E-235 VOL. 28 500 KV TRANSMISSION SYSTEM PROJECT FOR INDEPENDENT POWER PRODUCERS ELECTRICITY GENERATING AUTHORITY OF THAILAND REPORT NO. 21200-3901 SYSTEM PLANNING DEPARTMENT JANUARY 1996 RIWLUCLW LWMItfl21 CriL1t tLK-:JDLRIKg UL& f-n z %tntp ,6sEr-L 009 DRULODLLk2U I n>D L DLwnLLricWMu3sU:Lf UFW%U-ILU nguBA LrLuL^AAsuLL LWi 009 Ltf[lrLFLLLLU'LWj GP LLUL.tf1 L LWL* uSLUhUILLUUDW%LyWtffL21 bbSZ uDW UI3Gn-1-WWLLIll UGc.-:W LLUSZl'|%RUQlULL*fASUl3 (py19 U!OsSSUgJi L U!ej) ULWULAArRR-:Lt5L)LLUflnflL4 LLUfll nnllUGlLL vsLuLeLu AsuLM CWi 009 LLfRLR;LLLUD!LW ARSRU lKLKl5U lRhUbQ ree Lpvr uLsnneuP LF' l D8WKLUtWD3 SLU%:l (ddl lG3fnPOJd JaMOd lU9pued9pul) tL .U PRU @1 LAl goNNULI LLtI MLRLIL3N I1~~LL W 0 - DULSURgDOL5BAl ltRZUQlLIAlSLIULPiLF-KgIRLRLL tWI 005 LKKIDPRRn-L5LUUDLW[lgNlglDN- LLU2LLtII69Gt13 I L06£-00 LZ AIAZ1nLDrNLLJU .,saonPoJd JaMOd luepuedapul JOJ 1DfOid Wa8SAS UOISSIWSUeJ2 AM 005,, LLUDLW1LLkUQl 3rWL"FIADS ptvl wLnUhLplIUrt nfiLl ngIUG1LLtALULLKltRLL.L4L C-W1 009 L lL'pRrLLLUKWl £'GLl 000 L L RLuttn rU11uL 1::LRlSnXrLzfAL5U r)T i T T/0z L z NU U. 'JL4w & & 2. n a-imuln1 -ih 500 tF lJ U1dIiVAlU 111h SUIAllU1 500 LP1 IIJ6d fll1.Ja4Ud slUTh 4 ld 4 4 WreavRsrdy LLsa li 500/230 LPI! VU11 1,000 MVA 414UTU I ji LVfL4fAl J'1.1ny-J1JA1 230 LFfl J9UTU 3. auJu H-.500 L19 108VU& LYwasullJu1 l rd 500 L) iin ofWf.u-dm-lmu 4-m- 4 ThJ0 4. daVIN9uin'IA- 500 LF fl7i3jIuAU.LLUu Gas Insulated Switchyard (GIS) 1nn iutn'hrJTh 500 LF Inl11UtuqjuU Tpmn fl1 -lluflEJOO 500 LP1 loal41J - lmsaFJ u dsii 2 ld95 LL IiEtfllufldl 500 LW) MAOUd - Tldu'l ld4S1LWU 1 ldM5 (LLUl flluldinflQulvriS fl.1mluti OduLLITI) RdnAmlunIA-1 500 LF5MIIAFdnii-n SAINVAMpt qlJmCU'1A11:1 UU 500 LFI1 OwMSUfl-mfdbJ6U flWmUmdnu'ari unt~ flbLUqdMlOM 1.43fl 5. 5iL'l3 Shunt Reactor 10l1 1 50 MVAr 11U8ftd 1!Jf'i 500 LFil U1dYZT - laJJd 6. ti ULfl{)tEJLJ YL.500 Lf) Ul4f_Wl 7. LL1111LflEfl?Jm n tIn1 ssuE4.-'dolr0- 50o LW) fl u11f l w1 L l?Ifl n zlua~Mn~n nJsaiuiiirul-w i 9W14U 1. d fl MlUfdb 500 ifll ldOR QwlUlU 2 UU1 Cln 1l74.7:LiOd 4 IUd10 LjAN (T Junction) VEJ1AI 500 LR' -nSAw fn - MIdUOU SJUjlild1JSnl1U 1 55 Ula 1 70 2. H81n1"5l El id2 30 LF19 LwUinowd9 wn 0l1W.3!l8 4 IIJI ' 0AiYJ.P-00 2 S_UitidlJS:IJlU 1 0 ATflILUM 3. inltO1YJIn 4i 500 LFi 1U.80 4 R-n'Autntdf 500 LW) 'LdJ!Jd vA.11u4Nmi LLIC lYJ.du81i LLiflzz 2 ldql 1 EAfJIM6QFNIiIMALLL 500/230 LW) WUliJ 1,000 MVA 41UlU 2 t6i Un-oflS d iulnlvJAl 230 Lfll L A¶J'Ul3TfLL¶dfld1U- 2 ldUS UN-altid 230 LE1 ll'JU HJ.1UtJEW 2 4Viwu 2 d5 ULR 9s = ttwbIibR Um I firi1Ug[ILL8QW /1T: UlR ~~~~~~ I~~~~~~~~~W 009 LLff4Aoprlrl: LLUCILW1DL £bSZ nRUfttU n191MLK5n:LRLMlt^LL- LWfWI £bSZ aPUltb 889S aInlwD 9 UL LUlP L NtSLWIW11p'PbLU1 1 LLUKDlOL.ILWETlV -i 0'l- uzt 050 o 689 0SiEL'f hb U KoDut O 09Zt L L 0-086L (Z, LE 0 08Z'£ UGQ :toLWWLL -0 L 6L O-SSL, L (Z-8SZ) O-S9v9 Uwnt:WWLU tnJU1ILA P5LULIL^4A5RLftLi4Lp >M1 oo9LLA4yDFnlflLLLUC'LWI (tULnMtL (ALRnLu) (Lqaafbcum (uunncg) KILL tALnttPl tALflfl A'Kt ULnttLi O-SeL'0O UQUL4LrfttPl'U (6rwofbLbflLI tb-68£ L,41flfraL) ULtLUMI O-S09L'6 flrL LL5fl aIURII LtrLnrLt OLb'O£ MUt2L ULtl-KVlDA UGGflA WWt LLIo1UIInUW.tt^WWLLIfUBG1 iL%LI ULNL4tRLrLKLp 1 009 LPRD^55LUPLWLL EgLWnfLK45 - bt N313i. - 1 OOS 009- LL 2GUGPA1KWtAI3UpWI 9 %IOLPKLU QigVKtt - b' 0002-L LWI 009 Ig1n UGQGflLM - b PQR^5L 1I 009 PFRLR PQR%LMRDUPpRLgRfL4 JVAW 00L 911 08 WL%2 JO13eaj junfS NwvW 9g 'KtttLpN b, 0(3QR.5-L) ULb WIl 083 DFRLORLa5QM1 Z PQRi-- LWI 08Z' FU RLri *b CL 3D& 0 A SD m r c -j .A m 1+ tt 3B O M) tt m 0) W-i M a) UL n ct Du M 3DC C! :90- Co. -j r-q cl rn- 3D 3D "CL tt 30 tt A ML Co- 2 We me CA) do Clit C!) C A m .A cc A & -) A A Mt r- 3D M) A 3D e s m 2! a! m LA CAL :gC em M =0 :SL :s -) d S M MD in r- A - 2 do M M Ln :3 41, e. 91 Ca 3) -.3 t c e- 3D el M m M -3 m 0 e -j 3DC MA m Be ex!,e M C! m r- Ca 3D --j P P W !3 m- 30- e -3 C:! 3D tt M 2 S A m 22 SD Me 2) 10-t J- M- _j m .0- We -j WI A 2!1 tt 0! -A M M W C! :S lo- :s -j -S 2! tc P A ::r_- =3 At 33 39 =D e ci At 3D .4% 3D Me 3: r -jc -I el -j s 2) ct Co M) 2!lL rn Be e. 4. rn 3! 92 M) Z! C& 3D 2! -j 31 X!L. M 30C A -14 -A cm .4 tt do !a e J cc SD 'a W t 2- CP A C) M A M- M C!!- 3D -j -j := j! 2!j e- .--6 M e-0 - e M A 2!- M -3 5 ID M- e- W A = 33 -4q .4-t A -j Ca Ca M et A- M e- do- " -3 CA) M 2! C!) tc W :9 _5 M C. -) e. -j M 4. Ca 2! Me *A O 3D C3 e. CE M Ca to .4 3: -j A Co .AU -j e A A M 3) %A MD 21 tt ft 20 SDC M ;a Ste A :ft M p aN is im ;9 im CP 4v. c- c- CE a :;3 Ml x C- C' M ';Z I 34 ir- za a -X: a ;3 C- ;3 IR c- v- U r, a GO v- V. IP c- C' )C Z r CP CP r- TZ VOC IC% =S IE at, v- c- cr) C v- Is 73:: (rb c- C- r cli CP 04-2 a OF. c- c *! r(,;) :t -IE C- C- C- a rg Ga r r UL. (PI :3 GP F IC. M or. );I Cc -P ;I ) i A .-a ix e- w- ix if r- ;C 63 v 4-u X C' aa C) IP -= -X cr a V, C) -P -0 ;9 ic) 0 CP v- C- 3 -5 i t C' lg I= ;9 I= ar_ c- dom C GC ZE 3 -7 A C r- C- GD v- cr r- CE c- 4 --a m cr. v- =s C' C' C- acs Cp CO =:s at c- oc U') 0-.7 kfl ;C CM p O c- cc C- am im C W. b- r- ;I ;C p *_ ir is v- GO Z C- OC ;:3 3a Go V, )V- a la a P am r- CE -:- C;t 6- 2! X6. r- (IC c- P C;) -15: ai, r U Z ;9 -t C) CV) c- IEC- GO (E C3 rD ac acE 3 rl V, -7 IP Go C- ICZ) as ce) cri C' C- C V;9 C Q a, co It ns S: (;3 - -7 IP cr. cr) rk%) - C- c- C- C) (rL ;3 ES JX cv) &-- c- -v 4- W) -x v-, -7 C- C- C- amp 11- X r- cu r- .7 I., v- cm C- C- 'tLBQULunnlLI LLrL ltnLpLt1 tFt (dQru1UQlLLtt5jUL%LLt RSAL4 CLA I SL L0RRL55t50U0W t giUJTflLm (Ll 6£ZIv ALL 5QW) nUWLtS1ULQL54Lritr5RLY S4L 1 005 1tWLtFrLtU LUtSgj LI ( tLulA LLUL MWni 6i5Z 'Mi-K IALUTrtb L t.iknt 6ESZ/Z Itt5 ML1LL,,ue> LL"t$LsULLULLtti1,q I4W[p1 1 lumnuaL94le R1?'1 2/2539 '1UWM 7 nummuff '.M. 2539 7iflhIIn WwIQtGI LLLU*V@RCWl; 009 LLALUt%L9UK04 (LoUllpQ loottLU a nnLLLLPUISQPSLJI wnn) L&CK t PUIOL&L oQetC - Dnt'g& c i 009 tPFL1111M.- no't a cmUP. se2tLntt - MGntt LU1 005 OFOLOWMLMUS1l faLiDful tLW1 00 L^LAU1nL%UmUvUI (S19) pJuAqOj!MS polWInSUI se8 r1nMt"M9QW %LLUt Wi 009 L*tAtUp1LN0LktQU ' L tv flLtfl% %L?A:,acLI-ftA ULb tW1 009 I3OLtnLOQP1 OWNtt& LWI 009-A OLfiB £ LbQL L t fLbflfUllQNUnL twI O£Z LAltUlnL.RLMRn1t5 (wa t nI ttIC L L U3t. @Jeds :9n 4 £ LfLL VAINJ ECI9O00 NLfl OsOtd OiRuIS Oifl1O 3Mu) l flLflLp VAlW 000' L NlM I1 owtOE:Z/OS P0ftlIGRQUWWttLIA LIL t, flttLp PWKOhb C>QIpj LId OOS PpOLrnLKLt MIA:21PLR LWI 009 L*jAUPtLUCtLLNQU z oj0M punoi9 PeG4JQA0 SL0unt 'Kil I ntnL onldo ajql p¶Wott%K1 nIlLyNL LWStIlglU 08Z 5U1 GLZ mULfLLfQLUL4ISL i,ts10. HSsV 0P111 %LM2l^PLVfAU UL& tMl z MALp PLbso t,1 005 opr3LlILL8jU L nw L KLpEnLU QL1rnU2LP UUlWt.WLH U13ULA\PLULbLL*AtRkILRtL4 1 00r L>4AIDpULR:LLLUP>Ij - C. ~L(I LU~LwIDi3a bW L NrLLU nQ^\nU Q5L 5wbUsqKntLLE LLg -R^5LLIAGULLURIBRI L UUfUOADLLQ,UllLLUPMLLfLpL hhSZ-9£LL S. M. ?% 49I DGZLILILrL1,InMLK LfU[LlfitOgL5pU5QLAUOLUNLDL4%lKILMK PLLn5LU-K-LPY QhUglL4URLwUlgUPriLBnn.LKttolLLU LMtK5LLUtLUSbWLU(I%nBLaiLLUtteSItIn EWLuPagnE> U.LULrLimnnew LLAfAJWLLU %l OIOKLLiKfUQllLWW LUrUSLnILQ(lrLriltLY (ddl) %RUQ1L*QtI0LUL&LAtUIr1fLLUnL Q5Lt41 (Pu9 UOIS9IWSUBJJ. UIie) UUL4L ttpnno 1LU%o%1LyLLU%Q1PR fAUO7LL+tAIL ULrhLLRArLnLR.L ti1 00 L^.1Qf!rU^LLLUOLtlf1t3rIoaLWtLLItLruLp tflURliL~tL'lLqULNE1LRLrtL3 K i1 WI OOW-LtIrR[ LLUn'LW1 L£6 5i *Z'° lb . m .. .i 1qunnicul,IfiV llU 500 Wl t^ 50o L14i -JiuvJ- 7 m.UNfl8fl14J nufltev ua1s.LL iRJuz viu 2 lMVI8WUawim 5. i9P3 Shunt Reactor 4UIm 1 50 MVAr 500 LPi1 U4dflmWl - 1 a1 1d 6. f PI'UA aflW l!flF 4.500 NI U1filU 7. tu"sSdflnnla U.J.-na-UmbemiI4 1 oI411 1. neg-ido 500 LA! i 1-UnU 2 UUl3 lin fli.:1V84 4 IU§UdR LOOu (T Junction) fllUfl4 500 tLil msam4 n - T4uIU l{fle,iiA-rouwim 4xl 272 MCM ACSR iBLVd6 7U:i:wNd:Urlwu 155 LUmi 1 70 AttLuAjm msiauhRL "f8iH Fibre Optic iluw 1 LAtU 'Ubw, Overhead Ground Wire 2. nafidfll44 230 LWI uuuwq-s win 0vW.L7:5 4 iU& 0A.I:i84u 21T 11I'WNl'DUla 4x1272 MCM ACSR aLvtIw 1:aj:Wd1:34ln 10 fltflLU iH-3 Fibre Optic 411U 1 LATUtU4flJ Overhead Ground Wire 3. def(figalub0nWi, 500 L^; 1U:14 4 dLhvi'uflfltd4 500 Li1 'iJd hi1mamedn Um.fls aF-i.1d414uJ UL45: 2 WSqUi Vilstoai flmANTOdM 500/230 LR1 UAli 1,000 MVA lU41U 2 ?iR (nTunI16 Single Phase BUIR 200/267/333 MVA 41U7U a 6 Ufft spare lemn 1 8jm rjHLT4U 7 IN) u:danff'wa-I4l'nhiP1 230 LRn WE81U dM8LInd1u1U 2 24d1S LUMlagIwfda 230 LR1 I'HJUd fl.l:Ui0 2 4ilUlU 2 49S1 4. 111111 Iv.230 Ll IU110N 2 LWlUfillUiE 230 l; vin VflIV.Ll184 4 41Ul4U 2 d4)1- 5. iA.Ii4 Shunt Reactor 1ulP 80 iw: 100 MVAr AJBiflfl4114WOm141TIEUN flinidj 500 LA! 'S.-Sa 4 - nmudmfn Ua: 500 LF 1s:118 4 - i'oirati MiN,u Alu 6. qm nnteIn14LABedu14 flW.500 LFn IZUJ8 4 7. ANL LSJJ OfUlSn tiENd iS-bUlnwjal I l All^4iqw -m-u dil-O-i 500 tf"l )SUUltli dlitlwn1:tlhSfnlRi-ln1a-fil:ThlEwJn ULL :dUY4lUS-1U 30,470 t4'iulm mjn& LUMf-11111JULYP 9,735.0 ElUUIVI (AlUJLYIl 389.4 1411..LLNUMA-1) unCUlul1fAn 20,735.0 tlhUlk Oo LU (l'uuai (lUL-im1ScUS-r,n (ilRuln) (CLUUM) Tm-jgn-rm--uijd4lA1500 091 fl1R01:Th0Ifl 6,455.0 (258.2) 12,755.0 19,210.0 2541 106.0(4.3)3,0082 Q 3,Rg14) 14.835. 0 RllNlSlUt EllNl1lSt8ht7dfilSwUUil0Al500 LA"i dllMiSUib lrJAlqlnlslYlAlLantulss-lvusnu{~JqlflR-wsalr usidu ~vluzwS"ll (ibuUl)mQnMU@lS) 1(fl-ult) (fl#nUuaI) 2539 --157.7 157.7 2540 - -288.3 288.3 2541 106.0 (4.3) 3,008.8 3,114.8 2542 3,928.6 (157.1) 4,817.2 8,745.8 2543 1,977.8 (79.1) 3,863.5 5,841.3 2544 442.6 6ii) 619.5 1/ t 1l4551Q CJ79 127 5 0 1912100 1041ilSiq : 1/ tiM-s-iuanlf9l6lU 1 Mtt71USIA- -= 25 UlIV o N CD O vESC gQX=- a;o O r. Lr ) a: MgCQ- Ln ~ ~ ~ |l U)- C) to W am v,D CI a3F V, C z 3~-;; to r Cxl r a) 03 ! 0: clr ; C- r QX ; = r C; ;; a ;sf GS a X 3 r Q p -tS Q Z C 34 G 33 7 n <_ 4E;; = ~~~~~~~~~~~~~~~~~i D e- tg C 2 C;!~~~~~~C Lr O'; ' =P C- -I cm;C - r LC r- ob ) - a; Ga :;S WC tC N | r r fl u eG C _ ar = | r g O} X _ N n $ CCE U $ ~~~~~~~~~~P t .. ;S t CI <1; -.|7 (M; -4 0 ci 2! !m tt tt St !B cAk. C-4 e. CD crm ci m ct CD M C07 ;:, SL Zs 3D SL tt C! (D 3DI! te -4 e. 30e ML At CL tt C: CD A M at M C* A L L I !9 LIC W M M tt e- i M W W W W SD M C) 3D 3D C! Mt CL --i C! SL d 3D r- -j r- M A F: -It --) M e. Zs 2: C! = 2! m c- CD r- :0 e2 St m .A d- Ca C!! e A St -j SIt C2 C: RD tt M -ISL M- e- r- -6 3D 91 M .V- ;:is 7c -3 CD A :19 A M cc cte CD SL LA C:! 3D 3D. dD ro 'CL M -j S n 3D .-t M .3- so -2 3: ;!. e- ru 38 ctle e. M "'t W A-t 3! me A 30 me -j ;u ml o 3: coo, -j e, rn 2!IL r rf ;-i 0 ;: M 3D CA) Lin :3- M A X, M :0 M A 0 %- 0 -A % ! M CC cc S. Ae LA &a J M -Af :SL J ce V.e sDt, CA) A) A r- M -3 =SL MA, 4. M :3 ro A-k CA -j ---I _j C2 -4 2! (?J A ;!'D 2! j co 2! -) -1 J U) A M M M cl 9! - - fi A- t 0 e M -) r' Fa C!! AQ, m M 2! -Ati C!! A :J! A A Mt R) we .j C! P M ;:i. C! 4 M V 3 mt me W j e G n, -.P c- 0 co Z 0 C- 59 C- C- M C- C- -17. C- C, ar, iS -1p CP fm C q - v- Ca ;3 31 OL- aa a C- 33 L) C- cm ;1 ;;f b- ax -R m c-i rs rg io 3 (E Da r c -t; acm t c- am CZ) CZ Cu C, cc: c C- a CP P G-L a a M C- Z IP C- It- ig U-) C; )Q;t C- 0 OM K C, C- r, GP C", av- C- r 7r. LO M q. P 1c, aa C- o EE M; aa " &-- CL M CM =2 D)M ;I "Z C M cm 1 - . - C)0 62 25 IP C- - M CE C- (E -ov CM N c- 3p :3 C;$ v- C p U IE Z cm -Ur.: 0 ;- aa a a 0 tm ;3 CJI -a cr) C.P 9-1 r- Lr) Dz: :l atA C- a3s: -(- Gr ;C -.;, ;i 0 al CP :z a. Co 0 4- -7 Co am M M lp C C, NX X C- -C ;:3 la ro OLO lip am 43 =2 L.- C C IP U-2 4- tcp C;o U OM C- C C- S: OZ p v- Z -a S'S: Z CP (ij -7 C- gn -p CM C- sz D a - 0 I ar. C- p L- M QM 41;j a 0 ;f M GO m M r.) ;I:: au 0 azz -IF -g -1;;c -C. DI 0- 33 --. ;:3 31 ;M - C- ;o W) am GO SX (M 0 CO ;C )GM 0 Om C- 33 C- zz o a' av- a ;:3 ;3 0 -t;t O- ow- -x -io r. a V- LC) TP S 3: CP a c- io co M ;v r- " C C- C- la C- 0 C, a C- ig c- 5i; 'a ;' " ;' 33 ;:?, 'a 'a 4r- ;t -x' )C- GP 4 a cm- co a a C.- -g SX C C 9-- a a .-7 -;F CM Cs 0 1) C- Z =s st =3 Z V, CL c- U-) (r a r- 0 C -ax: ;1: ;,C ;t e . 0 c- .7 3 a cr) CO C ftF) ;t $: I 0 a. cu 41- C[: GP a - Cs CL v- C- > ar, a;t A; C- a U') I V;., C c- -0.3. a GP 0 -c ',7' cr. a C- c- v- Z am -10 U r- c- CU v- -1;c =2 - r- CP ;C C- CP C -15;: cp V. r, A a )r. v- r, X . ;I C- C- 3X 4-) CY) s: C-' ;r CM ax F =2 W (rL Go ai -x -P NZ 0 11a vX: cm V 1: *E (r, GO W- G) tm v- .7 C- 1E W-a am lip C- C- cr. 43 A agio P :2 )0 P c\j C )4- ;3 ai 5::, a Iv. cm -P LO Ar ix S- (M IV, o(M 3w V- C- IE SZ -CM CM ;3 C- C- - c r- -x C; 20 1A ip zi I-7 V-- C Cr GO C. " r. = -, ;2 %v- LL) c. c- M 14 GO ;3 or.;X -x C- ;C 0 v- GP -M I)r2l -P I VM. a;v C C M cm W) -P r- Mee !Z CIL r-o Cb, dot e. -) -C e m (!!) c m C!! A cn M M e M- 2! C!) A St C!! 39 2! e, C% ce so- e. m m e. 0 D CLO -CIL ei do We (n 41 iv 0) -) c!) do A 2! Re -A C! At 3 C: it --, w o A c' .R -j :Stem -P6 CO ce m 0) 0 MA tt 9 - -) . m m St c! Aft r'o r- -j e cit C! -0 he e- do CA-t "'ca, W Co- 0 z --s _j Ln M) M Ae l< r" 0 so m co 4. m -, C!) :L r .0 (D eJ Ca M St 0 m w--a A -At .4e zste e t Cs MD I!f e. -j r e m m M4 < do LTI me C! e t t :S -j MD 3 re --s 0 R) 0 SD r- :1'. :9- t :C :SL 70 0 Ct r C2 70 (V LTI VID ce JQL 0 -j M 0) 2!e 0 2: a. C!) u AD tD 20 er"- --& it -4 - cc a! cn Lil 0 m- p 0 S -, --t M r- .3f- ;a- we C) At -1 3f 2! .)a -At 0 ge w C:L IM CA) -)a -0 5A D (--4 Co > 0 t A r-e C.) e- 0 le) e -31L C:tf J4 ci CD M -j --tL < -A A ej .4 Ci- M e rA > e. ei; --I -At -j CD r2! Cf -ri W !z Mt C!) o e. C! !D 0 C! 3 0 ja A C' t t C!! CD M. 8) C: ce C! :1) r, LTI .4 CA 0 tt r, !nz M Vlt 0 e. < iio o C! M p M :s CD -) do A w -4t =r M e- C! 0) tt CD r' M r- ct m- ilk fn 0 M w h A_ e C) CL C):3 M C! C! r- M a ZS Ti do 0) 0 G) -j et L U) M -ell -j e. 5D 9= C2 C) C= 0 At w -n a: !n e. :3 e _j tt e 0 LTI M M4 ::S e. 4- - i CD M cl N) e-t 3) -n C_' A CL Ln V, (C o IA tt -j 77 )t --9 , r- r' e. CD p a- R- d) .32 !M e. e. Ae CA e t CD 2!L t C :P- C--2 M, -G M co M% : D e. A c:_ N) mm 0) =3 -t M 3 Ca Mc CD Me A Mc -) c) cc t t rt) 2! M e. 0 4. a 97 5. MIM Shunt Reactor VU'14 1 50 MVAr wJn uJEl IrgMiW ibi, 500 LR1 1U1dfl_WlU - rBUUM 6. 94-NSWnSSdfJf .500 LAI VNIftZWlU 7. LVJ34L1fll?ThN 1. dfl81ISldlU 500 AI' WqIi4 l3UlU 2 LUUl qn 1fl .SjdN 4 M'I Nong Chok/Wang Noi T Junction \UlT0 AU-0 4x1272 MCM ACSR 6M:Nfl S:8uvrw .IhSH1mU 155 ULRZ 170 n-5La4IR' M113 hLuflJ YAfRisi`Id Fibre Optic sluWlU 1 LflUtURJ Overhead Ground Wire 2. datl11EIUJRd 230 LAI LLUUIJIJS -fl4in nflk.1Z 4 1tiJ fti.u-[i 2 1 Rfl IlYJ!Ulw1Ri 4x1 272 MCM ACSR iiiklvJ UZ id:anrii 10 ATfI.4M1 WA iARX Fibre Optic SIUiwU 1 LJ uWUfIl Overhead Ground Wire 3. ndfi f nIl 500 L0i SZUJbd 4 dimSUVIlA4 500 LA9 lIJd -.MUYSOVEn UflNZi fl-W.IL 1VdUJ LLU 2 -NdJ'S IA1J3AdMNALia 500/230 LWfIJ uil11 1,000 MVA 41fU1U 2 JRi (1 ELLIJIM Single Phase ZUl4s 200/267/333 MVA slW)Ul 6 1 LUflv spare lk@n 1 ?J1 7SL;lqU 7 JR) uLLzn:lewho-mnIAr 230 Lfll LIAEIudmA3 lUlS 2 Vd91 UftZliJd4 230 LP1 tiEd fliJ6B 2 4-IUwU 2 IM 4. ai1UJ flW.230 bfIl IveJE 2 tL eSUlJUidi 230 Fil win `1.1ZUBd 4 1UWlU 2 ldlS 5. Wtl Shunt Reactor VIVIR 80 LLU 1 00 MVAr ni11ludndV.rn3'3 tflEidJ 500 Ltfl Su1m 4 - Munadan fLLN 500 LA! -jEal 4 - ildUEUj P11Hfl-10a1 6. S^{E90UtWBiMfl ? SI.500 Lfl F vUEN 4 .i nI e-. t SSi flJS* SC.t 5 ISClCInCV,I OCIfilSSU500 til. .l bfltUnl^RwlURflUb'fl~Jll^R4 QUBBll LtULdjndio30,470 6IU.JUAlUl U flLdUL5U IR101JdIZLYM 9,735.0 PIMIJV1 (t.IJJLrnl 389.4 fl'quLAThLASt-) lw.-CmU-i1Yn 20,735.0 f'llU'UlYI pi*dU TFr54n-lSSw--tudqlA1500 LAI fl1R14i1fl 6,455.0 (258.2) 12,755.0 19,210.0 SlUtd"U 9 2735-0 (,3R9.4) ZO-735.0 SM470, fl1:~~~~U88fl 3.Z8Q.t'O I F (t34IJit%mii L9 0. Fi1.Z6.Q. ~Jfl52eLT1flJ LdUR JtEJUJ'eLfJ'J LdUy I JJJ*Sl 2539 157.7 157.7 2540 - 288.3 288.3 2541 106.0 (4.3) 3,008.8 3,114.8 2542 3,928.6 (157.1) 4,817.2 8,745.8 2543 1,977.8 (79.1) 3,863.5 5,841.3 2544 4A42. (17.7) 6192.5 ,0621 S111 1 t 950l2fl51J2J¶ 1715f.W1 25 u 1 91Q0 'A311lUlA 1/ ItTgrs-lutnoi'aiu 1 LnsuSqlms'5Jn 25 UlnA LO~~~ ~~ r;- tn LOi c- t-~ GM cCh S: - O N s a {z r ~~~~~~g C p C- $ 3 u8)) Uz Ua) t n la a cBG......=;Px; o r9 ,,7 r t G < "t br s _r' Nt N lrN=s r ;jX vm i M ;,t iG ttr-2 cf- :s co 0 A .0 'k et e C*k- 1+ 1-i 0) 3DQ, C!) 3 CrQ M W CIL C) ct C.0 C! r-q M :s -eL 3D L2 CD 3$j C) et te me sDe -411 C2 z At A a) r- M OL me Li r -3 M 2! M A -J r, L L C! ct C9 -J 3D a 2", n 4. A CD - A -.) et e M 33 CD Clt -V 3D C! M e C V 0 C* 9= -J M, C!- -J Me 1E M A A CD Zs r- Cn M -1 9 em .A -C M :s c2 mr, C! M 22 3"Ie m r, !2)D -J Sle e r, 0 -J M et := CD 71- r- M A -J cl A ceg-e ro 0) a 9 -C So 9- cc :1. .1 CD UA F -1 --) Al --a e C! MD CIL e- cmtt -n ct SD 2.1 'r- - cite e- Co s= Aq Ak M St C) rD C! I  -1 1-1 e. r 4. r- M 2!L r r .A - M tt M 11 c!) MD -7j C. 'Z :0 9LM A A C: M A M M CD .J C!) &A C: M- M cc e cc M !2L 2o e) rae he La Al Lo -J e -3 I A _-a -:5 we 0 e- M M A ML M l) --i _J te 0 CA) 3) C* MD M Ak -J -J cc co 2! A M iiD A M A we M M M -4 o cm J co a - A A Al -J M e- e C!! O M 3 A A U) L Mt Mt So. 0 C! :3 r- M M se 500 KV TRANSMISSION SYSTEM PROJECT FOR INDEPENDENT POWER PRODUCERS REPOR'I NO. 21200-3901 JANU]ARY 1996 Prepared By: Concurred By: Transmission System Planning Divisionviston____i_' __ (Prakob Dhienhirunya) Assistant Director, System Planning Department Submitted By: Approved By: ~ (Prutichai Chonglertvanichkul) (Koomchoak Biyaem) Chief, Transmission System Director, System Planning Department Planning Division ABBREVIATIONS ACSR - Aluminum Conductor Steel Reinforced ADB - Asian Development Bank BVI - Black & Veatch International Company B/C - Benefit/Cost Ratio cct-kn - Circuit-Kilometer DC/ST - Double Circuit/Steel Tower DR - Discount Rate EDR - Equalized Discount Rate EGAT - Electricity Generating Authority of Thailand EHV - Extra High Voltage F.C. - Foreign Currency GIS - Gas Insulated Switchgear HVAC - High Voltage Altemating Current HVDC - High Voltage Direct Current IBRD - International Bank for Reconstruction and Development IDC - Interest During Construction IPP - Independent Power Producer 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 NPV - Net Present Value OECF - The Overseas Economic Coorporation Fund PDP - Power Development Plan PEA - Provincial Electricity Authority SPP - Small Power Producer TDRI - Thailand Development Research Institute THIB - Thai Baht TLFS - Thailand Load Forecast Subcommittee USD - US Dollar VAT - Value Added Tax W/O - Without TABLE OF CONTENTS Page 1. INTRODUCTION I 2. SUMMARY AND RECOMMENDATIONS 3 3. LOAD FORECAST AND POWER DEVELOPMENT PLAN 6 4. 500 KV TRANSMISSION SYSTEM PROJECT FOR 10 INDEPENDENT POWER PRODUCERS (IPPs) 4.1 500 kV Transmission System in the Western Area 11 4.2 500 kV Transmission System in the Eastern Area 12 4.3 Cost Estimate 13 44 Avn ndi$iirp qrChede 14 4.5 Implementation Schedule 15 5. POWER SYSTEM STUDIES 31 6. ECONOMIC ANALYSIS 39 7. FINANCLAL JUSTIFICATION OF THE PROJECT 50 8. SHUNT REACTOR SIZING 61 REFERENCES 70 APPENDIXES 1. Substation Load Forecast 71 2. Power Flow Diagrams 81 3. Dynamic Stability Curves 119 4. Fault Flow Diagrams 205 5. Full Name and Abbreviation of Substation 211 V~~~~~~ ~ ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ - 1 0 = = - 0 . Et * ( I . ~~~~~~~~. . 4-:. -i........... AW1 t t ~ ~ ~ ~ ~ ~ 1. INTRODUCQ IN The electric power consumption in Thailand has increased very rapidly. The average growth rates of peak demand recorded in the last five years were at two digits, and the continuously rapid increase is foreseen in the latest load forecast. A huge investment program is required for EGAT, who is responsible for the provision of the sufficient and reliable electricity generation, and also to build the necessary new power plants and transmission system facilities to meet the growing demand. EGAT so far has successfully managed in the financing programme, mainly on the international capital market and from official sources, such as export credits, IBRD, ADB and OECF. The rapidly increasing volume of capital investment and loans from the international market for EGAT alone has exceeded the national foreign borrowing ceiling imposed by the Government. The Government also has the policy on the privatization of power supply industry to increase the competitiveness in electricity business, as well as to increase the efficiency and to reduoe the investment in the public sector. In September 1992, the cabinet approved a directive, the Four-Step Plan, for the Thai Power Utilities to perform and restructure their organizations in response to the privatization policy. The Four-Step Plan has included three forms of private participation in the power sector: (i) Subsidiary companies, (ii) Small Power Producers (SPPs), and (3) Independent Power Producers (IPPs). In the third step of the Four-Step Plan, the activities involving EGAT for the implementation in Fiscal Year 1995 includes the invitation announcement to the private sector to participate in the build-own-operate (BOO) scheme of the power plants which are scheduled for the commission during 1996-2002 as IPPs. The current EGAT long term Power Development Plan (PDP 95-01) has included a total power purchase from IPP up to the year 2011 of about 13,100 MW, representing 30 % of the total installed capacity. In the 7th NESDP, the power purchase from IPP totalling 4,100 MW has been proposed, of which the first stage of 1,300 MW is scheduled for commissioning during 1998-2000 and the second stage of 2,800 MW will be commissioned during 2001-2002. The first solicitation to purchase electricity from IPPs of -1 - 4,100 MW was announced on 15 December 1994, and there were more than 30 investor groups submitting their 50 proposals on the bid openning day, 30 June 1995. To facilitate the private sector investment in IPP projects, EGAT will construct two 500 kV transmission lines along the Gulf of Thailand from Bang Saphan (Prachuap Khiri Khan Province) to Sai Noi and Wang Noi on the westem coast and from Rayong to Nong Chok and Wang Noi on the eastern coast. These 500 kV lines will receive the power from IPPs' power plants and transmit most of the generated power to the load centers which are at Greater Bangkok and the surrounding areas. This report presents the scope of work, tentative construction schedule, cost estimate and expenditure schedule of the proposed 500 kV Transmission System Project for Independent Power Producers. The results of the power system study to ensure the satisfactory system operation are also included. -2- 2. SUMMARY AND RECOMMENDATIONS 2.1 Resulting from the Government's privatization policy, Four-Step Plan has been issued under the Cabinet's resolution on 12 September 1992 to direct the Thai power utilities to restructure their organization to be as the business-like operation organizations, and eventually convert themselves, parts or whole, from the state power utilities into public limited companies. The Four-Step Plan has also included the promotion of private sector participation in the investment of power generation in the form of Independent Power Producers (IPPs). 2.2 According to EGAT's Power Development Plan (PDP 95-01), during the 7th Nation Plan, EGAT has given a total capacity of 4,100 MW power plant projects to the private sector as the IPPs through the competitive bidding process. The first solicitation was announced on 15 December 1995 to purchase electricity from IPPs for the first stage of 1,300 MW which will be completed within 1998-2000, and the second stage of 2,800 MW to be in operation in 2001 and 2002. Another capacity of 4,000 MW IPPs are expected to be solicited during ihe oth National Plani. 2.3 The preferable sites of the large IPP projects will be in the areas of Westem and Eastem Seaboard. To facilitate the connection of IPPs with the national network, the EHV transmission trunk lines along the Gulf of Thailand are required. 2.4 The study on the long-tern transmission development in the western area had been previously carried out by the engineering services of Black & Veatch International (BVI) in association with Power Technologies Inc. (PTI). The main objective of the study was to determine the transmission system for interconnection of 10,000 MW thermal power plants near Bang Saphan in Upper Southern Thailand with Greater Bangkok through year 2008. The study report titled "Feasibility Study for Transmission System Development for Southern Power Plant Project" was completed in March 1994. The study has examined the feasibility of using three basic systems, they are 500 kV HVAC, 765 kV HVAC and +500 kV HVDC, and the 500 kV HVAC is recommended. -3- 2.5 Based on the BVI/PTI studies, 500 kV transmission lines along the Gulf of Thailand from Bang Saphan to Sai Noi/Wang Noi on the west coast and the others from Rayong to Nong Chok/Wang Noi on the east coast are planned to accommodate the power plant projects for the total capacitv of about 10,000 MW in each area. 2.6 Part of the new 500 kV transmission system in the western area will be implemented for the Ratchaburi Power Plant Project which has been planned for a combined capacity of 4,600 MW (1,800 MW combined cycle and 2,800 MW oil/gas fired thermal power plants) to utilize the natural gas from Myanmar. Therefore the additional 500 kV transmission system to accommodate the planned IPP projects will consist of two double- circuit 500 kV lines from Bang Saphan to Chom Bung or Ratchaburi 3 Substation, which will be a new 500 kV substation to be constructed for Ratchaburi power plant, and the maximum transfer capability to accommodate the new IPP power plants will be about 5,800 MW. 2.7 The development of the eastern 500 kV transmission lines consists of a double circuit 500 kV line from Rayong 4 to Nong Chok and a double circuit 500 kV line from Rayong 4 to Wang Noi. The lines can accommodate the maximum power transfer of about *8,800 MW. 2.8 The total estimated cost for the 500 kV Transmission System Project for IPPs based on 1995 price level is THB 30,470.0 million, comprising the foreign currency requirement of THB 9,735.0 million (USD equivalent 389.4 million )1f and local currency portion of THB 20,735.0 million. The estimated cost of the project which consists of two parts : (i) the western 500 kV transmission lines, and (ii) the eastern 500 kV transmission lines, can be summarized as follows: Foreign Currency Local Currency Total (MTHB) (MTHB) !MT£B) The western 500 kV lines 6,455.0 12,755.0 19,210.0 The eastern 500 kV lines .280.0 7Q980 11,260.0 Total 97470 0 Note : 1/ 1USD =25 THB -4- 2.9 The proposed in-service date of this 500 kV transmission system for IPP Project is Setember 2000. 2.10 The 500 kV transmission systems for IPPs on the west and east coast are proved to be the least cost alternative to transmit bulk power from those IPPs to EGATs load centers. The net present value at 10 % real discount.rate when compared to the 765 kV transmission system altematives are THB 1,719.3 million and THB 3,754.8 million for west and east coast respectively. 2.11 The economnic internal rate of return (EIRR) of the project was conducted by comparing the project cost with its benefit which was calculated by using two approaches, they were the outage cost reduction and the revenue made available from the incremental energy sale. The EIRR of the two approaches are as follows: - For Approach I 107.01% - For Approach 2 = 22.63% 2.12 The financial internal rate of return (FIRR) calculated based on the revenue from the incremental energy sale is 22.23 %. -5- 3. LOAD FORECAST AND POWER DEVELOPMENT PLAN 3.1 Load Forecast The peak, gneration of EGCAT svytem was recorded at 12,267.90 MW on May 26, 1995. The latest load forecast prepared by the Thailand Load Forecast Subcommittee (TLFS)V issued in June 1994 (Revision of June 1993 Forecast) has indicated that the peak generation requirement would increase to 13,009 MW by the end of 1996. The peak generation would be 19,029 MW in 2001; 25,371 MW in 2006; and 33,532 MW in 2011. This forecast represents an average annual growth rate of 10.09 % during the 7th NESDP (1992-1996). The growth rates are expected to decline to 7.90 %, 5.92 % and 5.74 % in the periods of 8th NESDP (1997-2001), 9th NESDP (2002-2006) and 10th NESDP (2007- 2011) respectively. The 1994 TLFS Load Forecast for the total EGAT generation requirement is shown in Table 3.1. 3.2 Power DeveloDment Plan The latest PDP (PDP 95-01) has been prepared under the rapid changing situations due to the uncontrollable incidents and the Govemment Policy on the power supply industry in Thailand. The uncontrollable incidents were such as: (i) the shortage of water inflow in the existing dan reservoirs; (ii) the obstacles to implement several projects previously proposed due to lack of the public acceptance on hydroelectric projects, and the environmental problems on the new proposed coal/lignite-fired power plant sites at Ao Phai and Lampang; and (iii) the changes in natural gas supply situations due to the unconfirmed status on gas supply from Malaysia, while the imported gas from Myanmar Note: I/ The Thailand Load Forecast Subcommittee is a subcommittee of the National Energy Policy Formulation Committee. The group is made up of representatives from NEPO, EGAT, PEA and MEA. Outside consultants from TDRI, Monenco Consultants Ltd. of Canada, Bugach Associated Ltd. of Canada, and Dr.Tienchai Chongpeerapien of BERA Ltd. Thailand, had assisted the Subcommittee to prepared the 1993 Load Forecast. -6- was under negotiationsi. The Government policy on the power suppiy industry in Thailarid has been set forth to cover: (i) the purchase of electricity from Independent Power Producers (IPPs) under the aggressive program on the private sector participation in power generation, as well as the purchase of electricity from neighboring Lao PDR, and (ii) the improvement of power supply reliability to cope with the growing economy of the country. The new Power Development Plan (PDP 95-01) has been formulated based on the following updated information: (i) reducing the dependable capacity of the five existing hydro power plants by a total of 600 MW., (ii) indefinitely postponing Kaeng Krung and Mae Lama Luang hydroelectric, Lampang lignite-fired and Ao Phai coal-fired power plant projects; (iii) increasing the power generation reserve margin from the current 15 % to 25 % from the year 2001 onwards; and (iv) delaying the retirement dates of some existing power plants. The PDP 95-01 comprises power generation and transmission projects which have been approved and committed for construction; and it is also supplemented with several projects including the purchased power from IPPs which is planned to provide sufficient, and reliable power supply at reasonable prices. Table 3.2 shows the list of projects in PDP 95-01 (Recommended Plan). Note 1/ Negotiation on the purchasing of natural gas from Myanmar's Yadana field has been concluded on 9 September 1994. -7- Table 3.1 Total EGAT Generation Requirement (1994 TLFS Forecast) Peak Generation Energy Generation Load Fiscal Increase increase Facto Year MW GWh % ___________ MW _____ GWh % Actual 1984 3,547.30 343.00 10.70 21.066.44 2,000.14 10.49 67.79 1985 3,878.40 331.10 9.33 23,356.57 2,290.13 10.87 68.75 1 986 4,180.90 302.50 7.80 24,779.53 1,422.96 6.09 67.66 1987 4,733.90 553.00 13.23 28,193.16 3,413.63 13.78 67.99 1988 5,444.00 710.10 15.00 31.996.94 3,803.78 13.49 67.09 1989 6,232.70 788.70 14.49 36.457.09 4,460.16 13.94 66.77 1990 7,093.70 861.00 13.81 43.188.79 6,731.69 18.46 69.50 1991 8,045.00 951.30 13.41 49,225.03 6,036.25 13.98 69.85 1992 8,876.9(J 831.90 10. 34 5o,006.44 6, 7°1 .41 13.78 72.02 1993 9,730.00 853.10 9.61 62,17',;73 6.173.29 11.02 72.95 1994 10,708.80 978.80 10.06 69,651.14 7,471.41 12.02 74.25 Average Growth 1985-1994 - 716.15 11.68 4,858.47 12.70 - Forecast 1995 11,880.00 1,171.20 10.94 78,023.00 8,37i.86 12.02 74.97 1996 13,009.00 1, 129.00 9.50 85,571.00 7,548.00 9.67 75.09 1997 14,193.00 1,184.00 9.10 92,879.00 7,308.00 8.54 74.70 1998 15,315.00 1,122.00 7.91 100,383.00 7,504.00 8.08 74.82 1999 16,446.00 1,131.00 7.38 108,160.00 7,777.00 7.75 75.08 2000 17,685.00 1,239.00 7.53 116,795.00 8,635.00 7.98 75.39 2001 19,029.00 1,344.00 7.60 126,025.00 9,230.00 7.90 75.60 2002 20,237.00 1,208.00 6.35 134,041.00 8,016.00 6.36 75.61 2003 21,440.00 1,203.00 5.94 142,849.00 8,808.00 6.57 76.06 2004 22,690.00 1,250.00 5.83 152,529.00 9,680.00 6.78 76.74 2005 23,997.00 1,307.00 5.76 162,187.00 9,658.00 6.33 77.15 2006 1 25,371.00 1,374.00 5.73 1 171,745.00 9,558.00 5.89 77.28 2007 26,835.00 1,464.00 5.77 181,745.00 10,000.00 5.82 77.31 2008 28,409.00 1,574.00 5.87 193,505.00 11,760.00 6.47 77.76 2009 30,044.00 1,635.00 5.76 204,956.00 11,451.00 5.92 77.88 2010 31,749.00 1,705.00 5.68 216,428.00 11,472.00 5.60 77.82 2011 1 33,532.00 1,783.00 5.62 228,445.00 12,017.00 5.55 77.77 Average Growth | 1982-1986 - 318.44 10.06 - 1,763.91 9.20 - 1987-1991 - 772.82 13.99 - 4,889.10 14.71 1992-1996 - 992.80 10.09 - 7,269.19 11.69 - 1997-2001 - 1,204.00 7.90 - 8,090.80 8.05 - 2002-2006 - 1,268.40 5.92 j - 9,144.00 6.39 - 2007-2011 - 1,632.20 , 5.741 - j 11,340.00 5.871 - -8-- Table 3.2 List of Projects in the Recommended PDP(1995-2011) Power Plant Fuel Lid Rting TOtWl Colum _nll TM-e rNober fSn amW pot Yhafom CC I (Sa) - 1 226 226 Febuary 1995 8SHldt Hydro 4 125 125 March 1995 Mae Mob IgpiuM 12 300 300 May 1995 Nons ChokGm Turbine DIesd 1-4 122 413 May95 - Aug 1995 SolNolGm Turlbie DBei 1-2 122 244 May95 - Jun 1995 Me Meob Linle 13 300 300 November Im Rhbu o P ped-tue Hyro 8 168 163 December 1995 WIg Nd CCI (GT) Gm 1-2 223 446 Mar96 - May 1996 Wang Nd CC2 (GI) Go 1-2 223 446 Jul g6 - Aug 1996 South BagOkCC2 (GI) Gm 1-2 202 404 Oct 96 - Nov 1996 EGAT-TNB Stage U Intereomectku - 300 300 Apra 1997 Wa No CCI (8T) - 1 205 205 AprO 1997 Wan Nd CC2 (S) - 1 205 205 Jul 1997 SOuth Bang_kCC2(ST) - 1 219 219 August 1997 Lanm Taoug Puped-Storag Hydro 1-2 250 50o Febraq 2000 Wag NoICCStoge2(GI) Ga 1-2 200 400 Nov 97 - Dec 1997 Purchased Power - 300 300 Januay 199S Ratehabai CCI (Gl) Gm 1-2 200 400 Jul93 - Aug 19f Ratchhubi CC2 (CG) Gm 1-2 200 400 Sep 98 - Oc 199 Wuag NeiCCSbtge2(ST) - 1 200 200 November 1993 Ratdaburl CC3 (G) Gm 1-2 200 400 Nov 98 - Dec 199f PurchJed Power - - 300 300 Janua 1999 Ratckabud Therall Ol/Ca 1 700 700 Apr1 19f Rakdabul CCl (51) 1 200 200 July 19g9 RatchaburThermal OIWm 2 700 700 Aug" 1999 asaui cm (SI) 1 200 200 Septmber 1999 Puarcased Power - 300 300 Ociober 2q99 Rathburd CO (ST) - I 200 200 November 1999 Purhad Power - 400 400 Jaur 2000 Krbl/SuraTh"iTberd Oil/Gs 1 300 300 J-nuy 2000 Rathahr TherFa OilGs 3 700 700 October 2000 Ratcdabud Thead OWGl/ 4 700 700 Februay 2001 Purduaed Poer - 1400 1400 AprO 2001 Southem Reoo Therma OiGa 1 300 300 March 2002 Purchaed Power - 1400 1400 Aprl 2002 Purched Power - 1000 1000 J qur 2003 Lh- Tahug Pumped-Ste Hydro 3-4 250 500 Apri 2003 P-raedt Power - 1000 1000 Jana 2004 Southern Reglon Thermal OlGas. 2 300 300 January 2004 Chulabhon Pumped-Stope Hydro 1-2 200 400 April 2004 Purchased Power - 1000 1000 Jaury 2005 NewTmbnua Co- 1 1000 1000 Apr41 2005 Purchsed Power - 1000 1000 Januy 2006 New Thernml Coal 2 1000 1000 Apri 2006 Purchased Power - 1000 1000 Janua 2007 Southen Regio Therml OilG 3 300 300 Jaury 2007 New Theral C-ol 3 1000 1000 Aprg 2007 Purchased Power - 1000 1000 Janua 2008 Chuabborn Puped-Storae Hydro 3-4 200 400 JaUa1ry 2008 Khlldhn Pmped-Storage Hydro 1-2 200 400 March 2006 New Thermal C-I 4 1000 im Apri 2008 Purhaed Power - 1000 1000 Jaur 2009 Southe Reago ThalD OlGa 4 300 300 Jauay 2009 New Thermrl C-I 5 1000 1000 Apri 2009 PUrsed Power - 1000 1000 Janury 2010 New Thead OilGs I 1000 1000 Apr4 2010 New Pearg GT DWel 1-3 100 300 Apd 2010 Purchased PFer - 1000 1000 Jary 2011 Sou8her RePmgi Termal OIGU 5 300 300 JanUa 2011 New Then_I OLGas 2 1000 1000 April 2011 Easin Caft by Septm r 1994 - 12911.9 MW TObl Added Capd (Up to 2011) 33,6760 MW l R ioAn-u- 2.747.1 MW TOW Capait by Yer 2011 - U|23MW -9- 4. 500 KV TRANSMISSION SYSTEM PROJECT FOR INDEPENDENT POWER PRODUCERS (IPPs) In June 1993, EGAT entered into a contract with Black & Veatch International Company (BVI) who was engaged in association with Power Technologies, Inc. (PTI), to undertake the feasibility study for Transmission System Development for Southern Power Plant Projects where all power plants were assumed to be located near Bang Saphan in Prachaup Khiri Khan province. The purpose of the study is to determine the most appropriate transmission system requirement to transmit 10,000 MW of power from new power plants to the Greater Bangkok Area. The study which was completed in March 1994, recommended that 500 kV system is the preferred transmission system based on the technical and economical justification. The proposed 500 kV system would be consisting of thrree double-circuit lines from Bang Saphan to an intermediate substation assumed to be located at Chom Bung district in Ratchaburi province. From this intermediate substation, the 500 kV lines are further extended to link with the 500 kV system in Greater Bangkok Area with one double circuit line termninating at Sai Noi Substation, and another double circuit line terminating at Wang Noi Substation. The study also recommended that in case of the difficulty to obtain the right-of-way for the third 500 kV double circuit line from Bang Saphan to the intermediate substation, the installation of series compensators on the first two 500 kV double circuit lines between Bang Saphan and intermediate substation was considered as an alternative. The transmission plan recommended in the BVI/PTI Study Report is actually the main power transmission trunk line to facilitate the connection of the IPP projects in western areato the EGAT system. Based on PDP 95-01, the 500 kV transmission plan for the power plant projects in the western area has been reviewed and the transmission system studies have been extended to cover the transmission systemn requirement for the power plant projects to be developed in the eastern area using the same approach and methodology of BVI/PTI study. Based on the results of the reviewed study, the 500 kV Transmission System Project for Independent Power Frouuceis -which have been divided in.to wo parts, arg a follows; -10- 4.1 500 kV Transmission System in the Western Area (a) Construction of two routes of the 500 kV double circuit line from Bang Saphan to Chom Bung (a new 500 kV substation to be constructed for Ratchaburi Power Plant Project), using 4xl272 MCM ACSR conductors per phase. The distance of the two line routes are approximately 275 km and 280 km respectively. One overhead ground wire with optical fibre would be provided. (b) Construction of a 50C) kV Bang Saphan Substation to accommodate four 500 kV outgoing lines to Chom Bung and one 500/230 kV interbus transformer rated 600/800/1000 MVA (consisting of four single-phase units, inclusive of one spare unit, each rated 200/267/333 MVA). The existing 230 kV substation will be expanded to provide space for the interbus transformer bank. (c) Expansion of the 500 kV Chom Bung Substation to accommodate four incoming lines trom Bang Saphan Substation (d) Since the capacity of the 500 kV equipments of GIS substation at Sai Noi can cazry the current up to about 3,000 ampere which is not sufficient to carry the additional power from the West Coast IPP, so that it is necessary to construct a new 500 kV GIS switchyard located next to the existing 500 kV GIS switchyard at Sai Noi Substation. The double circuit 500 kV Chom Bung - Sai Noi line and one circuit of the 500 kV double- circuit Chom Bung - Wang Noi line (to be constructed for Ratchaburi Power Plant Project) will be sectionalized and they will be connected together at the new 500 kV GIS switchyard at Sai Noi. The new switchyard will also provide four line bays for the future lines to Bangkok Noi and Chaeng Watthana Substations. (e) Installation of line shunt reactors rated 150 MVAr at both ends of the 500 kV Bang Saphan - Chom Bung lines. (f) Land procurement for the 500 kV Bang Saphan Substation. (g) Addition of communication system. -11 - 4.2 500 kV Transmission System in the Eastern Area (a) Construction of two routes of 500 kV double circuit transmission line, using 4x1272 MCM ACSR per phase, approximately 155 and 170 km for the the first and second line routes respectively, from the proposed new 500 kV Rayong 4 Substation to interconnect with the 500 kV Sai Noi (Wang Noi) - Nong Chok transmission line (T Junction). At T Junction, one of the two lines of the 500 kV double circuit Wang Noi - Nong Chok transmission line will be sectionalized and reconnected such that one 500 kV double-circuit linr 4rrni; Rayong 4 Substation will be terminated at Wang Noi Substation and the other line will be terminated at Nong Chok Substation. One overhead ground wire with optical fibre will be eg .pped. (b) Construction of a 230 kV double circuit Rayong 4 - Rayong 2 line, double circuit on steel tower, using 4x1272 MCM ACSR conductors per phase, for a distance of approximately 10 km. (c) Construction of a 500/230 kV Rayong 4 Substation. The 500 kV switchyard will be provided for the four 500 kV outgoing lines to Wang Noi and Nong Chok Substations, and two 500/230 kV interbus transformers, each rated 600/800/1,000 MVA (consisting of seven single-phase units inclusive of one spare unit, each rated 200/267/333 MVA). The 230 kV switchyard will be provided for the interbus transformers, and two 230 kV outgoing lines to Rayong 2 Substation. (d) Expansion of the 230 kV Rayong 2 Substation for two incoming lines from the Rayong 4 Substation. (e) Installation of line shunt reactors rated 80 and 100 MVAr at both ends of the 500 kV Rayong 4 - Nong Chok and the Rayong 4 - Wang Noi lines respectively. (f) Land procurement for the 500 kV Rayong 4 Substation. (g) Addition of communication system. -12- Figure 4.1-4.2 show the locations and preliminary line routes of the proposed 500 kV transmission systems in the Western and Eastern Areas respectively Figures 4.3-4.4 illustrate the single-line diagramn of the proposed 500 kV transmission systems in the Western and Eastem Areas respectively. 4.3 Cost Estimate The cost estimate of the 500 kV Transmission System Project for IPPs is based on the EGAT standard design, including engineering and supervision, physical contingencies, escalation, import duties, interest during construction and value added tax (VAT) at the 1995 price. The escalation factors for the foreign currency portion and local currency portion are as follows: Escalation Factor (% Change)" Fiscal Year F.C. Portion 2' L.C. Portion 3/ 1996 1.79 4.00 1997 2.59 40Q 1998 2.52 4.00 1999 2.46 4.00 2000 2.48 4.00 The cost estimate of the 500 kV Transmission System Project for IPPs is shown in Table 4.1. The estimated cost of the project which consists of two parts: (i) 500 kV system in the Western Area, and (ii) 500 kV system in the Eastern Area, are summarized below: Notes: 1/ Per annum growth rate from previous year. 2/ G-5 MUV index from the World Bank Quarterly Report on Commodity Markets and the Developing Countries, January 1995. 3/ Local Consumer Price Index estimated by NESDB and Bank of Thailand, 1994. -13- Description Foreign Currency Local Currency Total (MTHB) (USD.Million)" (MTHB) (MTHB) (i) 500 kV system in the Western area 6,4JJ0 (2582) 12,755. ,210 0 (ii) 500 kV system in the Eastem area 3.280 0 (131.2) 7.980 0 11.260.0 Total 9.75. (38,4 2Q10 3.Q 4.4 Expenditure Schedule The expenditure schedule of the 500 kV Transmission System Project for IPP is shown in Table 4.2. The annual disbursements are summarized as follows: EXPENDITURE SCHEDULE OF 500 KV TRANSMISSION SYSTEM PROJECT FOR INDEPENDENT POWER PRODUCERS IN WESTERN AREA Fiscal Year Foreign Currency Local Currency Total (MT__B) (USD.MiIlionV' 0MDII) (MTHB) 1996 - - 157.7 157.7 1997 - - 288.3 288.3 1998 106.0 (4.3) 3,008.8 3,114.8 1999 3,928.6 (157.1) 4,817.2 8,745.8 2000 1,977.8 (79.1) 3,863.5 5,841.3 2001 442.6 (17.7) 619.5 1.062.1 Total 6, 455.0 1 2.58.2 1221Q Note : 1/ Rate of exchange 1 USD = 25.0 THB. -14- EXPENDITURE SCHEDULE OF 500 KV TRANSMISSION SYSTEM PROJECT FOR INDEPENDENT POWER PRODUCERS IN EASTERN AREA Fiscal Year Foreign Currency Local Currency Total (MTHB) (IJSD.Million" (MTBB) (MTHB) 1996 - - 253.0 253.0 1997 - - 175.2 175.2 1998 62.5 (2.5) 1,795.1 1,857.6 1999 2,077.5 (83.1) 2,974.1 5,051.6 2000 934.4 (37.4) 2,390.7 3,325.1 2001 205.6 (8.2) 391.9 597.5 Total 3,280.0 71.l260.0 4.5 implementation Schedule The proposed implementation schedule of the transmission system expansion for the Western and Eastern Areas are shown in Tables 4.3 and 4.4. The expected commissioning date is ae2tember 2000. Note I/ Rate of exchange 1 USD 25.0 THB. -15- AI~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ -4 IL~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ 1~~~~~~~~~~~~~~~~~~~~~~~~~~~~T1 z-- ~ ~ ~ ~ ~ ~ ~ ~ r- '~~~ *, --- I--~, O F f G~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~- ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ - t t ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ". Figre4 ___Pelmiar LieRueof50k rnsiso yse nteWetkiAe fi~~~~~ ~ ;. C'-( -, Y o Z Wf :- - A XSUSSTA | G I K F ) A I 1 A 1) "X t I. . . . . ) . . . . . . . . -"~~~~~~~~~~~~~~~~~~~~~~ '- iz ''I &e 1 1, A N IV~~~~~~~~~~~~~~~~~~~~~~~~~ ; ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ ~~~~~~~~~~~ . ... .. 0~~~~~~~~~~~~~~~~~~ PRAC4IIIJ BURl U 0~ ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ STATIONIO SUBSTATION ~~ >~~2 ~ :;4...T 0mn~ ~~~~~~~ ~~~~~~4\~~~~~~K1U~~~~~~~ 7.J~~~~~~r4_K BANG LAMUN~~~B as~ I . . uX e g~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~g _i - . ,,VIL a°~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ I '~~~~~~~~~~~~~ - - _ Lt~~~~~~~~~- 0N <>, _~~ 1' F 's w_ - S ." L_ S~~~I . _A's w > 1* T, .~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ I JLA.L~iII,- - -- .W Wo no k klnv n: .4 .- .-~~~~~~~~~~~5/WVPY ~TO mxv RAYONG 2 ~TOOH4KR00 U4*~ _a,Xa, rx F~~~~~~~i C r dr = 599 Y> | | iS . . -> ., ELECTRICITY GENERATING AUTHORITY OF THAILAN .'4"""""' - w _____ _ SI LIN D t~~~ ~~~~~~~~~~~~~~~~ -g 3IGL LI&4_ NcBE DIAGRAJ I I I Table 4.1 Cost Estimate of 500 kV Transmission System Project for IPPs F.C. L.C. Total (MTHB) (MTHB) (MTRIB) IN WESTERN AREA TRANSMISSION LINE 1. 500 kV Bang Saphan - Chom Bung I st Line Route (4xI272 MCM ACSR, DC/ST, 275 km, Including Optical Fibre with Overhead Ground Wire) 1,361.1 3,250.5 4,611.6 2. 500 kV Bang Saphan - Chom Bung 2nd Line Route (4x1272 MCM ACSR, DC/ST, 280 km) 1,293.4 3,294.0 4,587.4 Subtotal 2,654.5 6,544.5 9,199.0 SUBSTATION 3. 500/230 kV Bang Saphan Substation Expansion 632.0 298.1 930.1 4. 500 kV Chom Bung Substation Expansion 289.5 87.3 376.8 5. 500 kV Sai Noi Substation Expansion 1,592.0 106.1 1,698.1 6. Installation of Line Shunt Reactor at 500 kV Bang Saphan - Chom Bung Lines 352.8 21.2 374.0 7. Communication System Addition 27.7 3.3 31.0 Subtotal 2,894.0 516.0 3,410.0 Total Direct Cost / 5,548.5 7,060.5 12,609.0 INDIRECT COST 8. Engineering & Supervision - 630.5 630.5 9. Physical Contingencies 555.0 769.0 1,324.0 Total Cost (w/o Escalation, Import Duties, IDC & VAT) 6,103.5 8,460.0 14,563.5 10. Escalation 351.5 1,236.5 1,588.0 Total Cost (w/o Import Duties, IDC-& VAT) 6,455.0 9,696.5 16,151.5 11. Import Duties - 742.5 742.5 Total Cost (w/o IDC VAT) 6,455.0 10,439.0 16,894.0 12. Interest During Construction - 1,454.0 1,454.0 Total Cost (w/o VAT) 6,455.0 11,893.0 18,348.0 13. Value Added Tax - 862.0 862.0 Total Cost 6,455.0 12,755.0 19,210.0 Note : / Price Level 1995. -25- Table 4.1 Cost Estimate of 500 kV Transmission System Project for IPPs (Continued) F.C. L.C. Total (MTHB) (MTHB) vMT IT) IN EASTERN AREA TRANSMISSION LINE 1. 500 kV Rayong 4 - T Junction I st Line Route (4x1272 MCM ACSR, DC/ST, 155 km, Including Optical Fibre with Overhead Ground Wire) 773.2 1,903.3 2,676.5 2. 500 kV Rayong 4 - T Junction 2nd Line Route (4x1272 MCM ACSR, DC/ST, 170 km) 785.3 2,069 7 2,855.0 3. 230 kV Rayong 4 - Rayong 2 (4x 1272 MCM ACSR, DC/ST, 10 km, Including Optical Fibre with Overhead Ground Wire) 43.5 106.0 149.5 Subtotal 1,602.0 4,079.0 5,681.0 SUBSTATION 4. 500/230 kV Rayong 4 Substation 872.6 449.8 1,322.4 5. 230 kV Rayong 2 Substation Expansion 40.7 9.6 50.3 6. Installation of Line Shunt Reactor at 500 kV Rayong 4 - Nong Chok and Rayong 4 - Wang Noi Lines 286.6 23.5 310.1 7. Communication System Addition 18.6 2.6 21.2 Subtotal 1,218.5 485.5 1,704.0 Total Direct Cost a/ 2,820.5 4,564.5 7,385.0 INDIRECT COST 8. Engineering & Supervision - 369.5 369.5 9. Physical Contingencies 282.0 493.5 775.5 Total Cost (w/o Escalation, Import Duties, IDC & VAT) 3,102.5 5,427.5 8,530.0 10. Escalation 177.5 779.5 957.0 Total Cost (w/o Import Duties, IDC & VAT) 3,280.0 6,207.0 9,487.0 11. Import Duties - 416.0 416.0 Total Cost (w/o IDC VAT) 3,280.0 6,623 0 9,903.0 12. Interest During Construction - 866.0 866.0 Total Cost (w/o VAT) 3,280.0 7,489.0 10,769.0 13. Value Added Tax - 491.0 491.0 Total Cost 3,280.0 7,980.0 11,260.0 TOTAL PROJECT COST 97-35. 20,735.0 30,470.0 (USD Million Equivalent / 389.4 829.4 1,218.8 ) Notes a/ Price Level 1995. k/ 1 USD = THB 25.0. -26- Table 4.2 Expenditure Schedule of 500 kV T'ransmfission System Project for IPPs (Million Baht) item ~~~~~Descoption TOtW 1996 1997 1998 1999 2000 2001 F.C L.C. Tota F.C. L.C. Tota F.C. L.C Tota F.C. L.C. Tota F.C L.C, Tota F.C L.C Total FC. LC. Tota TRANSMISSION LINE 1 500 kV Buig Saphan - Cut Bung I st Lime Route (4xl272 MCM ACSR, DCIT. 275 kin, nluhxogOptca1Fibmewih Ovuhead Oroqu wire) 1,361.1 3,250.5 4,611.6 - 55 5.5 - 03.9 103.9 49.7 1.137.7 1,187.4 1.2219 1,095.0 2,316.9 39.8 725.1 764 9 497 1833 233 0 2 500 kV Bang Saplia - Cham Bwzg 2nd Line Route (4x] 272 McMACSP,1:DC/ST, 2SOkrn) 1,293.4 3,294.0 4,527.4 - 5.6 5.6 - 105.8 10589 414A 1,156.6 1.198.0 1.17-75 1,107.2 2,284.7 33.1 73371 7668 414 1851 226.5 Subtota 2,654.5 6,544.5 9.199.0 - 11.1 11.1 209.7 209.7 91.11 2,294.3 2,385.4 2,399.4 2,202.21 4,601.61 72.9 1,45889 1,531 7 91 1 368 4 459,5 3 500'230kV BazaSpShm Suzdion Expuanion 632.0 298. 1 930-1 - 0100 000 - - 25.2 25 2 2149 717 2866 354.0 83.9 437 9 63 1 17 3 80 4 4 SOD0kV Chai Bunig Sdustation Expautilo 289.5 87.3 3768 - - . 98.4 36.2 134,6 162 2 42.4 204.6 2839 87 37 6 5 50okVSai Noi SubhalalzExpension 1,592.0 106.1 1,698.1 - - . - . - 5413 440 5853 891.5 51.5 943 0 159.2 10.6 16989 NJ 6 inswalatmnofLne Slzzt Raadgwat SODkV Bospa-hmugie 352.81 21.21 374.0 - .- - - 120,0 8.8 2a 197.51 10.3 20789 35 3 2 1 37 4 7 ComnuaiicatmoSytaAddition 277 33 310 - . - - --2.8 0.31 3.1 22.1 2.7 24. 28 0 3 1 Subtot.a 2,394.0 536.0 3.410.0 IW10. 10D00 252 25,2 9774 161. DJ1,138.4 1,627.3 190.8 1,818.1 289.3 39.0 328 3 TOtaDiz'eoCoet 8/5,548.5 7,060.51 12,609.0 111H 111.1 209.7 209.7 91.1 239.5 2,410.6 3,376.8 2,363.21 5,740.0 1,700.2 1,649.6 3.54989 380.4 4074 7878 8 Eazginveaizw&.Szqzaiaic - 630.5 630.5 - - - - 0 1.0 21.4 21.4 - 332.5 332.5 - 275,6 275 6. 9 PhyalCo,airmies 3555.0 769.0 1,324.0 - 11.1 1 - 21.1 21.1 9.1 234.2 243 3 337.9 269.4 607.3 170.0 192.5 362 5 38 0 40 7 78 7 10 Eacagic 351.5 1,236.5 1,588.0 - 2.4 214 - 14.0 14.0 5.8 265.9 271.7 213.9 437.1 651.0 107.6 409.2 516.81 24 2 1079i 132 1 11i n;wt Duties - 742.5 742.5 - - . .I. -- 501.9 501.9 - 240.6 240.6 - - subtotal ~~~~~906.5 3,378.5 4,285.0 13.5 135 36.1 36.1 14.9 521.5 536.4 5518 1,540.91 2,092.7 277.6. 1,117.91 1,395.5 62.2 148 6 21081 To(alCost (W/o IDC &VAT) 6,455.0 10,439.0 16,894.0 - 124.6 1246 - 245.8 245.8 106.0 2,841.0 2,947.0 3,928 6 3,904.11 7,832.7 1,977.8 2,767.51 4,745 3 442 6 556.0 998 6 1 2 Interest DurnagConsbuctoni 1,454.0 1.454.0 - 33.1 33.1 42.5 42.5 - 124.6 1246 - 1 438.21 438.2 - 815~6 815.6 . - - Total Cost (w/oVAT) 6.455.0 11,893.0 18,348.0 - 157.7 157.7 - 288:1 288.3 106.0 2,965.6 3.071.6 3.928.6 4,342.3 8,270 9 1,977 8 3,8. 5,560 9 4426 556 0 998,6 1 3 Value Added Tax 8 6201 86210 - .-- 42 4321 - I4.9 4749 84 280 4 - 63 5 63 5 TOWalCoat 6.45501 12,755.0 19.210.0 157.7 157 - 288.1 28831 106.0 3,00881 3,11481 3.928.6 4,1. ,48 1.977 8 3,83 5.1 44261 619 5 1.0621 ~ 1PlioLcv 1995 Table 4.2 Expenditure Schedule of 500 kV Transmission System Project for IPPs (Continued) (Million Baht) it_n Desaption Totl 199 1997 199_ 1999 200D 2001 F.C. L.C. Total FPC. L C. Total F.C. L.C. Total F.C. L.C. Totl F.C. L.C. Total F.C. L.C. Total F.C. L.C. Total TRANSMISSIONLINE I SW kV Reg 4 - T Jcion st Line Route (4cI272 MCM ACSR. DMMST. 155 m 1cbxl*ng OicalFibe with Osead CrmdWir) 773.2 1,903.3 2,676.5 3.1 3.1 53.6 58.6 23S6 649.9 673S5 693.1 651.S 1,344.9 22.9 42'7.4 452.3 23.6 110 5 1391 2 500 kV Raym 4 - T btion 2nd Line Route (441272MCMACSR, DYST. 1710km) 735.3 2,069.7 2,S55,0 3.4 3.4 64.2 64.2 25.1 710.7 735.8 715.0 706.2 1,421.2 20.1 46.5.t 485 9 25.1 119.4 144 5 3 230 kV Rr 4 - Rayctg 2 (4xl272 MCM ACSR, DCIST, 10 km, Incudi07 Opt,cal Fibre wil Ovedtad Gunod Wire) 43.5 106.0 149.5 _ 0.2 02 32 7 565 392 9 6 41 54.7 1.2 4 2 5.4 SublaI 1,602.0 4,079.0 5.681.0 0.0 6.5 6.5 0.0 222.3 122.8 53.7 1,360.S 1,414.5 1,440.S 1.414.5 2,355.3 52.6 943 992.9 549 234 1 289 0 4 50/V230kVR R4Subtiotn 372.6 44938 1,322.4 200.0 2000 13.9 1S 9 296.7 95.7 392.4 438.6 1121 600.7 37 3 23.1 1104 5 230 kV Ry 2 Subswicn Expmiu 40.7 9.6 50.3 1 . 23.9 2.5 16.4 22. 6.1 28 9 4.0 1 0 5 0 00 6 1zbalai efLine Shmt Reaceat 500 kV Rayo. 4 - Nmtg Cok wd Raog 4 - Wu NoiLinn 236.6 23.5 310.1 . . . . . . . . 23.7 2.4 311 229.2 237 2479 23.7 24 31 1 7 ComnmicationSysternidditio 23.6 26 21.2 . - . _ .9 03 2.2 143 2.0 163 2 9 0 3 2.2 Suial 1,213.5 435.5 1.704.0 200.0 200.0 1 .9 231.9 341.2 100.9 442.1 755.4 13 8 9 894 3 121.9 26 1243.7 Totl Dire Cost I| 2S,20.5 4,564.5 7,335.0 206.5 206.5 0.0 22.3 122.3 53.7 1,379.7 1,433.4 1,732.0 1.515.4 3,297.4 303.0 1,079.2 1,387.2 176 3 260.9 437 7 INDECT C>T____ _ _.._ S Eagjne ng&Supavision - 369.5 369.5 - - 12.0 2.0 .I 2. 2. 192.3 192. - 263 9 163.9 9 physica 2Cownrcies 232.0 493.5 775.5 20.7 20.7 12.4 12.4 5.4 139.3 144.7 181.3 171.0 352.3 77.6 124 0 201.6 17.7 26 1 43 3 10 Escaltion 177.5 779.5 957.0 4.5 4.5 S 2 32 34 1573S 161.2 114.2 276.7 390.9 48.S 263.2 312.0 III 69.1 S0 2 I I lcat Duties - 416.0 416.0 .- - _ . 285.4 235.4 - 13106 130.6 Subtotal 459.5 2.053.5 2,523.0 _ 25.2 25.2 21.6 21.6 3.3 303.9 317.7 295.5 925.9 1,221.4 126.4 6121.7 308.1 23.3 95 2 124 0 Tots Cost(w/o EDC & VAT) 3,230.0 6,623.0 9,903.0 231.7 2317 144.4 144.4 62.5 1,688.6 1,751. 2,077.5 2,441.3 4,513.3 934.4 1,74509 2,695.3 205 6 3561 561 7 22 jatreDtDwuri Cuuuuctin - K6.0 t66.0 21.3 21 3 30.3 30.8 - 79.5 79.5 - 260.3 260. - 473 6 473.6 . Total Cost(w/o AT') 3,230.0 7,439.0 10,769.0 253.0 253.0 1752 1752 62.5 1,763.1 1,330.6 2,077. 2,702.1 4,779.6 934.4 2,2t45 3,16S 9 205 6 356 1 561 7 13 Value Added Tax 491.0 491.0 27.0 27.0 o 272.0 2720 156.2 256.2 . 35 S 35 8 Total Cost 3.2t0.0 7,930.0 11,260.0 = 253.0 253.0 1 175.2 175.2 62.5 1,795.1 1,357.6 2,077.5 2,974 1 5,052.6 934.4 2,390 7 3,325 1 205.6 391 9 597 5 TOTAL PROJECT COST 9,735.0 20,735.0 30,470.0 410-7 410.7 463.5 463.5 163.5 4,303.9 4,9724 6,06.1 7.7923 23,797.4 2,912 2 6,254 2 9,1664 64.82 p011 4 11.659 6 USD MillionEuent b 339.4 329.4 1,213.3 16.4 26.4 - .5 15.s 6.3 292. 1 939 240.2 311.7 551 9 116 5 250.2 3667 25 9 40 5 66 4 Notes :/ Priceevel v995. b/ I0 USD = TIM 25.0. Table 4.3 Implementation Schedule of 500 kV Transmission System Project for IPPs (Western ArVea) 1995 1996 19'3 1998 1999 2000 2001 F easibility Study I2 i ii X t1t[ f1 124 4 t1}8 Approval by EGAT Board._.. ........ . Project Appraised by NESDS Hil I Ill I Il I 11 I .11II . I Land Procurement &c Rights-of-Way I I H .l t 1 1 1 111 . .1 lll 1ll il 1ll 4 I Line Routs Survey .llIl1illILLi llSI 111M 11111 IIIII Se e U f@cations & Tender Document i i t4l | *_ _ LLt B5id Ealaimon & Negotiaton lll||1 lllllW 0 1II I M t,I fi1 [ tt4 Substation_ .. - _. . 33 4 2 3t i E TRIANS)aSSION SYSIS PLANNING DIVI'ION Table 4.4 Implementation Schedule of 500 kY Transmission System Project for IPPs (Eastern Area) 199 1998 1 97 1 98 1999 2000 20 Approval by EG_ Board______________________________11111111111 TRA21SMSSSJON SYSTEI PLANNING DIVISION 5. POWER SYSTEM STUDIES Power system studies have been made to investigate and verify the maximum power transfer capability of the 500 kV transmission plan as recommended by the BVI/PTI study. This revised study has been perforned with the changing conditions from the previous BVIPTI study; i.e., the adoption of new load forecast and Power Development Plan (PDP 95-01); the generating capacity of the planned Ratchaburi Termal Power Plant is increased from 3,600 MW to 4,600 MW; and the possibility of 600 MW stage I IPP Project to be integrated at Ratchaburi 2 Substation. The 500 kV transmission plan is also adopted for the connection of 10,000 MW power plant projects in the eastern area. In the 1994 solicitation for power of 4,100 MW from IPPs, has included the first 1,000-1,300 MW (First Stage IPPs) for completion during 1996-2000. With the limitation of the existing transmission capability, many substations have the capacities enough to . ecei. the power from the first stage IPPs with the maximum of: either 600 MW at Ratchaburi or 800 MW at Sam Phran for the western area, and either 700 MW at Ao Phai or 700 MW at Pranchin Buri or 300 MW at Khlong Mai and 200 MW at Rayong for the eastern area. For the next 2,800 MW of capacity, preference will be given to a division of approximately 1,400 MW located in the westem area and 1,400 MW located in the eastern area in order to stabilize the power system. According to the recommended plan in the PDP 95-01, the power development program during 1998-2011 includes many new large base-load power plants and the power purchases from the IPPs as follows: IPP 1,300 MW (without system reinforcement) 1998-2000 Ratchaburi Combined Cycle (3x600 MW) 1998-1999 Ratchaburi Thernal Plant (4x700 MW) 1999-2001 -31- IPP (2x700 MW) 2001 IPP (2x700 MW) 2002 IPP (1,000 MW) 2003 IPP (1,000 MW) 2004 IPP & EGAT new thermal plant (2xl 000 MW) 2005 IPP & EGAT new thermal plant (2x 000 MW) 2006 IPP & EGAT new thermal plant (2x 1000 MW) 2007 IPP & EGAT new thermal plant (2x 000 MW) 2008 IPP & EGAT new thermal plant (2x 000 MW) 2009 IPP & EGAT new thermal plant (2x 000 MW) 2010 IPP & EGAT new thermnal plant (2x1000 MW) 2011 As shown above, up to 2011, the large base load power plant projects of about 13,100 MW will be given to IPPs and the other new power plants for a total capacity of 11,600 MW will be developed by EGAT. For the studies, all of the first stage IPPs (1,300 MW) of the 1994 solicitation are assumed to be located in the Western and Eastern Areas at the limited capacity of each substation. However, for the next and future IPPs, including the new EGAT thermal power plant projects as indicated in the PDP 95-01, two basic plans are used for the studies: (1) All future power plants are assumed to be located in the west coast for the studies of the transmission system in the Western Area; and (ii) All future power plants are assumed to be located in the east coast for the studies of the transmission system in the Eastern Area. Steady state power flow and stability studies are simulated at both peak load and light load conditions to determine the maximum power transfer capability of the proposed 4 circuits of the 500 kV transmission lines. Fault level study is also carried out. The following machine parameters ate used in the study. Inertia constant of each generator (iH) = 3.8 kW-s_VA Transient reactance (Xd) = 0.28 p.u. Subtransient reactance (X"d) = 0.22 p.u. -32- Auto transformer impedance (500/230 kV) = 22 0/a Short-circuit impedance of generator transformer = 18 % Power factor = 0.85 All exciters are equipped with power system stabilizers (PSSs) 5.1 The 500 kV Transmission System in the Western Area Two double-circuit 500 kV transmission lines, using 4x1272 MCM ACSR conductors per phase, from Bang Saphan to Chom Bung switching station and from Chom Bung to Wang Noi and Sai Noi in the Bangkok vicinity have been planned. The latter line sections will be constructed under Ratchaburi Power Plant Project. The generated power, totalling 4,600 MW, from the Ratchaburi combined cycle power plant and the Ratchaburi thermal power plants, as well as 600 MW of the first stage of IPP installed at Ratchaburi 2 Substation, are assumed to be included in Year 2000. With the completion of the proposed 500 kV iines by the end of Ye 2000, the results of the studies can be concluded as follows: a) System of Year 2001 with additional 2x700 MW IPP Power Plants (total 1.400 MW) From the power system analyses, it is shown that the system works technically satisfactorily. b) System of Year 2002 with additional 2x700 MW IPP Power Plants (total accumulative new caDacities from Year 2001 is 2.800 MW) With the samne configuration, the system is technically satisfactory. c) System of Year 2003 with additional 1.000 MW IPP Power Plant (total accumulative new capacities from Year 2001 is 3.800 MW) The system is technically satisfactory without any reinforcement. -.33 - d) System of Year 2004 with additional 1 000 MW IPP Power Plant (total accumulative new capacities from Year 2001 is 4.800 MW) The system studites based on the N-! critprinn confirm th the svytem i technically viable. If, however, the N-2 is applied on the 500 kV Chom Bung - Sai Noi line during the light load period, the system is oscillated (Figure Case TS-LO4W). To solve such problem, the sectionalization of one circuit of the 500 kV Chom Bung - Wang Noi line and the reconnection of the two line sections at the 500 kV Sai Noi Substation is proposed. e) System of Year 2005 with additional 1,000 MW IPP and 1,000 MW new thermal Power Plant (total accumulative new capacities from Year 2001 is 6-800 MM Transient stability studies based on the N-1 criterion show that the system is unstable if a three phase fault occurs on the 500 kV Bang Saphan - Chom Bung line during light load period (Figure Case TS-LO5W). flowever, if only 1,000 MW Power Plant is included this year, the system is technically satisfactory with both N-I and N-2 contingencies.. Based on the results of the study, it can be concluded that the maximum power transfer capability of two double-circuit 500 kV lines from Bang Saphan to Chom Bung can be 5,800 MW. To increase the power transfer capability, the addition of more parallel lines or the installation of the appropriate series compensators are required. Further studies will be carried out for the next stage of transmission system reinforcement or expansion program. Power flow diagrams and stability curves are shown in Appendix 2 and 3. 5.2 The 500 kV Transmission System in the Easem Area Two double-circuit 500 kV lines consisting of one double-circuit from Rayong 4 to Wang Noi and another double-circuit from Rayong 4 to Nong Chok, using 4xi272 MCM ACSR conductors per phase, are assumed in the studies. The integration with the existing system is made at Rayong 4 by the installation of two 500/230 kV tie -34- transformers, each rated 1,000 MW, connecting to Rayong 2 Substation via a 230 kV double-circuit line, using 4x1272 MCM ACSR conductors per phase. Since it is possible to add 700 MW out of the first iPP into the Eastem Area, the injection of 300 MW in Khlong Mai and 400 MW in Ao Pha is assumed in this study. This case is considered as the worst scenario to the network conditions. The results of the studies can be concluded as follows: a) System of Year 2001 with additional 2x700 MW IPP Power Plants (total accumulative new caDacities from Year 2001 is 1.400 MW) With the proposed 500 kV transmission system, the system is technically satisfactory. b) Svstem of Year 2002 with additional 2x700 MW IPP Power Plants (total accumulative new capacities from Year 2001 is 2.800 MW) With the same system configuration above, the system is technically satisfactory. c) System of Year 2003 with additional 1,000 MW IPP Power Plants (total accumulative new canacities from Year 2001 is 3.800 MW) The system is technically satisfactory without any further reinforcement. d) System of Year 2004 with additional 1.000 MW IPP Power Plants (total accumulative new caoacities from Year 2001 is 4.800 MW) From the power system analyses, it is shown that the system is still technically satisfactory. -35-. e) System of Year 2005 with additional 1.000 MW IPP and 1,000 MW new thermal Power Plants (total accumulative new capacities from Year 2001 is 6.800 MW) The results of the studies show that the system is technically satisfactory without further reinforcement. f) System of Year 2006 with additional 1.000 MW IPP and 1.000 MW new thermal Power Plants (total accumulative new caRacities from Year 2001 is 8.800 MW) The high fault current (exceed 50 kA) at 500 kV Rayong 4 was observed. The measure to limit the fault current was the splitting of the 500 kV bus into two buses, with equal capacity at each bus was used. But the power flow studies shew thfat, in ca-e of N- I contingency, if a fault occured on the 500 kV Rayong 4 - Nong Chok line, the 500/230 kV tie transformer at Bus #1 of Rayong 4 would be 8 % overloaded during peak load period, and if a fault occured on the 500 kV Rayong 4 - Wang Noi line, the 500/230 kV tie transformer at Bus #2 of Rayong 4 would be overloaded about 18 % and 5 % during peak and light load periods respectively. So that the installation of two additional 500/230 kV tie transformers at Rayong 4 Substation will be recommended. No transient instability is shown, when a disturbance occurs in the system. g) System of Year 2007 with additional 1.000 MW IPP and 1.000 MW new thermal Power Plants (total accumulative new caDacities from Year 2001 is 10.800 MW) The power flow studies based on the single contingency criterion show that the 230 kV Rayong 2 - Ao Phai line will be overloaded by 7.6 %, if a fault is applied on each line. The transient stability studies have been also investigated. The results indicate that the svstem is unstable if a three-phase fault occurs on the 500 kV Rayong 4 - Nong Chok line. -36- If only 1,000 MW Power Plant is connected to the system in this year, hne results of the studies show that the system is still unstable, if a three-phase fault is applied on one circuit of the 500 kV Rayong 4 - Wang Noi line during the light load period. As the results of the study, the maximum power transfer capability of the Eastern Area is 8,800 MW. Further studies are required to determine the additional transfer capability. The installation of more parallel lines or series compensators would be recommended in the next stage of transmission system expansion program. Power flow diagrams and stability curves are shown in Appendix 2 and 3. Conclulsion For the 500 kV transmission system in the Western Area, the maximum power transfer capability of the two 500 kV double-circuit line is 5,800 MW by the stability limit. For the 500 kV transmission system in the Eastern Area, the maximum power transfer capability of the two 500 kV double-circuit transmission line is 8,800 MW by the stability limit. To increase more power transfer capability of the two areas, further studies will be required. According to the BVI study, the installation of more 500 kV lines or the installation of series capacitor with appropriate compensation would be the options to be considered. 5.3 Fault Level Studies The fault level studies have been conducted for the development of the Western 500 kV transmission system and the Eastem 500 kV transmission system in Year 2005 and 2006 respectively. The three-phase fault and the single-line-to-ground fault at the concerned power plants and substations have been investigated. The high fault current is observed at 500 kV Rayong 4 Busbar in 2006. This is due to the fact that many generating units will be installed. To limit the fault current at this power plant, splitting the bus at the switchyard into two sections would be therefore recommended in 2006. The expected high fault current at significant power plants and substations (with the measures to limit fault currents) are shown below: -37- 5.3.1 The Development of the Western 500 kV Transmission Lines 3-0 (kA) 1-0 (klA 230 kV South Thon Buri Substation 40.5 28.0 230 kV Bangkok Noi Substation 44.0 26.7 230 kV Wang Noi Substation 38.8 41.8 500 kV Bang Saphan Substation 34.0 30.5 500 kV Wang Noi Substation 34.1 23.9 5.3.2 The DeveloRment of the Eastern 500 kV Transmission Lines 3-0 (kA) 1-0 (kA) 230 kV On Nuch Substation 41.6 25.0 230 kV Wang Noi Substation 39.7 42.6 230 kV Rayong 2 Substation 42.0 39.0 230 kV Bang Pakong Substation (Bus #1) 39.9 45.1 230 kV Bang Pakong Substation (Bus #2) 47.1 48.0 230 kV Rayong 4 Substation 46.9 42.1 500 kV Rayong 4 Substation (Bus #1) 29.9 33.0 500 kVRayong 4 Substation (Bus #2) 29.6 33.0 500 kV Wang Noi Substation 41.5 27.0 Fault current flow diagrams are shown in Appendix 4. Notes 3-0 = three-phase fault. 1-0 = single-line-to-ground fault. -38- 6. ECONOMIC ANALYSIS The economic analysis is made to justify the economic viability of the proposed 500 kV transmission system. The proposed 500 kV transmission system project is compared with the other transmission project which can transmit the bulk power from the IPP plants to the load center. Referring to BVI/PTI study, two out of three basic systems have been reviewed: the 500 kV transmission system (the preferred plan) and the 765 kV transmission system (The second best alternative). The requirement of transmission system for the 765 kV alternative are determined to meet the same maximum transfer capability of the 500 kV alternative. The cost streams of the two altematives which comprise the capital investment cost, operation and maintenance cost (O&M) and the cost of system losses are compared by U-sxng disoCunt csh flow technique. Trhe benefit/cost ratio (B/C ratio), net present value (NPV) with reference to 10 % discount rate and the equalized discount rate (EDR) are calculated to indicate the least cost alternative. The study is conducted separately for westem and eastern coast IPP. 6.1 Transmission System Altemative The transmission system alternatives for the west and east coast power plant projects (IPPs as well as EGATs future base load power plant projects) can be summarized as follows: The West Coast 500 kV Alternative - Construction of 500 kV Bang Saphan Substation. -39- - Construction of two routes of the 500 kV double circuit line from Bang Saphan to Chom Bung, using 4x1272 MCM ACSR conductors. The distance of the two line routes are approximately 275 and 280 km respectively. - Expansion and improvement of the related substations. 765 kV Alternative - Construction of 765 kV Bang Saphan and Chom Bung Substations. - Construction of three circuits of 765 kV Bang Saphan - Chom Bung, consisting of one double circuit steel tower line and one single circuit steel tower line. The tiree circuits are strung wihm 4x1590 MCM ACSR conductors, a distance of approximately 285 km. - Installation of 765/500 kV tie transformers at Chom Bung Substation, rated 1,000 MVA, in the stages as required by the demand of the power system. - Expansion and improvement of the related substation. The East Coast 500 kV Alternative - Construction of 500 kV Rayong 4 Substation. - Construction of two routes of the 500 kV double circuit line from the proposed new 500 kV Rayong 4 Substation to interconnect with Sai Noi (Wang Noi) - Nong Chok transmission line, using 4x1272 MCM ACSR conductors with the distance of approximately 155 and 170 km for the first and second line routes respectively. - Construction of 230 kV double circuit line Rayong 4 - Rayong 2 using 4x1272 MCM ACSR conductors with the distance of approximately 10 km. -40- - Expansion and improvement of the related substations. 765 kV Alternative - Construction of new 765 kV Rayong 4 Substation. - Sectionalization and extension of two circuit of 500 kV Wang Noi - Nong Chok to be terminated at the junction located 17 kan away from 500 kV Nong Chok Substation and construction of the new 765/500 kV substation at the junction. - Construction of three circuits of 765 kV Rayong 4 - New Substation. consisting of one double circwut steel tower line and one single circuit steel tower line. The ree circuits are strung with 4xl 590 MCM ACSR conductors, a distance of approximately 155 km. - Construction of 230 kV double circuit line Rayong 4 - Rayong 2 using 4x1 272 MCM ACSR conductors with the distance of approximately 10 km. - Installation of + 1,800 MVAr. Static Var Compensator (SVC) at new substation. - Installation of 765/500 kV tie transformers at new substation, rated 1,000 MVA, in the stages as required by the demand of the power system. 6.2 Capitl Cost of Alternatives All capital cost are estimated based on 1995 price level. The cost without import duties and taxes, interest during construction (IDC) and escalation are used in the analysis. The economic capital cost of two altemnatives can be summarized as follows: -41- Unit: MTHB Transmission Substation Total Line Westem Transmission System 500 kV Altemative 10,625.0 3,938.5 14,563.5 765 kV Alternative 11,428.1 7,682.8 19,110.9 Eastern Transmission System 500 kV Altemative 6,562.1 1,968.0 8,530.1 765 kV Altemative 6,198.1 12,059.4 18,257.5 6.3 Operation and Maintenance Cost (O&M) The O&M cost of the transmission line portion is assumed to be I % of the capital investment cost while the O&M cost of substation is assumed to be 2 % of the capital cost. 6.4 Losses in the Transmission System Since two alternatives produce different losses to the power system, the difference in EGATs power system losses is also taken into account in the least cost analysis. The capacity loss (MW) is adopted from the power flow study of the respective alternative. The energy loss (GWh) is calculated from the capacity loss and loss factor using the equations as follows: Energy Loss Capacity Loss (MW) x 8.76 x Loss Factor Loss Factor = 0.1 x (Load Factor) + 0.9 (Load Factor)2 The cost of losses used in the study are adopted from EGATs Long Run Marginal Cost (LRMC) which is based on 1994 price level and is escalated to be 1995 price as follows: Cost of Capacity Loss = 3,117.3 THB/kW-yr Cost of Energy Loss = 0.7402 THB/kWh 6.5 Economic Life The economic life of the transmission line and substation are assumed to be 40 and 25 years respectively. -42- 6.6 Results of the Least Cost Solution Study a) Comparison of Present Value P. V at 10 % DR. (MTHB) Western System 500 kV 32,518.3 765 kV 34,237.6 Eastern System 500 kV 28,919.7 765 kV 32,674.5 b) Net Present Value, B/C Ratio and EDR. Net P. V. B/C EDR. (MTHB) Ratio (%) Westem System 500 kV VS. 765 kV 1,719.3 1.0529 > 150.0 Eastern System 500 kV VS. 765 kV 3,754.8 1.1298 > 150.0 The results of the study have led to the conclusion that the construction of 500 kV transmission system to transmit bulk power from the IPP power plants and EGAT base load power plants is the least cost alternative for both west coast and east coast transmission systems. The summary of the results of the least cost solution study and the cost stream of each alternative are shown in Tables 6.1 to 6.6. -43- Table 6.1 Summary of Results of Economic Analysis Project Transmission System Project for IPP Cost Stream 500 kV Transmission System for Western IPP Benefit Stream 765 kV Transmission System for Western IPP Discount Present Value Present Value B/C Present Value Rate of of Ratio of (%) Benefit Cost Net Benefit 4.00 66045.18 65119.70 1.0142 925.49 6.00 51853.61 50471.44 1.0274 1382.18 8.00 41694.44 40077.11 1.0404 1617.33 10.00 34237.61 32518.32 1.0529 1719.28 12.00 28633.47 26892.21 1.0647 1741.26 14.00 24328.12 22612.40 1.0759 1715.72 16.00 20953.07 19290.41 1.0862 i662.66 18.00 18258.27 16663.80 1.0957 1594.47 20.00 16070.71 14551.83 1.1044 1518.88 22.00 14268.41 12827.72 1.1123 1440.69 24.00 12763.77 11400.93 1.1195 1362.84 26.00 11492.79 10205.68 1.1261 1287.11 Equalized Discount Rate is Greater Than 150% Transmission System Planning Division 29-Jan-96 -44- 04:19 PM Table 6.2 Cost Stream of 500 kV Transmission System for Western IPP Unit: MTHB Fiscal Capital Cost O&M Cost Syste Losses Cost of Losses f Total Year Line 1 Sub. Line Sub. Peak Energy Peak Energy Cost 1995 j 1 (GWh | . 1996 12.2 110.0 i 122.2 1997 231.8 _ 231.8 1998 2633.6 41.7 2675.3 1999 5359.7 1320.1 I 6679.8 2000 1882.3 2105.6 3987.91 2001 505.4 361.1 106.3 78.8 376.05 1889,99 1172.3 1399.0 3622.8 2002 106.3 78.8 427.63 2158.42 1333.1 1597.7 3115.8 2003 106.3 78.8 481.37 2456.52 1500.6 1818.3 3504.0 2004 106.3 78.8 585.91 3052.17 1826.5 2259.2 4270.8 2005 106.3 78.8 602.40 3162.88 1877.9 2341.2 4404.1 2006 106.3 78.8 602.40 3187.79 1877.9 2359.6 4422.6 2007 1 106.3 78.8 602.40 3207.32 1877.9 2374.1 4437.0 2008, 1 106.3 78.8 602.40 3215.15! 1877.9 2379.9 4442.8 2009 106.3 78.8 602.40 3222.99 1877.9 2385.7 4448.6 2010 106.3 78.8 602.40 3230.05 1877.9 2390.9! 4453.8 2011 106.3 78.8 602.40 3237.12 1877.9 2396.1i 4459.1 2012 106.3 78.8 602.40 3237.12 1877.9 2396.1 4459.1 2013 iu6.3 ,. eo2.4 2-37.12 1877.9 2396.1 4459.1 2014 106.3 78.8 602.40 3237.12 1877.9 2396.1 4459.11 2015 106.3 78.8 602.40 3237.12 1877.9 2396.1 4459.1 2016 106.3 78.8 602.40 3237.12 1877.9 2396.1 4459.1 2017 106.3 78.8 602.40 3237.12 1877.9 2396.1 4459.1 2018 106.3 78.8 602.40 3237.12 1877.9 2396.1 4459.1 2019 106.3 78.8 602.40 3237.12 1877.9 2396.1 4459.1 2020 106.3 78.8 602.40 3237.12 1877.9 2396.1 4459.1 2021 106.3 78.8 602.40 3237.12 1877.9 2396.1 4459.1 2022 106.3 78.8 602.40 3237.12 1877.9 2396.1 4459.1 2023 106.3 78.8 602.40 3237.12 1877.9 2396.1 4459.1 2024 106.3 78.8 602.40 3237.12 1877.9 2396.1 4459.1 2025 -3984.41 - 106.3 78.8 602.40 3237.12 1877.9 2396.1 474.7 Total 6640.6 3938.5 2657.5 1970.0 - 1 45267.4 57247.1 117721.2 P.V. 7067.8 2544.2 599.1 444.1 - - 97082 12154.9 32518.3 10% DR. I I I I__III__ -45- Table 6.3 Cost Stream of 765 kV Transmission System for Western IPP Unit: MTHB Fiscal Capital Cost O&M Cost System Losses Cost of Losses Total Year Line Sub, Line Sub. Peak Energy Peak Enorgy Cost (MW) (GWh)l 1995 1996 12.2 110.0 122.2 1997 345.8 _ 345.8 1998 3626.7 56.5 3683.2 1999 5144.3 1984.1 7128.4 2000 1817.4 3097.8 4915.2 2001 481.7 974.1 114.3 124.5 374.55 1882.46 1167.6 1393.4 4255.6 2002 511.9 114.3 134.7 418.65 2113.09 1305.1 1564.1 3630.1 2003 453.9 114.3 143.8 463.16 2363.59 1443.8 1749.5 3905.3 2004 445.7 114.3 152.7 552.14 2876.25 1721.2 2129.0 4562.9 2005 48.8 114.3 153.7 554.13 2909.44 1727.4 2153.6 4197.8 2006 114.3 153.7 554.13 2932.36 1727.4 2170.5 4165.9 2007 114.3 153.7 554.13 2950.32 1727.4 2183.8 4179.2 2008 114.3 153.7 554.13 2957.52 1727.4 2189.2 4184.5 2009 114.3 153.7 554.13 2964.73 1727.4 2194.5 4189.9 2010 114.3 153.7 554.13 2971.23 1727.4 2199.3 4194.7 2011 114.3 153.7 554.13 2977.73 1727.4 2204.1 4199.5 2012 114.3 153.7 554.13 2977.73 1727.4 2204.1 4199.5 2013 114.3 153.7 554.13 2977.73 1727.4 2204.1 4199.5 2014 114.3 153.7 554.13 2977.73 1727.4 2204.1 4199.5 2015 114.3 153.7 554.13 2977.73 1727.4 2204.1 4199.5 2016 114.3 153.7 554.13 2977.73 1727.4 2204.1 4199.5 2017 114.3 153.7 554.13 2977.73 1727.4 2204.1 4199.5 2018 114.3 153.7 554.13 2977.73 1727.4 2204.1 4199.5 2019 114.3 153.7 554.13 2977.73 1727.4 2204.1 4199.5 2020 114.3 153.7 554.13 2977.73 1727.4 2204.1 4199.5 2021 114.3 153.7 554.13 2977.73 1727.4 2204.1 4199.5 2022 114.3 153.7 554.13 2977.73 1727.4 2204.1 4199.5 2023 114.3 153.7 554.13 2977.73 1727.4 2204.1 4199.5 2024 114.3 153.7 554.13 2977.73 1727.4 2204.1 4199.5 2025 -4285.5 - 114.3 153.7 554.13 2977.73 1727.4 2204.1 -86.0 Total 7142.6 7682.8 2857.5 3783.4 - - 41912.8 52988.7 116367.7 P.V. 7690.1 4653.2 644.2 835.0 - _ 9068.1 11347.0 34237.6 10% DR.] _ . -46- Table 6.4 summary of Results of Economic Analysis Project Transmission System Project for IPP Cost Stream 500 kV Transmission System for Eastem IPP Benefit Stream 765 kV Transmission System for Eastern IPP Discount Present Value Present Value B/C Present Value Rate of of Ratio of (O) Benefit Cost Net Benefit 4.00 66339.75 62399.89 1.0631 3939.86 6.00 51200.26 47163.03 1.0856 4037.23 8.00 40469.28 36524.66 1.1080 3944.62 10.00: 1 2674.4B 28919.65 1A1298 3754.81 12.00 26880.44 23359.48 1.1507 3520.96 14.00 22480.44 19207.23 1.1704 3273.22 16.00 19072.64 16044.36 1.1887 3028.29 18.00 16385.55 13590.54 1.2057 2795.01 20.00 14232.06 11654.45 1.2212 2577.61 22.00 12480.82 10103.13 1.2353 2377.69 24.00 11037.86 8842.S3 1.2483 2195.32 26.00 9834.83 7805.05 i.260I 2029.78 Equallzed Discount Rate is Greater Than 150% Transmission System Planning Division 29-Jan-96 04:23 PM -47- Table 6.5 Cost Stream of 500 kV Transmission System for Eastem IPP Unit: MTHB Fiscal Capltal Cost O&M Cost System Losses Cost of Losses Total Year une Sub. Line Sub. Peak Energy Peak Energy Cost (MWv) (GWh) 1995 1996 7.2 220.0 227.2 1997 136.2 - 136.2 1998 1561.5 28.4 1589.9 1999 3321.9 555.7 3877.6 2000 1217.3 1000.3 2217.6 2001 317.9 163.6 65.6 39.4 396.11 1990.81 1234.8 1473.6 3294.9 2002 65.6 39.4 403.34 2035.81 1257.3 1506.9 2869.2 2003 65.6 39.4 426.62 2177.12 1329.9 1611.5 3046.4 2004 65.6 39.4 490.54 2555.36 1529.2 1891.5 3525.6 2005 65.6 39.4 539.60 2833.15 1682.1 2097.1 3884.2 2006 65.6 39.4 663.96 3513.56 2069.8 2600.7 4775.5 2007 65.6 39.4 663.96 3535.08 2069.8 2616.7 4791.4 2008 65.6 39.4 663.96 3543.71 2069.8 2623.1 4797.8 2009 65.6 39.4 663.96 3552.35 2069.8 2629.4 4804.2 2010 65.6 39.4 663.96 3560.13 2069.8 2635.2 4810.0 2011 65.6 39.4 663.96 3567.93 2069,8 2641.0 4815.7 2012 65.6 39.4 663.96 3567.93 2069.8 2641.0 4815.7 2013 65.6 39.4 663.98 3567.93 2069.8 2641.0 4815.7 2014 65.6 39.4 683.96 3567.93 2069.8 2641.0 4815.7 2015 65.6 39.4 663.96 3567.93 2069.8 2641.0 4815.7 2016 65.6 39.4 663.96 3567.93 2069.8 2641.0 4815.7 2017 65.6 39.4 663.96 3567.93 2069.8 2641.0 4815.7 2018 65.6 39.4 663.96 3567.93 2069.8 2641.0 4815.7 2019 65.6 39.4 663.96 3567.93 2069.8 2641.0 4815.7 2020 65.6 39.4 663.96 3567.93 2069.8 2641.0 4815.7 2021 65.6 39.4 663.96 3567.93 2069.8 2641.0 4815.7 2022 65.6 39.4 663.96 3567.93 2069.8 2641.0 4815.7 2023 65.6 39.4 663.96 3567.93 2069.8 2641.0 4815.7 2024 65.6 39.4 663.96 3567.93 2069.8 2641.0 4815.7 2025 - 240.8 _ 65.6 39.4 663.96 3567.93 2069.8 2641.0 2355.0 Total 4101.3 1968.0 1640.0 985.0 - _ 48428.5 61300.41 118423.2 P.V. 4355.5 1314.3 369.7 222.1 - _ 10053.3 12604.7 28919.7 10% DR. ... .. ... -48- Table 6.6 Cost Stream of 765 kV Transmission System for Eastern IPP Unit: MTHB Fiscal Capital Cost O&M Cost Svstem Losses Cost of Losses Total Year Line Sub. Line Sub. Peak Energy Peak Energy Cost (MW) (GWh) 1995 1996 7.2 550.0 557.2 1997 203.0 _ 203.0 1998 2071.3 71.2 2142.5 1999 2535.7 1664.7 4200.4 2000 1130.5 3119.0 4249.5 2001 250.4 944.4 62.0 127.0 401.19 2016.35 1250.6 1492.5 4126.9 2002 120.4 62.0 129.4 390.02 1968.58 1215.8 1457.1 2984.8 2003 405.1 62.0 137.5 416.46 2125.27 1298.2 1573.1 3476.0 2004 969.1 62.0 156.9 474.24 2470.45 1478.3 1828.6 4495.0 2005 3768.9 62.0 232.3 505.46 2653.90 1575.7 1964.4 7603.3 2006 446.6 62.0 241.2 582.77 3083.91 1816.7 2282.7 4849.2 2007 62.0 241.2 582.77 3102.81 1816.7 2296.7 4416.6 2008 62.0 241.2 582.77 3110.38 1816.7 2302.3 4422.2 2009 62.0 241.2 582.77 3117.96 1816.7 2307.9 4427.8 2010 62.0 241.2 582.77 3124.79 1816.7 2313.0 4432.8 2011 62.0 241.2 582.77 3131.63 1816.7 2318.0 4437.9 .2012 62.0 241.2 582.77 3131.63 1816.7 2318.0 4437.9 2013 62.0 241.2 582.77 3131.63 1816.7 2318.0 4437.9 2014 62.0 241.2 582.77 3131.63 1816.7 2318.0 4437.9, 2015 62.0 241.2 582.77 3131.63 1816.7 2318.0 4437.9 2016 62.0 241.2 582.77 3131.63 1816.7 2318.0 4437.9 2017 62.0 241.2 582.77 3131.63 1816.7 2318.0 4437.9 2018 62.0 241.2 582.77 3131.63 1816.7 2318.0 4437.9 2019 62.0 241.2 582.77 3131.63 1816.7 2318.0 4437.9 2020 62.0 241.2 582.77 3131.63 1816.7 2318.0 4437.9 2021 62.0 241.2 582.77 3131.63 1816.7 2318.0 4437.9 2022 62.0 241.2 582.77 3131.63 1816.7 2318.0 4437.9 2023 62.0 241.2 582.77 3131.63 1816.7 2318.0 4437.9 2024 62.0 241.2 582.77 3131.63 1816.7 2318.0 4437.9 2025 -2324.3 - 62.0 241.2 582.77 3131.63 1816.7 2318.0 2113.6 Total 3873.8 12059.4 1550.0 5607.1 - - 43152.1 54689.0 120831.3 P.V. 4172.5 6431.6 349.4 1150.0 - _ 9132.9 11438.0 32674.5 10% DR. . _ _ _ _ _ -49- 7. FINANCIAL JUSTIFICATION OF THE PROJECT The financial justification is the economic and financial internal rate of return (MU DD FIRA oTtDD he 500 kAV 1,,, -"',"' -ystem f"r the wvest ct anfd east coast IPP power plants by comparing their investment costs with the benefit accrued from the project. The study is made separately jor EIRR and FIRR study. 7.1 Economic Internal Rate of Return Study (EIRR) The economic internal rate of return study is conducted by comparing the cost of impletnenting the 500 kV transmission system of both west coast and east coast systems with the benefit which will be made available from the purchasing of electric energy from the IPP together with the electric energy generated from EGAT's coal-fired power plants which are planned to be connected to the proposed 500 kV transmission system. Details of IPP and EGATs power project planned to be connected.to the proposed project are shown in Table 7.1. The cost and benefit applied for the study will be the combined cost and benefit of the west coast and east coast systems since the projects are proposed to be implemented simultaneously. The benefit of the project for the EIRR study can be pointed out by two approaches, i.e; Aporoach 1 : The benefit of the project is assumed to be the reduction of the countrys load losses and outages. The load losses will be presented as the difference in the probabilistic Expected Unserved Energy (EUE) between the EGAT's Power Development Plan (PDP) with and without the project calculated by using Westinghouse Interactive Generation Planning Software (WIGPLAN) computer program. The cost of the reduction of the EUE resulting from the implementation of this project is adopted from the latest "EGATs Cost of an Outage Study" conducted by EGATs System Planning Department on October 1992. The cost of an outage according to the mentioned study is 58.87 THB/kWh. -50- 3' - Approach 2 : Since the proposed 500 kV transmission system project is proposed to transmit bulk power from the IPP and EGAT's coal-fired power plants to the load center in the central region, so it is reasonable to assume that the benefit of the project is the incremental energy sale resulting from the implementation of this project. 7.1.1 Basic Assumptions The economic internal rate of return (EIRR) study of the two approaches are performed based on the following assumptions: Cost Stream The cost stream of the projects consists of the following a) Capital Investment Cost The capital investment cost is the construction cost of the 500 kV transmission system implemented for west coast and east coast systems. The constant 1995 price without import duties and taxes, interest during construction (IDC) are used for the stud.v b) Operation and Maintenance Cost (O&M) The O&M of the project are also assumed to be the percentage of the capital cost as used in the economic analysis. c) Cost of Energv Supply The purchasing price between EGAT and IPP is assumed as a cost of supplying electric energy of both IPP and EGATs coal-fired power plants. Since the real purchasing price is still unknown at the time of the study, the forecasted purchasing price is adopted from EGATs financial projection which are conducted based on EGATs PDP 95-01 for the period of 1995-2001. The levelized nominal purchasing price (current value) at Year 2001 is 1.6040 TUB/kWh. Benefit Stream The assumptions used for the calculation of benefit stream are: Aooroach I The benefit is assumed to be the incremental economic benefit of the country due to the reduction of expected load losses which may occurred if the proposed project is not implemented. The Expected Unserved Energy (EUE) is used to represent these losses and the cost of an outage of 58.87 THB/kWh is used to calculate the monetary value of these losses. -51- Approach 2 The benefit is assumed to be the incremental energy sale made available to EGAT by this project. The calculation of the benefit is based on the assumptions as follows: a) Incremental Energv Sale The value of the incremental energy sale is calculated from the energy produced by the IPP reduced by the losses in transmission system. The losses are represented in term of energy loss occurring between the sending end and the receiving end of the proposed transmission line. The energy loss (GWh) is calculated from the capacity loss (adopted from the power flow study) and IPP's plant factor as follows: Energy Loss (GWh) = Capacity Loss (MW) x 8.76 x Plant Factor b) Averaze Sellinz Price The EGAT average selling price is adopted from EGATs financial analysis of the Year 2001 which is adjusted to conform with all of the required financial criteria. 7.1.2 Sensitivitv Study Due to the uncertainty of the purchasing price from IPP, EGATs average selling price and other economic paramneters of the project, the sensitivity studies of EIRR study based on the variation the project's vital economic parameters are also conducted to examine the effect of these variations to the EIRR of the project. The sensitivity study is calculated according to the variation of the economic parameters as follows: - The purchasing price from IPP. - The EGAT's average selling price. - Capital investment cost of the project. - Expected unserved energy. -52- 7.1.3 Results of the EIRR Study The results of the base case and sensitivity study can be summarized as follows: a) Base Case EIRR (%) - Approach 1 107.01 - Approach 2 22.63 b) Sensitivity Studv A_Mroach I EIRR (%/6) - Purchasing Price -Increased by 10 % 106.95 - Increased by 20 % 106.89 - Increased by 30 % 106.84 - Capital Cost - Increased by IO % 104.62 - Increased by 20 % 102.47 - Increased by 30 % 100.52 - EpxDected Unserved Enersv - Decreased by 10 % 104.37 - Decreased by 20 % 101.47 - Decreased by 30 % 98.26 Approach 2 - Purchasing Price - Increased by 5 % 16.78 - Increased by 10 % 7.55 -53- EIRR (%) - Capital Cost - Increa-ed lw 10 % :21.42 - Increased by 20 % 20.35 - Increased by 30 % 19.39 - Average Selling Price - Decreased by 5 % 15.86 - Decreased by 10 % 3.50 It can be concluded from the results of the base case calculation of EIRR that the project is economically feasible and the sensitivity studies indicate that for Approach 1, the EIRR is not sensitive to the tested variation but for Approach 2, the EIRR is sensitive to the increment of the purchasing price and the decreasing of EGAT's average selling price. Details of the base case calculation of EIRR of the two approaches are shown Table 7.2 and 7.3. -54- Table 7. IPP and EGATs Power Project Planned to be Transmitted via the Proposed 500 kV Transmission System Power Plant Fuel Unit Rating Cumulative Commissioning Type Number (MW) Capacity Date *_____ ___ :___ ___ (MW) IPP - - 1,400 1,400 April 2001 IPP - - 1,400 2,800 April 2002 IPP - - 1,000 3,800 January 2003 IPP - - 1,000 4,800 January 2004 IPP - - 1,000 5,800 January 2005 New Thermal Coal 1 i1,000u 6,800 Arii 2005 IPP -- 1,000 7,800 January 2006 New Thermal Coal 2 1,000 8,800 April 2006 IPP - - 1,000 9,800 January 2007 New Thernal - 3 1,000 10,800 April 2007 IPP - - 1,000 11,800 January 2008 New Thermal Coal 4 1,000 12,800 April 2008 IPP - - 1,000 13,800 January 2009 New Thermal Coal 5 1,000 14,800 April 2009 -s5 - Table 7.2 Calculation of EIRR of 500 kV Transmission System for IPP (Approach 1) unil: MTHS Fiscal al_ _ Cost Stream ... b/ Benefit Stream Net Year Capita Cost O&M Cost Supplied Purchasing Price Cost Total Expected Jnserved En rgy (GWh) Cost of Project Benefit Lire Substation Line Substation Energy (THB,l of Cost W/O 500 kV Wth 500 kV EUE Outages Benefit (GWh) Current 1995 Supply Transmission Transmission Reduction (THB/k'Wh) ____ _____ ______ _______ Price Price _ roject o/ Prope,t cl 1995 1996 19.4 330.0 - 349.4 -349.4 1997 368.0 _- - 368.0 -368.0 1998 4195.1 70.1 _ - 4265.2 -4265.2 1999 8681.6 1875.8 _ - 10557.4 -10557.4 2000 3099.6 3105.9 - d/ - 6205.5 -6205.5 2001 823.3 524.7 171.9 1182 1.5 1.6040 1.2677 2.0 1640.1 1.55 _ 1.5 5s.87 91.1 -1549.0 2002 - - 171.9 118.2 19.3 1.6040 1.2677 24.5 314.6 19.32 19.3 55.87 1137.3 822.7 2003 171.9 118.2 534.1 1.6040 1.2677 677.1 967.2 534.12 534.1 55.87 31443.4 30476.2 2004 171.9 118.2 1238.9 1.6040 1.2677 1570.5 1860.6 1238.86 1238.9 53.87 72931.7 71071.1 2005 171.9 118.2 7303.3 1.6040 1.2677i 9258.1 9548.2 7303.27 7303.3 53.87 429943.6 420395.4 u' 2006 171.9 1182 17352.8 1.6040 1.2677 21997.5 22287.6 17352.75 17352.8 53.87 1021556.4 999268.8 ' 2007 i 171.9 1182 24934.0 1.6040 1.2677 31607.9 31698.0 24933.981 24934.0 53.87 1467863.6 1435965.6 2008 ! 171.9 1182 40631.0 1.6040, 1.26771 51506.41 51796.5 40630.98 I 40631.01 513.87 2391945.5 2340149.0 20091 171.9 1182 54067.7 1.60401 1.2677 68539.7; 68529.5 54067.72 54067.71 513.87 3182966.9 3114137.1 2010\ 17i.9 11152 W202o 1 .5040 1 .267 81156.2 81446.3 64020.24 6402021 5!3.87 3768871.5 3687425.2 2011 i 171.91 1182 734s.020 1.60401 1.2677 93148.0 93438.1 73480.00 273480.0! 3.87 4325767.8 4232329.7 2012 1 171.91 118.2 73480.0 1.60401 1.2677 93148.01 93438.1 73480.00 73480.0'1 53.87 4325767.8 4232329.7 2013 171.9 118.2 73480.0 1.6040 1.2677 93148.01 93438.1 73480.00 73480.0 583.87 4325767.8 4232329.7 2014 | 171.9 1182 73480.0 1.6040 1.2677 93148.01 93438.1 73480.00 m 73480.0 583.87 4325767.8 4232329.7 2015 171.9 1182 73480.0 1.6040 1.2677 93148.0 93438.1 73480.00 j 1 7348.00 58.87 4325767.8 4232329.7 2016 171.9 118.2 73480.0 1.6040 1.2677 93148.0 93438.1 73480.00 73480.0 593.87 4325767.8 4232329.7 2017 171.9 118.2 73480.0 1.6040 1.2677 93148.0 93438.1 73480.00 73480.0 513.87 4325767.8 4232329.7 2018 171.9 1182 73480.0 1.6040 1.2677 93148.0 93438.1 73480.00 73480.0 s53.87 4325767.8 4232329.7 2019 171.9 1182 73480.0 1.6040 1.2677 93148.0 93438.1 73480.00 73480.0 513.87 4325767.8 4232329.7 2020 171.9 118.2 73480.0 1.6040 1.2677 93148.0 93438.1 73480.00 73480.0 513.87 4325767.8 4232329.7 2021 171.9 1182 73480.0 1.6040 1.2677 93148.0 93438.1 73480.00 73480.0 513.87 4325767.8 4232329.7 2022 171.9 118.2 73480.0 1.6040 1.2677 93148.0 93438.1 73480.00 73480.0 513.87 4325767.8 4232329.7 2022 171.9 1182 73480.0 1.6040 1.2677 93148.0 93438.1 73480.00 73480.0 513.87 4325767.8 4232329.7 2024 171.9 1182 73480.0 1.6040 1.2677 93148.0 93438.1 73480.00 73480.0 563.87 4325767.8 4232329.7 2025 -6445.1 _ 171.9 1182 73480.0 1.6040 1.2677 93148.0 86993.0 73480.00 73480.0 513.87 4325767.8 4238774. Total 10741 .! 5906.5 4297.5 2955.0 _- _ - t6e3559.71 1687460J3 I - - 77255268.0 755678072 Economic Internal Rate of Return = 107.01% Notes: a/ Capital investment cost of western and eastem 500 kV transmission system for IPP. Transmission System Phnnng Oivision bf Probabilistic unserved energy calculated by using WIGPLAN . 30-Jan-9g6 J/ Adopted from 'Cost of an Outage Study, by EGAT's System Planning Department (October 1992). 41 Adoptecl from EGAT's Financial Projection (1 995-2001) and assumed to be constant alter 2001. 2/ Incremental EUE. Table 7.3 Calculation of EIRR of 500 kV Transmission System for IPP (Approach 2) Fiscal Cost _S_r_e Unit :MIHB Fiscal __________ Cosit Stream ______ Benefit Stream Noet Yewt Can 1 Cost O&M Cost Cost of Energy Supply Total Poweor Energy Energy Average SelOing Price Revenue Benefit Uine Substailotn Une Substation Planned Plnned PurchasIng Price Cost C t Loss Loss Sale (IHB*WhI Power Energy (THB/ kWh) of : ;; U(MW) (GWh) (GWh) Current 1995 Purchase Purchase Currert 1995 Supply PHice Price W (SHlh) Price P.e ' _ :' _ :___ 1995 _ _ 1996 19.4 330.0 349.4 _ -3494 1997 368.0 _ 368.0 -358.0 1998 4195.1 70.1 4265.2 _ -4265.2 1999 8681.6 1875.8 10557.4 -410557.4 2000 3039.6 9105.9 1 1 6205.5 _ - -6205.5 2001 823.3 524.7 171.9 118.2 1400 4600.0 1.6040 1.2677 5831.3 7469.4 8.4 589 4541.1 1.8478 1.4603 6631.6 -837.8 2002 - - 171.9 118.2 2800 13800.0 1.6040 1.2677 17493.8 17783.9 32.4 227.1 13572.9 1.8478 1.4603 19821.2 2037.3 2003 171.9 118.2 3800 23330.0 1.6040 1.2677 29574.6 29864.7 58.0 406.5 22923.5 1.8478 1.4603 33476.2 3611.5 2004 171.9 11 82 4800 29900.0 1.6040 1.2677 37903.2 38193.3 95.0 665.8 29234.2 1.8478 1.4603 42692.0 4498.71 20051 171.9 118.2 6800 39755.0 1.6040 1.2677 50396.0 50688.1 134.6 943.3 38811.7 1.8478 1.4603 56678.4 5992.31 1 20066 i e t171.9 118.2, 8800 52895.0 1.6040 1.2677 67053.1 67343.2 243 1t698.3 5t196.7! 1.8478' 1:4603 74764.8; 7421.6 20071 I 171.9 118.2 10800 66035.0 1.6040 1.2677: 83710.2' 84000.3 242.3 1698.3 64336.71 1.84781 1.4603 93953.7 9953.4 2008i 171.91 118.2| 12800 79175.0 1.60401 1.26771 100367.3 100657.4 242.31 1698.31 77476.7 1.8478', 1.4603 113142.6. 12485.2' 20091 171.9! 118.2, 14800 92315.0! 1.60401 1 2677 ! 117024.4 117314.5 242.3! 1698,31 90616.7, 1.8478' 1.4603 132331.5 15017.0! 2010, 171.91 118.21 148D0 97240.01 1.50401 1.2677 123267.7, 12S557.8 242.3 1698.3, 95541.7: 1.8478j 1.4603 139523.7 15965.91 20111 17191 118.21 14800 97240.01 1.6040i 1.2677, 123267.71 123557.8 242.3| 1698.3, 95541.7 I 1.84781 1.4603 139523.7 15965.9 2012 171.91 118.2j 14800 97240.0 1.60401 1.2677' 123267.71 123557.8 242.3 1698.3 95541.7 1.84781 1.4603 139523.7 1596591 2013 171.91 118.2 14800 97240.0 1.6040 1.2677 123267.7 123557.8 242.3 1698.31 95541.7 1.84781 1.4603 139523.7 15965.9 2014 171.9 118.2 14800 97240.0 1.6040 1.2677 123267.7 123557.8 242.3 1698.3 95541.7 1.8478 1.4603 139523.7 15965.91 2015 171.9 118.2 14800 97240.0 1.6040 1.2677 123267.7 123557.8 242.3 1698.3 95541.7 1.8478 1.4603 139523.7 15965.9 2016 171.9 1182 14800 97240.0 1.8040 1.2677 123267.7'| 123557.8 242.3 1698.3 95541.7 1.8478 1.4603 139523.7 15965.9 2017 171.9 118.2 14800 97240.0 1.6040 1.2677 123267.;' 123557.8 242.3 1698.3 95541.7 1.8478 1.4603 139523.7 15965.9 2018 171.9 11&2 148O0 97240.0 1.6040 1.2677 123267.7 123557.8 242.3 1698.3 95541.7 1.8478 1.4603 139523.7 15965.9 2019 171.9 118.2 14800 97240.0 1.6040 1.2677 123267.7 123557.8 242.3 1698.3 95541.7 1.8478 1.4603 139523.7 15965.9 2020 171.9 118.2 14800 97240.0 1.6040 1.2677 123267.7 123557.8 242.3 1698.3 95541.7 1.8478 1.4603 139523.7 15965.9 2021 171.9 1182 14800 97240.0 1.6040 1.2677 123267.7 123557.8 242.3 1696.3 95541.7 1.8478 1,4603 139523.7 15965.9 2022 171.9 118.2 14800 97240.0 1.6040 1.2677 123267.7 123557.8 242.3 1698.3 95541.7 1.8478 1.4603 139523.7 159659 2023 171.9 118.2 14800 97240.0 1.6040 1.2677 123267.7 t23557.8 242.3 1698.3 95541.7 1.8478 1.4603 139523.7 15965.9 2024 171.9 118.2 14800 97240.0 1.6040 1.2677 123267.7 123557.8 242.3 1698.3 95541.7 1.8478 1.4603 139523.7 15965.9 2025 -6445.1 - 171.9 118.2I 14800 97240.0 1.60401 1.26771 123267.71 117112.7 242.3 1698.3 95541.7 1.8478 1.4603 139523.7 22411.0 Total 10741.9 5906.51 4297.51 2956.0 - - - - | 248163711 2505538.0 --- | 28058711.2 300333.21 Economic Internal Rate of Retum = 22.63 _J Noe: al Adopted from EGAr5 Financial Projection (1995- 200t) and assumed to be constant after 2co1. Traismission Sys:em Planning Drvs,on 30-Jan- 96 7.2 Financial Internal Rate of Retum Study (FIRR) Apart from the intemal rate of return study based on the country's point of view, the intemal rate of return of the project based on EGAT's point of view is also conducted to evaluate the financial viability of this project. According to the purpose of the project as previously mentioned, the 500 kV transmission system project is proposed to transmit the bulk power to EGATs load center which is resulting in the increment of EGAT's energy sale. So the financial intemal rate of return (FIRR) which is EGAT's rate of return from this project is made by comparing the total cost of the project with the benefit from the incremental revenue. 7.2.1 Basic Assumptions The financial intemal rate of return study is performed based on the assumptions similar to the Approach 2 of the EIRR study. But all costs are based on their current values including import duties and taxes, interest during construction (IDC). 7.2.2 Sensitivity Study The sensitivity study of the FIRR study is also conducted as done for the EIRR study of which the assumptions are: - The purchasing price from IPP is assumed to be increased by 5 and 10%. - The EGATs average selling price is assumed to be decreased by 5 and 10%. -58- 7.2.3 Results of the FIRR Study The results of the base case and sensitivity study can be summarized as follows FIRR (%) a) Base Case 22.23 b) Sensitivity Study - Purchasing Price - Increased by 5 % 16.41 - Increased by 10 % 7.25 - Capital Cost - Increased by 10 2!.03 - Increased by 20 %XO 19.96 - Increased by 30 % 19,00 - Average Selling Price - Decreased by 5 % 15.50 - Decreased by 1 0 3.24 It can be noticed from the results of the base case calculation of FIRR that the project can generate the internal rate of return to EGATs acceptable level while the sensitivity study shows that the FIRR is not sensitive to the change of project's investment cost but sensitive to the variation of the purchasing price and average selling price since the 10 % variation of these values can make the FIRR dropped below EGAT's acceptable level. Details of the base case calculation of the FJRR is shown in Table 7.4. 59- Table 7.4 Calculation of FIRR of 500 kV Transmission System for IPP L)r,_t M rH13 Fiscal Cost Stream -Benefit Stream Net Year Capi1al Cost O&M Cost Cost of Energy SuPPlY Total Power Energy Energy Average Sellirng Price Revenue Benefit Une Substation Line Substatbon Planned Planned Purchasing Price Cost cost Loss Loss Sale _CB/1W1 Power Energy (THB/kWh) of (MW) (GWh) (GWh) Current 1995 Purchase Purchase Current 1995 Supply Price Price ______ ________ ) (GWh) Price Price _________ ._______ ________ ________ ___G__e_ _ __ __ 1995 - - _ _ 1996 44.1 366.6 410.;r - -410.7 1997 424.7 1 38.8 463.5 -463.5 1998 4852.4 120.0 4972.4 _ - 4972.4 1999 11444.7 2352.7 13797.4 _ - -13797,4 2000 4938.2 4228.2 o/ 9166.4. _ - -9166.4 2001 1055.4 604.2 227.6 154.2 1400 4600.0 1.6040 1.2677 7378.4 9419.8 8.4 58.9 4541.1 1.8478 1.4603 8391.1 1028.7 2002 - - 227.6 154.2 2800 13800.0 1.6040 1.2677 22135.2 22517.0 32.4 227.,1 13572.9 1.8478 1.4603 25080.1 2563 1 2003 227.6 154.2 3800 23330.0 1.6040 1.2677 37421.3 37803.1 58.0 406.5 22923.5 1.8478 1.4603 42358.1 4555.0 2004 227.6 154.2 4800 29900.0 1.6040 1.2677 47959.6 48341.4 95.0 665.8 29234.2 1.8478 1 .4603 54019 0 5677 6 2005 227.6 154.2 6800 39755.0 1.6040 1.2677 63767.0 64148.8 134.6 943.3 38811 7 1.8478 1.4603 71716.31 7567.5 2006 227.6 154.2 8800 52895.0 , 1.6040 1.2677 84843.6 85225.4 242.3 1698.3 51196.7 . 1.8478 1.4603 94601.3 9375.9 2007 227.6 154.2 10800 66035.01 1.6040 1.2677| 105920 1 106301.9 242.3 1698.3 64336.7 1.8478 1.4603 1118881.41 12579.4 2008| ! 227.6 154.2 12800 79175.0| 1.6040 1.2677 126996.7| 127378.5 2423 16983 77476.7 1.84781 1.4603 143161.4 15782.9 2009 ! 6 227.6 154.2 14800 92315.01 1.6040 1.2677 148073.31 148455.1 242.3| 1698.3 90616.7 A.84781 t.4603 167441.5 18986.5 2010 227.61 154.2| 14800 97240.01 1.6040 1.2677 155973.01 156354.8 242.31 1698.3 95541.7 1.8478 1.4603 176542.01 20187.2 2011 227.6 154.2 14800 97240.01 1.6040 1.2677, 155973.01 156354.8 242.31 1698.3 95541.7! 1.8478 1.4603 176542.0 201872 2012 227.6 154.2 14800 97240.0) 1.6040 1.26771 155973.0 156354.8 242.31 1698.3 95541.71 1.84781 1.4603 176542.0 20187.2 2013 i 227.6 154.2 14800 97240.0 1.6040 1.2677 155973.0! 156354.8 242.3j 1698.3 95541.7 1.8478j 1.4603 176542.01 20187.2; 2014 227.6 154.2 14800 97240.0 1.6040 1.2677 155973.0| 156354.8 242.3' 1698.3 95541.7 1.84781 1.4603 176542.01 2018721 2015 227.6 154.2 14800 97240.0 1.6040 1.2677 155973.0 156354.8 242.31 1698.3 95541.7 1.8478, 1,4603 176542.0| 201872 2016 227.6 154.2 14800 97240.0 1.6040 i.2677 155973.01 156354.8 242.3 1698.3 95541.7 1.8478 1.4603 176542.0 20187.2 2017 227.6 154.2 14800 97240.0 1.6040 1.2677 155973.0 156354.8 242.3 1698.3 95541.7 1.8478 1.4603 176542.0 20187.2 2018 227.6 154.2 ,14800 97240.0 1.6040 1.26771 155973.0 156354.8 242.3 1698.3 95541.7 1.8478 1 4603 176542.0 | 20187 2 2019 227.6 154.2 14800 97240.0 1.6040 1.2677 155973.0 156354.8 242.3 1698.3 95541.7 1.8478 1 4603 176542.0 20187.2 2020 227.6 154.2 14800 97240.0 1.6040 1.2677| 155973.0 156354.8 242.3 1698.3 95541.7 1.8478 1.4603 176542.0 20187.21 2021 227.6 154.2 14800 97240.0 1.6040 1.2677 155973.0 156354.8 242.3 1698.3 95541.7 1.8478 1.4603 176542.0 20187 2 | 2022| l l 227.6 154.2 14800 97240.0 1.6040 1.2677 155973.01 156354.8 242.3 1698.3l 95541.7 1.8478 1.4603 176542.0 20187.2 2023 227.6 154.2 14800 97240.0 1.6040 1.2677 155973.01 156354.8 242.3 1698.31 95541.7 1.8478 1.4603 176542.0, 201872 2024 227.6 154.2 14800 97240.0 1.6040 1.2677 1559730 156354.8 242.3 1698.3 95541.7 1.8478 1.4603| 176542.0 201872 2025 -8534.8 - 227.6 154.2 14800 97240.0 1.6040 1.2677 155973.0 147819.9 242.31 1698.3 95541.7 1.8478 1.4603 176542.0 28722.0 Total 14224.| 7710.5 5690.0 3855.0 - - - - 3140062.63175428 -j- - L -- 3550321 Sl 378778.8t Financial Internal Rate of Return = 22.23% _ Note a/ Adopted from EGAT's FRnancial Projection (1995-2001) and assumed to be constant after 2001. Irarism,ss,on SysternPOrrnngDv,s,on G7 - Dr - 99 8. SHUNT REACTOR SIZING 8.1 Objective and Method of Study Two shunt reactors of equal magnitude are installed at each end of an extra high- voltage transmission line to compensate for the Ferranti Effect. Ferranti Effect is a phenomenon that the voltage at the receiving end of a long open-ended uncompensated transmission line is higher than at the sending end for the steady-state condition. The receiving-end voltage, VREc, can be roughly calculated by the following expression VREC VSENDJCOS where e is the line length and j is the phase factor, which is equal to approximately 7.20/100 km. The longer the transmission line is, the higher the Ferranti Effect becomes. In the study, the size of the shunt reactor to be installeu at each end of the transmission line is varied from 0-300 MVAr. The installation of shunt reactors has been considered for the transmission lines which are longer than 150 km since the Ferranti Effect on a shorter line is found to be nonsignificant. Shunt reactors can also reduce the overvoltage during energization of transmission lines but the amount of surge reduction is small compared to other more practical counter-measures. The study has been conducted with the computer software developed by Manitoba HVDC Research Center. The use of the software is under a trial agreement between Manitoba HVDC Research Center and EGAT. 8.2 Results of Studv The shunt reactor sizing study has been conducted for four 500 kV transmission lines as follows: 1) Bang Saphan - Chom Bung 2) Wang Noi - Chom Bung -61- 3) Rayong 4 - Wang Noi 4) Rayong 4 - Nong Chok The overvoltage during line energization of the Bang Saphan - Chom Bung has been found to be 1.046 p.u. For the other 3 lines, the overvoltages are less than 3 % Nontheless, if shunt reactors were to be installed to compensate for the Ferranti Effect, the following are the reactors which would reduce the receiving end voltages to 1.0 p.u. 1) 150 MVAr/phase for Bang Saphan - Chom Bung lines 2) 100 MVAr/phase for Wang Noi - Chom Bung lines 3) 105 MVAr/phase line Rayong 4 - Wang Noi lines 4) 82.5 MVAr/phase line Ravong 4 - Nong Chok lines The results of the reactor sizing study are shown in Figure 8.1 to Figure 8.4. Samples of the switching transients for the Bang Saphan - Chom Bung lines are also shown in Figure 8.5 to Figure 8.7. -62- FIGURE 8.1 REACTOR SIZING FOR BANG SAPAN - CHOM BUNG LINES (280 KM) 1.05 1.04 g 1.03 _ | 1.02 0\ 1.01 o 0.99 0.98 . . . ........... ~0.97 0.96 ,150 MVAR 0.95 I , I I I 0 50 100 150 200 250 300 350 REACTOR SIZE (MVAR) -63- FIGURE 8.2 REACTOR SIZING FOR WANG NOI - CHOM BUNG LINES (192 KM) 1.051 1.04 1.03 1.02 1.01 ZF- 0.99 00.98 O0.97 0.96 100 MVAR 0.95 I i I I I I 0 50 100 150 200 250 300 350 REACrOR SIZE (MVAR) -64- FIGURE 8.3 REACrOR SIZING FOR RAYONG 4 - WANG NOI LINES (210 KM) 1.05 1.04 1.03 1.02 Q \ 0 1.01_ . .. X... . .......... o0.99 00.98 0.97 0.96 -105 MVAR 0.95 I I l l 0 50 100 150 200 250 300 350 REACTOR SIZE (MVAR) -65- FIGURE 8.4 REACTOR SIZING FOR RAYONG 4- NONG CHOK UNES (172 KM) * 1.05I 1.04 1.03 | 1.02 1.01 0.99 0 0.98 0.97 0.96 :82.5 MVAR 0.95 I I I i I I 0 50 100 150 200 250 300 350 REACTOR SIZE (MVAR) -66- o Voltage at Bang Saphan Phase A (tanient) o Voltage t BaU Saphan Phae A (stady tate) 2.5 2. 1.5 -..____.. _._ __.___.__._.-_ ...-.-.--.-....g.__.___. ..... ___._. -- ---- ------ …---- 0.5;F ~ ~ -_ _ __. _ _ _ _ . _ _ . 0 o a !7... -. . - ---- 0.5 . .____ ** *f------- -2 -_ . --------t----.---- - - - -- __.. -2.5 1 480 500 520 540 560 Time (sec) xio3 O Voltage at Bang Sapban Phae B (transient) 0 Voltage at Bang Sapbhn Phasw 3 (shady state) 2.5 - 2 ------ _ _ -1--..---..-.- ........ . .......----- -1.5 _ ___--- ------- - --- - ~ ---,,, ------__ AIA~~~~~~~~~~~~ > 1 ,,___.4..___~~~~~~~~~~~~~~~~~~--- - --- *----t,t5 0 -0OI o --M-- -M---q- -+-e-f- ° ..2 .L ......-------- - ------ … 480 SOO 520 540 SO Time (sec) x104 Ol Voltage at Bang Saphan Pbhe C (tansient) 0 Volta at Bang Sapban Pae C (shdy state) 2.5 - 2 … . …____---------.. t --1 - - --------- An------ .5 0.5 o-… -A ---, …-... _. -_ 0 -1.5 …--- -- - --------- . -0.--…-2---. -----.….--- . -2.5 480 500 520 540 560 Time (sec) x104 Pigure 8.5 Energization of Chom Bung- Bang Saphan Lines (wf 150 MVAr Reactors) (Energize from Cbom Bung) -67- 0 Voltage at Chom Bung Phase A (transient) 0 Voltage at CBG Phase A (steady ste) 2.5 > -1_ _~_ ___________ ;_. _ ..-.-..----.--- .-.~.-................................................. .. ........ ............. -1 .5 ........-... ...-. .................... ; 0 5 --- - - -- - -s- t-t- -...-........... --- - - --- ---- - -- - - --- 2 - ---2 ..--* -----...-...- ________.__-__ -_______ -2.5 - 480 soo 520 540 560 Time (sec) X104 O Voltage at Chom BURn Pbae B (ti.nent) a Voltage at CRC P B a(smlY Ate) 2.5 2 --.- -.-.---..-....-.. .- .. ..... ....... .-.- - - - 1.5 -.-. . _... ........... .............. . .. ........... -1 O . . ...... ...... _ ..__..._ . _ _ ...... _._.- ; -1 -. -----.--. ------ -. ._.... .... _.._.____....----------------- - ------ - _. -12 ........... ............... ... .... . ..... . -2.5 480 500 520 540 560 Time (sec) x104 * 1 O Voltage at Chom Bung Phase C (transient) 0 Voltage at CBG Phase C (stedy stae) 2.5 1 2 ....................... .......................... ..... ..... . -- 1 0.5 . _ _ .-. ....… . __........…. _ .\ 1 -. ..- ....~~~~~~~~~~~~~~~~~...............--- '-15 _ __ _ _............ ...._ _ _ _______ _ _ 0 -2 --- ----------------- -2.5 . . . . . 480 500 520 540 560 Time (sec) x2103 Figure 8.6 Energization of Chom Bung - Bang Saphan Lines (w/ 150 MVAr Reactors) (Energize from Bang Saphan) -68- 0 Voltage at Bang Saphan (with reactors) 0 Voltage at Bang Sapban (wio react) 2.5 T 2 --- -________ _.._ ....4... .. 10.5 .._.__._.______ r- 6g-.A _@..4 .~..__J_.-_ . 415 *--..- -= -- -. .-.-.-- ------- -- - 0.5 *.. o 2 - - ._ __ ----.----- . .-------.. _ -2.5 J I 480 500 520 640 50 Time (sec) x104 O Voltage at Bang Sapban (with reactor) 0 Voltage t Bang Sphan (wlo reactorv) 2.5 1.56 - -, 1.5 *--. Phse-- .-V--.--.------- --- I.s _ Phj... B .. ........- ............ ..___.__ 480 500 520 540 560 Time (icc) xlO' O Voltage atBang Saphan (with reactors) 0 Voltage at Bang Saphan (w/o racton) 2.5 2 - -- Ph0 e-C ................... .. 1.5 - --------- - --- -I 0 .5 _ _ . _. ...._.__.--F''---t-'t---f _ 0- -o-2- ----t------.- -- -2 _. ....._.__. __._.__.._.____...........~....._.__.._______._…_ -2.5 480 soo 520 540 560 Time (sec) X103 Figure 8.7 Comparison of Overvoltage for Chom Bung - Bang Saphan Lines (Energize from Chom Bung) -69- REFERENCES 1. EGAT's System Planning Department. EGAT Power DeveloDment Plan (PDP 95-01). Report No.21200-3802, April, 1995. 2. Black & Veatch International Company. Feasibility Study for Transmissiion System Development for Southern Power Plant Proiect, July, 1994. -70- APPENDIX I SUBSTATION LOAD FORECAST -71- I I ADDendix I Page 1 Substation Load Forecast of Metropolitan Area COINCIDENT ____________________ UNIT: MW ACT1AL . FTORECAST SUBSTATION 1994 1997 1998 1999 2001 2006 2011 (25. (2540) (2541) (2542) (2544) (2549) (2554) BANG KAPI 69 KV 617.40 565.03 543.34 570.11 599.06 724.31 763.74 BANG KAPI 230 KV (CL) 421.80 348.21 345.25 355.43 387.49 282.51 270.50 BANG KAPI 230 KV (KT) 0.00 0.00 0.00 0.00 377.41 629.52 666.80 BANG PHLI 69 KV 301.00 175.55 197.01 202.83 213.55 321.22 358.09 BANG PHLI 115 KV 331.70 509.31 394.78 368.97 424.06 342.09 359.13 BANGKOK NOI 69 KV 415.60 355.26 417.23 428.96 475.12 395.17 440.52 BANGKOK NOI 115 KV 0.00 50.85 50.93 66.97 97.70 303.08 342.72 CHAENG WATTANA 115 KV 0.00 249.35 340.60 463.98 670.74 656.61 720.73 LAT PHRAO 69 KV 574.00 536.86 605.01 606.01 420.13 714.04 730.80 NONG CHOK 115 KV i77.60 212.58 188.80 208.20 269.72 334.43 450.58 NORTH BANGKOK 69 KV 391.851 494.67 502.39 558.26 548.94 498.65 534.40 NORTH BANGKOK 2.30 KV 0.M 0.00 0.00 0.00 0.00 510.72 1,025.00 ON-NUCH 230 KV 0.00 0.00 178.84 247.02 296.83 544.74 804.32 ON-NUCH 230 KV (PK) 0.00 0.00 0.00 0.00 0.00 0.00 679.38 RANGSIT 69 KV 205.70 275.45 282.02 264.45 209.87 368.51 367.11 RANGSIT 115 KV 92.90 136.20 137.66 177.44 259.22 275.81 285.26 RATCHADA PHISEK 69 KV 0.00 354.65 365.99 394.85 355.67 346.67 359.80 RATCHADA PHISEK 115 KV 0.00 0.00 0.00 0.00 0.00 115.88 313.06 SAI NOI 115 KV 0.00 25.29 27.53 28.32 131.32 306.77 341.97 SOUTH BANGKOK 69 KV 620.20 495.82 517.92 528.50 607.02 630.86 703.27 SOUTH BANGKOK 115 KV 269.60 262.20 198.49 187.66 244.72 196.98 164.05 SOUTH THONBURI 69 KV 335.40 374.52 372.60 405.07 462.68 463.60 455.63 SOUTH THONBURI 230 KV 0.00 446.66 549.56 608.43 726.32 1,088.94 1,553.44 TEPARAK 69 KV 0.00 180.77 205.33 221.07 207.16 256.28 351.78 TEPARAK 115 KV 0.00 155.86 248.52 281.50 305.32 335.42 373.92 TOTAL 4,754.75 6,205.09| 6,669.80 7,174.03 8,290.05 10,642.81 13,416.00 -73- AmDend ix 1 Page 2 Substation Load Forecast of Central Area NON- COINCIDENT UNIT: MW _______________ ______________ _ __ _ _ __ __, _ _ _ _ _ _ ( 5 ) (2 4 ) _ _ _ ACTUAL FORECAST SUBSTATION 1994 1997 1 1998 1999 2001 2006 2011 (2537) Aqi4p 4 2541 (2.S42) (54 (2549) (2554l ANGTHONG 1 14.31 14.63 14.75 14.89 15.19 16.21 17.68 ANGTHONG 1 (69 KV) 0.00 10.20 10.20 10.20 10.20 10.20 10.20 ANGTHONG 2 25.69 38.80 42.72 46.79 55.44 80.22 112.36 AYUTTHAYA 1 53.76 38.80 42.56 46.59 55.46 82.81 118.22 AYUTTHAYA 2 13.38 18.52 20.32 22.24 26.47 39.53 56.42 BANG PA-IN 1 39.12 44.36 48.57 53.03 62.79 92.74 132.04 BANG PA-IN 1 (115 KV) 25.49 36.68 40.50 44.44 52.88 77.81 105.49 BANG PA-IN 2 178.40 327.14 355.60 381.54 435.69 581.82 744.03 CHAIBADAN 24.48 16.10 17.46 18.75 21.19 27.02 33.59 DOEMBANG NANGBUAT 21.58 32.93 35.26 37.69 42.92 58.66 79.50 LOP BURI 1 36.70 29.80 31.93 34.13 38.73 51.86 68.37 LOP BURI 2 19.03 28.44 30.47 32.56 36.96 49.49 65.25 LOP BURI 2 (115 KV) 0.00 12.20 13.75 15.30 15.30 15.30 15.30 NAKHON NAYOK 24.58 19.74 21.49 23.31 27.21 38.77 53.42 PHRAPHUTTHABAT 36.10 50.52 56.07 61.78 73.68 107.39 152.17 RANGSIT (69 KV) 213.46 264.08 286.05 307.95 353.07 491.36 679.59 RANGSIT (115 KV) 219.74 264.08 286.05 307.95 353.07 491.36 679.59 SAI NOI (115 KV) 0.00 55.58 59.97 64.63 74.86 106.99 151.58 SARABURI 1 44.40 52.57 .57.15 61.96 72.51 105.86 152.82 SARABURI 2 35.85 25.53 27.93 30.44 35.88 52.58 75.75 SARABURI 2 (115 KV) 179.23 255.29 298.11 331.84 361.74 370.26 382.33 SARABURI 3 96.06 95.00 95.00 95.00 95.00 95.00 95.00 SARABURI 4 35.96 63.62 68.28 73.25 84.23 118.95 168.00 SARABURI 4 (115 KV) 11.82 18.30 18.30 18.30 18.30 18.30 18.30 SINGBURI 33.50 33.95 36.47 39.04 44.26 58.84 77.11 SINGBURI (115 KV) 0.00 16.00 16.00 16.00 16.00 16.00 16.00 SUPHAN BURI 43.88 31.12 33.84 36.72 43.04 62.79 90.17 THALAN 1 26.38 35.79 37.53 39.34 43.18 .54.11 67.10 THALAN 1 (115 KV) 95.94 10.10 10.10 10.10 10.10 10.10 10.10 THALAN 3 (115 KV) 0.00 263.03 276.70 289.35 312.96 372.82 436.46 THALAN I (CEMENT) 57.82 60.00 60.00 60.00 60.00 60.00 60.00 THALAN 2 (STEEL) 53.36 115.00 115.00 115.00 115.00 115.00 115.00 PHACHI (VOA) 2.45 2.50 2.50 2.50 2.50 2.50 2.50 TOTAL 1,662.47 2,380.40 2,566.63 2,742.61 3,065.81 3,932.65 5,041-44 -74- Ap2end i x 1 Page 3 Substation Load Forecast of Eastern Area NON- COINCIDENT UNIT: MW ACTUAL FORECAST SUBSTATION 1994 . 1997 1998 1999 2001 2006 2011 _2537) _ (2540) (2541) (2542) (2544) (2549) (2554) AO PHAI 29.35 12.40 13.35 14.36 16.67 23.88 33.83 AO PHAI (115 KV) 53.60 173.26 187.85 199.94 226.27 305.79 412.61 BAN BUNG 49.62 58.01 65.07 72.53 88.95 139.99 207.15 BAN BUNG (l15KV) 0.00 21.87 27.98 29.86 29.86 29.86 29.86 BANG LAMUNG 55.69 66.21 71.78 77.68 90.55 130.41 185.27 BANG LAMUNG (115 KV) 28.27 43.69 47.36 51.25 59.75 86.05 122.25 BOWIN (115 KV) 64.20 169.70 181.61 192.22 209.84 256.97 291.77 CHACHOENGSAO 98.84 62.28 68.3 74.41 87.64 127.83 181.74 CHACHOENGSAO (115 KV) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 CHANTHABURI 65.08 51.73 56.41 61.30 71.85 104.65 149.95 CHANTHABURI (115 KV) 0.00 49.24 53.57 58.10 67.91 98.36 140.37 CHOM THIEN 23.64 33.48 35.65 37.94 42.96 58.47 79.83 CTH ON BUDIT 76.64 31.22 33.90 36.72 42.85 61.62 87.11 KHLONG MAI (115 KV) 120.00 238.45 257.11 276.57 317.i7 438.3 605.12 KLAENG .38.84 30.18 32.53 35.01 40.45 5728 80.36 PRACHIN BURT 1 53.56 28.91 30.96 33.16 38.02 53.47 75.06 PRACHIN BURI 2 0.00 9.47 10.14 10.86 12.45 17.51 24.58 PRACHIN BURI 2 (115 KV) 0.00 115.56 139.12 157.80 199.60 300.45 388.56 RAYONG 1 45.14 44.49 49.07 53.86 64.13 94.98 137.77 RAYONG 1 (115 KV) 44.64 0.00 0.00 0.00 0.00 0.00 0.00 RAYONG 2 23.09 26.59 28.61 30.75 35.43 49.75 68.98 RAYONG 2 (115 KV) 92.01 402.79 463.42 485.62 514.49 57.15 634.51 RAYONG 3 50.60 42.24 46.80 51.38 61.02 90.78 132.27 SI RACHA 28.44 32.44 34.47 36.58 41.16 55.26 7428 TRAT 26.50 25.91 27.36 28.85 32.00 40.97 51.92 TRAT (115 KV) 0.00 6.16 6.50 6.86 7.60 9.74 12.34 WATTHANA NAKHON 29.66 27.17 29.43 31.80 36.98 52.95 74.74 WATTHANA NAKHON (115 KV) 0.00 13.35 14.46 15.62 18.17 26.01 36.71 AO PHAI (THAI OIL) 42.64 50.00 50.00 50.00 50.00 50.00 50.00 AO PHAI (ESSO CO. PLANT) 7.31 3.80 3.80 3.80 3.80 3.80 3.80 SATTAHIP I (DIR) 8.27 10.00 10.00 10.00 10.00 10.00 10.00 SATTAHIP 2 (DIR) 22.69 31.96 34.89 37.86 43.96 57.52 69.77 TOTAL 1,178.32 1,912.56 2,111.43 2,262.69 2,561.53 3,404.85 4,452.51 -75- ADDendix 1 Page 4 Substation Load Forecast of Western Area NON- COINCIDENT ______________ _____ _UNIT: MW ACTUAL FORECAST 1 SUBSTATION 1994 1997 1998 1999 2001 2006 ' 2011 .2537) (2540) (2541) (2542) (2544! (25491 t2ss* BANPONG 1 91.60 .50.36 55.32 60.37 70.79 100.62 140.96 BANPONG 2 66.16 34.53 35.53 36.61 38.99 46.65 57.53 BANPONG 2 (115 KV) 0.00 49.26 50.77 52.38 55.96 67.45 83.77 BANG SAPHAN 47.00 17.16 18.60 20.07 23.06 26.17 41.17 BANG SAPHAN (115 KV) 0.00 135.00 135.00 135.00 135.00 135.00 135.00 CHA AM 40.84 35.22 38.07 40.94 46.88 62.84 82.22 HUA HIN 0.00 29.97 32.36 34.78 39.83 54.02 71.57 KAMPHAENG SAEN 30.71 40.44 43.53 46.84 54.17 77.73 111.26 KAMPHAENG SAEN (115 KV) 26.81 0.00 0.00 0.00 0.00 0.00 0.00 KANCHANABURI 43.48 59.03 63.18 67.55 77.06 106.17 145.60 KANGKRACHAN 0.00 0.00 0.00 0.00 0.00 0.00 0.00 KHAO LAEM 4.83 5.00 5.17 5.35 5.71 6.76 8.06 NAKHON CHAISI 124.74 117.19 126.74 136.91 159.25 229.08 325.83 PHETCHABURI 30.76 42.89 46.34 49.86 57.14 76.26 96.38 PRACHUAP KHIRI KHAN 26.20 20.15 21.84 23.56 27.07 36.64 48.33 PRANBURI 25.66 17.63 19.01 20.43 23.40 32.05 42.90 RATCHABURI 1 21.54 31.90 34.34 36.85 42.13 56.80 73.44 RATCHABURI 2 33.56 26.13 28.64 31.20 36.47 50.35 66.70 RATCHABURI 2 (115 KV) 0.00 60.46 66.16 71.99 84.67 117.84 161.67 SAM PHRAN 1 113.30 82.79 89.31 96.29 111.70 160.88 231.02 SAM PHRAN 1 (115 KV) 0.00 291.22 314.26 338.57 391.44 555.34 784.40 SAM PHRAN 2 87.84 75.68 81.74 88.20 102.50 148.02 212.88 SAMUT SAKHON 1 87.80 53.16 57.75 62.66 73.53 108.09 157.08 SAMUT SAKHON 2 73.76 103.87 112.70 122.09 142.79 208.20 300.07 SAMUT SAKHON 2 (115 KV) 12.92 26.15 29.97 34.08 43.12 70.00 103.54 SAMUT SAKHON 3 82.12 69.48 75.38 81.68 95.59 139.60 201.53 SAMUT SONGKHRAM 36.16 25.65 27.58 29.58 33.85 46.36 62.48 SkRNAGARINu 0.60 0.69 0.74 0.79 0.89 1.16 1A9 THA MUANG (PEA) 28.56 31.17 33.22 35.40 40.20 55.21 75.75 TOTAL 1,136.95 1,532.18 1,643.25 1,760.03 2,013.19 2,775.29 3,822.63 -76- Apoendi x I Page 5 Substation Load Forecast of Northeastern Area NON - COINCIDENT __._._. UNIT: MW i ACTUAL FORFCAST SUBSTATION 1994 1997 1998 1999 2001 2006 2011 _ 25-37) 1 (2540) (2541) (2542) (2544) (2549) (2554) AMNATCHAROEN .00( 17.41 18.85 20.32 23.40 32.21 42.25 BAN PHAI 16.88 24.66 26.69 28.80 33.33 46.94 65.35 BAMNETNARONG 0.00 0.00 36.80 38.10 40.80 47.79 55.40 BUNG KAN 15.96 10.96 11.78 12.62 14.39 19.19 24.76 BURI RAM 55.88 20.52 21.92 23.34 26.19 34.08 43.82 CHAIYAPHIUM 37.68 40.66 36.80 39.75 44.51 60.29 80.74 CHAIYAPHUM (115 KV) 000 5.81 6.22 6.64 7.55 10.20 13.56 CHULABHORN 0.00 0.15 0.16 0.18 0.21 0.31 0.43 CHUM PHAE 37.47 39.34 42.22 45.19 51.44 68.92 89.26 KALASIN 36.80 29.23 31.28 33.39 37.88 50.23 64.80 KANTARALAK (.00 0.00 19.90 21.70 25.30 35.60 45.45 KHONG 28.20 24.29 26.74 29.26 34.54 49.78 69.40 KHONG (115 KV) (.00 34.65 39.29 40.70 43.59 51.52 60.92 KHON KAEN 1 48.96 61.84 66.70 71.79 82.61 113.30 148.90 KHON KAEN 2 25.12 32.51 35.07 37.75 43.44 59.57 78.29 LOEI 33.44 23.15 24.93 26.75 30.40 40.69 52.91 LOEI (115 KV) 0.00 8.62 9.29 9.96 11.35 15.16 19.71 MAHA SARAKHAM 37.24 36.33 38.57 40.87 45.69 59.48 76.66 MUKDAHAN (PEA) * 18.54 24.03 26.22 28.46 33.07 45.74 60.15 NAKHON PHANOM (PEA) 15.18 19.58 21.10 22.72 26.27 37.37 52.50 NATKHON RATCHASIMA 1 75.95 28.92 43.17 45.58 50.49 61.97 80.43 NAKHON RATCHASIMA 2 44.00 59.40 43.17 45.58 50.49 61.97 80.43 NAKHON RATCHASIMA 2 (115 KV) 3.60 58.91 66.73 73.88 85.63 123.35 165.65 NAM PHONG 25.31 22.71 24.67 26.65 30.72 41.87 55.36 NAMPHONG(115 KV) 19.43 40.30 41.43 42.59 44.98 51.58 59.30 NAM PHUNG 2.64 4.03 4.49 4.96 5.97 9.1D 13.43 NONG BUA LAM PHU 0.00 30.43 32.59 34.79 39.30 51.82 66.52 NONG HAN 14.02 17.54 18.67 19.83 22.24 28.64 36.81 NONG HAN (115 KV) 6.45 8.50 8.50 8.50 8.50 8.50 8.50 NONG KHAI 27.10 35.67 38.57 41.64 48.24 68.31 94.83 PAK CHONG 34.48 43.68 46.84 50.13 57.13 77.45 102.92 PHAYAKKHAPHUM PHISAI 0.00 25.41 27.11 28.85 32.40 42.32 54.57 PHAYAKKHAPHUM PHISAI (115 KV) 0.00 12.75 13.60 14.46 16.18 20.89 26.68 PHANG KHON 20.36 22.92 24.53 26.23 29.86 40.51 53.62 PHANG RHON (115 KV) 0.00 7.31 7.85 8.42 9.60 12.79 16.51 PHON 19.88 26.02 27.96 29.99 34.36 47.03 62.04 PHON THONG 0.00 19.82 21.28 22.70 25.86 34.62 45.03 PRAKHON CHAI 0.00 30.78 32.88 35.01 39.29 51.11 65.73 ROI ET 40.76 57.35 61.84 64.67 74.43 101.93 134.20 SAKHON NAKHON 25.30 33.28 35.98 38.86 45.21 65.09 92.64 SANGKHA 0.00 0.00 15.30 16.80 20.00 28.80 39.90 SI SA KET 49.40 54.73 36.25 38.87 44.86 63.11 87.01 SIKHUI 35.20 42.11 43.00 45.56 51.04 67.27 87.96 SIRINDHORN 8.61 10.94 11.85 12.78 14.65 19.72 25.78 SOMDET 20.80 20.82 22.54 24.30 27.95 38.14 50.66 SURIN 52.80 51.01 42.16 44.38 48.70 60.51 74.79 THAT PHANOM 10.52 12.24 13.20 14.19 16.31 22.75 31.43 UBON RATCHATHANI 1 49.80 50.33 53.67 57.14 64.47 85.32 111.33 UBON RATCHATHANI 2 23.68 15.64 16.76 17.93 20.43 27.66 36.58 UBON RATCHATHANI 2 (115 KV) 0.00 22.76 24.38 26.05 29.56 39.45 51.55 UDON THANI 1 51.52 35.84 38.10 40.40 45.14 .58.09 73.14 UDON THANI 2 26.88 35.85 38.10 40.40 45.14 58.09 73.14 UDON THANI 2 (115 KV) 0.00 4.91 5.22 5.53 6.18 7.96 10.02 YASOTHON 37.84 29.65 32.09 34.60 .39.84 54.84 71.94 MUKDAHAN (SUVANNAKHET) 7.30 7.97 8.35 8.73 9.49 11.25 12.88 NAKHON PHANOM (THAKHIIK) 4.20 5.05 5.25 5.45 5.85 6.85 7.85 TOTAL 1,145.18 1,419.32 1,568.61 1,674.72 1,896.45 2,529.03 3,306.42 -77- ApDendix 1 Page 6 Substation Load Forecast of Southern Area NON - COINCIDENT UNIT: MW | ACTlAI, FORECAST | . n 1 - 1979 1971 1970 ;99 2001 2v06 4 (2537) (254A 0__ (2541) (2542) (2544) (2549) (2554) BAN DON 52.36 42.12 45.34 48.61 55.45 74.39 95.20 BANG LANG 5.92 8.66 9.40 10.15 11.66 15.74 20.54 CHUMPHON 43.72 46.73 50.74 55.07 64.33 90.18 120.79 HAT YAI 1 53.04 44.76 48.41 52.16 59.95 81.80 108.40 HAT YAI 2 38.80 36.62 39.61 42.67 49.04 66.93 88.69 HAT YAI 2 (115 KV) 0.00 44.09 57.15 66.61 85.07 112.75 136.58 KAENG KRUNG 0.00 3.95 4.34 4.76 5.63 7.90 10.22 KHANOM 30.24 33.84 36.44 39.10 44.67 60.99 81.37 KHOK KLOI 0.00 5.36 7.05 8.33 9.35. 9.84 9.84 KRABI 19.86 15.12 16.30 17.48 19.90 26.62 33.91 KRABI (115 KV) 0.00 12.33 13.42 14.53 16.79 22.90 29.78 LANG SUAN 0.00 11.68 12.69 13.77 16.08 22.55 30.20 LAM POO RA 43.70 25.60 27.63 29.75 34.17 46.01 58.82 LAM POO RA (115 KV) 0.00 31.29 33.77 36.36 41.77 56.23 71.88 NAKHON SI THAMMARAT 66.56 67.82 73.31 78.90 90.35 121.77 160.16 NAKHON SI THAMMARAT (115 KV) 0.00 19.13 20.68 22.26 25.49 34.35 45.17 NARATHIWAT 31.80 17.56 18.89 20.28 23.19 31.38 40.66 PATTANI 36.68 57.52 61.38 65.33 73.60 97.00 125.28 PHANGNGA 15.80 10.65 11.65 12.73 14.77 20.46 27.17 PHANGNGA (115KV) 0.00 4.56 4.99 5.45 6.33 8.77 11.65 PHATTHALUNG 24.86 32.81 35.53 38.26 43.79 58.59 76.53 PHUKET 1 44.00 40.05 43.37 46.84 54.25 76.53 105.76 PHUKET 2 42.74 39.73 43.02 46.47 53.82 75.92 104.92 PHUKET 2 (115 KV) 0.00 39.29 42.55 45.96 53.23 75.09 103.77 PHUNPHIN 19.60 28.95 31.85 34.87 41.23 57.93 74.98 RANONG 26.30 25.68 28.28 31.00 36.78 53.20 72.60 RANONG (115 KV) 0.00 19.37 21.33 23.38 27.75 40.13 54.77 RANOT 0.00 23.35 25.17 27.03 30.91 41.93 55.44 RAJJAPRABHA 2.75 3.63 4.01 4.39 5.21 7.45 10.12 SADAO 14.31 18.87 20.26 21.68 24.75 34.21 46.89 SATUN 20.66 28.72 31.79 34.97 41.88 60.13 80.52 SONGKHLA 64.08 63.14 68.04 73.09 83.58 113.36 149.88 SUNGAI KOLOK 0.00 26.34 28.34 30.42 34.77 47.07 60.99 TAKUA PA 11.92 13.30 14.23 15.19 17.23 23.27 30.91 YALA 30.34 37.60 40.50 43.55 50.07 69.58 94.62 THUNG SONG (PEA) 27.00 33.91 36.29 38.70 43.65 57.80 74.67 THUNG SONG (PEA 115 KV) 0.00 15.58 16.77 17.98 20.50 27.52 35.21 SADAO TO TNB 0.00 0.00 0.00 0.00 0.00 0.00 0.00 THUNG SONG (CEMENT) 32.04 78.50 78.50 78.50 78.50 78.50 78.50 TOTAL 799.08 1,108.21 1,203.02 1,296.58 1,489.49 2,006.77 2,617.39 -78- Appendix 1 Page 7 Substation Load Forecast of Northern Area NON- COINCIDENT _UNIT: MW ACAL TORhCAST SUBSTATION 1994 1997 1998 1999 2001 2006 2011 (2537) (2540) 2541 2542 2544) (2549) (2554 BANG MUN NAK 0.00 34.00 36.65 39.34 44.87 60.36 79.64 BUNG SAM PHAN 0.00 22.93 24.69 26.40 29.66 37.51 *46.09 CHLANG MAI 1 58.80 47.00 33.91 36.85 43.54 65.58 90.71 CHIANG MAI 2 58&80 47.00 33.91 36.85 43.54 65.58 90.71 CHIANG MAI 3 54.56 47.42 50.90 54.57 62.51 85.73 113.47 CHIANG MAI 3 (115 KV) 0.00 80.80 86.56 92.64 105.80 144.47 190.28 CHIANG RAI 81.78 65.93 70.78 75.84 86.62 117.49 154.01 CHIANG RAI (115 KV) 0.00 16.00 16.92 17.87 19.86 25.45 31.82 CHOM THONG 23.40 27.21 29.26 31.29 35.47 45.94 56.60 CHOM THONG (115 KV) 0.00 8.13 8.74 9.35 10.59 13.72 16.91 KAMPHANGPHET 24.42 36.91 40.51 44.30 52.62 79.30 116.53 LAMPANG 1 34.68 30.23 32.15 34.18 38.57 51.75 68.65 LAMPANG2 25.30 29.05 30.89 32.84 37.05 49.72 65.96 LAMPANG2 (115 KV) 0.00 40.00 40.00 40.00 80.00 80.00 80.00 LAMPHUN I 13.66 21.29 23.80 26.40 31.83 46.84 62.69 LAMPHUN 2 49.04 37.04 41.40 45.92 55.38 81.49 109.06 LAMPHUN 2 (115 KV) 0.00 31.79 35.54 39.41 47.53 69.94 93.60 LAN KRABU 7.31 12.91 14.38 15.89 19.01 27.52 38.04 LOM SAK 15.72 15.05 15.99 16.95 18.96 24.64 31.61 LOM SAI M1:5 V, 0.00 4.59 4.93 5.28 5.98 7.96 10.32 MAE CHAN 0.00 23.02 24.72 26.49 3025 41.03 53.78 MAE SOT 0.00 20.20 21.97 23.78 27.63 39.99 54.01 MAE TAENG 0.00 0.00 34.40 37.20 42.60 55.70 68.82 MANOROM 37.04 30.33 32.76 35.17 39.95 52.19 66.15 MANOROM (l15 KV) 0.00 23.83 25.74 27.63 31.39 41.01 51.98 NAKHON SAWAN 58.16 32.01 34.24 36.50 41.01 53.13 67.19 NAKHON SAWAN (115 KV) 0.00 26.05 27.87 29.71 33.40 43.24 54.69 NAN 25.42 21.43 23.13 24.94 28.91 41.31 58.26 NAN (115 KV) 0.00 10.55 11.39 12.28 14.24 20.36 28.70 PHAYAO 48.68 44.13 46.62 49.17 54.53 69.76 88.60 PHETCHABUN 28.08 30.30 32.42 34.49 38.54 48.35 58.72 PHICHIT 42.24 39.22 42.58 46.00 53.15 73.85 100.75 PHITSANULOK I 53.84 47.00 50.35 53.85 61.34 83.31 111.01 PHITSANULOK2 8.91 11.19 11.94 12.72 14.38 19.16 25.07 PHITSANI)LOK2 (115 KV) 0.00 19.20 20.57 22.00 25.06 34.03 45.34 PHRAE 37.24 33.58 36.11 38.70 43.96 58.69 75.38 PHRAE (115 KV) 0.00 13.06 14.04 15.05 17.10 22.83 29.31 SALOKBAT 17.72 30.45 33.07 35.66 40.84 54.67 71.52 SAM NGAO (BHUMIBOL) 1.94 2.23 2.42 2.62 3.01 4.05 5.30 SAWAN KHALOK 17.46 21.61 23.35 25.11 28.76 39.12 52.77 SIRI}IlT 2.67 4.18 4.52 4.87 5.58 7.60 10.21 SUKHO7TAJ 19.78 28.34 30.19 32.10 36.15 47.68 61.72 TAK 1 31.43 21.88 23.80 25.77 29.93 42.24 58.51 TAK 2 (PEA) 0.00 0.10 0.10 0.10 0.10 0.10 0.10 TAKHLI 2 (PEA) 12.17 15.89 17.02 18.17 20.59 27.34 34.91 THA TAKO 10.07 16.84 18.28 19.69 22.45 29.09 36.36 THOEN 6.85 6.88 728 7.70 859 11.14 14.19 THOENG 0.00 1825 19.46 20.72 23.37 30.96 40.08 UITARADIT 30.72 42.34 44.95 47.68 53.51 70.83 93.07 TAK 2 (PADAENG CO. MANI) 38.78 40.00 40.00 40.00 40.00 40.00 40.00 TAKHLI I (CEMEN-I) 11.82 13.00 13.00 13.00 13.00 13.00 13.00 OTHER (CONSTRUCTION PROJECI) 72.60 135.00 176.00 125.00 148.00 165.00 143.00 TOTAL 116L.09 1,477.37 1,61620 1.66604 1,940.71 2,561.75 3,259.20 -79- I APPENDIX 2 POWER FLOW DIAGRAMS -81- M~Od _A-, -4SV spa,t lung woi4Sa- Z ue4des 6ueg A4 oo5 pue 2 ueTdvS Buee Pu mw ooL x Z 41!M) t OOz Sddi MA Ppapod WesAssUuosssuwsuJl A)l 009 X1 M[Od :11 3SF::) e~~~~~~~~~~~~~~~aJeJJJaisam a4a Ul sddi Pool )lead.o 10S6 dQd VSunr Peoi ";daq] buluueld UMBsAs _ rPl to1 -ArvO-mmu om cd £ |__ :a 1ttI .,_ STJ ,__________-------- .I tsS'.,$§*, Eg^ GxtSG OD §: l~~~~~~~rK ov _o= umm IGGT'_i __GeT W]Yd~~~~~~~~~~~~~~~~~~~~~~~~~~~~~9 em :-wi2 t, IF I6 UglaSyil's 1. . Ii T 0 0 Z i[LLS^S t t TtSM . . __~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~c AtT Soo SYSTEM 2 00 1 *~~~~~~~~~~~~~~~~~~~~~~~~m NO & P;i i_7_3° Pi ;r 2 0o "I S. it~~~~~~~~~~~~~~~~~~~~~3 - i.T:L 7.S ~ ~ ~ ~ ~ ~ n z!): 1a 1-4 ~ ~ ~ ~ ~ ~ i0ii;t0; am;}5}i PAX 7M I Vl LI HT L A D IYt ; W | Systen Panning Dep71 ,L oa u9,P P5-1| Lgti a PsI h etrae | 4 - f | 5 0 0 K V Ra n 7 Is s S s e P r J c F o I P P s 1- 2 .0 0 1|(3h 2 7 0 M t B n S p a 2 a d 5 0 v a n S p a 2 C o u g 4 c t A E L - L 1 m ~ . O" _A O 7i'__ SYSTPM 2002 02 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~~~~~~D ~ System Plnig .Dep.. Loa Ju d,PP9ClI P kLod PPIn th wete ar _ I Jransso Stem P o IP I 2 2 I it a a 2 a 1 a _~~~~~~~~~~~~~A D . _.D i' .fS.1* ,xXijg. I~~~~~~~~~M ff iII. uII. 2::(;LX a } . i .............. ".' | | .... S | ] | ,_ _7 a _ Lll'ibt' e } } } X ' O}Lt} tS~~~~~~~~~~~~~~~~~~~~~~~~~~~ "T E tS !s i-d MX4~~~90Mwo PEAK LOAD ^> X | |System Planning Dept.,Load JunS4,PDP95-Gt Peak Load iIPPs In the westemarctta CASE LF - P02W |S|500KV Transmission System ProJect For IPPs 2002 | {Wlth 4 x 700 MW ait Bang Saphan 2 and 260 ksv Bang Sitphan 2 - Chom Bung 4 Cdsts. .~~~~~~~~~~~~~~~~~~~~~~~~~~~T SYSTEM D200 r 3 trr m D t; 11 .|,I 1 . 4 . I4 I I IIE jzzL. w vNS Fa o~~,, n LX1s > . Sii } , 1 ,. se}s}s 41Z 5SSa 01l1 1r F O :o 1 10| tLrQ1r>ut0g,all -3 m LIGHT LOAD- --- |System Planning DepL,Load .IunS4,PDPS6.O1 |Llgh2 Load |IPP5 In the westernarea (With 4x700+1,000MW at BangSaphan2 500f|ffOKV TransmIssIon System Project Fsr IPPs 2003 |and 500 kvBang Saphan 2- Chom Bung 4 cdt5.)} . CASE LF - LO3W SYSTEM 2004 I 11 I j.. !'' e 1 ,-' S PI 1.12 W i f , o, 1%. ! _ _!il sovsTXs i"' sonsar . _ X, v t~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~0. 8 5 00 N~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~0 .0 PE~~~~ARLOD.|9 @3|Systemn Planning Dept., Load Jun 94,PDPS95-O01 |IekLodrPPs In the westear are ( With 4 x700.+2 x1,000 MW at Bang Saphan 2 _ DM . - _. ..._ * 'm m ~~~~~~~~~~~SYST]tiI 2004 m//z---' wn ~~~~~~2 i T:4o r ___ / z w , 7|7 , fi __ 2 E it§; " 7 -1 ,0 -7 i l S1. --------JlI { eso 7 MA S a t2 $ | o : 11 ligi-lXltlWol}t}o i WON LIH 7ODi.| > E E | Slisem PbnningIDepth Loa Jun94 PDPS-Q1RO |PO Llh od|tsI ewsenae(lh4 W x1w Wa agSpa | f OOVTrnmisonSslmPrjd orIPs| 204 | n SOsv g aha -ComBng4cd.) ASELF-L0W- M w MM l~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ ;msni - SYSTEM 2004 KV~~~~~~~" Trnms2nSse rjc o Ps20460wBn ahn2 hmSn es 814444r 2$ 1.3.. LJ11 Di.X e._R_ 0 ; ; i I i,5 X 9 t 1 X X~~~~SA "O s i pj- ,,,,2 I ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~II M,.,.,_i PEA LOAD IO I>, . e . ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~A, PAO t iao TnSl9ZOnLSS°SPne{lPP;t 0d lp5 n hewet m (hkXB7°5phn2chm un 4 et |ASVol SYSTEM 2004 . X~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~0 so 0 _ .wnIAs.DD fl~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~M -. 10045!.. - cmi m jj A L L NO:r CHOR T 0 ; T ,, T < t ~~~~~~~~~~~~~~~~~~~~~~~~_ <4 :a I2. ' 100 I 5 ''.00 -sa so rA t:zmA [ l l | 6 | A~~~~~~~~~~~fll 104 2~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ 2 J;ii}"2351>oolWo }~~0 0 2 ..< LIGHT LOAD A717 & Systern Manning Dept,,Load Jun94,PDP!15-01 | Light Load |IPPS In the westernarea (With 4x700+2xl,0O0MW at Bang SaphanZ, . . <,f|.50KY Transmbsalon System ProJect For IPPs 2004 |0k an alRng bu tSaihn Nhom Run | s CASE LF - L04W - 2 50 anI-- VnMbs t alNd 1 2 g ,,, =&'g ... ~~~~~~~~~~~SYSTEM 2005X ~~~~~~~~~~~~~~ S I .Sol 6- ,,, . , , - -- _ _~~~~~~~~-- - - - - t sstmPlnnnigDetjsempojctFr PP L di PP n hewstq- re tWthvX7 SpXa °-CoX unA4cts |GSELF-L0W M~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~n splbn bu.t.a N \ Q fa T ~~~~~~~~~~~~~~~~~~sysrEM 2005 15 r ' | qJ H 1 ;e$28 T | Xo o17" iX t s 3 ttq n~~~~~~~~~~~~~~~~~~~~~~~~~~~~~1 J A | L x,2582 = I I 1W1 l 'S-f-f-1' BB j X1 1~~~~~~~2 Re _ I trt e tsE_~~~~~I R 2~~~~rii A7FX ) :X mTr " 9z1,Djl Bg Xi°]4' i $ |p7U.7 -}a2.|1 LD3: 1~~~~~~~~~~~~~~~~~~ } [u _ _= | t [ r ~~~~54 411 | -XGD ^tX 4@DS t 2 / l l l l I^D s | % ZNW=~ ~ ~ ~ ~ ~~gi .} }D 0D .D1WD2|t PEA]t LOAD RIKYCItmm |xam | t | ystrnPannnileptLoaJun4,PP9501| Pak oad| IF7snthwesemae (iihX70+5xh1002MhWmt8unng4acc | ASELF-05W2 g | 500W Transmbssion Systern Prolect For IPPs | 2005 | and spling bus at Sal Noi >~~~~ho PHA *______________ _4 _ SYSTEM 2005 1:~~~~~~~~~~~~~~~~~1 i 1" F111< sLL~~~~~~~~~L . gm 525 T 5"'" C4 'j2L] 'US SE F - g W t taKNa LIGHT LOAD A02 Sy |spte Planning DeptLoad Junn 94PP 851 ILoad IPPs In thc sSrc {tkv Sang Saphan2- Chain Blung 4 csts.I CASE UF - LO5W - 2 g COKV ranrnislo Sysem roe Fo IPs | 2005 |and aplkiIng bus at SailNol) |_____ 5=*01 sT^2 ~~~~~~~~~SYST1EM 2 001 Wsi~~~~~~~~~~m no // 6L T I 1 S~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ WE t~~~~~~~~~~~~~~~~~~~~~~~~~~m cFt- SAX~~ ~ ~ ~ dX , _ ~ ~ ~~~~~c wsO-ib . u. "°i I1°t ;_ PEAK LOAD FAX01X3 a 0 8~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~10 SAMOX_ RDI b SsemPanig kp.LodJu9,PPS-1 ea oa eP i teeatrnra Wi x7 W ayn4;50kRaog4Wngo 2cd.i AE F P1 | o |6WK TansisionSytemPrJec Fr PPs| 001 1 nd wkRaSon4-Nngo AO cct- I SOM M"01~~~~~~~~~~~~~~~~~~~~~~~~~~ ar,5801 Z M SfaSn ~~~~~SYSTEM 2001 *~~~~~~~~~~~~~~~~~~~~~~~~~~W NotC 4t LIGHT LOAD oj, I m ~ ~ . sm ....... L. _T am _ cfj',. W~~~~~~~~~~~~~~~~ 2t< w| [ =3m$$fi,' .., 'i' ,, r;i u u~~~~~w L-. II-. /- -UZ , .. lU t a tz I I I i i l} iU}3 I: ~~5fi}} 7o. ),m PEAK LOAD o mZ °s1~~~~~~qj | | SOOKV Thnsmistdon ~~~~~LSyse PntFr Ps|202 P and§0nRpn4NrCMx2ct. -~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ 0 SYSTEM 2002 igH rT ^'li,~~~~~~~~~~~~~~~~~- _ 11 42l so. S.5 wLia.or 2~~~~~~ *P;;L ; a * . FD' *. fflT ue * *,1 oll tal tjols 25 0 _5 POI 436~~~~~~~~~~~~~~~~~~~~~~~~=02 PAZ .0 - t: R-U- 02 -3. i 9 ; m !i1' . , r f S 1 l l l l l~~~~~s 3a l . M . ±1011 10 1 1.2 1 Z..oo 00:°s L 2Z.Z.0 0 .. 2500 JO M Rol _- _ _ _ _2- . ._2 is | yI Plannina DeptL,Load JunMPDPW95-O1 |ULght Load |IPP5 hn the eastern area (With 4x700 MW at Rayong4; BOOkvRayong4-WangNol 2 ccts.| * System ~ ~~~~NDAD MCAS E FL2 | 600KV Tranamiuslofi System Project For IPPs | 2002 and 6001w Rayong 4- Nong Chokt 2 cdts. )IAELF-L2 *w .N- M Ansmi rs sys'rEM 2003 - >°}°r5 / X / L 23~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ r. ~ ~ ~ " A //2r Q)Q2 il -r;1t'S1 --fl1 ;~~~~~~~~~~~~~~~~~~~~~~~~~ I w ! a: ,,,,, s .. ..................IM 1 1.1. L sea" R I Ir 1t ~~~~~~~~~~~~T= I II 1>02 . 1 1 } };° } } } ° f f i X Dle | I_~~~~~1.41 P E A K L O Ar *e23 | L t l ) i _ _ _ - 2 |--- ---- --- E _ _ . _._. . 1 - | __ _ _ | I~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~i | 3 Sytem bnnn61 ept,Loa Ju94,DP9501 Pea Lod | m i th eatrnare -------------Wa Ryng; 0kvayn4-anlio | tr| 60 K Trnsmssin Sste PrJectForIPP | 003 j 2cds an 50 kvayon4-NngCox css >| CSE F -P03 SYSTEM 2003 Z | A[i t 3 SAT N00 I . or 2~~c 2 _ System Planning Dept., Load Jun 94, PDP 95.-01 Light Load IPPs in the eastern ar ea ( With 4 x 700 + 1 ,000 MW at Rayong 4; 500 xv Rayong 4 -Wang Nol CAS E LF - LO3E 500 KV Transmission System Project For IPPs 2003 12 ccts. and 500 kv Rayong 4 Nong Chok 2 ccts. )_ 3 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~ _ __._ ![,', ,m ~~~~~~~~~~sys'rEM 2004 l 1 3w>3X5 8 3 L S. - M M t n 9 : ti+_L I I bs p..L I~~~~S1 §1 a,2 t -Wjeelll~~~~~~~~~~.0 0< l2 1 i ^ . of _ _ fr : tjl°z 1| *. ~~~~~~~~~~~~~~WAG I P^ NF f | tf li, . ;P-lsJ Lj6 l l l l l~~~~~~~~~~~~~~~~~ 1-AIZ; w | | 2°J n l I.-~~~~~~~ mmtt4}ot r_ r PEAK LOAE ^,0 l R^ONC 3x,A | t |Systm Plnninl Det., oad un 9, PD 9S 01 Pea Loa | IPs i theeader are ( Wth 4x 70 + 2x 1 OOt viW t Raong ; S0 kv ayon 4.-WangNoi2 | | ~~~~~~~~~~SOOK TrnmslnSse rjc o Ps|20 cs n OkRyn4Nonghk2ctr |CS F-P4 g1"0' -' ^,, SYSTEM 2004 2 I T t~~~~~~~~~~~~~~~~~~0 400 IJQ . -1Z//7 a gzaW i1°4° 1 -a C-,, L eI GHT LOAD 11 t : A t~~~~~~1, 1111 w I I .2Z 11- m $ ttJiSM 1 2 1 ~~~O0~~~ KV Transmi-s-on SytmPojc IPP I 200 "1' It 14 4 l LL:|t4U 3~ ~ ~ 9ii1}X}1t}10 t '___jtO LIHTLOD 8D [ F:Ql WS3D . ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~I -7 - - --- U I'm~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ RA ACI I y5e lann Dp.LodJnS,D95O LgtLod|PP nth atenra Wt 4T02x,0MWMRyog;WkRyng-agNl | gJ | 60 KV TransIslnSdmPoetFrIP 204 |2csan5WkRaog4-NnChk2c. CA LF-0E J., ATI ~~~~~~~~~~~~~-M 4t SASY S rEM 2 00 5 01.0. -O i /.0 2'F = , W~~~AM NO] w 7 1 - X /// ' t$SgS ~~~~~~~~~~~~~~ 2 13 f S i f >/ ' W _ W ~ fiS g __ '.1, 22; "A : :,S Ols7 . L .>gRH HF: 11- 'WC t e... ,. I~~~~~~~!M >; 44;m: ; F ;~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ S5 f_AT NO I t° m r rw04 StA 1 PrSl -Sff"=4 10 IM~~~~~~~~~~~~~~~~~~~~~~}135>q6>t)111111}1}Isls BAMXOK~~:ml°°7}°l°1}° MI1 -,' PEAiC LOAD 8°:! S22m | .4~~~~~~~~~~~~~~~~~~IDi Ml.ft 1-~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~C | yse Pan i g e t. L a J n 4 P PSS- t| e k oa I P5 i t e eatenara it x70 4x1,00Mka R y ng4* 00k R yo g4 an iii | t | OOK Trnsmssin Sste Prjec Fo IPs | 200 | ccs. nd OOk Rayng4 Non Cho 2 ds. | ASE LF Po E . Arz 4 T , ,,/ SYSTEM 2005 51, 2~~~~~~ u ML ~~~4L 3 -, - SAI NO! to - 4, LIH Li' OAD | 3 | ystemPianning Det,La Jun 94, PDP gr_01 |Light Load |I75in the easterna~rea (With 4 x700.4x1,W000vMW at Rayong 4;500kvRfayong 4-Wang Noi| CASE L.F- L05E | { f15W KV Transmission System Project For IPPs | 2005 | 2 ccts. and 500 kv Rayong 4- Nong Chok 2 ccts i Ln~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ At2sB0t 4tnm mx ~~~~~~SYSTEM 2 00 6 j r = :~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~1' ! //S wl zZ$ot 2 1 oss _ ^ WA9G 1 [~~~~~~~~~1 V :; "__i.; _ 0 ,1 -'r ,, SX,,, l6- t1 I i;8 ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~cE xE s__s L; ''2j;|; ^ ............... < !- I ....................... r jlj ii44=24-t|3 2 g~~~~~~~~~~~~~~A MI-l 1 :z. _ _. i miLua7ox ero -12 g F s O tj t t X,015 ";g L.x- l r ' 177 27 rw i o t ,, A m = = 4 d | i | I ! ] ! X j4;; C)~~~~~~~~~~~~~~~~~oXt IIa''''} rnggzosoWsW0w0- ,e3°,¢ PEAEt~~~~~~~~~~ LOA -21,,,|7 TAOQig222 g~~~~~~I .7-ytmPann et,odJn4PPf-1|Pa La Psi h atrae Wt x0+x,0iW tRyn4S0vaoG-agoICS F-P6 g t g 00' Tanmisio SytemPrJec Fr IPs| 206 2cds ad SOk taong NngCok2 cS.4 _ t~~~~~~~~~~~~; IIA71r7l~ S..ll SYSTEM 2 00 6 4 -=),== t:'1' g~~~~~~~~~01 2/}2 _O5 8+ f 8 z x t i . ;2j) j) |+t F q; oP7 ' ot _W I 5| * 7 NL 2 t;, s t $S0+ XsIF lini V~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ < ~ ~~~P 4 1 0j- r...................................'""' ' 4 2Fi''.........Il ;4_ _i SllliBAK:ol7 i A PW |;I rT m":1 Fi' a Lu 1[1 , Im~ ~~ I' 0Jt-S$IIII S zts 7ti NORTH~~~ ~ ~ iiiWs-; ;;};S 3 . . LIGHT LOAD ,,, 1 7UtYONC t222gg' |SOTH |A t J O PH& > | Systm Plannng Dept ,Load un94,PD95-01 |i ight Lad | jP5 in th easterarea (Wth 4x20+6x 1,00MW at Ryong4, 00xvRayng4-WanNol| CAE LF- -L06E IF | 15 00K V r anm isi o 5ytemProectForIPs |200 | ce. nd 00 v Ryon 4 on Chk 2cct. - 1 5 5tt lA 2 4 7 ~~~~~~~~SYSTEM 2 00 6 ut 3 v zo2 // 177it ;1!1Wm m r A NOr J -0X i 7 X I ,4mi ~~~~~~~~~~...W3... S11......1 | m 7 >l T S Z lg)a,- H t *" is l < <0t~2 r S" ~ ~ ~ ~ ~ ~ ~ ~ ,11 PHR111 i"f _ '° 1 .: > LIGHT LOADCN|l,!5s;i w m , | f¢b1system Planning Dept., Load Jun 94, PDP 95 - n1 Light Load I PPs in the eastern area With 4 x 700 + 6 x 1,000 lItW at Rayong 4,; 500 kv Rayong 4 - Wang Noi| CASE LF: L06E -4| |0 | OKV Transmission System Project For IPPs | T 20th 2 ccts. and 500 kv Rayong 4 -Nong Chok 2 ccts. ) SYSTEM 2006 bm Mr PEAK LOAD ; 5 l\ |System Pbanning Dept. ,Load Jun 94,PDP 95-01 | Peak Load |PPS in the eastern area (With 4 x700.6 x1,000 MW at Rayong 4; 50kv Rayong t- Wang Noi|cs FP6 | f|500 KV Transmilssion System Project For IPPs | 2006 |2 ccts. and 500 Kcv Rayvong 4- Nong Chok 2 ccts.) CAS FlP6 >5 ;2j ls / 4nj 4§,Otr 5;: , Xl ' Ft -.RSYSTEM 2 00 6 .ic.io.isoo.E _ //S i7' X L u:, cO L~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~Z - SAXj 4ArUs 1:'?,,~~~~~~~~~~~~~~~~~~~~~~~~~~~~~l NM CR-,X OK,1 1 i 1::i:--" " 11 li3 _4 _ _ _ _ _ :j' I .. H WE~~~ LIGHT LOAD 1ai3 51 X~~~~ *.:,~~~~~~~~~~~& ,., ,NC 1W ~ ~ ~ ~ ~ ~ . } System Pbnning Dept.,Load Run94,DP950 1 ih o d IP nteesenra( K x0+x,00 W a aog;0k Ryn4W n Nlc F L 6 M0 V rnm isb Sytm4oe o IF. 0 62ct.adS0k ayn4-Nn hk2ct SYSTEM 2007 PEAK LOAD !:55:5 I55 NC, System Planning Dept., Load Jun 34, POP 9S - OR Peak Load IPPs in the eastern area ( With 4 x 700.*8 x 1,000 MW at Rayong 4, 500 kv Rayong 4 -Wanig No AElF- OE \v, 500 KV Transn¶lsslon System Project for IPPs 2007 2 ccts. and 500 kv Rayong 4 - Nong Chok 2 ccts.)ICS F-P7 _J~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ SYSTEM 2007 / / / / .@ _ 1f)tOtW ) r | s q~~~~~* ~ ,. .. 2~~~~~~~~~~~~~~~~~~~~~~~~~~ EF,,,, g ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~-- -i-t 3 + S e=77i S=S 2 .,I .., II11 : X[1 . System Planning Dept., Load JuJn94 PDP 95-01 Peak Load IPPs In the eastern area (Wlth Asx700 + Txt,000 MW at Rayoig 4 500sv Rayong 4-Wang NoifCS FP7 jj ¼i/ 500 KV Transmission System Proje.ct For IPPs 2007 (2 ccts. and 500 kv Rayong 4- I Nong Chok 2 ccts.) CAEL -P7 . . . . _ _ _ _ _ _ _ _ _ _14 APPENDIX 3 DYNAMIC STABILITY CURVES -119- !~~~~~~~~~~~~~~~~~~~~~~ In 0n3 SYSTEM PLANNING DEPT. PDP95 PEAK 2001 SYSTEr PLANNING DEPT. PDP95 ,PEA 2001 fJd 1 A IPP AT THE WESTERN AREA (1400 MWI 3 PHASE FAULT AT BSP2 ON 500KV BSP2-CBG LINE ° 3 0PHAS FAULTL 4 CSO Ci] PEN FAULT LINE 4 CYCLES OE AL IE4CCE C's YFILE: P01W F i FILE: P01W u c- > L _CHNL1 20: lANGSNfR H551 1 CINL 41: (V:230KV RY2I 1 0 D C - - - - -50.0 | 1. 3000 0.30000 CONL IS (14 AG EPK Tll I'CONLI 36: (¶1:230KV ORTI r -150. 00 . -150.0 ~" 1.300D0 150 00 C 0 13 IANG MH3 T31 -150 0 i 1 3000 CHNB 34 IV T3031V 0KV NB1_3 [150.00 ~~~~~~~~~~~ ~~~~~~~ ~ ~~~~~-150.0 I 1.3000 * C130L8 2 h-00 CHNLI 10: IANG: KN G111 - 150.0 | 1.13000 CHNL4 2il: lV SOOSV 81131 v 0 30Q0 | CHNL0 1: IANG SB T1 ] CHNL0 32: IV:5000V CBGI _E 150.00 - - -150.0 I (1.3000 0.3oO00 I 150 00C -150 0 | 11 3000 CIL0 31 IY 520KV 10 t0 :0 o C~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~' 1 : E~~~~~~~~~~~~~~~~~~~~~~E a. o N (A( - 41 , k~~~~~~~~~~~~~~~~t I 9.... ~~~~~~~~~~~~~~~~~~~~~~~~~~~~ fO : A.,~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~U () SYSTEM PLANNING DEPT. PDP95 PEAK 2001 SYSTEM PLANNING DEPT. PDP95 ,PEAK 2001 IPP AT THE WESTERN AREA (1400 MW) IPP AT THE WESTERN AREA (1400 NW) r4 LINE TO GROUND FAULT AT BSP2 ON 500KV BSP2-CBG 2 LINES * LINE TO GROUND FAULT AT BSP2 ON 500KV BSP2-CBG 2 LINES O ,FIII OPEN FAULT LINE 4 AND 6 CYCLES (CONTIGENCY N-2) OPEN FAULT LINE 4 AND 6 CYCLES (CONTIGENCY N-2) Cd ~~~~~~~FILE: P01WBSP2-CBG FILE: POIWBSP2-CBG ath D.. | lSo.oo CML 20: [ANG:SNR HSI .-A: -150.0 | | 1.3000 eaLe tl :230KV RY21 - , _ _ - 0 1 150.00~ ~~~~~~~~~~~~~~~~~~~~~~~~-5. 1 C4 11.3000 1 150.00 CH 13 I AG:B PX Tl - - - -lS0. 11.00 0 c t 36 Iv 230KV SRT - - - 0.30000 CM#NL 10: [ANG BK GIllj CMM#L 20 [V:2300V SRT1 150.00 - - - - - 150.0 N | 1 . 3000 c. . . 0.30000 I150.00 CLOS - - -150.0 1 il.3000 32-0.30000 1 150 00 ~~~~~~CHNL# 10: [XNG XN GllI - - - - - - - _, ---- 150.0 i 1. 3000 CHNBt 283 IV 00XV HH3E 100 |150-00 CHNLt 1: rANG:SB T51 . loo1[00CHNL# 32- MV500XV CSGI _ _. 030000 I ~~~~~~~~~~CENLI 25: rAN4G:WIP Ul] CKN,, 31: [V50011V ESP21 | 150.00 CN -150.0 | 1.3000 3- 31 0.30000 ~~~~~~~~~~~~I I 1 '" °I Ill1111 o 0 I ; f 0' lD 11 If t1)~~~~~~CoI 0 I~~~~~~~ ~~~~~~~~~ I -ftc jW 0 ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~0 S C I it~~~~~~~~~~~~~~~~~~~i I H ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~04 oO~~~~~~~~~~~~~~~~~~~~~~~~L 1 :0 it .u~~~~~~~~~~~~~~~~~~~~~~~~~~~~~U f,ZI1 SYSTEl PLANNING DEPT. PDP95 ,PEA 2001 SYSTE( PLANNING DEPT. PDP9 PEAK 2001 te ) pw-e SIPP AT THE WESTERN AREA (1400 NW n)- IPP AT THE WESTENU AREA (1400 NW) in LINE TO GROUND FAULT AT CBG ON 500KV CBG-SNO 2 LINES ' LINE TO GROUND FAULT AT CBG ON 500KV CBG-SNO 2 LINES . O) t Ej OPEN FAULT LIKE 4 AND 6 CYCLES ICONTIGENCY N-2) - D = OPEN FA13LT LINE 4 AND 6 CYCLES |CONTIGENCY N-2) Oi; FILE: P0WNCBGS_O _0 FILE: P01WCBG-SNO _ O *~~~1s~~. I 15000 LA~C&$ :NDi US IL...... 100CENL 41: lV:2301V RY2 -- ) 0300 -lic 1150.00 ------- -150.0 0. 3: V20I 10 150.oo CHtiLl 15. .:P Ti~x-JA -ml-m- -K 150.0 J 13000 1M 6: tV:230HV SRTI ] .00 - 150.00 - IL-3.-1_-- -150.0 ; 1.3000 CM# 34: M2300 NBI 0.30000 | | CO50., 10: 1M6:uN Glill ._ . _ v . CR.00L 28: IV:500H V O 131 . N | ] |1 5 0 .0 0 - _-1 10 0 0 - - 1 : 1 1 3 T51 . - . ..1. I [ f 0 32: I V :5 0 0 V t - - 0 .3 0 0 0 0 j a C H N ;1 2 5 : ! M W : VI P 01 11 - e C- .#* 3 1 : IV :5 0 0 1V 3 s P 2 1 e C I I .~~~~~~~~~~~~~~~~~~~~~~4 IJ i i _ Cr'''',''/\ tR _ 0°,~~- _ l, tY,' fip_O (~~~~~~ '1s ' 6'i5\ \H I I 1 1\ ~ ~~'.w t t I I ° I_( - . .. . . .4{ .~~~~~~ .. .- * I 4( I~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ 0~~~~~ 0 r iSYSTE2( PLANNING DEPT. PDP95 .PEAK( 2001 j~ ( 1SYSTi PLANNIN DEPT. PDP95 SPEAK 2001 r VW1IPP AT TOiE WESTERN AREA (1400 NW) U W~'1IPP AT THE WESTERN AME (140 NW) I |-1 LINE TO GROUND FAULT AT CBG ON 500KV CBG-WNO 2 LINES |LINE TO GRON ALT AT CBG ON 500KV CBG-WO 2 LnIES OPEN FAULT LnIE 4 AND 6 CYCLES (CONTIGERCY N-2) OPf FAULT LIN 4 AD 6 CYCLES (CO1TIGDNY N-2) in FILE: P01WCEG-WUO FOM,01~GlUOj a 150.00 F-. - - - - -1500 1 1-3000 0: POli- 10_ _ _ 0.30000 150.00 CML 15- rANG:BPK Till xj...... --1-so t 1 .3000 r 35s IV:23V fl -------K 0.30000 | llso.oo ~ ~ ~~~~mufr. ra1, sa _A'p TS)o c;1-00rw03tons 3sM0K IPPI --- + e3oe1l 150.00 N ol * -- -Vsu.e F1K.3000 ---rv- 0.30000 | ; | 150.00 ' C0rII 10: 00: SB GiT5 --------= -15.e0 11.3000 C4NL 2 : yj 1 0.30000 I -II0 1 11.3000 ~0.300000 cmiii 15 10001-sD '15 - I CMIi.. 16 Iv:som wo.0.0a0 |150.00 em5o.es0025: till - I cir..oi lv 5eK300021 _~~~~ ~ . * _t:i.1@_e :0 S * I I.~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ I 0~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~0o I I~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~W j. ~ ~ ~ ~ ~ ~ x r SYSTEK PLAOING DEPT. PDP95 LIGHT 2001 SYSTE4 PLANNING DEPT. PDP95 LIGEHT 2001 T l n U\ FP AT THE WESTERN AREA (1400 KW) IPP AT THE WESTERN AREM (1400 MW) aO 3 PHASE FAULT AT BSP2 ON 500KV BSP2-CBG LINE 3 OPHE FAULT ATBSP2 ON 500KV BSP2-CBG LINE 011EN FAULT LINE 4 CYCLES O52CG IE3PHEN FAULT ATN BSP 0CYC0LESP2C LN Cd st 2150.00FILE; LOIW FI LOi| CUM#, 20: rAi#3SNI H51 @ cOL41I:2301KV 1Y21 150. 00 C 11.3000 - 0.30-e - - so-oo CEL#15 f^S:3Ta31____- 113000 [ BT.f36 IV:230OVR _ -T 0.30000 150.00 o ........ -150.0 E1.3000 . 2tl: lv 5o.X.. 0.3009j A I~150.00 ----- 1001 00----- .00 II50.00 CU# 10: tANG:SB SSI1 - - - - -10. - - -13e CM# @26: IV:SOOI:Vt I _ _ 0.30000 | 1 350.00~~~~~~~~~~~~~~~~~~~~~~~-5.1360--- so0.ooc* 5:I0l -150.0 V p 1.3000 elo 1rsonsP * 0.3000e dune 25. U ll 1 1 . 3 0 0 0~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~0300 _ § t y 4 & I I . | ||Egg 0 j~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~IC .l 1l SYSTER PLANNING DEPT PDP95 LIGHT 2001 *- SYSTEM PLANtING DEPT. PDP95 .LIGHT 2001 *1 [ II PAIHEwsER]m (10 W IPP AT THE WESTERN AREA (1400 NW) l~ ~~~P AT THE WETR A OE r10 , NP TIEWSEW RA(40D50 G2IZ LINE TO GROUND FAUJLT AT BSP2 ON 500KV BSP2-CBG 2 LINES LINE TO GROuN FAULT AT BSP2 ON 500KV BSP2-CBG 2 LINES ). G L'" I OPEN FAULT LINE 4 AND 6 CYCLES (CONTIGENCY N-2) mOWl FAULT LIE 4 AND 6 CYCLES (COd IGENY N-2) I FILE: LO1WBSP2-CBG FIE:LlWS2-B S150.00 CDOL0 20: IANG:SR H51 _ , -1 1.3000 aIo *1: [V:230XVKY2I >, _ -_ 0.30000 | g CEL# 15: ROD IPX Tit I 4 CM#L 36, V21OKV SRTI ..... 150.00 0 ...1 1 . . . -150.0 | N |.10000 I cHN., 13w fOAD 221 TR]~ CElLO 34, FV1-230KV EB) 0. 80 150.00 - - ---- -150.0 |11.3000 -----' e.30eoo I g |150.00 CM#L0 10: tINGAN - - - - - - 10- [R- -150.0 |1.3000 CHNB5 2i: tV:5oxvMI ---------- 0.30000, | |150.00 . -150.0 | | 1.3000 CID-IL. 3 0.30000 | b 50.00 CHNBO I5 ram :II-P- -~lS 0 1 | |1.3000 CElLO 32: OV:5001V BSP21 - 0.30000 | CElLO 25: tAO: NIP il 'CElL 31: 01:500KV .SPl1 0 ,50. 0--150 0 11.3000 .-r:000 I . > ro ... *10~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~, - I,~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~7 I . 0H [I~~~~~~~~~~~~~~~~~~~~~~~~~~~~~U _ _~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~c SYSTEM PLANNING DEST. P9 L PLANNING DEPT. PDP95 ,LIGHT 2001 ~~U r- IPP AT THE WESTERN AREA (1400 NW)1?ATHEWSRNRA 1014)It LINE TO GROUND FAULT AT CBG ON 500KV C3G-SNO 2 LINES INP AT TON W AUTE AT 140 N 5 2LE k)iV i O1?EN FAULT LINE 4 AND 6 CYCLES (CON!3TIGEN'3CY N-2) OPEN FAULT LINE 4 AND 6 CYCLES (CONTIGENCYCY N-2) I FILE: L0lWCBG-SNO FILE: LOIKWBG-SNO *fi 3 2 X { ISO OO ~~~~~~~CHNL 10, IAHG_5R SI _ E -1501 130 CJDW e3, IV 230XV B2103001 |150.00 cw§1 aG5sT1^|13O §3 V20WIXK0.300001 CN#15: [AM:G PK TIl . .. -5. I 1. 3000 CHNLI 36: [V.230KV SRTI . " 0130000 I50.30 CHNL 13 U 3 3 11.3000 _ I T CHlL. 34. IV 230KV NBI _ _ I 0 150.00 -1506 0 1 1 1.2 .30000 1 : 1 150.00 ~~~~~CHNL0 10: [ANG:KN Gllll0. 1130 CHNL 2a: [Y:500SV M310-001 i150.00 CHRI 1: FANG: S T51 -150.0 1.3000 CHL0d 32: IV:500KV CBG1 , 0.30000 | |150.00 cH-o -5: tAMAGPUll 150.0 1 1l.3000 CM- o31 [VSOOKV85nl 0.30000 I . I I I '11 1- 1 I V I , I >oI I | 1' ' ' I ' ' o I 0 a~~~~~~~~~~~~~~~~~~~ _ , *, a | ' _ o _ t I ' O _ o ,I I 0 ... l . . . _-_ _ . _ 1 CI~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~C f oN~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~L 00 SYSTEH PLANNING DPT. PDP95 LIGHT 2001 g j SYSTEM PLANNING DEPT. PDP95 ,LIGHT 2001 J ipp AT THz wEsTERN AREA (1400 NW)>, J1 IPP AT THE WESTERN AREA (1400 NW) '4 0) LIKE TO GROUND FAaLT AT CBG ON 500KV CBG-WNO 2 LINES LINE TO GROUND FAULT AT CBG ON 500KV CBG-WNO 2 LINES I AT OP EN FAULT LINE 4 AND 6 CYCLES (CONTIGENCY N-2) DO PEN FAENLFALINELINEID 6NDCYCLESESC(COTTGGECYYNN22 FILE: L1OWBG-WNO FILE: L01I BG-iWiO 1 00 CNLt 20: [ - _ . - 150.0 1 I1.3000 crlL 0 (V23000 - - - --- - 0.310000 I g cunt. 15; r.oo:an TiI fCMML 35: rV:2300V UKII--.---u-~if | 150 Go co 13 i ElS x - - …- K -150.0 | | 1.3000 CHNB0 35: r .2301V RP. 0.30000 CONLI 10 , (AM30 3 Tl01 1 CElLO 33 & IV:5001V RU31PI 150.00 -150.0 11.3000 - 3 0.30000 | g CHNLO 10 [ANOAMS Gill CElM 28; IV:5OO0CV la31I 150.00 - -r - IN - -- -150 o 11.3000 0.30000 |50. 0so oo nBL tASG ss TS1 _ _ _ . -150 0 | |l1.3000 crD&o Z6: lV:SOOlCV Nt:Ol - - - * 0.30000 | 150.00 C-NL0 2s AaGNIP ol I -150.0 i 1.3000 C- 31: [V51V W21 c------ 0.30000 t j t i i>S ] t 10' I sH!! I I 1~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~1 S ;1 ~ ~~~~~~~:1q' |01, .1lti Lll~~~~~~~~~~ i: ''' F t t.I.1~~~~~~~~~~~~~~~~~~~~~~~~~~~E I _~~~~~~~ C) cli N .eJ fOw (1 SYSTEM PLANNING DEPT. PDP95 PEAK 2002 SYSTEM PLANNING DEPT. PDP95 PEAK 2002 .. 2PP AT THE WESTERN AREA (2800 NW) , N f2Z' IPP AT THE WESTERN AREA (2800 NW) L 0) 0 3 PHASE FAULT AT BSP2 ON eOOKV BSP2-CBG LINE 4-j 3 PHASE FAULT AT BSP2 ON 500KV BSP2-CBG LINE gOPEN FAULT LINE 4 CYCLES METg OPEN FAULT LINE 4 CYCLES _______- ~~~~~~~~FILE: P02W IFILE: P02W in~ 20: 5AN2 0NK HSI | COILI 413 IV*2309V RY21 _ IS.00 1 13: Ai:BP- Tl - . - -150.0 1 | 1.3000 - 36: IV:230- RI9. - - - -0.30000 | [ ' CHNL 10: [E:1Q1 Gll] _ g . g ~~~~~~~~~~~~~~~~~~~~~~~~CHNkL# 36: IV:2309V SRTI I LSS.C *'--- -- -lS0.0 11 11.3000 - - -2-8-v- -- 0.30000 | t~~~~~~~~~ ~HL WI0 2: [AMCI U| Km 011 |H# 28: IV: 0SOOV P21. | llSO.SO ° ° ~~~~~~~ ~ ~~~~~~~~~~~~~-lS0.0 1 1.3000 - -* 0.30000 I _I fAG . S- TSI - 0. CHM# 32 (V 600KV - tg- 0.20000 I I ~~~~~~~~ ~~CNOI 25. (ANG.OIIP Uill --Q.l5 .0 11.3000 3K5.11 (V 500KV ISp2Z--------I..00 i;, I I ° - l o _ :~~~ ~ ~ ~~~~~1 -o _1 .- - 6 0 o f X 0 *T _t % I ~ ~ ~ ~ ~ ~ ~ ~ l 0~~~~~~~ I ji~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~0 III .~~~~~~~~~~~~~~3 i~~~4 \ L-.~~~~~~~~~~~~~~~~~~~~~~~ I ,.-i SYSTEM PLANING DEPT. PDP9S PEAK 2002 r. SYSTEM PLANNniG DEPT. PDP95 PEAK 2002 Fi : ~~~~IPP AT THE WESTERN AREA 12800 MsW) u)IPP AT THE WESTERN AREA (2800 NW) un 0 LINE TO GROUND FAULT AT BSP2 ON 500KV BSP2-CBG 2 LINES ^ - LINE TO GROUD FAULT AT BSP2 ON 500KV BSP2-CBG 2 LINES b4 0 (LL; OPEN FAULT LINE 4 AND 6 CYCLES (CONTIGENCY N-2) ; OPEN FAULT LINE 4 AND 6 CYCLES (CONTIGENCY N-2) i FILE: P02WBSP2-CBG FILE: P02WBSP2-CBG CENBL 20: IXAG:SNR H51 0| CHML 41: fV:2309V RY21 150.00 - - - - - - - -150.0 I 11.3000 - --- - - --- 0.30000 CMiNI. 15S [AM: PK Tl I CaM.. 36: 11V:230KV aRTI lS0.00 - - IJWG:XN -l-l -150.0 | Hl.3000 N . . 111131 0.30000 | 150.00 CHIL 13 IANGB3 TOI 300-lS0.0 1 .3000 CHNL0 342 IV:2300V KBSI 1201L 10: (AAJN EN 1 Ii CUE.* 28: fV. 50XVW 3(3 150.00 - … … - - -:-l--Ull -150.0 I 11.3000 - -3 -l-:-0-v --- 0.300001 H CmhN9 le IANG:SB TSI 32MN , rV,500XV CBGI 150.00 - - -150.0 (1.3000 0.30000 CHNOL# 25: fAONG IP Ull cm&#L 31: r1:500Kv SP2lI 150.00 -150.0 - 13 00 0.30000 k~~~~~~~~~~~. I ' il-o It I , ° 1 C I I o S 0 cS . I2 .i IN I S -~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~a I TI --~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~L x * SYSTEM PLANNING DEPT. PDP95 ,PEAK 2002 SYSTEM PLANNING DEPT. PDP95 ,PEAK 2002 9 rPP AT THE WESTERN AREA (2800 MW) IPP AT THE WESTEN AREA (2800 MW) ) Q) - LINE TO GROUND FAULT AT CBG ON 500KV CBG-SNO 2 LINES __ LINE TO GROUND FAULT AT CBG ON 500KV CBG-SNO 2 LINES '' PI nl " <1 OPEN FAULT LINE 4 AND 6 CYCLES (CONTIGENCY N-2) IOPEN FAULT LINE 4 AND S CYCLES (CONTIGENCY N-2) <: Cw FILE: P02WCBG-SNO FILE: P02WCBG-SNO U' , C HNL 10: IAUIG: SNR B151 1 ° CHllI 41: rv:230rV RY21 150.00 -30 - - - - - 1 - - -- - 0.30000 > CHOI 15: IANG:BPK Tll CU II 36: IV:230XV SRTI 150~00 - ------- -150.0 1.3000 x - ------ x 9._5.- iS0. 00 1 13: [AMO:MM3 T3O _ _ _34: VNBI _ _ _, | l50.00 C--0 il.3000 0.30000 15000~ ~ ~ ~~~CKL 0 AMX IIL'M 8 V:09 3 | 1 5 0 .0 0 l- l0 .0 - i 1.3 0 0 0 C 0 .3 0 0 0 0 - | 150.00 D-1500 il.3000 0.30000 12 _ I ~~~ ~~:1 I _ z. t _ ', 'v1 t _ o :1' l0§.1_ 3I- r--~~~ ~~~~~ I. ' 0 o >1 I~~~~~~~~~~~~~~~~~~~~~~~ * ~~~~~~~~~~~~03 I'~~~~~~~~~~~~~~~~~ I N~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~I k a.~~~~~~ : C Lu co SYSTEM PLANNING EPT. PDP95 ,PEA 2002 SYSTE PLAN DEPT. PDP95 TPEH 2002 A IPP AT TNi WESTEFN AREA (2800 NW) ..n IPP AT TNE WESTERN ARPD 92800 MW) 200 -y LINE TO GROUND FAULT AT CBG ON 500KV CEG-WNO 2 LIKES LINE TO GROUND FAULT AT C3G ON 500KV CBG-WHO 2 LINES OPEN FAULT LINE 4 AND 6 CYCLES (CONTIGENCY N-2) OPEN FAULT LINE 4 AND 6 CYCLES (CONTIGENCY N-2) FILE: P02WCBG-WSNO FILE: P02C13-NO l 150. 00 FILE 20:IANC:SN HSI - - - -.0 1.3000 C 0: iV230iYASll - _ 0.30000 | 050.0 00 CHt4L 15 1S: lA3pPig Tll K - . . ,,H_ -150.0 | | 1 3T0400 35: IV:230KV K 0.3000 i 150 .00 --00 - 13 3- - - - - -150.0 1.3000 0033: I P _ 0.30000. I g i 150,0 CHN5L0 10: -0,0 - H | 1.3000 CNNLI 28: iV:SOOKV 40431 0.30000 | H ISC OO ~~~~~~~CHNL 10: IANG:SBN Glll . I0 130 CHNL0 26: IV: 5001tV ltO _ _3 .00 [150.00 - - - -.SE-T-I- - -150.0 11.3000 - r- 0-Pr-l- - - - 0.30000 150.00 CHNL00 25: 1ANC:.IP Ull _____ , -150.0 | 11.3000 0I3II 31: IV:SOOXV SP_00 CHN 1. 25 1 4AW:WIP I I CHCi I I I I BI °o Co i;L I . . 0 .1 I C III~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~C SYrSTEM PLANNIG DEPT. PDP95 ,OLIGHT 2002 .. >} } . SYST2 PLANNING DEP. PDY95 ,LIGIfl 2002 IP TTE 81NAU 20 W SYSTEM PLANNING DEPT. PDP95 ,LIGHT 2002 'IPATEWSERAEA (80W a 3 _ P rP AT THE WESTERN AREA 2800 MW1 Pl - 3PHASE FAULT AT BSP2 ON 500Kv BSP2-CBG LINE 3 PHASE PAULT AT BSP2 ON 500KV BSP2-CBG LINE 1 OPEN FAULT LINE 4 CYCLES L2.* OPEN FAULT LINE 4 CYCLES a) a) m ~FIE:L2W11300FILE: L02W 150 00|ISO.OO COO 20: tG:0R HSI - - - -150.0 | @a CMi 41: rV:230KV RY21 _ _ 2 D 1 150.00 CRILI 15: lAG:EBPK TSI -ISO.O H *1 | 1.3000 OCHNLS 36: IV:230KV SRTI N * * 0.30000 | 1 150.00 CtiNBI 13: UlNB:19t3 TBI - - - - . -150.0 1 .3000 . . tV:2301V . . 0.30000 I g | 150.00 CHL 10: rAIIG:tW Gll1 -150.0 i 11.3000 C-NLt 2-: :SOOV - -31 -- 0.30000 | H 150.00 ~ ~ ~ CUL 110 5 I)J~COOL# 32: fV;SO0KV MaOl | 150.00 CaL< l: lAas:sB _ _ _ -150.0 | | 1.3000 CNNLt 32: IV:5001V- - -150.0 11.3000- 0. CKNL# 25: F00M0 I2 Ull CM*L 31: MVsoorV DSP2I 150.00 CHL-2:t------Q -150.0 I |1.3000 - 0.30000 1 -~ ~~ I o. IX *8 oI ' i I ~~~~~~~~~~~~~~~0~~~~~~~~~~~~~~ _ } I . _ r _ } R X § _ r t C . . _~~~~~~~~~~~~~~~~~~~~ :4 a~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~0 C! 04~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~' [w] SYSTEM PLANNING DEPT. PDP95 LIGHT 2002 . SYSTEK PLANNING DEPT. PDP95 |LIGHT 2002 IPP AT THE WESTERN AREA (2800 MW) i P AT THE WESTERN AREA (2800 MW) t -4 LIKE TO GROUND FAULT AT BsP2 ON 500KV BSP2-CBG 2 LINES LINE TO GROUND FAULT AT BSP2 ON 50o0V 3SP2-CBG 2 LINES . CO | 150.CO FILE: L02WBSP2-CBG - FILE: L02WBSP2-CBG _3 Cd ~~~~~~~CHOOLO_20:__1ABM _NR H51 __ __ _CM___ __ _41___ __ __ _V__ _ __ _ 3__ __ _V __ ___Y21__ __ __ _ IOL 150.00 IJ ' .NG:PI Tll -150.0 . 1.3000 L 6: [V:230V RTI - - - -- -- 0.30000 | |150.00 CHIL0 13: IANrG:03 TBI - _----- _ -1.3000 [CHNL 34: IV:2301VB_ 0.30000S| | 150.00 ~~~~~~CHNL0 10: IA16G:IQ Glll -100 l .30 L 28: IV:500XV K310300| 050.00 -4 - -050.0 (1 k .3000 - X. .N -- 0.30000 cmm#. 13: IAM02iz( TElC CHNLOO 32: lV*500KV Cal I 150.00 -150.0 | | 1.3000 CfL3C_0.30000 | 050.00 ~~~~~~~CHILO 30- lAawlwp GUll -CHN4 318 fV:500XV BS(21 03001 | 150.00 - - -150.0 | 1-3000 - 3 * 0.30000 | |~~~~~~~~~~~ I I Xo ij f I Ia r Co Cc~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~S t : ~~~~~~~~~~~~*0 t.4 .4>g6 0 I § ffi t t. z 0: I I 9 I c!~~~~~~~~~~~ . _ I j ]~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~I I I ~~~~~~~~~~c 0~~~~~~~~~~~~~~~~ I - ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~o ~~~~~~~~~~~~~~~~~~~~~~~~~~L .~ ,1 uGSYSTDE PLANNING DEPT. PDP95 ,LIGHT 2002 SYSTEM PLANNING DEPT. PDP95 ,LIGHT 2002 w ~~~~ LINlE TO GROUND FAULT AT CBG ON 500KV CBG-SNO 2 LINES IPP AT THE WESTERN AREA (2800 2W)INES zi_ Co f I LPfPfE TTOTfGE if ZDTFA^LTRE&T CB(G 0fw1 500N CBG-SlfO 2 LINES LINELINE TO GROUND FAULT AT CBG ON 500KV CBG-SNO 2 LIES ;1 bt 1z ' 1 o PEfN FAULT LINE 4 AND 6 CYCLES (CONTIGENCY N-2) OPEN FAULT LINE 4 AND 6 CYCLES (CONTIGENCY N-2) A cof FILE: L020(!BG-SNO a, FILE: LO2WCBG-SNO in IO X 300 - - - - ---CHNL0 20: [S H -lS0.0 | 5 1.-3000 . a 1 1V230zvpY21 _ _. iD3009; CM$L 15; [ANG:BPK T11** CDIWL# 36, 1v20V 0.30110 lG . 150.o00 ---a-3 15: l - - -- K -1500| C 36: V:230SRV S, X 0.30000 | l ~~~~~~~~~CHNW 13:4 fAmG:m3 T31 d HL 4 £29[ ff 150.00O -0 M0 G I 110.300 001 150.00 -oo- - 1- O 1 - - - - -150.0 | iI3.0ooo -l-L- 32, [v:ooOXV 13- - - - -; 2 l5: tAM:KP. 11 -150.0 | 11.300 CHmL, 31: IV:5009Xv spil -_1.3o _ ' 1 ,' ', _ . _ 1'3000 0 : .t 4 0 ~~~~~~~~~~~~~ SYSTEM PLANING DEPT. PDP95 ,LIGHT 2002 N SYSTEK P OLANNING DEPT. PDP9 5S ,LIGf 2002 IPP AT THE WESI'EEN AREA (2800 NW) 1FP AT THE WESTERN AREA (2800 NW) L LINE TO GROUND F)AULT AT CBG ON 500KCV COG-WNO 2 LINES LINE TO GROUND FAMLT AT CBG ON 500KV CBG-WNO 2 LINES OPYEN FAULT LINE 4 AND 6 CYCLES (CONTIGENCY N-2) _ OPEN FAUT LINE 4 AND 6 CYCLES (CONTIGENCY N-2) bi a | *so.ooFILE: LO2WCBG-MIO x FILE: L02kCBG-WO ,| CHNIi 20,. IANG;Ma 1151 cm.~ Icmi fV2O Al 0015: . --, -150.0 | 11.3000 I - - - - - -* 0.30000 | cmii 150 oA1n.SP Til _ CHNL# 35: [Vo23OKV mll _,| 130.00 ' .10 . . . . ..50.0 I 11.3000 x . . .S.O. -. . K 0.30000 I c Iii1 AiM*NR Telj CfUA 33- rV.SDOOV kIPPI 150.00 CHNLS -150.0 i | 1.3000 t 0.30000 | 150.00 ~~~~~~~CHIO 10: IANG:Ail 0111 -C-10. * j L 23: W-----* .3000 I W250.00 - --------i 1lAP l * -i50.0 1 11.3000 O.il 2 KV OVp 0.30000 150.00 1 - .0' I I 1.3000 C -2 , , VS0.30000 150.00 CM#i 23. IANW:WP Ull c10. t.00 31. [V.SDDNV MP2 I.00 t I ~~~~~~~~~~~~~~I-Ill I t I Ii I ,~~~~~~~~~~~~~~~~. I , "2 ,L, , ,; - . .~~~~~~~~~~~~~~~~ . _ T- -v- 7~~~~~~~~~~~~~o I S. .1~~~~~~~~~~ ..... o~. * 10 l~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~- x *H r.*. SYSTE3 PLANNING DEPT. PDPS5 ,PEAK 2003 SYSTEN PLANNINh DEPT. PDP95 ,PEX 2003 l K IPP AT THE WESTERN AREA (3800 NW) '0 IPP AT THE WESTERN AREA (3800 NW) 0) 0) ~~' OP SEN FAULT LN AT CYCLE ON50aP2CGLN 3 PHASE FAULT AT BSP2 ON4 500KV BSP2-CBG LINE 3 AE FAULT Ai ES OPEN FAULT LINE 4 CYCLFS I u 150.00 PILE. P03W s _ _ -150 0 | 1.1000 PIE- P03W , _ FILE:0P0300FILE: P03W CHNOL# 20: rANG:SNR HSI CIM 1t: fV-230KV R2 150.00 I 11 -- - - - - -150.0 1 1 1 .3000 - - - - - - 0.30000 1 CMu. IS: tAN3t*3 ITl _ CHL 35* 1V:230XV _ --- 0.30000 1 > 150.00 ' CI-# 10 I---- Gxll * -150.0 1 J1.3000 .... 2.: .. 0.3000e 1 A 150G.00 CHNL o: tOl A liS SA _ - - * -IS0.04 i 1X.3000 32V: V r71.000 _ - - - - 0.30000 1 CHN0L 25: FANG:WZP )I, -150.0 TSI ClO 31: IV;S00IV * 0.30000 | 15 0 _ .3000_ D, _ 10 00 150.00 -1* .l 0.0 - 4 03 000 0 ; q [ k tt~~a 1 0 3 6.'., I''X'S 0 1'fi'S'0 , , ,S,'',1,.',, , , fi 1' I S i,,S l 0 ~ ~~~~~~~~ .i . * . * 1 0 0~~~~~~~~~~~~~~~ 0 * 0~~ -1 oS SYSTE4 PLANNING DEPT. PDP95 PEAiK 2003 [. SYSTEM PLANNING DEPT. PDP95 PEAK 2003 . IP A E I A 30 IPP AT THE WESTERN AREA (3800 MWN) ' LINE TO GROUND FAULT AT BSP2 ON 500KV BSP2-CBG 2 LINES LN T DIO aB : G 0PEN FAULT LINE 4 AND 6 CYCLES (CONTIGENCY N-2) OPEN FAULT LINE 4 AND 6 CYCLES (CONTIGENCY N-2t FILE: PO3WBSP2-CBG PILE: P03WBSP2-CBG 150 00 -150.0 |1 3000 CHNW 41: rv 230xv r21 - - _ 0.30004 | ' 150 0 CEMLO 15 IANG BPX T1l 1.3000 COL, 36: rV:230xV SRTI x K 0 |15.00 - - - - -1 - -5 -lSO O |3000 c.... 3. I.230. _ 0.30000 | < LIM#I 10, r0NG00 TS]oll CHNL# 34, IV:230KV NBI3 150. 00 -lOO.0 1300 0.30000 | F 150.00 ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~*-150.0 I4 *1.3000 9 |IS 1O.0 CNIW 1 IANG SB TS1 -lS O -10. |1.3000 cHOL 32: IY SOOXY -BG _ _ .00 | lSO OO ~~~~~~CHNNBO 25 IANGWIP Ull -SO||1.00cHNs 311 rv:500xY BSP21 0100| i 150.00 25~-150.0 1 [.3000 *----C 0.30000 1 k i ' l ~~~~~~~~~I II | I I i 0 Q ts t 0 g ~~~~~~~~~~~~~11 |EU I~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~I 2-~~~2 o 1-4 ,4.; I o . S E° * LC&~~~~~~~~~~~~~~~C q CeI . c\ \4 IL~~~~~~~~~~~~0 w In In x X I SYSTEM PLANNING DEPT. PDP95 ,PEAK 2003 SYSTEK PLANNING DEPT. PDP95 PEAK 2003 . w *,H a J\/ IP1' AT THE WESTERN AREA (3800 NW) IPP AT THE WESTERN AREA (3800 MW) 1r -1LI1NE TO GROUND FAULT AT COG ON 500KV CBG-SNO 2 LINES LINE TO GROUND FAULT AT CBG ON 5OOKV CBG~-SNO 2 LINES OP N FAULT LINE 4 AND 6 CYCLES (CONTIGENCY N-2) < LrOPEN FAULT LINE 4 AND 6 CYCLES (CONTIGENCY N-2) In FILE: P03WCBG-SNO FILE: P3 2 2 oe CML 20: [Ais 51 -HSI0 - I I C004L8 *1: [V:2'1C I OYll -.3ee oe 1 t ____OC CNIIW 15: [ANG:BPX Tll X K -150 .0 1 1. 3030TCO 36: rV:230iV 01TI * 0.30000 | 150.00CHNL013: IANG:113 t331 _ _ _ _ -150.0 | |1.3000 3:IV:230itV NI _ _ _ _ _0 0.30000 t C H NL0 10: iJl3 iG :X G il -15 . T0 28 . [V :SO O iV N031 1 CR5010 1 lASo_------ -is |. 1 3000 - - -- -- 0.30000 I 150.00 CllXS 1: 1ANO: 5B T51 _ _ _ . ~~~~~ ~ ~~~-150.i 1 l.3000 CHN -2 IV50X CBG - - -. 0.30000 150.00 CHN L 1 25 [ANG:NIP .11 1 11.3000 c 3 1: IV :500 V sP21 - 0.30000 1 IM 5 ' :II IwPUl CM I1 IV5oK aI o -r~~~~~~ * l " 0 E|{-O 150.00 il.3000 0.30000 1 4. *- d>1t ti §tH-I L~FJ 1 . J [ 0 1 T 4' C 2 B 0 ' * 0 03 * I I'~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ C) -I; 02~~~~~~~~~~~~~~~Q I~~~~~~~~~~~~~~~I I ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ C * 00 I. ~~~~~~~~~~~~~~~~~~~~~~~~~~ C~~~~~~~~C II :0~~~~~~~~~~~~~~~~~~~~~l .1 '~~~~~~~~~~~~~~~~~~~ ~~~~~~~~81~~~~~P SYSTEM PLANNING IEPT. PDP95 PEAK 2003 .. SYSTEM PLANNING DEPT. PDP95 PEAK 2003 cI LINE AT RON FAUTE ATEGO 500K CGN 2 LIE_ IPP AT THE WESTERN AREA (3800 MW) LINE TO GROUND FAULT AT CBG ON 500XV CBG-WNO 2 LINES I LNE TO GROUND 4AULT AT CBG Y N SLEKV CBG-TiNO 2 LINE zD 1K"- OPEN FAULT LINE 4 AND 6 CYCLES (CONTIGENCY N-2) OPEN FAULT LINE 4 AND 6 CYCLES O CONTIGENCY N-2) L FILE: P03WCBG-WNO FILE: P03WCG-WNO In 3 . CHIL 20 [AM: HSNR K) -1000 |1 CHNLO 40: IV:230KV ATll - , _ _ _ 0 0 00 CHNL# 15: [ANG:BP TIl -150.0 1.3000 CHNLI 35: iV:2301V K I 0.30000 > 150D00 CHNL 13. A... T81 . . . -150.0 | 1.3000 CIL 33: I .. . . 0.30000 | i 050 .. . CHNJLf 10: IANG:H N G Ill _3| CUNLI 2S: IV:SOOKV 110.30000 _ _ _ - -- - - -* -lS0.0 | H |l.3000 * ----' 0.30000|H I CYNL 1: tANG:SB TSI _ i ClM 26: FV:SOOXV KCOI | I150.00 - - - -lS0.0 1 1 1.3000 2 * 0.30000 1 | 150.00 CNNI.I 25: IANG:WIP Ull ___u- -15U.0| 11.3000 0L 31: Iv:SOKv SP20 - 0.30000 | t:~ ~~~~~~~~~~ I, ']I .-1-- I1X' S 0 0~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ I. 01~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~1. ' I ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~c-t A~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~( 9 . IL. 0 q co~~~~i C.) X SYSTEM PLANNING DEPT. PDP95 ,LIGHT 2003 [ SYSTEN PLANNING DEPT. PDP95 LIGHT 2003 IPP AT THE WESTERN AREA 13800 04W) IP TTHE WESTERN AREA (3800 MW) kol -Ii (-'1 ~ 3PHiASE FAULT AT BSP2 ON 500KV BSP2-CBG LINE PHASE FAULT AT BSP2 ON 500KV BSP2-CBG LINE ~ii1OPEN FAULT LINE 4 CYCLES OPEN FAULT LINE 4 CYCLES P. ~~~~~~~~~~FILE: L03w a,"FILE: L0~3W h5 0 - ~N~2:JA~:~R13 - - - - -. 150.0 I113000 - L 2 v:3z YI- - - -~ - 0.300001 -150.0 0.30000~~~~~~~~~~~~ CHNlLS 13: fANG BP3 T81 C.00 MI 34, lV:23GKV ND] .300 6150 00CIL 1 AGMN o -050.0 11.3a00 -IOL- 4 -:2-KV -- 0.30000 150.50 ~~~~~~~cOOJL 100 lAICiKN Gill I * 1.00CENLI 280 [V:500KV MNI 3100 CHN0.# 1 tAN9 SB T51 CHNLi 32: lV-50010V 12B f 15.0.0 71 -0-050. (4 1.3000 - - 0.30000 1 150.50 -10l 1.3000 -------- 0 0.30000 I - ~~~~~~~~~0~~ I . 0 Ij a~~~~~~~~~~ * ~ ~ ~ ~~~~~~~~~~~~~~~~~~~~~~~~~~~~ I L ' I. fI~~~~~~~~~~~~~~~~~~~~~~~~~~~~o I I : ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ I., 4~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~g f*~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ K~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~d 1-~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~c ~~~~~~~~~~~~~~.~~~~~~~~~~~c I I~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~L SYSTEM4 PLANINING DEPT. PDP95 LIGHT 2003 ' ~ yTE4PMNGDET D9,LGT20 IPP AT THE WESTERN AE.EA 13800 MW) IPP AT THE W'ESTERN AREA (3800 MW) LINE TO GROUND FAULT AT BSP2 ON 500KV BSP2-CBG 2 LINES LINE~ TO GROUND FAULT AT BSP2 ON 500KV BSP2-CBG 2 LINES OPEN FAULT LI -2)~~~~~~~~~~~~~~~~~LIE 4 3j4~~ OPEN FAULT LINE 4 AN4D 6 CYCLES (CONTIGENCY N-2 OPE FAULT LINE 4 AND 6 CYCLES (CONTIGENCY N-2) 24LO ~~~~~~~~~~~FILE: LO3WBSP2-CBG FILE: LO3WBSP2-CBG C 1( I COLO20-AO- 51- - - - 1001300 - - - - -41:1V - - R 10.30000 CHNL4 15: [AM: BPK Tl - I CHKL# 36: rV:230V SRTlJ ' 200 00 - -. -- -350.0 12.3000 '.'.... 4 0.30000 150.00 CMM#. 10~ fA34G:3 T i -150.0 11. 3000 CKNL# 24: lVS230KV NBI1 0.30000*1 * CHNo.. 1G [AN000 Gll51. CHNL# 328: iV5005V MEGi431, i 150o.DO - - - -- -150.0 11.3000 - - - --4 0.V3D000 CKNL# 25 IANG,S WT 111 CHNOLO 32: fV:500KV 00B21 1150.00 .------ -150.0 I 1.3000 S------- 0.30000 ChNL 25 (AN *WI Ul 15. il300CHI 31 IV:0K BS2 ---I.00 V 4I 0~~~~~~~~~~~~~~a4 0~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~~~~~~~~4 0 EU~~~~~~~~~~~~~~~~~~~~~ E.~~~~~~~.1 00 4~~~~~~~~~~~~~~~~~~ V . S ( 4'~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~Lr S.S - 4. .4" ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~R us 0 04 _a-&4~W _4 C 6YSD/ 2003 A S- STEI PLNNIN DE"P. PD095 ,LIGHT 2003 t N - ]:~~PP AT THE WESTE*RN AREA (3800 HW) to,l|IPP AT TttE WESTRSN AREA (3800 KW) r j VAL.-J LINE TO GROUND FAULT AT CBG ON 500KV CBG-SNO 2 LINES LrNE TO GROUND FAULT AT CBG ON 500KV CBG-SNO 2 LINES 0 G'i a)| .(oPEN FAULT LINE 4 AND 6 CYCLES (CONTIGENCY N-2) OPEN FAULT LINE 4 AND 6 CYCLES (CONTIGENCY N-2) i [20 o FILE: L03rWBG-SNO _ FILE: L03iCBG-SNO In ~~~~~~ ~~~~~CINL# 20, [A-.-.-N cmOL514 IV:23KV RY210300 | 150.00 C-- 15 rn P TI j - - - - - C-L 6 V230K ST _ - - - - - - 0.30000 10.0o0c 13 rAin t3o~ Th[ - -150.0 | I | 1.3000 CIIOOLO 34. fv 230Kv 1-30-0 0.30000 | g 1a.00 - CHNL[.0 10- lAMin GTll . |1.3000 A CM# 20: [V.2300V T 0.30000 | 151.00 - -c3 1 1 ANG:s T S 1 - - - - -150.0 11.3000 32. [V:5000 - . .30000 COOSIL 25. OAOD.5lIP0 CEOOL 31: rV:230KY NSPlI 050.03 C -10S0 | 1.3000 C-3 0.30000 | ll 5. -.. C, 10: [hM:KN I -'K I - - -'a - - , , , , 2 CM#1 ANG TI, aH ./3 I -SQ- Cola ITI. _5 -150.0~~~1i '1(DI _ t z X S _ o _ *'x\ § 13' I.X dmI I* a I~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~aC t a00~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~0 I:~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ .~~~~~~~ ., ~ ~ ~ ~ ~ ~ ~ ~ ~ X It SYSTE5 PLANNING DEPT. PDP95 LIGHT 2003 SYSTEM PLANNING DEPT. PDP9s ,LIGT 2003 .0 et IPP AT THE WESIER2N AREA (3800 MW) wIPP AT TEWESTEN ARE (3800 M) Wr i_ LINE TO GROUND FAULT AT CBG ON 500KV CBG-WNO 2 LINES LINE TO GROUND FAULT AT CBG ON 500XV CBG-WNO 2 LINES a) C2 ;, ,'" OPEN FAULT LINE: 4 AND 6 CYCLES (CONTIGENCY N-2) i In. OPEN FAULT LINE 4 AND 6 CYCLES (CONTIGENCY N-2) iH 0 FILE: L03WCBG-WNO FIFLE: L03WCBG-NO 9 (d i anKL~~~~CM 20: fAN3:S HiaSI g0 gD 0 v2craI I150. 00 - - - - - - - L30 i43000 --- -I-V-I- -- 0.30000 i i50.00 CHt IS: 1 AN:BP Tll -15 0 | 1.3000 GHNL# 35: IV:230KV 1011 . . . . 0.30000 | CRnLE 13: IJAW :3 T'3 - 0 G . 4 31: IV 500EV RUPPi J 2 150.00 - -150.01 1 1.3000 - -- 0.30000 1 C | CNNRIL1 10: [aN3:N Glll _RlL 30 *V _50 8 [:SOV IQ131 1 I 150.00 -- …------ ' -150.0 I .' 11.3000 0.30000 .-. 150.00 Cl*I 1: IANGlll -15 - - . - - 1 .3000 |CHNLL 26: iV:500KV UCOI -- - 0.300001 CHNlLE 1030 FAGlS T51 J I CERLE 31: [V.5QKV NMI1 150.00 _ _ -150.01 11.3000 - 0.30000 I lS0.0CHNL1 25: AWI Ull C |I 31: IV;0V BSP21 0 150.00 -lRoI 0 1.00 03 000 0 3*~~~~~~~~~~~~~~~ ,~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~j l. N O 1 I . . Ho° ,'1 _ zoO t C F I~~~~~~~~~~~~~~~~~~~~~~~~~* 1oo : o 0 - I I 1t 1,'''11 1'''.I3lCi 0L>-l C= g. I ~~~~~~~~~~~~00 I ~~~~~~~~~~iI I I I. 0~~~~~~~~~~~~~~~~~~~~~aD 0 /, ~~~~~~~~~~~~~~0 CO) 0 0.. r. r X SYSTEM PLANNING DEPT. PDP95 ,LIGHT 2004 ENSYT~ PLANNING DEPT. PDP95 ,LIGHT 2004 X IPP AT THE WESTERN AREA (4200 MW) t-I N TO RN FAULT AT CBG ON 500NT CBG-SNO 2 LINES LINE TO GROND FALT AT CBG ON 500KV CBG-SNO 2 LINES 0 (D 4) O'PEN FAULT LINE 4 AND 6 CYCLES (CONTIGENCY N-2) E.- OPEN FAULT LINE 4 AND 6 CYCLES (CONTIGENCY N-2) FILE: A FIEn 050 1CH s 20:tAlrw [0 0111H51 --150.0 | I 41: 0:230tsv- - - - - - - 0.30000 150.00 C-w 1S- ---G:OPn -K -1SJ. '3 | 1.3000 COOOLI 36: 230rv sT3 - K 0.30000 | c_ t 13- 101:43 TS) - - - - - -100 1.33000 CHNL0 34 [-230KV NIS - - - - - 0 | | lSO . D0 cBL! 10 tAss: B Gll l ~~~~~~~~~~~~~~-150.0 I 4 1 30 lN6} vsoS e3 .30000| C0 CI t1 : iB TSI - lS-053.0 | | 1.3000 32: [V:500KV C1. 0.30000 ~l o 0.0 -U# -IN~S 5 -150.0 1 E 1i.3000 - 0.30000 150.00 o- -0CtWL 25 tA)X:WI1.3000 e -SD0|-CHNB 31: [v soo-V BP-1e 0.30000 1 F - A | ° | k C b So. ° I LtS - 11g10 _ I; / , ' 4 - (, ; X - x sUl - ;> ~~~~~~~~~~~~~~~~~~~~~-, 4 4 Q-- -4 I ~~~~~~~~~~~~O ....) /~~ . ( .4' ~~~~~~~~~~~~~~~~~~~ oO~~~~~~~ 4 ...~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~0 K / 44 &54c 0~~~~~~~~~~~~~~~~~~~~~~~~~~L 4., a.ca 0~~~~~~~~~~~~~~~~~~~~~~~~~~~~c H < SYSTEI PLANNING DEPT. PDP95 PEAK 2004 SYSTEM PLANNING DEPT. PDP95 PEAK 2004 .- 0 ~~~~~IPP AT THE WEST:ERN AREA (4800 NW) IPP AT THE WESTERN AREA (4800 NW) CPASE FAULT AT BSP2 ON 500KV BSP2-CBG LINE > 3 PHASE FAULT AT BSP2 ON 500KV BSP2-CBG LINE z t " ~~~OPEN FAltLT LINE I CYCLES OPEN FAULT LINE 4 CYCLES E FILE: P04W FILE: P04W < > | lS0.00 ~~~~~~~~~CHNL 20: [tNG:BFK T51 -IS0.0 | |1. 1000 C 1IV20 1 _,__ 0.30000| too ca C004L# 15: 200 Tll51 - - - -~ . . - x -150.0 | 1.3000 C 1 3 V:230 loco x - - - - - - - 0.30000 CttNLO 13: IANG:H1 1"31 T | | CHNL# 34: fV:230KV S31 NBI T.oo C01 1. K -150.0 | H 1.3000 C 0.30000 H CtWM1 10: tMNG:XN T51 N CHN 328: (V:500Kv CSG3| l50.00 - -f-3- - - - -' -150.0 1 11.3000 - -o- - - - - - - 0.30000 H CHNI 10* IAIHI SE T1 GO CHINLS 328 (V:50OtV 0*43 150.00 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~-* -130.0 H 1.3000 * 0.30000 H. | IS0. 00 CHNL0 25: lANG:WVI- Ull -10.0 |1.3000 C-M# 31: (V:5001W BP21 0.30000 | , I I~ ~ ~~COL 25 IHO HI *i , CIOL 31 ':50K ESP21-£ I ~ (''K '1 I 'l I I I IX . 00 44~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ I I X ,'- ,:''. , f"'~~~~I I LiSl to 0 q~~ -~~~~~ ~~~~~~~~~~~~~~~~ :.1 ' .. aD~~~~~~~~~~~~~~~~~~~~~~a 53 ~~~~~~~~~~~~. oN~~~~~~~~~~u X. SYSTEM PLANNING DEPT. PDP95 ,PEAK 2004 j SYSTEM PLANNING DEPT. PDP95 ,PEAK 2004 . V-. -- IPP AT THE WESTERN AREA (4800 MW) r , IPP AT THE WESTERN AREA (4800 £)lI . - LINE TO GROUND FAULT AT BSP2 ON 500KV BSP2-CBG 2 LINES ' ' LINE TO GROUND FAULT AT BSP2 ON 500KV BSP2-CBG 2 LINES ' Ui ~ Z2i GPEN FAULT LINE 4 AND 6 CYCLES (CONTIGENCY N-21 O2.Z1 OPEN FAULT LINE 4 AND 6 CYCLES (CONTIGENCY N-2) FILE: P04WBSP2-CBG Ch FILE: P04WBSP2-CBG n la , 1 150 00 C N N T,t 2 0 : IA N G :S N R 1151 0I ,| IV :230K V R Y 21 I , _ a 50 00- - - - -7150. ' 1.3000 Om 4 v~Jx Y1- - - ~- - - .50 0 I a _ _ _ C HN Bt 15: f : BPK T1 I - C HNL t 36: Y1:230 1V SRTI ,0.30000 150.00 44. . .4' -150.0 '~~~~~~~~~~~~~~~~~~~~ 1~1.3000 - -. .4- -- 0.30000 I 150.00 CMt 13: IANG:MM3 T0? - 0 | - | -.5.00 CM$ 34: (V*230KV NBI _ _ _ _ 0 1150.00 C-OG 10 - - -- -150.0 | - ….3000 - - - --- 0.30000 | 150.00 c1nn; 1: tAN1:gSB a51 - -150.0 1.3000 CBNLI 12: IV:5001N- - - -0.30000 CHIIL# 25: fAN1:WIP Ull (-lS 0.0 I1 1 300 CHONLt 31: (V:500KV BSP21 0 1100.00 I 'I I 1000 I . ~I 170.30000 _ '~~~~I .'S_O _* S _O 6 I . 6 1 Bv 10 4 ,~~~~~~~~~~~~~~~~~~~ LII~ ~~~~ .j. a I ' I .0~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~- 0 ,. c5J~~~~~~~~~~~~~~~~~~~~~- E L i J I I '~~~~~~~) I % -~O ~ - x S K PLANNING DEPT. PDP95 PEAK 2004 [ ] SYSTEM PLANNING DEPT. PDP95 PEAK 2004 {3 Wv-) IPP AT THE WESTERN AREA (4800 MW) IPP AT THE WESTERN AREA (4800 MW) C. i LINE TO GROUND FAULT AT CEG ON 500KV (CONTIGENCY N-2) H LINE TO GROUND FAULT AT CBG ON 500KV (CONTIGENCY N-2) CL OPEN FAULT LINE E AND 6 CYCLES (CBG-SNO, CBG-SN02i OPEN FAULT LINE 4 AND 6 CYCLES (CBG-SNO, CBG-SNO2) S L b b FILE: P04WCBG-SNO2 FILE: P04WCBG-SNO2 a, Cd X 5.0cHtLI 20: lANG,:Sb 5135 i00||130 CNN1# 41: IV:230XV RY21 o ,__> 0.DO ~~~~ c:: :0 .~~~~~~~~~~~~~~~~~~I--- - - - .. '0 1 11.3000 0mI64~?~3KR2 .3Goooo | lSO.O CHKNLt 15: [HNG BPK Tll - o CHNILI 36: IV:230KV SRTI , 150. 00 . . ....T31 -150,0 | | 1l.3000 4 030000 .CNL 10 GN Gil0 CL 3 IV - - - - -- 0.30000 150.00 CICIL4 1: tANG:5 1 51 -150.0 | 13000 CHNLE 32: IV:500KV Cs? I - - 0.30000 | 150.00 -150 I 11.300 0.30000 CHNL.6 25: fAOOGNI WOO S? CHNO. 31. [V:500XV BSP2) F150.00 9------- -150.0 i 1.3000 9- -- ---- 0.30000 I- I , I tI |- I L ~ |I I I B IO 1 0 . . C Es C~~~~~~~~~~~~~~~~~~~~~f ,~~~~~~~~~~~~~~~~~~~~~~I . ' o -5~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~- 8 w~~~~~~~~~~~~ UV) Ca SYSTEN PLANNING DEPT. PDP95 LIGHT 2004 SYSTEM PLANONING DEPT. PDP95 LIGHT 2004 .H O IPP AT THE WESTERN AREA (4800 NW) IPP AT THE WESTERN AREA (4800 NW) - B | PHAEN FS^AULLT AET B0000 vi150 00 C lii 13 10040 S3 _ -150.0 1 . K 13000 34 V 2300 1 _ _ _ _ 0.30000 | 1 COOLS 10, fANG,M GTll CHMOL 340 IV 0.30000NET 150.00 CHNLO 1 0A:KN 0 I l - - -150.0 | F1.3 CRNLI 2a IV:S00KV 31 - - 0.30000 1IG.L0 #2 1: 003 [AM 51_ 5 CHNL 312 IV:SOQIV CBG21 1 150.00 S-~~~~~~~~~---------~~~~~~~~~ -150.0 i P 11.3000 0.30000 I k i150.00 CNNLI 25: [ANG:i1IP Ull -150.0 1 3000 ClINLl 31: (V:500XV RSP21 -------- 1.30o -I | I I I . ~~~~~~~~~~~~~~~I IA- I I I S T111111_° _ , ~ ~~ I , ' < _.1' _o : IL . a . . . .. o '~~~~~~~~~~~~~~~. 00~~~~~~~~~LLc 01~~~~~~~~~~~ L i~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~-a~a I-I a',, SYSTEI PLANNING DEPT. PDP95 ,LIGHT 2004 SYSTE5 PLANING DEPT. PDP95 ,LIGHT 2004 IPP AT THE WESTERN AREA (4800 MW) 4 N) NI LINE FALTO GRIUNE 4A ANT6 CYCLES 0CONTIGNCY BSP2-CBG2 LINES LINE TO GROUND FAULT AT BSP2 ON 500KV BSP2-CBG 2 LINES FT GOND FU AT 6 C ONTIGBNCY N2L OPEN FAULT LINE 4 AND 6 CYCLES (CONTIGENCY N-21 a.) 02EN ~~~~~~~~~FILE: LO4WBSP2-CBG (hFILE: LO4WBSP2-CBG "h 1L | 150.00 ' CllNtL 20: (AM SNGR H51 I CHW4 41: IV:230KV ,__ 0 3 | V50.00 C 1 . T y , y -150.0 |i 1 .3000 - - - - - - 0.30000 | 0 1lS0.00 CEILI15: IANAG:BPK TSI -150.0 |3 CiDL 36: PV:230KV SRi > _ 0.30000 1 |IS0. 00 CNJ1:IN:NGi -150. |H 1,3000 xHL -3 -VSO: -1 - -- _ 7 x-__ 0, 30000|H I 150.00 CMH 13: FANG 13 TO) - - - --- , | | i 1.3000 CH14 34: IVP230KV N) _ _ - . 0.30000 50,00 . C 25HNI : 1fANG:KN Gll ,, CH-L0 2: IV:500KV M K 0.30000 I COIso ANGSE O)-------- - -10, 1.30IN*32 .-- ----- 0.30000 H- I I ri- CHNLI 25 [ANGqB T501 :0 CMZ# 32: rV:500 00P23 1 :~~~~~~~~ ~~~~~ rH OK - +1SXG- 150.0 - 0 I il.3000 0.3I 00 0000 _ t .~~~~ I . 0 ''t, 0 I x r i [ t l X S Wi~~~~1 0 ,t 0 X o { X S $ o |~~~~~~~~~~~0 ...~~~ ,. It oO~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~' I ~~~~~~~~~~0 9 0 A I o~~~~~~~~~~ I . 0~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ V ~~~~~~~~~~~~~~~ CJ~~~~~~~~~~~~~; 0Ia - CL~~~~~~l 0. L [] SYSTER PLAING DEPT. PDP9s ,LIGHT 2004 SYSTEM PLANNING DEPT. PDP95 ,LIGHT 2004 H IPP AT THE WESTERN AREA (4800 NW) IPP AT THE WESTERN AREA (4800 MWr I. INE TO GROUND FAULT AT CBG ON 500KV (CONTIGENCY N-2) ^ LINE TO GROUND FAULT AT CBG ON 500KV (CONTIGENCY N-2) OPEN FAULT LINE 4 AND 6 CYCLES (CBG-SNO . CBG-SN02) U i"i OPEN FAULT LINE 4 AND 6 CYCLES (CBG-SNO CBG-SN02) FILE: L04WCBG-SNO2 F_LE|3 1 02, 15 0CHN4L# 20: [AN4G:SNR H(51 I ELO4:(V31 02 t s oo cIV 1S fM :EPK Tl- -150.0 CL 36: V:Z30KV aT - - - - K 0.30000 1500oo C=LUI 11: (A0G:BPK3 Tt1 -15O.0 | l |1.3000 CMM# 346 IV:230KV NBJ _ __ 0.30000 | 150.00 CHNLI 10: fA N Gll -1-- -150.0 1.3000 CIO 20: (V:SOOKV H131 0.30000 | F _50.00 1 1 1IJG:SB S51 _ _ 3000 CtDLI 32: tV:SOOKV C0G1 J50.00 - -50.CHNL 25: IANG:WIP Ull e - 5 1.3000 CtQi 31: VOKV B 0.30000 150 00 ~~~ ~ ~~~~~~~~~~~~~--------- -~ 1.3000 0.30000 I I I 1 K_ l ' I i I 1 I I I _ I '. I | s L H00 _ '.\11 - _ 0 L ' 0 0 -o F I I I 1 1, g ,( I i ' I I I ___1 1 K 1I1 S * j _' _ _ K 1:~~~~~~~~~L1 .; S.~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~u -, ...J~~~~~~~~~~~~~~~~~~~~~i SYSTEM PLANNING DEPr. PDP95 ,LIGHT 2005 [( SYSTad PLANNING DEPT. PDP9S ,LIGHT 2005 ; r4 IPP AT THE WESTERN AREA (6800 0W) (SPLIT BUS AT SNO) r _ IPP AT THE WESTERN AREA (6800 MW) (SPLIT BUS AT SNO) 3 PHASE FAULT AT BSP2 ON 500tV BSP2-CBG LIKE 3 PHASE FAULT AT BSP2 ON 500KV BSP2-CBG LINE :O FAULT AT O5CYCLEI OPEN FAULT LINE 4 CYCLES FILE: L05W H_FILE: LSW | I 150 00 - - - - -- -150.0 I 113000 0- - - - 0.30000 CHOL 150 f00H:BPK T1l x - L CHNLS 36 IV:2309V SRT1 x x 150.00 - 0 -150.0 I (13000 K .K.... 0-30000 CHHLS 13 MAS 51Q13 T81 - - - CHNLS 34 lV 230XV N31 - - 150.00 s---- -150.0 1 X 113000 - 0.30000 1; 150.00 CNNL- 10 I 121-- Gil- -S10.0 13000 CHNLS 20 V 5XV * 0.30000 1 F CKNL# 1 rANG,SB TSI t CHNL4 32 [V 500KV CBG1 j 11 150.00 - - - 0 -150.0 11.3000 - * 0.30000 CHNL0 25 [.ANG:IIP Ull 3 CHINLI 31: [V:500KV BSP21 150.00 -1500 1.3000 -s0.30000 o C0~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~1 E - t 0 | , ----- , - _ _ _ _ _ _0 D |~~~~~0 0I :~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~R C1 o If 1- I-~- CU~~~~~~~~~~~~~~~~~~~~~~~~~L N SYSTEM PLANNING DEPT. PDP95 PEAK 2005 SYSTEM PLANNING DEPT. PDP95 iEAK 2005 K i.~4 t') r IPP AT THE WESTERN AREA (5800 KW) (SPLIT BUS AT SNO) IPP AT THE WESTERN AREA (5800 MW) (SPLIT BUS AT SNO) 3 PHASE FAULT AT BSP2 ON 500KV BSP2-CBG LINE 3 PHASE FAULT AT BSP2 ON 500KV BSP2-CBG LINE (D0~ 1j C I OPEN FAULT LINE 4 CYCLES OPEN FAULT LINE 4 CYCLES FILE: POSW-58 FILE: P05W-58 i 2 I- 0 00 C HNBI 20: IA( - -150.0 ICHN112300ANG:SNR 10C C H # 41: fV':230KV RY21 _.30000 a 150.00 S - - - - -l0.0 1 CH0 I 36: IV:2301V SRT1 , 0.30000 | 0 CHNLI 13: tAG::lOt3 T1' J 0 CHNLO 34: IV:230KV NRT > 1 150.00 ~ - - - -+ -10.0 1 11.3000 - - - - - 0.30000 I 150.o0 -150.0 …0.30000 CHOLI 30: IAM~nG GIll C)DOD 28: 1V:5000'/ 1043 CNL0 lANGa S O_ - 5- - *1.3000 CIN 328 IV:500KV CEG 0 150.001A -l0.0 1.3000 0.30000 CNSLI 25: tANG:WIP 11.30 0 CHNBL 31: [V:SOOKV BSP21 150.00 O------------------~~~~~~~~~~~ -050.0 ( 1~~~1.3000 - --- 0.30000 ~~~~~~~~~~~I I 'I I I I. j I I1 1 Ir l I I *1 _ ' 'I z _ g _ ll 3 _00 I 0 I~~~~~~~~. ... I _-II _ B 8 H I 10 -~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~4 - 1t1~~~~~~~~~~~~~~~~~~~~~~~~~~L I. I. 0~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ I~~~~~ 0 / ~ ~ ~ ~ ~ ~ ~ ~~~~~~~~.0 L i I I I~~~- 'A I 0 0 5I " -. -.- - 0..~~~~~~~~~~ tn~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~' SYSTEM PLANNING DEPT. PDP95 PEAK 2005 (BSP2=5800W) SYSTEl PLANNING DEPT. PDP95 PEAK 2005 (1BSP2=5800ONW ) ; 114__ IPP AT THE WESTERN AREA 15800 NII (SPLIT BUS AT SNO) IPP AT THE WESTERN AREA 15800 NW) (SPLIT BUS AT SNW) LINE TO GROUND FAULT AT BSP2 ON 500RV BSP2-CBG 2 LINES r4 LINE TO GROUND FAULT AT BSP2 ON 500KV BSP2-CBG 2 LINES OPEN FAULT LNE 4 AND 6 CYCLES (CONTIGENCY N-2) OPIN FAULT LINE 4 AND 6 CYCLES (CONTIGENCY N-21 )E FILE: PO5XWBSP2-CBG G FILE: P05RWSP2CE " 1 |I0.00 CHNOJ 2°: I l X .,1 _00| 1.3000 41* tY:230 0.30000 | a.CML *. tAW,3BK Tl l . CH1L# 36. fVN2300YV f I 150.00 X L -150.0 i 1.1000. *.300 I CEt. 13: f1A:X3 *M 1 1 c C 34- 0V*230KV = I 150.00 -150.0 I | 11.3000 - 0.30000 i c 150.00 IC OlAm r f 0311 ------- -150.0 * H |13000 cS 28- l500KVS l---- 0.30000 I.H lSO.OO ClD~~tFl: (JsNO:SB t51 + - - " -1~50.0 | N |1.3000 o3 v0sIz - - .3eooe 0 COO1, (AM SO TS) J M ~L# 32- 113-500113 CBGI 150.00 -150i0 . 11.3000 - - - .300000 1150.00 ~~~~~~CHNIA 25: IAM33 I? Ull ICWIL# 31; 013:500KV 308P21 * I I ~~~~~~~~~~1 0.0k 0030000. 0 _ . ' t _ 4"o rfl _* I i 0 'e4G I I I,I I£ ,1,,,'; 1 1 . I o I I - 1 IaI. I l a I Al~~~~~~~~~~~~~~~~~~~ 0 .3~~~~~~~~~~~ i I ,~~~~~~~~~~~~~~~~~~~~~~~~~~~~ I, H~~~~~~~~~~~~~~~~~~~~~l H~~~~~~~~~~~~~~~~~~~~~a , 0~~~~~~~~~~~~~~~~~~~~~~~~~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ L X SYSTEM PLANNING DEPT. PDP95 PEAK 2005 SYSTEP PLANNING DEPT. PDP95 ,PEAI, 2005 ,H Ln IPP AT THE WESTERN AREA, (5800 MW8) lPIBUATSO fIPATlEWSBWARA(5C ll SPLIT BUS AT SNO) L n __ I.INE TO GROUND FAULT AT CBG ON 500KV (CONTIGENCY N-2) ' < 1 LINE TO GROUND FAULT AT CBG ON 500KV (CONTIGENCY N-2 g: k-- J OPEN FAULT LINE 4 AND 6 CYCLES (CBG-SNO CBG-SN021 OPEN FAULT LINE 4 AND 6 CYCLES (CBG-SNO , CBG-SNO2) OL oi FILE: PO5XWCBG-SNO2 u FILE: PO5XWCBG-SNO2 cos 100 CL3Z 20: (:HsNR H5) o N|S30 HL l v20v Rn}_---- >I0300 °°- c 15000 20~ [A2 E 51 1 - - - - - -150.0 j | |1. 3000 6 v:2301v -32! - - - - - -K 0.30000 1 cwm0 1!: (ANG:5PK TO1 -1 [ CHOLO 3J6 [V230KV SRTI y 0.30000 | 150.0CBL 10 raNGL6 11 G111 ~4 -150 .0 | H |1.3000 CHNL0 2 3: l 230-4v 091 _ 1.1000 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~ --- 0.30000 0 5 0 . 0 0 - 1 5 0 . 0 i .-f . 3 0 0 0 * 0 0 | 150.00 CHUL0 1: 103 50 T51 _ - -150.0 1 | 1.3000 eo 32: tv 5t al - _ 0.30000 | cHILI 25: ItOfWIP Ull -150.0 0 13000 C# 31: lv: SQKV 0SP21 e-------------- 0.30000 1 - I ~ ~ ~ * I ' I I IsI I ,l I I I I I _o , I, o I i.§ ° _ : & t - Z _~~~~I I t C 1I L I0 z .. .. 0 I a~~~~~~~~~~~~~~~~~~~~~~~~ I 0 $~~~~~~~~~~~~~~~~~~~~~~~~~~ I 0 ~ ~ ~ ~~ ~~ ~~~~~~~~~~~~~~~~~~~~ -~~~~~~~~~L 0 4.1~~~~~~~~~~~~~~~~~~~~ 4 . I i'0 0 t0 ) \. 4:~~~~~~~~~a / " ) 9u, ~J Lu -4 z SYSTEM PNIN DEPT. PDP95 .LIGHT 2005 ..YX WST PL GU DEPT. PDP95 ,LIGHT 2005 * D~~~~~p AT TE 3 tMEsFUTE Am (52O^ o800 MBw) ISPLIT BU AT SNO) o PP AT TENSUARA 15800 N) (SPLIT BUS AT SNO)° Pt FpF AL A ILE: L05W-58 n OPEN FAULT LIN 4 CYC LES nOW5 lS0.OO Caz 1: rJ"Ns:SB 51 _ _ .. ~~~~~~~ ~~~~-150.0 { 1.3000 , :Iv5x l- - 0.30000 150.00 § 5 ^I:rPol, -1S0.0 | 1 .3000 r- -1 -V Q -w2 -- 0.30000 (H#1 IMS T1w CM# 32a fV,SOOICV 0X 1000 -1--. 7 ' 00 0.30000ts to o~~~~~~~~~~t - . o~~~~~~~~~~~~~ Ln~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~I 65fSTm PLW511 D~EP. FD195 ,LIGmZ 2005 A?M PLAE DEPT.R liDP9 53 iS)(IGHT 2005 AT IPP AT THE WESTERN AMRE (5800 NE) (SPLIT BUS AT SRN0) IPPIA SEPT. 15 .LII1 2005 LIME TO GR2IW FALT AT BSP2 ON 500EV BSP2-C5G 2 LIMES T GOM WEAT AT62 ON MY(PI BUSC A2T LO a (v iPER FAMLT LINE 4 AND 6 CYCLE (CONTIGEdCYf N-2) k O9- PiS FAULT LIME 4 AIM06 CYCLE (COWTIG3EM N-2) FILE: LO5ZNSP2C FILB: LO-ESP2Bm 4c uoo 115D OO tIM 20 K 11 NRB1 -150.0 | H 11.3000 f. U6 n :23e0nV X - -- eloo | H 0Cm 101 A -. -. . . -150.0 | 4 11.3000 c 1 34: nV 230K O - 15sevo 1 0 IRE _ -150.0 1 1.3000 0.30000 1 so~~~~~~~~~= oe, -me ql11 CWQ# IN UI- .__ 6oe l |.ooq a: t ser2 QV - - .eo 150.00 0 . . - * -Lso. 1 - 1.3000 12 30 KV - - . . . . . . | 5 do - - - ---- -150.0 1.3000 me -1- V:00 2 ..3000 t~ ~ ~~~~~~~~~cm id FA9 3S rv scalyi my I~ ~ ~~~~~~~~~~~~~~~~~~~~ I I. . iI' 1I .-. I I I I *.i \\ '',X'',' 51I ..m010 0.3 1 f .~~~~~~~~ '. . a I a :11~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~- 6* I a *: *I~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ * S ~ ~ ~ ~~I ~~~ I 3.~~~~~~~~~~~~~~~~~~~~~ I: a ii~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~U ii : 9:,~~L 4 co ~~SYDETSTEK PLANNIING DET DP95 LIGHr 2005 In SYSTEN PLANNING DEPT. PDP95 LIGHTP 2005 IJZ1IPP AT THE WESTERMAREA (5800 MW) (SPLIT BUS AT SNlO) tW- IPP AT THIEWESTERNAREA (5800MNW) (SPLIT BUS AT SNO) LINE TO GROUND FAULT AT CBG ON 500KV ICOS1FIGENCY N1-2) LN OGOi AL TCGO 0X CNIEYN2 I ti ~OPEN FAULT LINlE 4 AND 6 CYCLES (CBG-SSIO CBG-SN02) u.P. TAULTOUNKEFAULTDAT CYCLS CBGNN 50K (CBNG-SN0K2) I 4 FILE: LO50CBG-SN02 Fl IL: LO5MCEG-SNO2 L ~~ j cuE., 2p~~~~~ Ohm-ouR 055 - - - -~~~~~~~~~ -150.0 1.30001 ~~ E#lISO 15 Om.aiW TIO 150.0 16, flt-230111 9= I iso. 00 ------13--ID 33 1] 15.* 6. 1.23xv001 ------- o3o00 04 I150 .00 ---- -150.0 I 1.3000 .00 550.00 ~~~~~~~CHOO 10: [AMM4 IJJGil CElL 28, [V500XV 11311 150.00 ~~~~~~~~~~-- …--- -150'.0 H 1.3O00 ------. 0.30000 1 H CEN# 1s fAID-S TSI CM .Wf 32- IV5001V CBaIJ 1150.00~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~.k 150.00 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~ - S -150.0 I 11.3000 - -' 0.30000 150. 00 ~~~coos. 25 FAM;V: VI] 10. 100 COOLS 31, [V:500KV BSP21 .00 --..----.-..40 -150 0 I 11.3000 U-------- 0300I 1150.101 I -~~~~~~~~~~~~~~~~~~~~~~~~~~ -- II~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~A I .~~~~~~~~~E I.~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~t LU x ..-4 - 4 r~~ Q~~~ S-YSTE2N PLAjOING DEPT. PI)P95 ,PEAK 2001 ( 1 SYSTE PLANENING DEPT. PD995 ,PEAK 2001 a) Q) 3 °PHASE FAULT AT RY4 ON 50 RY4-NCO LINE 0 3 PHASE FAULT AT RY4 ON SOOKV RY4-NCO LINE A~ " N2 OPE FAUTTE LIEAS4 CYCEAS 40 OPEN FAULT LINE 4 cYCLES A | C S.o FHK0 lAr IIINS:BPgILE: PO lE F. . K -0 | C IL0: P01 S------ 0.30000| < ~~~~~~~CHNL# 164 EAM :S HS I __ _ __ _ __ _ __ _ __ _ _ __ _ __ _ _ P_ __ _ _ __ _ _OM,__ __ _ _ 150.00 7 -150.0 0' 11.3000 - K -- 0.30000 150.00 C-LO 13: IANS:111- - - - - -150.0 | t 11.3000 CANL1 20 IV:30EV N- - - - 0.30000 | i150.00 ~ ~~~C3GU0 0 103 D fA G il3 T. 1 3 0 CElLO 23. IV,230KV NBI3 -I - 1150.00 1 Gil - * ~~~~~~~~~~~~~~~~~~~~1. 0.30000i CMI#L 10: IAN.:vm G11 - 00 CHNL 23: 1V:500KV R131 0 ~15 - - - - - - - -150.0 k3000- - a- -----. Ww 1530.00 CHNI 1: IADG:SB Gil -150.0 i 11.3000 CW-@ 21: IV:500SV NC] _ 0.30000 | h ~~~~~~~~~CM$L M0 fAG;:EIP U1 100||l.looO CRL# 26: IV:500KV RY61_e .0O| -j 1.3000~ 01 J1- I '0~~~~~~~~~~~~~~~~~0 to 0I 0 I;a I S I 0 Ii~~~~~~~~~~~~~~~~~~~~~~~~~~L 4 I~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~E V~~~~~~~~~~~~~~~~~~~~~~~~ cl Lu~c , S~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~C L i I I~~~~~~~** IL * _ . ,~ . .4 r71 SYSTEM PLANNIN DRPT. PDP95 ,PEAK 2001 *. r-i SYSTEM MIn= DEPT. PDP95 PEAK 2001 IPP AT THE EASTEX4 AREA (1400 NWf) f IPP AT THE EASTERN AREA (1400 cW) cGI 3PHS FAULT LN 4 CYLSO Y L3 PHASE FAULT AT RY4 ON 500KV RY4-WNO LINE C3 PE FAULT iT CYE O OPEN FAULT LUIN 4 CYCLES 2 EFN FILE: POlEl F% FILE: POlEl 01 Mtql 16:f tANS: H51 at I t 27: tY:50 SOKVPPI - . 150.00 N - -- - -150.0 1.3000 c - 0.-0000 mii 2 |150.00 CB 13 1A Tl - - * y -15Do0 fN 1.3000 CMI 30: fV-230V II 0 *30000 | __ __|__ _ _ _ __^.132L3_ __ _ _ _ __ _ _ __ 10: taNG:rN Gl_l |_,_ _ ClII, 23: [V:500V tf31 f150.00 I-------- -150 11.3000 -------- 0.30000 150.00 CtHSL 1: tAHG:SB Gll 1fi 300 I M 21* [V:SOKV O IW^0 0 140 z ISO..00_ - _ - _ _ -150.0 I 11.3000 0.30000 4 150.00 GBNOLI 20. tANIG:EIP Ull f -.----|1.00 ...260y:oOvxs 0.30000| . | . * aw r| I ' :.Ig5 I 0 1~~~~~~~~~~~~~~~~~~~~ I 0~~~~~~~~~ la~~~~~l ~~~~~~~~* _ I n _ *1 t0 . \il"s t} . o ll 0> jAO,; 111. . IIe i 0 I I _0 I~ ~ ~~ ~~~~ I 0 I, 0 ; n 111oII '- @ -Il . 1, 11 . :, 0 . . .._0 ,H - .4 -4 SYSTEM P3ING DEPT. PDP95 ,PEO 2001 SYSTEM PLANNING DEPT. PDP95 ,PEAK 2001 IPP AT THE EASTERN AREA (1400 NW) C' IPP AT THE N A (1400 MN C' SINGLE LINE TO GROUIND FAULT AT RY4 ON 500KV RY4-NCO 2 LINES 4 S INGLP LIE EATO GRND FAULT AT RY4 ON 500K RY4- 2 n . OPEN FAULT LINE 4 AND 6 CYCLES (CONTIGENCY N-2) X OPEN FAULT LINE 4 AND 6 CYCLES (COOTIGUUY 3-2) ,in Cd FILE: POlE2RY4-NlCO FILE: POlE2RY4-NO . - CH?U 16: [Am SmIR _51 __ 1.3000 _-iLl27 IV:SOOKVPP _01 CUILI 14- [AME:BPIK Til CFM 30* [V:23MK STIT ,so.00 CHllt. 14: I:6n Tll -1-50.0 | - | 1.3000 X - .----- I 0.30000 150.00 uhLo 13: 1>JtG:g3 Sol _ _ _ F W 701 to O |1.3000 CUIL 20: IV-2301V ]E _ __ 0.30000 150.00 cHalLO 10 I^NG:RN GIII ---- _46H 1 11.3000 CIM 23: rV:500V OK ----- 3 ___ _ oMHo CoM. 10 [ANG,s aill _ - CU5J 2: Wrvsoox l - N-* 0.30000 1SO.000_ _ _ 5 . (13000- - 03c § 20: 1 IM . RI C 2 6: t: 500 x RY40 * ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~s I 01N;m 0~~~~~~~~~~~~~~~~~~~~~~~~' 10 -~~~~~~~0i * 3F I I,~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~3I I H~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~L SYSTEM PLANNIN DEPT. PDP95 *PEAK 2001 'I' SYSTRN PLNNIN DEPT. PDP95 ,PEAK 2001 IPP AT TEN EASTERN AREA (1400 NW) ;;IPP AT THE EASTERN AREA 11400 NW) e I- SIN=L LINE To GROUND FAUlLT AT RY4 ON 500KV RY4-WH0 2 LINES SINMLE LINE TO GROUND FAMTL AT RY4 ON SOOKV RY4-WN0 2 LINES OPEN FAULT LINE 4 AND 6 CYCLES (COZITIGEPKY N-2) 0OPEN FEIlLT LINES 4 AND 6 CYCLES (CONTIGERC N-2) FILE: PO1E2RY4-l00 i LE: 1nV000 X I.0 C f 5A16: rt lb3 1-150.0 | 30 20 0.30000 1 g 1001 14: ABM Tl C 3: fV:0 f3 __230XV _R TI _ L01: 1B Oll " ----*--. -150.0 I il.3000 ..21 0.30000 com 11* r.mo*m TS) CM 2B- fV-23OXW I1I I150.00 s o - - - -150.0 1 1.3000 _ 0.30000 I |1500 COOs I10 1mm OO Gil ---------00 m, 23: CV:' 0 v 3r31 030 !00 - ' . -150.0 1. 3000 150.00 cI#20: ( GilpUl 8--5. 1.3000 CL 4 y50VR4 .00 u ll o 3 * i I~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~Li * ji I 'H' U2.S : ~~~~~~~~~~~~~~~~~~~ - . H ':~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~0 I 3m Os . xl ~~~S'i'STE24 PLANNING DEPT. PDP95 ,LIGHT 2001 [ SY~STEM PLANNING DEPT. PDP95 ,LIGHT 2001 X ~~~IPP AT THE EASTERN AREA 11400 MW) IPP AT THE EASTERN AREA 1l400 mw) 14 tn ~ 3 PHASE FAULT AT RY4 ON SOOKV RY4-NCO LILNE 3 PO0E PAULT AT RY4 ON 00KV RY4-NCO LINE L IOIIENFAULT LINE 4 CYCLESP FALLIE4CLS FILE: L1E In2OEN FAM 50 1 CCLES I CD.: PLE L EFILE: L01l at 1PO'L d 150.0 - -- - - -1500 1.300 CL0 30: NV:50KV PI0.00o 0M0HR R)0 0 141 AM: llCMM# 30& tV 230KV ST 15.0 -- ..... u -150.0 il1.3000 x - * 0.360000 I C cm.. 10, lm52-R Tel CUILO 23: WM=00K NO i150.0 CD-150.0, gg 1.3000 . …0.30 000 i C104L# 1a 10525! 0111 Cm%#~ 21: IV:SDQKV I I 150.00 - - - - - - ~~- - - -150.0 i 1.3000 -- - - - 0.3010001 CMM# 20 1A052 GIP 1)ICMML 21: 111500KV NMI) kso.ao~~~~~~~ -150.0 il1.3000 e- - - 0.30000 i 150. 1. 'IHI .120 I TE,jP Il300 WM 26 IVSQ Y4 Ip --------- .1 I sq ~ ~ ~ ~ ~ ~ ~ ~ ~ I . 4 : Ii -~~~~~~~~~~~~~~~~~~~~~~~~~~~ * I "Il~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~1 'I I 0 gIl - C~~~~~~~~~~~~~~E I 0 = C~~~~~~~~~~~~~~~~~~~~~~~~~~ I * II.~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~a - I~~~~~~~~~~~~~~~ 0 1 C~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~C U~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~L I . - :~~~~~~~~~~~~~~~~~~~~~~~~~~~~II * 0.~~~~~~~~~~~~~~~~~~~~~r 4 SYSTD PLJANNING DEPT. PDP95 ,LIGHT 2001 PPTTOKESTEM LR rSI ADEPT PD914 GH001MV IPP AT THE EASTgENP JR (1400 NW) IPP AT TAL EATTERN A 500K 21 3 PHASE FAULT AT RY4 ON 500KV RY4-WMO LIIE 3 PHASE FAULT AT MEIN 5001tV RY4-W1O LINE OPEN FAULT LINE 4 CYCLES OPB FADT LIE 4 CYCLES I FILE: LOIEl FILE: LO1lElt C1.ILI 16. [AM-MM NS1 at - I MPBP 3 _ _ #,I 1150. 00 -- - -150.0 11.3000 - - 0.30000 1150.00 c-150. C's 11.3000 .. .... 0.3000 1150.00 -150.0 1.3000 oULO 21 IVSOOKv - - - 0.30000 150.00 -150.0 1 11.3000 06: IV:3KV R000 I I I I 'MM'I ' I all I - 1 I I , _ - ', i 0 9, - ° - lI3i _ 00 CM 0 I a Ull 1, _ I _lso.00 I -,. 11.00 0000I - I 0 _~~~~~~ a : @0 -1 a, C~~~~~~~~~~~~~~~~~~~~~~~~~O a~~~~~~~~~~~~~~~~~~~~~~~~~ I I . :' I a-~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~U ~~~~a ~ ~ ~ ~ ~ ~ ~ ~ 0~~ * I ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~.~~~~~~7 .~~~~~~~~~~~~~~ ~~~~~CL a . ~~~~~~~~~~~~ 14 1 V~~~~~~~~~~~~~~~~~~=~t o C Ia ( ~~~~~~~~~~~~~~~~~~~~~~~~C I~ ~ ~ ~ ~ ~ ~ ~ ~ ~~~C a-- ,a / 0 a~~~~~~'iI L.a& S~~~~~ XIq ann to X lL SIM M DP IDP95 LIGH 2001 r | SYSM III I w DEP. n795 ,LWHT 2001D {:U _ IPP AT THE EASTERN AREA (1400 M) O W%-IPF AT THE ELSTIN AMEA (1400 NWi ° SINGLE LINE TO GROUND FAULT AT RY4 ON SOOKV RY4-NCO 2 LINES -, J L--1 SINGLE LINE TO GROUND FAULT AT RY4 ON 500KV RY4-NCO 2 TLNE P. bi OPE0i FAULT LINE 4 AND 6 CYCLES (CONTIGBNCY N-2) . aOPEN FAULT LINE 4 AND 6 CYCLES (CONTIGENCY N-2) in FILE: LOIE2RY4-NCO " FILE: LOE2RY4-NCO CMM# 16 [A02M, SNR aa ' VI CEI.* 27 rif:5001V n3PIP | 150.00 16: - - ' -150.0 I 11.3000 s- - - - - - .30000 | 0 oomLO 14 10; sn ni -- - - | 0C01 30: IV:2301V SOTI x 0>30000 | | 150 oo 0o 13' ISO.I.X3 TVI _ 1 3000 L. . .I.v 3 ) . . 0.30000 | g |00 10: fAWl ol T11 ,_ |1.3000A 23: 1v 3 S3) i o so . . - 1 5 0. 0 1 1 . 3 0 0 0 0 . 0 0 C14M# 1.; Iwo so 0101 CM#~L 23: IT: 5001V IW 150.00 - --- - - - - -5. 11.3000 - - - - - 0 - e.30000 so0.oo CM# 20: r NG0ErP 0ll 0 (I s - -.3000 CuSis 26: Mv:5001v rY41 0.30000 1150.0 -150.1 1130 -----r-l-* 0.,00 I l -~~-11§XU _ . ' I ' _ '0 1 11 c -°O .0L~~~~~~~ N .. I 0l c .~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ . a a i.~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ N I N *i~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~L NI I ~~~~~~~~~~ 02 a -~~~~~~~~a= I N I~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~NL I N~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~: I N j~~~~~~~~~~~~~~~~~~~~~~~~~~~~L tn SYST8 PLAIIG DEPT. PDP95 ,LIGHT 2001 .. SYSTS PLNNING DEPT. PDP95 ,LIGT 2001 IPP AT THE EASTERN AREA (1400 NW) I '" IPP AT THE EASTERN MEA (1400 NW) SINGLE LINE TO GROIND FAULT AT RY4 ON 500SKV RY4-IalNO 2 LINES ^ SINGL LINE TO GROGM FAULT AT RY4 ON 500KV RY4-kf 2 LIN ta .J:7-" OPEI FAULT LINES 4 AND 6 CYCLES (COkTIGECY N-2) I OPE FAMLT LIE 4 AND 6 CYCLES ICCOTIGENCY N-2) FILE: LO0E2RY4-iNNO FILE: LOlE2RY4-WO ,O | lSO OO ~~~~~~CHNLO 16: *:llfSI, -lSOO|R 1.00017 DfV:SO: 9BPPI w ,__ .000|- 150.00 a - - - - - - -150.0 | | 1.3000 1- --3x 0.30000 > I ~~~~~~~~~~ C#14* fAiN:gpK T -50. It 300 CW30- rV*230KV MT) K ii4r. l50.00 CH 3: TI _ _ _ _ -150.0 | |1.3000 3 - - V- -5 0.30000 | § 1I0.00 ~ LC 10: fA)iI:pi 9111 OM# 23: IV:500XV N30 1 150.00 - -- * -150.0. 11.3000 ----- 0.30000 } a4 20: fAMG:XP U11 11TD 26:1- V500V NMI 150.00 - -150.0 I 11.3000eo3 ~~i V j I ,I , 14 ,, ,.° I I I' ~f' I , I , I o 13 . : ~~~~~1 :1- 150.00 cunt 9: tANo: zipin I -IWO 1.3000 cmuA 23 M. -; ni 0. 0 - a ~~~~~~~~~~~~~~~~~~~~~~~~r : . a X r 7 SYSTEM: PLAMi DEPT. PDP95 ,PEUX 2002 SYSTEM PLANNi DEPT. PDP95 ,PEAK 2D02 r IF ATH TRNA 280M)IPP AT THE EASTERN AREA 5S2800 NW) =zi a; 9 E3 PHASE FAULT AT RY4 ON 50oxV RY4-NC0 LINE r 3 PHASE FAUJLT AT RY ON 0KV RY4-NCO LINE at; B' OE'ENt FALJLT LIBt 4 CYtrCLES OPEti FAULT LD 4 CYCLESiE t;l stFILE: P02E e FILE: P02E An OE'ti FAuT INE 00 CCLES 16: rAcMMMR H50 1 CMNL0 27: fV:SOOWXV RpP > 150 00 S1. -: .l - 1. rs 1 1.3000 - 0.30000 0 C|lS 14. CNt UbpK TBI C5.0# J j | 10: 0IV:230XV NiRT _ _ 0.30000 1 r;: £150.00 CHNI0 10: -AIIG:^N - . - |5 ~ |113000 qi6A 27- 0V:S ^301V m-------- l -0.3-O- 150.00 00510~~CMM 13- I0MM1 TO)051. CEWL 23: Ov:2300v * .300 I so 500 -a - _150.0 1.3000 - - t 0.30000 | 1550.00 CHID0 20: tJlDa EIP Ull -- - ---5. - 1.3000 Cgnl5 26: IV:SOOKV 31 e- 0.30000 I t~~~~~~~~~~M 1_ l (A;g Gi --v 1.300CMA2m[v5 M 150 00i o 0.30000S _ 1 20: ING:EIP Ul, l CI .' #j I IV 1 I I I t , . JU E _~~~~~~~~~~~' .a _i . a:II I I, .t~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~4 1- I I .~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~- I II~~~~~~~~~~~~~~~~~~~~~~~~~~~~~i I I aO * J~~~~~~~~~~ oO~~ OO SYSTEI4 PLANNING DZ?T. PDP95 .PEAK 2002 . SYSTEM PLAN;N DEPT. PDP95 ,PEAK-2002 . ' _ IPP AT THiE EASTERN ARLEX (2800 N) rP IPP AT THSI EASTER ARIA J2800 ?1) b r t r3 PHASE FAULT AT RV(4 ON 50OKV RY4_WH0 LIN:° 3 PHASE FAULT AT RY4 ON 500SCV RY4-WM0 LINZ° ; Ol k-q. OPEN FAULT LINE 4 C'YCLES inC: OPEN FAULT IAE 4 CYCLES FIE ;9 FILE: PO2E1 in ~~iso.oo ~~~~K0AL4CM 16; IANR3:SmKR I Fcm IL: Py50211 MP - 1 1 5-0 a l L 5 I. - - . - , -1 5 0 . 0 1 4 1 1 .3 0 0 0 0; 3 7 : S XV *_ 3 0 0 0 0 - { r 0 g 1 150.00 QWEJO 11: fA S n l - - - - - . - K -150.0 IA N |1.3000 CMM0 30: tV:230XV SRT1 0.30000 l 4 1150.00 --- .QIL .L .3 . ... -150.0 113RD P 1 0.30000 1o50. 001- -150.0 1 ' 11.3060 -----. 0.30000 1150.00 ~~~~~~~CM 10- rAm-xm M11 10.l CBALS 23: (V:5009V 0- * .3I0 CHNLO 1- FAOGSB Cli IcEOa 21, FV; SOOKVV NMI 1150.00 _ -_ - * -150.0 1 1.3000 0- * .30000 150.00 cHN- aQ fIE1E U - -- -150.0 | 1.13000 -sT 2o 1V:S00XV ,Y41 030000 - ,#/~~. I 00 A III o00_ * i . f0 * 0 _ * ~ . . _ _I 0 II~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~0 * II~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~I ~~~~~~~~~~~~~~~~ 4~~~~~~~~~~~~~~~~~~~~~~~~~~~90 0 -~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~8 c 64* IL2W- V. I 0o H ~~~~~~~ H~ I 0 I~~~~~~~~~~~~~~~ X SYSTEX PLANNIMG DEPT. PDP95 ,PEAK 2002 SYSTEM PLNIG DEPT. PDP95 PEAK 2002 - -H a IFP AT THE EASTERN AREA (2800 KN) IPP AT THE EATEN AR (2800 MR) 9: -- SINGLE LINE TO GROUND FAULT AT RY4 ON 50OKV RY4-NCO 2 LINES SINGLE LINE TO GROUND FAULT AT RY4 ON 5001V RY4-XC0 2 LII4E ao C 1 . OE'EN FAULT LINE 4 AND 6 CYCLES (CONTIGENCY N-2) J OPEN YAUILT LIN 4 AND 6 CYCLES (CONTIGENCY N-2) 0) ~~~~~FILE: P02E2RY4-NCo - - FILE: P02E2RY4-NCO * -0.00 < A | 150.oo - CHNLC 16* ct L 27: V:SO0KV EOS oP _| 150.00 cm 14* E30: I ll -150.0 | 13000 - -- 0.30000 COOLI 11' rw~~~~ ooo gui . I~1 CMEL 230 IV:S30KV MdlI oo x3l ------- K-150.0 1 (1.3000 ........ 0.30000 | 1 5 0 .o o ~ ~ ~cI O 1 . r0: l SNG X G 1 1 (le . | | .h00c t A 2 1i: I v s o o x v I O O G i l oso.oo CDSLI 1: tANG:SII G11 _ _ -150 .0 | 1.3000 C t 2: M D = _ 0.30000 150.05 -- -- =-5. 1 i3000 u-------- 0.300o0 _ ~~~~ ~ ~ ~~I . a t 150 CIMI I* I ANG, S *1C 2'M1 I. II I I I I NI I I I I _ ,:. 0 A -14~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ * I *0 2~~~~~~~~~~~~~~~~~~~~E CM 2 * UO.E~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~u F 1SYSTEM PLANNING DEET. PDP95 PEAK 2002 SYSTUK PLANNING DEPT. PDP9S PEAK 2002 L IPP AT THE EASTERNi AREA (2800 MM) | Ipp AT THE EASTERN AREA. (2800 NW) SINGLE LINE TO GROfUND FAULT AT RY4 ON 500KV RY4-WNO 2 LINES SRY-N0O 2 LINES it ~ P4FUTLNE N YLS(COIE0Y1-)OPEN FAULT LINES 4 AMD 6 CYCLES (COTEfIGENCY 11-2) a |150.00 FILE: PO2E2RY4-o-| FILE: P0292RY4-WNO I50 otCNN 16: rA3N:lSNR O | a |all 20: )51-D-v -RE-x 0.30000 | |150 .00 - & - 3 lUlG:1113-T3 -150 .0 1 O|1.3000 -6 Iv -3r a - a - - 0.30000 | Cie" 14C FNImnPx o11 I W# 30: fV:.230KV ERT!J I150. 00 1001.0 ........ . m | ISo.Oo CHI&I 10OL. 13. A000 TBI -j A 23: IV-2301_ 0.30000 |I 1 | 150.00 CUILO 1: lUNG: G0ll - - -15 Q 1.3000 cOL0 21: W*000or 31 - _ _ 0.30000 150.00 **NL -150.0 |1.3000 2 00.300 Il00I M 0. I 0~~~~~~~~~ A if * C~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~- * II. 4 Ii~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~C4U o 1~~~~~~~~~~~~~~~~~~~~~~~~~c II~~~~~~~~~~~~~~~u x ~~~SYSTEM PLANNIN DEPT. PDP95 ,LIGHT 2002 IPA U ATR NA'801W X1i uI AT T (2800 LIN N SYST PLANNIG DEPT. PDP95 LIGHT 2002 N 9 3 PHASE FAULT AT RY4 ON 500KV RY4-NCO LIN 3 PHASE FAULT AT RY4 ON C 0 RY4-NCO LIN ° (D ; OPEN FAULT L3NB 4 CYCLES ost OPEN FAUJLT LIN 4 CYCLESFL:L2 4L FILE: L02E FILE: L02E In 150. 0 O30,00 16: IAC: 651 - - 0 27: I - 0.30000 | > O 1at 14: I): ,,PK T-| 1.3 00 CI 30: IYV2301Y M.a30000 | |150. 00 ot h . 3000 - 13: N- m43T 8 - -. j; 1.6 2.: IV:230 3 ----- 0.30000 1 GUE4.00 . CSN 10: 167C:Y Glill ~. 23: 1V:000 - _-- - --- 0.30000 4 COM 1O I& ss GI1 -1. |1.3000 * 21; fV:500WY 1 -_ _.30 |0I | 150.00 aXw 20: I:BIP Ull a -- |3* 26: tvl3 000I .. 0.30000 | CMII I 2 I0 II T I I I IP O ,,.,.. S I . 0 :4 1 _ .4~~~~~E L I I 1! I~~~~~~~~~~II I II 3 iii I.~~~~~~~~ SYSTEk PLAOUING DEPT. PDP95 ,LIGHT 2002 SYSTEk PLANNING DEPT. PDP95 .LIGHT 2002 tn t IPP AT THE EASTEIN AREA (2800 IW) e lw v_ IPP AT THE EASTERN AREA (2800 NW) . P F T 4 O3 PHASE FAULT AT RY4 ON 500KV RY4-WN0 LINEL i) OPEN FAULT LINE 41 CYCLES *n E- L tb0 |F150.00 PILE: L02E1 FILE: L02E1 a _0 Ctiut. 16: fANG:SNR 451 - - - - - - - 1.300027 V~00 Epl-0.30000 . 15lS0.00 CmIOHN 14: IANM:BEX TIl , -150.0 1 " 1C.3000 30: 1V:230zrV SI . .-030000 I " |150.00 .C. . . . . . . . -150.0 dL 13: r_-1500 - . -IL- 2 -V-2301VJI _- -_- 0.30000 1 - 1-150 0 10: tO I Gil -0V:500XV 031 * _ _0.30000 | I 150.00 ~~~~~~CKMLt. 10 (AN:K Glll Aioo K I cUL# 21- rv-SQOI o ]v021.........:.~..........-..-... 15D. 00 -15~~~~~~~~~~~~~~ 11.3000 0.30000 CHMLI 20 tAMS.00 Gll CHOOL 21, OV,5O0KV RCOIJ i150.00 _.- -- * -150.01 1l.3000 2-- 0.30000 1 i150.00 CHNL0 20: tAtl:EIP Ull i, ,, -l i | 1.3000 CHNL 26: IV:5001V RY41 e 030000 F l g ' ' 1 1 } 1 r m I I I .1 I S I I t r I I a I -b 10 i!1 | 1X 1 . r L-~~~~~~~ . - . . a ,S o a~~~~~~~~~~~~~~~~ a a~~~~~~~~~~~~~~~~~~~~~~~~~~~I a U a~~~~~~~~~~~~~~~~~~~~~~~~1 * I a~~~~~~~~~~~~~ * * ~ ~ ~ ~ ~ ~ ~ - .- 0-~~~~~~~ X SYSTEM PLAMNING DEPT. PDP95 LIGHT 2002 in SYSTEM PLANNING DEPT. PDP95 LIGHT 2002 Sn .14 ~~IPP AT THE EASTERN AREA (2800 NW) IPP AT THE EASTERN AREA (2800 MM) ; - sINGLE LINE TO GROUND FAULT AT RY4 ON 500KV RY4-NCO 2 LINES ° SINGLE LINE TO GROUND FAULT AT RY4 ON 500KV RY4-NCO 2 LINES 09EOPEN FAULT LINE 4 AND 6 CYCLES (CONTIGENCY N-2) OPEN FAULT LINE 4 AND 6 CYCLES (CONTIGENCY N-2) CL lFILE: LO2E2RY4-NCou FILE: LO2E2RY4-NCO U' ci CHo1,IMStHS UlZP 2 X } 150 00 CHII 16 iANG:SNR H51 -150.C | ^ | l.3000 -ffiL -:1Y:SOSt 1-_ , _ _ _ 1 0.30000 > |CHL# 14 IM;B sPX Tll I CHNL5 30: IV:2301v R- K 0T30000| 1 lo.00 KCILI 13: lAN)t 103l _ _ -S1.0 QRNL0 26- !v2300v N _ _ _ | CHN ) Io I | CEILI 23: [V:500KV N31EI 150.00 * -153.0 0 - - o- -- 0.0000 15.0 CliN[. 10: fwN:mi Gll - - -.-- -s. - - - 1.3000 MaL 2: IV: s0oav NC01 - - - - 0.30000| 150. 00 L~~~~~~ClLom 1. lANG SB GIl 1.30 CIINL8 21, rVSo5KV adO) - - * ~~-150.0 1.00 C * 030000 |l55.00 CIWLO 20: IAN9G:1P Vll I ____1.3000 Cyl=O 26: IV:500KV RY4 0 I I I - 'I i I . I ' I i '' ''' I I ' I I I I I I I 5 i t r It R o 8 IrN0 I~> : .II p 1 .'~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~4 cc 0))~~~~~~~~~~~~~~~~~~~~~~ I Llll,Ml,'l'~~~~~~~ .11- 0 h^ la o 0~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ I i 0 '.E~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~cm I.~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~ ~ ~~~~~~~~~~~~~~~~~~~~~~~~~~~0 I. Ii~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~C Ln~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~0 [J SYSTEM PLANNING DEPT. PDP95 .LIGHT 2002 .. SYSTEM PLANNING DEPT. PDP95 LIGHT 2002 ,> 8 < StNGLE LINE TO GROUNiD FAULT AT RY4 ON 500RV RY4-WNO 2 LINES a SINGLE LINE TO GROUND FAULT AT RY4 ON 500KV RY4-WNO 2 LINES H 0 SW-~INGL ATITE EATE RUND FAULTAA (2800 50 RY IPEN FAUTE LIEASTER ANDEA CY2800 CNTGNCN2 C.lI ~ OPEN FAULT LINES 4 AND 6 CYCLES ICONTIGENCY N-2) U S FILE: LO2E2RY4-WNO FILE: L02E2RY4-WNO ISO 150 00 - 1 - p5 -150.0 | 1.3000 C6 27: V:500V RPPI - - 0.30000 CHMI 14: IRAN:BPK TKOO | CMOC 30- [V:230PV SRTI I CL0513:0.00rw liM3 P3l -lS0.0 1 o 11.3000 iN L 213: [Y:230XY N31 | _ _ __ _+ 0,30I00 - -- 1150.00 CHWO, 10:IANG:KN Glil -1S0.0 1|.3000 C. 0.30000 CHNLS 10a lAK12 XK0 T8II OM#NN 23- [V 230KV 1043 I50. 00 * -150.0 [o 1. 3000 *-* 0.30000 CNNLI 1: IANGR GI1 V | CMIS 21: iV:500rV NCOI iso.00 o - - * -150.0 I 1.3000 - - - * 0.30000 CENLI 20. [ANOG:EIP U11 -150.0 |1.3000 CHLt 26: [V:SOYKv RY4I 0.30000 _ , t ' _ oo I I . ,1 T _ oo K I i~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~i o K~~~~~~~~~~~~~~~~~~~~~ _ 1.^ : . t " -a _ b W _ o~~~~~~~~~~~~0 I I~~~~~~~~~~~~~~~ 00 H CM 4.. 0~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~4 aD iIi.~~~~~~~~~~~~~~~~~~~~~c * z~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ rYSTEN PPLANING DEPT. PDP95 PEAK 200>3 SYST1 PLA ING DEPT. PDP95 PEAK 2003 IPP AT THE EASTERN AREA (3800 NW) IPP AT THE EASTElN AREA (3800 NW) * 3n 1 PHASE FAULT AT RY4 ON 500KV RY4-NCO LINE 0 PHASE FAULT AT RY4 ON 500KV RY4-NCO LINE Gl i bI OPEN FAULT LINE 4 CYCLES FI OPEN FAULT LINE 4 CYCLES * ~~~FILE: P03E as I2I: 1vP003ERPP C > |lOo CNNL0 16: [AM:M HNR IS -I Co 133 CHNL0 27% IV 530KV RBPPI 00 150 0 CHOO 16 1Ar03 B T - - - - - - -150.0 I | 1.3000 FL 0l 3E 0.30000 } 150.00 CiNOL 23 IANG 8K TII -I50.01 'i | P T00 CHNLI 30: V:2308V SNB __ 0.30000 | g CNN4LI 13 IANG SN4 G111 __ u CNNLO 23 IV.5001V IIM31 150.00 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~~~~~x--- - - - -, -150.01 1 . 3000 . .. .--.. 0.3008 N COINL 130 17.0) 3 TBI Gil...... CHN4L# 23: [V.230KV NB4! 1_500 I __ -iSO v1 113000 - … - - - - 0.30000 I 150 C-al 0- 150. 0 il.3000 -I CBNL0 1 fANG: SB Gll I I |1.3000 CHNLS 21 IV:500KV tlCoI _ . 0.30000 CHNLt 20. IANG.EIP Ull _= i l3000 CiNLJ 26 Iv:SO00XV RY43l 0 30000 l ~ ~ ~ ~~~~ 0 I I I^ ] 111111 i 2 ° I. T I8 0 til |1.K1s,8= $ _ ;zztgt { _ ~ ~ ~~~~~~~o _' I} Ie 0 g 0 f | 0 2;\;>'1j/<)1 1 1 ]3 0 <~~~~0 0g Clol 0~~~~~~~~~ . 0 " U II __._.I _ 0 04 ~ ~~- -a. c4 A -4 SYSTEb PLANNING DEPT. PDP95 ,PEAK 2003 vSYSTEM PLANNING DEPT. PDP95 ,PEAK 2003 IPP AT THE EASTERNJ AREA (3800 MW) IPP AT THE EASTERN AREA (3800 Nw) _ - 3 PHASE FAULT AT RY4 ON 500KV RY4-WNO LINE ° 3 PHASE FAULT AT RY4 ON 500KV RY4-WNO LINE D j,J OPEN FAULT LINE 4 CYCLES OPEN FAULT LINE 4 CYCLES M, a ~~~~~~~~FILE: POM E1 FILE: PO3E cr*4 I CiNL0 27 IV500KV SO BPPI Wo _ .ao CH}IL3 14: lAN;:i3P! Tll x ~~~~~- - - - - - -x -lS0.0 |r |1.3C000 -RL -0 -V20 SRT ,, - , 030000 > % CINL0 143 1AIX:!PK Tli _ CL 30V: (V:230WV FRTI 0 1 000 -lS -.0 | :| 1.3000 00K ] 0.30000 | CHNLS 13 [ANK3:G3 Tll a CHl 28: IV:SOW NBI , CHNIaSID, IAOE 00 0331 COOLO 23: IV:500KV 00531 IT, T. DO -- - - - - -- - -150.0 l30 --- - - * 0.30000 00 ~~~COOlS 20 fANG aEO lF Vii j COO# 216 I50V NO k2 IT i il.3000~~~*7)I 0.30000 | l0.00 CHN03 20: [^AW Elp Uli Q -150.0 il .3000 CliNL 26: [V:500WV RY41 o 0.30000 a a~~~~~~~~~~~~ I 0~~~~~~~~~~~~~~~~~~~~~~ *^' I. 0- -0 0tl- , o', & i * 4~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ I~~~~~~~~~~~~~~~~~~E r * I L * . a-~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~a * I ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ..u 0.~~~~~~~~~~~~~~~~~~~c I~~~~~~~~~ X F. N~~~~~~~~~~~~~~~~~~~ n 1 ! wu9~SSTE P11IG3 DEPT PDr95 PEAK 2003 SYnSTE PLNI NG DWn PDP95 PEA 2003 r P9 rt t ~~~IPP AT THE EASTERN' AREA 13800 NW) w IPP AT THE EAiSTERN AREA (3800 MW) tl j u ) SINGLE LINE TO GROUND FAULT AT RY4 ON 500KV RY4-NCO 2 LINES H SINGLE LINE TO GROUND FAULT AT RY4 ON 500KV RY4-NCO 2 LINES o1o i'' '" IOPEN FAULT LINE 4 AND 6 CYCLES (CONTIGENCY N-2) OPEN FAULT LINE 4 AND 6 CYCLES (CONTIGENCY N-2) FILE: P03E2RY4-NCO FILE: P03E.2,RY4-NCO L L4 r _ILO 10: !A60:ONO St1s H51 0_@ u CH L 5 27 IV 500KV RsMPPI * H1 1 500 - -- --- - - - - -150.0 1 3000 - .3000 3 00 C_ CHXW 14: [ANG BPK Sll -c5,# | 1 OII 30: IV;230KV SRTI0 VI50.00 - -150.0-1 il.3000 K 0.30000 150.00 C OIINL 13 1 M tA D 3 551 _ _ _ _ _ , -IS0 o8 O 1 3000 C HNL 28. fV 230KV N0 l _ - - 0.30000 I k50.00 Q 0 I00G 11N Gil - 0 C0 23 Iv 500rv nt31_ | 150.00 C h N L ? 1… *^Na;ss Gll -150.0 | | 1,3000 CHNL 11.3000 .30000 CHNLL' 10 lAW:MSBGII1 CR04A 231 fV:500KV M371 i150.00 - a --- - - - -150.0 I11.3000 a.-.--- - - - 0.30000 CONt 01100 1 1111sE GI]....... CWM04 21: [10:500EV NCOI 150.00 CHNL3 -150,0 11.3000 C-R 0.30000 | koC # I I I (A'M: I I I I o I I 5{ I I I I I 00 a 0 o j 0 * §>~~~ ~~~~~~~~~~a. 0'~~~~~~~~~~~~~~~~~~~. O . U a~~~~~~~ U,ni cc SYSTEM PLANNING DEPT. PDP95 PEAK 2003 g SYSTDI PLANNING DEPT. PDP95 ,PEAK 2003 n A. IPP AT THE EASTERN AREA (3800 MW) IPP AT THE EASTERN AREA (3800 MW) __ SINGLE LINE TO GRCOIND FAULT AT RY4 ON 500KV RY4-WNO 2 LINES ( 'j SINGLE LINE TO GROUND FAULT AT RY4 ON 500KV RY4-WNO 2 LINES ) ffiLJ OPEN FAULT LINES 4 AND 6 CYCLES (CONTIGENCY N-2) C I= OPEN FAULT LIS 4 AND 6 CYCLES (CONTIGENCY N-2) FILE: PO3E2RY4-WNO m FILE: PO3E2RY4-WNO a 150I lO.00 1CHNL1 16: IASC:SNR g51 H _| CHNL 27: IV:500KV R3PPI - _ | 150.00 ~~~CHNL3 14: lI'NCBPR ll -1 x -ENISOOt|130 30: 1v:2301V SPTI x - 0300|' 150.00 CN 1T -150.01 O 1.3000 C-L 0.30000 CULO 13 [ANCG111 T-l | CML8 27: tV2301v 1 _ oT0 150.00 - - - - - - - - -150.0 |1. 3000 Q 2 N. 0.30000 150.O 00 CHI&IO 20: IANG:EIP Ull o C 10: |A| 1 3000 CHNL0 23: tV:500KV NW41) .3000 1150.00 - - - - - 150.1 l.3000----- - - - * 0.30000I F10 00 CM&# 1, [AM SB GI E- i 0300 Ml 21 I I ' I 'I I ' 0000 I 00~~~~~~~~~~~~~~~~~~~~~ . ,I .- 0 T 2 4 0 8X~ 0 0 IQ m . . ,, I 5 ~~~~~~~~~~~~~~~0 0 ~~~~~~~~~~~~~~~~~~~~~~~~04 FLSYST0E PLANNING DEPT. P0P95 ,LIGHT 2003 C [ 2 1V SOPLANNING DT. PDP95 3LIGH 2003 .IPP AT THE EASTERNI AREA (3800 MW) 01 .14 I~~~~~~~~~~~~~~~~~~~~~~~~PHAS FAUT TH ASTER AREA N 3500K Y-NW) IN 'd Ln 3 PHASE FAULT AT RY4 ON 500KV RY4-NCO LIME 3 PPHATSE EASLTE AT R A (38500V RY4NC0LN 9 ~~~~FAULT LINE 4 CYCLES OPEN FAULT LIKE 4 CYCLES (D F~~~~~~~~ILE: L03E FILE: L035 ___ __ _C__ __ ___ _16_:___ ___ __ __ __ __ __R___HS]__ __CHN__ __ __ __27, IV:50QiV IWPPI 1I 100CL9 16- IAOG:ONR Ull -- - - 10 1. 3000 - -2 IV SXV Rtl - 0. 30000 | CIINLI t fANGIBPK Tll CI_30_ I_I'I I °I,. I IV:0 RTI I 150.0 O.C 150. 11.3000 K.K.... 0.30000 N 150.00 ~~~~~~~CUM#L 13; [ANG 1M13 -15-0.0- - --11.3000 CWM#L 2 8 fV 230KV NBI-- - 0.00 150.00 10(30 O Gl -1SO.0I z 120 HL 3I 0K 13.300001 150.00 GIGOLO~~~UM4 10 ifANGO Glll~ COOl!. 231 (V:500KV OEo31 k3. -0. ~ ~ ~ ~ ~ ~ ~ *-500I 11.3000 -- 0.30000 I MM#L 20. IANG:00P GIl -1.1CUM# 21. IV, 500Kv Mal ~~~~~51 H ~~~~~~~~~~~~150 1.3000 ---Q0.30000 .* 150~00~ I I : 30 0.30000 F 0 , I .1. 0~~~~~~~~~~~~~~~~~~~~~~~~. 41~~~~~~~~~~~~~~~1 "I ~~~oN / I 'I o 01~~~~~~~~~~~~ I*SYSTEM PLANNING |EPT. PDP95 ,LIGHT 2003 .n SYSTEM PLANNING DEPT. PD3P5 LIGHT 2003 Ln0 : 'W') ripp AT THE EASTERN AREA (3800 NW) Wi2 IPP AT THE EASTERI AREA (3800 MW) rr zz C E |3 PHASE FAULT AT RY4 ON 500KV RY4-WNO LINE 3 PHASE FAULT AT RY4 ON 500KV RY4-idNO LINE ° 1OPEN FAULT LINE 4 CYCLES ,o. OPEN FAULT LINE 4 CYCLES FILE: L03E1 FILE: LO3E1 , _ 150 - lSO.JO CI-G 16: iJ-NC:R HSI -1_0__ | 113000 CliNHO 27: IV:500KV iHPPI 0 3 | - ________ C1(L* 1G:.30 IA0G: Tll 14 -I Tl. N i CHNL 30: rV:230](V SRTI x > 150.00 CtWLG 13: lAIIG:MMl3 TO] -150.0 | i 1.3000 CHiSHG 28: tV:230WV NBI 0.30000 CHN0LI 10: fANr:0N G0I1 I. CHNLO 23: 1V:5OOKV 031 050.00 GCHi 1: IANS:13 Gll - - - -ISO.O i1.3000 CHIILO 21: -V:500V NCOI _- - 0.30000 150.00 ~ ~ ~ ~ ~ ~ ~ ~ ~ - -050. il1.3000 ~- - -' 0.30000 150.00 Ci-L0 20: fANG:EIP Ul -lSO.J 1 i1.3000 CHliLO 26: IV:509V RYGI 0.30000 ~~I I 11 1' oI I .1, 1 : I I I II_ ' _ ; 1 2 _ o _ . a ' o _ oI I . 1 S j C_ ' E W;~~ 61 .. _. 0 4~~~~~~~~~~~~~~~~~~~~~~~ I i~~~~~~~~~~~~~~ 4~~~~~~~~~~~~~~~~~~1 aq & B 4 .~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~9 N : 'I 0~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~:C 0 C' 0 1/ 1c9~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~4 :LUI ~~~~~~~~~~~.-~~~~~~~~~~~~~~~~~~~~c o X ~7] SYSTEM PLANNING DEPT. PDP95 ,LIGHT 2003 In SYSTIm PLANNING DEPT. PDP95 ,LIGHT 2003 Ti IPP AT THE EASTERN AREA (3800 NW) IPP AT THE EASTERN AREA (3800 NW) g: __~ iSINGLE LINE TO GROUND FAULT AT RY4 ON 500KV RY4-NCO 2 LINES ^ 0 SINGLE LIA E TO GROUND FAULT AT RY4 ON SOOKV RY4-NCO 2 LINES OPEN FAULT LINE 4 AND 6 CYCLES (CONTIGENCY N-2) (9 L. OPEN FAULT LINE 4 AND 6 CYCLES (CONTIGENCY N-2) n FILE: L03E2RY4-NCO 1 0 FILE: L03E2RY4-NCO u. CHNL# 16: tAOsOSnR N51 C,,|.0 2?. Iv:5000v RBPP1 _ _50- C 14 I0Ci:PX 11 - - - - -.0s6 r 1.3000 CINI 30: (v:230Kv -x - K 0.30000 |H I 150.00 C5ff10S 13: -ANG:lI3 T31 _ _, -lS0 .0 Q 14 [A.1000 CPN1# 2S: (V:230KV N1 030000 5-00 CHB0. 10:IN -15014 0 | A| 1.3000 CHIIL0 23: Iv:sooxv * 0.30000 | ! i ~~~~~~~~~CMNL 13: I^N:SH3 TV} - C P . 21: IV:SCOXV MI# 1150.00 1 - - -150.0 1 1 1.3000 2 - - 0.30000 1 CIN7L 30: IlAloGIP UGn | CNNL3 26: IV:SOOKV RU3 IT-10 ----150.00 o - I 1.3000 0.30000 I150.00 I I I I 'I jl(i1 'I ' 15000 _. I I I 0o30000 0 1f. t ;' 0''0 (I i;2- oC Oo L_~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ 0 I -~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~Z I o~~~~~~~~~~H 0 H I -~~~~~ ~ E. E. I . 0 I 0~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~r '1 ~~~~~~~~~~~~~. . . . ~~~~~~~~~~~~~~~~~~~~~~~~.c C)) 0% In la SYSTEM PLANNING CEPT. PDP95 LIGHT 2003 ' 1 SYSTEM PLANING DEPT. PDP95 ,LIGHT 2003 1il*.1 Pw~-1IPP AT THE EASTERN AREA 138D001W) ~W'fIPP AT THlE EASTERN AREA (3800 NWI OSENGLE LINE TO GRO FAULT AT RY4 ON 500 RY4-WNI 2 LINES - SINGLE LINE TO GROND FAULT AT RY4 ON 500KV RY4-WNO 2 LINES SIGOPEL FAULT LINES 4 AND 6 CYCLES (CONTIGENCY N-2) 2 OPEN FAULT LINES 4 AND 6 CYCLES (CONTIGENCY N-2) , FILE: L03E2RY4-I 4O FILE: L03E2RY4-WNO tf U bb S.O CIINII 16: I ANG:SUR H51 > > -S. 1300CS32:f:OF BPI5___ .00 bO C1 5. 0K1L 1 i0150.51- - 1.CNO 7:1100K --- ' 0.30000 : X l tSo.oo CHNW 14: IANG:BPX T11 -150 0 j rl | 13000 CMHNL# 30: IV:230KV SRTI -0 51.01 ~~~~~~CW4L# 1: 4 OA~0KK TI' CMW 28 IV:2309V NS i 150.00 - - - - -- -150.0 il.3000 0.30000~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ ' .00 1150.00 CHNLI 13:0 [ G- - - -I -- -150.0 i 11.3000 CHlNL 23: IV:2301V ta31 - - - - - 0.30000 j § }150.00 . CHSLI10 :00 IAKIG: Gil ________ -150.0 C I1.3[AM GCHS 23: tV:SQCXV 00 | 150.00 1500 l.3000 C 1 0.30000 150.00 CH NL 20: lANG:E lP Ull -150 0 i 1.3000 CHNL- 26: IV:SOD-IV R- 0.30000 | { ~ ~~ ; 'l 1 II ° - ? {'''| 0 Oo f~~~~~~~~~~~~ 0' 1 0 0 .1~~~~~~~~~~~~~~~ . *Q (O 4 EU .5 ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~1 E- I *00 .5~~~~~~~~~~~~~~~~~~~~~~~~~~~~~L7 I ..II~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~V .1 ..= ~~~~~~~~~~~~~C .5 I i 0 .111~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~l I .~~~~~~~~~~~~~~~~~~~~~~~~~~~ 0~ ~ ~~~~~~~~~3 I . . . 0~~~~~~~~~~~~~ H ~ SYSTEM PLNNNI?G DEPT. P0F95 * PEAK 2004 SYSTEI PLANIN DEPT. PDP95 ,PEAK( 2004 IPP AT THE EASTERN AREA (4800 NWo) 3fIPP FALT TH ASTER ARt 014800K RY-COLN 3 PHsE FAULT AT RY4 ON 500KV RY4-NCO LINE I 3 PPSE FAULT AT RY4 ON 500K 0 RY4-NCO LINE C1) (0) 4 OPEN FAULT LINE 4 CYCLES F-E POPEN FAULT LINE 4 CYCLES 0 00 | eiso oo -s 16: I3SNR 151 - , _ _ _ -F -150.0 | L P1.3000 -----F P030-000 S5.0 COG.-*H 14: IAII BPK ] x -- .. ^-;5 0~ 1|1.3000 1L 30~ rv2301V SrTS X 0.30000|° 150.00 - Cob.. 13 booo m3 - - - _ , _. 1501 § 11.3000 COlL 298 IV,23011V 010 _ --- -- 0 I00 1 sooo creL IC: rANG X1l -150.0 I R…p |.30000 J cbG.0 it 1004000 TO) j 5. CROLO 31. (V:20XV 0.C000I 150.00 - - 7-150.0 I I 1.3000 x ........ 0.30000 CIONJ1o 20 Mwj "01*IP 011 CHNLI 29E, [V:1X00V NY4 150.00 -150.01 11.3000 - 2 I - 0.30000 0 1100 -10. :- - -- -0 -g - ; - -- .- i150.00 I I~~~~11 *.II-..1............ I CM#21 IV,0K NCI I 0 .1'' .'' *2I)4,,1 E- I I _ l >~~~HM 20: 4 ', [h:I VI -10. 1o.30 _IM I6 [V;0O1 R1 0.1 0 o g~~ -.. _ _ _ . _ _ w co X SYSTEM PLANNING DEPT. PDP95 ,PEAK 2004 SYSTEM PLANNI1G DEPT. PDP95 ,PEAK 2004 IPP AT THE EASTERN AREA (4800 WI IPP AT THE EASTW AREA (4600 NW) C_ ; 3 PHASE FAULT AT RY4 ON 500KV RY4-WNO LINE w 1 3 PHASE FAULT AT RY4 ON 500KV RY4-WNO LINE co eL 1 ^, ...OPEN FAULT LINE 4 CYCLES OPN FT LNE 4 CYCL E 1 a b) F~~~~~~~ILE: P04E1 PILE: P045 at 2 :\ 150 00 CHNL# 16: [AND:SNR H51 - 0 ,1 | 1.3000 C-G. 27: tv:5OOv P-BPpl - _ - - 0.30000 | a 0 15 GoS ClII-:lll:P 1 - - - - -i -lS A > .00CN03:I:3S RI^@, .00 CHNLI 13: [ANGBHP3 T'n -1 CMNL 230 rV:2301V NBI at2| i150. 00 CHL 0 AGXGi -150.0 0 il 13000 ODE .3 .VSOS 1#3 . . . . 0.30000| 1150.00 ~~~~~~~C111& 13 I ANG:S BIC1 -10 0 1 11.3000 CENL 28: FV:SOOl:V NBIl_ - 0.30000 ilso .0 CE0L0 20: OlNG:EIP t'11 e X -150.0 I1H3000 Cl:f 26: [V:S:elWRl' 1 e 0,30000 I .' § a -50 - -\ - ---- 0--- - i- - o CMW 1 [N , SD Glli CmL 21o oVSOK N I~~~~~~~~C= 20 ANEIP ,4'L''I I o°m 2I IV 5.'K ';>.1 . _1.111o co :E Ot 0 02 C -~~~~~~~~~~~~~~~~~~~ a a.' II~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~1 o C~~~~~~~~~~~~~~~~~~~~~~~~C 91~~~~~~~~:1 ~~~~~~..' \ 'I 0~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~L X - SYSTI PLANING DEPT. PDP95 .PEAK 2004 SYSTER PLANNING DEPT. PDP95 ,PEAK 2004 - .H u ~ IPP AT THE EASTERN AREA (4800 1W) [ ~IPPA H ATR PA(80M)1 L-J L.- o SINGLE LINE TO GRO1ND FAULT AT RY4 ON 500KV RY4-NCO 2 LINES SINGLE LINE TO GROUND FAULT AT RY4 ON SOOKV RY4-NCO 2 LINES 9 C: ()OPEN FAULT LINE 4 AND 6 CYCLES (CONTIGENCY N-2) O i OPEN FAULT LINE 4 AND 6 CYCLES (CONTIGENCY N-2) Ca FILE: P04E2RY4-NCO FILE: 04ELRY4:CO 4F2RY4-NCO m t kso oo CHIMI 6: [AQ;ISNR H51 > -lS. O | '. 1 1.30C0 CHNL6 27: IV: ,P0KV 9BPI _ 1- - lo5o 1 - -o.0 T 11.3000 L 3 0 30000 I } ISO. 00 CHINL1 13 IANG:BP3 Thl - - - - I 1.020 NL 23Cit IV:230000 -1500 I ~~~~~~~~~~~~~~ 10.3000 ~ ~ ~ ~ ~ ~ ~ i300 150.00 CHNLO 10 IH iA X1 GII = 11.3000 CS 0.30000 I 150.00 CHNL 1: lANG 00 Gil - - _ -11 | 1.3000 CHSL6 21: IV 500KV NCOI _ - _ 0.30000 ce& 23: tASG:OI2 ull __ X -lso.a 4 ~~~~~~~~~~~~~~~~11.3000 CNL2:I:O6 Y1G0,30000 i 153.00 ~~~~~~~~~20: OME Ksp Ulj ] 3ONL# 26. fV.500]KV RY41 -------- * 0~~~~~~~~~~~~~~~ _ . A + _ O _ ~ ~~~~~~~ I S4 1 1 o4 3 4 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ S~~~~~~~~~ .~~~~ I . t I 0~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~0 r I~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ 0 I~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~4 * 4 1~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~O (. I~~~~~~~~~~~~~~~~~~~~~~~~~~~~~( w w~~~~~~~~~~~~~~~~~~~ 0 - ID fl SYSTEM PLANNING LEPT. PDP95 ,PEAK 2004 L7 SYSTEM PLANNING DEPT. PDP95 ,PEAK 2004 IPP AT THE EASTEFN AREA f480D MW) Z IPP AT THE EASTERN AREA 14800 MW) SINGLE LINE TO GROUND FAUUr AT RY4 ON 500KV RY4-WNO 2 L1NES h _ SINGLE LINE TO GROUND FAULT AT RY4 ON 500KV RY4-WNO 2 LINES OPEN FAULT LINES 4, AND 6 CYCLES (CONTIGENCY N-2) OPEN FAULT LINES 4 AND 6 CYCLES (CONTIGENCY N-2) ni t'L ~~~~~~FILE: PD4E28Y4-%WO FILE:- P0ERY4-N CHNLt 16 (Ai:S ( H51 --- - .3000 CHNBt 27: iV:500KV RBPP1 , 0 -150. 11.3000 - - - - - - -K 0.30000 | ^ 151.01 CHl&l 14: [AZNG:BK TIS _1 CHN*L 32t IV:230KV SiT D.3DODO kso.oo -- CHNJLU lD: [ANG:i G4 01_ _ _ _ _ _ 1 -1S1.0 | Ni i 1.300D CHNlL5 23: -IV U131V00... 0.30000 | CHNM# ID fANGM SO Il I__ I CHNLO 231 fV:50OKV oC31 150.00 ~~~~~~~~~~~~~~~~~~ ----- - -150.0 i 1.3000 ------ - 0.30000 0 lSO .ao ~~~~~~~CHNLt 1: IANiG:SB Gli _ f -S. .00CIWLI 21: rV:5OOKV NCOI _ _ 0.0D| J150.30 CNtt 20. fAG:SIP Ull 11.3000 CHOM 26: IV:500KV RY4_ 0.30000 | I _. I l jl - - ° I I . I °, Ift . [0 D I 4 C0 _ :, I' t - Z _ t b2 _ .I I 0 4' U~~~~~~~~~~~~~~ I. 0~~~~~~~~~~~~~ ::: I- ~~~~~~~~ ~~~~0 1 ..- inllf~~~~~~~~~ i t C _ - 0~~~~~~~~~~~ -I £~~~~I \ II 1 ~~~~~~~~~~~~~~~~~~~~~~~~~~~ ~~~~ LU i SYSTEM PLANNING DEPT. PDP95 ,LIGH 2004 PLANNING DEPT. PDP95 LIGHT 2004 ri __ IPP AT THE EASTERN AREA (4800 MW) c o IPP AT THE EASTERN AREA (4B00 MW) LINE - 3 PHASE FAULT AT RY4 ON 500KV RY4-NCO LINE 0 3 PHASE FAULT AT RY4 ON 5 v RY4-NCO LINE ° (~YThi ,aOPEN FAULT LINE 4 CYCLES OPEN FAULT LINE 4 CYCLES In _L~- o CBNLE 24: [ANG:BPK Tll __ -_-_- -OWLC K -lSO 01. CM$ 30i fV:230KV SRTI COEI1- 1.30[ 0IC [ T COL 28: [Vm230KV NBI - _ _ _ _, 0.30000 | k, -~~~~~ 0 1-1~~50 1.3000 0 0.30000 F 15_.10 CHNL# 10: [ANG:KN GUl _ _ CNNL1 23: [V:500KV 31 030000 | a I 15 0. CHNLO 1 iANGS Gl _ - - 1500 i | 1.3000 CHNbL 21: [V:500KV NCOI _ - 0.30000 | F 150.00 CFJOHN 20: IANG:EIP Ull 1 0 1 |1.3000 CHH# 26: IV:500KV RY41 _.30000 _ -Ir--*X---*r---n--0.O | | .t qiI 1 - -------- _ ' 1 : I _ o _ il I 0 l I_ X~~~~~~~~~~~~~~~~ ]I § S 1 C ~~~~~~if- I. 0 t.I - 0~~~~~~~~~~~~~~~ * I I~~~~~~~~~~~~~~~~~~~~~~~~ I , 0 in~~~~~~~~~~~~~~~~~~~~~Jmc * I~~~~~~~~~~~ 0 p~~~~~~~~~~~~~~~~ , 4 00oO~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~' w -~~~~~~~~~~~~~~~~~~~~~~ SYSTE1 PLANNING DEPT. PDP95 LIGHT 2004 SYSTM PLANNING DEPT. PDP95 -LIGHT 2004 -, cc I~~~PHATSTE EA'ENAA(400 - 3 FAULT AT RY4 ON 50KV RY4-WNO LINE -< SYSTEM PLANNING r DEPoT.sPDP9 A ItlOGHT ll20°4 IPP| AT THEj EASTERN AREA (4800 0 W J) :3 IC - 3 3HASE FAUT M3 A RY4 ON 500KV RY4-WNJNN LIN _ O F L 4 CYCLES OPEN FAULT LINE 4CYCLES OPNFAL LK 4CCLSn - ~~~~~~~ ~~~~~~FILE: LO4E FILE: LO4E Cd .00 14 3000 - - - - -- b- _ __ __ ___ __ __-___-__ __ __ COO*16 M:NA0 3. .. ..- CHlL 21 V:S KRBPI'- -- -- 0.30000 50~~~~~~~~~~~~~~~~~~~ 150.00 ~~~~~~~~~~~~~~~~~~~~~~ ~~ -100.0 il.3000. ." 0.30000 C#13, [AW.MK3 TeI -oo. 1.00CHNuL# 28: fVq230KV NBI --*----~-*~*-- 1ClINi 10 tANG 0N Gill - I | i CHNLB 23 IV 50OXV NE31 0 1i10.00 __ _ ---- -150. I | 1.3000 CRN 21- IV NO]* 0.30000 150 00 ---- -150.0 | | 1.3000 C0NIC 2. IV 500KV - Y41 030000 | CHNL# 20; [ANG-EIP Ull_______ CHNOL# 26: [V:500KV RY4l I150 00 a- - -l.01.3000 O-----C 0.30000 \ 1$,, , 1m 2,~~~~~~~~~~~~~~~~~~~~~~~~~ 19 l~~~~~~~~~~~~~~~ 1 ;So'0:L . .11SM I .1 0~~~~~~~~~~~~~~~~~~~~~ a I~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ Cq0) W 41~~~~~~~I* * I C. C.~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~0 .. . I :lj~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ ' ) 4' I~~~~~~~~~~~~~~~ 0') >C (r) SYSTEM PLAING DEPT. PDY95 .LIGHT 2004 Ua g - SYSTEM PLANNING DEPT. PDP95 ,LIGHT 2004 . 'D 4 ;1 IPP AT THE EASTERN AREA (4800 M) O, IPP AT THE E4800 N) ° = I ~~~SINGLE LINE TO GROMD FAULT AT RY4 ON 500KV RY4-NCO 2 LS H SINGLE LINE TO GROLID PAULT AT RY4 ON 500KV RY4-NC0 2 LIMR CD0a) Q IOPEN FAULT LINE 4 AND 6 CYCLES (CONTIGENCY N-2) O OPI PAFULT LINE 4 AND 6 CYCLES (CONTIGENY N-2) gll PFILE: L04E2RY4-NCO FILE: LO4E2RY4-NCO O G |150003CWL 16: [AIm:sn 15S - | C| 30 27: EV:5009V PBPPI , <1G o 1150 00 - - - - -150.0 | 1 |3000 4-9,*. 030000 - - CElLO 14: rIOG-BPK T1l j I. cm 30: [V,230KV 60T] ..... I F5Q.00 _ -150.0 0l.3000 maIe0 ~~~~ ~ -150.0 to 1l.30300. 0.30000 1 F cOillB 10: I IA m- - G1-13 -150.0 | 11.3000 a s 2 3: -' - - - - - - - - * 0.30000 | MQ#L 1* 0IAN:m Gll >1ICommA 21- IV*SoGKV Irol i 150.00 - : G -150.01 i 1.3000 - , * 0.300001 i 150.00 CMa 20: IAW:EIP 011 -150.0 1 i 1.3000 cQIL0 26: [V:50OIV RY61 - 0.30000 I k i t i s g L t~~~~~~~~~~~~~~~~~~~~~~1 ift'|ul IE1 'I .1 I is It oJP - _0 ! - I I , N ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ II ~ ~ ~ ~ ~ ~ ~ ~ ~ ;E I I I~~~~~~~~~~~~~~~~~~~~~~~~~~~~ 'ItI I ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~~~~~~~~~~~~~I I 0~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ * I ii ~~~~~~~~~~~~~~~~~~~~~i*e ~~~~~~~~~~~~u Ln L~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~n f1 SYSTEM PLANNNG DEPT. PDP95 ,LIGHT 2004 ' 1 SYTE PLNIGDP.PD9 UH 04W ~ (~W~-I IPP AT THE EASTEIRN AREA (4800 14W) IP ATE TPE ATENr AREPT (4800 LIGHT00 OFNN FAULT TOGROUND FAULTAT RY4 ON 500V RY4-WNO 2 INES ~r-L-I INGLE LINE TO GROUND FAULT AT RY4 ON 500WV RY4-WNO 2 LIVES SPENGFALTE IE oiN YLS(CgIEC OPEN FAULT LINE 4 AND 6 CYCLES (CONTIGENCY N-2) in FIEL4EY-lOPILE: L04E2RY4-WNO a Id CH1 IS I6 AlInSN 051 - -WM300~# 27: IV:5001V MIPP) j I 050.00~ ~ ~~~ ~~~~~~~~~~~~~~~~~~~~~40 50.00 - - - - - - -~~~~~~~ -T150.01 Si .3000 …0.00 150.00 - 150.0 I I 1.3000 - . .30000 ~ C'MI 3~ ING ji TO E I i I V23XV 'I ~~~~~~~~~~~~~~~~~0~~~ CMMI10;IW;N 011 MMI23:IV LIK )0 ISO. 00 1. 3000 6.30000 00I 0 ~ ~ ~ ~ ~ ~ ~ ~ * 0~~~~~~ :jI~~~~~~~~~~~~~~~~~~~~~~~~~~~~i I 0 A I~~~~~~~~~~~~r I~~~~ ~~~Em I a N a~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ 0 0 1 41~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~0 w X SYSTEK PLANN1NG DEPT. PDP95 PEAK 2005 *[AZ SYSTEM PLANNINl DEPT. PDP95 ,PEAK 2005 , -4 ~~~IPPA H rT:NARA(80M)4IP AT THE EASTERN AREA (6800 MW) 'T4 L, -A 3 PHASE FAULT AT RY4 ON 500KV RY4-NCO LINE 3 PHASE FAULT AT RY4 ON 500KV RY4-NCO LINE OPEN FAULT LINE 4 CYCLES n OPEN FAULT LINE 4 CYCLES in FrLE: POSE 0% FILE: POSE e ___ -_ rI 16s - - - - - s - -150.0 | - Ii.3000 0.30000 50 r 0O > | 150,00 .........CHNU 1d r or r11 -150.0 1.3000C 30: (:230KV -K .300 I _ElIA _*- ry 13 rA: 2 I cHHL# 2,30XV 1111 i5o 0.00 3 -1 ---- 0.30000 9 ~~~~~~~~~CHNL# 10: IANG:ICN Glil-lS. | cm | .30 3: rv:sooKV Sl_ .300 | 150 00 -HL 1: -MGS -l - - - 150.0 | 1 11 3000 -NL -,, -VS-O - - - - - 0.300| rr I I i 'l' f- i' 'dE ' ' I I I ' F I l jE X§g !~iI 0 : SE- . - * ii~~~~~~~~~~~~~~~ .1Ia.11 * I. a I~~~~~~~~~~~~~~~~~~~~~~~~~~ 4 01 'I~~~~~~~~~~~~~~I 0 a~~~~~~~~~~~~~~~~~~ F1 SYSTEK PLANNING DE0T. PDP95 PEhK 2005 SYSTI PL-NNIN DEPT. PDP95 ,PEK 2005 '.i _' - IPP AT THE EASTERN AREA (6800 KW) )'. '- IPP AT THE EASTERN AREa (6800 HW) CD r_ 4 ,3 PHASE FAULT AT R!f4 ON 500( V RY4-WNO LINE 3 PHASE FAULT AT RY4 ON 500KV RY4-NO LINE rZlJ OPENI FAULT LINE 4 CYCLES FIE:P0ElinOPEN FAULT LINE 4 CYCLES L FILE: POSEl ~ ~~~~~~~~~~mFILE: PO5E1 at~* I 0.D0 CONLO 10: iA13: R 151 - - -C 16: hSR -1 0 1 3000 a.0 27: (V:5009V RBPP1 .00 1 g a i ISD 0. Z0 C )NL $ 1 4 : IP K - 1 5 0 .0 : I 1 x .3 0 0 0 - - -3 0 -v- -00 3 0 0 00 i 4 j-150.00 L01:IN;11331-5.| |1.00C 2,,V:3X ,____ 0.00| CH0S.4 10: rn*Bm3 I ll ,CHL 230 IV:2309V SRT1 1 150.00 - -150.0 Il 1.3000 0.30000 I COOLa 12 1M0: lOS 011 TJI CHCI, 26: IV:5002V 3B1| I150.00 * -100.0 J1.3000 a.* 0.30000 I ~~~~~~~CMM#. 10 [ANr,;I S 0111 - J Eiso CHL# 23,1- v:000V MKJI 1150.00 - - -150.0 I 11.3000 - - 0.3000o i150.00 ~COONLO 20:t ooMEI oll J10. !1300 IM# 26: [1V:500KV RYO1I300 l I I . ~ l I I , I I Io I I . 1111 ''- ;~~~~~~~~~~~~I I' -' I1 I cc 1~~~~~~~~~~~~~~~~~~~~ I - 1 .~~~~~~~~~~~I I ,~~~~ - ... .. .- H! I *0 A~~~~~~~~~~~~~~~~~~~ * ~~~~~~~~~~~~~~~p: *1 ~ ~ ~ ~ ~ ~~~~~~~~~~~~~~~C I :~~~~~~~~~~~~~~~~~~~~~~ I -~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~r I : ~~~~~~~~~~~~~~~~~~~~~~~ * on~~~~~~~~~~~~~~~~~~~~~r ; soIii . I a .1~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~= I :l~~~~~~~~ ~~~~ ~~~ * I a - . ,11 ~~~~~~~~~~~~~~~~~~~~~~~~~~ a-.~~~~~c 7 o~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~c SYS'TEK PLANNING DEPT. PDP95 PEAK 2005 SY ST? PLAOrnNI DEPT. PDP95 PEAK 2005 0 X I~W~'-1 IPP AT THOE EASTERN AREA (6800 NW) I PP AT THE EASTERN JRRA (6800 NW) XH t ' 9SINGLE LINE TO GROUND FAULT AT RY4 ON 500KV RY4-N00 2 LINES ;-' SINLE LINE TO GROUND FAULT AT RY4 ON 500KV RY4-NO 2 LIE OPE FAULT LINE 4 AND 6 CYCL (CONTOLIGENCY N-2) 6 FILE: P05E2RY4-NCO ll i FILE: P5OE2RY4-NC0 N-2) CMiz#8 16: IAiW:SNR H51 go4 113000 FILE: P052Y C P0 -150.0 130 .00 iG 00 : I: x . - - - - - - x -150 0 | 1 3000 30: A¶T:2301V t xl 28- 0.30000 | ^ QINL4 11: tuG:113 T81 _ -l- + _ 1J 2 h-3000 §0 22: IV:230N1V -l I §.33 | CU# OL 10 luG Gill I MIL# 23: IV:5o*0V WIn 150.00 --------- -150.0 1 1.3000 21: :50_* . | 150.00 -o -HSC 1: IJ[NG:SB Gll _ v |1.3000 14 0.30000 CHNAL0 20. tMBiIGP Ull -15j0 0 | 1.3000 0DiL 26: IV:500V RY41 | 1% 0 0 *. -~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~0 L a.~~~~~~~~~~~~~~~ . tQ 4 A~~~~~~~~~~~ ~~~~~~~~~, . _ I...._ SYSTE4 PLANNING DES'. PDP95 .PEAK 2005 r. SYSTEM PLANING DEPT. PDP95 ,PE 2005 .f IPP AT THE EASTERN AReA (6800 NW) ^ _ IPP AT THE EASTERN AREA (6800 HWl *rs SINGLE LINE TO GROUND PAULT AT RY4 ON 500KV RY4-WNO 2 LINES SINGLE LINE TO GROUND FAULT AT RY4 ON 500KV RY4-WNO 2 LINESS OPEN FAULT LINES 4 AND 6 CYCLES (CONIGENCY N-2) OPEN FAILT LIKES 4 AND 6 CYCLES (CNTIGCY N-22 FILE: P05E2RY4-WfOp FILE: E2RY4-W0N in C UILO 16: fA04 a SW 001 __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ a 150.00 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~- -~ -150.0 is.: CL AUT IES4AN CCLS(CNIGN00-2 is. ~0.306008 CHMIL 14: rlJES-Pw 2. T 11.3000 Vno230V SRIT | 150.00 Ca&o 13: f604 t3 T81 _ -150.01, | 1.3000 C 2& IV:2301VDl - - - - -- 0.300W01 CiDL0 10: t11G:B S li0 C,#lL 23: WtVSOt1V 131 i150.00 - - - - - - - . -150.0 | |1.3000 - - - - - - - 0.30000 _____________________ L_M_ # 1- 2 A0, B GI:C : 21: : : : : : ; WD l 150.00 -150.0 | 1.3000 - -- * 0.30w00 1150.00 m -#20 mxl l -iso.0 1 1.3:000 m#2;I-01 L4 .00 F I I I t 0 tjYo' { s "I 'III I0 *iI' 0 : ) . .&i ,' 13 ;~~~~ ~~ ~~ ~ ~~~~~~~~~ I t I1 300. V I - 1I " _ ' I' t, i r,' o _ o _ 1~~~~~~~~~~~~~~~~~~ I0 I Ib I - #i/ \1 1 X *Ik I I;_| I I I IL S c 4.. e IL * 0 B~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~L B S~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~L 0 B~~~~~~~~~~~~~~~~~~~~~~ ~~~l Os I' B . B 4~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~a '-4 * B -. .=q *~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~L ~~~ 'I' B ,~~~~~~~~~~~~~~~~~jI ~ ~ ~ ~ ~ ~ ~ uc.~~~~c O~. SYSTEM PLANNING DEPT. PDP95 LIGHT 2005 0 X SYSTEM PLANNING DEPT. PDP95 ,LIGHT 2005 0 IPP AT THE EASTERN AREA 16800 MW) ,r N IPP AT THE EASTERN AREA (6800 NW) r .,g i - _- - 3 PHASE FAULT AT RY4 ON 500KV RY4-NCO LINE 3 PHASE FAULT AT RY4 ON 500KV RY4-NCO LINE o OPEN FAULT LINE 4 CYCLES 0~ OEN FAULT LINE 4CYCLES C 0FILE: LOSE 13000 FILE: LOSE - _ 0.30000 | HN 16: rMAoN ER H----5-- cHm4L 21: [V,SoKv Rapp] CBN 14: [A:BPX Tll xK 11.3000 IV230KV SRTI 0.30000 > CH4NL# 13: ( _ _ I D |13000 TKNL0 28: tV4230XV NI - | 250. 00 - -1,-50.0 - -(-.-0-- 0.30000 | 150.00 CEIX0 10: [A(M :O 0 1 -150.0 | (|1.3000 OCP S 23: iV 500KV Mil31 0.30000 | |150.00 CPLI o .0G G- 1.1000 - - CONL 21 LVSOOKV p0(1 _ _ 0.30000 | 150.00 CM0o 20: iANr:EIP Ull -150.0 |1.3000 CHNL# 26: rV s500KV RY41 0.30000 | ~~~~~I I j i : .1 1 I 0 F I ° 1I9 0 i1) -* .~~~~~ . . . ,0 'I~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~LC I 0~~~~~~~~~~~~~~~~ 0 ~~~~~~~~~~~~0 *1'~~~~~~~~~~~~~~~C 4, 01~~~~~~~~~~~~~~~U *0~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ SYSTEM PLANNING 5EPT. PDP95 LIGHT 2005 SYSTEM PL:NNIG DEPT. PDP95 ,LIGHT 2005 IPP AT THE EASTEFN AREA 16800 MW) coIPP AT TE ASTEON AEA 0 MW tI t- stesSPHASE FAULT AT RY4 ON 500KV RY4-WN10 LINE oIP AS TH A RN 0RE 500K W L ~iZJOPEN FAULT LINE 4, CYCLES FILE: L05EIOPEN FAULT LINE 4 CYCLES D 0 ~ ~ ~ ~ ~ ~ ~ ~~IE LSlFILE: LOSEI. D j ¢ 150 Od C0M O 16 UUtG S 51 - _ _ , -1500 | 3000 CBWA 27 fV:SOOKV RBPPI a t _ _ 0.30COO 0 C 150 co CHNLO 14: fA)t:BPK TI) -150 0 |0LC 35 IV:230 tRr x 0.30000 1 t 150 00 -HDt 13: 1gCt:M3 I31 -150 0 t 8 1 1.3000 t IINLO 283: IV 230HV S _ T 0I30000 | V 5 CL 10 3KN Gil . -1500 1 3000 23 Iv500KV I 0.30000 I CHNL5 13: [AUDftM3 TO) -5 }130 CHIIL 28: IV:SOORV NH)_ 0300 I 150 00 - - - - - ' 150, 0 | 1.3000 2 6 1-500KV RYl l - 0.30000 CHNL# 20. IA0G:EIP VI)0 CML 26- [¶P500KV RY41 00 ~~~~~~~~-150.0 I1.3000 --- .00 11s000~ -~------------~ -~ 4 1 ' I I * * 1 ~ ~ I I ' T II I I I 00 0 ' --.. ~~~~~~~a 0 I~~~ . 0 I -~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~I 7- - /~~~~~~~~~~~~~~~~~~~~~~~~C S * 4 .~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~U .~~~~~~~ 00 ~ ~ ~ ~ ~ ~ ~ ~ t) SYSTEM PLANNING DEPT. PDP95 LIGHT 2005 w SYSTEM PLANNIG DEPT. PDP95 LIGHT 2005 .. X 14,;- ~IPP AT THE EASTERN AM E (6800 MW) o4 IPP AT THE EASTERN AREA (6800 WIIW *IiNGLE LINE TO GROUND FAULT AT RY4 ON 500KV RY4-NCO 2 LINES SINGLE LINE TO GROUD FAULT AT RY4 ON 500KV RY4-NCO 2 LNES r CiPEN FAULT LINE 4 AND 6 CYCLES ICONTIGENCY N-2) OPEN FAULT LINE 4 MAD 6 CYCLES (CONTIGENCY N-2) FILE: LO5E2RY4-lOC FILE: LD5U2RY4-NCO " C0 CH40 16: (031S:060 ES) - _ _ _ - -150.0 I f | 1 3000 - - - - - - 0.30000 H 150. OU CH 14W 1ANGBPX TI) x . . . . .l. . L S1 30. [V:23oxV SRTI . . x 0.30000 . 150.0o ,.~ QL1311CI53-S: .30 - -- Y3001_ _-- 000 -150.0 .3 CIM# 1. 1303 fAN 011 Te CMX4 23: WM=S0I 341 | 150.00 a o 0: IA; __ _ _ _ _, -150.0 1|13000 3_30ooo | 150,00 ~~~CHI%# 10 [MU 00 0111 100130 CM# BA 21:V:5oOIV MD EO1----- r 30-- J150.00 - oo s -5 all . _ ( 5 t -1.3000 C- 21; rV SOKVNM - - - 4 0.30000 I | 150.00 ClLO 20: IUAN:EIP UlI -150.0 |1.3000 cEmL 26: lV:500V RY41- 0.30000 | I .~~ ~ ~ ~~~ 41. 4~~~~~~~~~g 4 V a .0~~~~~~~~~~~~~ f ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~! ..~~~~~~~~~~~~~ _._ a 0 * , 0 o I~~~~~~~~~~~~ I ~~~~~~~~~~~~~. 1 0~~~~~~~~~~~~~~~~~~~: S4~~~~)~~~.~~~: ~~~~b' K -ISO ~~~~~~~~~~~~' Ct)~~~~L SYSTEM PLANNING DEPT. PDP95 .LIGHT 2005 t [ n SYSTE( PANNING DEPT. PDP95 ,LIGHT 2005 I~~ w ~ IPP AT THE BASTEE AREA (6800 MW) IPP AT THE EASTERN AREA (6800 K) Hq SI.ELN OGONDFUTA Y N50K Y-N IE SINGLE LiNE To GRouND FAULT AT RY4 ON 500KV RY4-WNO 2 LINES SIOPNGPLE LINES TO AROND FALTA C YCLE ONC 50IGN RY4N-WK ) I- iiI OPEN FAULT LINES 4 AND 6 CYCLES (CONTIGENCY -6-2) P FILE: LO5E2RY4-WN0O FILE: LO5E2RY4-WNO CHNLt 6O 13 1A SUP 9S 1 -51. | CH 27: lV:SOOFV R8PPI rE | 150.00 -. -aKt lt: -Alg3:8Pt Tll x, . ... - - -150.0 a1 | 1.3000 0.30000 | 150.00 C---- 14: rAS G :I ¶ -150.0 1.3000 --t- 28--: r230 g 1150.00 QOQf 13. rAW-NQ - B- - -150.0 1.3000 MM 28' FV*2301V HSI 0.30000 § 150.00 MLCh 10: [AG:KN Glll ------- -1 1.3000 Cm# 23: IV:500KV I--3- 0.30000| I5,0 lS.OCtSg 1: tANG:SB G1l _ -150.0 1.3000 tilNL 21: tV:500rv li31_M_] 0.30000 150.00 CH at 20:ANG:51P U1… o -150.0 1.3000 26: IV:500IV RY1 0.30000 1150.00 0~~~~~~~~~~~~~~~~1 71 CE1 fAN SE Gi 01 Cj 2: VO0V I ' s *, o ,&,2 / o~~~~~ I 0 X t \ 1 &Xo " E 1tl~~ 0 *I $al 9~~~~~~~~~~~~ I~~. a t~~~~~~~~~~~~~~~~~t 9~~~~~~~~~~~~~9L a - a~~~~~~~~~~~~~~~~~~~~~~~c X1 - 'iYSTEM PLASNNNG DEPT. PDP9S ,PEAK 2006 SYSTE PLAING DEPT. PDP95 PEAK 2006 IEPP AT THE EASTERN AREA (8800 MW) (SPLIT 500KV-BUS RY4) u l - .IPP AT THE EASTERN AREA (8800 NW) (SPLIT 500KV-BUS RY4) in zi3 PHASE FAULT AT RY4 ON 500KV RY4-VZO LINE "' 3 PHASE FAULT AT RY4 ON 500KV RY4-NCO LINE C( OPE?ES FAULT LINE 4 CYCLES OPEN FAULT LINE 4 CYCLES g; t I FILe: P065E ( FILE: P06SE 0 CHNLO I6: fAM:S Olin liSm#o 27; rV - - - 0.30880 150.00 1 - 3000 0.30000 1 C g cunt 1S.O CItL0It: [AM: - * -150.0 | _ _|1.3000 t0 30: lV:230tEV SRy,TI 0.30_ O _ _ _ 1150.00 tilNL 11: tAM:lt:13 S11_"I _ -150.0 to |1.3000 - tL, 28,; Wy,230t1V =I - - - - - 0.30000 | S 150.00 - - - -______-- -150.0 l - - - - ----- - 0.30000 150.00 CNM0 1: tANG:SB Gll -10. F 1.3000 tEHliL 21: IV:SOOEV NM _ __ _o CH0 20: fAW:lIP UllI cmm#. 26; IV:5OUK Rut1 150.00 C-150.0 | l.3000 0.30000| 7 j. I8 I 0 I:: 1.,X'-t'',X'''l~~~~ L0 0g ~~~~ /. . a S _ a H~2' ~~~~~~~I *, U~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~C ~~~, H 2, ~~~~~~~~~~~~~~~i I~~~~L C: g~~~~~~~~~~~ :1 SYSTEM4 PLANNING DEPTr. PDP95 .PEAK 2006 W 1 SYSTEKO PLANNING. DEPT. PDP95 ,PEAK 2006 3 IPP AT THE EAsTERIi AREA (8800 NW) (SPLIT 500KV-BUS RY4) ' i - IPP AT THE EASTEN AREA (8800 MW) (SPLIT 500KV-BUS RY4) - 0 ~-1 3 PHASE FULT AT RY4 ON 500KV RY4-WONO LINE ' ~ - 3 PHASE FAULT AT RY4 ON 500KV RY4-WONO LIKE 1) 3oPH FALT LINE 4 CYCLES OPE. NoW FAULT LINE 4 CYCLES FILE: P06SEI FILE: PO6SX1 a x \ 150.00 ClIL 16. (AIMGSR 1, _ _ _ -515C | 11,3000 BC 27: IV:SOOKV RWPPI __ 0 150 00o ee CBL-4 AG:? I - - - -,, - 150.0 | s }1.3000 -A/ -0 -22t - - _, ,,, 0.30000 > .CHNL 14: [AW610PK T81 E _ CHA 2J; Trj:30E I_ 1Z50.00 - -- -150.0 ri 11.3000o - - - - 0.30000 I 0 CHNJ 13 00 1AWiFEGil3 T cmc# 23: Iv:23OOX jm3l. 1150.00…~~~~~~~~ ~ ~~~~~~~~~ ~ ~~~~~-150.0 OI 11.3000 … * 0.30000 I 150.00 CHNL6 10' I IN I - - - - - - - - -150.0 |1.3000 C-M# 23: IY:500N W] - - - - - - - 0.30000 1 15C.00 CHNI, I:* (AM,:5B GI? E- _ I0. .3000 ,CNN; 21v [V50t OIV _ ___ 0.30000| 150 00 CHNL0 20: [ANS:EIP TI! -150.0 1.3000 CMA 26: lV:5001V RYSI 0.30000 0 I 1A~~~~~~~~~~~~~~~ I- 1I .1j1 .. . IE * I a I a~~~o E i~~~~~~~~ :1 a ~~~~~~~~~~~~~~~~~~~~~~~~~~. ij a~~~~~~~~~~~~~~~~~~~F I: I a~~~~~~~~~~~~~~~~~E C I * C - a~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~0 I 0 7.~~~~~~~~~~~~~A * I * j F -~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~c * 1. *~~~~~~~~~~~~~~~~~~~ *I. ~ ~ ~ ~ ~ ~ ~ ~ ~ C X _ YSTEM PLANIG DPT P 20SYSTEM PLANNING DEPT. PDP95 ,LIGHT 2006 * Y. H ~~~~~IPP AT THE EASTERN AREA 18800 MW) ulIPP AT THE EASTERN AREA (8800 MW) in t_ c ,. ."3 PHASE FAULT AT RY4 ON 500KV RY4-WNO LINE d ; 3 PHASE FAULT AT RY4 ON 500KV RY4-WNO LINE d 5K4 ii OPIEN FAULT LINE .4 CYCLES FIE 0S1OPEN FAULT LINE 4 CYCLEs P t UFILE: L065E1 - - FILE: L06SE1 -n - |~ ~ ~ ~ ~~ ~cNO1 150t 00 C631 AN:P T1? , - - - 10. | j COILO 3C: IV 230KV 551 - . . - K, 0.30000 | § CHNL# 16: fANGtlSGM13 1 . 5 CHNL# 23 IVV500KV P1I 0 1 150.00 -150.0 1 O 1.3000 -- 0.30000 § 0 150.00 CPNOL 10: 0IGBE Gll -150. - - - K 10.300 CNL# 231 IV;5002KV SRT- 0.30000 I > CMNlO 20 1r ANGzSB Gl _ _ CHNLJ 23: IV:SOOKV SCO1 _.300 1000O -150.0 11.3000 - 0.30000 |150.00 C PJIL I 20: [ANG :EIP Tll1 -150.0 i 1 1.3000 CHNL J 26: IV;500KV RY 51 0.30000 k X f _f : ' , I. £ S . . S - 4 __~~~~ ~ .. . o Q~~~~~~~~~~~~~~~~~~~~~ ' a~ 51, (~~~~~~~~~~~~~~~~~~ 7 *0 -.~~~~~~~~~~~~~~~~~~~~~C I ~~~~~~~~~~, ~~~~~~~~~~ E,u~~~~~~~~~~3 cm wL 40)~~~ u- SYSTEM PLANNING DEPT. PDP95 ,LIGHT 2006 SYSTYE PLANNING DEPT. PDP95 ,LIGHT 2006 1PP AT THE EASTERN AREA (8800 NW) 'W- IPP AT THE EASTERN AREA (8800 NW) L x0 S 3 PHASE FAULT AT RY4 ON 500KV RY4-NCO LINE C 3 PHASE FAULT AT RY4 ON 500KV RY4-NCO LINE ) lo..JOPEN~ FAULT LINE 4 CYCLES O PEN FAULT LINE 4 CYCLES Q) ~~~~~~~~~FILE: L06SE FLE: VLO6 SE i - k[ m.0-.P1i 1_16 i 5 1 - - _ _ 150 | 1.3000 27- - - - - -s 0.30000 | 0 *150 00 C50lL 14:_iANlj:BiS ?11 ~-150.0 i '8 3000 CJ 10: IY:230h7 t1 - - K 0.30000 | NV ____________________..........s J J.iL.L&~imL . 13:- - - - - - - _- 1 1.3000 c- 8 v . . . . _ 0.30000 | § CM#L 10* fAO-JO 03 l E23 CMI 230 IV;2500V NBI1 150.00 -150.0 | |1.3000 0.30000 I | 150 -DO C N N LJ 1: TA tX G:SB C ll I - - - - -150 .0 || 1.3000 CHNE4 2 3: iV :SO O xV R11 0 _ _ 0 000 -10.1 C50IL 21: IV:50OEV NCO] I - I150-00 _-0 1J1.3000 - -* 0.30000 CENLO 20: [ANG:EIP VI]1 I j M#OL 25: [V:50034V Ry41 |150.00 CN -150 0 | 1.3000 - 0.30000 :1 0 0 0 : a '.~_ , I 5.~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~I Jw/~ --5-- - 0~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~C LU SYSTEM PLANNING DEPT. PDP95 PEAK 2007 SYSTEM PLANNING DEPT. PDP95 PEAX 2007 X l PPA TiEEATREi RA lOOOli)° lIPP AT TFiE EASTERN AREA ' °r *'e t 3 PHASE FAULT AT RY4 ON 500KV RY4-NCO LINE IPP AT THE EASTERN ARYEA r-~ ~ ~ IPA H ASENA~A (OD W 3 PHASE FAULT AT RY4 ON 500KV RY4-NCC) LINE ~ OPEN FAULT LINE 4 CYCLES OPEN FAULT LINE 4 CYCLES V.) 4) FILE: P07SE an FILE: PO7SE i>. i | 150.00 ~~~~~~CMNL 16: IAS)M:Sl H5L >. _.- ----lS. DM R | 03C 3Iv:soxv RBpPPi ___ o300| C | 150 00 C 1 -150.0 1.3000 -L : Iv:20xv 5- - - - - 0.30000 | |L. 150.00 CHNWL 14: iANG:B5 00K Tl CH1.3 300 iV:230KV SETI N 0.30000 150.00 CHa0 13 0r W TE CR1&4 23: [v:230KV 0N1 o N0.30000 | | 150.00 COiSLa 10 [0200 aiiXBGll Oi | i 11H3000 NL#1 23. iv soo r v Nll , _, 0.30000 I 00 Ci.5- - - - - o - - -150.0 | | 1.3000 co- - 26: IV;5o RY41 - 0.30000 | 000c# 1f r [:E TI I I MI ., I I l 21: V I I COLI30m 2024 ( RIEp U~l. 0.30000 0:[VS0K YO I100.0 U -DO --15.0 j 11.3260 *-V--00--V--Y- 0. 30000 'N 00~ Zo to o N l Jg,r | s ,;,19--- L,,, 1 1 1o 4= ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ -4 a' ___ YSTEM PLAEM NING DEPT. PDP95 ,PEAK 2007 51 SYSTEM PLANNING DEPT. PDP95 PEAK 2007 3 PHASE FAULT AT RY4 ON 500KV RY4-NCO LINE 3 PHASE FAULT AT RY4 ON 500KV RY4-NCO LINE __1 ~ OPEN FAULT LINE 4 CYCLES c. 0ziL=..J ICPEN FAULT LINE 4 CYCLES FILE: P07SE-98 F_IL: PPISE-80 150s co 16 fo 5 -Ia ROl2: V50IVEP - - - - - - - 0.30000 a : 5 .*- CONLO 14: IAtl:B l _W _n 0_ -l .(O 1 l.3000 30: IV:2301 SATI _0.30000 | ' | lSO.0OO CHNBI 13 70082.N3 TBi j _ _M# _10 _0 IV:230KV NBT1 _ _ 150SO.00 CHNLO lO: -ANG:DI -lil - _ _ _ _ _ _ ., -150.01 C o 11.3000 0 23: {V:5006v 1 _ _ _- - - -- -- 0.30000 I 150.01 ~~~~~~CON00O 10~ lAM:M TBO Gil-CUOL 23, lV:2300V NI030 | 150.00 CNDO 1: i:SB Gul _ ., _150A0 1 3000 1 21:- - _ 0.30000 CNNLO 20: AING::lP 1ll - - - - - - - 0 dROLl 26: IV:500KV 3-41 * 0.30000 1150.00 0300 0o#2~ VSOr O I I I I I I I 1 -*-1'').°0 0.30000 00ok 360--- 00 00 0 X o g r tl 2 | 111~~~~~~~~~ 0r 62~~~~2 n ul t f-Ci 4 n 0-o so)-' - > a~~~~~~~~~~~ 04 _~~~~~~~ _ - -t _C - .,,,,':,<-~~ I (e 0 . . .. i APPENDIX 4 FAULT FLOW DIAGRAMS -205- I SYSTEM 2005 mT[ 271F 1:77.71 5''';L " W~~~~~~~~~~~~~71 1 * , -5.3 A E MM00 OCH1 AIK - .1 | t2 174S _ X~~I 7 yT i . p 1n 1 i ji rt2 11 I T } t gtttThREE57.,7 1 1 5 :'- ' ° { 1''''' zl70]] PHASE FAULS2 S.T i, 7;12=982z W l1.it70tS t <)888411 ??tt + || ;z 7774 1 7 m*2 *o X Z@@ II ~~~~~Im | |System Planning Dept. ,Load Jun 94, PDP 95 -01 |3 -Phase F:aultl IPPs in the western area SookvB4ang70 ap3 xt ,000MWa Bung Saha 2,ts CAS SC 05- 1 f|500KV Transml5slon System PtoJect Fo, IPPs | 2005 an SWkvBangSahn-hr buns at Sats |NASS-P0W- 5t 4§rim m ~ ~~~~~~~~~SYSTEM 2 00 5 71~ ~ 77s@ _37 S _ J. ~~~~~T 5'1 C ; 7X. 11 z | Syste~m Plnnr J{ zy|50K rasislnSytmPrJctFrIPs| 05 | 0kBagapa2ChmBug4css CS S-P5W-0 A - ' SYSTEM 2006 u ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~O, **.o°§/,:K' ;~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~7 C ci' St .j |~~~~m |7 1lI C ]