4 5 LOWER 6 T-; n-a 7RnA .4 4 C5. BPS - I13 1 - 71- 613 132,6 6 . 1 001 |1. W7. I 2I77S V (a 41i 1 1 THA THUNG NA SRINAGARIND ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~~~~~~BAGKK O 7713 4 %~~~~~~~~~~~~~~~~~~~~~~~~~~~~6. 732 .7 30.7 -85 7728 3.1 22 4 1 70412.63 73 2. 7712 -13.1~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ -40 8 TO 102 BANGKSPA OCOPO upOKec N0 . bYSThMSPLANNNG DEPT LOAD JJN~3 P0P94-O1 gePiGA 1998 NORMAL CASE CASE250 P25.982P-iO62 TO SAI NOI 19.6 -7.9 -41.1 33 7 19. 6 -7.9 -41.1 33 7 21 -17 KHL 2.046 ~~~~~~~19 .3 -7.9 0 4 046 20 -7_9 _RAO LAM 19.3 B2724 - - 7 - 79 03 3X100 MW . ;19_ 00O~~~~~~~~~~~~~~~~~~1 '0 ~~~~~~~~~~~~~~~~~~~~~KS 0.996 123 ~~~~~~~~~~~~~~~~~~~~~~~~T .0 5 57709 -24.6 o a a 1 00~1 0.29s9.2 78KL a"110 94 jaX^19TlHX30 SINRl 1.045 41 M 1 4 06 -4~~" ..20............In. 6el2 I ~~~~~~~~~~~7-34 -119 ~ ~ 7 0 0 " ~ 7799 * 10221 7.0 21- SRINAGARIND 2Xl9.lX30 KW SNR ~1.047 ff 0.2XI80 KW 3.. 2 - ^7713 -13.9 30.3 -30.8 ): -51.4 52-,1 r, O I"43 _314B 1.01S 7712 6. -17.7 - -7 1 1 a 9~~~~~~~: -9 _ _ _ _ _ _ _ _ _ _ _ _ _ _ _- , 02 lse9 _15 3 6 TO XB 1.001 n! RB2 _ _ o * q a _ 21.017 770______8__________GKOK NOI -21~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~1 50 ., 1.101 TM4 1 03 a . 04 -05 TO1 7711 r -23.2 77 2 0. 5. 17 =. TO X 2.5S -2 8 _ 1 . 000 SOUTH THON BURI IKAE3N KEACHAN 2a 0 27 IR2 1(0) _B 0. 9;1|! S27r4 r %7 1-26,1 1711 - . 9~~~~~~~~~~~~~~~6 gKXXC .o | 0.990 CA. | . t 0.972 10 9 1 -47~~~~~~4 - ; 1 73t 12 1 ~~~~~~~~~0.198g -1. o99 -182 ~7,-801 -196 ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~0-23. 8.1 -7 9I . 8 I 00 2.9 -0 7 953 1025 P0 1 000 - 1 7922 25 Z-io s 7803 r Hr- 1-020 10 lsn *1 0 974 SY | C.996 SN42 0.99s0 t;NI 0.994, °N3 0.995 205 6N0. 974 77 -30 0 7704 : : -31.0 7703 -2929. l 1 ~~~~~~~~~~~7720, | e. 54 77l l- .8 II | ,~ 22.7 -22. ,.2 4° 56.7 75 5 0 , 0 0 C4^7-TS9.F0.6 -1.1 -0.3 0.9 1- .5 56. -0.3 0. PKEa109 OB , 0.990 7720 29 LOWER CENTRAL CC. I 3x12x201,200499TOBANGTO CANU PHON Subproject No. 5 S14F ES LANIG DEPT LOAD iN 93 PDP 94-O01 96P I RB2 PEAK LOAD 230kV RATCHABURI2 - HUA HIN LINE TRIPPED LCASE PB' -98P-1 I [MA7-TW.DRW ~ ~ ~ ~ ~ I 1.998 V TO SAI NOI 203 -19 107 -106 17.2 -0 .6 -42. 6 38.6 2 -199 1807 201 -19 78. _HL 1.046 2016.9 -5.7 7724 0.5 ~~~ ~~~~~201 -19 16.9 -5.71 X3HxAlO0O LAEM 74:B 1. 015 3X100 MN~ ~ ~ ~ ~ ~~~~~~761 -11. 7 ,-.-) (- ) Oj)J s 7 _ _ _ r r _ XS 0. 997 ~~~~JO 0 ~~~~~~~~~~~~~7709 -17.4 2Xl9+1X30 Mll 0 713 11 _ 5 6 382290+2 10 5 41 41 00 r X)(HL | 53 i °3-29-- -,2 17.0 00 SNs 1c4 41.9 l-41.4 7712 21^ _1_ -S.72 -; 8 .1 _ 15 6N N N0 2638256r * Tx T. N -4 9; 9Rn _2 ;5 6 79.A61 1T | - -3 90-13 7 2 |. 7 G _023 o.oo.o 730}~, - m 5 >7 L t t | i z 1t 5 17016.2 52| I8. PX .' s . 3B PRS ,U 1101 LOWER7CENTRAL.0C. | 1 7720 D SN.PDP - Ot WPt1+ | P L° | ZSV RATCHABUR!Z -HUA HIN UNE TRIPPED | CASE B980-0 |712 j.5 W181 - 19.1 _. -6.373 - 0 0~~~~~~~~~~~~~ii 1. -g0 4 04 BA TO O IKAENGKRA 020 7. 0~1 1, . . - 0012.4 62 7 S61. ..-i. 1. - . B 1 . 004 -~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~1.0-93 2.2 -2.5 - 6-2.9-0. 409R 425 b -19.0232 0 0 772 , ~ 7709 -23.0 7704-24.6 7303 -23.6 7710 -23. LOWER CENTRAL CC.~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~1 -1.02. 6.71. 9 0 9 0~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~60-. TO ShI NOI 205 -200 -S47 55.0 16.8 -20 -55.6 4B 8 205 -200 -54.7 55.0 03 _1 19 1tH L ;2 ' '| ' L2 ' e 1i0 5 0 26N R 3l li O 4 5 - ^ 1 6 . 4 - 48 8 " p ~ ~ ~ ~ 1.6I BP2 r 1.015 MO 790 `1 -~~~~~~~~~~~~~~~~~~~~~~~~~~~23 3 - I32 -1311 °27n6 1n7N13 l14 ., 0 1 125 XHL 790 -2m 68 54 .3 A6_T ~~~~~~~~-1~~~~~~~~-3 . n1 1 8 7.u 3 SU O BURT 13~~~~~~~~~10 -~~~~~~~ 2 -102 F Subrojct5o.0 TO BTUG SAPNSAN TO CHUIPNON SD-p,o*e,t_ No._ W SYSTEMS PLANNING DEPT. LOAD JUN9~3 VP 94-01 97P11RB2 | PEAK LOQAD| OPEN LINE 1I15kV RATcHABuRl2 - PHETCHABuRI | CASE PB-97P-1O g ss a7-1s9DRw 1997 1 0 24I TO- NONG CHOK 3 6704 -2 t -.7D 37' : ?72 _ 3 TotRs :;776 3 2 9 io -? TOBS 7~~~~~~~~~OONNCH. TO ON NUCH BANG PAKONG -16.5 3 -2p 67- -51.0 - - '-I ~~~~~~~~~~ 22Q550).2XI23O0120 K6W - - . 16 74-i2 41 r |1 i DDs7 1 .029 6802 -50 2 L _0 .. 60 1.0 01 1.3 001 1 a _ . . . 3 1~~~~~~~~~~1 6749 3.030o;16 - 33 6740 -1. - l 'aml I I I I 7I3 I -52.1 4 I 11 61.llI -66, 61.2- ugo 1.014 lo -36.0 |' '3 09ES337ET 0 N3PP03ft E O^ OA AE AEK9P1 a 6734, , 39 4 -4516 {~~~~~~~~~~~~~~~~~~~~~~~~~- .5 '- 14 1tT9S 9 -6 - . ~ - 1 634 1.029 -1 .6 ~~~~~~~~6707 03663 2. 0 1.016. JLP 1 90~~~~~~3.6 165 -1660 6709~ ~ ~ ~ ~ ~ ~ ~ ~~~~~~~~-. KIRIDHARN 36 6~~~~~02 0. 020i009i _ __ 3-03-03-0C3C-3 D - 12 BL n I i ~~~~ ~ ~~~~~~~046. RAYONG 2 iso 0 2 RY' ~~~~~~ ~67 4X1(2X03103121 KW5 6i31 - 25 57 A 30.6~~~~~~~~~~~~~~3. -5.7~~~~~~~~~~~~~~~~~~. Subproiect No. 6 SYTEMS PLANNING DEPT, LOAD JUN 93 PDP 94- 01 96P11 WVNK PEAKALCAE LOADK-8P1 DtA&-TSG ORW 19 OMLCS AEWK9P1 TO NONG CHOK 1i3 I Dil Ir 1 1 F 1 F j~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~.07 A103 .4 TO RS 31 81.2 3~ 31 ~~~~~~~~~~~~~~81.2 TO ON NUCH 27.3 _1i. = _ _ _ TO ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~BA1GPL 42 250 22i G P2A0)ONG 7 o _ 1.058PA0I - (2X550)2 N 67S0 - -12. 673 -6.7 -51.46TO BAN; PHLI 4 83.9 7144 lam45 80 1.053 8002 OH 0. 0 0 -.3 8 - _ . 35 1.021 1.''~~0-~- c o -DO3I. 80 1.33 1. 33 1.00 39 _. 4_ 10330 6 09ng ~~521 61 3i3 r 2 6D. a ~ ~ ~ ~ m. 5 6710 51>51' 1i616 667Y2 1 7 |e- mm 1i.01 1.032+12 lr- i 0'1~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~1 q t~~~~~~~~~~~~~~~~~~~~~~0 9 ic'5Si 25 o -3-°3 8.0~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~70_ . rii6 1 z 1 1 13037-5t -30,.7lo4~~~~~~~~~~~~~~~~~~~~~~07 . 3927 4810 130 882 1333 1841 1.812 4453 ~~~~~~~~~~~~~~~~~~ 1.060 801 ~~~~~~~1.838 N 1.02 8 C 6712 -17.1 6311 7 a L-856 6f713 .,-iP.s 6711 -15.1 671, -16.8 L717 -. -3 6718 627966 T_ tt 12~~~. 2 03i QS I i10 0.5 9 o -71. 3. 4.80 0- . 82 1. 1.0 012 2. 3. DIA6-T89 DRw I 1998 I6709 NAK0 O00 . 2X. MW 5 u prjc o | t | SEEMS P - NiNG DET.L - D PDP>01PtC | PE LOX | ORMAL VS,WITH 11kV UNE MCHIN BU2'WA5HA | CASE :-9OD-2 VIENTIANE . 0* 7 I 0.,. *.S -.3~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~m MNIU PHNOIG _ :S_o 2X(2XI212113)MW SYTM _LrNN DEP ,LOAD JUN 93.i PDP 940 T9 9 PA ODI NRMLOEAINCAEM29P D UR, _ _ ; _t. lil. d 1iW lia ''w , FE ' T , T . -T rLlI: i is°t-i°ai I 1 -"Xol,ol | sLoo -Ilszl i ] g14* sX I~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~4 SR~~'',_qtg"H1lcil 758. . 7 ' 2 ^° PC SKISbrjetN.7 ^[ -PI SYSTEMS PLANNING DEPT, LOAD JUN 93, PDP 94- 01, NTS8-Q097 Supojc No.4 LOD|7 N | DIA 2.TS 9 | 97 OML OPIERATiON |CASE MD2 -97P - 10| VIENTIANE .~~~~~~~~~~~~~~~~~~~~~~~~~~~~~0 075 00 S c0. o 00 NAN' NG :.,:'- 1'~~~~~~~~~~~~~~~~~~~~~~0 00 "~ 1~*~ 0 - - °' -"Ioo LS _ I-.~~~~~~~~~~~~~~f r~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~0 . _ c. 1 -s _0 - - - -- I _ _ _ i o:,.,,_ i' ,° +'-,': .: _________________________________________________Subproject No. 7 0 | '., SYSTEMS PLANNING DEPT,LOAD JUN 93. PDP 94-01 .MD2 -97(0-11 I PEAK LOAD I i ~ ,?~ 'r I1A TI 197t15KV. YASOTHON -AMNAT CHAROEN TRIPPED I CASE MD2 - 97P -11 q W 1 0tA2.T9 1 1997 1 1 R * , VIENTIANE THEUN HINBOUN tW . -s-' 1- ' - ~~~~~~~~~~~~~~~~~~~Z5'tJ t _ 11415 X,. E~~~~~~~~~~~~~~~~~ 5-t { I dL'. :11 11 1.1 'S - - 9 I e - = w w I I I~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~S5 t I # tsgtogs tIN Isl ;- . I 55 005+C4> Ut to s F -og -.4~~~~~~~~~~~~~~~~~~~~~~~~~T 4- 18 Ill - S _ . 14.l i== it 1 -~ il n - it - _ 05 3 _, 93 1 t | wAfS |~~~~~~~~~~~~~~~~~~ * i - tos 55- .. ~ tt.. - ~ ss tos ., to, r: ti SYSTEMS PLANMING DEPT.L1OAD JUN 93. POP9-01 NTS9-- 09 PEAK LOAD | WITH ,15I MUKDA4AN 2- THT PHANOM DC/ST AND I .~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~i f 2X NAN PHONG T IS 2~~~~S 0 VIEN.TIANE THEUN HINB HO1iN , l -iooloz >5 173e -77 i ( ~~~~~~~~~~~~~~~~~~~~~~~~~~~~THtAKHEK . 8 >'i'7] .t.t.' £'+t, ". e ;' t 'i~~~~~~~~~~~~~~4" 'S 2X (2X121+m .1 7 3) | W >1 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ W 7 7_1:o|.| J1NFTHEN l 7l :l1 s _ 001|l I III77n1|77JI7 - ':l'#ll~~~~~~~~~~~~~~~~~-6 LSi ;i3 g77i*71l 71 a1 j a lt J | | t o t X X | o c f | l E~~~~~~~~! NN TM m { { ,",L !1 ' M: ioRo ,0, ' i 'ii': | | 7'm. ? °,? *, . i i | I ni 7>7Z7j 1~~~~~~~~~~~~AVANN"ET '' '' 1_ - 4 SiE - W -1-fE w i1 1 ,!,^-iE 7H SR3 + 4-.in io . f .IIN HUAI HOR PCN ilCl ~~~~~~~~~~Subproject No. 8 -s' SYSTEMS PLANNING DEPT,L-OAD JUN93.PDP94-01,NBL-gQ- 10 PIEAK LOAD NOMA OPRAIO | ,&I DIA2. TS | 1998 ,OM OEAIN CS N8.9P VIENTIANE iTHUHEKO) I A,'' [<1'''' V r + ;Wz I~~~~~~~~~~~~~~~~~~~~' - 2X(2X12I.113)MW 5~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~.1~:001 F~~~~~~~~~~~~U I;^_r ; - ... C iol ,>,'i' si:',, -'5' S t _ _ ,.b .o It No. ~Y~PL~JIN -i:T, LODJN., POP................ i40 .NS . |9 J......... PEAK LOA I o 1|11' t:St'~~~~~ ~~~~ 199 WIT 115' 'i'N THN 2- NO ALMPUSOND/T CS B - _9"' -20S I 1- 1 #= -- I I I I liM CLg <8= 1 et _ D " F-1 E E -1g° i t _i il t _ A ns e n« | nm . x oig~~~~~~~~~~~~~~~~~~~~~~~~~~~~~NM HEIN ~~~~~~TT ,|| 7,___ _ i__ r 10 1 2 I I ~~~ t- ii"i # * siS 80 o 1z 1z s l~~~~~~~VW Wrt o . 1l ,,:i't Xi6 SR2 HUA DI2.T9| 19HOIH 1 VU(NTAI2- OGBAIMUSO C/Te S D 8-2 * , # .~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~R VIENTrIANE THEUN HINBO3UN {4~~~ ~ ~ ~~~~~~~~~~~~~ 330 s fl -. - -30.*- 2X(2XI21t113XHl N e -t~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~- I~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~S - -' I '0 20 o: m -*-NAM THEUJN 2 ~ T * @ 01 rSAVAWMAET U, .llJ.~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~Ji1,i rr-7 0 ! Ai A 7 t . kt 11 . 3 W .. HV 7r~i' I . ~~I SI b rojec: No. 9 034.......5-i: I~~~.i~ ~ SYTM P1NNN DETLA JUN 93 POP 940 .SU - - 980$ - ,10 | | 1&J -LOAD71 l0a % Xi D2IAA2 HO R I 199 NOMA T 'i:' SU-98P-1O FC O Subproject No. 9 PM7,- SYSTEMS PLANNING DEPT, LOAD JUN 99,PDP 94-O0tSU-90Q- 10 PEA LOAD tiRA PRTO CS U-9P-1 | }|DIA 2. TS 9 1998 1 EOMLOEAIN|CS U-9P-1 VIENrIANE THEUN NIHBOUIN TRAKHEK~~~~~~~~~~10 NNTHU NAM PHONG~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~SVINXE 0..) -41~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~4 ___________________________________________________ __________________________________ LS~~~~~~~~~~~~~~~~~~~** .0 S 00 0 1.l 40 1U 04 00 - 00 4~~~upojc o [J~iEMS~T~I~NIN DEPT. LOAD JUN93. PDP 94.01 ,TS9 - 098 PEAK OADT WITH 115 K ROI ET - PHAYAKHAPHUM PHISAI NE STRINGING CAE SU - 98P -A 2 4,! +1 SAVANNA99 AD 1 K PAYKHAHU PIAI- URNSCONDCS I 0~~~~~~~~~~HA O VlENTIsbNE ~~~~~~~~~~~~~~~~~~~THEtIN HINBOUN re"l si 4s1 &1 I_ IH 171 PRO -i- r-NtP 2r W J s ~ e i wr-!4r i 2X ,: 3 S |2Xl*2l5 -l t !,o ; 1;73 1 _rM i UR7 1 ;lj i 1-5- i:' . . _sOi | a E L i 3; F . [,:: I I | .:t 1: f _ m :. . ; r I I 1 i sAVAKKH=:~~~~~~~~~~~~~~~~~~I SVANMHE 9 _ 75 _ 16 | \ 15*i ~ ~ ~ ~ ~ -Sl.StI ;7l _ . _1:111 | | § { 1:iS571 _ _{iZ~~~~ T M'SXS .,_iia i7ttili||j L ~~~~~~~~~~~~~~~~~~~~~~~'1 VA~L - I r ' fi|SYSTEMS PLANNING DEPT, LOAD JUN 93, PDP 94- 01,NTS9 - °98t PEAK LOAOCAS BN | 4 | DU2 TSg | 1998 | VlyT~~~~~~~~~MfH 1 15 KV CFHAIYAPHUM -BAMNeT NARONG SC ON pC/sT |CS NI9P VIENTIANE THEL'N HINBOUN . W S9ll I > > t g°3' j * e.§*o~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~*0.1 105 __________j______________ ________________________ I °' nIl Li - -2_ NAM PHONG _ ° i r r _1 101 _b CPA N o 11 - __ _ _ _ _ _ _ _ _ _ _ _ LS LYES L G T 1 - 08 E1A L A T 1 7 - T S - 8 00 NAY- i=|. THEUI 2 I -i~/ -IA.TS 1998- . . I I fE Nole v I I T;E5lT I I | 0zn P. | FCH iXI ~~~~~~~~~~~~~~~~~~~Subproject No. IIss e | t|SYSTEMS PLANNING DEPT, LOAD JUN 93, PDP 94-Ot,.NTS9 - 098 PEAK LOAD WIT 11 5 VUO ACAHN ATHRLKS ND/T9l- | |DIA 2.TS 9 | 1998 |WT 1 VUO ACAMI-ATA>SODMT|CS l9P1 VIENTIANE THEK H _ r .1 i 1 -l | - 1 - ^ i +1 * .10.0 _ -LO. - 041.3. _ Ik 02 -0.2^ 0t°-- Ii THAKHEK~~~~~~~~~~~~SVNNXE S - . ,, .S T r _ bjc :^' l H~~T 7 " _ 7 | j ..i _ 71^__ __ - _ 7 0 0. u9l S)C e-FX0tNMM) S nXil i Xjl- ;; 4 t f D _ _ | 4 ___ --11 (2xj N~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~P0SN3 | TTU | nTs i| i1. *i9.iT z" , aicsz | | a?ss 4. 4b _ _ 1.00 II 1.00 00 . 0 ............ 100 -i 00* -1 l t|.|- -§ | 0 se i .s \ +7 J e X e - -. 0 2 + |x .p1 113510 i 5 ; ) | | ; _ X i " S o.s j ; | | 1 -0-- $ NDR0| } EtH I ~~~~~~~~~~~~~~~~~~~~~~~~~~~Subproject No. 12 o{o | L SYSTEMS PLANNING DEPT,LOAD JUN 93.,PDP 94-01, NTSg- Q98 PEAK LOAD |Xsf | DIA2.TS9 | 1998 { ~~~~~~~WITH 115 Ky SURIN-SANGKH-A SCON DC/ST |CASE SKfl-98P R T 95P PKK 5WJAFiABIA . .._0i ;;J L L 71S ' o n _ -i7 1 -005 I_10 i71-7¢t %,14Q Q i;; _ X1 ;t ~3> 000 _ 0 _1 101 0101 * _ *1* 0 -° 004 1 II~~ ~ ~ S; 114 0 ; r ;s3 0 00~~~~~~~~~~~~~~~~~ r | 1.|13 _lo. lo 7 }%.4 J~~~~~~~~~~~~~~~~~~~~~~~RW LN Subproject No. 13 agi | SYSTEMS PLANNING DEPT, LOAD JUN 93. PDP 94- 01 TS- 960-10 I PEAK LOAD NORMAL OPERATION CASE TS - 96P -10 DIA 3. TS9 1996 i BSP P1K KHANOM (27109 4L226 6 93 s :.09 IS 11T T 70A,AU .1 1 702' .26. - - 4.. miK t. ,2 lt . ; - - letiX N~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~" i F~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~o 6 00~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~10 UL~~~~~~~~~~~~~~~~~~~~~~~~~~~~~" l~~~~~~29 I 11 -, i _P s:,2 r 1 =AWS- . 1 |1SYSTEMS PLANNING DEPT, LoAD JUN93, PDP 94- 01,T5-9 11 . PEAK LOAD630A KHNOM-AKNSITHMMART 1CGT TRIPPED - 96P -11 |DIA 3. TS9 1971 -2 BSP PXX 010 rr-20 000200 KRHANOM (000 ioiooozo*, no 16 RAJJAPRi7BHA KA _ 000 _ 0 b7 _ L . - - - 01i 0101 ._0.0 0101l- .'-. -002 000 ....- .N C 0 _ - 9 D-A 3O TS 2 1999 ow -r; ,z .- ozo o 0 010 . ..-.S ,i707'20=' no - loot - - - 0.020 000 * 0000 002 * .0 .0.000 010 0000~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~BXGIPNG7t ; i Subproject No. 13 ,|SYSTEMS PLANNING DEPTLOAD JUN 93.,PDP94-01,.TS- 99Q -10 |PEAK LOAD WITH 115KV SURAT THANI-.THUNG SONG DCIST CASE TS -99P - 10 | f|DIA 3 . TS 9 1999 NORMAL OPERATION -~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ . b f ~ ~ ~ ~~~~~~~~~~~~~~~~~~~~~~~~~ 1 .-00 07 - o.5.1 070 ~~~~~~~~~~~~~~~~~-70.02rV RAJJAPRABHA I 0o _ vT1' i7 v * XG377ss, T" ;70 i _( tt3~ ~ ~ ~ ~ ~ ~ ~~5. 005 .5 .00.1____ __ _ 06 _ __ _ 0,3 0r00 1. ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~o oo° ". Oso 51 -- OT o is _ to _ . .1 Il ^.-.~ - , - - - ° -I - - - 00~~~~~~~~~~~ i - 7o ofll 0.000 i7 II 1* | __.0___ 1 _______ r r*04 |70 010 70 *5 .00 170 Ii iL - Xss 4 1 70 i01 '-H I 'tE 3 r t t 2 i770 i s'k? - .- - L 0 - - - - - - - -11 - - 0 L, d . 0.02 Subproject No. 13 I ..|SYSTEMIS PLANNING DEPT, LOAD JUN 93, POP 94- ol,TS-9Q 11KV PHTHLN-A PPEAK TRIPPE -9p l t f|DIA 3.TS 9 1991Kt9HATAUGLM -O ATIPE A E TS- g -1 BSP PUX . ~~~~~~~~~~~~~W (2770)OU12102.2261 RAJJ7,PRAEHh ~L 4, " ,tT'MrX - 710 MI * I s@7 0 A F -5 - - - - - - - - - *- - - 571~~~0 __ .223 X:i.: -I t2FF lANG LANG fl; 1>- Y TMS U(NNNG DPT OAD UN93PDP401.S9-9Q-3| PEK LOD | OPEN 115KV. NAKHON SI THAMMAPAT -THUNG SONG UNE |CASE TS - gP -2 @ | DIA 3 . TS 9 | 1996 _ _L BSP PK- I'M~ ~ ~ ~ i 2;L RAJJAPRASHA~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~XA3A 32375). 14336332.0351 77P 7 r3 7 3. -3. r loo 3.303- :2__ l 3I I.._a| l~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~36 i i- 33513i7 00 *$>351 z, 137 -3 5j, 1i:e jj t h H A~~~ ~~~t' n' 4 ..A±.AJH'4],1 31 3 313 ;33 iT i 13fl 251 33 . _a |e n,3 ~~~~~~~~~~~~l:~-31. 3 7 -i BOG LG t 5 o |Subproject No. 13 | .3 SYSTEMS PANNING-DEPT, LOAD JUN93, PDP901, NTS9 - 97 PEAK LOAD | WITH 115K. NAKHONSITHAMMARAT-THUNGSONG DCtST 3737 -63.0 3DIA .3 TS9 1997 333 -ND OPEN 115KV. THUNGSO3NA OPEN 1 CASE TS-97P-10 Cr, 3 I73 73397 URT HNI2cT BSP PKK ,too w~~~~~~~~~~~~~~~~~oo-a f4 g Z (2170001Z41(00taat 0D 1 40 . .5,2 1& >_.07 oni 1.000 0~~~~0 02 0.047 I 000~~~~~~~~~~~~~~~~~~~~~~4 n tit 7 s< _;7i 3 w 1bMM. r o.5 . ZO1 7. °l a. Ii744 9 o _ _ I -s7 113l s Z~1. VT 0 ' W; I - l' * o -4LDy_oc .' 9, 0 - ; 20 .4.]35l55 t7s4 xt , * :SO _ 00 - 40. Subproject No. 14 4 SYSTEMS PLANNING DEP, LOAD JUN 93, PDP 94-01 KNE-Qa1- ii PK LOD | 115KV. PATTANI - YALA TRPPED CASE KNE - 01P- 1 DIA 3. TS9 I 011 BSP P5K .U 0 e~~~~~~~~~~~~~~~~~~~e 708 5 o . o I 0.000 040. -00 4000S1 SL0 _ E O5.9 300P 9 O -N 40 - Io r 7 _ i r _ _ T i t _ w r * r 1.050~~~~~~~~~~~000 ... j 0 215~~~~~~~~~~~~~~~~~~~~~~~~i _0 _ 00 100 Fz i _ 4 s X r ir __ l3 4 _ _ _0 7 .teaJ1070 l lss lzjDIA70 *1i 3., T-S 19992 700. -°o 0;7 l _ .00]7 4 080 - 0.0001 | ?70 A wjw78 %? - w_ T* ! * |~~~~ X10 0 9 0- ~ 0040 sz 1;l -4 X ' HVDC s.s *~~ | | ______ 302 .200 - - ~ ~~~~~~~~~~~~~~~~~ 4'j' 0 007.0 i0 70 ft~~~~~~~~~~~~~~~~~~~~~~~~~~~~~Sbrjc No. 014 0.-o ! Wf I DIA S TSg | 1 999 1 . _ l~~~~~~~~~~~~~ ~~00 asp PKK a 2i.. I * a [ 7,. .... - l-.4s . F., 4- X _ _] . *~~.4V 7 + 1 T M: 4I . o o l | ua ' Lj W i 17 v - _lb e tt~juL -t .0 .| 77vb _ _ -i5 l -94.0 - 99 n *- - - - - t-O t ',-. ,j., HVDC 1z^Zfi ,. 1 1 ' g 116.0 X S 09 BANG LANW Subproject No. 14 SYSTEMS PLANNING DEPT, LOAD JUN 93, PDP 94-01,KNE- 990-1 PEAK LOAD 1 1 KV. HAT YAI 2 - PATTANI I CCT TRIPPED CASE KNEi- 99P - iL < DIA 3 TS13 1999 11K.HTA2PlAN1CTRPE| C SE N :-9 1 BSP PKK 12X75) . (4X012.26) 'I 1.051 702 I 7 l. 0 .000 - 7 _ _________, -L. tW;KBS~~~ 00 f o _ _ __ _ _ __ _ _ __ _ _ _ .7 '. . 5. _ On - - - - 100 . 11° ~ ~ 15 w1 5o1! i it 1 iz **~~~- 0'01 1066 O- 0.0 0_ *2 t~~~~~~ ~ ~ ~~~~~~~~~~~~~~ 0 0 S 0 5 0 _5 03 0 .10. tO 101 US 1s _000 _1 10_0 oL IT tv~~~~~~ Io I I .-"' "- tsHsq q 6° " 030 10s - ~ l I I 0 .1o0.3rr issXs 7 7 i _> _ r t si5 : | 05 -fl- +5O :o ,* |j. < 7 7 ° A L °. ___ ___ __ °5 s 0 0S040.5 q foJ ~ ;1 75 77.71 0 00 DC |, 1 1 010|nl.u 7no ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ S u p oj c N o.j 14. l.. SYSTEMS PLANNING DEPT LOAD JUN 93 PDP 94-01 ,I'ffS 9098 PEAK- L>OAD WIH2a|KHOGNA - YAL DCS 127 MC AEKE-9P 10 BANG LANG X T- Subproject No. 14 . |SYSTEMS PLANNING DEPT. LOAD JUN 93, PDP 9- 01NTS 9- 098 |PEAK LOAD | IH 2S0O6' KHLONG NGAE -YALA DC/ST 1272 MCM. |CASE KNE - 98P -1 0| ,f|DIA S . TS 9 i 998 11 PKK .40.-O 20 MT (2VS5).(4Z111,20422W 3.60 m~AX61 10,~~~~ '. T "~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~A o .(75rr - ~~ ~ ~ t@ _1..404 10lt l ;14.1 _ . . _ L--l0140 4 l , i, 3 u ol _ r LjO38 r; _ *_ * Lo3e~~~~~~~~~~~~~~~~~~22 Q 3~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~7' 1 010 = 010* _ _l o. 100 4 _* 1.0203 z Subproject No. 15 SYSTEMS PLANNING DEPT. LOAD JUN 93. PDP 94-01 PK -970- 10 PEAK LOAD -1 \A'f" DIAs. Ts 9 1999 NOMA OERTINCAE K-9P 1 BSP p1K CF .4 1.0 2A (2X15).(IX112.226) NW6 RAJJAPAIFt A BHA I 021 ~ ~ ~ ~ 0 Ct 0.224 0 1.001~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~10 A. o'~~~~' OPI 2 HVD u. - C 2 2. 3 0 2X 0 2r 2 l.s 25 1.0 -12.01.n _3 0As 1.026 _ o b R ( 1 ~ 2 i *SnorN -sY TE.S -P LA -1 -N 1DK 0-I i1 26KV _G - .K IP -A0 DIAS TS . 11 . .07. ,,,o,~~~ -. -. - 2.02... 0,0 2°it.000 . . 0.00 ,:_ 50 SYSTEM PL NNN DET LOA JU 9, P| |40 ,PK ,,-1 I PE K OA 15KV 'jN N APF K T lOOnXsT' TRIPE CAS PK-99 7, 1010 ,:AJ DIAS TS9 | 100 IVC|12; E ejzoei L j -43i-43z39 aolwoO I n s.Zz0 _ " XjaX(ansB-Xal^z. 4 BSP P1K '25 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 2 to ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ W _.06 P6.0 _ -i _065 ., 7 - 7 -1 0 2 0 . 0 7-| .t _ ._ __________________________________ _ Suprjet No. 15 ELOADJUN ,D 94.01 .P - 0. 11ANRMAL PERAIONSE1 . i 3;; .. . _ gL=: n- e w~~~~~~~~~~~~ i *.1-@1 -1. 111 217 _a^d1 n . io1H I;"'~~~W - 22 lIIHVC-.7 , .,j Gloi, Wi ~~~~~~~~~~~~~~~~~~~~~~~~~~~1 '. - 4. - '>!e -vD2I Subproject No. 15 |SYSTEMS PLANNNG DEPT.,LOAD JUN 93, PDP 94- 01,PK - 0O- 101 PEAK LOAD |NORMAL OPERATION |CASE PK-03P-1 DIA 3 . TS 921D03 -101 BSP P1K IM .000-20 r0 0 .-5 .- 0 - zS.II.Z 1| KA;SN 1KUNO .|1lla30, H ;'1~~~~~~~~~~2 0 a ,H ''- 0 A 00 0 00, t,, T ~ ~ ~ ~ ~ ~ ~ M A? A H 11, 00 3l __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ___ . _ . _ _ __ _ 01040 ~ ~ ~ ~ ~ ~ ~~]| IO7ito . a4i7 Il 0, '0057 709~ ~ ~ ~~~~~~~,~ .0~ , o. a . 5 ._ 0 _O__. On 0.00 ST ,1 0.00 - _ 0.00 9_ S _ 106 0 - t r D _ . _ _ _ t¢ * | _ r s 0007 I tF T;Tn f W a S'I 12- E t~~~~~- 0.0 .00 | f .5 jo l | l }{VDC .i,§ 3 9 | 000 *0.o Olo -~ ~~~~~~ ~~~~~~~ ~~o 3-3 . . ;j - 0ua = ; iii07 -iiio.0 rrr^9 |7 n -i 00.0 00 1 CC- LkENG ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 7 KRUNGt& ;; 00 "0 DI T 20 I 0~~~~~mW 106 ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~3 t 1-~~~~upo,c N.1 SYSTEMS PLANNING DEPT. LOAD JUN 93. PDP 94-01 .PK - o3a -11 PEAK LOAD 115KV. PHANGNGA - PHUKET 1 1CCT TRIPPED CASE PK - 03P -11~~~~~- F-7 DJA 3. TS 9 2003 I~~~HV L.0~~~~~~~~~~~~~~~~~~~~~~~~~.0-O0.0 31.0~~~~~~~~~~~~~~~~~~~~I - 111k 'L'~~- On .. 4 3 - 47 0 rS 70 s 4A -70~~~:1: _.0 --0 - - -10. .11' 3 . .011.0 0* z1Zl 470 -1. 0000 0.._ _14- 370 r -o 0 > . ... . 0471 5 .. 0 _T 0-7 l r > ..... ll .....~~~~~~~~~~~~~~~~~~ I C _ 135 4 -4077 476rt Ei2 1l ii - -- i l3'-B41 ., I to io -70 3 S Subproject No. 15 |SYSTEMS PLANNING DEPT LOAD JUN 93, PDP 94-01, NTSQ -097 PEAK LOAD OPEN115KV. PHANGN(A-PHUKET2 LINE CASE PK-97P-10 'sf DIA 3 TS9 1997 . BSP PKK 1C755 4401 - - 0 00 .00.0 '('1' 'N |~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~0 0000 .J 3090~ ~ ~ ~ 77 _ .LI .22W 70 -00- RIJJAPR!BIA I _.!r- -0 0; 6.c *77' 100 *00 - _00 0 7-~~~~~~~~~~~~~~~~~~~~ opT- _e8 3 I- }702~~~ ~~ 00 00 0 -=0 000 0 73i 50 -04 - _0 0 _ -0 _ _ _ ii -1 _ -1 SI o I 0t o~ 0 i I IX _ ' Ti~~~~~~~~~~~~~~~%l I, 4' 2r 'i"' MMs 00_i§Ni . . 0 0 0 .0S6 i , SYSTEMS PLANNING DEPT, LOAD JDN PDP 94- 01 PK - 970 - 11 p LOA5 i IU IQ0. 0 0 007 009 ' ' 07 CASE PK-97P-11 MAqwq BSP PSK .60,-2 i7W KHA1NO I..., _..\ @Xl IMJAPaARn __ i -j 100 _ . I-I I -F11: ; w I int '1 t HYDC I "4 . h tir l~HVD to~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~- Subproject No. 15 I SYSTEMS PLANNING DEPT. AD JUN 95, PDPP 9401,NTSQ - 096 PEAK LOAD VTH NEW 115KV. PHANGNGA - PHUKET 2 DCST CASE PK.. 98P-10 |DIA3. TSO 1998 1 BSP PK r? 1.000{ 360.-20 MR (32X0) (.40X112221) M RAJJAPtABHA 3I:) 0 3. 1 0 A k A: 3 _ __ - - ,-~~~~t. I Ill2. e < nco 1.l b I;o.i ~~~~~~~~~~~~~~~~~~-Ao h J . . I, o o2 M 1 ; .Subproject No. 16 SYSTEOAS PLANINING D.EPT, LOAD JUN 93, PDP 94- 01, NW - 980 - 1 0 1998LO NORMAL OPERATION LCASE NW - 98P - 10 \f/ DIA 3. TS 9198 0 4 BSP PKK .600-20 WAR (217S1 ,(Mfl2.226) RMJJAPRA-HA On . 0.4 a 3t 0 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~~~~~~~~~- aw1w7 " _,Cc4 317"5 _ _ ¢s3to 3X7RT] ^ w * to 1 _ | | I0.043 04 1.014 0007... .. o 00_ oW 1.0( M. -7 - _ _ 27, i,71} r _ 7 )|* W 5 Bo X oNu~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~7 _________________________________ ^ | :L; _________________ _ _ W1Subproject No. 16 I ~ SYSTEMS PLANNING DEPT, tOAD JUN 93. POP 94- 0Qi TS Cos PEAK LOAD WITH Ii 1 KV. Y(ALA - NARATHIWAT 2ND CCT CASE NWV - 98P - 20 It ILDA 3. TS g 1998 = BSP PKR Tf X T 1230722 120112.232s)Sl I.OtZ IJ I.ele @ Q 0 ( >~~~~~~~~~~~~~~~~~~~~ I -, L X 175 o.0075 ' r 1 7 ~ 2 l.a 3.00 0 " H T 9~~~~~~~~0 -.X 1a5 _2 _1 1.020 - -2 s7Cs a ^ r oVrDoCI _ _ Xn I I 2 - - I X -- ITt m;[k =ll q t CT~~~I 0 -5 selt~~~~~~~ lU 2 01 S v .| 550.2'0 1W I 0. 31 .Subproject No. 17 | SYSTEMS PLANNING DEPT, LOAD JUN93,PDP94- 01.BDN -980 - PEAK LOAD | NORMAL OPERATION CASE BDN 98P-10 r v TC 0 1 BSP PKK KHAONO RAJJAPR.BRA 0707 000, T.- 0 0 i -I -100- Jg~~~ ~ ~ 7r _- F" 'To b~i <1 a_5 _~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ ;117 _- 3 1_ .'.NC 0 ______________________________________________________________________u Subproject No. 17 SYSTEMS PLANNING DEPT, LOAD JUN 93. PDP 94- 01 ,NTS 9 - 098 PEAK LOAD WIH1 KISRTTAI-A O N C AEB \ 70I I DIA 3. TS 9 1998 W 5 S A - D 2N T C 22.0 -2109 .52.0 -51!3 29.6 -29.6 -n.5 - 26 -2 6 ' 1 6 12 li °~ -'' i oc_ - -S 29.6 9. 5 I~~~~~~~~~~~~~~~~~~~ 0. .7 00 . 033 06 0.08 02 034 4722 -06.3 4734 -073 4723 47.3 3. 00 1. 00 _iiI~ 637.0501 ;] S 083 3.023 _ . °|r _ 357 M,^s5)K3H 3 , r . 333 _ -52.4~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~- 47220 -A < te)30 11 __1 420 2005 22 4 6 , 4 ]3HU!11BOL se_:L 53 - 1ioo34 |~~~~~~~~47 .4 471 -19.n a 2, 07 . 0~~~~~~~~~~~~~1 T T~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~0 LPI 0 1-10 1021 -41~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~2 5 00 4 Z~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ 7~~~~~~~~057 .~ %) (4) ) t) (g) (§3 _ t 26 2 26 61 l l TO KHON NAE:N 3 6~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~TOKHN AE > _ 4 > 701 r w 3jo S S L~ ~~ ~~~~~~~~~~~~~~~~~~~~~~3.S; 2.0 i t 0 7 Lev 9~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~, '.2. 0po 0. s.o o. as .n - 7j 7s ; -9 36 r_.11 n -i6ll o ,5o$7 .. 4 -r4 0 99X oso n .- . 2 2 o 0 2 ol olr M qo s t~~~~~~~~~~~~~~~~~~~A I -2 2 47D0S tc 12 .3 P 471 -24.0 is.2 0 0 -2-43i2 1 X -i 2 1 ;W8o in 17 9 - - . 0 00.0 - P 0 TO N7210N00 gSAWOd TO NAJHOJ40 SVAO4 TO TNOA 'rAO Subproject No. 18 ,~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~40 , . 1 J8 ;: | s.'r_T0M PLASIMNG DEPT LOAD 1!N9., PDP 9-0' 97020 | PEAK LOAD | I ._. 1 2 27007 NORMAL CASE CASE CR-97P-10 3 4~~~~~~~~~~~~~~~~~~~~~~~~~~~IA a 22.1 -21. 9 9.13 -9.5 111l1lN9c72 11.C-17_3 _ 07.6 -00.3 _._ 12 4718 -T5. -C6.81 |2C M ;9 C i ov 7 , . : w . C46 !:6 3.9?7 5 ! 2 i * I.OS0~~~~~~~~~~~~~~~~~~~~~14 S. - -S3.1~~~~~~~~~~~~~~~~~~~~~~~~~~ .7. aS 356 75 3. -3.i o rr r? 3 . SO.2 B03MIOOL - El 31.6 -1. 2 |r 0(3) 3.2 t5()71 -6Z 41222 |7 171 2*|L7NMAEMOH 3 t |_ |~~~~~~~~~~~~~~~~~~~~ 0 D C- | 499 )0,~~~ as 1.22~~~~~~~~~~~~~~~~~~~~~~~~~~41 -2748 .5 _________________ 6 ~~~~~~~~MAEO3 0.~ 1Z¢5 | SIL\SIS CIANNING OEPT ~~~LOAM UD _ )4 ii.1J7Jt | E K L A HH VrœEMF1 .I AIL RPE I CA E R97-1 SIRIKIT 94X02586 W. 0~~~~~~~~~9 .7 Os I S 00 17 U,~ T 32 001~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~L .4 3, 9 3X I W~~~~~~~~~~~~~~~~~~~~~~~~~~. 5 .7 ~ ~~~4 g 4~~ ~ ~~~ - 4 0 1- 471 -;3,a~~~~~~~~~~~~~0 -0 TC j.3. 26.1~~~~~~~~~~~~~~~~~~~~~~~C0.1 -, 10.0 -9.9~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~L1 4 0.9 so 0. so 0. 4 4 0.99~~~~~~~~~~~~~~~~100 - . . DAd. -~~~~~~~~~~~~~~~9 ~~~~~~~R,VJ7- 41 3 1 01 23 7 -2346 -16~~~~~~~~~~~~~40 1. I~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~0 l;n I 2. Oil ii .;0 17 -, -' _ - Q4701 .'. 4 6 4726 -71 o I I nu 1 5; 6 _ 7322 , O. 36 _ _ 7-O 9)9@ 0 50 0. -50 . FY ^ 04 363 3 2 - 9 ,71*.7 - 07 'ii22Q 7 1 =in - .. i§1 jliL a 1 C 9 !iM7 _ . . _3 4722 4720_ _MAE_' 1 _ -__ 15 _v -o *74 -16 1 ,0_ -3 6 _ , _ o ;1 _ . 4T: 17 ~ -. 4703 7BOL 1191 IiII4 -. 6 . o -15, - 479 154 O jSO <>.so90 -5. (1(32 Tl 1 .0)CT 'i3~ 35 10 1 '~s° n3 ||L FF J~~~~~~~~~~~42 4_ T-= GoT_; I; Tm io _o_S _ i i I TTTTTo~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ III r r L - I .- 47 3-4 -. - .., . D' l. .l ,-1, | 2 ffTO NAXHON ZAN .1 1 2 TO NA}IO01 3AWIN TO TIIA TAKO _________ ____ ___ ___________ ___________________________ I. Subproject Na. 181 | SYST_MS PLANJNClII DEPT . LOAO JUJN937 FPO94-Ct 93Q1 C | FEAK LOAD |NOjRMAL CASE .WITH 230kV MAE MOH3 - CHIANG RAI |C S R9P1 01Z §DA4^-TS9 DRW , I 998 _. . * . .. 9 0. 0.91 3.22 _ t 7 F,34 _ | | liC42 Q12 1 > _ -i7 *_ 4818 iZ ^1i5°76 MI8E MOH-3 >~~~~~~. S3. -S. 37. 12t36,,.9S Si>1' (313~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~1. 1. 47722_ e -i7 34 4soMAE 9000* 3 7if .44~~~~~~~~~~~~~~03 01.5 2027 ~~~~~~~~~~~~~~~~~~~~~~901 - 5.2 ________________ OO~~~~~~~~~AENOH 3 40150 w 0. is io 4 T S 7 | >. > T Z _ - ^ ~ ~~~~~~~~~~~~~S,IR2IKIT_ - ~ 4X125 M0W Mc 1-22 s 4 i-2O.2 :7is, e nw> f i 0a46 997,: i7 600 4721 -3620i8 _ s .! _ s n T r o n i ~~~}1;0 j-767jjll|o w oi 0 0 4.4 ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~00 01. :Nl D!3 11.1 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 1 4 --6 -46~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~. 4 l ~ ~~~~~~ ~~~~~~~ ~~ ~ _72 4l Li sW }i 76f-l-lt FiCN SAWAN _TO NAKHIUON SAWANO To rHIA TAXO Subproject No. 18 | &23 | SYSTEMS PLANNING DEPT . LOAD JUN933. PDP94- 01 980 11 MAM2 PEAK LOAD | 230KU MAE MiOH 7- CHIANG RAI UNE TRIPPED CASE CR - 9P - 11 | DIA4-TS O3DRW | 1998 I . I M 2202 0 - -2 : ..25.~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~.2 2C7 - 2 9.10 eIO o <6 o I 1o$ on q 2 522 7 S2.0 19 7 7 -29 5 _ _ _ _7 52 .2 -Si 10 ,f . 2 -0 7.Z ___ __ i 2.? _ _~~~~~~1 -7 50 M211 07175ex -2 ? ~~ --~ of --1 : l50 1. O (o) Tio1 4722 -io el MM MO_ 3 4 50 _2 2 1. ., 4 . 5 . 26 103 9~~~~~~~~~~~~~~~~~~~~~~53~714 0< *00 3.5-1 SX7Y0 S 't I E 012 -17- | G (0) 0 I 0 1 i1 -2.2 1 v T :;° 4 .Ll 1>511 + 704| 2 0 No. 105019'1.1.. -7 99 000 6 I .241 700~~~~~~~T IT 7 ' S| ,0 r |7 7.7 HTJMTBOL 473 0-~~~~~~~~~~~~~~~~~~~~~~~~~~I02 02 6X002' u).lX70. K- TO 0HON0K.EN 7 j00~~~~51 ~~~~Tit__________ ____~~~~~~~~~1P4 .1 -S. 6~~~~~l1 ~ 0000 1 .4~~~~~~~~~~~~~~~~~~~~~~~Ii.3 '~~ sY0-TEMS PLANNING cEPT 93 POP 94- ~~~~~~.3I PEKLAPOL2JN .NRA AS AEK 9Pl I ~~~~~~~~~~~~~~~ 01 97010~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~1 0 / D2A4-TS9DRW 1997 . -- _____________ ____~~~~~~~~~~~~~~~~~~, - --::7 -.q - , 22.0 -2.9 C113~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~C 1.3 -l r 1.0 01 m 1.0.023OO 4719 - 25 4 4754 -29 -12.4 .~~~~~~~~~~2 2o 4! _iit ^2. o wi 1wi .S 6 .6 -S1.0 -3.I 4 P_ _ 01 1. 1.02 w -2.5 . 12,,2 |4i w 4 i3 4 -i 4722 17|0 _711 O' %3 s717 - 303i 4H7, r.Hl- 3.00 -3 ~ _ __ _ _ _ __ _ _ ___ F 1;___5 7__7 _ _ 4 9(Ae |E- wO6 I3 O 479 3 15. 0 50 9100 | 6&) 4 Oil 2 w o. - py .~~0992 ' I0000 10 i - C 71 X i-29 7 r_ IRIKI BHU7HIBot, ~ ~~~~~~~~~~~~~~~~~~~~ 40025 1940I _ +2 1 ln Xn G i 2 t | 0 -33 4 - . 74500 50 4 2150- 3 | 755 -2 -1 6 . l l | 1.0-9 _92 0 3 L 4723_ | 44 | | } r7 ;2 0.505 LAN KltABU [ rs --2:. 94 T.; 0. 0.0 S'~~~~~~~~~~2. 34.2 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~~~~~~~~2 24 13 0 1. 0395 2.2 7 2202 l, ,6 s | | 4?°A < _ 72 -6. 907 20.4 00 115.l X 7 -14.1 n ; l l I ItsW_ o6i>L CH3 CIS~ ~ ~ ~ ~ ~~~~~~WH 1 loG0 1 i F°S y _ii i S 49s . 1. D4S , 4 I r d r d -31 15i c7x7 0981 l l i12 ne _ t _ a0 0rj 2 TI X5W 7 L 9 o 6 MOE9003 j (6X701.1l111;51.(1X17S) ~ ~ ~ ~ ~ 1.71 999 1.5 79 007L79l o 9-.~~~~~~~. 12.C~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~. ii~~~~~~~~~~N no4 liej ac ceS7 9il 21}| 1 ' o - 2i3 21 1 +--e - rLl 1,, * l i, SS52it l~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~L 109 4722 -20.9 0. 0~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~0979097 R5 3 OO3 2- LAN P- X7ABU I 17 S _ -G.7 oi l i i~~~~~~~~~~~~~ 0. - .00 |4.9 A.r, 4,71r | |-ls. | r _ _ 1 0 N . 2 0|0 4708 4730 -. - 0 99 if'.... j~ ... KAE MOH 2~ ~ ~~~~~~~~~Supojc N.2 01A4-TS9.DRW PEAK ~~~~~~~~~~~~~~~~~~3LOA SYSTEMS PLANNING DEPT. LOAD] JUN ~~~~~~~~~~3 POP 94- 01 98O1CkJ 1998 NORMAL CASE CASE LP2-96P-10~~~~~~~~~~~~~2 42 7 3- 6.. 23.7 -23.5 1. 039 71 1.011 n.019 031 21.3 47113 4. 4734 4 t ^1 45.6- 473 -|5.1 H ~~~ 3 3 ^5O -l7~~~~~~~~~~~~~~~~~~~~~~~~~~~~~. 00 __ 3 1. o II)()g V63 4.00 063 2.0 2 1.03 C _1.l 9 4722 -07.3 34 . 2 - D _ . ( 3 LV l i l | i8 1 CR 4 °(D 412 473] |MO 3iD9 tSE~____2 A H2rrtc _ r BHUM3'BOB~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~010 6.6..i311] r N Ct) 4xl 0 NW 0 75 192033ig.SIj No T. 1 x...~~~~~~~~. X |S\7EtuS LA~tG uF LE t3 0. 00 1.0 044 on ;,. IJF I. T.:R I I 02I all 1.047 |(1 1.;73 |0 1.0230 2 o 472 - 5. 734 7 -1. 173 4. -17.24;8t I4 8l 3~ .s 6.7t w X -2a __ is ~~~~~~~~~~~~~~~~~~~~~~~~MM V06 4 3 . TI 07 LM 0 I .. 0 f 15 0 607 I ",- ia 4 UliOiD L i ! O 1oli 1-,,i's40 111 5bl.'jrjlS"' l~~~~~~~~~~~~~~~~~~~~~~~~~~~1010011KAZO { t t t 2 3 L2 ule; mlsi " 1ii°35 ii37 -ii 8~037 | Tr 0.996 039 8so l l 23 251 ¢]- 3 1 _ -6 9 l0907 4>4 ml UTE0aID1N Lz. 9l> . -10.5 471, -11.4 a~~~~~~~~~~~~~~~~~~~~~~~~~~-1. -. LAI TO6.4 NAiCHOW SA1SA 0 TO NI S7-3 Ul 1.021 S p j 1.. 03 401.0 32 -1:5 .47I *. 47045 , -25.8 | W | SSTES LANtNGDEP LA0 INtPGi 9-01310 | K K OAD| NRML CSE,WIT 15kVM3 AEN SBSTTIO | AS MlM98 1 3 1 1 1 . .2 80 -5.1 ~ ~ ~ ~ ~ -5.0 4703 01 98C~~iO 4708 -1S.4 - 1.0 -3.9 2.,~ ~ ~ ~ ~ ~ ~ ~ ~~~~~uprjc N.2 _ I I~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~1 1 . J~4T9 s LAD NOML.AS ,9H 15V A TEN SBTAIO CS MGsoP1 * APPENDIX 2 FULL NAME AND ABBREVIATION OF SUBSTATION -217- ..I ' - FUIL NAM[ AND ABB3REVIATION OF SUBSTATION 4O. SUBSTATIONS ABBR. NO. SUBSTATIONS ABBR. N. SUBSTATIONS ABBR. _. AnlNAT CHAROEN AN SS. TA- D0 RA LR 169. PHUKET 112 PKI12 2. ANG THONG 162 ATlb2 86. LAn TAKHONG _LK 17O. PHUNPHIN PP 3. AO PHAI 162 _ApI2 8 7. LAMPANC 1/2 L.PlP2 I& . PONG BON PBO 4.- AO UDOII AU BO8 1AMPHUN 11.2 LNI&2 172. IPRACHII4 BURl 142 PAI1.2 5.ARANYAPRATHET AR 89- LAN RABU 1KB 173. IPRACHUAP KHIRI KHAN PKK 6. AYuTTHAYA 1t2 ATII2 I 0- LAT PHRAO LPR 174. PRAXHON CHAI PrKAC 7. fAnWFT NARn. OA7 RUN IJ I UI 7% DPRA RI B- BAN BUNG _BHG 92- ...I_ _ t . PfRAN BUfll PO?WER STAT IUN PflT 9. BAN COK CHAN2 BCC 99. _ O SONAJJAPRABHA .CHIEE LARN) RPB T. VET UOOM 00 136. NA~~~~~~~~~~~LOI LUEN 1722. JAR12TAl . WANR DON ABDN 94. Lon SAK LS2 IN. TRANCSIT RS _. RAN DUNGC _ 8G _9. LOP BURI 162 81_6_2 2379. TRANONG RN 12H.BAN KHA N KLAN2 HBK_ 146- NLOAER MAE PING LMP N 80. HRANOT- RA HO. BAN NA SAN NS 197. nAE CHAET Mc a N 25. RATCHABURI 1.2NG RBI.26J 14. BAN PHAI HH 14 9N- InAE CHAN LAN Pa2U RATCHANVR6 224. THAKA 2BP21 HS. BAN PONG HH2 8P1 .2 nAE HONG SON nH 283. RATCHADAPHISEK RPS 16.BAN SANTI HST 100. nAE KHAn NHr 2248 RAroNG TY2&3 RYl.2&3 Ir. BAN YANG___r Brc IOI. InAE KOK nKK 185. ROI ET RE HU. BANG KAI HN 102- InAE KUH LUANG (NEA) nKL 186. SAHA HoN S 9g BANG LAnUNG BL IOJ. MAE K IANG MKC 187~ SADA0 SOO 20-0ANC LANG BLG 104M AE LAMA LUANGC nLL fg8A SAI NOI SNO 21 8BANG MAU NAK BMN 160. MAE nOH 1.2PJ 244.2& . UPPESAI BURI SBR ?2. BANG PA-IN 1 BNlE2 106. HAE HAO MINE n- 190- TSAKON GAKHON 192 Soit2 3. BANG PAKONC - PK 107. PAE NCAI N P I194. SALoKTAR SLB BANG SAPHAN BS N 109. MAE SARIANC _2SR 932. sAnuT SAKHON 1.26J SNI K2 *KRIDA-RNIHUAK SAHA H R SN 14. MAHO SO Hs 194. SAEUT HAENGKC MS ?7. BEToNc 8A I IPOnAE TAENG POT 195. SAN KAPI SKP K8R. KHuABOL Be 112-. nHA sARAKHAA MK 19r5 SANT KHA ALA VIO WIN OW -N29 AN- AR 19 SARABIJRI 162 SRI iO. 9VUSi KA. Soi 4. TA P;;uT NTP F 98. SA-Ah iR j &, SRJ3&4 . IUNC sAn PHAN BGS I Is. lnuKoAHAN 162 ME) 62 W 19 s S AI 162 |si iJ. URI RAM -- UR 116 I|NA KAE (OUT'OF SERVICE) H E 1l200 |SATUN |sTu Zi. lCHA-An CA 1 17. |NAKHON CHAISI |NCS 1l201. 1SAWANKHALOK SC _1 5,_ |CAEG WATTMANA - _ _W 120 |NAKHON PAHAOM NT 12 120.S RAlKHA ---SC- - 9 |CHiANG KAN -CKT 12J. [AKHON Si THAMnARAT | NST | 207r |SINC POURI SlU O. IC"IANC MAI 1 .243 cHI . 24 124. lNAM CHOEN _ NCE 1 20a. ISIRIKI I SK I . CH IANG RA I CR 125. NAM CHON |NCN 209 I S IR INDHORN SRD 2v .CHUPON CHICP 12lJ. INAM HAENi NSNHA 1 iUI Su D.COEnBUNG NACB- 1276 [NAii SUH-E* NAKI S|2) rK | rLe . HONC THON CTG 12| INAM L3UA NA§E 2PHU SOT DLAN KU so6I H . IHUAI NCAEO _ H~~~~~CNC 129. NM KHAN NM 21122. SOUTHA THUNC HAR ISTB C1 HUNKHVI HPK 146. INAMT NGACOK NNA 214. SRTHATARINOH NR CHONG KLAK CHSK I131. |NUCLEARU NNC _11 2JI UIHA THUNC ST? 3.KCHNG; EKRUC -KB| 132 9A |PAK r CUN 21 SH=|2. |THVN-HNKOLUK S TPT IAENC UATEN PS S PKHUNG I& NPO& 1217 2J4 UIHAHNC I STK CHUKPAEN CPAN 1I4 NAM PVNT NlHn|PH 1|2;8 SUA TRANC _ _ | SRT CH. PO CP?TNGK 135. NPANC KHON T PHK 1240. SUORITNA S- I R 5. DOEMANG ALK UAT KBN I115R. NPAMTrHAEUNs | NpN 221.-,,O TAK .CHAHAN 182 I KIfH&2 |KHLNC FAAI_ | LTl NAMO HT KHEUHN 2 HSj NTH2 ||245. TAPER AE PI, | IU_ i.L4 GETRBNGKOK _B|KK Ilag. N6? CAM UAII[ NPB 1226. IUTARADOIT TMO KIIHATN YHAI SAP H A HYIN)IRD1140 MA5-HN NA PO2249 T IECHAKENC I I H IKLANC _S KA HA 11416. IHNARtHONCT NW PD 21250 IXESE MAN HKUAYI HO HHA 11425. NIPHRA Af PHUTTAA NTB .1226 THALAN 1I4. TL I2 IKUAI NGE HNO 11456. IPHRAN _ |A NK 12529: THASTHUN NA TN HUAI PHUKNI HPK 146. INORTH BANKOK No 2.30. THTR PS1 ANSOIISSE P^KN TIIN KABIDN IJR K-B11)- nARC NUHON 2295EPAA