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K Range – Series 1 - Schneider Electric

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1. gt INP Blk to n amp to 4 RLY to 1 lo gt FWD ges RLY lo Fwd lop gt REV RLY lo Rev Li INP BIk to q EARTH GROUND amp te FAULT SETTINGS O 0 Ai T RLY to i 1 TSS voos FWD 9 lop gt INP BIk to amp H to gt gt gt 4 O00 T RLY to 1 gt gt gt gt FWD ote T L1 lop LOG4 O 0 010 INP CB Open CLP LOG6 1 LL O00 1 Bie 1 COLP LORD OUTPUT RELAY 3 TRIP ars L4 2n OPERATED TO INITIATE los LOG2 4 O10 LOG2 INP Aux RLY Aux CB FAIL c e 513 6 tAUX1 INP Aux2 RLY Aux2 t L 1
2. INP BIk to zu amp to 4 RLY to O10 R lo gt Yopz FWD RLY lo Fwd h REV RLY lo Rev H INP Bik to gt gt EARTH GROUND amp H to gt gt FAULT SETTINGS O0 O F ps RLY to 1 22 1 4 T ORO UR fW Cu INP to amp H to gt gt gt 4 RLY to 4 2 1 4 T OX FWD 01 07 INP t amp 4 amp gt 4 RLY t gt RLY I LOGA INP gt gt 010 amp t gt gt 4 RLY gt gt Hore Koro ee PFI INP_Blk_t gt gt gt 104 2 4 Ls amp H gt gt 4 RLY gt gt gt T SEO S gt gt gt 1 a Y CB Open CLP 1066 O00 1 1 5 OUTPUT RELAY 3 TRIP AF OPERATED TO INIT
3. INP t pa amp t gt T RLY t i gt RLY I INP t amp gt gt RLY gt gt 7 INP_Blk_t gt gt gt amp H gt gt RLY gt gt gt 1 1 gt gt gt 2 LOG4 0 Lt p INP CB Open CLP LOG6 1 006 Mm O 1 COLD LOAD J START OUTPUT RELAY 3 TRIP tBF OPERATED TO INITIATE OUO tBF lt LOG2 O10 2 LOG2 FAIL INP Auxt RLY Auxl 1 L y 2 I lt 1 tAUX1 Aux2 RLY Aux2 AUXILIARY J T PF7 5 5 tAUX2 I lt 3 Sec Delay SD8 6 Loo RESET 1 INP Aux3 gt 010 010 Recorder Stopped 2069 1055 1 lt 99 O ANY RLY Aux3 010 144 gt 1 tAUX3 _4 O T 0 0 O4 508 S Recorder Stopped
4. INP Blk to m to 415 RLY to t lo Vop Po Eie T RLY los Fwd REV RLY lo Rev INP BIk to T L amp H to gt gt Qoo 1 RLY to 9120 1955 Wo FWD 1 INP Blk to amp H to gt gt gt 4 ono 000 1 RLY gt gt gt oss Vop Po FWD T 17 2 EF5 INP Blk t gt 4 000 RLY t 1 gt Vp gt Ped PH3 RLY I gt Fyd Le REV RLY I Rev H INP BIk t amp H e 4 T RLY t ToD S ves Ru T 16 INP gt gt gt 2 5 d amp H ec 4 OO T RLY gt gt gt ass es up 6 RLY tV T 1 Vs tV 4 1 OUTPUT RELAY 3 TRIP 1061 tBF OPERATED TO INITIATE 062 or INP Aux Qoo RLY Aux I lo l A LOG2 tAUX1 Q00 1 INP Aux2 RLY Au
5. Blk to 4 gt 4 7 0 T RLY to 1 4 lo gt FWD EF3 T RLY io Fwd REV RLY lo Rev INP to amp H to gt gt 000 epe T RLY to O10 O10 1 4 1 lo gt gt Vop gt FWD EF4 gt gt gt amp H to gt gt gt 4 000 eal T RLY to 10 1 99 5 We FWD Ots L 1 LOG4 9 0 0 INP Open CLP 1066 t 000 1 4 1 OUTPUT RELAY 3 TRIP 061 OPERATED TO INITIATE 010 7 log LOG2 zT 062 INP 1 010 RLY 1 O00 b lo lt X tAUX1 4 INP Aux2 RLY Aux2 Du X EF7 1 010 los tAUX2 508 506 Aux3 gt 1 010 010 DISTURBANCE 00 000 Stopped RECORDER 5088 lo lt 1 RLY 5 orp tAUX3 pd LOG3 508 T 999 Recorder C O10 Stopped INP Stg Grp2 504 Y 03 SELECT 910 000 ALTERNATIVE 1065 010 SETTING GP2 REMOTE CHANGE 1 RESET REMOTE CHANGE 2 SET gt 501 010 GLOBAL LOAD
6. INP Blk t amp H gt T RLY t I gt RLY gt gt gt amp H gt gt RLY gt gt 9 01 O 4 1 PFI gt gt 27 gt gt gt 5 amp H v 4 RLY gt gt gt 4 0O 1 o 1 2 gt gt gt K LOG4 Open 066 9 4 O00 1 pie E COLD LOAD START 7 OUTPUT RELAY X TRIP LA OPERATED TO INITIATE tBF LOG2 2 1062 FAIL lt INP Auxt RLY Aux Ce 2 lt 1 tAUX1 Aux2 RLY Aux2 AL 1 476 IS tAUX2 1 1 lt AUXILIARY J 4 3 Sec Deloy SD8 SD6 TIMERS oo 5 gt 1 010 010 DISTURBANCE RECORDER 5069 105 1 lt 99 0 ANY RLY Aux 0 1 O 1 ALL gt 1 tAUXS LA T 000 508 Stopped INP Stg Grp2 gt 504 05 SELECT CHANGE 1 X O10 000 ALTERNATIVE x 1005 SETTING GP2 REMOTE CHANGE 1 RESET REMOTE CHANGE 2 SET RLY Reduct 1 LOAD SHED LEVEL 1 RLY V Reduct 2 lt LOAD SHED LEVEL 2 LOAD J RLY V Reduct 3 SHEDDING LOAD SHED LEVEL 3 gt to 0 GLOBAL LOAD SHED gt
7. Ajddng TONOS e 8 5k LC 1599 68654 Ve Tex 6 157 e e oc ea T gt e e 1 28h ct e e 9 cpi C e 1 Ib e 2 e ce 1207 v o 1207 6571 e 1 86 1641 e ie sq Ire Vee e e Por d SL UOTJEJOI c Y x Atddns 5qyov Id 1 JO Page 176 LLI 98eq Direction of forward current flow AC DC supply Vx Phase rotation Supply to trip coil gt Relay failed gt Relay healthy Case earth Lm 29 Dm e UC 13 4 1531 3271 5 gt 9s 0 e cs e 17 81 1 35 36 1 ces 19 101 1237 3871 gt e 1 39 4071 3 gd 119 71 250 1243 4471 9 e 120 e ces 55 46 500 1547 483 e 1 21 224 59 504 Lo 23 AC 24 I 51 5251 25 sl 54 1255 561 27 28 e 12 x SCNGO Module terminal blocks viewed from rear with integral case earth link Notes 1 a ce CT shorting links make XC before b and c disconne
8. 7 7 7 7 7 7 21807 suoroouuoo Low 9 Kquo suopoouuoo Lo c LT ASP i L xq 97 purua Suo 9 2 xe21q 3104 Cow q ST yOaUUODSIp 2 pue q X Po oxeur SuNIOYs LO lt D yod suomnvorunururoo snq y FI S210N i 75 ywa aseo 18 PIMIA I uoururoo ndur 21801 42014 T GDNOS 5 4 Poc oc 8 010 gt i ye 11 Ds o 9c X 9 9p 5 TO ORE o Za 9 1 0 lt nC lt tV LTA i 69 Z C 10 611 _ o Ta 747 4 6E 9TA Orc NAOM e 56 0 3 t P e Por 415 cem Pe if tfe cd e ce 9t 18 11 rh Pu at P S e 4116 vm Pe fj ou Me 6c 1 67 lt ETA yea ose gt LPs 3 e 5 10 TTA 5 4 eseuq 9 2 yY lt roo din Ajddng Ayyeoy lt x Ajddns Od OV porey lt
9. Multiple of setting xIs Figure 55 Operating times KCEG I gt gt gt and gt gt gt Page 147 Appendix 2 LOGIC DIAGRAMS FOR KCGG KCGU and KCEU RELAYS INP Blk to as amp to gt 4 gt RLY to 1 lo RLY lo INP gt gt p Sis amp H gt gt gt EARTH GROUND RLY to gt gt FAULT SETTINGS o de gt gt de INP_Blk_to gt gt gt 4 amp H to gt gt gt 4 RLY to T lo gt gt gt 14 LOG4 0 Y INP CB Open
10. Ssuorjgorunurulroo pere ALTA lt Keay Key lt e 1795 e vs Uonoouuoo T yeo 1 LTA Iv 166 9TA 16 Le e St STA 55 6 7 ETA Or TTA e 8t e 1 9E ITA OTA 706 e t 9 1 v zd ss ya IE LOB mu F mu _ tr 091 DADYA 3 uoururoo jndur 21807 LT 1 91 SI 1 rl E 1 uoururoo 21801 K uo suorouuoo yueg c K uo e2rd A3 suorouuoo Lo 7 9843 p 8107 lt 104 q 2euuoosip pue sur Sunsoys LO SS D 5910 uongo oseuq Y yea oseo 8 YIM 652014 TONOS e 8 LT b ar IS c 9 5k Sc e 1205 PEREZ e 5 6 1505 672 72 Ici 5 1287 02 611 2 1297
11. Operating time at specified current seconds x TMS description 2 x Is 10 x Is Nominal Range Nominal Range STI30XDT 1 780 1 68 1 87 0 52 0 49 0 55 SBOXDT 10 03 9 52 10 53 2 97 2 82 3 12 I30XDT 15 05 14 30 15 81 2 34 2 23 2 46 VI30XDT 13 5 12 82 14 18 1 50 1 43 1 58 EDOXDT 26 67 24 66 28 67 0 81 0 74 0 87 26 67 24 66 28 67 0 81 0 74 0 87 LTBOXDT 120 0 121 126 13 33 12 66 14 Set time to gt 5 0 02 to 0 04 seconds Table 6 13 Note The operating times given above are for TMS 1 Therefore to obtain the operating time for any other TMS setting the relay s actual TMS setting must be multiplied by the time given in the table above For all curves there is an additional tolerance of between 0 02 and 0 04 seconds All the operating times given have no allowance for errors in the measuring instruments Current setting for lo gt gt and gt gt gt WARNING THE RELAY MAY BE DAMAGED BY APPLYING EXCESSIVE CURRENT FOR LONG DURATIONS DURING TESTING OR IN RECURRENT BURSTS WITHOUT ALLOWING TIME FOR THE RELAY TO COOL DOWN This test is to check that the instantaneous current level of the lo gt gt and Io gt gt gt is correct If gt gt element is to be used by the customer then the EARTH FAULT function link 1 must be set to 1 This test can only be performed if the test set available can inject sufficie
12. vie tAUXI Ic Io tAUX2 tc m to E un tAUX3 ic to gt gt gt Fn Flags for last fault Fn 1 Flags for previous fault A B C N Indicates the phases that started gt operated V Undervoltage trip t gt gt operated 55 t gt gt gt operated AUX123 Indicates which of the auxiliary outputs operated Figure 2 Flag display format Page 16 3 2 Menu system Data within the relays is accessed via a MENU table The table is divided into columns and rows to form cells rather like a spreadsheet Each cell may contain text values limits and functions The first cell in a column contains a heading which identifies the data grouped on that column Four keys on the frontplate of the relay allow the menu to be scanned and the contents displayed on the liquid crystal display LCD The act of depressing any key will result in the LCD backlight being switched on The backlight will turn off again if a key is not pressed again within one minute The display will normally be the selected default setting and a momentary press of the function key F will change the display to the heading for the first column SYSTEM DATA Further momentary presses of the F key will step down the column row by row so that data may be read If at any time the F key is pressed and held for one second the cursor will be moved to the top of the next column and the heading for that column will be displayed F
13. S a A ee e N 9 9 909 9e Tats S EU 9 AUPA lt tte uf e Aey lt all e e ces 4 et Lest 10 61 1766 OST NHOW Ke ed e 4 vr ETA 3 amp 26 20 E Po 3 252 lt 9 ITA 3 er 51 oTa e E 1018301 oseud 170 JO 184 091 NADY 9d yeo 7 4 ured8erp uoneordde peordAT 16 uoururoo jndurt 21801 Gi mz 2 2 8 ___ Lb F 91 A 21d41 suoroouuoo Yeo oseo qi 1795 51 eordA Lo c 1991 potesta yod suoneorunururoo snq y SXoo q m e
14. gt 0 0 gt 5 IO m 8 A Recorder REC Control REC Capture REC Post Trigger REC Relay Trigger Power mode measurements Mode Page 193 10 1 10 1 4 10 1 5 10 1 7 10 1 8 10 3 10 3 1 10 3 1 1 10 3 1 2 10 3 1 3 10 3 2 10 3 2 1 10 3 2 2 Commissioning preliminaries Serial number on case module and cover checked CT shorting switches in case checked Terminals 21 and 22 23 and 24 25 and 26 27 and 28 checked for continuity with module removed from case External wiring checked to diagram if available Earth connection to case checked Test block connections checked Insulation checked Auxiliary supply checked Auxiliary power checked Auxiliary voltage at the relay terminals Watchdog contacts checked Supply off Terminals 3 and 5 Terminals 4 and 6 Supply on Terminals 3 and 5 Terminals 4 and 6 Field voltage Dual auxiliary powered relay
15. gt Jado Jo UONIAIIG Page 186 181 Sed Direction power flow for operation 13 e Series 1 ACIDE REG WD 6 gt Relay failed e supply Vx 14 AN 2 2 e e 31 Sopire To gt upply to WD gt Relay health trip coil 11 LY d A 48 s2 1 77 uve RLO 32 1 C B N 4 45 rotati RLI gt Phase rotation 36 gt e i 3 4 38 15 RL2 T 40 JE nuum 267 RL3 s LEE 44 res 3 4 4 1 29 30 gt gt gt Tu 20 128 A To 55 9 349 e 17 eL Rn e 362 RLS 351 19 101 1537 38 118 o nd 27 og 37 47 13 14 141 2 2 241 RL6 39 gt ad 17 B 9 47 E i3 cki Ce e pe sq ped sd p e e C 25 X 26 29 ail i E 155 56 50 Case earth 28 s 7 12 connection E 5 Module terminal blocks viewed from rear 1 with integral case earth link 54 4 Notes K bus communications port 1 ex CT shorting links make 56 before b and c disconnec
16. K uo ques c eord 4 suoroouuoo LO 7 843 qod p ruma 8001 2 5 1104 9 q joeuuoosrp pue q Ik syur Sunsoys LO C D 5910 queo osvo v139jur YIM 82014 euru XA Ajddns GONOS e 8c X Lc TA mC M IPS 9c X ec Te acd cc 209 1205 172 Ic oO ge 5 sr 106 dq 5 19 g 5 tr TA 1207 6 1 e e ces 1 86 LET 101 6 eo ces 1 96 l 18 11 e lt o ces tt 19 e ces ce oa 1 05 6 ese Od OV Id JO Page 171 TLI 9 4 Direction of forward current flow V lt 2 Case earth da 29 e 30 13 4 I31 32 1 e o e 15 61 293 3471 ce e e 17 81 1235 3671 ces e 19 101 1237 38 1 s pc 47 13 14 p 27 e 143 44 1 17 18 5 46 59 00 ag 121 224 5000 Sm e e 23 24 Dsi EX E e 23 XC 26 1253 5421 NK 95 5
17. Logic input common 2 gt Relay healthy gt Relay failed RL7 Case earth connection 1 Un D i K bus communications port 48V field voltage Figure 70 Typical application diagram 3 phase overcurrent and earth fault relay Type KCGG 140 012 gt LL yeo 4 ure18erp uoneorydde eordA TL K uo c LO 7 ad q d puuna 8 2 seutuna 3104 BENE 2180 joeuuoosrp pue 9 X OBEIOA PPH At TUM syur 801105 Lo 21 emm porcis m un 9c snq y lt B 12014 euru x QONOS TES 295 ce 2 49 d o RET 1205 6b Zz i 1 amp 012 ODOM i 1 BD 9 cpi C 7 T UOrnoouuoo 97 oo e xc T Se 1207 ue 52 e e E 1 86 101 61 ES
18. INP t gt x El LI amp t gt O00 1 RLY t O10 I gt Vp gt FWD RLY I Fwd REV RLY I gt Rev 4 INP gt gt amp HnH gt gt 000 RLY gt gt Vos FWD 0 1 PHASE FAULT PF1 PF4 SETTINGS INP_Bik_t gt gt gt 104 25 d PF8 amp H gt gt gt 4 eel T RLY gt gt gt D St Um gt fw 0 0 T 2064 PF6 RLY tV 010 amp tV lt y lt d 4 CB CLOSED IND 4 CB_OPEN IND PLANT __ STATUS CB BUS 2 WORD J Y M INP CB Open CLP LOG6 1 O00 1 COLD FOAR OUTPUT RELAY 3 TRIP O10 AF OPERATED TO INITIATE LOGI I lt Loc2 O10 O10 1062 0 FAIL INP Auxi O10 29 RLY 1 Hooo 7 1 212 tAUX1 Aux2 RLY Aux2 AUXILIARY PE Ic TIMERS 010 x tAUX2 O00 I lt t 5 Sec Delay 8 6 Loo cal RESET Aux3 gt 1 O10 010 DISTURBANCE Recorder LE HE Stopped RECORDER 1069 1065 15 ANY L Sro 010 ALL si auza RLY Aux3 000 508 O10 Stopped LOGIC AND SYSTEM INP Stg Grp2 SETTINGS 06 CHANGE 1 505 SELECT Beo as o1 0 000 ALTERN TIVE 065 m SETTING GP2 REMOTE CHANGE 1 RESET REMOTE CHANGE 2 SET LOAD SHEDDING 5 1 1 010 GLOBAL LOAD SHED LOAD SHED LOGIC tRESTORE 0 INP L Close CB CLOSE INP L Trip CB SD2 RLY CB Tri 1 010 TRIP CB
19. ed4q god SONOS K LY 80071 c ex Da 17 uomnoouuoo e 1 0 11046 q 2x So T jndur 01807 39euuoostp pus 4 210329 4 em 5 6 y ayeu syur SUOS LO gt lt D D c P el 5910 d 6 20 m ve 0042 ce 7 1005 61 tr e ce 5 LT Lp cp e 81 LI T er e cs lt 1 6 9TH e 01 22 D a e 130 6 rE Te Tol Cet ip 9 40 f at fe t Unos TO cd e T 6c Hs J 9520 lt ETA lt OV 7 1 cS 9 cd 1018301 oseuq uf 85 S e 51 96 ITA 9 ve AU lt 1 OTA 9 200 porey epy lt S a Lee e y Apea ley lt 9 Id e 5 I i m JO a d J noan Page 185 OPT HOM 2451 yeo pu c ure18erp jeordAL 6 amS
20. Curve Operating time at specified current seconds x TMS description 2 x Is 10 x Is Nominal Range Nominal Range STI30XDT 1 780 1 68 1 87 0 52 0 49 0 55 SBOXDT 10 03 9 52 10 53 2 97 2 82 3 12 I30XDT 15 05 14 30 15 81 2 34 2 23 2 46 VI30XDT 13 5 12 82 14 18 1 50 1 43 1 58 EDOXDT 26 67 24 66 28 67 0 81 0 74 0 87 26 67 24 66 28 67 0 81 0 74 0 87 LTBOXDT 120 0 114 126 13 33 12 66 14 DT Set time to gt 5 0 02 to 0 04 seconds Table 6 25 Note The operating times given above are for TMS 1 Therefore to obtain the operating time for any other TMS setting the relay s actual TMS setting must be multiplied by the time given in the table above For all curves there is an additional tolerance of between 0 02 and 0 04 seconds The operating times given make no allowance for errors in the measuring instruments Current setting for lo gt gt and gt gt gt WARNING THE RELAY MAY BE DAMAGED BY APPLYING EXCESSIVE CURRENT FOR LONG DURATIONS DURING TESTING OR IN RECURRENT BURSTS WITHOUT ALLOWING TIME FOR THE RELAY TO COOL DOWN This test is to check that the instantaneous current level of the lo gt gt and Io gt gt gt is correct If the lo gt gt element is to be used by the customer then the EARTH FAULT function link 1 must be set to 1 This test can only be performed if the test set available can inject sufficient current into the relay to cause the
21. LO 5 v 1 4 lt 15910 e 19 e S te N bY Ud Tw a dq 1197 81 ZI e to rc 2 8 62 ASP ces 1 86 101 61 L 1 uouruoo ndur 21807 e t3 57 e ces 19 z1 e cs e 12126 v 179 T amp 1108 suonvorunururoo 6c 1 e asea vs a 9p ose DDOM 1 ES 8c Sse g lt ETA 3t LC 4 wn 921 ae Ba aseyd x Lo e S cc c lt OTA o TA gt poprey Aey lt jS Ic XA T _ VI Ajddns Ley lt 9 D Od OV L I 161 Sed AC DC supply C A ay Phase rotation Case earth 29 30 30 13 4 131 32 1 e 2 61 133 3471 e 17 81 1 35 36 1 t 5 Ts ost gt e 1 39 40 1 13 14 27 e e 1143 44 1 17 18 er el de 145 461 9 2 ad 121 22 500 s 23 24 Ps sx e 9 42 25 1 53 54 Os 27 E 28 e y SCNGO Module terminal bloc
22. e o e e ce 2 p 1107 6571 let e or fg IPE ze j Dos ec o 2 XA Ajddns a Oq ov ose Page 173 YLI Direction of forward current flow zd C B Phase rotation Case earth 29 j 30 da 13 4 1531 32 1 e e 15 61 1 33 34 1 cs e e 17 81 1595 362 93 3866 e ep e 239 4071 13 14 e 9 ee 141 4271 43 44 7 17 8 ee gt c 1245 4621 19 201 g 48 1 57 51 9 204 5 59 504 23 24 1251 gt lt 95 2 5 1553 5421 E 955 sd 27 XX 28 e xe xc SCNGO Module terminal blocks viewed from rear with integral case earth link Notes 1 a CT shorting links make before b disconnect b Short terminals break before c Long terminal d Pin terminal pcb type 2 CT connections are typical only 3 Earth connections are typical only T e AC DC mb Supply to trip coil 1 50 NN ON ss jab NY Series REG D 6 gt Relay failed c3 puc D WD 5 gt Relay healthy DJ 20 1 RLO lb 6 34 2 36 gt e 384 RL2 40 1 gt 42
23. INP Stg Grp2 SD4 Y 03 SELECT O1 0 000 ALTERNATIVE CHANGE 4 0090 1065 oci SETTING GP2 REMOTE CHANGE 1 RESET SET L REMOTE CHANGE 2 RLY V Reduct 1 LOAD SHED LEVEL RLY V Reduct 2 LOAD SHED LEVEL 2 gt LOAD J RLY V Reduct 3 SHEDDING lt LOAD SHED LEVEL 3 F 4 toro GLOBAL LOAD SHED LOAD SHED LOGIC tRESTORE f L Close CB e CLOSE 1 4 INP L CB 502 RLY CB Tri 1 01 TRIP CB tTRIP CONTROL RLY CB Close CLOSE CB tCLOSE INP_CB Closed I CB Open TO PLANT STATUS 1 WORD CB STATUS INP CB to Bus2 F gt PHASE FAULT SETTINGS gt LOGIC AND SYSTEM DATA SETTINGS Figure 57 Logic diagram two phase overcurrent relay Type KCGG 120 Page 149
24. Accuracy class Composite error at rated accuracy limit 5 1 5 10 3 10 The accuracy limit factors detailed above should be used to ensure full range fault recording Where sensitive earth fault protection is required core balance CTs Ferranti effect CTs may be used High voltage withstand Insulation IEC60255 5 1977 2 0kVrms for one minute between all terminals and case earth 2 0kVrms for one minute between terminals of independent circuits including contact circuits 5kVrms for one minute across open contacts of output relays O to 7 1 0kVrms for one minute across open contacts of the watchdog relay Impulse IEC60255 5 1977 5kV peak 1 2 50us 0 5J between all terminals and all terminals to case earth Insulation resistance IEC60255 5 1977 gt 100 MQ Electrical Environment DC supply interruptions IEC60255 11 1979 The relay shall withstand a 10ms interrupt without de energising Page 91 5 15 2 5 15 3 5 15 4 5 15 5 5 15 6 5 16 5 161 5 16 2 5 16 3 AC ripple dc supply IEC60255 11 1979 The relay shall withstand 12 ac ripple High frequency disturbance IEC60255 22 1 1988 Class 2 5kV peak between independent circuits and case 1 0 peak across terminals of the same circuit No additional tolerances are required for the operating time or the unit s thresholds Electrostatic discharge IEC60255 22 2 1989 Class III 8 0kV disch
25. 2 CT connections are typical only 3 Earth connections are typical only Logic input common 15 L6 L7 2 KCGG 240 Case earth connection 54 gt Relay failed gt Relay healthy K bus communications port 48V field voltage Figure 73 Typical application diagram dual powered 3 phase overcurrent and earth fault relay Type KCGG 240 OLI DAON Oddy yeo ure18erp eordA pL 1104 snq y Aep lt KeA lt 8 NN 9 uonsouu0s 9525 DHOM xvo1q 1104 pue syur 3unious LO K uo c Aquo 15 Z puuna 5 9 a 9 1 910 ad4q q d 1 uoururoo ndur 21807 UIT teo oseo 8 Sxoo q GONOS
26. AREVA Range Series 1 Overcurrent and Directional Overcurrent Relays Service Manual R8501H Models available The following list of models are covered by this manual KCGG 110 KCGG 210 KCGG 120 KCGG 130 KCGG 230 KCGG 140 KCGG 240 KCGU 110 KCGU 140 KCGU 240 KCEG 110 KCEG 210 KCEG 130 KCEG 230 KCEG 140 KCEG 240 KCEG 150 KCEG 250 KCEG 160 KCEU 110 KCEU 140 KCEU 240 KCEU 141 KCEU 241 KCEU 150 KCEU 250 KCEU 160 Page 4 1 1 1 2 1 3 14 1 5 2 1 2 2 2 3 3 1 3 2 3 3 3 4 3 5 3 6 3 7 4 1 4 2 4 3 4 4 4 5 4 6 4 7 5 1 5 2 5 3 5 4 5 5 5 6 5 7 5 8 5 9 5 10 5 11 5 12 5 13 5 14 5 15 CONTENTS SAFETY SECTION HANDLING AND INSTALLATION General considerations Handling of electronic equipment Relay mounting Unpacking Storage INTRODUCTION Using the manual An introduction to K Range relays Models available RELAY DESCRIPTION User interface Menu system Changing text and settings Selective Features and Logic Configuration External connections Non protection features and communications APPLICATION NOTES Application of overcurrent characteristics Blocking Schemes Application notes for directional overcurrent relays Application notes for dual powered relays Breaker fail protection backtripping and back up transfer tripping Restricted earth fault Further applications and control facilities TECHNICAL DATA Ratings Burdens Overcurrent setting
27. Phase fault element PHASE FAULT function link gt 3 D 4 gt gt gt 5 6 28 Page 118 6 1 9 1 6 1 9 2 Test connections If the relay being commissioned has directional phase fault elements then the test equipment should be wired to the relay as shown in Figure 43 Care should be taken to ensure that the correct polarities are connected to the phase angle meter With the phase shifter set to 0 the phase angle meter should read 0 Angular boundary of operation With the test connections as detailed in Section 6 1 9 1 apply current and rated volts to the phase under test The current should be set above the setting threshold to I gt Make a note of the relay characteristic angle RCA which can be found under the PHASE FAULT 1 heading of the relay menu 20 9 gt Phase angle meter Figure 43 Connection for directional overcurrent relays relays KCEG 130 230 KCEG 140 240 KCEU 140 240 The forward start contact selected by the RLY I gt Fwd relay mask under the RELAY MASKS heading and the reverse start contact selected by the RLY I gt Rev relay mask should be monitored to indicate when the relay is in the operate region Taking positive angles as leading and negative angles as lagging adjust the phase shifting transformer so the phase angle meter reads 180 RCA Check that the reverse start contacts selected by the I gt Rev Start relay mask have closed and the fo
28. suorouuoo yueg Aquo eord 4 15 D Hg 8 E LI ed amp iqod purusi 7 A a rumo 8001 2 17 91 5 1104 9 q act joeuuoosip pue q Ik yod snq y TH P 51 sur Surous LO 5 D lt 910 M a LY 1 43289 osvo 8 hd 1991 uonoeuuoo 42014 o hpo A 7 T yrs asea jndur 21801 GDNOS La 2 44 g Vu ost nrg i o De 64 feu C CHR 9 rd 4 6 9TA 9 ue vt 9 ad t cl e e E Ib lt ISE STA e 1227 v I Le Por s e e cs ij 7 2 4 Le 1296 18 Li ao TO St lt ETA L e NADYA 1206 Y I e 8 e 6 cy 3 02 6c z I 510 TTA L yea ose s 21286 2 i 6 2 1 lt 96 TTA 3 SR 7 4 414 OTA 3 e lt porez epy lt 6 1018301 aseyg e Se ris Y epy lt 19 9 xA K ddns lt 2 I o e e Id 14
29. Current display Key press Effect of action Default display or F short or Display changes to first menu column fault flags after a trip F long heading SYSTEM DATA O short Backlight turns ON 0 long If the fault flags are displayed the trip LED will be reset and the display will return to the selected default display Column heading 0 short Backlight turned ON 0 long Returns to the selected default display without waiting for the time out delay Anywhere in menu F short Displays the next item of data in the column F long Displays the heading for the next column O short Turns the backlight ON 0 long If a resettable cell is displayed it will be reset Table 6 1 With the cover removed from the case The key presses listed in 6 1 1 1 still apply and in addition the and keys are accessible Current display Key press Effect of action Column heading Move to next column heading short Move to previous column heading A settable cell Puts relay in the setting mode flashing cursor on bottom line of display if the cell is not password protected Setting mode Increments value Decrements value Changes to the confirmation display If function links relay or input masks are displayed then the F key will step through them from left to right A further key press will change to the confirmation display Escapes from the setting mode without setting bei
30. 82 T DE 1275 9c pos is vc Ed 09 15058 61 1 1287 Ld 102 611 Dor ad e 81 11 64 ce 1207 v I 1207 6571 e cs 1 8 101 61 e ces 1395 GELI 18 LI e 19 cl P C e Pe t 24 ose ep A 1018101 aseyg g 2 of af v Y 2 V IS cs 4 d V ld JUALIND JO 168 691 Direction of forward current flow 2 e e lt 5 C B Phase rotation AC DC supply Vx e Case earth iy 304 13 4 15311 3221 15 61 1 33 3471 cs e 17 81 1 35 3621 t 5 e e 1 39 40 1 13 14 1441 4271 e 43 44 1 isl 9n 5 e 9 46 119 201 1247 4871 e gt e 121 22 1 149 e 5 23 24 51 5201 E e 25 AC 26 e 5 1 55 56 1 27 XC 28 e SCNGD Module terminal blocks viewed from rear with integral case earth link Notes 1 exc lt CT shorting links make before b disconnect b e gt Long terminal Short terminals break before c d Pin terminal pcb ty
31. FWD b 1 1 Pr INP BIk gt gt gt amp gt gt gt mm p RLY gt gt gt 1 0 1 O10 I Vp gt REV 1 S 1 2 5 2 73 RLY tV O10 amp tV 4 PFA v lt dio 4 CB CLOSED IND 4 IND PLANT 4 STATUS CB BUS 2 WORD t uf 2 INP_CB Open CLP LOG6 f COLD LOAD 1 START 4 OUTPUT RELAY OPERATED TO INITIATE 061 T lt LOG2 err O10 lo lt FAIL lt 1052 1 O10 RLY Aux m 4 gt I lt X 1 tAUX1 tT gt Aux2 195 RLY Aux2 4 44 PF7 a Em 1 tAUX2 lo lt AUXILIARY 4 t ora 010 TIMERS Auxs RLY Aux3 1063 Is 1 O10 tAUX3 i 1068 log Lr O10 00 EARTH GROUND FAULT SETTINGS PHASE FAULT SETTINGS LOGIC AND SYSTEM DATA SETTINGS CONTINUED SHEET 2
32. KCGU 110 KCGU 140 KCGU 240 KCEG 110 KCEG 210 KCEG 130 KCEG 230 KCEG 140 KCEG 240 KCEG 150 KCEG 250 KCEG 160 KCEU 110 KCEU 140 KCEU 240 KCEU 141 KCEU 241 KCEU 150 KCEU 250 KCEU 160 Note Earth fault relay Two phase overcurrent relay Three phase overcurrent relay Three phase overcurrent and earth fault relay Sensitive earth fault relay Three phase overcurrent and sensitive earth fault relay Directional earth fault relay Directional three phase overcurrent relay Directional three phase overcurrent and earth fault relay Directional earth fault and non directional overcurrent relay Directional earth fault relay with dual polarisation Directional sensitive earth fault relay Directional three phase overcurrent and sensitive earth fault relay Directional three phase overcurrent and sensitive earth fault relay with wattmetric element Directional sensitive earth fault and non directional overcurrent relay Directional sensitive earth fault relay with dual polarisation The 100 series of relays are powered by an ac dc auxiliary supply The 200 series of relays are dual powered i e powered by an ac dc auxiliary supply or from the line current transformers in the absence of an auxiliary supply Page 14 Section 3 RELAY DESCRIPTION 3 1 3 1 2 User interface This interface provides the user with a means of entering settings to the relay and of interrogating the relays to retrieve recorde
33. RLY V Reduct Load shed level 1 RLY V Reduct2 Load shed level 2 RLY V Reduct3 Load shed level 3 Figure 19 Load shedding by voltage reduction Trip and flag logic Not all protection functions will be used for tripping purposes some may be used for control or alarm The flag latching has been made programmable so that it can be set to suit the application Figure 20 shows that the trip LED and the flags are latched for operation of relays RLY3 and RLY7 but the breaker fail is only initiated by the operation of relay RLY3 To ensure correct flagging RLY3 should not be used for alarm or control functions RLY7 is used for remote tripping of the circuit breaker and when it is not required for this purpose it may be used as an additional trip relay to provide an extra trip contact The flags for the start functions for each phase and for earth elements that are operated at the time RLY3 or RLY7 is operated will be latched In addition it is possible to select an option whereby the start indications are latched even though a trip was not initiated To do this Logic Link LOG7 must be set to 1 and to inhibit this latch LOG7 must be set to 0 Note that when this option is selected it does not cause the trip LED to come on because the relay did not trip The default display does not change to the fault flags when only the start flags are latched so they can only be read by selecting the FAULT RECORDS colum
34. This is located at menu location 0020 and each bit in the word corresponds to the status of the associated opto isolated input bit 3 L3 A 1 indicates that it is recognized by the relay as being energized and 0 indicates that it is de energized Relay Status This is located at menu location 0021 and each bit in the word corresponds to the status of the associated output relay bit 3 relay 3 A 1 indicates that it is operated and 0 indicates that it is reset Serial communications Relay 2 Relay 1 SAA or unn Protocol converter Desktop computer PC Figure 27 Basic communication system Serial communications are supported over K BUS a multidrop network that readily interfaces to IEC60870 5 FT1 2 Standards The language and protocol used for communication is Courier It has been especially developed to enable generic master station programs to access many different types of relay without continual modification to the master station program The relays form a distributed data base for the Master Station and may be polled for any information required This includes Measured values Menu text Settings and setting limits Fault records Event records Disturbance records Plant status or Sow oho ue Status an eight bit word that identifies the trip and alarm state busy state also the
35. _ LOAD SHED LOGIC O lt GLOBAL_LOAD SHED gt tRESTORE TRIP f INP L Close CB CLOSE L Trip CB RLY CB Tri 502 1 T TRIP CB tTRIP 1 RLY CB Close CB CONTROL lt L ltcLose m INP CB Closed 4 INP CB Open TO PLANT STATUS rm RD TATI INP CB to Bus2 WORD CH STATUS gt PHASE FAULT SETTINGS LOGIC AND SYSTEM DATA SETTINGS Figure 58 Page 150 Logic diagram three phase overcurrent relay Type KCGG 130 INP to amp to gt 4 T RLY gt n 4 gt RLY lo INP_Blk_to gt gt amp H to gt gt RLY to DD 4 655 lt gt gt gt amp
36. 1 LOGIC function link LOG4 0 Input masks INP CB Open CLP or INP Aux2 must be allocated an input The cold load start can be initiated by either energizing the input set by the INP Aux2 mask or by energizing the input set by the INP CB Open CLP mask When cold load pick up is initiated by energizing the input set by INP Aux2 mask an additional time delay tAux2 is introduced before setting group 1 is returned to To test the cold load start the relay should be injected with current above its setting during the cold load start period The trip flags can then be examined to ensure that it was setting group 2 which initiated the trip during the cold load start period Circuit breaker control Provided the relay is wired to control a circuit breaker a manual test can be performed via the user interface of the relay as a check that the connection is functioning correctly 6 1 10 8 1 CB trip test The relay mask CB Trip must be assigned to the output relays that are to trip the circuit breaker This will not enable the remote control of the circuit breaker provided system data links 1 and 2 are set to 0 The circuit breaker trip time delay tTRIP under the LOGIC heading should be set to a value appropriate to the application Select the SYSTEM DATA heading from the menu Step down the column with short F key presses until the display reads SYS CB Control No Operation Press the key and the cursor will fla
37. 28 67 0 81 0 74 0 87 26 67 24 66 28 67 0 81 0 74 0 87 LTBOXDT 120 0 114 126 13 33 12 66 14 DT Set time to gt 5 0 02 to 0 04 seconds Table 6 17 Page 110 6 1 7 4 Note The operating times given above are for TMS 1 Therefore to obtain the operating time for any other TMS setting the relay s actual TMS setting must be multiplied by the time given in the table above For all curves there is an additional tolerance of between 0 02 and 0 04 seconds The operating times given make no allowance for errors in the measuring instruments Current setting for gt gt and gt gt gt WARNING THE RELAY MAY BE DAMAGED BY APPLYING EXCESSIVE CURRENT FOR LONG DURATIONS DURING TESTING OR IN RECURRENT BURSTS WITHOUT ALLOWING TIME FOR THE RELAY TO COOL DOWN This test is to check that the instantaneous current level of the gt gt and gt gt gt is correct If the I gt gt element is to be used by the customer then the PHASE FAULT function link 1 must be set to 1 This test can only be performed if the test set available can inject sufficient current into the relay to cause the element to operate at the customer s current setting The relay selected for the I gt gt trip can be found under the RELAY MASKS heading in RLY t gt gt Table 6 16 shows which terminals are used for each relay element To prevent sustained application of excessive current the trip output contacts for to gt gt
38. KCEG 210 KCEG 230 KCEG 240 KCEG 250 ae Ape Siar dise KCEU 110 KCEU 140 KCEU 141 KCEU 150 KCEU 160 KCEU 240 KCEU 241 250 Table 6 3 Page 100 6 1 2 2 6 1 2 3 Table 6 3 lists the relay types and the tests that must be performed the relay power supply overcurrent earth fault and directional elements A in a column indicates which type of power supply each particular relay has A number in a column indicates how many elements of that type each particular relay has After the auxiliary supply tests the settings required for the particular application should be entered as described in Section 6 1 4 After the settings have been entered the measurements checks described in Section 6 1 5 should be carried out None of the current voltage and time ranges given in these instructions make any allowance for instrument errors Commissioning the relay with the logic required for a particular application The relay should be commissioned with the selective logic settings required for the particular application Table 6 4 lists the selective logic schemes and the tests that must be performed on the relay to ensure these work correctly Selective logic function Test Opto input blocking logic 6 1 10 1 Timer blocking functions 6 1 10 2 Undervoltage logic 6 1 10
39. The threshold settings for both setting groups will be set the same as follows Page 47 25252 3 5 2 3 3 5 2 4 Phase Fault I gt 1 x rated current I gt gt 10 x rated current I lt 0 1 x rated current Earth Fault Ilo 0 2 x rated current Io gt gt 4x rated current Io lt 0 1 x rated current Sensitive E F Io gt 0 02 x rated current Io gt gt 0 4 x rated current Io lt 0 01 x rated current Directional Ip gt 0 05 x rated current Vop gt 2 volts Char Angle 0 degrees Initial control settings For relays providing phase fault protection the flags are set to auto reset three seconds after a line has been successfully re energized This feature is not available on relays that respond to residual current only because there will be no load current to pick up the undercurrent element and so perform the reset function Relays which have eight output relays will be configured for remote circuit breaker control but will not function until the link SD2 is set to 1 Load shedding automatic reset of the flags and change of setting group will be inhibited and must be similarly selected via the SD links if required Remote change of settings will be possible over the serial communication port so that settings can be downloaded via this path The disturbance recorder will be set to automatically reset on restoration of the supply and will be triggered by operation of the trip relay relay 3 Initial time dela
40. to indicate that there are no longer any records to be retrieved Page 133 6 2 4 2 Problems with disturbance records 6 2 5 6 2 6 6 2 6 1 Only one record can be held in the buffer and the recorder must be reset before another record can be stored Automatic reset can be achieved by setting function link SD6 to 1 It will then reset the recorder 3 seconds after a current greater than the undercurrent setting has been restored to the protected circuit The disturbance records are erased if the auxiliary supply to the relay is lost for a period exceeding the hold up time of the internal power supply Disturbance records can only be read via the serial communication port It is not possible to display them on the LCD No trigger selected to initiate the storing of a disturbance record Disturbance recorder automatically reset on restoration of current above the undercurrent setting for greater than 3 seconds Change function link SD6 to 0 to select manual reset Post trigger set to maximum value and so missing the fault When a master station has successfully read a record it will clear it automatically and the disturbance record bit in the status byte will then be set to 0 to indicate that there is no longer a record to be retrieved Circuit breaker maintenance records When a replacement relay is fitted it may be desirable to increment the CB maintenance counters to the values of that on the old relay The current squa
41. 020A MSI Vc 020B MSI Vo 020C MSIF Measurement 2 READ 0301 MS2W 0302 MS2 VA 0303 MS2 VAr 0304 MS2 Imax Fault current for last trip Fault current for last trip Fault current for last trip Fault current for last trip Fault line voltage for last trip Fault line voltage for last trip Fault line voltage for last trip Fault residual voltage for last fault Circuit breaker operation time for last trip Current state of flags not latched Flags for last fault n RESET trip LED only Flags for fault n 1 previous fault Flags for fault n 2 Flags for fault n 3 Flags for fault n 4 Clear fault records except CB trip time RESET Current in phase A dual polarized Current in phase B Current in phase C Current in neutral N Line voltage A B Line voltage B C Line voltage C A Phase voltage A Phase voltage B Phase voltage C Residual voltage Frequency Three phase power Three phase VoltAmps Three phase reactive power Highest of the three phase currents Page 22 3 2 6 3 27 030C Power Factor Three phase power factor 0310 MS2 Sum OPS Sum of circuit breaker operations RESET to 0 0311 MS2 Sum a 2 Sum of current phase A broken RESET to 0 0312 MS2 Sum Ib 2 Sum of current phase B broken RESET to 0 0313 MS2 Sum Ic 2 Sum of current phase C broken RESET to 0 031 MS2 Mode 0 Mode select PWP Signing direction of power flow The standard current and voltage connections shown
42. 3 and 5 contact closed contact closed 4 and 6 contact open contact open Table 6 9 6 1 3 2 3 Field voltage The relay generates a field voltage that should be used to energize the opto isolated inputs With the relay energized measure the field voltage across terminals 7 and 8 Terminal 7 should be positive with respect to terminal 8 and should be within the range specified in Table 6 10 when no load is connected Nominal dc rating V Range V 48 45 60 Table 6 10 6 1 3 2 4 Capacitor trip voltage Measure the supply to trip coil voltage across terminals 9 and 10 Terminal 9 should be positive with respect to terminal 10 and should be within the range specified in Table 6 11 when no load is connected Nominal capacitor trip voltage V dc DC range V 50 45 55 Table 6 11 6 1 3 2 5 Energization from line CTs With the auxiliary supply disconnected from the relay inject current into the relay terminals listed in Table 6 12 In each case the relay should power up correctly with the LCD showing the default display and the centre green LED being illuminated Repeat tests 6 1 3 2 3 and 6 1 3 2 4 with the relay powered from the injected current Injected current x In Terminals 0 4 x In Inject into terminals 21 and 23 Link terminals 22 and 24 0 4 x In Inject into terminals 25 and 21 Link terminals 26 and 22 0 4 x In Inject into terminals 23 and 25 Link terminals 24 and 26
43. H to gt gt gt 4 T RLY to T d To gt gt gt 1 INP t amp gt 4 RLY t gt E RLY gt INP_Blk_t gt gt Ls amp gt gt 4 RLY gt gt g INP gt gt gt EE 75 amp H gt gt gt 4 RLY t D WO Ue 01111 4 1064 0 CB Open CLP LOG6 L 4 _____ O00 1 4 1 SOLD lt OUTPUT RELAY 3 TRIP AF 5 OPERATED INITIATE 061 iB C tBF lt LOG2 O10 155 FAIL lt LOG2 Aux RLY Aux 4 0 0 O lt 1 tAUX lo INP Aux2 RLY Aux2 4 7 I lt 7010 EET tAUX2 000 lo lt t O10 Se ONE Aux3 RLY Aux3 po LOG3 I lt 0 10 tAUXS AUXILIARY J O99 5068 os TIMERS lt 3 Sec Delay 08 06 09 RESET 5 gt 1 10 010 5 DISTURBANCE ecorder Stopped RECORDER 1068 105 10 1069 RLY Aux3 1055 1 lt O any gt taux3 t T 010 O 1 0 4 ALL V 4 000 508 o Stopped 000 gt gt gt EARTH GROUND FAULT SETTINGS PHASE FAULT SETTINGS LOGIC AND SYSTEM DATA SETTINGS CONTINUED SHEET 2 Figure 59a Logic diagram three phase overcurrent and earth fault relays Types KCGG 140 and KCGU 140 Sheet 1 Page 151 CHANGE STG LOAD SHEDDING CB CONTR
44. It is also the software equivalent of rewiring a relay to connect the functions together in a different way so that they operate in a new sequence to provide the required composite function At first this may seem to be a complicated process but it will in fact be found very simple once the basic concept is understood Basic configuration factory settings The basic configuration contains the factory settings and calibration data It is not generally accessible because any incorrect changes would affect the accuracy and performance of the relay Any detected change to the basic configuration will cause the protection to stop and give an alarm since incorrect operation could follow Initial factory applied settings Initial protection settings As received the relay will be configured as a basic overcurrent relay with two protection elements per pole one having a standard inverse time current characteristic selected and the time multiplier set to 1 0 The reset time setting for this characteristic will be set to zero the second element having a definite time characteristic set for instantaneous operation The third measuring element will be inhibited and if required the appropriate function links in the phase and earth fault setting columns of the menu will need to be set to 1 The second setting group will be inhibited and its settings will not appear in the menu The breaker fail and cold load start features will also be inhibited
45. JUALIN JO Page 182 281 Direction of power flow for operation P2 Pi P2 Pi A e e e e 1 13 i eR wee be supply 14 lt i e WD 6 gt Relay healthy L N IC 51 z x 21 31 2 me a Phase rotation e WD 5 gt Relay failed 22 EXC D N 23 300 24 RLO 87 1 gt 1 3E mo 125 e 26 g Case earth 21 2 e RL2 40 d gt Al J 29 30 eS 4212 Ys 0 KCEU 141 4 3 3 RL3 44 gt gt w fs xd EI o 29 17 81 1235 3621 eo 2 95 ox RL4 al e o LL e 5 40 e Ge Ud RLS TE 143 4421 ELI 17 B Vas as 3745 495 2 asd RL6 6 JD 21 9 Nos 350 ust 50 23 24 151 5241 Semel sa RU 2 43 gt 255220 e 27 2028 595 1 52 k a SEND Logic input 1 Case earth Module terminal blocks 13 connection a viewed from rear 54 7 with integral case earth link 147 14 Notes i K bus communications port zd 56 1 lt CT shorting links make pig before b and c disconnect SCN b e Short terminals break before
46. Lco lox tAUX2 000 AUXILIARY gt 1 9 95 DISTURBANCE lt INP Aux3 Recorder TIMERS 111 Stopped RECORDER Loss los 1 RLY 5 gt tAUX3 5 EL 4 0 oio Recorder LOGIC AND SYSTEM Stopped DATA SETTINGS gt INP Stg Grp2 SD4 O00 moio SD3 SELECT CHANGE 25 O 1 0 000 ALTERNATIVE 23 1065 010 SETTING GP2 REMOTE CHANGE 1 RESET SET L REMOTE CHANGE 2 RLY V Reduct 1 LOAD SHED LEVEL 1 RLY V 2 LOAD SHED LEVEL 2 LOAD J RLY V Reduct 3 SHEDDING LOAD SHED LEVEL 3 e GLOBAL LOAD SHED LOAD SHED LOGIC tRESTORE INP L Close TE 4 INP L Trip CB RLY CB Tri SD2 010 TRIP CB tTRIP 4 TROL 000 RLY CB Close CB GONTROL lt 4 CLOSE CB 4 _tcLose Closed INP CB Open TO PLANT STATUS rm STAT INP CB to Bus2 WORDE CE STATUS Figure 65 Logic diagram dual polarized directional sensitive earth fault relays Types KCEG 160 and KCEU 160 Page 159 CB FAIL lt AUXILIARY 4 TIMERS CHANGE 4 STG GP CB CONTROL 4
47. The cold load pick up logic consists of a timer tCLP which picks up without any intentional delay when the protected circuit is de energized The initiating contact would be typically an auxiliary contact of the circuit breaker 52b that is closed when the circuit breaker is open and assigned in the CB Open CLP input mask The link LOG4 must be set to 1 then the output RLY t gt gt is delayed until the cold load pick up time delay tCLP has timed out This will delay operation for motor starting currents that may result when the predominant load is air conditioning plant It may also be used to give additional compensation for transformer inrush currents when I gt gt is set lower than that recommended for stabilization under transformer inrush conditions but care should be taken if transformer inrush can occur when the circuit is already energized Setting link LOG4 to 0 inhibits this option The cold load pick up feature may not be reliable with dual powered relays when energized from current alone because the initiation may disappear before the relay powers up Group 2 settings selected by cold load pick up Setting link LOGS to 1 SD3 to 0 causes the protection to change to the group 2 settings for the cold load pick up delay tCLP but only if the alternative setting group has been activated with link SD4 and selection is set to local with link SD3 Link LOG4 must be set to 0 to prevent the
48. prevent the relay from being damaged no external ground connection should be made to this circuit Figure 25 Capacitor discharge trip Page 57 3 6 6 4 AC series trip 3 7 3 7 1 3 7 1 1 As an alternative the trip capacitor in the dual powered relays may be discharged into an auxiliary relay This relay will be de energized in the quiescent state with its break contacts short circuiting the trip coils of the circuit breaker Figure 26 The trip coils are connected in series with the current transformer secondary circuit so that when the auxiliary relay is operated the full secondary current is diverted through the trip coils To cover all fault conditions three trip coils are required and may be necessary to limit the maximum energy that can be fed to each coil by means of saturating shunt reactors Figure 26 AC series trip arrangement Non protection features and communications Non protection features Self monitoring and protection alarms The monitoring circuits within the relay continuously perform a self test routine Any detected loss of operation in the first instance initiates a reset sequence to return the equipment to a serviceable state Examples of this are the main processor the communication processor and the display processor The voltage rails are also supervised and the processors are reset if the voltage falls outside their working range Should the main pro
49. shifting transformer so the phase angle meter reads 180 RCA Check that the reverse start contacts selected by the gt Rev Start relay mask have closed and the forward start contacts selected by the gt Fwd Start relay mask are open Rotate the phase shifting transformer so the phase lag is decreasing or the phase lead is increasing on the phase angle meter and continue until the forward start contacts close and the reverse contacts open Note the angle on the phase angle meter and check it is within the limits stated in Table 6 23 Continue rotating the phase shifting transformer until the forward start contacts open and the reverse start contacts close Note the angle on the phase meter and check it is within the limits stated in Table 6 23 Relay in operate region Phase angle meter indication Tolerance RCA 90 lag through to RCA 90 lead 99 6 23 Current sensitivity for Io This test checks the current sensitivity of the relay Operation of the relay can be monitored in three ways 1 By indication from the relay contacts 2 Viewing the SYS Relay Stat display under the SYSTEM DATA heading of the menu 3 Setting the display to Fnow which will be found in the fault record column Note The default display can be set to Fnow if preferred If the display is Fnow the current state of the flags a letter is displayed to indicate which phase has started and an will ind
50. shorting link E shorting links make before b disconnect L6 b Short terminals break before c 7 4 c e Long terminal L7 448V field voltage d Pin terminal pcb type 8 2 CT connections are typical only Logic input common 2 3 Earth connections are typical only Figure 94 Typical application diagram dual powered 3 phase overcurrent and directional sensitive earth fault relay Type KCEU 250 Appendix 4 COMMISSIONING TEST RECORD Multifunctional Overcurrent Relay Type KC Relay model number Date Relay firmware number Serial number Station Circuit Front plate information Multifunctional overcurrent relay type KC Model No Serial No Rated current In Aux Voltage Vx Pol Voltage Vn Frequency System data settings SYS Password SYS Fn Links SYS Description SYS Plant ref SYS Model No SYS firmware Ref SYS Frequency SYS Comms Level SYS Relay Address SYS Software Ref Page 189 Earth fault 1 EF1 Fn Links 01010 CT Ratio EF1 VT Ratio EF1 Charact 1 10 gt to gt TMS 1 toRESET gt gt to gt gt gt g
51. typically 30ms t gt gt to gt gt typically 50ms t gt gt gt to gt gt gt typically 50ms Minimum dwell disengagement time is affected if measuring circuit resets within 100ms of pick up For further information see Section 3 6 5 1 5 7 4 Directional Characteristic angle Operating boundary PU DO differential Polarizing voltage Vp Polarizing voltage Vop gt Polarizing current Ip gt Undervoltage V lt Undervoltage delay tV lt 5 7 5 Auxiliary timers Operating time Disengagement time Breaker Fail Timer tBF 0 90 accuracy 2 less than 3 typically lt 1 10 at dc 80 10 at dc 80 10 at 80 10 at dc 80 0 5 50 to 70 ms 30 596 or 15 to 35 ms 0 to 10 ms for timers alone 15 to 30ms including output relays and opto inputs 0 5 or 10ms Page 87 5 7 6 5 8 5 8 1 5 6 2 5 8 3 Measurements Voltage Current Power VAr VA Frequency 45 65Hz Wattmetric characteristic Influencing quantities Ambient temperature Operative range Current settings Voltage settings Operation times Angle measurement Frequency With frequency tracking Operative range Current setting Voltage settings Operating times Angle measurement 2 Vn typical Reference range 1 to 320V 2 In typical Reference range setting range 4 Pn typical 4 Pn typical 4 Pn typical 1 Fn typical 4 typical
52. 0 2 x In Inject into terminals 23 and 28 Link terminals 24 and 27 Table 6 12 Page 104 6 1 4 For 0 2 x In the relay may chatter This is due to the loading effect of the output relays and is overcome by disabling the relevant output relay masks Start and Trip Settings The commissioning engineer should be supplied with all the required settings for the relay The settings should be entered into the relay via the front keypad or using a portable PC with a K Bus connection The protection settings for the relay are contained in PHASE FAULT 1 EARTH FAULT 1 PHASE FAULT 2 and EARTH FAULT 2 menu columns The last two columns are only required if setting group 2 is used The time characteristics for the first overcurrent stages are selectable and it is not necessary to select the same curve for both phase and earth faults The selection is made in the menu columns for phase and earth fault settings but the password must first be entered before the characteristic can be changed The following abbreviations are used for the relay characteristic curves STI30XDT Short time inverse characteristic goes definite time after 30xIs SIB0XDT Standard inverse characteristic goes definite time after 30xIs EC I30XDT Inverse characteristic goes definite time after 30xIs VI30XDT Very inverse characteristic goes definite time after 30xIs EC EDOXDT Extremely inverse characteristic goes definite time after 20xIs EC EIIO
53. 005 0 8In 0 0025In Sensitive earth fault 10 gt 0 002 0 08In 0 00025In gt gt 0 002 0 8In 0 00025In Io gt gt gt 0 002 0 8In 0 00025In Io 0 0005 0 08In 0 00025In Reset General 0 95Is Note Operation is not guaranteed for earth faults below 0 2In regardless of the actual setting when the load current is below 0 4In and the auxiliary voltage is not available See also the special application notes for dual powered relays and the table in Section 4 4 3 regarding the maximum number of outputs and inputs that may be energized at any one time Page 84 5 4 541 54 2 5 4 3 Time setting ranges Inverse definite minimum time IDMT Where K x TMS I Is 1 t operation time K constant I fault current Is current threshold setting constant TMS time multiplier 0 025 to 1 2 in steps of 0 025 Curve description Name Constants Short time inverse 5 0 05 a 0 04 Standard inverse SIBOXDT 0 14 0 02 Inverse IN30XDT 94 07 Very inverse VIBOXDT 13 5 a l Extremely inverse EDOXDT 80 a 2 Extremely inverse 80 gt 2 Long time inverse LT30XDT 120 a l TEC standard characteristic Definite Independent time Setting range to gt t gt Definite time 0 to 100s tRESET Definite time 0 to 60s to gt gt t gt gt Definite time 0 to 100s to gt gt gt t gt gt gt Definite time 0 to 10s Auxiliary time delays Setting ran
54. 12b shows three auxiliary timers that may be initiated from external inputs assigned in the respective input masks and which after the set time delay operate the relays assigned in the relay masks Setting link PF7 to 1 timer tAUX2 will be initiated when the currents for all three phases are below the undercurrent settings I lt Setting link EF7 1 timer tAUX2 will be initiated when the earth fault current is below the undercurrent setting 10 lt The output to the relay assigned in the RLY Aux2 output mask will be delayed by the time setting tAUX2 Setting link LOG3 to 1 timer tAUX3 will be initiated when the current in any of the three phases rises above the undercurrent threshold I lt This can be used to provide a fourth time delayed overcurrent and fault stage Similarly setting link LOGS to 1 will produce the same effect when the residual current exceeds the setting 10 lt INP Auxl RLY Auxl RLY Aux2 RLY Aux3 Figure 12b Auxiliary timers Page 39 3 4 6 3 4 6 1 3 4 6 2 3 4 6 3 Breaker fail and backtripping Breaker failure protection When selected the breaker fail logic is activated by any protection function that has been selected to operate output relay 3 and is terminated when the command signal to this relay is terminated This feature is arranged to inhibit the START FORWARD START REVERSE START functions if the circuit breaker fails to trip Bre
55. 2 10 10 7 Cold load start pick up Initiate cold load start 10 10 8 Circuit breaker control Trip test Close test Commissioning Engineer Customer Witness Date Date Page 200 Section 11 INDEX A Accuracy Alarms Alternative setting groups Analogue inputs Auto reclose inhibition Auxiliary supply Auxiliary timers B Back tripping Back up transfer tripping Blocked overcurrent Breaker fail Burdens Busbar protection Circuit breaker control Circuit breaker maintenance Cold load start pick up Commissioning Alternative setting group Auxiliary supply tests Auxiliary timers Blocking Breaker fail Circuit breaker control Cold load start pick up Earth fault elements Equipment required Directional earth fault Directional phase fault Measurement checks On load tests Opto inputs Phase fault elements Preliminaries Test record Undervoltage logic Wattmetric element Communications Configuration Connection diagrams Contacts Dwell time CT requirements D Dead substation protection Definite time Default display Directional 85 87 21 29 57 62 40 42 53 54 78 52 87 37 38 40 76 76 68 71 39 76 81 83 69 70 20 43 80 59 41 42 79 96 130 124 101 104 123 121 124 125 124 105 108 100 111 117 117 121 105 126 121 108 110 96 189 200 122 129 28 63 66 89 46 49 160 187 50 88 54 89 75 67 81 25
56. 25 to 55 C 1 0 03 per C 1 2 46 to 65Hz 1 1 1 lt 1 Without frequency tracking 110 210 KCGU 110 110 210 160 KCEU 110 160 Operative range Current setting Voltage settings Operating times Angle measurement Auxiliary supply Nominal 47 to 52 5Hz or 57 to 63Hz 5 5 2 29 Operative range 24 125V 19 to 150 dc aux powered 50 to 133V ac aux powered 48 250V 33 to 300V dc aux powered 87 to 265V ac aux powered 100 250V 60 to 300V dual powered 60 to 265V ac dual powered Page 88 5 6 4 5 9 5 10 Current settings Voltage settings Operation times Angle measurement System X R Transient overreach Effect upon directional characteristics 0 5 0 5 0 5 0 5 lt 5 Effect upon Operating Times fault 45 from RCA lt 40ms 30 I gt 515 lt 75ms x90 I 25Is Minimum protection time delay for directional stability fault 45 from RCA 40ms lt 15 I lt 40In Additional time delay incurred for forward direction fault 45 from RCA Opto isolated inputs Capture time Release time lt 60ms X R lt 5 I 16In 100ms X R lt 15 I lt 40In 12 5 2 5ms at 50Hz 10 4 2 1ms at 60Hz 12 5 2 5ms at 50Hz 10 4 2 1ms at 60Hz Minimum operating voltage gt 35V dc Input resistance 10kQ Maximum series lead resistance 2kQ for single input at 40V min 1kQ for 2 inputs in parallel at
57. 30 34 35 71 85 Directional earth fault Disturbance records Dual polarised Dual powered Default display E Earthing Earth fault External connections Event records F Fault records Field voltage Flags Flag Trip logic reset Frequency response Frontplate Function links H Handling I Instantaneous operating times Inverse time curves K K Bus KITZ Keypad L LED indication Load shedding Logic functions diagrams M Magnetising inrush Maintenance Masks input output Measurements Menu system contents Modems O Operating times Opto isolated inputs Output relays Overcurrent Page 201 72 60 61 36 73 52 74 76 30 29 59 81 15 62 45 46 29 94 96 19 28 10 146 67 84 139 145 63 64 64 15 14 29 20 44 45 80 25 30 46 147 159 79 135 138 25 26 29 31 21 58 16 17 17 26 66 146 52 81 83 88 54 32 34 67 Password PC requirements Plant status Polarising synchronous Problem solving R Rated current Rated voltage Recorded times Reset timer Remote control Repair form Restricted earth fault S Self monitoring Settings Setting groups Signing of direction Software Start Forward Reverse Storage Synchronous polarization T Technical data Transient overreach Trip test Trip indication Trip arrangements U Undercurrent Undervoltage Unpacking User interface Watchdog 18 27 65 19 43
58. 40V min 0 5 for 4 inputs in parallel at 40V min Maximum ac induced loop voltage 50Vrms thermal limit Maximum capacitance coupled ac voltage 250Vrms via O 1uF Contacts Output relays 0 to 7 Type Rating Make Carry Break 2 make contacts connected in series 30A and carry for 0 2s 5A continuous DC 50W resistive 25W inductive L R 0 04s AC 1250VA maximum of 5A Subject to maxima of 5A and 300V Page 89 5 11 5 12 5 13 Watchdog Type 1 make 1 break Rating Make 10A and carry for 0 2s Carry 5A continuous Break DC 30W resistive DC 15W inductive L R 0 04s AC 1250VA maximum of 5A Subject to maxima of 5A and 300V Durability Loaded contact 10 000 operations minimum Unloaded contact 100 000 operations minimum Operation indicator 3 Light Emitting Diodes internally powered 16 character by 2 line Liquid Crystal Display with backlight Communication port Language Courier Transmission Synchronous RS485 voltage levels Format HDLC Baud Rate 64k bit per second K Bus Cable Screened twisted pair K Bus cable length 1000m of cable K Bus Loading 32 units multidrop system Current transformer requirements CT requirements for use in typical applications are shown below These CT requirements are based on a maximum prospective fault current of 50x relay rated current In and the relay having a maximum high set setting of 25x rated current In The CT requirements
59. 44 62 34 36 72 85 96 130 134 81 81 62 78 58 203 204 77 57 28 46 83 85 20 40 22 65 32 35 11 96 81 88 95 44 45 46 54 57 33 42 78 37 11 14 15 89 131 Page 202 REPAIR FORM Please complete this form and return it to AREVA T amp D with the equipment to be repaired This form may also be used in the case of application queries AREVA T amp D St Leonards Works Stafford ST17 4LX England For After Sales Service Department Customer Ref Model No Contract Ref Serial No Date 1 What parameters were in use at the time the fault occurred AC volts Main VT Test set DC volts Battery Power supply AC current Main CT Test set Frequency 2 Which type of test was being used 3 Were all the external components fitted where required Yes No Delete as appropriate 4 Listthe relay settings being used 5 What did you expect to happen continued overleaf Page 203 6 What did happen 7 When did the fault occur Instant Yes No Intermittent Yes No Time delayed Yes No Delete as appropriate By how long 8 What indications if any did the relay show 9 Was there any visual damage 10 Any other remarks which may be useful Signature Title Name in capitals Company name Page 204 Publication R8501H AREVA AREVA amp 0 Automation amp Inform
60. 47 RL3 44 gt 3E LO Logic inputcommon 1 KCEG 210 Case earth e lt connection 54 K bus communications port 48V field voltage Figure 80 Typical application diagram directional earth fault relay Type KCEG 210 CLI 8 Direction of forward current flow AC DC supply Vx Phase rotation Supply to trip coil 18 T 230 Case earth 29 30 1 C 13 4 1531 3271 gt e e 15 6 233 3471 e ce 17 81 1 35 3671 I d os e 1 39 4071 13 14 D 2 o e 1243 4471 Pas 47 4 9 Qi as Oy sat e 7 23 24 ic 52 gt Q 25 AC 26 e 50 E 1255 56 1 27 2528 e e x SCNGD Module terminal blocks viewed from rear with integral case earth link Notes b Short terminals break before c Long terminal d Pin terminal pcb type 2 CT connections are typical only 3 Earth connections are typical only 1 2 Gs shorting links make before disconnect Logic 1 Logic 2 er 3E gt Relay
61. 6 2 3 1 6 2 3 2 Curve selection cannot be changed Enter the password as these menu cells are protected Curves may not have been made selectable in the particular relay Alarms If the watchdog relay operates first check that the relay is energized from the auxiliary supply If it is then try to determine the cause of the problem by examining the alarm flags towards the bottom of the SYSTEM DATA column of the menu This will not be possible if the display is not responding to key presses Having attempted to determine the cause of the alarm it may be possible to return the relay to an operable state by resetting it To do this remove the auxiliary power supply for approximately 10 seconds and if it is powered from the CT circuit as well remove this source of supply possibly by withdrawing the module from its case Then re establish the supplies and the relay should in most cases return to an operating state Recheck the alarm status if the alarm LED is still indicating an alarm state The following notes will give further guidance Watchdog alarm Auxiliary powered relays the watchdog relay will pick up when the relay is operational to indicate a healthy state with its make contact closed When an alarm condition that requires some action to be taken is detected the watchdog relay resets and its break contact will close to give an alarm Dual powered relays the watchdog relay operates in a slightly modified way on this
62. 7 4 Environment 8 8 CE MARKING 8 9 RECOGNIZED AND LISTED MARKS FOR NORTH AMERICA 9 Pxxxx EN 55 1 1 2 10 Safety Section BLANK PAGE Pxxxx EN 55 81 1 Safety Section Page 3 10 1 INTRODUCTION This guide and the relevant operating or service manual documentation for the equipment provide full information on safe handling commissioning and testing of this equipment and also includes descriptions of equipment label markings Documentation for equipment ordered from AREVA T amp D is despatched separately from manufactured goods and may not be received at the same time Therefore this guide is provided to ensure that printed information normally present on equipment is fully understood by the recipient Before carrying out any work on the equipment the user should be familiar with the contents of this Safety Guide Reference should be made to the external connection diagram before the equipment is installed commissioned or serviced Language specific self adhesive User Interface labels are provided in a bag for some equipment 2 HEALTH AND SAFETY The information in the Safety Section of the equipment documentation is intended to ensure that equipment is properly installed and handled in order to maintain it in a safe condition It is assumed that everyone who will be associated with the equipment will be familiar with the contents of that Safety Section or this Safety Guide When electrical equipment is in
63. CLP LOG6 L e 1 LI 2121 tCLP pos E 1 COLD LOAD OUTPUT RELAY 3 TRIP 1061 START 5 OPERATED TO INITIATE pide tBF tBF log LOG2 1062 FAIL lt INP 1 RLY 1 VT 00 h r lo lt 1 tAUX Aux2 RLY Aux2 1 1 lo ftaux2 AUXILIARY J SD8 06 TIMERS INP_Aux3 21 O 1 O O DISTURBANCE i 4 950 000 Stopped RECORDER mE lo RLY Aux3 000 gt 1 tAUX3 595 LOGIC AND SYSTEM V 0 DATA SETTINGS INP Stg Grp2 so 000 SD3 SELECT CHANGE tCLP 910 000 ALTERNATIVE DASE LOG5 10 SETTING GP2 RESET T a REMOTE CHANGE 2 SE RLY V Reduct 1 LOAD SHED LEVEL 1 1 6 RLY V Reduct 2 LOAD SHED LEVEL 2 LOAD RLY V Reduct 3 SHEDDING LOAD SHED LEVEL 3 gt tof 6 lt GLOBAL LOAD SHED gt LOAD SHED LOGIC tRESTORE Wwe TRIP ELOSE 4 NP L Trip CB SD2 RLY CB Tri TRIP CB 4 tTRIP CB CONTROL 4 RLY CB Close CLOSE CB 4 tcLose Closed 4 INP Open TO PLANT STATUS T INP CB 15 8052 WORD CB STATUS s Figure 56 Logic diagram earth fault relays Types KCGG 110 and KCGU 110 Page 148
64. Check the relay characteristic angle for the phase fault elements is correct Note the current setting of the overcurrent setting I gt this will be found under the PHASE FAULT 1 column heading of the menu Then temporarily reduce this setting to a value less than the level of load current that is flowing at the time The direction of the relay can then be determined from operation of either the forward or reverse start relays Should the operation of the relay be the reverse of what is expected recheck the direction of current flow against the settings of the relay before making any changes to the external connections Restore all settings to their application values Note These tests alone are not conclusive that the phase connections to the relay are correct A phase angle measurement is required for conclusive testing 6 1 11 2 2 Earth fault directional relay KCEG KCEU 140 240 Earth fault directional relays are not energized under normal load conditions and it is therefore necessary to simulate operating conditions For relays that also have directional phase elements the earth fault polarizing voltage is derived from the VT phase inputs To carry out an on load test we recommend the temporary connections shown in Figure 44 which simulate a phase A to neutral fault If load current is flowing in the operating direction then providing that the correct phase relationships of the CTs and VTs have been proven and the artificiall
65. FUNCTIONS SET 0901 LOG Fn Links Link 1 LOG CB Fail Link 2 LOG Backtrip Link 3 LOG Aux3 not I lt Link 4 LOG CLP gt gt Link 5 LOG CLP Chg Grp Link 6 LOG CLP tAUX2 Link 7 LOG Latch Start Link 8 LOG Aux3 not Io lt 0902 LOG tCLP 0903 LOG tAUXI 0904 LOG tAUX2 0905 LOG tAUX3 0906 LOG tBF 0907 LOG tTRIP 0908 LOG tCLOSE 0909 LOG LS Group 090A LOG tRESTORE 090B 090C 090D 090F LOG Default Display Default Display SET 0 1 2 F now 3 Ia Ic 4 Ia Vab INPUT MASKS PWP 0A01 INP to 0A02 INP BIk to 0A03 INP Blk to gt gt gt Time time multiplier setting Hold up time for timing integration Second current threshold Time delay for second threshold Third current threshold Time delay for third threshold Characteristic angle for directional feature Undercurrent threshold Undervoltage threshold Undervoltage time delay Function links for miscellaneous logic PWP 1 Enable circuit breaker fail circuit 1 Enable backtrip circuit via Aux 1 Enable I lt to trip via Aux3 and tAUX3 1 Cold load pick up to delay t gt gt to gt gt 1 Cold load pick up to change setting group 1 CLP initiation delayed by tAUX2 1 Start function to latch flags without trip 1 Enable Io lt to trip via Aux3 and tAUX3 Time delay associated with cold load pick up SET Time delay associated with Aux1 output SET Time delay associated with Aux2 output SET Time delay associated
66. For instruction on how to change the various types of settings refer to Section 3 3 Menu contents Related data and settings are grouped together in separate columns of the menu Each column has a text heading that identifies the data contained in that column Each cell may contain text values limits and or a function The cells are referenced by the column number row number For example 0201 is column 02 row 01 The full menu is given in the following notes but not all the items will be available in a particular relay For example a single pole earth fault relay would not display any phase fault settings and a non directional relay would not display any settings associated with the directional feature Those cells that do not provide any useful purpose are not made available in the factory configuration to avoid the confusion that would occur in deciding at what values to set them In a similar way certain settings will disappear from the menu when the user de selects them the alternative setting group is a typical example If System Data Link SD4 is set to 0 alternative settings EF 2 and PF 2 will be hidden and to select them and make them visible link SD4 must be set to 1 This note is included at this time to explain why some of the items listed below may not appear in the menu for the relay that is being compared with the full list Page 18 3 2 2 The menu cells that are read only are marked READ Cells that can be
67. SHED LORD SHED TOGIC RESTORE L Close CB B L INP L Trip CB _______ 502 RLY CB Trip 1 0 1 tTRIP RLY CB Close CLOSE CB 4 JtCLOSE 4 INP_CB Closed CB Open TO PLANT STATUS NP CH to Bus2 WORD CB STATUS V gt gt EARTH GROUND FAULT SETTINGS LOGIC AND SYSTEM DATA SETTINGS Figure 60 Logic diagram directional earth fault relays Types KCEG110 and KCEU 110 Page 153
68. a substantial output is produced for the 2nd harmonic of the system frequency and also for the 3rd etc Hence it is for this reason the relays are restricted to tracking the phase quantities and do not track earth fault signals Page 95 T T T 0 100 200 300 400 Frequency Hz Figure 38 Response when tracking a single frequency Transient overreach The gt gt gt gt and I gt gt gt Io gt gt gt elements are often required for instantaneous high set and or low set functions and for these applications they need to be unaffected by offset waveforms which may contain a large dc exponential component and by transformer inrush currents To achieve this two criteria for operation are applied independently The first is that the Fourier derived power frequency component of the fault current is above the set threshold as for I gt Io gt The second is that the peak of any half cycle of current exceeds twice the set threshold value and is provided to reduce the operation time to less than that which could be obtained with the Fourier measurement alone For directional overcurrent relays see also Section 5 19 1 Another point to be aware of is that the second criterion uses peak values and these are only filtered by the anti aliasing filter However the peak measurements are still based on sampled values and the position of the samples relative to the peak of the harmonic will depend on the phase relationship The freq
69. are designed to provide operation of the phase and earth fault elements Where the criteria for a specific application are in excess of those detailed above or the actual lead resistance exceeds the limiting value quoted the CT requirements may need to be increased CT requirements for a variety of further applications are provided in publication R6096 Auxiliary powered relays KCGGI KCEGI KCGUI KCEUI KMPC Relay and CT Nominal output Accuracy class Accuracy limit Limiting lead secondary rating factor resistance one way A VA x rated current ohms 1 2 5 10P 20 1 3 5 7 5 10 20 0 11 Page 90 5 14 5 14 1 5 14 2 5 143 5 15 5 15 1 Dual self powered relays KCGG2 2 KCGU2 KCEU2 Relay and CT Nominal output Accuracy class Accuracy limit Limiting lead secondary rating factor resistance one way A VA x rated current ohms 1 7 5 10 10 0 6 5 10 10P 20 0 17 Where the K Range relays are being used for Restricted Earth Fault protection the CTs must be sized to assure stability as described in publication R4120 The CT requirements for auxiliary powered relays can be used for the KMPC but the following points should also be considered The accuracy class should be chosen depending upon the required accuracy of measurement Limits of error for accuracy class 5P and 10P Current error at rated primary current
70. are required for the application These will then respond in the display those that are not selected will be inoperative and some of them will be hidden their current set values being of no concern The next stage is to allocate output relays to the chosen functions This must be done with care because it will determine which functions latch the flags and those which latch the TRIP LED Selecting options 1 Select SYSTEM DATA heading from the menu step down to SYS Password and enter the password The alarm LED will flash to indicate that the relay is no longer password protected If required a new password can be entered at this stage Select the function link settings in the next menu cell down If SYS AUTORESET is set to 1 the trip LED will automatically reset after the protected circuit is re energized and line current is above the undercurrent threshold I lt for three seconds Note that this feature is not available on relays that only give earth fault protection If the link is set to 0 then the flags have to be manually reset with the 0 key 4 description will state the main functions for example 3PH EF Dir O C This may be changed to the user configuration reference 5 The Plant Reference can be used to identify the plant circuit or circuit breaker that the relay is associated with 6 The communication address is to be entered manually or by the auto addressing function of the Master Station
71. case whenever possible More information on safe working procedures for all electronic equipment can be found in BS5783 and IEC 60147 OF It is strongly recommended that detailed investigations on electronic circuitry or modification work should be carried out in a Special Handling Area such as described in the above mentioned BS and IEC documents Relay mounting Relays are dispatched either individually or as part of a panel rack assembly If loose relays are to be assembled into a scheme then construction details can be found in Publication R7012 If an MMLG test block is to be included it should be positioned at the right hand side of the assembly viewed from the front Modules should remain protected by their metal case during assembly into a panel or rack The design of the relay is such that the fixing holes are accessible without removal of the cover For individually mounted relays an outline diagram is normally supplied showing the panel cut outs and hole centres These dimensions will also be found in Publication R6501 Unpacking Care must be taken when unpacking and installing the relays so that none of the parts is damaged or the settings altered and they must only be handled by skilled persons The installation should be clean dry and reasonably free from dust and excessive vibration The site should be well lit to facilitate inspection Relays that have been removed from their cases should not be left in situations whe
72. circuit breaker then a trip test can be performed remotely in several ways 1 Measure the load current in each phase and reduce the phase fault setting of the relay to a known value that is less than the load current The relay should trip in the appropriate time for the given multiple of setting current The settings can then be returned to their usual value and the circuit breaker reclosed Note If the second group of settings is not being used for any other purpose it could be used for this test by having a lower setting selected and issuing a command to change the setting group that is in use to initiate the tripping sequence 2 If the relay is connected for remote control of the circuit breaker then a trip close cycle can be performed This method will not check as much of the functional circuit of the relay as the previous method but it will not need the settings of the relay to be changed If a failure to trip occurs the relay status word can be viewed whilst the test is repeated to check that the output relay is being commanded to operate If it is not responding then an output relay allocated to a less essential function may be reallocated to the trip function to effect a temporary repair but a visit to site may be needed to effect a wiring change See Section 3 3 8 for how to set relay masks CB maintenance Maintenance records for the circuit breaker can be obtained at this time by reading the appropriate data in the MEASUR
73. d 1 1239 27 E 28 EC 52 cs Me Logic input common 1 earth m 13 connection Module terminal blocks 77 viewed from rear 47 y 54 with integral case earth link L4 TEC Notes 49 ye K bus communications port ii 15 56 1 C CT shorting links make v e before b and c disconnect L6 51 J b Short terminals break before c n n 4 c gt Long terminal 17 3 E 48V field voltage d Pin terminal pcb type 2 CT connections are typical only Logic input common 3 Earth connections are typical only Figure 85 Typical application diagram 3 phase overcurrent and sensitive earth fault relay Type KCGU 140 OPT 3 ne Yes oAnisues pue aseyd c enp peordAL 7998 ndur 21807 Aquo K uo eord 43 Lo 7 e3vipo q d purua p Suoy 1104 q J2ouuoosrp 2 q X syu 301120 LO ec D S9J0N Suorjgorunuruioo
74. feature Undercurrent threshold Page 24 3 2 9 3 2 10 060 060 PF V lt tV EARTH FAULT 2 SET 0701 0702 0703 0704 0705 0706 0707 0708 0709 070A 070B 070C 070E 070F 0710 EF2 Fn Links Link 1 EF2 Enablelo gt gt Link 2 EF2 Enablelo gt gt gt Link 3 EF2 Dirn to Link 4 EF2 Dirn to gt gt Link 5 EF2 Dirn to gt gt gt Link 7 EF1 Aux 2 Io Link 9 EF2 gt gt Link E EF2 Rev Io gt gt gt EF2 CT Ratio EF2 VT Ratio EF2 Charact EF2 Io EF2 to gt TMS EF2 toRESET EF2 gt gt EF2 to EF2 Io gt gt gt EF2 to gt gt gt EF2 Char Angle EF2 Vop EF2 Io EF2 Po Undervoltage threshold Undervoltage time delay Earth fault function links PWP 1 enable gt gt 1 enable gt gt gt 1 directional control of Io gt 1 directional control of gt gt 1 directional control of lo gt gt gt 1 enable delayed undercurrent CLS initiation 1 Io gt gt operates on the Fourier result only 1 reverse direction of lo gt gt gt Ratio of CT supplying earth fault current PWP Neutral VT ratio PWP Selectable time characteristic PWP Current threshold for selected characteristic Time time multiplier setting Hold up time for timing integration Second current threshold Time delay for second threshold Third current threshold Time delay for third threshold Characteristic angl
75. flowing from the busbar to a feeder These time delays are for worst case conditions and may be reduced depending on the system X R and maximum fault level Feedback from regenerative loads must be less than the relay setting The protection can be enhanced by arranging for the internal breaker fail circuits of the feeder relays to backtrip the incoming circuit breaker as described in Section 4 5 and the transfer back up tripping described in Section 4 5 2 The use of a KCGG240 relay on the incoming feeder will provide dead substation protection as described in Section 4 4 5 Page 70 Incomer Block Short Time OC Backtrip Feeder 1 Feeder 2 Feeder 3 Feeder 4 Figure 30 Simple busbar protection 4 2 3 Protection for busbars with multiple infeeds Where there are multiple feeds to the busbar the START elements must be directionalized such that they will block operation of any relays on circuits feeding current to the busbar when they detect current flowing from the busbar to their associated feeder Directional relays can be used to provide composite schemes of protection for the feeders and the busbar using the non cascade mode of operation Application of Midos K Range relays for single and double busbar protection is further described in publications R4112 and R4114 Incomer Incomer eeder 4 eeder 1 Feeder 2 eeder 3 Figure 31 Protection of busbars with multiple
76. for In 1A ohms for phase neutral phase neutral DC supply 2 5 6 0 W at max with no output relays or logic inputs energized 4 0 8 0 W at Vx max with 2 output relays and 2 logic inputs energized 5 5 12 W at Vx max with all output relays and logic inputs energized AC supply 6 0 12 VA at Vx max with no output relays logic inputs energized 6 0 14 VA at Vx max with 2 output relays and 2 logic inputs energized 13 23 VA at Vx max with all output relays and logic inputs energized Page 83 5 2 5 Opto isolated inputs DC supply 0 25 per input 50V 10kQ 5 3 Overcurrent setting ranges 5 3 1 Auxiliary powered relays Threshold Is Step size Phase fault I gt 0 08 3 2In 0 01In gt gt 0 08 321 0 0110 gt gt gt 0 08 321 0 0110 I lt 0 02 3 2In 0 0110 Standard earth fault 10 gt 0 02 0 8In 0 0025In gt gt 0 02 8 0In 0 0025In Io gt gt gt 0 02 8 0In 0 0025In Io 0 005 0 8In 0 0025In Sensitive earth fault 10 gt 0 002 0 08In 0 00025In gt gt 0 002 0 8In 0 00025In Io gt gt gt 0 002 0 8In 0 00025In Io 0 0005 0 08In 0 00025In Reset General 0 95Is 5 3 2 Dual powered relays Threshold Is Step size Phase fault I 0 4 2 4In 0 01In I gt gt 0 4 32In 0 0110 gt gt gt 0 4 32 0 01In I 0 02 3 2In 0 01In Standard earth fault Io 0 02 0 8In 0 0025In gt gt 0 02 8 01 0 00251 Io gt gt gt 0 02 8 0 0 00251 Io 0
77. given for loss of the ac auxiliary voltage unless it is externally monitored by a separate supervision relay Special application notes for dual powered relays Dual powered relays may be fitted with eight opto isolated inputs and eight relay outputs but at the claamed minimum operating current they cannot all be energized at the same time If they are then the minimum operation current will be increased However in applications requiring a dual powered relay it is unlikely that more than two output relays will be energized at any one time The following table shows how the minimum operating current varies with the number of relays not including the watchdog and inputs that are to be energized at the same time Number of output relays energized 2 4 6 8 8 opto inputs energized 3xImin 1 5xImin 1 7xImin 2 0xImin 6 opto inputs energized 3xImin 1 4xImin 1 6xImin 1 8xImin 4 opto inputs energized 2xImin 1 3xImin 1 5xImin 1 8xImin 2 opto inputs energized 1xImin 1 2xImin 1 4xImin 1 6xImin Imin 0 4In for phase faults and 0 2In for earth faults Dead substation protection The dual powered relays derive power for the electronics and the trip coil of the circuit breaker from the line current transformers and optionally from an auxiliary ac voltage supply Applying one of these relays on the incoming feeder to the substation will ensure that the substation is still protected in the ev
78. infeeds Page 71 4 2 4 4 3 4 3 1 General points to consider in blocking applications It is possible to separate the phase and earth fault START outputs and use them to block the respective elements of the upstream relay However if this is done then the effect of current transformer saturation during phase faults has to be considered If the current transformers transiently saturate on one of the circuits then a spill current is produced in the neutral circuit of the current transformers This can result in one of two effects 1 the current exceeds the threshold of the earth fault element then it will attempt to trip if it does not receive a blocking signal from a downstream relay This will be an incorrect operation that may trip more circuits than necessary 2 as a result of spill current an earth fault element gives a blocking signal to the relay on the infeed for a short duration The problem from 1 above can be lessened by increasing the time setting of to gt gt but this will reduce the benefits of non cascade schemes The solution to consider is to block the phase and earth fault trip elements with the phase and earth fault start elements of the downstream relays but prevent blocking of the phase fault trip elements under transient current transformer saturation conditions This will be most easily achieved by setting the earth fault element polarising voltage threshold Vop above the maximum expected zero sequence vol
79. limits of the crystal This is not a problem when a Master Station is on line as the relays will usually be polled once every second or so Events that are recorded include change in state of logic inputs change in state of relay outputs fault records as defined in the FAULT RECORD column of the menu 1 2 3 change to settings made locally 4 5 alarm messages Items 1 and 2 may be deleted from the events so that up to 50 fault records may be stored Disturbance records The internal disturbance recorder has one channel allocated to each of the measured analogue quantities one to record the eight control inputs and one to record the eight relay outputs As with the event recorder when the buffer is full the oldest record is overwritten and records are deleted if the auxiliary supply to the relay is removed This ensures that when the buffer is read the contents will all be valid The disturbance recorder is stopped and the record frozen a set time after a selected trigger has been activated For example a protection trip command could be the selected trigger and the delay would then set the duration of the trace after the fault Each sample has a time tag attached to it so that when the waveform is reconstituted it can be plotted at the correct point against the time scale thus ensuring that the time base is correct and independent of the frequency The K Range overcurrent relays measure eight samples per cycle but the method of r
80. non volatile memory which remembers the state ON or OFF of the LED trip indicator when the relay was last powered and therefore Page 102 6 1 3 1 3 6 1 3 2 6 1 3 2 1 6 1 3 2 2 the indicator be illuminated With a continuity checker monitor the state of watchdog contacts as listed in Table 6 6 Terminals With relay de energized With relay energized 3 and 5 contact closed contact open 4 and 6 contact open contact closed Table 6 6 Field voltage The relay generates a field voltage that should be used to energize the opto isolated inputs With the relay energized measure the field voltage across terminals 7 and 8 Terminal 7 should be positive with respect to terminal 8 and should be within the range specified in Table 6 7 when no load is connected Nominal dc rating V Range V 48 45 60 Table 6 7 Dual powered relays 200 s Auxiliary Supply The relay can be operated from either an ac or a dc auxiliary supply but the incoming voltage must be within the operating range specified in Table 6 8 Relay rating V DC Operating AC Operating Maximum crest range V range V voltage V 100 250 60 300 60 265 380 Table 6 8 CAUTION The relay can withstand some ac ripple on a dc auxiliary supply However in all cases the peak value of the dc supply must not exceed the maximum specified operating limits Do not energize the relay using the batter
81. of zero amplitude For small frequency deviations of 1Hz this is not a problem but to allow for larger deviations an improvement is obtained by the addition of frequency tracking With frequency tracking the sampling rate of the analogue digital conversion is automatically adjusted to match the applied signal In the absence of a signal of suitable amplitude to track the sample rate defaults to that to suit the selected rated frequency Fn for the relay In presence of a signal within the tracking range 45 to 657 the relay will lock on to the signal and the 1 on the horizontal axis in Figure 37 will coincide with the measured frequency of the measured signal The resulting output for 2nd 3rd 4th 5th and 6th harmonics will be zero Thus Figure 37 applies when the relay is not frequency tracking the signal and also if it is tracking a frequency within the range 45 to 65Hz Power frequency signals are predominant in phase quantities and are therefore used in the frequency tracking routine whereas earth fault quantities often contain a high proportion of harmonic signals The earth fault element of multi pole relays will generally be locked to the power frequency as the relay tracks it using the phase quantities If the relay were to track a frequency above 65Hz then it would try to lock on to a sub harmonic frequency and the response would then be as shown in Figure 38 The horizontal axis of this graph is in Hz the units of frequency and
82. parts at hazardous voltage also electronic parts may be damaged if suitable electrostatic voltage discharge ESD precautions are not taken If there is unlocked access to the rear of the equipment care should be taken by all personnel to avoid electric shock or energy hazards Voltage and current connections should be made using insulated crimp terminations to ensure that terminal block insulation requirements are maintained for safety To ensure that wires are correctly terminated the correct crimp terminal and tool for the wire size should be used The equipment must be connected in accordance with the appropriate connection diagram Safety Section gt gt gt gt Pxxxx EN 55 811 5 10 Protection Class Equipment Before energising the equipment it must be earthed using the protective conductor terminal if provided or the appropriate termination of the supply plug in the case of plug connected equipment The protective conductor earth connection must not be removed since the protection against electric shock provided by the equipment would be lost The recommended minimum protective conductor earth wire size is 2 5 mm 3 3 mm for North America unless otherwise stated in the technical data section of the equipment documentation or otherwise required by local or country wiring regulations The protective conductor earth connection must be low inductance and as short as possible All c
83. programmable outputs The terminal numbers for the output relay contacts are given in the table at the start of Section 3 6 Output relay minimum dwell time Outputs from t gt t gt gt t gt gt gt to gt to gt gt to gt gt gt have a minimum dwell of 100ms This is because they are normally used for trip outputs and the minimum dwell ensures that they will provide a positive trip signal to the circuit breaker Circuit breaker control outputs tCLOSE tTRIP have a minimum dwell of 500ms which be increased to a maximum of 2s The restoration timer 5 is followed by the circuit breaker close dwell time All other outputs such as I gt Io tV Aux1 Aux2 and Aux3 have no deliberate dwell time added to them This is because they are either followed by a timer or used for control purposes which require a faster reset time Improving reliability of trip and closing contacts In the event of the circuit breaker failing to trip the relay contacts are called upon to break the trip coil current The majority of protective relays are not rated for this duty and their contacts may be damaged as a result This problem can be eliminated if arelay with heavy duty contacts is interposed between the output contacts of the protective relay and the circuit breaker trip circuit This can be more economical than the repair costs and the overall fault clearance time need not be increased as a result If the interposed relay is c
84. provides a quick method of setting the relay but requires the use of additional equipment such as a KITZ101 interface unit and a portable PC with suitable software Page 50 3 6 External connections Standard connection table Function Terminal Function Earth Terminal 1 2 Not Used Watchdog Relay b 3 4 m Watchdog Relay Break contact 5 6 Make contact 48V Field Voltage 7 8 48V Field Voltage Capacitor Trip Voltage 9 10 Capacitor Trip Voltage Not Used 11 12 Not Used Auxiliary Voltage Input 13 14 Auxiliary Voltage Input Not Used 15 16 Not Used A Phase Voltage In 17 18 In B Phase Voltage C Phase Voltage In 19 20 Out Common Voltage Neutral A Phase Current In 21 22 Out A Phase Current B Phase Current In 23 24 Out Phase Current C Phase Current In 25 26 Out C Phase Current Neutral Current In 27 28 Out Neutral Current Output Relay 4 29 30 Output Relay 0 31 32 Output Relay 5 33 34 Output Relay 1 35 36 Output Relay 6 37 38 Output Relay 2 39 40 Output Relay 7 41 42 Output Relay 3 43 44 Opto Control Input L3 45 46 Opto Control Input LO Opto Control Input L4 47 48 Opto Control Input L1 Opto Control Input L5 49 50 Opto Control Input L2 Opto Control Input L6 51 52 Common L0 L1 L2 Opto Control Input L7 53 54 K B
85. relay and then restored Note These tests alone are not conclusive that the phase connections to the relay are correct A phase angle measurement is required for conclusive testing Direction of forward current flow 2 Phase rotation A B short circuit re connections 1 Temporary open circuit connections Directional relays Figure 44 Connections for on load directional earth fault test KCEG 140 240 KCEU 140 240 Direction of forward current flow 2 1 Phase rotation Temporary short circuit connections gt Directional relays Temporary open circuit da connections Figure 45 Connections for on load directional earth fault tests KCEG 110 210 KCEG 150 250 KCEG 160 KCEU 150 250 Page 129 6 1 12 6 1 12 1 6 1 12 2 KCEU141 241 Wattmetric element Test connections and settings Connect the auxiliary supply to the relay and record the voltage at terminals 13 ve 14 Ensure that the line CTs short circuited and disconnected from the relay The relay to be commissioned should be set up as shown in Figure 46 Terminals 17 and 19 should both be connected to earth To test the wattmetric element it is necessary to set some function links to directionalise the earth fault elements Table 6
86. required and the relay should be returned to the factory Relays remain picked up when de selected by link or mask If an output relay is operated at the time it is de selected either by a software link change or by de selecting it in an output mask it may remain operated until the relay is powered down and up again It is therefore advisable to momentarily remove the energizing supply after such changes Page 135 6 3 6 3 1 6 3 1 1 6 3 1 2 6 3 1 3 6 3 1 4 6 3 2 Maintenance Remote testing K Range Midos relays are self supervising and so require less maintenance than earlier designs of relay Most problems will result in an alarm so that remedial action can be taken However some periodic tests could be done to ensure that the relay is functioning correctly If the relay can be communicated with from a remote point via its serial port then some testing can be carried out without actually visiting the site Alarms The alarm status LED should first be checked to identify if any alarm conditions exist The alarm records can then be read to identify the nature of any alarm that may exist Measurement accuracy The values measured by the relay can be compared with known system values to check that they are in the approximate range that is expected If they are then the analogue digital conversion and calculations are being performed correctly Trip test If the relay is configured to provide remote control of the
87. s 10 00 1 00 0 10 0 01 1 00 10 00 xIs Figure 49 Characteristic curve IN30XDT inverse definite time above 30xIs Page 142 s N 10 00 1 00 0 10 0 01 1 00 10 00 xIs Figure 50 Characteristic curve VI30XDT very inverse definite time above 30xIs Page 143 s H 10 00 1 00 0 10 0 01 1 00 10 00 xIs Figure 51 Characteristic curve EIDOXDT extremely inverse definite time above 20 15 Page 144 10 00 1 00 0 10 0 01 1 00 10 00 xIs Figure 52 Characteristic curve extremely inverse definite time above 10xIs Page 145 10 10 00 1 00 0 10 0 01 1 00 10 00 xIs Figure 53 Characteristic curve LT30XDT long time inverse definite time above 30xIs Page 146 120 105 Maximum Minimum 90 75 Operating time ms 60 45 30 10 Multiple of setting xIs 100 Figure 54 Operating times KCGG gt gt gt gt gt and gt gt gt 150 135 120 105 90 75 Operating time ms 60 Maximum Minimum
88. sales office and request the necessary information Pxxxx EN 55 1 1 Page 4 10 Safety Section 3 3 1 3 2 SYMBOLS AND EXTERNAL LABELS ON THE EQUIPMENT For safety reasons the following symbols and external labels which may be used on the equipment or referred to in the equipment documentation should be understood before the equipment is installed or commissioned Symbols Caution refer to equipment documentation Caution risk of electric shock dp EE Protective Conductor Earth terminal IE Functional Protective Conductor Earth terminal Note This symbol may also be used for a Protective Conductor Earth terminal if that terminal is part of a terminal block or sub assembly e g power supply NOTE THE TERM EARTH USED THROUGHOUT THIS GUIDE IS THE DIRECT EQUIVALENT OF THE NORTH AMERICAN TERM GROUND Labels See Safety Guide SFTY 4L M for equipment labelling information INSTALLING COMMISSIONING AND SERVICING 4 Equipment connections Personnel undertaking installation commissioning or servicing work for this equipment should be aware of the correct working procedures to ensure safety The equipment documentation should be consulted before installing commissioning or servicing the equipment Terminals exposed during installation commissioning and maintenance may present a hazardous voltage unless the equipment is electrically isolated Any disassembly of the equipment may expose
89. set are marked SET Cells that can be reset are marked RESET Cells that are password protected are marked PWP SYSTEM DATA 0001 SYS Language The language used in the text READ 0002 SYS Password Password PWP 0003 SYS Fn Links Function Links PWP LINK 0 SYS Rem ChgStg 1 Enable remote setting changes LINK 1 SYS Load Shed T 1 Enable global load shed tripping LINK 2 SYS Rem CB Ctrl 1 Enable remote circuit breaker control LINK 3 SYS Rem ChgGrp 1 Enable remote change of setting group LINK 4 SYS Enable Grp2 1 Enable setting group 2 LINK 5 SYS Auto Reset 1 Enable auto flag reset function LINK 6 SYS Auto Rec Enable auto reset of recorder LINK 7 SYS En Log Evts 1 Enable event records to be stored 0004 SYS Description Description or user scheme identifier PWP 0005 SYS Plant Ref User plant location identifier PWP 0006 SYS Model No Model number READ 0007 SYS Firmware No Firmware number READ 0008 SYS Serial No Serial number READ 0009 SYS Frequency Frequency SET 000A SYS Comms Level Communication level READ 000 SYS Rly Address Communication address SET 000 SYS Plant Status CB and isolator positions READ 0000 SYS Ctrl Status Not used READ 000E SYS Setting Grp Setting group in use 1 2 READ 000 SYS LS Stage Current state of load shedding READ 0010 SYS CB Control CB control NO OPERATION TRIP CLOSE SET 0011 SYS Software Ref 0020 SYS Logic Stat Current s
90. short time delay t gt gt being increased Setting the LOGS link to 0 inhibits this option This feature is useful where the predominant load is resistance type heating because it takes longer for the loading to diversify Therefore the overload settings have to be increased for periods of up to four hours It is also useful for setting the protection to grade with large industrial motors where the starting time may exceed the required protection trip time The cold load pick up may be initiated via the CB Open CLP mask as in the previous example However where the load is predominantly resistance heating with thermostatic control the cold load pick up feature will not be required to take effect unless the circuit has been de energized for sufficient time for all the thermostats to reset Delayed initiation can be provided by timer tAUX2 To select this method the control input that is to initiate cold load start should be assigned in the INP Aux2 input mask instead of CB Open CLP mask and link LOG6 should be set to 1 Page 43 3 4 9 By setting link PF7 to 1 cold load pick up may be initiated by the phase and earth fault undercurrent elements instead of a circuit breaker contact A delayed undercurrent output may be provided via the relay assigned in the RLY Aux2 mask INP CB Open CLP Select Setting GRP2 QUO Figure 16 Cold load pick up increased protection settings Cir
91. should be connected to trip the test set The time delay t gt gt should be set to less than 0 1 second for the test and restored to its original value when the test has been completed When the setting is above the continuous current rating of the relay DO NOT INCREASE THE CURRENT SLOWLY since this may damage the relay before it can operate Instead the current level should be set and then suddenly applied Two tests specified in Table 6 20 are for the particular current setting required for the application Initially the higher current level should be applied to check that the instantaneous element operates and then the lower current level should be applied to check that no trip occurs TRIP gt gt gt gt gt NO TRIP gt gt gt gt gt 1 05 x current setting 0 95 x current setting Table 6 20 If the gt gt gt threshold is to be used by the customer then the PHASE FAULT function link 2 should be set to 1 Test 6 1 7 4 can then be repeated for I gt gt gt but only if the test set available can inject sufficient current into the relay to cause the element to operate at the customer s current setting The relay selected for the gt gt gt trip can be found under the RELAY MASKS heading in RLY t gt gt gt The instantaneous trip output contacts must be connected to trip the test set Table 6 16 shows which terminals to use for current injection into the individual phase elements To prevent su
92. terminals break before c L6 tee Long terminal 53 Ee 17 9 7 4 Pin terminal pcb type 2 CT connections are typical only 3 Earth connections are typical only Logic input common e J RL7 43 gt Li 9 34 Case earth 227 connection 54 K bus communications port 48V field voltage Figure 72 Typical application diagram dual powered 3 phase overcurrent relay Type KCGG 230 191 Sed 2 e e Ry B AC DC supply Vx A A Supply to trip coil e B Phase rotation Case earth 1 29 30 1 E e 5 2 13 4 xd ce 15 61 133 3471 e S 4 55 xq 19 101 1237 38 1 D 40 7 Bou Pa od o 1143 44 1 T 17 18 ie 145 461 19 201 47 10 Db 2i 23 i3 24 sx i gt 25 26 1 53 54 1 sca L2 27 28 Logic inputcommon 1 Module terminal blocks viewed from rear with integral case earth link Notes 1 lt CT shorting links make before b disconnect b e gt Short terminals break before gt Long terminal 4 Pin terminal pcb type
93. the Fourier derived phase angles The relay has no electro mechanical adjustments all calibration is effected in software and all three of the above options are used in the calibration process For normal use as a fault recorder SAMPLES will be the most useful Recorder post trigger The Post Trigger setting determines the length of the trace that occurs after the stop trigger is received This may be set to any value between 1 and 512 samples When recording samples the total trace duration is 512 8 64 cycles because the interval between the samples is equivalent to one eighth of a cycle However the Fourier derived values are calculated once per cycle and so the total trace length when recording these calculated phase or amplitude values is 512 cycles Recorder logic trigger available only on models A and B Any or all of the opto isolated inputs may be used as the stop trigger and the trigger may be taken from either the energization or the de energization of these inputs The bottom line of the display for this cell will show a series of 16 characters each of which may be set to 1 or 0 A 1 will select the input as a trigger and a 0 will deselect it The selection is made using the instructions for the setting links in Section 3 3 4 The opto isolated input LO to L7 associated with each digit is shown on the top line of the display for the digit underlined by the cursor A preceding it will indicate that
94. the fault operates faster than the relays nearer to the source This is referred to as cascade operation because if the relay nearest to the fault does not operate the next one back towards the source will trip in a slightly longer time The time grading steps are typically 400ms the operation times becoming progressively longer with each stage Blocking Schemes Adding an extra time graded stage may not always be acceptable but an additional stage can be added without increasing the number of time steps by implementation of a simple blocking scheme Blocked overcurrent protection Inverse time delay blocking Non cascade operation allows closer time grading between relays and is achieved by using the START contact relay of one relay to block the operation of the time delayed element t gt to gt on the relay further back in the system towards the source Thus both relays can then have the same current and time settings and grading will be automatically provided by the blocking feature If the breaker fail protection is selected it will release the block if the circuit breaker fails to trip This gives a constant close time grading but there will be no back up protection in the event of the pilots being faulty Short time delay blocking Improved fault clearance times can be obtained by setting the gt gt gt gt element above the transient load level and setting t gt gt to gt gt to 200ms for relays with directional elements
95. the same procedure described in Section 3 3 1 Only capital upper case letters may be used for the password Page 28 3 3 3 3 3 4 3 3 5 3 3 6 BE SURE MAKE A NOTE OF THE PASSWORD BEFORE ENTERING IT ACCESS WILL BE DENIED WITHOUT THE CORRECT PASSWORD Entering text Enter the setting mode as described in Section 3 3 and move the cursor with the F key to where the text is to be entered or changed Then using the and keys select the character to be displayed The F key may then be used to move the cursor to the position of the next character and so on Follow the instructions in Section 3 3 to exit from the setting change Changing function links Select the page heading required and step down one line to FUNCTION LINKS and press either the or to put the relay in a setting change mode A cursor will flash on the bottom line at the extreme left position This is link F as indicated by the character printed on the frontplate under the display Press the F key to step along the row of links one link at a time until some text appears on the top line that describes the function of a link The key will change the link to a 1 to select the function and the key will change it to a 0 to deselect it Not all links can be set some being factory selected and locked The links that are locked in this way are usually those for functions that are not supported by a particular relay when
96. the trigger will occur for energization and a will indicate the trigger will occur for de energization Recorder relay trigger Any or all of the output relays may be used as a stop trigger and the trigger may be taken from either the energization or the de energization of these outputs The bottom line of the display for this cell will show a series of 16 characters each of which may be set to 1 or 0 A 1 will select the the input and a 0 will deselect it The selection is made using the instructions for setting links in Section 3 3 4 The output relay RLYO to RLY7 associated with each digit underlined by the cursor is shown on the top line of the display A preceding it will indicate that the trigger will occur for energization and a will indicate the trigger will occur for de energization Page 62 3 7 1 8 Notes on recorded times The times recorded for the opto isolated inputs is the time at which the relay accepted them as valid and responded to their selected control function This will be 12 5 2 5ms at 50Hz 10 4 2 1ms at 60Hz after the opto input was energized The time recorded for the output relays is the time at which the coil of the relay was energized and the contacts will close approximately Sms later Otherwise the time tags are generally to a resolution of 1ms for events and to a resolution of lus for the sample s values Flags available via serial port Status Byte This is
97. tolerance of 5 except power which is the product of two quantities and therefore has a tolerance of 10 The maximum displayed measured value for SEF element is 1 638A with a CT ratio of 1 1 Earth fault sensitive earth fault element KCGG110 210 KCGG140 240 KCGU110 KCGU140 240 The relay should be commissioned with the settings calculated for the application For dual powered relays it is recommended that the relay is energized from an auxiliary voltage supply as this will reduce the burden imposed by the relay on the current injection test set Ensure that the main system current transformers are short circuited before isolating them from the relay in preparation for secondary injection tests Also isolate the relay trip contacts Page 106 6 1 6 1 6 1 6 2 6 1 6 3 Test connections Connect the auxiliary supply to the relay and record the voltage at terminals 13 ve and 14 Ensure that the line CTs are short circuited and disconnected from the relay If relay has simple overcurrent elements then connect the current injection test set to terminals 27 and 28 of the relay If the earth fault elements are directionalized then go to Section 6 1 8 Current sensitivity for Io This test checks the current sensitivity of the relay Operation of the relay can be monitored in three ways 1 By indication from the relay contacts 2 Viewing the SYS Relay Stat display under the SYSTEM DATA heading of the menu
98. version of the relay because it does not initiate an alarm for loss of the auxiliary power as this may be taken from an insecure source or it may be powered solely from the current circuit In either case it will not be required to indicate an alarm for loss of the auxiliary power source as this may be a normal operational condition Operation of the watchdog is therefore inverted so that it will pick up for a failed condition closing its make contact to give an alarm and in the normal condition it will remain dropped off with its break contact closed to indicate that it is ina healthy state Note The green LED will usually follow the operation of the wathchdog relay in either of the above two cases There is no shorting contact across the case terminals connected to the break contact of the watchdog relay Therefore the indication for a failed healthy relay will be cancelled when the relay is removed from its case If the relay is still functioning the actual problem causing the alarm can be found from the alarm records in the SYSTEM DATA column of the menu see Section 3 7 1 Unconfigured or uncalibrated alarm For a CONFIGURATION alarm the protection is stopped and no longer performing its intended function For UNCALIBRATED alarm the protection will still be operational but there will be an error in its calibration that will require attention It may be left running provided the error does not cause any gradin
99. 01 0 000 4 PHASE FAULT gt Ve FWD Pye L 1 SETTINGS gt gt gt 104 2 amp H Uv PMS 4 000 T RLY gt gt gt 1 qio gt Vp FWD ae x T 1 PH6 RLY tV 010 y lt tv lt 4 OUTPUT RELAY 3 TRIP 1061 tBF OPERATED TO INITIATE 062 UT O10 CB FAIL 4 INP Auxt RLY Aux K lt lo lt A LOG2 tAUX1 O 0 O Aux2 RLY Aux2 1 E AUXILIAR 7 12 1 UXILIARY 4 t 010 E tAUX2 TIMERS 010 et 00 Aux3 RLY_Aux3 L K n tAUXS 1 LOGIC AND SYSTEM 2 DATA SETTINGS 04 549 Grp2 SD3 SELECT CHANGE J 1 240 O00 ALTERNATIVE STG GP 0 1 5 SETTING 2 RESET 2 SET INP L Close CB INP L Trip CB 502 RLY CB Tri O10 TRIP tTRIP CB CONTROL lt RLY CB Close CLOSE CB 4 tCLOSE Closed TO PLANT STATUS INE CB t6 Bua WORD CB STATUS J Figure 63 Logic diagram directional three phase overcurrent and sensitive wattmetric earth fault relay Type KCEU 141 Page 157
100. 1 relays 0510 gt Phase fault 1 SET 0601 0602 0603 0604 0605 0606 0607 0608 0609 060A 060B 060C 060D PF1 Fn Links Link 1 PF1 Enable I gt gt Link 2 PF1 Enable gt gt gt Link 3 PF1 Dirn t Link 4 PF1 gt gt Link 5 PF1 Dirn gt gt gt Link 6 PF1 En V Trip Link 7 PF1 Aux2 I Link 8 PF1 I gt gt 2Ph Link 9 PF1 I gt gt NoPeak Link E PF1 Rev I gt gt gt Link F ALL 2 3 PF1 CT Ratio PF1 VT Ratio PF1 Charact 1 I gt 1 t gt TMS PF1 tRESET PF1 I gt gt gt gt 1 I 1 gt gt gt PF1 Char Angle 1 I lt Wattmetric power threshold Phase fault function links PWP 1 enable gt gt 1 enable gt gt gt 1 directional control of I gt 1 directional control of I gt gt 1 directional control of I gt gt gt 1 enable delayed undervoltage trip 1 enable delayed undercurrent CLS initiation 1 enable 2 3 logic for gt gt 1 gt gt operates on the Fourier result only 1 reverse direction of gt gt gt 1 2 3 logic applied to all phase outputs Line CT ratio PWP Line VT ratio PWP Selectable time characteristic PWP Current threshold for selected characteristic Time time multiplier setting Hold up time for timing integration Second current threshold Time delay for second threshold Third current threshold Time delay for third threshold Characteristic angle for directional
101. 2 P T o 2 cc 19 c e 0 Dx 52 epos lt lt di A ddng xq Aiddns T ose uonejo1 oseuq Y Page 165 991 93eq WD 6 gt Relay failed WD gt Relay healthy 2 1 B 52 51 AC DC me T 14 E mE iMacs Supply to trip coil pply to trip t i D Phase rotation 21 e Case earth 122 23 C 1 29 304 Tu 27 3 gt 13 4 Pu 325 e e e 24 15 61 1 33 34 1 25 o 17 81 1235 36 1 T TG e co eo 19 101 1237 38 1 2 1 e e 26 494 27 13 1141 421 25 gt e 43 44 1 Te 17 18 oe 28 gt 1145 4641 46 19 201 9 e e e 6 o7 BA fe 5701 148 KCGG 230 23 24 5 52 1 Ll lt uq 1 50 Pss seq 27 E 28 e 152 x SCNGO Logic input common 1 145 Module terminal blocks 13 viewed from rear with integral case earth link 47 14 F Notes 149 1 gt Ge CT shorting links make LS before b disconnect 51 b e gt Short
102. 21807 UH y 8 18 PIMA euo PPY 87 C1 42014 eururmo o hpo A L GDNOS UI 9 af e _ foc 01 rc 7 yod suonvorunuruioo snq X 7 991 DE 15 D i Ta tcc Tel vs 17 gt c 10 6u 1299 e gt ce 1 yuo OTT NADA g ps c 8c QU ee af oS oe BG P A Mm eae ol 12 De i p RH 9 lt E gt 57 cn ST OF 6c yc eo ose Ie lt j 9 c a 4 ce yp Lx 1018301 5 Ic g 2 oe ge e rn poney Avjoy lt 16 gt 216 xA ddns 7 3 epy lt 9 D e M e Loe I _ 2 d a _ 2 gt _ MOJ VULIN JO Page 181 9 oAnrsues pue eseud c peordAT 798 e 21807
103. 3 Auxiliary timers 1 Aux2 Aux3 6 1 10 4 Breaker fail and backtripping 6 1 10 5 Change of setting group 6 1 10 6 Cold load start pickup 6 1 10 7 Circuit breaker control 6 1 10 8 Table 6 4 Selective logic features listed below require K Bus remote commands and are not covered by the commissioning instructions Remote setting change Remote group change Remote circuit breaker control Remote load shedding control Equipment required For KCGG and KCGU relays the following equipment is required Overcurrent test set with time interval meter Multifinger test plug type for use with test block type MMLG Continuity tester Page 101 6 1 3 6 1 3 1 For and KCEU relays the following additional equipment is required 440 110V star star phase shifting transformer AC voltmeter 0 440V DC voltmeter 0 250V AC multi range ammeter Suitable non inductive potentiometer to adjust polarizing voltage level Phase angle meter or transducer If necessary suitable current shunt s for use with the phase angle meter For KCEG160 and KCEU160 only Resistor for controlling the polarizing current signal Additional multi range ammeter for the polarizing current 110 3V step down transformer for use with the phase shifter to obtain the polarizing current source only necessary if the phase shifter cannot provide sufficient current directly A portable PC with suitable software and KITZ101 K Bus IE
104. 3 5 inch Page 66 3 7 2 4 MS DOS 3 2 or later IBM PC DOS 3 2 or later Parallel printer port for optional printer Additional equipment Printer RS 232 link KITZ 101 K Bus RS232 communication interface Modem Modem requirements AREVA T amp D has adapted the IEC60870 5 ft1 2 frame format for transmitting the Courier communication language over RS 232 based systems which includes transmission over modems The IEC60870 5 ft1 2 specification calls for an 11 bit frame format consisting of 1 start bit 8 data bits 1 even parity bit and 1 stop bit However most modems cannot support this 11 bit frame format so a relaxed 10 bit frame format is supported by the Protection Access Software amp Toolkit and by the KITZ consisting of 1 start bit 8 data bits no parity and 1 stop bit Although Courier and IEC60870 both have inherent error detection the parity checking on each individual character in the 11 bit frame provides additional security and is a requirement of IEC60870 in order to meet the error rate levels it guarantees It is therefore recommended that modems should be used which support these 11 bit frames The following modems have been evaluated for use with the full IEC60870 ft1 2 protocol and are recommended for use Dowty Quattro SB2422 Motorola Codex 3265 or 3265 Fast Other modems may be used provided that the following features are available refer to the modem documentation for details on setting the
105. 3 Setting the display to Fnow which will be found in the fault record column Note The default display can be set to Fnow if preferred If the display is Fnow the current state of the flags a letter is displayed to indicate which phase has started and an will indicate which element has tripped See Section 3 1 5 for more information on the flag display Inject single phase current into the earth fault current input of the relay terminals 27 and 28 and slowly increase the current noting the pick up value at which the START relay operates Reduce the current slowly and note the drop off value at which the START relay resets Check the pick up and drop off current is within the range shown in Table 6 12 Current level Pick up 0 95 x Is 1 05 x Is Drop off 0 9 x pick up 1 0 x pick up Table 6 12 Time characteristic for to The relay selected for the to trip can be found under the RELAY MASKS heading in RLY to The terminals for each relay are shown in the application diagram Connect the relay contacts for the to trip to both trip the test set and to stop a timer Inject single phase current into the earth fault current input terminals 27 and 28 at 2 x setting current If the test set used can inject sufficient current repeat the test again at 10 x setting current Check that the operating time for the relay is within the range shown in the table below Page 107 6 1 6 4
106. 32 0 034 0 027 0 024 0 022 0 021 0 021 0 021 0 333 0 220 0 091 0 037 0 026 0 022 0 021 Polarizing current circuit In 5A In 5A Polarizing current Reference voltage circuit Polarizing voltage Auxiliary voltage Earth 2 4 2 9 2 0 1 9 1 9 1 9 1 7 27 3 11 3 5 2 2 6 2 0 1 8 1 6 0 106 0 088 0 078 0 072 0 071 0 069 0 062 1 082 0 454 0 207 0 103 0 078 0 073 0 070 Earth 0 08 0 008 SEF 2 6 202 2 0 1 8 1 7 1 7 1 5 29 9 12 4 5 6 2 6 2 0 1 8 1 6 0 108 0 089 0 079 0 071 0 068 0 066 0 064 1 219 0 500 0 225 0 101 0 077 0 071 0 066 SEF 0 18 0 012 0 02 VA at 110V 0 15 VA at 327V ohms at 0 5 In for Vx 110V ohms at In for Vx 110V ohms at 2 In for Vx 110V ohms at 5 In for Vx 110V ohms at 10 In for Vx 110V ohms at 20 In for Vx 110V ohms at 30 In for Vx 110V ohms at 0 5 In for Vx 0V ohms at In for Vx 0V ohms at 2 In for Vx 0V ohms at 5 In for Vx 0V ohms at 10 In for Vx 0V ohms at 20 In for Vx 0V ohms at 30 In for Vx ohms at 0 5 In for Vx 110V ohms at In for Vx 110V ohms at 2 In for Vx 110V ohms at 5 In for Vx 110V ohms at 10 In for Vx 110V ohms at 20 In for Vx 110V ohms at 30 In for Vx 110V ohms at 0 5 In for Vx ohms at In for Vx ohms at 2 In for Vx ohms at 5 In for Vx ohms at 10 In for Vx ohms at 20 In for Vx ohms at 30 In for Vx ohms
107. 37 shows which EARTH FAULT function links must be set to 1 to enable directional control of each of the earth fault elements Earth fault element Earth fault function link gt gt 1 gt gt gt 2 Dirn to gt 3 Dirn to gt gt 4 Dirn to gt gt gt 5 Table 6 37 To test the Wattmetric element the following settings should be applied to the relay Po 30W 5Amp relay 6W 1 Amp relay EF1 Char angle 0 to gt Os tREST Os Power setting for Po gt Apply 60V to terminals 18 and 20 with the neutral being connected to 20 Inject a current of 450mA 5 relay or 90mA relay and gradually increase until the relay operates Operation should occur in the region of 500mA relay 100mA relay The value of operate current should be noted The relay fault flags will show operation of the earth element N in group 1 The above test to prove operation of the wattmetric element relies on the injected current being in phase with the applied voltage Alternatively the required operating current can be calculated from the following formula Po Vox Io x Cos Wc Where zero sequence power threshold Vo residual voltage 3 x zero sequence volts Io residual current 0 Phase angle between applied volts and current Relay characteristic angle Page 130 6 2 6 2 1 6 2 2 6 2 2 1 6 2 2 2 6 2 2 3 Reverse the polarity of the 60V voltage sup
108. 4 This arrangement will also trip the circuit breaker when the auxiliary trip supply is lost If the circuit breaker is fitted with a line VT then this may be used to provide the trip supply for the circuit breaker and the circuit breaker will then be tripped when the protected circuit is de energized Page 56 3 6 6 3 The capacitor is included to reduce the release time and tune the coil to the power frequency The series resistor then limits the current in the coil to its rated value Figure 24 AC no volt trip arrangement Capacitor discharge trip Dual powered relays may use either of the above methods In addition these particular relays charge an internal capacitor from the current circuit and also from the auxiliary voltage circuit Figure 25 This capacitor 15 680UF and it is charged to 50V dc It may be discharged directly into a suitably sensitive trip coil via one of the programmable output relays The minimum energy fed to the trip coil is that from the capacitor but in most cases it will be supplemented by a current from the auxiliary voltage circuit and or the current circuit When energized from current alone the lowest current for which the relay will operate will be that necessary to start up the power supply To be able to use lower fault settings an auxiliary supply will be required see Technical Data Section 5 The capacitance discharge circuit is not isolated from the auxiliary supply and to
109. 4 tTRIP 3 CB CONTROL RLY CB Close CLOSE CB tCLOSE INP_CB Closed CB Open TO PLANT STATUS is WORD CB STATUS T Figure 61 Logic diagram three phase directional overcurrent relay Type KCEG 130 Page 154 INP BIk to d amp to gt ps RLY to O10 lo gt FWD EF3 RLY lo Fwd REV RLY lo Rev gt gt 4 amp H to 000 O00 T RLY to gt gt 4 O10 O10 lo gt gt Vop gt FWD EF INP_Bik_to gt gt gt 55 4 Ac 4to gt gt gt I FU RLY to _ ape O 655 gt Vop tV 2 EFS INP BIk t 4 amp o I T O00 1 RLY t 1 010 _ 0 00 1 gt Vp FWD o10 Z5 H PFF 1064 wd 0 0 4 000 5 oio 79191 23 REV RLY I Rev 000 EI 2 O10 PFF INP gt gt 4 amp gt gt 1 RLY gt gt gt
110. 40 and KCEU 140 Sheet 2 Page 156 T INP Blk to x amp to gt gt RLY to T lo 55 gt FWD o1 RLY lo Fwd hH REV RLY lo Rev INP BIk to H z 4 EARTH GROUND amp H to gt gt 4 FAULT SETTINGS RLY to 1 lo Vop gt Po gt FWD H INP BIk to amp H to gt gt gt 4 000 O 0 O F T RLY to gt gt gt s lo Vop Po FWD iot y 4 INP Blk t E BL t gt 4 O 0 O T RLY t 010 H 4 LED E PH3 RLY I gt Fwd H REV RLY I Rev INP BIk t H amp H e 4 000 T RLY gt gt
111. 5 YELLOW LED Indicates alarm conditions that have been detected by the relay during its self checking routine The alarm lamp flashes when the password is entered password inhibition temporarily overridden RED LED Indicates a trip that has been issued by the relay This may be a protection trip or result from a remote trip command the trip flags have to be viewed to decide which Keypad Four keys on the frontplate of the relay enable the user to select the data to be displayed and settings to be changed The keys perform the following functions F FUNCTION SELECT KEY INCREMENT VALUE KEY DECREMENT VALUE KEY 0 RESET ESCAPE KEY Note Only the F and 0 keys are accessible when the relay cover is in place Liquid crystal display The liquid crystal display LCD has two lines each of sixteen characters that are used to display settings measured values and records which are extracted from the relay data bank A backlight is activated when any of the keys on the frontplate of the relay is momentarily pressed This enables the display to be read in all conditions of ambient lighting The numbers printed on the frontplate just below the display identify the individual digits that are displayed for some of the settings ie function links relay masks etc Flag display format Fault ta gt gt gt tb gt gt gt record Setting ta gt gt tb gt gt number group ta gt tb gt tV lt Ia Ib
112. 5 36 Output Relay 6 37 38 Output Relay 2 39 40 Output Relay 7 41 42 Output Relay 3 43 44 Opto Control Input L3 45 46 Opto Control Input LO Opto Control Input L4 47 48 Opto Control Input L1 Opto Control Input 5 49 50 Opto Control Input L2 Opto Control Input L6 51 52 Common LO L1 L2 Opto Control Input L7 53 54 K BUS Serial Port Common L3 L4 L5 L6 L7 55 56 K BUS Serial Port Key to connection tables and indicate the polarity of the dc output from these terminals and indicate the polarity for the applied supply In Out Note the signal direction for forward operation All relays have standard Midos terminal blocks to which connections can be made with either 4mm screws or 4 8mm pre insulated snap on connectors Two connections can be made to each terminal Page 52 3 6 1 3 6 2 3 6 3 Auxiliary supply The auxiliary voltage may be ac or dc provided it is within the limiting voltages for the particular relay The voltage range will be found on the frontplate of the relay itis marked Vx 24V 125V or 48V 250V An ideal supply to use for testing the relays will be 50 dc or 110V ac because these values fall within both of the auxiliary voltage ranges The supply should be connected to terminals 13 and 14 only To avoid any confusion it is recommended that the polarity of any applied voltage is kept to the Midos
113. 67 27 28 SCNGD Module terminal blocks viewed from rear with integral case earth link Notes 1 exco Gs CT shorting links make before b and c disconnect b e gt Long terminal Short terminals break before c d Pin terminal pcb type 2 CT connections are typical only 3 Earth connections are typical only AC DC supply Vx TUA Logic input common Logic input common 150 46 47 49 51 Fh 22022 AR N lo 3X ON e e 4 2 4 0 gt JJ RL2 fw lola Is e e EN 5 RL3 L RLS gt gt Li RL7 A wo 1 C i Case earth connection 54 56 7 8 2 T J k LS Ja X gt gt Relay healthy gt Relay failed K bus communications port 48V field voltage Figure 78 Typical application diagram 3 phase overcurrent and directional earth fault relay Type KCEG 150 091 0804 odd yeo wesserp eordA 6
114. B Input to initiate tAUX1 Input to initiate tAUX2 Input to initiate tAUX3 Input to change to setting group 2 Input to indicate circuit breaker open Input to indicate circuit breaker closed Input to circuit breaker connected to bus 2 Input to initiate CB trip pulse timer Input to initiate CB close pulse timer Relay to be operated by Io FWD Io gt START Relay to be operated by lo gt REV Relay to be operated by to gt Relay to be operated by to gt gt Relay to be operated by to gt gt gt Relay to be operated by I gt FWD I gt START Relay to be operated by I gt REV Relay to be operated by t gt Relay to be operated by t gt gt Relay to be operated by t gt gt gt Relay to be operated by tV lt Relay to be operated by Aux Relay to be operated by Aux2 Relay to be operated by Aux3 Relay to cause stage 1 voltage reduction Relay to cause stage 2 voltage reduction Relay to cause stage 3 voltage reduction Relay to provide remote trip of circuit breaker Relay to provide remote close of circuit breaker RUNNING TRIGGERED STOPPED SET SAMPLES MAGNITUDE PHASE SET Trace length after trigger SET Select relay output to trigger SET Settings and text in certain cells of the menu can be changed via the user interface To do this the cover must be removed from the front of the relay to gain access to the and keys Give the key a momentary press to change from the selected default display and switch on the ba
115. C60870 5 interface unit will be useful but in no way essential to commissioning Auxiliary supply tests Auxiliary powered relays 1007 6 1 3 1 1 Auxiliary supply The relay can be operated from either an ac or a dc auxiliary supply but the incoming voltage must be within the operating range specified in Table 6 5 Relay rating V DC operating AC operating Maximum crest range V range VAC voltage V 24 125 19 150 50 133 190 48 250 33 300 87 265 380 Table 6 5 CAUTION The relay can withstand some ac ripple on a dc auxiliary supply However in all cases the peak value of the auxiliary supply must not exceed the maximum crest voltage Do not energize the relay using the battery charger with the battery disconnected 6 1 3 1 2 Energization from auxiliary voltage supply For secondary injection testing using the test block type MMLG insert test plug type MMLBOI with CT shorting links fitted It may be necessary to link across the front of the test plug to restore the auxiliary supply to the relay Isolate the relay trip contacts and insert the module With the auxiliary disconnected from the relay use a continuity tester to monitor the state of the watchdog contacts as listed in Table 6 6 Connect the auxiliary supply to the relay The relay should power up with the LCD showing the default display and the centre green LED being illuminated this indicates the relay is healthy The relay has a
116. EMENT 2 and the FAULT RECORDS columns Local testing When testing locally similar tests may be carried out to check for correct functioning of the relay Page 136 6 3 2 1 6 3 2 2 6 3 2 3 6 3 2 4 6 3 2 5 6 3 3 6 3 3 1 Alarms The alarm status LED should first be checked to identify if any alarm conditions exist The alarm records can then be read to identify the nature of any alarm that may exist Measurement accuracy The values measured by the relay can be checked against own values injected into the relay via the test block if fitted or injected directly into the relay terminals Suitable test methods will be found in Section 6 1 of this manual which deals with commissioning These tests will prove the calibration accuracy is being maintained Trip test If the relay is configured to provide a trip test via its user interface then this should be performed to test the output trip relays If the relay is configured for remote control of the circuit breaker the trip test will initiate the remote CB trip relay and not the main trip relay that the protection uses In which case the main trip relay should be tested by injecting a current above the protection setting so that operation occurs If an output relay is found to have failed an alternative relay can be reallocated until such time as a replacement can be fitted See Section 3 3 8 for how to set relay masks CB maintenance Maintenance records
117. EVERSE START Page 33 3 4 1 3 3 4 1 4 functions are provided for the respective phase and earth fault elements A non directional START indication can be obtained if both the FORWARD START and REVERSE START functions are directed to the same output relay This relay will then operate when the current threshold is exceeded regardless of the direction of current flow However if none of the three elements is directionalized then the FORWARD START becomes non directional regardless of polarizing signal and the REVERSE START becomes inoperative Undercurrent function The undercurrent elements 1 lt 0 lt shown in Figure 6 respond only to the instantaneous value of the waveform and require the peak value of at least one half cycle to be below the set threshold to indicate an undercurrent condition thus giving the fast response necessary for the breaker fail applications However before an output is given an undercurrent condition has to be detected by all the undercurrent elements in the relay the three phase elements and earth element An undercurrent condition is assumed not to exist when both the positive and negative peaks of the waveform on any one phase exceed the threshold I lt or Io lt The requirement for both peaks to exceed the threshold reduces over reach that would be caused by the exponential component of current This element has no software filtering and will be responsive to harmonics but the higher frequencies wi
118. Figure 62a Logic diagram three phase directional overcurrent and earth fault relays Types KCEG 140 and KCEU 140 Sheet 1 Page 155 t 3 Sec Delay 08 06 23 Aux3 gt 1 QT0 O00 DISTURBANCE ____ Recorder RECORDER 52 Stopped AUXILIARY 4 6958 TMERS 1009 i RLY Auxi 1065 3 T OrLO ALL SD8 S Recorder Stopped r INP Grp2 4 EDS SELECT LOGIC AND SYSTEM CHANGE 010 000 ALTERNATIVE STG GP 3 _ 065 SETTING GP2 DATA SETTINGS REMOTE CHANGE 1 RESET REMOTE CHANGE 2 SET LOAD GLOBAL LOAD SHED LOAD SHED LOGIC SHEDDING ARE RESTORE Close CB 9 4 INP L Trip CB ______ 502 RLY CB Tri TRIP CB tTRIP CONTROL lt RLY Close CLOSE CB tCLOSE J s INP CB Closed CB Open TO PLANT STATUS INE 15 WORD CB STATUS Figure 62b Logic diagram three phase directional overcurrent and earth fault relays Types KCEG 1
119. IATE oct Tm pi BF I lt LOG2 O10 lo lt Js FAIL lt LOG2 Aux1 RLY Aux 4 4 O 0 Om X 152204 tAUX1 Aux2 9 RLY Aux2 _______ T 4 4 y PF7 lt aum 0 10 SF tAUX2 1 AUXILIARY EF7 lo TIMERS 9 Z Bao E 3 Sec Delay SD8 06 O0 F RESET Aux3 gt 1 010 010 DISTURBANCE ux Recorder RECORDER Stopped 068 195 010 LOGY RLY Aux3 LOGS lt 0 O ANY gt tAUX3 4 0 10 O10 ALL 1 999 08 LOGIC AND SYSTEM 010 DATA SETTINGS Stopped INP 5 2 Lort 503 SELECT CHANGE 9 0 000 ALTERNATIVE STG GP 1065 SETTING GP2 REMOTE CHANGE 1 RESET LOAD _ toe GLOBAL LOAD SHED LOAD SHED LOGIC SHEDDING tRESTORE INPL Close CB RIE CLOSE NP L Trip CB RLY CB Tri SD2 ri 0 1 el TRIP CB 4 tTRIP po RLY CB Close CLOSE CB tCLOSE INP_CB Closed 4 CB Open TO PLANT STATUS 1 INP_CB to 2 WORD STATUS Figure 64 Logic diagram three phase overcurrent and directional earth fault relays Types KCEG 150 and KCEU 150 Page 158
120. OL 6 INP 29 2 sp4 4 1010 4 y 990 SD3 SELECT Ip 9 O 000 ALTERNATIVE LO oio SETTING GP2 REMOTE CHANGE 1 RESET RLY V Reduct 1 REMOTE CHANGE 2 LOAD SHED LEVEL 1 RLY V Reduct 2 4 LOAD SHED LEVEL 2 RLY V Reduct 3 LOAD SHED LEVEL 3 01 010 GLOBAL LOAD SHED LOAD SHED LOGIC P ooo TRIP CLOSE tRESTORE L CB SD2 RLY CB Trip toro TRIP 4 tTRIP lt RLY CB Close CLOSE CB 4 icLose INP_CB Closed INP Open TO PLANT STATUS T BEEN WORD CB STATUS LOGIC AND SYSTEM DATA SETTINGS Figure 59b Logic diagram three phase overcurrent and earth fault relays Types KCGG 140 and KCGU 140 Sheet 2 Page 152 COLD LOAD 4 START CB FAIL lt AUXILIARY TIMERS CHANGE STG GP LOAD SHEDDING CB CONTROL
121. OUP LOG tRESTORE LOG Default Dsply Input masks INP Fn Links INP BIk to INP to gt gt INP Blk to gt gt gt INP Blk t gt INP gt gt INP gt gt gt INP CB Open CLP INP 1 INP Aux2 INP Aux3 INP Set Grp 2 INP CB Opened INP CB Closed INP Bus Posn 2 INP LTrip CB gt gt gt gt gt gt INP LClose CB Oo D gt Page 192 Relay masks RLY In Links RLY gt Fwd RLY gt Rev RLY to gt RLY to gt gt RLY to gt gt gt RLY I gt Fwd RLY I gt Rev RLY t gt RLY t gt gt RLY t gt gt gt RLY tV lt RLY Aux RLY Aux2 RLY Aux3 RLY V Reductl RLY V Reduct2 RLY V Reduct3 RLY CB Close RLY CB Trip gt gt gt gt
122. Test connections Connect the auxiliary supply to the relay and record the voltage at terminals 13 ve and 14 ve Ensure that the line CTs are short circuited and disconnected from the relay If any of the phase elements are directionalized refer to Section 6 1 9 for the test instructions Current sensitivity for I gt This test checks the current sensitivity of the relay Operation of the relay can be monitored in three ways 1 By indication from the relay contacts 2 Viewing the SYS Relay Stat display under the SYSTEM DATA heading of the menu 3 Setting the display to Fnow which will be found in the fault record column Note The default display can be set to Fnow if preferred Page 109 6 1 7 3 If Fnow the current state of the flags is displayed indication that a phase has picked up is given by a letter and an will indicate which element has tripped See Section 3 1 5 for more information on the flag display Where there is a star point on the relay it is advantageous to inhibit the operation of the earth fault elements inhibit to gt to gt gt and to gt gt gt in order to avoid confusion with trip signals and indications Inject single phase current into one of the phase inputs to the relay and slowly increase the current noting the pick up value at which the START relay operates Reduce the current slowly and note the drop off value at which the START relay resets Check the pick up and drop of
123. US Serial Port Common L3 L4 L5 L6 L7 55 56 K BUS Serial Port Key to connection tables and indicate the polarity of the dc output from these terminals and indicate the polarity for the applied supply In Out the signal direction for forward operation This area is not available on single phase relays Not available on two pole overcurrent relays Note All relays have standard Midos terminal blocks to which connections can be made with either 4mm screws or 4 8mm pre insulated snap on connectors Two connections can be made to each terminal Page 51 Connection table for dual polarised relays Function Terminal Function Earth Terminal 1 2 Not Used Watchdog Relay b 3 4 m Break contact 5 6 Make contact 48V Field Voltage 7 8 48V Field Voltage Capacitor Trip Voltage 9 10 Capacitor Trip Voltage Not Used 11 12 Not Used Auxiliary Voltage Input 13 14 Auxiliary Voltage Input Not Used 15 16 Not Used Not used 17 18 Not Used Zero Sequence Voltage In 19 20 Out Zero Sequence Voltage Not Used 21 22 Not Used Not Used 23 24 Not Used Polarizing Current In 25 26 Out Polarizing Current CT Neutral Current In 27 28 Out CT Neutral Current Output Relay 4 29 30 Output Relay 0 31 32 Output Relay 5 33 34 Output Relay 1 3
124. XDT Extremely inverse characteristic goes definite time after 10 15 LTBOXDT Long time earth fault characteristic goes definite time after 30xIs DT Definite time characteristic The characteristics of the relay can be further changed by setting function links as described in Section 3 4 1 These links change the logic within the relay so that the auxiliary functions can be used for alternative tasks They can also turn OFF or block some of the unwanted functions and so this is the first place to look if the relay is not configured as required SYSTEM DATA SYS Fn Links EARTH FAULT 1 1 Fn Links PHASE FAULT 1 PF1 Fn Links EARTH FAULT 2 EF2 Fn Links PHASE FAULT 2 PF2 Fn Links LOGIC FUNCTIONS LOG Fn Links INPUT MASKS An eight bit mask is allocated to each protection and control function that can be influenced by an external input applied to one or more opto isolated inputs Page 105 RELAY MASK An eight bit mask is allocated to each protection and control function that can operate one or more outputs It is necessary to enter the password before the functions link time curve masks VT and CT ratios can be changed For each protection and control function input required at least one opto input must be allocated in the INPUT MASK menu For each protection and control function output required at least one output relay must be allocated in the RELAY MASK menu When the relay leaves the factory it is configured with a set o
125. ail function can be directed to one of the output relays so that in the event of the local circuit breaker failing to trip the trip signal can be re routed directly to the upstream circuit breaker The same backtrip relay can be energized by an external input via one of the auxiliary timers this timer being set to the required breaker fail delay In each case the backtrip relay and breaker fail timers will be reset by a current check element Alternative setting group An alternative group of settings is provided for both the phase and earth fault protection functions The alternative settings can be selected at any time either by energizing an opto isolated control input assigned to this function or by a remote command via the serial communication port of the relay A decision has to be made during commissioning as to which method is to be used to select the alternative setting group It is not possible to select by both local and remote control at the same time Change of setting group control When link SD4 is set to 0 only the settings for one of the setting groups will be displayed the other group will be inactive and hidden To activate the second group of phase fault and earth fault settings link SD4 must be set to 1 The second group of settings will then appear in the menu and can be set in the usual way Group settings are normally in use and switching to the group 2 settings requires either a remote command to be recei
126. aker failure protection Models A amp B Relay RLY3 is designated for the trip functions as will be explained in Section 3 4 13 When link 001 is set to 1 a command to operate RLY3 via any output mask will also initiate the breaker fail time delay within the relay If the circuit breaker fails to trip within the set time tBF the start relays are reset to remove any block which they may be asserting on an upstream relay The circuit breaker fail time delay tBF can also be arranged to produce a back trip so that the trip can be transferred directly to the next circuit breaker back in the system To achieve this Link LOG2 has to be set to 1 and an output relay allocated via the RLY Aux 1 output mask for backtrip The RLY Aux 1 input mask can be used to assign one of the control inputs to initiate the time delay tAUX1 By this means an externally initiated breaker fail function can be set up Time delay taux1 will be set to the required circuit breaker fail time setting and a backtrip output will be given via the RLY Aux1 output mask The backtrip output and the breaker fail timers are checked by the undercurrent element to ensure fast reset INP Blk t RLY t RLY I Start LOGI Relay 3 operated O io ir 10 LOG2 O10 Figure 13a Breaker fail protection Breaker fail protection Models C and onwards Relay RLY3 is designated for the trip functions as
127. al connection arrangement CO 65 T A LL Issue Rating Case details Mechanical assembly Relay Type Page 93 1 L 0 First Version 1 Single pole E F 2 Two pole Ph F 3 Three pole Ph F 4 Three pole Ph F E F 5 Three pole Ph F DEF only used for KCEG KCEU 6 Dual Polarized E F only used for KCEG KCEU 1 Auxiliary Powered V 2 Dual Powered V amp I G General application U Sensitive E F E Directional G Overcurrent C Current measured quantity Range Midos 01 Standard configuration CS L Back connected flush mounting standard mounting May be used as an additional digit for configuration later D Midos case size 4 Midos case size 6 H Midos case size 8 RTG L E Standard English text Vnz0V Inz 0A C Vnz0V Inz 50 60Hz E Vnz0V In 5A 50 60Hz Vnz0V In 5A equal PF and EF sensitivity 50 60Hz 0 In SA PF IA EF 50 60Hz J 57 120 0A L 57 120 1 50 60Hz Vn 57 120V In 5A 50 60Hz 57 120 In 5A equal PF and EF settings 50 60Hz 57 120 5A PP 1A EF 50 60Hz 2 24 125 ac dc Auxiliary powered version 5 48 250V ac dc Auxiliary powered version 9 100 250 ac dc Dual powered version Note Initia
128. apacitance to earth an angle setting of 45 lead is recommended For earth faults the minimum operating value of the residual voltage input to the directional earth fault relay is determined by power system imbalance and voltage transformer errors The zero sequence voltage on a healthy distribution system can be as high as 1 0 also the voltage transformer error can be 1 0 per phase which results in a possible spurious residual voltage as high as 2 0 under healthy conditions In order to take account of both of the foregoing quantities and thus eliminate unwanted relay operation it is necessary to introduce a minimum operating value of up to 3 5 In practice a choice of settings of say 2 0 to 4 0 should be considered with perhaps 10 and 20 for high resistance and insulated neutral systems respectively The setting for Vop gt will be found in the EARTH FAULT setting column of the menu and should be set appropriately taking the above notes into account Note The KCEG 140 requires a residual voltage in excess of 6 4V before the voltage threshhold circuit will function regardless of the Vop gt setting If this is considered to be a problem in a particular application then a KCEG 110 should be used for the earth fault protection and a KCEG 130 for the overcurrent protection Application of dual polarized earth fault relays When the zero sequence voltage under fault conditions is likely to be very small it may be advisable to use c
129. application of the KCEU141 241 is further described in a separate application note The conditions for operation of the wattmetric directional elements are 1 The earth fault current exceeds the current setting Io gt 2 The residual voltage exceeds the voltage setting Vop gt 3 Zero sequence power exceeds Po gt 4 The phase angle 0 between the fault current and the polarising voltage is such that the fault current lies in the forward zone 3 90 about the characteristic angle The relay characteristic angle c may be set between 180 and 180 With this wide range of adjustment the directionality of the relay can be reversed Setting the wattmetric power threshold Po to zero disables this characteristic and the element reverts to the standard directional characteristic When set the wattmetric power characteristic affects the directional control signal of all earth elements Io Io gt gt gt Io start Dual polarized earth fault relays The dual polarized relays have the addition of a polarizing current threshold in parallel with the polarizing voltage threshold and at least one of these thresholds must be exceeded before a directionalized output can be given INP Blk to RLY to RLY Io Rev Start Figure 10 Dual polarised earth fault logic Page 37 3 4 4 3 4 4 1 3 4 4 2 3 4 5 3 4 5 1 Undervoltage function and logic Undervoltage funct
130. ard start contacts have closed Rotate the phase shifting transformer into the lead quadrant on the phase angle meter and continue until the forward start contacts open and the reverse start contacts close Note the angle on the phase angle meter and check it is within the limits stated in Table 6 27 Reverse rotation and slowly wind the phase shifting transformer until the forward start contacts open and the reverse start contacts close Note the angle on the phase meter and check it is within the limits stated in Table 6 27 Relay in operate region Phase angle meter indication Tolerance 90 lag through to 90 lead 5 Table 6 27 Directional phase fault element The relay should be commissioned with the settings calculated for the application For dual powered relays it is recommended that the relay is energized from an auxiliary voltage supply as this will reduce the burden imposed by the relay on the current injection test set Ensure that the main system current transformers are short circuited before isolating them from the relay in preparation for secondary injection tests Also isolate the relay trip contacts To test the directional phase fault element it is necessary to set some function links to directionalize the phase fault overcurrent elements Table 6 28 shows which PHASE FAULT function links must be set to 1 to enable directional control of each of the phase fault elements
131. are displayed They are displayed automatically after a trip occurs or can be selected in the fault record column The reset is effected by depressing the 0 key for 1 second Resetting the fault records as described in 3 3 9 will also reset the TRIP LED indication Set function link SD5 to 1 for automatic reset of trip LED Alarm records The alarm flags are towards the end of the SYSTEM DATA column of the menu and consist of six characters that may be either 1 or 0 to indicate the set and reset states of the alarm The control keys perform for this menu cell in the same way as they do for Function Links The cell is selected with the function key F and the relay then put in the setting mode by pressing the key to display the cursor The cursor will then be stepped through the alarm word from left to right with each press of the F key and text identifying the alarm bit selected will be displayed Page 30 3 3 12 3 4 000000 Unconfig protection not operational needs to be configured 1 Uncalib protection is running uncalibrated calibration error Setting protection is running possible setting error No Service protection is out of service No Samples relay not sampling but not out of service No Fourier relay not performing Fourier on the data but not out of service For the above listed alarms the ALARM LED will be continuously lit However there is another form of a
132. arge in air with cover in place IEC60801 2 1991 Level 2 4 0kV point contact discharge with cover removed No additional tolerances are required for the operating time or the unit s thresholds Fast transient disturbance IEC60255 22 4 1992 Class IV 4 0kV 2 5kHz applied directly to auxiliary supply and watchdog relay IEC60801 4 1988 Level 3 2 0kV 5kHz applied directly to all inputs No additional tolerances are required for the operating time or the unit s thresholds Radio frequency interference EMC Compliance 89 336 EEC Compliance with the European Commission Directive on 50081 2 1994 EMC is claimed via the Technical Construction File route EN50082 2 1995 Generic standards were used to establish conformity Atmospheric Environment Temperature IEC60255 6 1988 Storage and transit 25 C to 70 Operating 25 C to 55 IEC60068 2 1 1990 IEC60068 2 1 1974 Dry Heat Humidity IEC60068 2 3 1969 56 days at 9396 relative humidity and 40 C Enclosure protection IEC60529 1989 IP50 Dust protected Page 92 5 17 5 17 1 5 17 2 5 17 3 5 18 Mechanical Environment Vibration IEC60255 21 1 1988 Response Class 1 Endurance Class 1 Shock and bump IEC60255 21 2 1988 Shock response Class 1 Shock withstand Class 1 Bump Class 1 Seismic 60255 21 3 1993 Class 1 Model numbers Configuration ie settings as supplied and connection diagram Sheet No varies with extern
133. arization the relay tracks the frequency on a current signal so that the phase correction is kept as close as possible even with some deviation in frequency Section 6 COMMISSIONING 6 1 6 1 1 Commissioning preliminaries When commissioning a K Range relay for the first time the engineers should allow an hour to get familiar with the menu Please read Section 6 1 1 1 which provides simple instructions for negotiating the relay menu using the push buttons F and 0 on the front of the relay Individual cells can be viewed and the settable values can be changed by this method If a portable PC is available together with a K Bus interface unit and the courier access software then the menu can be viewed a page at a time to display a full column of data and text Settings are also more easily entered and the final settings can be saved to a file on a disk for future reference or printing a permanent record The instructions are provided with the Courier Access software Quick guide to local menu control With the cover in place only the F and 0 push buttons are accessible so data can only be read or flag and counter functions reset No protection or configuration settings can be changed In the table F long indicates that the key is pressed for 1s and F short for less than 0 5s This allows the same key to perform more than one function Page 97 6 1 1 1 6 1 1 2 With the cover fitted to the case
134. articular application then a KCEG 110 should be used for the earth fault protection and a KCEG 130 for the overcurrent protection Additional settings for the KCEU141 241 Voltage threshold Vop gt 0 6 22V Characteristic angle Oc 180 0 180 Po 1A 0 20W 50mW steps Po 5A 0 100W 250mW steps Ratios CT ratios 9999 1 Default 1 1 VT ratios 9999 1 Default 1 1 Accuracy Reference conditions Ambient temperature 20 C Frequency 50Hz or 60Hz whichever is set Time multiplier setting 1 0 Auxiliary voltage 24V to 125V aux powered 48 to 250V aux powered 100V to 250V dual powered Fault Position Within 80 of the RCA where appropriate Current Undercurrent Minimum operation 10 gt 4 x minimum setting 20 lt 4 x minimum setting Page 86 Overcurrent Minimum operation 5 Reset 5 Repeatability 2 5 5 7 3 Time delays Reference range Operating time ST SI IN VL LT 5 20 40 5 215 to 3015 t gt to gt Extremely inv EI 7 5 20 to 40 ms 2Is to 2015 Definite time 30 596 20 to 40 ms 3Is to 3015 Operating time Definite time 0 5 10 to 45 ms 315 to 3015 t gt gt t gt gt gt to gt gt to gt gt gt Repeatabiltiy Inverse time 2 40ms Definite time 0 5 or 10ms Overshoot time Less than 50ms when current reduced to zero Reset time t gt to gt Definite time 1 505 Disengagement I lt typically 35ms gt gt typically 30ms t to
135. arting The cold load pick up feature may be used to assist in grading overcurrent relays with motor starting currents by lifting the curves above the motor starting characteristic In the example shown in Figure 35 the motor starting current encroaches into the operation zone of the overload characteristic provided by t gt to gt If this setting is increased by the cold load feature it will allow the motor to start and then return the protection settings to more appropriate values It is not suggested that this arrangement will eliminate the need for motor protection because it does not model the thermal characteristics of the motor However it can provide some basic overcurrent protection Time Alternat VE current Energizing current Current Figure 35 Energizing currents Sensitivity to transformer inrush currents Either the I gt gt Io gt gt elements or the I gt gt gt Io gt gt gt elements may be used as high set instantaneous elements The design is such that they will not respond to the transient component of the fault current and so may be set closer to motor starting current level The principles used should allow the instantaneous elements to be set down to 35 of the anticipated peak transformer inrush current To a first approximation the peak inrush is given by the reciprocal of the per unit series reactance of the transformer Page 80 4 6 Us
136. as described in Section 3 3 6 7 Moving to the EARTH FAULT column of the menu the function links are first selected 8 The CT and for directional relays the VT ratio may be entered if it is required to set the relay in primary values of current and voltage Otherwise these ratios Page 49 11 12 13 should be set at 1 1 when the settings and measured values will be displayed in the secondary quantities applied to the relay terminals Next the time characteristic for t gt can be selected 10 Repeat 7 9 for the PHASE FAULT column of the menu to select phase fault options The function links in the LOGIC column of the menu should now be set to the required functions from the available options The input and output masks are then set Section 3 4 13 gives some important notes on the allocation of output relays Finally the password protection should be established This will occur automatically two minutes after the last key press alternatively select the password cell and hold the reset key pressed until the alarm LED stops flashing The backlight on the display is turned off one minute after the last key press and will serve as a warning that the password may soon be reinstated The relay is now configured for the application and the configuration may be stored on a disc and referenced with a suitable name The file can then be retrieved and down loaded to other relays that require the same configuration This
137. ask INP CB Open CLP If link LOG6 is set to 1 then an opto input must be allocated in mask INP Aux2 or else link PF7 set to 1 To test the cold load start in this configuration the relay must be connected to an overcurrent test set as described in Sections 6 1 6 1 6 1 7 1 6 1 8 1 and 6 1 9 1 for the appropriate type of relay The current should be set to a value above the current Page 125 6 1 10 8 threshold setting gt gt or Io gt gt and then switched to the relay The time interval meter should be connected so that it starts when current is applied to the relay and stops when the output relay selected in the RLY I gt gt RLY Io gt gt mask operates The measured time should be increased by an amount equal to setting for tCLP when the cold load pick up function is activated To activate the cold load pick up timer energize the opto input allocated in INP CB Open CLP or INP Aux2 as appropriate If link PF7 and LOG6 are both set to 1 then tCLP will be initiated automatically when the current is switched off Note When timer tAUX2 is in circuit there will be a delay before the cold load pick up function is activated The second method of operation is by selecting setting group 2 for a period of time after the circuit is energized To operate in this way the function links must be set as follows LOGIC function link LOGS 1 SYSTEM DATA function link SD3 0 SYSTEM DATA function link 5 4
138. at the customer s current setting The relay selected for the lo gt gt gt trip can be found under the RELAY MASKS heading in RLY to gt gt gt The instantaneous trip output contacts must be connected to trip the test set To prevent sustained application of excessive current the time delay to gt gt gt should be set to less than 0 1 second for this test the original setting being restored when the test has been completed Special note for sensitive earth fault relays The actual minimum operation current for the sensitive earth fault settings will be affected by the magnetizing current that is taken by the core balance CT The effect that the CT has on the relay setting can be assessed if the primary circuit is de energized by reconnecting the CTs to the relay and repeating the setting test 6 1 6 2 The effective setting may be more than doubled in some cases Phase fault elements KCGG120 KCGG130 230 KCGG140 240 KCEG150 250 KCGU140 240 KCEU150 250 The relay should be commissioned with the settings calculated for the application For dual powered relays it is recommended that the relay is energized from an auxiliary voltage supply as this will reduce the burden imposed by the relay on the current injection test set Ensure that the main system current transformers are short circuited before isolating the relay from the current transformers in preparation for secondary injection tests Also isolate the relay trip contacts
139. ation Systems Business www areva td com T amp D Worldwide Contact Centre online 24 hours day 44 0 1785 25 OO 70 http www areva td com contactcentre
140. ative functions as determined by the setting of the INPUT MASKS so making maximum use of the available control inputs There are three such inputs on the single and two pole relays and eight on all other models Software filtering is applied to eliminate the adverse effects of induced ac signals in the external wiring The opto isolated control inputs are rated for 48V and energized from the isolated 48V field voltage provided on terminals 7 and 8 of the relay Terminal 8 must be connected to terminal 52 and on three and four pole relays terminal 8 must be connected to terminal 55 also The opto isolated control inputs can then be energized by connecting a volt free contact between terminal 7 and the terminal associated with the required input LO to L7 given in the above table The circuit for each opto isolated input contains a blocking diode to protect it from any damage that may result from the application of voltage with incorrect polarity Where the opto isolated input of more than one relay is to be controlled by the same contact it will be necessary to connect terminal 7 of each relay together to form a Page 53 3 6 4 common line In the example shown in Figure 21 contact X operates L1 of relay 1 and contact Y operates LO of relay 1 as well as LO and L1 of relay 2 L2 is not used on either relay and has no connections made to it The opto inputs are sampled eight times per cycle and five consecutive samples to indicate t
141. b type 2 CT connections are typical only 3 Earth connections are typical only Logic input common KCGG 130 L3 L4 15 L6 C Case earth connection 54 gt Relay healthy gt Relay failed K bus communications port 48V field voltage Figure 69 Typical application diagram 3 phase overcurrent fault relay Type KCGG 130 8 AC DC 52 51 B supply Phase rotation Ec Vi Case earth m 29 gt e EO 13 4 1531 3221 ce e 15 61 1 33 34 1 e e 17 81 1235 36 ces 19 101 1237 38 1 4 Do 42 13 14 Di 22 e 1543 4471 418 Vus aed e gt e e 119 201 4 6 Boe 1 224 50 23 AC 24 Psi 525 ud 25 XX 26 ET D d 955 C 27 E28 e SCNGD Module terminal blocks viewed from rear with integral case earth link Notes 1 a b gt Long terminal CT shorting links make before b and c disconnect Short terminals break before c 4 Pin terminal pcb type 2 CT connections are typical only 3 Earth connections are typical only E Logic input common D L3 21 L5
142. by 1 INDEED oO 1239 4021 33 ag RL5 351 gt 143 4471 A 17 08 Dis 47 ce E 5 Lo Par 7 RL6 391 gt LO 121 2 E x e 41 23 24 1 81 52 1 Li 26 sa E Bal 5 at e 27 AC 28 e e L2 l Sc SCNGD Logic input common 1 Garth Module terminal blocks L3 connection viewed from rear with integral case earth link 54 WR 14 9 K bus communications port 1 a lt CT shorting links make 15 56 IC before b and c disconnect b 5 Short terminals break before c L6 7 Long terminal 48V field voltage d Pin terminal pcb type L7 E 2 CT connections are typical only A 3 Earth connections are typical only Logicinputcommon 2 Figure 76 Typical application diagram 3 phase directional overcurrent relay Type KCEG 130 V connected 2 phase input 0804 2951 3jne Yes pue eseud c wergerp 3104 suoneorunuruioo 814 Uuornoouuoo esu porez lt Avpoy lt 19 uouruoo jndur 21807 ZI 91 ST I 21801
143. c L6 7 Long terminal d e Pin terminal pcb type 17 48V field voltage 4 6 E 2 CT connections are typical only Logic input common 2 3 Earth connections are typical only Figure 89 Typical application diagram directional 3 phase overcurrent and sensitive wattmetric earth fault relay Type KCEU 141 061 NAON 245 3 ne yeo pue oseud c ure18erp peordA T 06 are uouruoo 21807 Aquo eord 4 suoroouuoo LO 2 T 18 93vy 0 pI9 in m pi t pumu 80071 91 xe21q seutuna 1104 9 j2euuoosip pue 9 Ik yod snq y 2 sur 8011095 LO 5 C D SO10N VI vs oseo 18 ym uonooeuuoo EI 42014 eururro o hpo A Yue 9580 D 21807 GDNOS x e 8T RLT ri 6 1595 664 52 C LTA IPS ESSI NET c 157 vc X EZ Xs gt 1 po UR a Ta 9TH oT s o T T YN tz 2 us STA c 3
144. ce can be entered by the user but it is limited to 16 characters This reference is used to identify the primary plant with which the relay is associated 0006 SYS Model Number READ The model number that is entered during manufacture has encoded into it the mechanical assembly ratings and configuration of the relay It is printed on the frontplate and should be quoted in any correspondence concerning the product 0007 SYS Firmware Number READ The version of software and memory components is coded into this number It cannot be changed 0008 SYS Serial Number READ The serial number is the relay identity and encodes also the year of manufacture It cannot be changed from the menu 0009 SYS Frequency SET The set frequency from which the relay starts tracking on power up 000A SYS Communication Level READ This cell will contain the communication level that the relay will support It is used by master station programs to decide what type of commands to send to the relay 000B SYS Relay Address SET An address between 1 and 254 that identifies the relay when interconnected by a communication bus These addresses may be shared between several communication buses and therefore not all these addresses will necessarily be available on the bus to which the relay is connected The address can be manually set Address 0 is reserved for the automatic address allocation feature and 255 is reserved for global messages The factory set addr
145. cessor fail and not restart the watchdog relay will provide an alarm This relay will also signal an alarm on loss of the auxiliary energizing supply to the auxiliary powered relays but not for the dual powered relays for which the loss of the auxiliary supply may be a normal operational condition addition the memory of the relay is checked for possible corruption of data and any detected errors will result in an alarm being generated An ALARM LED Page 58 312 3 7 1 3 indicates several states which can be identified by viewing the alarm flags that are to be found towards the end of the SYSTEM DATA column of the menu and consist of six characters that may be either 1 or 0 to indicate the set and reset states of the alarm The flags offer the following indications 000000 Unconfig protection not operational needs to be configured Uncalib protection is running uncalibrated calibration error Setting protection is running possible setting error No Service protection is out of service No Samples protection not sampling No Fourier protection not performing Fourier For the above listed alarms the ALARM LED will be continuously lit the alarm bit will be set in the STATUS word as a remote alarm and the watchdog relay will operate However there is another form of alarm that causes the ALARM LED to flash this indicates that the password has been entered to allow access to
146. change protected settings within the relay and this is not generally available as a remote alarm Note No control will be possible via the key pad if the Unconfigured alarm is raised because the relay will be locked in a non operate state Measured values Measurements are divided into two groups those that are directly measured and those that are calculated from the directly measured quantities For example VA is calculated from the product of current and voltage measurement values can be displayed on the front of the relay The display of measured values will be in primary system values if the current and voltage transformer ratios are entered under PHASE FAULT and EARTH FAULT SETTINGS The default setting for these ratios is 1 1 the displayed settings and measured values then being in terms of the secondary quantities from the primary transducers Included under this heading is the number of circuit breaker trips initiated by the relay and the summated contact breaking duty for each pole of circuit breaker This feature can be extended to respond when another protection trips the circuit breaker by arranging for one of the opto inputs to be energized Remote control functions Control functions that affect the relay and that can be performed over the serial link include the change of individual relay settings and the change between setting groups Plant control functions include remote control of the circuit breaker positio
147. cklight the heading SYSTEM DATA will be displayed Use the and keys or a long F key press to select the column containing the setting or text cell that is to be changed Then with the F Page 27 3 3 1 3 3 2 key step down the column until the contents of the cell are displayed Press the or key to put the relay into the setting mode which will be indicated by a flashing cursor on the bottom line of the display If the cell is a read only cell then the cursor will not appear and the relay will not be in the setting mode To escape from the setting mode TO ESCAPE FROM THE SETTING PROCEDURE WITHOUT EFFECTING ANY CHANGE HOLD THE 0 KEY DEPRESSED FOR ONE SECOND THE ORIGINAL SETTING WILL BE RETAINED To accept the new setting Press the F key until the display reads Are You Sure YES NO 1 Press the 0 key if you decide not to make any change 2 Press the key if you want to further modify the data before entry 3 Press the to accept the change This will terminate the setting mode Password protection Password protection is only provided for the configuration settings of the relay This includes time curve selection set CT and VT ratios function link settings opto input and relay output allocation Any accidental change to configuration could seriously affect the ability of the relay to perform its intended functions whereas a setting error may only cause a grading problem Individua
148. ct b e Short terminals break before c Long terminal d Pin terminal pcb type 2 CT connections are typical only 3 Earth connections are typical only Logic input common 1 12 15 1 Logic input 2 f C Case earth 4 connection A 54 K bus communications port 56 e 1 7 8 pem field voltage EN Figure 83 Typical application diagram dual powered 3 phase overcurrent and directional earth fault relay Type KCEG 250 8 1 8 da Z 2 Pl WD 6 gt Relay healthy A AC DC supply Vx gt Relay failed 5 8 30 2 21 gt RLO 32 gt Phase rotation 1 34 122 23 RLI 36 gt 3 Case earth i Gy gx 1 29 30 25 RL2 401 gt T e 1 _ iy di 5 d 20 15 61 1233 345 Ce FP Wt Ys 27 M to 97 gt 3 T ces e e 424 1 239 4047 28 s 25 15 ext D an KCGU 110 Case earth 4 3 connection 44 Bs a 19 201 47 Dr m 1 gt gt e 23 24 Ds ES Ll 54 Aui e e 25 OK 26 gt 5 i 2d 1 55 56 1 12 gt K bus co
149. cuit breaker control For the relay to respond to remote close and trip commands for the circuit breaker it is necessary to set link SD2 to 1 and allocate output relays via both the RLY CB Close and RLY CB Trip masks The commands are not sustained for the closing time of the breaker and so time delays assert the close and trip commands to the circuit breaker for a set period of time a pulse output of duration set by time delays tTRIP and tCLOSE RLY 7 is usually allocated to RLY CB Trip and RLY 6 would be used for RLY CB Close Two circuit breaker auxiliary contacts to indicate the circuit breaker position must be connected to the control inputs of the relay The inputs assigned by the input masks INP CB Closed and INP CB Open are directed to the appropriate two bits L6 L5 L4 I2 Lit CBI 0 INP LClose Plant Status Word INP CB RLY CB Trip 11111 1 Trip CB Close CB INP Closed ATTI INP CB Open To plant stat plant status 3 Word CB status INP CB to Bus2 Sea Figure 17 Remote circuit breaker control Page 44 3 4 10 3 4 11 in the plant status word for CB1 The Plant Statu Word is used by the master station to determine where there are circuit breakers on the system which can be controlled and if they are in the open or closed
150. d data Frontplate layout The frontplate of the relay carries an identification label at the top corner This identifies the relay by both its model number and serial number This information is required when making any enquiry to the factory about a particular relay because it uniquely specifies the product In addition there is a rating label in the bottom corner which gives details of the auxiliary voltage reference voltage directional relays only and current ratings See Figure 1 Two handles one at the top and one at the bottom of the frontplate will assist in removing the module from the case Three light emitting diodes leds provide status indication and there is also a liquid crystal display and a four key pad for access to settings and other readable data Model number Relay types or Serial number Liquid crystal display LED indicators 2 2 Digit identifiers Entry keys Ratings 110 125 50 60 Figure 1 Frontplate layout LED indications The three LEDs provide the following functions GREEN LED Indicates the relay is powered up and running In most cases it follows the watchdog relay but dual powered relays are the exception because the watchdog does not operate for loss of auxiliary supply Such a condition would be considered a normal operational condition when the relays are energized from line current transformers alone Page 1
151. d for Io gt gt gt but only if the test set available can inject sufficient current into the relay to cause the element to operate at the customer s current setting The relay selected for the lo gt gt gt trip can be found under the RELAY MASKS heading in RLY to gt gt gt The instantaneous trip output contacts must be connected to trip the test set Special note for sensitive earth fault relays The actual minimum operation current for the sensitive earth fault settings will be affected by the magnetizing current that is taken by the core balance CT The effect that the CT has on the relay setting can be assessed if the primary circuit is de energized by reconnecting the CTs to the relay and repeating the Setting Test 6 1 6 2 The effective setting may be more than doubled in some cases Polarizing current sensitivity Ip When the relay is current polarized this test must be carried out to check the sensitivity Ip Connect the test circuit as shown in Figure 40 Set the currents to a value within the ratings of both the relay and the phase angle meter and adjust the phase shifter such that the two currents are in phase Then leave the phase angle set and short out the terminals of the phase angle meter While monitoring the forward start contact selected by the RL Y Io Fwd relay mask current above twice the Io setting should be injected into terminal 27 and the polarizing current should be reduced to the minimum In this cond
152. d up to a hazardous voltage At the end of each part of the test the voltage should be gradually reduced to zero to discharge capacitors before the test leads are disconnected Insertion of modules and pcb cards Modules and pcb cards must not be inserted into or withdrawn from the equipment whilst it is energised since this may result in damage Insertion and withdrawal of extender cards Extender cards are available for some equipment If an extender card is used this should not be inserted or withdrawn from the equipment whilst it is energised This is to avoid possible shock or damage hazards Hazardous live voltages may be accessible on the extender card Insertion and withdrawal of integral heavy current test plugs It is possible to use an integral heavy current test plug with some equipment CT shorting links must be in place before insertion or removal of heavy current test plugs to avoid potentially lethal voltages External test blocks and test plugs Great care should be taken when using external test blocks and test plugs such as the MMLG MMLB and MiCOM P990 types hazardous voltages may be accessible when using these shorting links must be in place before the insertion or removal of MMLB test plugs to avoid potentially lethal voltages Note when a MiCOM P992 Test Plug is inserted into the MiCOM P991 Test Block the secondaries of the line CTs are automatically shorted making them safe Fibre optic commu
153. detailed technical description of each relay feature and setting procedure Section 4 Applications An introduction to applications for the relays Section5 Technical Data Comprehensive details on the ratings setting ranges and IEC ANSI specifications to which the relays conform Section 6 Commissioning A guide to commissioning problem solving and maintenance Appendix Appendices include relay characteristic curves logic diagrams connection diagrams and commissioning test records Index Provides the user with page references for quick access to selected topics An introduction to K Range relays The K Range range of protection relays brings numerical technology to the successful MIDOS range of protection relays Fully compatible with the existing designs and sharing the same modular housing concept the relays offer more comprehensive protection for demanding applications With enhanced versatility reduced maintenance requirements and low burdens K Range relays provide a more advanced solution to power system protection Each relay includes an extensive range of control and data gathering functions to provide a completely integrated system of protection control instrumentation data logging fault recording and event recording The relays have a user friendly 32 character liquid crystal display LCD with 4 pushbuttons which allow menu navigation and setting changes Also by utilising the simple 2 wire communication link all
154. e 81 Section 5 TECHNICAL DATA 5 1 5 1 1 5 2 SU Ratings Inputs Reference Current In Nominal Rating Continuous 3 Seconds 1 Second Auxiliary powered 3 21 30In 100A In 5A 3 2In 30In 400A Dual powered In 2 4In 30In 100A In 2 411 30In 400A Reference Voltage Vn Nominal Range Maximum Withstand Value Polarizing voltage 0 327 phase neutral 375V 0 327 phase phase 0 327 3x zero sequence Auxiliary Voltage Vx Nominal Rating Operative Range Absolute DC Supply AC 50 60Hz Maximum Auxiliary powered 24 125V ac dc 19 150 50 133 190V crest 48 250V ac dc 33 300 87 265 380V crest Dual powered 100 250V ac dc 60 300V 60 265 380V crest Frequency Fn Nominal Rating Reference Range Frequency tracking 50 Hz or 60 Hz 45 65Hz Non tracking 50 Hz or 60 Hz 47 52 5Hz or 57 63Hz Opto Isolated Inputs Nominal Rating Off Voltage On Voltage Supply 60V dc only 12V dc 235V dc Maximum withstand 60V dc Outputs Field Voltage 48V dc Current limited to 60mA Capacitor Trip 50V dc 680 microfarad capacitor Energy 0 85J Burdens Reference current circuit Auxiliary powered Phase Earth SEF In 1A 0 04 0 08 0 18 ohmsat In In 1A 0 07 0 07 0 07 ohms at 30In In 5A 0 006 0 008 0 012 ohms at In In 5A 0 006 0 008 0 007 ohms at 30In Page 82 5 2 2 3 2 3 5 2 4 Dual powered Phase 1A 0 58 0 45 0 37 0 33 0 31 0 31 0 31 1A 8 1 54 2 1 0 8 0 46 0 35 0
155. e at the customer s current setting The relay selected for the gt gt trip can be found under the RELAY MASKS heading in RLY gt gt When the setting is above the continuous current rating of the relay DO NOT INCREASE THE CURRENT SLOWLY since this may damage the relay before it can operate Instead the current level should be set and then suddenly applied With the applied polarizing voltage set above twice the threshold level and the phase shifter adjusted to the characteristic angle of the relay inject the higher of the two currents specified in Table 6 33 and check that the output relay operates and the correct flags are displayed Reset the flags and repeat for the lower value of current and check that the relay does not operate the trip LED is not lit and no flags are fault displayed TRIP gt gt gt gt gt NO TRIP gt gt gt gt gt 1 05 x current setting 0 95 x current setting Table 6 33 If the gt gt gt threshold is to be used by the customer then the EARTH FAULT function link 2 should be set to 1 Test 6 1 9 5 can then be repeated for gt gt gt but Page 121 6 1 10 6 1 10 1 6 1 10 2 only if the test set available can inject sufficient current into the relay to cause the element to operate at the customer s current setting The relay selected for the lo gt gt gt trip can be found under the RELAY MASKS heading in RLY to gt gt gt The instantaneous trip outp
156. e for directional feature Polarizing voltage threshold Undercurrent setting Wattmetric power threshold for KCEG160 KCEU160 relays these cells are relocated similar to that in Section 3 2 7 PHASE FAULT 2 SET 0801 0802 0803 0804 0805 PF2 Fn Links Link 1 PF2 gt gt Link 2 PF2 EnableI gt gt gt Link 3 PF2 Dirn t gt Link 4 PF2 Dirn t gt gt Link 5 PF2 Dirn t gt gt gt Link 6 PF2 En V lt Trip Link 7 PF2 Aux2 I lt Link 8 PF2 I gt gt 2Ph Link 9 PF2 I gt gt NoPeak Link E PF2 Rev I gt gt gt Link F ALL 2 3 PF2 CT Ratio PF2 VT Ratio PF2 Charact PF2 I gt Phase fault function links PWP 1 enable I gt gt 1 enable I gt gt gt 1 directional control of I gt 1 directional control of gt gt 1 directional control of gt gt gt 1 enable delayed undervoltage trip 1 enable delayed undercurrent Cold Load Start initiation 1 enable 2 3 logic for gt gt 1 gt gt operates on the Fourier result only 1 reverse direction of I gt gt gt 1 2 3 logic applied to all phase outputs Line CT ratio PWP Line VT ratio PWP Selectable time characteristic PWP Current threshold for selected characteristic Page 25 3 2 11 3 2 12 0806 PF2t gt TMS 0807 PF2tRESET 0808 PF2 I gt gt 0809 21 gt gt 080A PF2 I gt gt gt 0808 PF2 gt gt gt 080 2 Char Angle 080D PF2 I lt 080 2 V lt 080F PF2tV LOGIC
157. e of the cold load pick up feature to increase the time setting for the instantaneous elements when energizing the primary circuit may also be considered as a way of allowing lower current thresholds to be used Circuit breaker control It is generally recommended that separate output relays are allocated for remote circuit breaker control This enables the control outputs to be selected via a local remote selector switch mounted on the circuit breaker sometimes a health and safety requirement Where this feature is not required the same output relay s can be used for both protection and remote tripping Protection trip Trip Remote 0 control Ric trip control Remote close Local Remote Figure 36 Remote control of circuit breaker Load shedding Load shedding by tripping less important loads can also benefit from the control connections shown in the remote control diagram Figure 36 Where load restoration is being used it will be necessary to provide for both tripping and closing of the circuit breaker via the relay The time delay may set to different values for each circuit so that the reclosures of the circuit breakers are staggered Note If the auxiliary supply to the relay is removed for a short period of time the relay will not remember that it tripped for a load shed command This will result in the relay not responding to a restoration command Pag
158. e power supply delay similarly varies with current The start up time is not reduced by lowering the Time Multiplier Setting With prefault load current there will be no start up time and the relays will operate within their normal time settings Note Where the start up delay cannot be tolerated it is recommended that the relay is also powered from an auxiliary ac voltage supply so that it can be up and running before a fault occurs It will also make stored disturbance and event records more secure Powered from an auxiliary ac voltage and from current transformers The addition of an auxiliary ac voltage supply to power the relay will 1 enable the settings to be changed when the protected circuit is de energized 2 enable records to be retrieved and control functions to be carried out over the communication link 3 reduce the burden on the line CTs Should the auxiliary voltage be lost during a fault power will be drawn from the current transformer circuit to maintain the relay in a fully operational state However if the source of the auxiliary voltage is carefully chosen it is unlikely to be lost completely during earth faults but it may collapse to 50 of its rated value Provided the voltage is still above the minimum required to power the relay very low earth fault settings can be successfully applied In the absence of the auxiliary voltage the relay is not guaranteed to operate for earth fault currents less than 0 2In No alarm is
159. e software of the KCEG relays has been arranged to reduce transient operation to a minimum but even so it may be advisable to set the associated time delay for any directional overcurrent element to between 40 and 200ms depending on the system X R ratio and the maximum fault level to ensure stability under this condition When KCEG relays are used in blocking schemes they will have sufficient time delay settings applied Therefore it is only the instantaneous high set elements where the delay may need to be added and often these particular elements need not be directionalized Page 72 43 2 4 3 3 Application of directional phase fault relays The characteristic angle setting of the relay is the phase angle of the line current with respect to the polarizing voltage in order to be at the centre of the directional characteristic For the phase fault elements the fault current will usually be lagging by an angle of 45 to 60 and it is desirable that this is at the centre of the directional characteristic However the phase elements are polarized by the quadrature phase phase voltage Thus phase A is polarized by Vbc but Vbc lags Va by 90 so that the effective polarizing angle of the relay for phase faults will be 90 Thus for most practical purposes the characteristic angle will be set to a leading angle of 30 or 45 for the phase elements The minimum operating value of the voltage input to the direct
160. ecording allows the analysis program to perform with records that may have a different sample rate The disturbance recorder may be triggered by several different methods dependent on the settings in the column of the menu However the records have to be read via the serial communication port and suitable additional software is required to reconstruct and display the waveforms Only one complete record is stored and the recorder must be retriggered before another record can be captured Recorder control This cell displays the state of the recorder a RUNNING recorder storing data overwriting oldest data b TRIGGERED recorder stop delay triggered STOPPED X recorder stopped and record ready for retrieval When this cell is selected manual control is possible and to achieve this the relay must be put into the setting mode by pressing the key A flashing cursor will Page 61 then appear on the bottom line of the display at the lefthand side The key will then select RUNNING and the key will select triggered When the appropriate function has been selected the F key is pressed to accept the selection and the selected function will take effect when the key is pressed to confirm the selection To abort the selection at any stage press the reset key 0 Recorder capture The recorder can capture a SAMPLES the individual calibrated samples b MAGNITUDES the Fourier derived amplitudes c PHASES
161. ectional decision is applied after the current threshold and before the following associated time delay The directionalization of any element can be selectively overridden by adjusting software links in the relay menu to a suitable setting The undercurrent element I lt is the exception since this element is not provided with directional control Zone of forward start forward operation 90 De 90 Figure 8 Directional characteristic Page 35 3 4 2 2 Directional overcurrent and earth fault relay logic The directional overcurrent logic is shown in Figure 9 for the phase elements and the following description applies equally to the directional earth fault logic When the current threshold I gt is exceeded and the polarizing signal is above the threshold Vp gt an output is directed to the RLY I gt Fwd mask for forward current flow and to the RLY I gt Rev for reverse current flow A non directional start can be obtained by allocating the same output relay in both start masks so that it operates for forward or reverse current flow The time delay t starts timing when the current exceeds the I gt setting and link PF3 is set to 0 to give a non directional trip via the RLY t gt mask With link PF3 set to 1 the time delay will only run if the current exceeds the I threshold and is in the forward direction External control is asserted via input mask INP Blk t gt and when this input is energiz
162. ed the time delay is reset to zero after the reset delay setting Selective directionalization of overcurrent elements If link PF3 EF3 for EF is set to 1 time delay t to gt starts timing when the current exceeds the I gt Io gt setting and is in a forward direction If link PF3 EF3 is set to 0 t to gt will start timing when the current exceeds the I gt Io gt setting regardless of the direction of flow The circuits associated with the gt gt gt gt and gt gt gt gt gt gt elements not shown but they also can be selectively directionalized with their respective function links PF4 EF4 and 5 Selective directionalization of the start outputs The phase fault start outputs will be directionalized if any one of the phase elements is selected to be directionalized and similarly the earth fault start outputs will be directionalized if any one of the earth fault elements is selected to be directionalized A non directional start can be obtained by allocating the same output relay in both start masks so that it operates for forward or reverse current flow but note that no output will be obtained if the voltage is below the polarizing voltage threshold setting Vp for phase faults and Vop gt for earth faults Alternatively if all three phase fault elements are selected to be non directional then the phase fault forward start mask will respond with a non directional start without requ
163. elay is assigned by mask RLY t gt gt The third overcurrent function gt gt gt is selected by link PF2 for earth faults lo gt gt gt by EF2 The following time delay gt gt gt has external control assigned by mask INP gt gt gt and output relays assigned by RLY t gt gt gt Two Out of Three Logic The t gt gt element has been provided with a two out of three logic selected by link PF8 When selected it will ensure operation only occurs for phase phase faults and double phase to earth faults It will not operate for single phase earth faults Page 34 3 4 2 3 4 2 1 INP Blk t gt I gt INP Blk t gt gt I gt gt INP Blk t gt gt gt ap mures j 2 I gt gt gt Figure 7 Overcurrent logic Directional overcurrent function and logic Directional overcurrent and earth fault relays function Phase fault directional elements are polarized by the quadrature phase phase voltage and the earth fault elements are polarized by the zero sequence voltage The direction part of the measurement includes a threshold value on the polarizing quantity and for phase fault measurement this threshold is fixed However for earth faults an adjustable threshold is provided to allow a setting above any imbalance in the zero sequence polarizing signal to be applied Control is provided for adjustment of the characteristic angle of the relay The dir
164. element to operate at the customer s current setting The relay selected for the gt gt trip can be found under the RELAY MASKS heading in RLY to gt gt To prevent sustained application of excessive current the trip output contacts for to gt gt should be connected to trip the test set The time delay to gt gt should be set to Page 116 6 1 8 7 6 1 8 8 6 1 8 9 less than 0 1 second for the test and restored to its original value when the test has been completed When the setting is above the continuous current rating of the relay DO NOT INCREASE THE CURRENT SLOWLY since this may damage the relay before it can operate Instead the current level should be set and then suddenly applied With the applied polarizing voltage set above twice the threshold level and the phase shifter adjusted to the characteristic angle of the relay inject the higher of the two currents specified in Table 6 26 check that the output relay operates and the correct flags are displayed Reset the flags and repeat for the lower value of current and check that the relay does not operate the trip LED is not lit and no flags are fault displayed TRIP gt gt 0 gt gt gt NO TRIP gt gt 0 gt gt gt 1 05 x current setting 0 95 x current setting Table 6 26 If the gt gt gt threshold is to be used by the customer then the EARTH FAULT function link 2 should be set to 1 Test 6 1 8 6 can then be repeate
165. en it will not be possible to change individual settings over the communication link Cold load pick up Cold load pick up refers to the need to either inhibit the instantaneous low set element of the overcurrent protection or raise the overcurrent settings for a period of time when a circuit is energized This allows the protection settings to be set closer to the load profile by increasing settings automtically to cover the transient increases on circuit energization This feature is not available in the KCEU 141 KCEU 241 relay For systems where the load is predominantly air conditioning there will be large transient currents whilst the blower motors start up To cater for this type of load it may be sufficient to simply block the instantaneous low set elements for a short time However where the domestic loads are predominantly formed by resistance heating the second method would be preferable where the fault settings for both the instantaneous low set and the inverse time overcurrent elements are increased The cold load pick up feature can be used to compensate for many transient load conditions including motor starting The cold load pick up timer tCLP allows for time delays from zero to 4 hours Page 42 3 4 8 1 3 4 8 2 INP Blk t gt gt RLY t gt gt From auxiliary 2 timer and I lt Figure 15 Cold load pick up increased lowset delay Instantaneous low set element delayed by cold load pick up
166. ent of complete failure of the trip battery supply Page 76 4 5 4 5 1 4 5 2 The application limitations are that the setting range of these relays is a little more restricted when power is being derived from the current transformers alone and that the circuit breaker must have a suitable trip coil fitted The tripping energy is provided by 680uF capacitor charged to 50V and the circuit breaker should reliably trip when this capacitor is discharged into its trip coil See Section 3 6 6 for alternative trip connections Breaker fail protection backtripping and back up transfer tripping Breaker fail protection and backtripping If the function links have been set to activate the breaker fail function then the blocking signals will be removed if the breaker fails to clear the fault within the set time delay tBF This will result in the START relays being reset so allowing any relays that they were blocking to operate It may be that the current setting of the blocked upstream relay is higher than the available fault current so it is not able to clear the fault In this case it would be an advantage to backtrip sending a signal from the relay that is trying to trip the failed circuit breaker directly to the next circuit breaker towards the source When the backtrip feature is selected the output relay is assigned via the output mask Aux1 and will be recorded in the fault flags as Aux1 The time delay tBF will typically have a
167. ess is 255 000C SYS Plant Status READ Plant status is a 16 bit word which is used to transport plant status information over the communication network The various bit pairs are pre allocated to specific items of plant 000D SYS Control Status READ The control status is not used in these relays but would act like software contacts to transfer data from the relay to the master station controlling communications For example it may be used by a frequency relay to transfer data to indicate different levels of load shedding that may be initiated by the master station Page 20 000 SYS Setting Group READ Where a relay has alternative groups of settings which can be selected then this cell indicates the current group being used by the relay For these relays it is either Group 1 or Group 2 000F SYS LS Stage READ Cell 000F displays the level of load shedding at all times It has been assumed that load shedding will be initiated either by tripping less essential loads or by voltage reduction not by both methods simultaneously Hence there is no arbitration on what is displayed in cell 000F If the load shed by voltage reduction feature is in use and a command issued to load shed to level 1 then it will display Vreductl If a command is then issued to the same relay to load shed trip this same cell will display that action even if SD1 0 Load shedding by voltage reduction is always responsive to remote commands if output
168. f current is within the range shown in Table 6 15 Current level Pick up 0 95 x Is 1 05 x Is Drop off 0 9 x pick up 1 0 x pick up Table 6 15 The test must be repeated on all the phase elements of the relay Table 6 16 lists the terminals that current should be injected into for each of the phases Phase Terminals A 21 22 23 24 25 26 Table 6 16 In addition with some site wiring it may be necessary to inject A N B N C N Time characteristic for t gt The relay selected for the t gt trip can be found under the RELAY MASKS heading in RLY t gt The terminals for each relay are shown in the application diagram Connect the relay contacts for the t gt trip to both trip the test set and to stop a timer Inject single phase current of 2 x setting current into one of the phase fault current inputs listed in Table 6 16 If the test set used can inject sufficient current repeat the test at 10 x setting current Check that the operating time for the relay is within the range shown in the Table 6 17 below Curve Operating time at specified current seconds x TMS description 2 x Is 10 x Is Nominal Range Nominal Range STI30XDT 1 780 1 68 1 87 0 52 0 49 0 55 SIB0XDT 10 03 9 52 10 53 2 07 2 82 3 12 I30XDT 15 05 14 30 15 81 2 34 2 23 2 46 VI30XDT 13 5 12 82 14 18 1 50 1 43 1 58 EDOXDT 26 67 24 66
169. f default relay masks input masks and protection settings Any of these settings can be left at these default values if required When the relay settings have been entered into the relay they should be noted down on the commissioning test record sheet If the K Bus communications are being used then the master station can download the settings to the relay record any relay settings on disc and download recorded settings to other relays All relays will leave the factory set for operation at a system frequency of 50Hz If operation at 60Hz is required then this must be set as follows From SYSTEMS DATA menu press the F key until SYS Frequency 50HZ appears the LCD Press the key until the display shows SYS Frequency 60Hz Then press the F key once more followed by the key to confirm the change Measurement checks To test the relay measurement functions a known current should be injected into each phase input and the neutral input For directional relays the polarizing voltage s should be applied to the VT inputs as per the application diagram The phase to neutral voltage should be measured with a voltmeter or for single pole relays the open delta winding voltage from the line VTs With the CT and VT ratio settings of the PHASE FAULT and EARTH FAULT headings set to the values of the line CTs and VTs the displayed measured values and settings will be in the equivalent primary quantities All measured values have a
170. failed gt Relay healthy 41 O RL7 43 gt e 1 1 C Case earth J connection 1 1 54 e K bus communications port 56 1 7 8 48V field voltage Figure 81 Typical application diagram dual powered 3 phase directional overcurrent relay 230 OPT 0804 odd 3 ne Yes pue c 4 penp ure18erp 9 ASpT L e 9S 3 vs uonoouuoo T aseg snq y tv LTA 9t ITA 9 OTA 0 pi A epy lt S i porez lt 19 Le I aid 9TH Orc uoururoo jndur 21801 56 t uoururoo ndur 21807 2 pue 4 X ayeul LO 1 K uo are eord 4 suonoouuoo Lo adAq q d p pumua 80071 2 xvo1q sppuruuo 11045 q 9 0 UIT Yue 5 8 YIM
171. for an insulated system a core balance current transformer should be used Where this is oriented as for an earthed system i e with the relay looking down the feeder the relay characteristic angle should be set to 90 If the current transformer is reversed anticipating capacitive current flow from the feeder onto the busbar 90 should be used For the protection of arc suppression Petersen coil earthed systems a sensitive setting is required to enable accurate detection of the relatively small currents flowing under fault conditions Angle settings in the region of 5 lead 0 5 lag are common with the relays having suitably fine setting adjustments of 1 Two options exist within the K Range for protection of arc suppression Petersen coil earthed systems a standard sensitive directional earth fault relay KCGU110 or alternatively the KCEU141 241 Both relays have an adjustable polarising voltage threshold setting with the KCEU141 241 having an additional wattmetric V I cos earth characteristic By virtue of these features either of the above options effectively ignore any residual spill current resulting from mismatch of line CTs due to the fact that there is negligible zero sequence voltage present under load conditions Page 73 4 3 4 4 3 5 Where a directional relay is used to prevent sympathetic tripping of the earth fault element which would otherwise result from the currents flowing via the cable c
172. for equipment atmosphere Compliance demonstrated by Notified Body certificates of compliance Radio and Compliance demonstrated by compliance to the Low Telecommunications Terminal Voltage Directive 73 23 EEC amended by 93 68 EEC Equipment R amp TTE down to zero volts by reference to safety standards directive 95 5 EC Pxxxx EN 55 81 1 Safety Section Page 9 10 9 RECOGNIZED AND LISTED MARKS FOR NORTH AMERICA CSA Canadian Standards Association UL Underwriters Laboratory of America UL Recognized to UL USA requirements 2 UL Recognized to UL USA and CSA Canada requirements c e UL Listed to UL USA requirements UL Listed to UL USA and CSA Canada requirements e oe US LISTED PRODUCT IDENTITY XXXX Certified to CSA Canada requirements Pxxxx EN 55 1 1 10 10 Safety Section BLANK PAGE Section 1 HANDLING AND INSTALLATION 11 1 1 1 12 General considerations Receipt of relays Protective relays although generally of robust construction require careful treatment prior to installation on site Upon receipt relays should be examined immediately to ensure no damage has been sustained in transit If damage has been sustained during transit a claim should be made to the transport contractor and a AREVA T amp D representative should be promptly notified Relays that are supplied unmounted and not intended for immediate installat
173. for the circuit breaker can be obtained at this time by reading the appropriate data in the MEASUREMENT 2 and the FAULT RECORDS columns Additional tests Additional tests can be selected from the Commissioning Instructions as required Method of repair Please read the handling instructions in Section 1 before proceeding with this work This will ensure that no further damage is caused by incorrect handling of the electronic components Replacing a pcb a Replacement of user interface Withdraw the module from its case Remove the four screws that are placed one at each corner of the frontplate Remove the frontplate Lever the top edge of the user interface board forwards to unclip it from its mounting Then pull the pcb upwards to unplug it from the connector at its lower edge Replace with a new interface board and assemble in the reverse order b Replacement of main processor board This is the pcb at the extreme left of the module when viewed from the front To replace this board First remove the screws holding the side screen in place There are two screws through the top plate of the module and two more through the base plate Page 137 6 3 3 2 6 3 3 3 6 3 3 4 Remove screen to expose the pcb Remove the two retaining screws one at the top edge and the other directly below it on the lower edge of the pcb Separate the pcb from the sockets at the front edge of the board Note that they are a tight fit and will
174. former must be set up as shown in Figure 40 Taking positive phase angles as the current leading the voltage and negative phase angles as the current lagging the voltage adjust the phase shifting transformer so the phase angle meter reads 180 set earth fault characteristic angle Once the phase angle has been set and the current input of the phase angle meter has been short circuited with a wire link the overcurrent tests can be performed The correct polarity of connection for operation with forward current flow is shown in the two tables at the beginning of Section 3 6 The test arrangement will depend on the type of relay being tested KCEG140 240 KCEU 140 240 The residual voltage is internally derived from the summation of the three phase to neutral voltages and for these relays a three phase voltage should be applied to the relay The residual voltage is then produced by collapsing one of the phase voltages with a potentiometer as shown in Figure 40 the residual voltage being equal to the actual amount by which the phase voltage is reduced KCEG110 210 KCEG150 250 KCEG160 KCEU110 KCEU150 250 KCEU160 The earth fault elements of other relays in the range require the residual polarizing voltage to be derived from an external source and so the connections should be as shown in Figure 41 Page 112 6 1 8 2 Polarizing voltage sensitivity gt To test the sensitivity of the polarising voltage the relay must be connected a
175. g problems To return the relay to a serviceable state the initial factory configuration will have to be reloaded and the the relay recalibrated It is recommended that the work be carried out at the factory or entrusted to a recognized service centre Page 132 6 2 3 3 6 2 3 4 6 2 3 5 6 2 4 6 2 4 1 Setting error alarm A SETTING alarm indicates that the area of non volatile memory where the selected protection settings are stored has been corrupted The current settings should be checked against those applied at the commissioning stage or any later changes that have been made If a personal computer PC is used during commissioning then it is recommended that the final settings applied to the relay are copied to a floppy disc with the serial number of the relay used as the file name The setting can then be readily loaded back into the relay if necessary or to a replacement relay No service alarm This alarm flag can only be observed when the relay is in the calibration or configuration mode when the protection program will be stopped Fault flags will not reset These flags can only be reset when the flags Fn are being displayed or by resetting the fault records see Section 3 3 10 Records Problems with event records Fault records will only be generated if RLY3 is operated as this relay is the trigger to store the records Fault records can be generated in response to another protection operating if RLY3
176. g the right hand terminal block to the top plate of the module Remove the two screws securing the right hand terminal block to the bottom plate of the module Unplug the back plane from the power supply pcb Remove the securing screw at the top and bottom of the power supply board Withdraw the power supply board from the rear unplugging it from the front bus Reassemble in the reverse of this sequence Replacing the back plane size 4 and 6 case Remove the two screws securing the right hand terminal block to the top plate of the module Remove the two screws securing the right hand terminal block to the bottom plate of the module Page 138 6 3 4 6 3 5 Unplug the back plane from the power supply pcb Twist outwards and around to the side of the module Replace the pcb and terminal block assembly Reassemble in the reverse of this sequence Recalibration Whilst recalibration is not usually necessary it is possible to carry it out on site but it requires test equipment with suitable accuracy and a special calibration program to run on a PC This work is not within the capabilities of most people and it is recommended that the work is carried out by an authorized agency After calibration the relay will need to have all the settings required for the application re entered and so it is useful if a copy of the settings is available on a floppy disk Although this is not essential it can reduce the down time of the system Dig
177. ge tV lt Definite time to 10s tAUXI Definite time to 14 4ks 4Hrs tAUX2 Definite time to 14 4ks AHrs tAUX3 Definite time to 14 4ks 4Hrs tCLP Definite time to 14 4ks AHrs tBF Definite time 0 to 10s tTRIP Definite time 0 5 to 2s tCLOSE Definite time 0 5 to 2s tRESTORE Definite time 0 to 100s Page 85 Minimum operation 1 05Is 1 05Is 1 05Is 1 05Is 1 05Is 1 05Is 1 05Is Step size 0 01s 0 15 0 015 0 015 Step size 0 01s 0 01 0 1 1 or 10s 0 01 0 1 1 or 10s 0 01 0 1 1 10s 0 01 0 1 1 or 10s 0 01s 0 16 0 16 0 015 5 4 4 55 5 6 5 7 5 7 1 52 Measurement Displayed Voltage 0 327 x VT ratio volts phase neutral Current 0 64 In x CT ratio amps per phase Power 0 9 999 x 1021 Watts VAr 0 9 999 x 10 VAr VA 0 9 999 x 102 VA CB Operations 0 65535 broken 0 9 999 x 1021 Frequency 45 65 Hz Directional settings Characteristic angle 95 0 4 95 Operating boundary 90 Undervoltage V lt 1V to 220V phase to phase Voltage threshold Vp 0 5 fixed overcurrent directional elements Voltage threshold 0 5V to 22V directional earth fault Current threshold Ip 0 005In to 0 05In dual polarized only Note The KCEG 140 requires a residual voltage in excess of 6 4V before the voltage threshhold circuit will function regardless of the Vop setting If this is considered to be a problem in a p
178. give as long a delay as possible but less than that which would interfere with normal Page 78 4 7 2 4 7 3 operation of the protection and control system will help to eliminate some less common health and safety problems Overcurrent relays in Midos K Range have provision for adjusting the reset delay to values between 0 and 60 seconds for timers t gt to gt Reset times of 60 seconds are most suited to cable applications where autoreclose is not generally permitted For overhead lines with fast reclosing equipment it can be an advantage to set the reset time to zero this will ensure that all relays will have fully reset before a reclosure takes place and that some relays will not be held part way towards operation as a result of the last fault When grading with electro mechanical relays which do not reset instantaneously the reset delay can be used to advantage to gain closer discrimination In these instances the reset time should be set to a value less than the dead time setting of any autoreclose relays on the system Sensitive earth fault relays will also benefit from having the reset time set as high as possible so that fault current pulses are summated Any reset delay will give an improvement in the detection of intermittent faults 2000 A 0 2s 3 0s 0 35 2 05 0 55 OA Trip Level Reset Time 5s Reset Time 08 71 Figure 34 Protection against intermittent faults Autorecl
179. hat the input is energized before this is accepted This ensures that the inputs are relatively immune to spurious operation from induced ac signals in the wiring thus the capture time is 12 2 5ms at 50 Hz 10 4 2 1ms at 60 Hz Note These inputs will not capture a fleeting contact unless it dwells in the closed state for a time exceeding the above values Relay 1 Common line Figure 21 Connection to opto isolated control inputs Analogue inputs The relays can have up to eight analogue inputs two on the microprocessor board and six on the auxiliary expansion board Each is fed via an input transducer a low pass filter and a three range scaling amplifier The analogue signals are sampled eight times per cycle on each channel as the sampling rate tracks the frequency of the input signal The wide setting range provided on the auxiliary powered version of the relays is sufficient to enable the 5A version of the relay to operate from either 1A or 5A current transformers and this version of the relay can be used where dual rated relays are specified Alternatively the wide setting range makes the relay suitable for use on circuit breakers that may be applied to a wide range of load circuit ratings with only one current transformer ratio For example a circuit breaker rated at 2000A and fitted with current transformers rated at 2000 10A or 2000 2A and relays rated at 5A or 1A could be applied to circuits with load rating
180. he forward start contact selected by the RLY Io gt Fwd relay mask current above twice the Io gt setting should be injected into terminal 27 and the polarizing voltage should be reduced to the minimum In this condition the forward start contact should be open The polarizing voltage should be then slowly increased until the forward start contact RLY Io gt Fwd operates this value should be the set value for Vop gt 10 Note for the KCEG140 where the residual voltage is generated internally the Vop gt settings cannot be guaranteed below 7V when the low gain range is selected by the healthy phases Directional relays A B 17 B 18 C VP 19 N 20 440V 110V Phase angle meter 27 Current injection E test set 28 Figure 42 Connections for current polarization check of KCEG160 and KCEU160 Angular boundary of operation for Vop gt Apply polarizing voltage above the threshold voltage Vop gt and operating current above the setting Io gt to the relay under test From the EARTH FAULT heading make a note of the relay characteristic angle RCA The forward start contact selected by the RLY Io gt Fwd relay mask under the RELAY MASKS heading and the reverse start contact selected by the Page 114 6 1 8 4 RLY Io Rev relay mask should be monitored to indicate when the relay is in the operate region Taking positive angles as leading and negative angles as lagging adjust the phase
181. he state they would take up with no inputs applied to the protective relay The function links are also implemented in software but have been drawn as mechanical links They are shown in the factory default position for the basic factory configuration In position 0 the function is deselected and in 1 the function is selected Opto isolated control inputs 17 10 are represented by an eight bit mask with a thicker line at the top and left hand side of the mask The control asserted by the input is stated above the mask and the position of the 176 within the mask will determine the input s that assert the control More than one control input may be assigned by the mask and the same control inputs may be used in several masks The output relays RLY7 RLYO are represented by eight bit mask with a thicker line at the bottom and right hand side A mask is allocated to each protection and control function that can be assigned to an output relay The function asserted on the mask is stated by the text above it and the position of the 175 in the mask Page 31 determines which relay s operate in response than one output relay may be assigned by a mask and the same relay may be assigned by several masks INP BLOCK t gt gt RLY TRIP gt gt Input mask Relay mask CLOSE CB Remote command Hardware representation of software links 10 2 1 gt gt gt Contact representat
182. icate which element has tripped See Section 3 1 5 for more information on the flag display With the applied polarizing voltage set above twice the threshold level and the phase shifter adjusted to the characteristic angle of the relay inject current into the earth fault current input of the relay terminals 27 and 28 Slowly increase the current and note the pick up value at which the RLY Io Fwd relay operates Reduce the current slowly and note the drop off value at which the START relay resets Check the pick up and drop off current is within the range shown in Table 6 24 Current level Pick up 0 95 x Is 1 05 x Is Drop off 0 9 x Pick up 1 0 x pick up Table 6 24 Page 115 6 1 8 5 6 1 8 6 Time characteristic for to gt The relay selected for the to gt trip can be found under the RELAY MASKS heading in RLY to gt The terminals for each relay are shown in the application diagram Connect the relay contacts for the to gt trip to both trip the test set and to stop a timer With the applied polarizing voltage set above twice the threshold level and the phase shifter adjusted to the characteristic angle of the relay inject a single phase current into the earth fault current input terminals 27 and 28 at 2 x setting current If the test set used can inject sufficient current repeat the test at 10 x setting current Check the operating time against Table 6 25
183. ing The electrical power should be removed before making any change to avoid the risk of electric shock Exposure of live parts Removal of the cover may expose hazardous live parts such as relay contacts these should not be touched before removing the electrical power TECHNICAL SPECIFICATIONS FOR SAFETY Protective fuse rating The recommended maximum rating of the external protective fuse for equipments is 16A high rupture capacity HRC Red Spot type NIT or TIA or equivalent unless otherwise stated in the technical data section of the equipment documentation The protective fuse should be located as close to the unit as possible DANGER CTs must NOT be fused since open circuiting them may produce lethal hazardous voltages Protective Class IEC 61010 1 2001 Class unless otherwise specified in the equipment EN 61010 1 2001 documentation This equipment requires a protective conductor earth connection to ensure user safety Installation Category IEC 61010 1 2001 Installation Category Overvoltage Category III EN 61010 1 2001 Distribution level fixed installation Equipment in this category is qualification tested at 5kV peak 1 2 50us 5000 0 5 between all supply circuits and earth and also between independent circuits Pxxxx EN 55 31 1 Page 8 10 7 4 8 Safety Section Environment The equipment is intended for indoor installation and use only If it is required for use in an outdoo
184. ion Directional phase fault relays have the addition of a three phase undervoltage characteristic that can be arranged to provide a trip command when the supply is lost It requires the voltage on all three phases to fall below the set threshold V lt before an output is obtained A following adjustable time delay tV lt is provided in the trip path for this element to prevent operation during a fault when the voltage may be temporarily depressed Undervoltage logic Directional relays have the addition of an undervoltage trip This can be arranged to operate an output relay via mask RLY tV lt after a set delay tV lt so that the circuit breaker is tripped on loss of all three phase voltages The circuit breaker or undercurrent element may then initiate CLP as described in Section 3 4 8 RLY tV lt Figure 11 Undervoltage logic Auxiliary timers Models A and B There are three auxiliary timers in the relays that are sometimes used in the internal scheme logic as will be discussed later in this document When they are not used internally they may be used as discrete time delays for external functions They may be initiated via the opto isolated control inputs and their outputs directed to any of the output relays by suitably setting the associated RELAY MASKS All the settings for the auxiliary timing functions that are used in the logic of the protection are located under the LOGIC heading of the menu The set
185. ion should be returned to their protective polythene bags Electrostatic discharge ESD The relays use components that are sensitive to electrostatic discharges The electronic circuits are well protected by the metal case and the internal module should not be withdrawn unnecessarily When handling the module outside its case care should be taken to avoid contact with components and electrical connections If removed from the case for storage the module should be placed in an electrically conducting antistatic bag There are no setting adjustments within the module and it is advised that it is not unnecessarily disassembled Although the printed circuit boards are plugged together the connectors are a manufacturing aid and not intended for frequent dismantling in fact considerable effort may be required to separate them Touching the printed circuit board should be avoided since complementary metal oxide semiconductors CMOS are used which can be damaged by static electricity discharged from the body Handling of electronic equipment A person s normal movements can easily generate electrostatic potentials of several thousand volts Discharge of these voltages into semiconductor devices when handling electronic circuits can cause serious damage which often may not be immediately apparent but the reliability of the circuit will have been reduced The electronic circuits are completely safe from electrostatic discharge when housed i
186. ion of output 1 gt gt gt from a protection function Delayed closing A Delayed opening gt contacts are shown the de energised position Figure 4 Key to symbols used in the Logic Diagrams Function 1 Function 2 Function 3 Function 4 Relay status Figure 5 Operation of input output masks Function is initiated by LO as indicated by the position of the 1 in the input mask The input masks act as an OR gate so that for function 2 it is initiated by either or both LO and L1 but L1 will not initiate function 1 Page 32 3 4 1 3 4 1 1 3 4 1 2 Both functions 3 and 4 can be initiated by L3 but only function 4 is initiated by LS Similarly the output masks can be used to direct the output of a function to any relay The relay masks also act as OR gates so that several functions can be directed to a particular output relay In the example function 1 operates relays 3 and 6 however relay 3 is also operated by functions 2 3 and 4 Overcurrent function and logic Overcurrent function There are three overcurrent stages per pole and the settings for each stage are completely independent of each other within the allowable setting ranges These elements have settings designated as I gt gt gt and gt gt gt for phase faults and the settings of each of these parameters affect all three phase elemen
187. ion software package designed to run under DOS on an IBM or IBM compatible personal computer It provides an interface for remote communication with the AREVA T amp D range of relays that implement the Courier Communication Language It utilises a standard RS 232 serial port of the PC to communicate using IEC60870 and the Courier language either directly to IEC60870 based relays or via an interposing KITZ protocol converter to K Bus based relays It can interface to a maximum of 254 relays although this is normally restricted to 32 relays at a time this being the maximum number of relays that can be connected to one spur directly User input is via the keyboard using the familiar system of pull down menus and windows to select various options and functions Two versions of the software are available Protection Access Software amp Toolkit PAS amp T which enables the user to have full access to all functions within the relay including the event and disturbance recording facilities Courier Access software which is a reduced version of the PAS amp T enabling the user to have access to all settings on the relay via the communication link PC requirements To operate correctly the Protection Access Software amp Toolkit requires IBM PC XT AT PS2 or true compatible 640 kB of main memory RAM Graphics adaptor CGA EGA VGA or MDA Serial adaptor port configured as COM1 of COM2 for communication Floppy disc drive
188. ional overcurrent relay should be as low as practicable from the aspect of correct directional response of the relay itself This follows because of the important requirement for the relay to achieve correct directional response during a short circuit fault close to the relay when the voltage input can be below 1 of rated value Furthermore there is no restriction on the minimum operating value from the aspect of the power system or voltage transformer performance Hence the threshold for the phase fault elements of the KCEG relays has been set at 0 5V Application of directional earth fault relays The earth fault element uses the zero sequence voltage as the polarizing quantity With multi pole relays this voltage is internally derived from the three phase to neutral voltages applied to the relay With single pole relays this voltage has to be externally derived from an open delta winding on the line voltage transformers or via star open delta interposing voltage transformers The characteristic angle setting for earth faults will be as shown on the relay and therefore lagging angles of between 0 and 60 may be used as appropriate dependent on the system earthing arrangements A 0 setting is generally used on resistance earthed systems whereas a 45 setting would be more typical on solidly earthed distribution systems with 60 being typical on solidly earthed transmission systems When providing sensitive earth fault protection
189. iring a polarizing voltage to be present Similarly if all three earth fault elements are selected to be non directional the earth fault start mask will respond with a non directional start without requiring a polarizing voltage to be present In either case the associated reverse start mask will be inoperative INP Blk t I Vp Fwd RLY I gt Fwd Start Rev RLY I gt Start Figure 9 Directional overcurrent logic Page 36 343 3 4 3 1 3432 Polarisation of earth fault elements The earth fault element is normally directionalised by the earth fault polarising voltage 3Vo No directional output is generated if the voltage or current inputs are too low to correctly determine the phase angle Vo also has an additional voltage threshold Vop gt Reverse blocking occurs when the current vector appears in the reverse start zone as shown in Figure 8 where the characteristic boundaries are 90 from the relay characteristic angle For the current operate vector to be on the relay characteristic angle under fault conditions the relay characteristic angle must be set according to the expected system earth fault angle KCEU141 Earth fault element In addition to the standard earth fault element characteristic the KCEU141 241 incorporates an additional wattmetric characteristic typical applications of this type of characteristic being resonant Petersen coil earthed systems The
190. is operated by one of its trip contacts via an auxiliary input This will result in the fault values as measured by the K Relay being stored at the instant RLY3 resets The flag display will include a flag to identify the auxiliary input that initiated the record Fault currents recorded are lower than actual values as the fault is interrupted before measurement is completed Few fault records can be stored when changes in state of logic inputs and relay outputs are stored in the event records These inputs and outputs can generate many events for each fault occurrence and limit the total number of faults that can be stored Setting System Data Link 7 to 0 will turn off this feature and allow the maximum number of fault records to be stored The event records are erased if the auxiliary supply to the relay is lost for a period exceeding the hold up time of the internal power supply Events can only be read via the serial communication port and not on the LCD Any spare opto inputs may be used to log changes of state of external contacts in the event record buffer of the K Relay The opto input does not have to be assigned to a particular function in order to achieve this The oldest event is overwritten by the next event to be stored when the buffer becomes full When a master station has successfully read a record it usually clears it automatically and when all records have been read the event bit in the status byte is set to 0
191. ital test equipment If commissioning testing is carried out using a digital secondary injection test set there may be an apparent erratic operation at the boundaries of the directional characteristic This will be particularly noticeable when observing the operation of the start relay contacts which is the method described in the commissioning instructions in Section 6 1 This is caused by the transitional errors when changing direction or applying signals instantaneously The problem is easily overcome by using the t gt t gt gt t gt gt gt to gt to gt gt or to gt gt gt outputs for indication of relay operation instead of I gt or gt These time delays should then be set to a minimum of 20ms See also the notes in Section 4 3 5 of this manual The slight directional indecision of the start relays should not cause any problem as it will be covered by the short time delays that are applied in the blocking schemes Page 139 Appendix 1 CHARACTERISTIC CURVES FOR KCGG KCGU KCEG and KCEU RELAYS t H s 10 00 1 00 0 10 0 01 c 1 00 10 00 xIs Figure 47 Characteristic curve ST30XDT short time inverse definite time above 30xIs Page 140 1 20 1 00 0 90 0 820 0 70 0 60 0 50 0 40 0 30 0 20 0 10 0 05 1 00 10 00 xIs Figure 48 Characteristic curve SIZ30XDT standard inverse moderately inverse definite time above 30xIs Page 141
192. ition the forward start contact should be open The polarizing current should be then slowly increased until the forward start contact RLY Io Fwd operates this value should be the set value for Iop 10 Angular boundary for Iop Check the test connections to the relay are as shown in Figure 40 Ensure the polarities of all of the connections are correct particularly where variable or step down transformers are used and that the phase shifting transformer is connected star star Apply polarizing current above the threshold Iop and operating current above the setting threshold Io to the earth fault circuit under test Note that the relay characteristic angle for current polarized directional operation is always taken to be 0 Page 117 The forward start contact selected by the RLY Io gt Fwd relay mask under the RELAY MASKS heading and the reverse start contact selected by the RLY Io gt Rev relay mask should be monitored to indicate when the relay is in the operate region Adjust the phase shifting transformer until the phase angle measured on the phase angle meter is 180 Check that the reverse start contacts have closed and the forward start contacts are open If the reverse start relay has not operated then check both current polarities conform with the diagram Adjust the phase shifting transformer until the angle measured on the phase angle meter is 0 Check that the reverse start contacts are open and the forw
193. ium to large transformer is arranged in delta restricted earth fault protection is often applied Restricted earth fault protection can be provided by a dedicated electro mechanical relay however the earth fault element of a K Range relay can be arranged to offer comparable protection When the earth fault element gt gt is connected in a restricted earth fault configuration a stabilizing resistor will be required to be connected in series with the neutral input circuit of the relay Application of Midos K Range relays for restricted earth fault protection is further described in publication R4120 Further applications and control facilities Protection against intermittent recurrent faults This type of fault is also sometimes referred to as a pecking or flashing fault A typical example of an intermittent recurrent fault would be one in a plastic insulated cable where in the region of the fault the plastic melts and reseals the cable extinguishing the fault but after a short time the insulation breaks down again The process repeats to give a succession of fault current pulses each of increasing duration with reducing intervals between the pulses until the fault becomes permanent When the reset time of the overcurrent relay is less than the interval between the fault current pulses the relay will be continually reset and not be able to integrate up to the trip level until the fault becomes permanent Having the reset time set to
194. ks viewed from rear with integral case earth link Notes 1 a exc Gs shorting links make before b disconnect b e Long terminal Short terminals break before c d Pin terminal pcb type 2 CT connections are typical only 3 Earth connections are typical only KCGG 120 1 Case earth d connection 1 4L 54 gt Relay healthy gt Relay failed 48V field voltage Figure 68 Typical application diagram 2 phase overcurrent relay Type KCGG 120 291 93eq Phase rotation 13 AC DC e ez supply 14 Vx e gt 2 Case earth 29 gt e Ye t 13 4 1231 32 1 e cs e 26 15 61 1 33 3471 o e 127 17 81 1 35 3671 ce 1 19 101 1237 3871 pak e 28 1539 4021 13 14 D 42d o 43 4471 5 gi 5 47 500 De ad il QD 4 95 97 gt Ll 23 24 Psi 525 sat 25 226 D EC L2 27 E28 e e RN Ogic input common Sic SCNGD Module terminal blocks viewed from rear with integral case earth link Notes 1 a gt CT shorting links make before b disconnect b Short terminals break before Long terminal d Pin terminal pc
195. ks must have inputs allocated to them to enable blocking of phase fault elements It is not necessary for opto inputs to be assigned in masks to elements which do not require blocking Phase fault element Input mask gt INP Blk t gt t gt gt INP Blk t gt gt t gt gt gt INP Blk t gt gt gt Table 6 36 Repeat Tests 6 1 8 5 and 6 1 8 6 for earth faults and Tests 6 1 9 4 and 6 1 9 5 for phase faults with appropriate opto inputs energized and check that the element is correctly blocked and does not operate The test should be repeated on each element that has been allocated a blocking input Undervoltage logic Only directional relays have the undervoltage trip facility To enable this facility PHASE FAULT Function Link 6 must be set to 1 To test the undervoltage logic a single phase voltage must be applied to the relay When the voltage falls below the threshold setting V lt the timer tV lt will be energized and when it times out the selected output relay in relay mask RLY tV lt will pick up When the applied voltage exceeds the threshold setting V lt the output relay will instantaneously reset The setting value for V lt and tV lt can be found in the PHASE FAULT heading of the menu The length of the delay measured should be within tV lt 0 5 0 02 to 0 05 seconds and the voltage at which the relay operates should be within 10 of the V lt setting Note Ifa three phase vol
196. l production relays will have the reference voltage rating marked as Vn 110V and for later models this will be marked 57 120V The voltage rating and operational range is the same for both marked ratings and the only difference is in the label affixed to the relay Page 94 5 19 Frequency response The operating criteria for each element have been chosen to suit the applications for which it is most likely to be used Knowing how these elements respond under operating conditions will help to apply them effectively 1 Fp when non frequency tracking 45 lt F lt 65Hz when frequency tracking Fourier filter response Anti aliasing filter response Harmonic Figure 37 Response of Fourier filtering Measurement is based on the Fourier derived value of the fundamental component of current and Figure 37 shows the frequency response that results from this filtering The 1 on the horizontal scale relates to the selected rated frequency of the relay and the figures 2 3 4 etc are the second third and fourth harmonic frequencies respectively It can be seen that harmonics up to and including the 6th are suppressed giving no output The 7th is the first predominant harmonic and this is attenuated to approximately 3046 by the anti aliasing filter For power frequencies that are not equal to the selected rated frequency ie the frequency does not coincide with 1 on the horizontal scale the harmonics will not be
197. l protection settings are protected from change when the relay cover is in place Entering passwords The and keys can be used to select a character at the position of the cursor When the desired character has been set the F key can be given a momentary press to move the cursor to the position for the next character The process can then be repeated to enter all four characters that make up the password When the fourth character is acknowledged by a momentary press of the F key the display will read Are You Sure 1 Press 0 key if you decide not to enter the password 2 Press the key if you want to modify the entry 3 Press the to enter the password The display will then show four stars and if the password was accepted the alarm LED will flash If the password is not accepted a further attempt can be made to enter it or the 0 key used to escape Password protection is reinstated when the alarm LED stops flashing fifteen minutes after the last key press or by selecting a column heading or the PASSWORD cell and pressing the 0 key for more than one second Changing passwords After entering the current password and it is accepted as indicated by the alarm LED flashing the F key is pressed momentarily to move to the next menu cell If instead it is required to enter a new password the key must be pressed to select the setting mode A new password can be entered with
198. larm that causes the ALARM LED to flash and this indicates that the password has been entered to allow access to change protected settings within the relay This is not generally available as a remote alarm and the alarm flags do not change No control will be possible via the key pad if the Unconfigured alarm is raised because the relay will be locked in a non operate state Default display LCD The LCD changes to a default display if no key presses are made for 15 minutes The default display can be selected to any of the options listed in Section 3 2 11 LOGIC FUNCTIONS location 090 by following the setting procedure given in Section 3 2 5 The display can be returned to the default value without waiting the fifteen minute delay by selecting any column heading and then holding the 0 reset key depressed for 1 second When the protection trips the display changes automatically to display the fault flags The trip LED indication may be reset by pressing the 0 key whilst they are displayed otherwise see Section 3 3 10 Selective Features and Logic In this section the scheme logic is broken down into groups which are described individually The logic is represented in a ladder diagram format and the key to the symbols used is shown in Figure 4 Contacts have been used to represent the output of the various protection and control functions even though they are actually implemented in software The contacts are all shown in t
199. ll receive some attenuation from the anti aliasing filter as shown in Figure 37 Time delayed outputs can be obtained from the undercurrent elements via the auxiliary timers The undercurrent feature can be an indication of loss of critical loads and using an inverted undercurrent signal an additional fourth overcurrent definite time stage can be arranged Overcurrent logic The overcurrent logic is shown in Figure 7 This diagram and the description following applies equally to the earth fault logic When the current threshold I gt is exceeded and output is directed to the RLY I gt mask this will result in the output relay s designated by the mask being energized Provided no control is being asserted by the input assigned to the INP Blk t gt mask and the I gt is exceeded the timer t gt will run When t gt times out the output relay assigned in the RLY t gt mask will be energized and close its contacts If at any time during the timing cycle the assigned control input is energized timer t gt will be blocked and reset to zero when the reset time has expired The second overcurrent function I gt gt is selected by the phase fault link PF1 for earth faults gt gt by EF1 There is no start function associated with the gt gt setting only a trip output from the following timer t gt gt External control can be asserted over this time delay by the control input assigned by the input mask INP Blk t gt gt and the output r
200. maximum length of 1000m Connection to the K Bus Port is by standard Midos 4mm screw terminals or snap on connectors A twisted pair of wires is all that is required the polarity of connection is not important It is recommended that an outer screen is used with an earth connected to the screen at the Master Station end only Termination of the screen is effected with the U shaped terminal supplied and which has to be secured with a self tapping screw in the hole in the terminal block just below terminal 56 see Figure 28 Operation has been tested up to 1 000 metres with cable to DEF Standard 16 2 2c 16 0 2mm dia 40mQ2 m per core 171pf m core core 288pf m core screen The minimum requirement to communicate with the relay is a K Bus IEC60870 5 converter box type KITZ and suitable software to run on an IBM or compatible personal computer Three versions of the KITZ are available KITZ101 z AC Powered version KITZ102 DC Powered version KITZ103 K Bus to Interface unit These units are further described in publication R6521 Note K Bus must be terminated with a 150Q resistor at each end of the bus The master station can be located at any position but the bus should only be driven from one unit at a time Page 65 35452 3 7 2 3 Figure 28 Terminal arrangement for communications Protection Access Software The Protection Access Software amp Toolkit is a dedicated applicat
201. mmunications port 27 228 e 56 2 Logic input common 1 Module terminal blocks 7 viewed from rear e with integral case earth link 448V field volt Exc 1eld voltage Notes 1 a CT shorting links make before b and c disconnect b Short terminals break before c Long terminal d Pin terminal pcb type 2 CT connections are typical only 3 Earth connections are typical only Figure 84 Typical application diagram sensitive earth fault relay Type KCGU 110 611 9 4 2 pi P2 Pl i JAM S AC DC e WD gt Relay healthy supply a LLL C V 315 WD 5 gt Relay failed 30 u N RLO gt 32 5 Phase rotation 252 RLI 364 E 3 PEN e Case earth RL2 e ji 3 e 29 30 4 0 7 e 3 ei bai at iw 2M oo 2915 e cs e 364 RL4 314 19 101 1537 38 1 0 91 05 009 KCGU 140 2 E TEEI G bal 44 RLS 35 5 gt 1 43 4471 1 2 albo 4 Vus 467 46 RL6 i 4 204 Dis ag 10 0 5 pue SH 101 21 0 27 al 5 7 23 24 iy 24 RL7 43 gt Bx De
202. n and load shedding by either voltage reduction or by load rejection Note if it is considered essential that it must not be possible to perform certain of these remote control functions they can be inhibited by setting software links in the relay These links are password protected see Section 3 3 1 Notes on security of remote control via the serial port Access to the memory of the relay is restricted to that addressed via the menu system of the relay In addition all setting changes are reflexed back to the Master Station Page 59 3 7 1 4 3 7 1 5 3 7 1 6 for verification before the EXECUTE command is issued On reception of the EXECUTE command the new setting is checked against the limits stored in the relay before they are entered Only then does the relay respond to the new setting All remote commands are reflexed back to the Master Station for verification before they are executed and any command left set is automatically rejected if not executed within the timeout period No replies are permitted for global commands as this would cause contention on the bus instead a double send is used for verification purposes with this type of command Remote control is restricted to those functions that have been selected in the relay s menu table and the selection cannot be changed without entering the password CRC and message length checks are used on each message received No response is given for received messages with a detec
203. n a value that varies with the measured quantity it should be added to the poll list as described in R8514 the User Manual for the Protection Access Software amp Toolkit Page 134 6 2 6 2 6 2 6 3 6 2 7 6 2 7 1 6 2 7 2 Relay no longer responding Check if other relays that are further along the bus are responding and if so power down the relay for 10 seconds and then re energize to reset the communication processor This should not be necessary as the reset operation occurs automatically when the relay detects a loss of communication If relays further along the bus are not communicating check to find out which are responding towards the master station If some are responding then the position of the break in the bus can be determined by deduction If none is responding then check for data on the bus or reset the communication port driving the bus with requests Check there are not two relays with the same address on the bus No response to remote control commands Check that the relay is not inhibited from responding to remote commands by observing the system data function link settings If so reset as necessary a password will be required System data function links cannot be set over the communication link if the remote change of settings has been inhibited by setting system data function link 00 to 0 Reset SDO to 1 manually via the user interface on the relay first Relay is not identified in the Circuit Breaker Cont
204. n allocated then an external time interval meter must be connected so that it starts when the opto isolated input is energized and stops when the relay allocated by the relay mask RLY tAUX2 operates the PHASE FAULT function link PH7 is set to 1 then the timer will be energized via the undercurrent element when an undercurrent condition exists The time interval meter must therefore be started when the current is removed and it must be stopped when the relay selected by the mask RLY Aux2 operates The measured time delay should be within the set time tAUXI 0 5 0 02 to 0 05 seconds 6 1 10 4 3 Timer Aux3 If the LOGIC function link LOG3 is set to 1 or the input mask INP Aux3 has been allocated an input then auxiliary timer 3 should be tested There are two ways of testing the timer depending on the relay s settings Tf the input mask INP Aux3 has been allocated then an external time interval meter must be connected so that it starts when the opto isolated input is energized and stops when the relay allocated by the relay mask RLY tAUX3 operates Tf the LOGIC function link LOG3 is set to 1 then the timer tAUX3 will be energized via the undercurrent element when the undercurrent threshold is exceeded ie an overcurrent condition The time interval meter must therefore be started when the current is applied and it must be stopped when the relay selected by the mask RLY Aux2 operates The measured
205. n or reading EVENT RECORDS via the communication port Note When LOG7 is set to 1 a fault record will be recorded under start conditions An event will only be logged if a start contact has been allocated Note On single pole and two pole relays where only four output relays are fitted it is still possible to allocate relays 4 to 7 in the relay masks This will not actually cause an output relay to operate but an output to relay RLY7 can be used to initiate the updating circuit breaker maintenance data without initiating a trip or autoreclose sequence An external signal will need to be routed to RLY7 via an opto input in mask INP Aux1 INP Aux2 or INP Aux3 with the respective auxiliary time delay set to zero Page 46 3 5 3 5 1 Bo 3 5 2 1 An event record will be triggered when the opto input is energized but a fault record will not result unless relay RLY3 is initiated LOG7 is set to 0 The disturbance recorder may also be initiated from the same opto input if required Initiate breaker fail Generate fault record Relay 3 p gt Latch trip led Relay 7 Log fault current Log CB data LOG7 Latch fault flags Start 1 gt gt Note Remote trip does not initiate breaker fail but it does latch the flags Relay 7 Figure 20 Selectable flag logic Configuration Configuration is the act of selecting from the available options those that are required for the application
206. n the case Do not expose them to risk of damage by withdrawing modules unnecessarily Each module incorporates the highest practicable protection for its semiconductor devices However if it becomes necessary to withdraw a module the precautions should be taken to preserve the high reliability and long life for which the equipment has been designed and manufactured 1 Before removing a module ensure that you are at the same electrostatic potential as the equipment by touching the case 2 Handle the module by its frontplate frame or edges of the printed circuit board Avoid touching the electronic components printed circuit track or connectors 3 Do not pass the module to another person without first ensuring you are both at the same electrostatic potential Shaking hands achieves equipotential 4 Place the module on an antistatic surface or on a conducting surface which is at the same potential as yourself 5 Store or transport the module in a conductive bag Page 11 1 3 14 1 5 If you are making measurements on the internal electronic circuitry of an equipment in service it is preferable that you are earthed to the case with a conductive wrist strap Wrist straps should have a resistance to ground between 500k 10M ohms If a wrist strap is not available you should maintain regular contact with the case to prevent a build up of static Instrumentation which may be used for making measurements should be earthed to the
207. ng changed Confirmation display Confirms setting and enters new value Returns prospective value of setting for checking and further modification Escapes from the setting mode without the setting being changed Table 6 2 Page 98 6 1 1 2 6 1 1 3 6 1 1 4 6 1 1 5 6 1 1 6 6 1 1 7 6 1 1 8 Terminal allocation Reference should be made to the diagram supplied with every relay The diagram number will be found on the label fixed inside the case to the left hand side Section 3 6 of this document provides useful notes on connections to the relay Electrostatic discharge ESD See recommendations in Section of this user manual before handling module outside its case Inspection Carefully examine the module and case to see that no damage has occurred since installation and visually check the current transformer shorting switches in the case are wired into the correct circuit and are closed when the module is withdrawn Check that the serial number on the module case and cover are identical and that the model number and rating information are correct Check that the external wiring is correct to the relevant relay diagram or scheme diagram The relay diagram number appears inside the case on a label at the left hand side The serial number of the relay also appears on this label the inside of the cover and on the front plate of the relay module The serial numbers marked on these three items sh
208. nication Where fibre optic communication devices are fitted these should not be viewed directly Optical power meters should be used to determine the operation or signal level of the device Cleaning The equipment may be cleaned using a lint free cloth dampened with clean water when no connections are energised Contact fingers of test plugs are normally protected by petroleum jelly which should not be removed Safety Section 7 1 7 2 7 3 Pxxxx EN 55 1 1 7 10 DECOMMISSIONING AND DISPOSAL Decommissioning The supply input auxiliary for the equipment may include capacitors across the supply or to earth To avoid electric shock or energy hazards after completely isolating the supplies to the equipment both poles of any dc supply the capacitors should be safely discharged via the external terminals prior to decommissioning Disposal It is recommended that incineration and disposal to water courses is avoided The equipment should be disposed of in a safe manner Any equipment containing batteries should have them removed before disposal taking precautions to avoid short circuits Particular regulations within the country of operation may apply to the disposal of batteries EQUIPMENT WHICH INCLUDES ELECTROMECHANICAL ELEMENTS AN A A Electrical adjustments It is possible to change current or voltage settings on some equipment by direct physical adjustment e g adjustment of a plug bridge sett
209. not interfere with communications on existing installations The communication address can be manually set by selecting the appropriate cell for the SYSTEM DATA column entering the setting mode as described in Section 3 3 and then decrementing or incrementing the address It is recommended that the user enters the plant reference in the appropriate cell and then sets the address manually to 0 The master station will then detect that a new relay has been added to the network and automatically allocate the next available Page 29 3 3 7 3 3 8 3 3 9 3 3 10 3 3 11 address on the bus to which that relay is connected and communications will then be fully established Setting control input masks An eight bit mask is allocated to each protection and control function that can be influenced by an external input applied to one or more of the opto isolated control inputs When an input mask is selected the text on the top line of the display indicates the associated control function and the bottom line of the display shows a series of 1 s and 0 for the selected mask The numbers printed on frontplate under the display indicate the number of the control input L7 to LO that is being displayed A 1 indicates that a particular input will effect the displayed control function and a 0 indicates that it will not The same input may be used to control more than one function Setting relay output masks An eigh
210. nt current into the relay to cause the element to operate at the customer s current setting The relay selected for the gt gt trip can be found under the RELAY MASKS heading in RLY to gt gt To prevent sustained application of excessive current the trip output contacts for to gt gt should be connected to trip the test set The time delay to gt gt should be set to less than 0 1 second for the test and restored to its original value when the test has been completed When the setting is above the continuous current rating of the relay DO NOT INCREASE THE CURRENT SLOWLY since this may damage the relay before it can operate Instead the current level should be set and then suddenly applied Two tests are specified in Table 6 14 for the particular current setting required for the application Initially the higher current level should be applied to check that the instantaneous element operates and then the lower current level should be applied to check that no trip occurs Page 108 6 1 6 5 6 1 7 1 6 1 7 2 TRIP Io gt gt Io NO TRIP gt gt Io 1 05 x current setting 0 95 x current setting Table 6 14 If the lo gt gt gt threshold is to be used by the customer then the EARTH FAULT function link 2 should be set to 1 Test 6 1 6 4 can then be repeated for Io gt gt gt but only if the test set available can inject sufficient current into the relay to cause the element to operate
211. nt relay on the outgoing feeder which is carrying the fault current The circuit carrying the fault current will be tripped by the overcurrent relay on that circuit In the event of any relay on the outgoing circuits becoming defective the watchdog repeat relay drops off to give an alarm and to transfer the t gt gt trip from the incoming circuit breaker to the buswire connected via the watchdog break contact of each relay on the outgoing feeders to the appropriate circuit breaker Thus the trip will be transferred to the circuit breaker with the failed relay and so a fault on that circuit will be cleared without tripping the busbar For a busbar fault the incoming circuit breaker will be tripped by gt gt gt after a short delay For faults on any healthy outgoing feeder both gt gt and gt gt gt of the incoming feeder will be blocked and correct discrimination will be obtained with only the faulted feeder being tripped Page 77 4 6 4 7 4 7 1 Watchdog 1 repeat relay Trip relays Incomer Incomer Feeder X Feeder 2 Me X X X X Feeder Feeder Feeder Feeder Feeder 4 1 2 3 4 Watchdog Watchdog contacts contacts Figure 33 Back up transfer tripping Restricted earth fault Where back up overcurrent or differential protection does not provide adequate earth fault coverage of the secondary winding of a transformer and where the winding of a med
212. o 1 and to deselect it link SD1 must be set to 0 Output relays must be selected via the RLY CB Trip and RLY CB Close masks to perform the circuit breaker control duty A relay may have already been selected in this mask for remote control of the circuit breaker If there are no spare output relays for this purpose then the main trip relay may be selected An indication is required that the circuit breaker was closed before the trip command was received otherwise the circuit breaker will not close to restore load when the appropriate command level is received A control input must therefore be assigned via INP CB Closed input mask Global load shed Load shed logic Trip Close tRestore i Close CB INP CB Closed Figure 18 Load shedding by load rejection Page 45 3 4 12 3 4 13 Load shedding by voltage reduction Three of the output relays can be allocated via the RLY Reduct 1 RLY V Reduct 2 RLY V Reduct 3 output masks to give three stages of load shedding Typically these outputs would be used to control the load shedding settings of a voltage regulating relay such as a type MVGC The relays allocated via these masks will respond to load shedding commands received via the serial communication port and the stage of load shedding to which the relay is responding can be viewed under the SYSTEM DATA heading of the menu see Section 3 2 2
213. o delete all fault records the next cell after Fn 4 must be selected This cell will read FLT clear records 0 and to complete the reset action the 0 key must be held depressed for more than 1 second The only settings which can be changed with the cover in place are those that can be reset either to zero or some preset value To change any other settings the cover has to be removed from the relay to gain access to the and keys that are used to increment or decrement a value When a column heading is displayed the key will change the display to the next column and the key will change the display to the previous column giving a faster selection When a cell containing a relay setting is displayed the action of pressing either the or keys will indicate to the relay that a value is to be changed and a flashing cursor will appear on the display To escape from the setting mode without making any change the 0 key should be depressed for one second Password protection is provided for the configuration settings of the relay This includes time curve selection set CT and VT ratios function link settings opto input and relay output allocation Any accidental change to configuration could seriously affect the ability of the relay to perform its intended functions whereas a setting error may only cause a grading problem Individual protection settings are protected from change when the relay cover is in place
214. o ordinating a number of relays and where there is great variation in fault current between relay locations EI20XDT extremely inverse curve becomes constant time at 20x setting Main use is for grading with downstream fuses and upstream overcurrent relays on distribution and industrial systems The relay maintains its very inverse characteristic to higher current levels than electro mechanical relays and therefore provides for closer grading with the fuse characteristic Page 68 4 2 4 2 1 EI10XDT extremely inverse curve becomes constant time at 10x setting This relay is also for use in grading with downstream fuses and upstream overcurrent relays on distribution and industrial systems However the change to definite time at the lower current level of 10 times setting will be particularly useful where more than one relay has to be co ordinated because it will allow additional time grading steps to be used at the high current levels This curve grades more closely with the characteristic of electro mechanical relays because of the earlier cut off Note the current measurement is linear to 820 times minimum setting and hence curves that become definite time above 20 times setting may tend to definite time at a lower multiple of setting given by 5 820 x minimum settable value actual setting selected IDTM relay co ordination Inverse definite minimum time relays are time graded such that the relay nearer to
215. of the relay functions can be read reset and changed on demand from a local or remote personal computer PC loaded with the relevant software KCGG amp KCGU relays provide overcurrent and earth fault protection for power distribution systems industrial power systems and all other applications where overcurrent protection is required The relays are used in applications where time graded overcurrent and earth fault protection is required The KCGU provides sensitive earth fault protection for systems where the earth fault current is limited Page 13 2 3 amp KCEU relays provide directional overcurrent and earth fault protection The overcurrent elements can be selectively directionalised making the relays a cost effective option where both directional and non directional protection is required The directional sensitive earth fault protection provided by the KCEU relay is particularly suitable for systems where the earth fault current is severely limited Integral features in the K Range relays include circuit breaker failure protection backtripping blocked overcurrent protection for feeders or busbars cold load pick up facilities load shedding capabilities and two alternative groups of predetermined settings The relays also have integral serial communication facilities via K Bus Models available The following list of models are covered by this manual KCGG 110 KCGG 210 KCGG 120 KCGG 130 KCGG 230 KCGG 140 KCGG 240
216. on connection diagrams are the convention of forward current flow from the busbar to the feeder This will correspond to positive values of active power flowing from the busbar to the feeder However alternative methods of signing the direction of power flow are provided and may be selected to suit a particular application or user s standards The mode for signing the direction of active and reactive power is provided in menu cell 031E in the MEASUREMENTS 2 column of the menu Lagging KVARs to busbar Mode 0 VAR Mode 1 VAR Mode 2 VAR Mode 3 VAR Power to busbar Power to feeder Mode 0 W V Mode 0 W Mode 1 W Mode 1 W Mode 2 W Mode 2 W Mode 3 W Mode 3 W Lagging KVARs to feeder Mode 0 VAR Mode 1 VAR Mode 2 VAR Mode 3 VAR When the relay is connected for forward power flow to the feeder then Mode 0 Nett Export signing nett export of power and negative VARs Mode 1 Reversed direction power flow to busbar in a jb form Mode 2 Normal direction power flow to feeder in a jb form Mode 3 Nett import signing nett import of power and negative VARs As a safeguard against accidental change the mode cell is password protected Earth fault 1 SET 0501 EFI Fn Links Earth fault function links PWP Link 1 EF1 Enablelo gt gt 1 enable gt gt Link 2 EF1 Enablelo gt gt gt 1 enable gt gt gt Link 3 EF1 Dirn to 1 1 di
217. onnected as a shunt repeat relay the protection will trip the circuit breaker directly and then be backed up by the contacts of the interposing relay On breaking the protective relay will reset first so that the interposing relay performs the actual circuit interruption As shown in Figure 22 Similarly the breaking duty of the relay contacts may not be rated for the circuit breaker closing current and in such cases an interposing relay will be necessary Page 55 3 6 6 3 6 6 1 3 6 6 2 CG4 blocking diode KCGG O P Figure 22 Contact re inforcing Alternative trip arrangements DC shunt trip Auxiliary powered relays require an auxiliary supply to trip the circuit breakers This will normally be a dc supply which is generally considered to be more secure than an ac supply It would be usual to use a shunt trip coil for dc energized trip circuits The trip circuit current will normally be broken by an auxiliary contact on the circuit breaker once the circuit breaker has opened If this is not the case then a trip relay with heavy duty contacts must be interposed between the contact of RLY3 and the trip coil As shown in Figure 23 Figure 23 DC shunt trip arrangement AC no volt trip For ac tripping it may be considered safer to opt for a no volt trip release Tripping from a make contact on the relay is still possible by using the circuit shown in Figure 2
218. onnections to the equipment must have a defined potential Connections that are pre wired but not used should preferably be grounded when binary inputs and output relays are isolated When binary inputs and output relays are connected to common potential the pre wired but unused connections should be connected to the common potential of the grouped connections Before energising the equipment the following should be checked Voltage rating polarity rating label equipment documentation CT circuit rating rating label and integrity of connections Protective fuse rating Integrity of the protective conductor earth connection where applicable Voltage and current rating of external wiring applicable to the application Equipment Use If the equipment is used in a manner not specified by the manufacturer the protection provided by the equipment may be impaired Removal of the equipment front panel cover Removal of the equipment front panel cover may expose hazardous live parts which must not be touched until the electrical power is removed UL and CSA Listed or Recognized Equipment To maintain UL and CSA approvals the equipment should be installed using UL and or CSA Listed or Recognized parts of the following type connection cables protective fuses fuseholders or circuit breakers insulation crimp terminals and replacement internal battery as specified in the equipment documentation Equipment operating condi
219. operation dangerous voltages will be present in certain parts of the equipment Failure to observe warning notices incorrect use or improper use may endanger personnel and equipment and cause personal injury or physical damage Before working in the terminal strip area the equipment must be isolated Proper and safe operation of the equipment depends on appropriate shipping and handling proper storage installation and commissioning and on careful operation maintenance and servicing For this reason only qualified personnel may work on or operate the equipment Qualified personnel are individuals who e are familiar with the installation commissioning and operation of the equipment and of the system to which it is being connected e are able to safely perform switching operations in accordance with accepted safety engineering practices and are authorised to energize and de energize equipment and to isolate ground and label it e are trained in the care and use of safety apparatus in accordance with safety engineering practices e are trained in emergency procedures first aid The operating manual for the equipment gives instructions for its installation commissioning and operation However the manual cannot cover all conceivable circumstances or include detailed information on all topics In the event of questions or specific problems do not take any action without proper authorization Contact the appropriate AREVA technical
220. option key to execute command After executing the close command the output relay assigned to close the circuit breaker by the CB Close relay mask will operate for the close time delay tCLOSE During the close test the status of this relay should be monitored to ensure it operates correctly On load tests There are some tests that may be carried out with the circuit on load provided there are no operational restrictions in force that prohibit this On load measurement checks Measure the secondary CT currents and if applicable the secondary VT voltages Compare the values of the secondary quantities with the relay s measured values which can be found in MEASUREMENTS 1 If the CT and VT ratios are set to 1 1 then the values will be within 5 of the secondary quantities if the CT and VT ratios are not set to 1 1 then the measurement values will be equal to the secondary values multiplied by the appropriate transformer ratios On load directional check Check the relay is wired correctly to the system diagram Measure that the secondary VT voltage is correct and check with a phase rotation meter that the system phase rotation is correct Page 127 Check that the CT polarities are correct and that the current flowing in the neutral circuit of the current transformers is negligible 6 1 11 2 1 Phase fault directional elements KCEG 130 140 and KCEU 130 140 Check the magnitude and direction of flow of the load current
221. or 80ms for non directional relays These time delays are for worst case conditions and may be reduced depending on the system X R and maximum fault level The time delays t gt gt to gt gt are arranged to be blocked by the START contacts of the downstream relay when the downstream relay detects a fault current flowing The short time delay is essential to ensure that the blocking signal will be received by the upstream relay before operation can occur The inverse time overload elements should be graded in the normal way for cascade operation and to provide an overload feature and backup protection The short time Page 69 4 2 2 elements operating in the non cascade mode then provide an instantaneous zone of protection and again the breaker fail feature can be used to advantage Overcurrent relays are adequate for non cascade operation on radial circuits but for ring circuits or where there are parallel feeds it will be necessary to use directionalized overcurrent relays 80ms gt 80ms Hi T Figure 29 Non cascade operation Protection for busbars on radial systems This is simply achieved on radial circuits by setting the short time lags t gt gt to gt gt of the relay on the incoming feeder to the busbar to 200ms for relays with directional elements or 80ms for non directional relays and blocking these time delays when the START element of any relay on the load circuits detects fault current
222. ose inhibition of instantaneous low set When overcurrent relays from the Midos K Range are used with autoreclose relays the I gt gt Io gt gt elements may be used as low set instantaneous elements The associated time delays t gt gt to gt gt would be set to zero seconds to effect rapid fault clearance Although the timer is set to zero its output still may be blocked via one of the control inputs to the relay on successive autoreclose cycles to inhibit the instantaneous trip element Blocking the element instead of the trip path with a contact of the autoreclose relay will ensure correct flagging at all times Where lightning strikes are frequent it can be an advantage to make the I gt gt Io gt gt setting equal to I gt Io gt in order to detect the maximum number of transient faults Additional fourth overcurrent stage As described in Section 3 4 5 auxiliary timer 3 tAUX3 can be used in conjunction with the undercurrent element to provide a fourth time delayed overcurrent and earth fault stage If I lt is set to a low threshold value the output can be used as an alarm to Page 79 4 7 4 4 71 5 indicate current flow in the feeder With the threshold set above load current an additional overcurrent stage is available for shaping the overall time current characteristic of the relays This stage may suffer from transient overreach when very low time settings are applied Cold load start pick up for grading with motor st
223. osvo Sxoo q o hpo A uoururoo 21807 TONIS K 80 T los coy e e MGE 4 IPS 9c 5 sc e 1 6 ISI 5k C De gl j 6 1 08 6t CC 5 87 71 T CT J 19 C Ue a 3 515 STA Ore gt 2 e 207 b I 1107 6 e cs lt 158 1571 101 61 e ces 1295 18 LI e ce d di IK 54 ose 0018301 aseyd d Aey lt dry jddng por fero 1 xAK ddns Page 180 OLI NAON 2951 uuo oAnrsues euonoourp ure18erp eordA 7 9 K uo eordA ywq c 021443 Lo purua 8107 5 2 seua 11046 9 q i 4 sxurp 8 1104 LO 1 18910 i T uowwos jndur
224. ould match the only time that they may not match is when a failed relay module has been replaced for continuity of protection With the relay removed from its case ensure that the shorting switches between terminals listed below are closed by checking with a continuity tester Terminals 21 22 23 24 25and26 27 28 Earthing Ensure that the case earthing connection above the rear terminal block is used to connect the relay to a local earth bar and where there is more than one relay the copper earth bar is in place connecting the earth terminals of each case in the same tier together Main current transformers DO NOT OPEN CIRCUIT THE SECONDARY CIRCUIT OF A LIVE CT SINCE THE HIGH VOLTAGE PRODUCED MAY BE LETHAL TO PERSONNEL AND COULD DAMAGE INSULATION Test block If the MMLG test block is provided the connections should be checked to the scheme diagram particularly that the supply connections are to the live side of the test block coloured orange and with the terminals allocated odd numbers 1 3 5 7 etc The auxiliary supply is normally routed via terminals 13 and 15 but check against the schematic diagram for the installation Insulation Insulation tests only need to be done when required Isolate all wiring from the earth and test the insulation with an electronic or brushless insulation tester at a dc voltage not exceeding 1000V Terminals of the same circuits should be temporarily strap
225. pe 2 CT connections are typical only 3 Earth connections are typical only LO Logic input common LS L6 L7 Logic input common 2 46 E sk KCEG 130 42 gt Relay healthy gt Relay failed Case earth connection K bus communications port 48V field voltage Figure 75 Typical application diagram 3 phase directional overcurrent relay Type KCEG 130 OLI Direction of forward current flow m B e P2 Pl lt AC DC supply 14 L Vx 5 WD 6 Relay healthy A gt e LLL Lc E 3 ai E WD 5 gt Relay failed Phase rotation 30 RLO 22 gt 34 36 gt 38 1 Case earth RL2 gt 40 1 52 30d KCEG 130 212 p e 13 4 131 322 cs RL3 44 gt 15 6 Ps me LLL e cs e 2912 17 81 1235 36 1 ces bj
226. ped together The main groups on the relays are given below but they may be modified by external connection as can be determined from the scheme diagram Page 99 6 1 2 6 1 2 1 a Current transformer circuits b Voltage transformer circuits c Auxiliary voltage supply and capacitor discharge circuit on 200 series relays d Field voltage output and opto isolated control inputs e Relay contacts f Communication port g Case earth Note Do not apply an insulation test between the auxiliary supply and the capacitor discharge terminals because they are part of the same circuit and internally connected Commissioning test notes Commissioning the relay with its calculated application settings Relay Model Auxiliary powered Test 6 1 3 1 Dual powered Test 6 1 3 2 Earth fault element Test 6 1 6 Sensitive earth fault element Test 6 1 6 Phase fault element Test 6 1 7 Directional earth fault element Tests 6 1 8 amp 6 1 11 2 1 Directional phase fault element Tests 6 1 9 amp 6 1 11 2 2 Dual polarized earth fault element Tests 6 1 6 amp 6 1 11 2 1 Wattmetric element Tests 6 1 12 KCGG 110 KCGG 120 KCGG 130 KCGG 140 79 KCGG 210 KCGG 230 KCGG 240 KCGU 110 KCGU 140 KCGU 240 KCEG 110 KCEG 130 KCEG140 KCEG 150 KCEG 160 Ulm Ul tm
227. ply and check that the relay restrains Directional relays 20 9 gt 440V 60V 27 Current injection 15 test set 28 Figure 46 Connection diagram for KCEU141 241 Problem solving Password lost or not accepted Relays are supplied with the password set to AAAA Only uppercase letters are accepted Password can be changed by the user see Section 3 3 There is an additional unique recovery password associated with the relay which can be supplied by the factory or service agent if given details of its serial number The serial number will be found in the system data column of the menu and should correspond to the number on the label at the top right hand corner of the frontplate of the relay If they differ quote the one in the system data column Protection settings Settings for highsets not displayed Set function link PF1 to 1 to turn on settings I gt gt t gt gt Set function link PF1 to 1 to turn on settings I gt gt gt t gt gt gt Set function link EFI to 1 to turn on settings Io to Set function link EFI to 1 to turn on settings lo gt gt gt to gt gt gt Second setting group not displayed Set function link SD4 to 1 to turn on the group 2 settings Function links cannot be changed Enter the password as these menu cells are protected Links are not selectable if associated text is not displayed Page 131 6 2 2 4 6 2 3
228. polarized from the voltage source alone If the voltage signal is below the threshold the current signal is used to polarize the relay provided it exceeds the current threshold Ip gt When neither polarizing signal is above its threshold the relay is blocked from operating Directional stability for instantaneous elements The directional information is calculated every 20ms on the last eight samples of the waveform from the analogue digital converter The first directional calculation after Page 74 44 4 4 1 the fault inception may be based on one or more of the samples that were captured before the fault Hence the phase information will contain an element of uncertainty However subsequent calculations will be based on eight samples captured from the fault and operation will be correct Therefore to ensure directional stability of the instantaneous elements during transitional conditions such as the one described the associated time delays t gt gt t gt gt gt to gt gt and to gt gt gt should be set to give a delay of between 40 and 200ms depending on the system X R and maximum fault level In directional blocking schemes for example those for providing busbar protection there will already be other requirements for a delay setting Application notes for dual powered relays Powered from current transformers alone When powered from the current transformer circuit alone the minimum current to operate the relay is that
229. position A third opto input may be used to indicate when the circuit breaker is connected to the second busbar in a two busbar system and is assigned by the INP CB to Bus2 input mask When this input is energized the circuit breaker positional information is directed to the two bits in the Plant Status Word for CB2 The two input masks INP LClose CB and INP LOpen CB assign control inputs for local initiation of the close and trip pulse timers for the circuit breaker Manual closure of the circuit breaker via the relay will ensure that closure does not take place unless the relay is operative It should be noted that by tripping the circuit breaker via this path a remote trip indication RT will be recorded Trip and close test facility If the relay is configured for remote control of the circuit breaker then a trip or close test can be carried out from the SYSTEM DATA column of the menu The control buttons on the front of the relay provide an input to the trip and close pulse timers in parallel with the INP LClose CB and INP LTrip CB masks If the relay is not configured for remote control of the circuit breaker then the output relays used for protection trips will need to be assigned in the RLY CB Trip mask before the trip test will operate Load shedding by tripping less essential loads The relay is capable of responding to global load shedding commands via the communication port To select this option link SD1 must be set t
230. presence of event and disturbance records for collection Page 64 3 7 2 1 Serial communication port K Bus Each relay in the K Range has a serial communication port configured to K Bus Standards K Bus is a communication interface and protocol designed to meet the requirements of communication with protective relays and transducers within the power system substation environment It has to be as reliable as the protective relays themselves and must not result in their performance being degraded in any way Hence error checking and noise rejection have been major concerns in its design The communication port is based on RS485 voltage transmission and reception levels with galvanic isolation provided by a transformer A polled protocol is used and no relay unit is allowed to transmit unless it receives a valid message without any detected error addressed to it Transmission is synchronous over a pair of screened wires and the data is FMO coded with the clock signal to remove component so that the signal will pass through transformers This method of encoding the data results in the polarity of the connection to the bus wiring being unimportant With the exception of the Master Units each node in the network is passive and any failed unit on the system will not interfere with communication to the other units The frame format is HDLC and the data rate is 64kbits s Up to 32 units may be connected to any bus at any point over a
231. pto each character represents A 1 indicates an energized state and a 0 indicates a de energized state Note opto isolated inputs may be energized from an external 50V battery in some installations Check that this is not the case before connecting the field voltage otherwise damage to the relay may result Controlled blocking of time delay elements These tests should only be done if the particular relay application requires blocking of one or more of the time delay settings associated with the overcurrent elements Typically this will occur in autoreclose schemes when blocking of the instantaneous element is required for certain parts of the autoreclose cycle or in blocking schemes used to provide unit protection such as that to protect a busbar Page 122 6 1 10 3 To perform the earth fault element blocking tests opto isolated inputs must have been allocated for each blocking function Table 6 35 lists which input masks must have inputs allocated to them to enable blocking of earth fault elements It is not necessary for opto inputs to be assigned in masks to elements which do not require blocking Earth fault element Input mask to gt INP Blk to gt to gt gt INP Blk to gt gt to gt gt gt INP Blk to gt gt gt Table 6 35 To perform the phase fault element blocking tests opto isolated inputs must have been allocated for each blocking function Table 6 36 lists which input mas
232. r environment then it must be mounted in a specific cabinet or housing which will enable it to meet the requirements of IEC 60529 with the classification of degree of protection IP54 dust and splashing water protected Pollution Degree Pollution Compliance is demonstrated by reference to safety Degree 2 standards Altitude operation up to 2000 m IEC 61010 1 2001 EN 61010 1 2001 CE MARKING C Compliance with all relevant European Marking Community directives Product safety Compliance demonstrated by reference to Low Voltage Directive 73 23 EEC safety standards amended by 93 68 EEC EN 61010 1 2001 EN 60950 1 2001 EN 60255 5 2001 IEC 60664 1 2001 Electromagnetic Compatibility Directive Compliance demonstrated via the Technical EMC 89 336 EEC amended by Construction File route 93 68 EEC The following Product Specific Standard was used to establish conformity EN 50263 2000 Where applicable The equipment is compliant with Article 1 2 of European directive 94 9 EC It is approved for operation 2 outside ATEX hazardous area It is however approved for connection to Increased Safety Ex motors with rated ATEX protection Equipment Category 2 to ensure their safe operation in gas Zones 1 and 2 hazardous areas ATEX Potentially Explosive CAUTION Equipment with this marking is not itself Atmospheres directive suitable for operation within a potentially explosive 94 9 EC
233. ranges Time setting ranges Directional settings Ratios Accuracy Influencing quantities Opto isolated inputs Contacts Operation indicator Communication port Current transformer requirements High voltage withstand Electrical Environment Page 5 10 10 10 11 11 11 12 12 12 13 14 14 16 26 30 46 50 57 67 67 68 71 14 76 77 77 81 81 81 83 84 85 85 85 87 88 88 89 89 89 90 90 5 16 5 17 5 18 5 19 6 1 6 2 6 3 11 Atmospheric Environment Mechanical Environment Model numbers Frequency response COMMISSIONING Commissioning preliminaries Problem solving Maintenance APPENDIX 1 CHARACTERISTIC CURVES FOR KCGG KCGU KCEG AND KCEU RELAYS APPENDIX 2 LOGIC DIAGRAMS FOR KCGG KCGU KCEG AND KCEU RELAYS APPENDIX 3 CONNECTION DIAGRAMS FOR KCGG KCGU KCEG AND KCEU RELAYS APPENDIX 4 COMMISSIONING TEST RECORD INDEX REPAIR FORM Page 6 91 92 92 94 96 96 130 135 139 147 160 189 201 203 Pxxxx EN SS B1 1 SAFETY SECTION Pxxxx EN SS B1 1 Safety Section Page 1 10 CONTENTS Ti INTRODUCTION 3 2 HEALTH AND SAFETY 3 3 SYMBOLS AND EXTERNAL LABELS ON THE EQUIPMENT 4 3 1 Symbols 4 3 2 Labels 4 4 INSTALLING COMMISSIONING AND SERVICING 4 5 DECOMMISSIONING AND DISPOSAL 7 6 EQUIPMENT WHICH INCLUDES ELECTROMECHANICAL ELEMENTS 7 T TECHNICAL SPECIFICATIONS FOR SAFETY 7 7 1 Protective fuse rating 7 7 2 Protective Class 7 7 3 Installation Category 7
234. re they are exposed to dust or damp This particularly applies to installations which are being carried out at the same time as construction work Storage If relays are not to be installed immediately upon receipt they should be stored in a place free from dust and moisture in their original cartons Where de humidifier bags have been included in the packing they should be retained The action of the de humidifier crystals will be impaired if the bag has been exposed to ambient conditions and may be restored by gently heating the bag for about an hour prior to replacing it in the carton Dust which collects on a carton may on subsequent unpacking find its way into the relay in damp conditions the carton and packing may become impregnated with moisture and the de humidifier will lose its efficiency Storage temperature 25 C to 70 C Page 12 Section 2 INTRODUCTION 2 1 2 2 Using the manual This manual provides a description of the K Range Overcurrent and Directional Overcurrent range of protection relays It is intended to guide the user through application installation setting and commissioning of the relays The manual has the following format Section 1 Handling and Installation Guidance on precautions to be taken when handling electronic equipment Section 2 Introduction An introduction on how to use this manual and a general introduction to the relays covered by the manual Section 3 Relay Description A
235. rectional control of Io Link 4 EF1 to gt gt 1 directional control of gt gt Link 5 EF1 Dirnto gt gt gt 1 directional control of lo gt gt gt Link 7 EF Aux 2 lt 1 enable delayed undercurrent CLS initiation Link 9 Io gt gt NoPeak 1 Io gt gt operates on the Fourier result only Link Rev gt gt gt 1 reverse direction of 10 gt gt gt Page 23 3 2 6 0502 0503 0504 0505 0506 0507 0508 0509 050 050 050 050 050 CT Ratio VT Ratio Charact 1 10 gt to gt TMS toRESET gt gt to gt gt EFI gt gt gt EFI to gt gt gt EFI Char Angle Vop gt Io Ratio of CT supplying earth fault current PWP Ratio of VT PWP Selectable time characteristic PWP Current threshold for selected characteristic Time time multiplier setting Hold up time for timing integration Second current threshold Time delay for second threshold Third current threshold Time delay for third threshold Characteristic angle for directional feature Polarizing voltage threshold Undercurrent Setting Variation for KCEG 160 KCEU 160 relays 050D 050 050 0510 EFI Ip CT Ratio gt Vop gt EFI 10 lt Ratio of CT supplying polarizing current Polarizing current threshold Polarizing voltage threshold Undercurrent setting Variation for KCEU 141 KCEU 24
236. red counters can be incremented by applying a number of secondary injection current pulses to the current inputs of the relay but note that the counter will increment rapidly for large current values The counter for the number of circuit breaker operations can be incremented manually by operating the relay the required number of times The circuit breaker trip time for the last fault cannot be cleared to zero This is to enable the master station to interrogate the relay for this value as a supervisory function The circuit breaker maintenance counters are not incremented when another protection trips the circuit breaker Add a trip input from the protection to an auxiliary input of the relay and arrange for relay RLY3 or RLY7 to operate instantaneously in response to the input Communications Address cannot be automatically allocated if the remote change of setting has been inhibited by function link SDO This must be first set to 1 alternatively the address must be entered manually via the user interface on the relay Address cannot be allocated automatically unless the address is first manually set to 0 This can also be achieved by a global command including the serial number of the relay Relay address set to 255 the global address for which no replies are permitted Measured values do not change Values in the MEASUREMENTS 1 and MEASUREMENTS 2 columns are snap shots of the values at the time they were requested To obtai
237. relays are assigned to this function To inhibit this function do not assign any output relays in the Vreduct masks The command levels received are latched and displayed in this cell Command Level 0 None stages reset Command Level 1 reduct 1 Relay for stage 1 picked up Command Level 2 reduct 27 Relay for stage 2 picked up Command Level 3 reduct 3 Relay for stage 3 picked up When the auxiliary supply to the relay is interrupted the states of the relays that initiate voltage reduction are remembered This ensures that the level of load shedding is not caused to change by momentary interruptions of the auxiliary supply The master station is expected to take care of any operational changes to the load shed level that may have taken place whilst a relay has been out of service by resending the last global load shed command When link SD1 1 it enables load shed tripping in response to commands over the serial port When SD1 0 it prevents load shed tripping in response to such commands over the serial port Example relay set to level 2 Command lt 0 gt None all load shed circuits restored Command lt 1 gt None command below set level Command 2 LS Trip trip in response to command level 2 or greater Command 3 LS Trip no response because already tripped Command lt 1 gt Restoring indication d
238. require levering apart taking care to ease the connectors apart gradually so as not to crack the front pcb card The connectors are designed for ease of assembly in manufacture and not for continual disassembly of the unit Reassemble in the reverse of this sequence making sure that the screen plate is replaced with all four screws securing it c Replacement of auxiliary expansion board This is the second board in from the left hand side of the module Remove the processor board as described above in b Remove the two securing screws that hold the auxiliary expansion board in place Unplug the pcb from the front bus as described for the processor board and withdraw Replace in the reverse of this sequence making sure that the screen plate is replaced with all four screws securing it Replacing output relays and opto isolators PCBs are removed as described in Section 6 3 3 1 b and c They are replaced in the reverse order Calibration is not usually required when a pcb is replaced unless either of the two boards that plug directly on to the left hand terminal block are replaced as these directly affect the calibration Note that this pcb is a through hole plated board and care must be taken not to damage it when removing a relay for replacement otherwise solder may not flow through the hole and make a good connection to the tracks on the component side of the pcb Replacing the power supply board Remove the two screws securin
239. required to establish the power supply rails within the relay Lowering the design value of this parameter increases the burden on the current transformers and the power dissipated within the relay case The limits are therefore a compromise based on these factors Minimum current to power the relay for phase faults 0 4In Minimum current to power the relay for earth faults 0 2In However a combined three phase and earth fault relay will operate with lower earth fault current settings when the load current in the protected circuit is sufficient to power the relay ie greater than 0 4In Settings less than 0 2In are provided for earth faults but they must be used with discretion However settings less than 0 2In should not be used for single pole earth fault relays that are powered from current alone When switching on to a fault the relay will be delayed in operation by the start up time and this delay will need to be taken into account in any grading exercise The delay is the time taken by the processor to initialize its registers read in settings from non volatile memory and perform self checks There will be an additional delay whilst the power supply builds up but this will be less significant when using 0 8 0 6 0 4 Time seconds 1 7 10 70 100 Multiple of minimum current to power the relay Figure 32 Start up time delay Page 75 4 4 2 4 4 3 4 4 5 an inverse time current characteristic as th
240. returned by the relay at the start of every message to signal important data on which the Master Station may be designed to respond automatically The flags contained are 0 1 Disturbance record available for collection Bit 1 1 Plant status changed 2 1 Control status changed Bit3 1 Relay busy cannot complete reply in time 4 1 Relay out of service 5 1 Event record available for retrieval 6 1 Relay alarm indication set Bit7 1 Relay trip indicated set Relay Alarms Available in System Data column of the relay menu at location 0022 The value of this cell is a series of binary flags indicating the alarms as follows 0 1 Relay unconfigured Bit 1 1 Relay uncalibrated 2 1 Setting error detected Bit3 1 service protection out of service Bit4 1 samples Bit5 1 Fourier Plant Status The plant status can be found at menu location 000C and the bits indicate the status of items of plant controlled via the relay they are defined as follows Bit 1 Bit O 0 connected auxiliary contacts faulty 0 CBl open 1 CBI closed 1 1 Auxiliary contacts or wiring faulty Bit 8 Bit9 0 connected auxiliary contacts faulty 0 1 CB2 open 1 CB2 closed 1 1 Auxiliary CB2 contacts or wiring faulty No other bits in this word are used in KCGG KCGU KCEG KCEU relays Page 63 3 7 2 Logic Status
241. rol Menu of the Courier Master Station if two auxiliary circuit breaker contacts have not been connected to opto inputs of the relay to indicate its position via the Plant Status Word Check input mask settings and the connections to the auxiliary contacts of the circuit breaker Output relays remain picked up Relays associated with auxiliary timers Relays with software issue A to F ie relays with model numbers suffixed by A or B will have logic arranged as shown in Publication R8501 Some problems have occasionally been experienced with these relays when using the timer tAUX2 in earth fault only relays Type KCGG110 210 KCGG120 KCGG160 KCGU110 KCEG110 210 KCEG160 KCEU110 and KCEU160 It is unlikely that this timer will be in use because of the limited I O but if it is to be used and you are experiencing a problem please contact our sales department at AREVA T amp D If an output relay is allocated in the output mask RLY Aux2 on any of the listed relays and it is in a continually operated state after the tAUX2 has timed out it can be reset by fitting an alternative EPROM supplied from the factory This will remove the hidden link that is latching the operation but will not in itself make the full modification available to the user To make the modification fully operational the relay will require re configuring to turn on the additional function links EF7 and LOGS before they can function To do this special equipment will be
242. rward start contacts selected by the I gt Fwd Start relay mask are open Rotate the phase shifting transformer so the phase lag is decreasing or the phase lead is increasing on the phase angle meter and continue until the forward start contacts close and the reverse contacts open Note the angle on the phase angle meter and check it is within the limits stated in Table 6 29 Rotate the phase shifting transformer in the opposite direction to check the other operating boundary Relay in operate region Phase angle meter indication Tolerance RCA 90 lag through to RCA 90 lead T5 Table 6 29 Page 119 6 1 9 3 6 1 9 4 Current sensitivity for I gt This test checks the current sensitivity of the relay The start contact selected by the RLY I gt relay mask or by RLY I gt Fwd for directional phase fault relays under the RELAY MASKS heading should be monitored to indicate when the input current exceeds the setting current Is This can be by either monitoring the relay contacts or viewing the SYS Relay Stat display in the SYSTEM DATA heading Where there is a star point on the relay it is advantageous to inhibit the operation of the earth fault elements inhibit to gt to gt gt to gt gt gt in order to avoid confusion with trip signals and indications Inject single phase current into a convenient phase current input on the relay and slowly increase the current noting the pick up value at
243. s Auxiliary voltage at the relay terminals Watchdog contacts checked Supply off Terminals 3 and 5 Terminals 4 and 6 Supply on Terminals 3 and 5 Terminals 4 and 6 Page 194 tick V ac dc V ac dc 10 3 2 3 Field voltage 10 3 2 4 Capacitor trip voltage 10 3 2 5 Minimum current injection to power the relay Terminals 21 and 23 Terminals 25 and 21 Terminals 23 and 25 Terminals 23 and 28 10 5 Metering checks CT ratio Phase A current Phase B current Phase C current VT ratio Phase A voltage Phase B voltage Phase C voltage 10 6 Setting Pick up current 10 gt Drop off current Io gt Curve to gt TMS Operate time at x2 Operate time at x10 Terminals 22 and 24 linked Terminals 26 and 22 linked Terminals 24 and 26 linked Terminals 24 and 27 linked Actual value injected Setting group 1 seconds seconds seconds Page 195 dc gt gt gt gt Relay metered value Test results for earth fault sensitive earth fault elements Setting group 2 if required seconds seconds seconds Io gt gt current setting Current to trip gt gt Current no trip lo gt gt Io gt gt gt current setting Current to trip lo gt gt gt gt gt gt gt gt gt gt gt gt gt gt gt Current no trip lo gt gt gt 10 7 Test resul
244. s from 100A to 2000A The dual powered relays have a narrower setting range and must be used with current transformers that match their current rating Thermal dissipation is the limitation for the upper end of the setting range and the energy required to power Page 54 3 6 5 3 6 5 1 3 6 5 2 the relay is the limitation at the lower end When the relay is powered from an additional auxiliary voltage source earth fault settings can be applied below that at which the relay can derive sufficient power from the CTs For this reason the earth fault setting range has not been restricted Output relays Four programmable output relays are provided on relays with no more than two analogue inputs and eight on all other models There are four programmable output relays on the microprocessor board and four on the auxiliary expansion board These relays each have two make contacts connected in series to increase their rating These relays can be arranged to operate in response to any or all of the available functions by suitably setting the OUTPUT MASKS The protection and control functions to which these relays respond are selectable via the menu system of the relay In addition there is a watchdog relay which has one make and one break contact Thus it can indicate both healthy and failed conditions As these contacts are mainly used for alarm purposes single contacts are used and their rating is therefore not quite as high as that of the
245. s set to 0 the setting group can be changed by energizing the opto input allocated by input mask INP Stg Grp2 However if link LOGS is set to 1 and no relay is allocated in input mask INP Stg Grp2 the setting group will have to be tested as described under cold load pick up in Section 6 1 10 7 If link SD3 is set to 1 then the setting group can only be changed by a command over the communication channel either from the master station or a local PC via suitable software To test the change of setting group initiate the change as described above The active setting group can be observed in the SYSTEM DATA column of the menu under SYS Setting Grp where the current selected group is displayed The active setting group is stored with the flags for each fault record If necessary some of the earlier setting tests can be repeated on setting group 2 to verify the settings in that group Cold load start pick up The cold load start feature can operate in either of two ways The first method of operation is by inhibiting the instantaneous low set element for an additional time delay equivalent to the setting of the cold load pick up timer tCLP when the circuit is first energized The relay will operate in this way if LOGIC function link LOGA is set to 1 The gt gt element must be enabled by setting PHASE FAULT function link PF1 to 1 and if link LOG6 is set to 0 an opto input must be allocated in the input m
246. s shown in Figures 40 or 41 according to relay type Directional relays 17 ag po ig N 4 20 E angle meter Current injection test set Figure 40 Connection diagram for KCEG140 240 and KCEU140 240 Directional relays 20 9 gt 440V 110V Current injection test set Figure 41 Connections for KCEG110 210 KCEG150 250 KCEG160 KCEU110 KCEU150 250 KCEU160 Page 113 6 1 8 3 When using the connections shown in Figure 40 the full three phase voltage should be applied and the voltage output from the potential divider adjusted to vary the residual voltage the voltage measured across the top half of the potentiometer should agree with the value of Vo displayed on the relay under MEASUREMENTS 1 When using the connections shown in Figure 41 the single phase voltage being applied is the residual quantity and should agree with the value of Vo displayed on the relay under MEASUREMENTS 1 Set the current from the secondary injection test set to a value within the rating of both the relay and the phase angle meter Then taking positive angles as the current leading the voltage and negative angles as the current lagging the voltage adjust the phase shifting transformer so the phase angle meter reads the set earth fault characteristic angle Once the phase angle has been set the current input to the meter should be short circuited While monitoring t
247. se features Must support an 11 bit frame 1 start bit 8 data bits 1 even parity bit and 1 stop bit This feature is not required if the 10 bit frame format is chosen Must be possible to disable all error correction data compression speed buffering or automatic speed changes Must save all the settings required to achieve a connection in non volatile memory This feature is only required for modems at the outstation end of the link Notes 1 The V23 asymmetric data rate 1200 75bps is not supported 2 Modems made by Hayes do not support 11 bit characters Page 67 Section 4 APPLICATION NOTES 4 1 Application of overcurrent characteristics Each relay is provided with seven inverse time current characteristics to cover the range of applications to which the relay may be applied In addition there is a definite current independent time characteristic The full range of curves will be found in Appendix 1 The various time current characteristics may find application as follows STI30XDT short time inverse curve becomes constant time at 30x setting For use where relatively short operation times are required to preserve system stability and where grading with downstream relays is not required LT30XDT long time inverse curve becomes constant time at 30x setting Provides protection for starting surges and overloads of short duration but the cold load start pick up feature would be considered the preferable solu
248. setting of 200 to 400 milliseconds An externally initiated breaker fail circuit can be arranged as described in Section 3 4 6 where time delay tAUX1 is the breaker fail time delay This externally initiated breaker fail circuit does not reset the START relays Application of Midos K Range relays for circuit breaker fail is further described in publication R4115 Back up transfer tripping Consider the radial feed arrangement shown in Figure 30 and repeated in miniature in Figure 33 The protection relay on the incomer provides two additional time delayed outputs t gt gt with an 80ms delay if the downstream feeder relays are non directional or 200ms if they are directional and gt gt gt with a delay of gt gt plus grading margin The t gt gt delay is for worst case conditions and may be reduced depending on the system X R and maximum fault level The t gt gt output contact is wired through a normally open contact on the watchdog repeat relay to the trip relay for the circuit breaker on the infeed The gt gt gt output is wired directly to the trip relay for the circuit breaker on the infeed With all the relays in a healthy state the watchdog repeat relay will be energized and for a busbar fault the circuit breaker on the incoming circuit will be tripped by t gt gt For a fault on any of the outgoing feeders t gt gt and gt gt gt of the relay on the incoming circuit will be blocked by the start contact of the overcurre
249. sh on the bottom line of the display Press the key once again and the bottom line of the display will change to TRIP Press the F key and the prompt will be displayed Are You Sure YES Page 126 Press either the 0 key to abort key to change option key to execute command After executing the open command the output relay assigned to trip the circuit breaker by the CB Open relay mask will operate for the trip time tTRIP During the trip test the status of this relay should be monitored to ensure it operates correctly 6 1 10 8 2 CB close test 6 1 11 6 1 11 1 6 1 11 2 The relay mask CB Close must be assigned to the output relays that are to trip the circuit breaker This will not enable the remote control of the circuit breaker provided the System Data Link 2 is set to 0 The circuit breaker close time delay tCLOSE under the LOGIC heading should be set to a value appropriate to the particular application Select the SYSTEM DATA heading from the menu Step down the column with short F key presses until the display reads SYS CB Control No Operation Press the key and the cursor will flash on the bottom line of the display Press the key once again and the bottom line of the display will change to TRIP and press again to display CLOSE Press the F key and the prompt will be displayed Are You Sure YES Press either the 0 key to abort key to change
250. stained application of excessive current the time delay for the gt gt current threshold should be set to operate in zero seconds for this test The setting can be restored to the original value when the test has been completed Page 111 6 1 8 1 Directional earth sensitive earth fault elements KCEG1 10 210 KCGG140 240 KCEG150 250 KCEG160 KCEU110 KCEU 140 240 KCEU 150 250 KCEU160 The relay should be commissioned with the settings calculated for the application For dual powered relays it is recommended that the relay is energized from an auxiliary voltage supply as this will reduce the burden imposed by the relay on the current injection test set Ensure that the main system current transformers are short circuited before isolating them from the relay in preparation for secondary injection tests Also isolate the relay trip contacts To test the directional earth fault element it is necessary to set some function links to directionalize the earth fault overcurrent element Table 6 21 shows which EARTH FAULT function links must be set to 1 to enable directional control of each of the earth fault elements Earth fault element EARTH FAULT function link Io gt 3 gt gt 4 gt gt gt 5 Table 6 21 Test connections for directional earth fault relays If the relay being commissioned has directional earth fault elements then the relay and the overcurrent test set and phase shifting trans
251. standard for dc supplies the positive lead connected to terminal 13 and the negative to terminal 14 for ac supplies the live lead is connected to terminal 13 and the neutral lead to terminal 14 Note To avoid damage to the relay do not connect any auxiliary supplies to terminals 7 and 8 or 9 and 10 Dual powered relays Dual powered relays derive power from the current transformer circuit and may be used with this power source alone However the application of an auxiliary ac or voltage will enable lower earth fault settings to be used also settings to be applied and data to be read when the load current is insufficient to power the relay It will also allow communications to be maintained at such times When powered from the CT circuit alone the 48V field voltage will be available to power the opto isolated control inputs when the protection starts up The phase fault current setting range is limited to the minimum current levels at which the power requirements of the relay can be maintained see Technical Data Section 5 This model of relay is rated for an auxiliary voltage Vx 100V 250V Note The capacitance discharge circuit is not isolated from the auxiliary supply and to prevent the relay from being damaged no external ground connection should be made to this circuit Opto isolated control inputs There are a number of opto isolated control inputs to the relay and these can be arranged to perform altern
252. t b e Short terminals break before SCNO Long terminal 7 d Pin terminal pcb t Ds Paes pab type 48 field voltage 2 CT connections are typical only 55 8 3 Earth connections are typical only Logic input 2 o Figure 93 Typical application diagram dual powered 3 phase overcurrent and sensitive wattmetric earth fault relay Type KCEU 241 881 Direction of forward current flow Pl AC DC i supply Vx 1 gt Relay failed Supply to gt Relay healthy trip coil Phase rotation gt Case earth 1 29 30 gt 13 4 5 29 2 15 1 33 34 cs o 17 81 1435 36 gt 52 for Ts 380 ls gt sd E KCEU 250 Tus Ds af EST 1143 44 Al 9 J Tas 44 Lo e 4335 y 19 201 95 4 tb 97 20 gt gt 50 L1 pst os 25 JC 26 1453 54 L2 Case earth dE 27 555 56 MA connection 272 28 oe oe Logic inputcommon 1 E SCNGD L3 Module terminal blocks 54 viewed from rear with integral case earth link 14 K bus communications port Notes 56 1
253. t gt to gt gt gt EFI Char Angle Ip EFI Vop EFI Io Phase fault 1 PF1 Fn Links 01010 1 CT Ratio PF1 VT Ratio PF1 Charact I 1 t gt TMS tRESET gt gt gt gt gt gt gt gt gt PF1 Char Angle PF1 lt V lt tV lt Page 190 Earth Fault 2 EF2 Fn Links 01010 2 EF2 VT Ratio EF2 Charact EF2 Io EF2 to gt TMS EF2 toRESET EF2 Io gt gt 2 to gt gt EF2 Io gt gt gt EF2 to gt gt gt EF2 Char Angle 2 Ip gt EF2 Vop gt EF2 Io Phase fault 2 PF2 Fn Links 01010 PF2 CT Ratio PF2 VT Ratio PF2 Charact PF2 I gt PF2 t gt TMS PF2 tRESET PF2 gt gt PF2 t gt gt PF2 I gt gt gt PF2 t gt gt gt PF2 Char Angle PF2 I lt PF2 V lt 2 tV lt Page 191 Logic functions LOG Fn Links 01010 LOG tCLP LOG tAUXI LOG tAUX2 LOG tAUX3 LOG tBF LOG rTRIP LOG tCLOSE LOG LS GR
254. t bit mask is allocated to each protection and control function When a mask is selected the text on the top line of the display indicates the associated function and the bottom line of the display shows a series of 1 s and 0 for the selected mask The numbers printed on the frontplate under the display indicate the number of the output relay RLY7 to RLYO that each bit controls A 1 indicates that the relay will respond to the displayed function and a 0 indicates that it will not The mask acts like an function so that more than one relay may be allocated to the same function An output mask may be set to operate the same relay as another mask so that for example one output relay may be arranged to operate for all the functions required to trip the circuit breaker and another for the functions that are to initiate autoreclose Resetting values and records Some values and records can be reset to zero or some predefined value To achieve this the menu cell must be displayed then the 0 key must be held depressed for at least one second to effect the reset The fault records are slightly different because they are a group of settings and to reset these the last cell under FAULT RECORDS must be selected This will display FLT clear records 0 To reset the fault records hold the 0 key depressed for more than 1 second Resetting TRIP LED indication The TRIP LED can be reset when the flags for the last fault
255. tage is applied to the relay then all three phase to neutral voltages will need to be reduced below the set voltage threshold V lt before the output relay can operate and any one phase voltage exceeding the threshold will cause reset Page 123 6 1 10 4 Auxiliary timers The auxiliary timers present in the relay should only be tested if they are to be used in the intended application and if the timer settings are not so high that testing is impractical 6 1 10 4 1 Timer AUXI To test the tAUX1 time delay an external switch must be connected to start an external timer interval meter and energize the opto input that activates tAUX1 The time interval meter must be stopped by the contacts of the relay allocated in relay mask RLY tAUX1 when it operates If the LOGIC function link LOG2 is set to 1 then current must be injected into the relay above the undercurrent threshold I during the test otherwise the timer will be blocked from operating If LOGIC function link LOG2 is set to 0 the current does not need to be injected into the relay during the test The measured time delay should be within the set time tAUXI 0 5 0 02 to 0 05 seconds 6 1 10 4 2Timer AUX2 If the PHASE FAULT function link PF7 is set to 1 or the input mask INP Aux2 has been allocated an input then auxiliary timer 2 should be tested There are two ways of testing the timer depending on the relay s settings Tf the input mask INP Aux2 has bee
256. tage occurring under healthy conditions thus preventing the earth fault elements on the incoming feeder relay producing a blocking signal under transient CT saturation conditions Problem 2 may not be a problem at all if the transient spill current only lasts a short time as the added delay caused by a spurious blocking signal will stabilize the protection for only a short time If this is seen as a problem then the use of a stabilizing resistor could be considered Note The response of directional overcurrent relays to power system disturbances will vary with the earthing arrangements It is not practical to consider all configurations of the power system and so the application notes in this document can only be a general guide Each application will need to be engineered to suit the system Application notes for directional overcurrent relays Directional stability Directional relays are required to withstand a fault in the reverse direction without operating In addition the directional relay is required to remain stable ie not operate when the reverse fault current is removed and the current falls to zero or to a load value which is below the overcurrent setting of the relay and in a forward direction With time delayed protection directional stability is not usually a problem but with directionalized instantaneous overcurrent relays it is much more difficult to achieve and momentary operation may occur when the fault is removed Th
257. tain the operating time for any other TMS setting the relay s actual TMS setting must be multiplied by the time given in the table above Page 120 6 1 9 5 For all curves there is an additional tolerance of between 0 02 and 0 04 seconds The operating times given make no allowance for errors in the measuring instruments Curve Operating time at specified current seconds x TMS description 2 x Is 10 x Is Nominal Range Nominal Range STI30XDT 1 780 1 68 1 87 0 52 0 49 0 55 SIB0XDT 10 03 9 52 10 53 2 97 2 82 3 12 I30XDT 15 05 14 30 15 81 2 34 2 23 2 46 VI30XDT 13 5 12 82 14 18 1 50 1 43 1 58 EDOXDT 26 67 24 66 28 67 0 81 0 74 0 87 26 67 24 66 28 67 0 81 0 74 0 87 LTI30XDT 120 0 114 126 13 33 12 66 14 Set time to gt 5 0 02 to 0 04 seconds Table 6 32 Current setting for gt gt and gt gt gt WARNING THE RELAY MAY BE DAMAGED BY APPLYING EXCESSIVE CURRENT FOR LONG DURATIONS DURING TESTING OR IN RECURRENT BURSTS WITHOUT ALLOWING TIME FOR THE RELAY TO COOL DOWN This test is to check that the instantaneous current level of the gt gt and gt gt gt is correct If the I gt gt element is to be used by the customer then the PHASE FAULT function link 1 must be set to 1 This test can only be performed if the test set available can inject sufficient current into the relay to cause the element to operat
258. tate of logic control inputs READ 0021 SYS Relay Stat Current state of output relays READ 0022 SYS Alarms State of alarms READ 0001 SYS Language READ The language in which the text is displayed is shown at this location On these particular relays it is not selectable 0002 SYS Password PWP The selected configuration of the relay is locked under this password and cannot be changed until it has been entered Provision has been made for the user to change the password which may consist of four upper case letters in any combination In the event of the password becoming lost a recovery password can be obtained on request but the request must be accompanied by a note of the model and serial number of the relay The recovery password will be unique to one relay and will not work on any other unless the user set password is the same Page 19 0003 SYS Function Links PWP These function links enable selection to be made from the system options for example which commands over the serial link will be acted upon They are fully detailed in Sections 3 2 2 3 2 7 3 2 8 3 2 9 3 2 10 and 3 2 11 0004 SYS Description PWP This is text that describes the relay type for example THREE PHASE OVERCURRENT It is password protected and can be changed by the user to a name which may describe the scheme configuration of the relay if the relay is changed from the factory configuration 0005 SYS Plant Reference SET The plant referen
259. ted error The Master Station can be set to resend a command a set number of times if it does not receive a reply or receives a reply with a detected error Aids to circuit breaker maintenance The information gathered by the relay can be of assistance in determining the need for circuit breaker maintenance The circuit breaker opening time is recorded under FAULT RECORDS If this value is monitored any significant increase may be used as an indication that circuit breaker maintenance is required Additionally the number of circuit breaker operations is recorded under MEASUREMENTS 2 Also under this heading will be found an indication of the summated contact breaking duty which is recorded separately for each phase Fault records Fault values are recorded for the last fault but the fault flags are recorded for the last five faults to give a record of a complete four shot autoreclose cycle They are stored in non volatile memory and can be accessed via the user interface There is provision for resetting these records to zero In addition the time taken for the circuit breaker to interrupt the fault current is recorded A copy of the fault record is also stored in the event records and up to 50 of these records can be held at any one time provided all other events are deselected These records will carry a time tag which is valid for 49 days However the event records will be lost if the relay is de energized and they can only be accessed
260. they will be set to 0 Merely moving the cursor past a link position does not change it in any way Changing setting values Move through the menu until the cell that is to be edited is displayed Press the or key to put the relay into the setting change mode A cursor will flash in the extreme left hand position on the bottom line of the display to indicate that the relay is ready to have the setting changed The value will be incremented in single steps by each momentary press of the key or if the key is held down the value will be incremented with increasing rapidity until the key is released Similarly the key can be used to decrement the value Follow the instructions in Section 3 3 to exit from the setting change Note When entering CT RATIO or VT RATIO the overall ratio should be entered ie 2000 5A CT has an overall ratio of 400 1 With rated current applied the relay will display 5A when CT RATIO has the default value of 1 1 and when the RATIO is set to 400 1 the displayed value will be 400 x 5 z 2000A Setting communication address The communication address will normally be set to 255 the global address to all relays on the network when the relay is first supplied Reply messages are not issued from any relay for a global command because they would all respond at the same time and result in contention on the bus Setting the address to 255 will ensure that when first connected to the network they will
261. time delay should be within the set time tAUX1 0 5 0 02 to 0 05 seconds Page 124 6 1 10 5 6 1 10 6 6 1 10 7 Breaker fail When LOGIC function link LOGI is set to 1 the breaker fail function should be tested Operation of relay 3 initiated via any relay mask will initiate the breaker fail timer tBF The relay should be connected to an overcurrent test set as described in Section 6 1 7 1 for overcurrent relays or Section 6 1 8 1 for directional overcurrent relays A time interval meter should be connected so that it starts when current is injected into the relay and arranged to stop by one of two functions Ifthe function link LOG2 is set to 0 the time interval meter should be arranged to stop when a relay allocated by the mask RLY I gt RLY 10 gt RLY I gt Fwd or RLY Io gt Fwd is reset dropped off by the breaker fail timer Tf function link 002 is set to 1 then the time interval meter should be arranged to stop when the relay allocated via relay mask RLY Aux1 operates The measured time delay should be within the set value of tBF 0 596 0 02 to 0 05 seconds Change of setting group Test the change of setting group if SYSTEM DATA function link SD4 is set to 1 as this will enable control of the setting group If link SD4 is set to 0 then there is no need for the tests in this section to be carried out If SYSTEM DATA function link SD3 is set to 0 and link LOGS i
262. ting of the Logic Function Links together with the setting of the input and output masks control the way in which the optional features are used thus maximizing the use of the available functions All function links and input output masks are password protected to prevent accidental changes being made during the course of minor setting adjustments Auxiliary timers Models A and B Figure 12a shows three auxiliary timers that may be initiated from external inputs assigned in the respective input masks and which after the set time delay operate the relays assigned in the relay masks Setting link PF7 to 1 timer tAUX2 will be initiated when the currents for all three phases and earth elements are below the respective undercurrent settings 1 lt 10 lt to give a time delayed undercurrent output Setting link LOG3 to 1 timer tAUX3 will be initiated when any of the three phase or earth fault currents rise above their respective undercurrent threshold I Io This be used to provide a fourth time delayed overcurrent and earth fault stage In the KCEU 141 KCEU 241 the time tAUX3 will be initiated from external inputs only Page 38 3 4 5 2 INP Auxl RLY Auxl I lt Se INP Aux2 RLY Aux2 59 I PF7 90 lt INP Aux3 RLY Aux3 SIE TE LOG3 000 Figure 12a Auxiliary time delays Auxiliary timers Models C and onwards Figure
263. tion for these applications Most useful for grading with low voltage system protection devices or for protecting neutral earthing resistors DT definite time characteristic Useful for achieving constant time grading steps over a wide current range and for offering faster tripping times than inverse time protection at low multiples of current setting This characteristic is often used where there is no significant variation in fault level between relay locations eg in the case of earth fault protection of a resistance earthed system or in the case of low circuit impedance compared to source impedance SI30XDT standard moderately inverse curve becomes constant time at 30x setting The standard characteristic for co ordination of protection on systems where the amount generation varies and for providing back up protection on transmission systems IN30XDT inverse curve becomes constant time at 30x setting Slightly more inverse than the SI30XDT curve but also for co ordination of protection on distribution systems and for back up protection for relays on other circuits This curve will allow closer grading with some relays that do not have an standard curve VI30XDT very inverse curve becomes constant time at 30x setting Being very inverse it allows for longer operation times at low currents or shorter times at high currents than the previous two curves This characteristic is especially useful when c
264. tions The equipment should be operated within the specified electrical and environmental limits Current transformer circuits Do not open the secondary circuit of a live CT since the high voltage produced may be lethal to personnel and could damage insulation Generally for safety the secondary of the line CT must be shorted before opening any connections to it For most equipment with ring terminal connections the threaded terminal block for current transformer termination has automatic CT shorting on removal of the module Therefore external shorting of the CTs may not be required the equipment documentation should be checked to see if this applies For equipment with pin terminal connections the threaded terminal block for current transformer termination does NOT have automatic CT shorting on removal of the module Pxxxx EN 55 1 1 Page 6 10 p i ii pe e p gt gt Safety Section External resistors including voltage dependent resistors VDRs Where external resistors including voltage dependent resistors VDRs are fitted to the equipment these may present a risk of electric shock or burns if touched Battery replacement Where internal batteries are fitted they should be replaced with the recommended type and be installed with the correct polarity to avoid possible damage to the equipment buildings and persons Insulation and dielectric strength testing Insulation testing may leave capacitors charge
265. ts equally Each threshold has a corresponding following time delay t t gt gt t gt gt gt See Figure 6 For earth faults there are separate threshold adjustments Io gt gt and Io gt gt gt and associated following time delays to to gt gt to gt gt gt gt gt elements operate when the power frequency component of the current exceeds the set threshold These elements may be set as a low set overload protection and may be expected to have relatively long associated time delays Time delays associated with these elements are respectively t gt to gt and a time current characteristic may be chosen from a selection of standard curves or may be set to non dependent definite time The time delays for threshold detection stages I gt gt 10 gt gt I gt gt gt Io may be set to give zero delay for instantaneous operation if required The frequency response for these elements is given in Section 5 15 Time Current Figure 6 Overcurrent characteristic Start function overcurrent relays are provided with separate phase and earth fault START functions which respond when the current exceeds the I gt or Io thresholds The use of the START outputs in overcurrent blocking schemes is described later in this document If any of the elements I gt I gt gt gt gt gt or Io gt gt Io gt gt gt is selectively directionalized then complementary FORWARD START and R
266. ts for phase fault elements Setting group 1 Setting group 2 if required Setting Pick up current for I Phase A A Drop off current for I gt Phase A A A Pick up current for I Phase B A A Drop off current for I Phase B A A Pick up current for I Phase C A A Drop off current for I Phase C A A Curve to gt TMS seconds seconds Phase A operate time at x2 seconds seconds Phase B operate time at x2 seconds seconds Phase C operate time at x2 seconds seconds Phase A operate time at x10 seconds seconds Phase B operate time at x10 seconds seconds Phase C operate time at x10 seconds seconds Page 196 Phase A current setting I gt gt Phase A current to trip gt gt Phase A current to no trip gt gt Phase current setting gt gt Phase current to trip gt gt Phase B current to no trip gt gt Phase C current setting gt gt Phase C current to trip gt gt Phase C current to no trip gt gt Phase A current setting I gt gt gt Phase A current to trip I gt gt gt Phase A current to no trip gt gt gt Phase current setting gt gt gt Phase current to trip gt gt gt Phase current to no trip gt gt gt Phase current setting gt gt gt Phase C current to trip gt gt gt Phase current to no trip gt gt gt Page 197 10 8 Test results for directional earth sensitive earth fault elements Vp gt setting Actual gt threshold Setting gro
267. uency response will therefore be modified for the I gt gt Io gt gt and I gt gt gt Io gt gt gt elements for which Figure 39 is typical only For certain applications it may be necessary to set the gt gt Io gt gt element to a low setting possibly lower than that for the I gt or Io gt elements In these situations the modified frequency response shown in Figure 39 may not be acceptable because of the lack of harmonic rejection To overcome this problem a software link is provided to select or deselect the peak detection feature for the I gt gt and Io gt gt overcurrent elements 1 Filter response for I gt gt I gt gt gt with peak measurement tracking a single frequency 0 50 100 200 300 400 Frequency Hz Figure 39 Typical composite frequency response Page 96 5 19 1 Frequency response of directional elements The peak measurement is not used for the I gt gt Io gt gt and I gt gt gt Io gt gt gt elements of directional overcurrent relays This is to ensure that the overcurrent and directional measurement is made from the same data to ensure decisive operation Figure 39 will then no longer apply and the frequency response of these elements will be as shown in Figures 37 and 38 The phase directional elements are provided with synchronous polarization which is maintained for 320ms after the voltage collapses so that decisive operation is ensured During the period of synchronous pol
268. up E F relay characteristic angle Lag Lead 1 2 Additional test results for dual polarized elements when current polarized Lag Lead 10 9 Test results for directional phase fault elements E F relay Setting group characteristic Phase A Phase B Phase C angle 1 Lag Lead Lag Lead Lag Lead 2 Lag Lead Lag Lead Lag Lead 10 10 Test results for selective logic 10 10 1 Opto input checks Opto input number tick LO Ll L2 13 14 L5 L6 L7 Page 198 10 10 2 Controlled logic blocking of time delay elements Earth fault element Input mask Input mask setting Operation to gt INP Blk to gt to gt gt INP Blk to gt gt to gt gt gt INP Blk to gt gt gt Phase fault element Input mask Input mask setting Operation t gt INP Blk t gt t gt gt INP Blk t gt gt t gt gt gt INP Blk t gt gt gt 10 10 3 Undervoltage logic Relay setting of tV lt seconds Measured value of tV lt seconds Relay setting of V lt Measured value of V lt 10 10 4 Auxiliary timers Timer Aux1 Timer Aux2 Timer Aux3 Setting Relay setting of auxiliary timer seconds seconds seconds Page 199 Measured value of auxiliary timer seconds seconds seconds 10 10 5 Breaker fail Relay setting Measured values 10 10 6 Change setting group tick Change to setting group
269. uring restoration time Command lt 1 gt None circuit restored On loss of the auxiliary supply the memory of having tripped due to a load shed trip command is erased This ensures that a relay that has been out of service for some time will not close a circuit breaker in response to a subsequent load shed command as this could be dangerous 0010 SYS CB Control SET This cell contains the functions for control of the circuit breaker Via this cell the circuit breaker can be closed and tripped either from the user interface or over a communication network To be able to do this the relay has to have output relays Page 21 3 2 3 3 2 4 3 2 5 allocated to circuit breaker control and these relays would normally be routed through the remote local control switch arranged to complete the circuits in the remote position 0020 SYS Logic Stat Current state of opto isolated logic control inputs 0021 SYS Relay Stat Current state of relay outputs 0022 Alarms Current state of alarm flags see Section 3 3 11 Fault records READ 0101 FLT Ia 0102 FLT Ib 0103 FLT Ic 0104 FLT Io 0105 FLT Vab 0106 FLT Vbc 0107 FLT Vca 0108 FLT Vo 0109 FLT CB trip time 010A Fnow 010B Fn 010 Fn 1 010D Fn 2 010 3 010 Fn 4 0110 FLT clear record 0 Measurement 1 READ 0201 MSI Ia Ip 0202 MSI Ib 0203 MSI Ic 0204 MSI Io 0205 1 Vab 0206 651 Vbc 0207 MSI 0208 MSI Va 0209 MSI Vb
270. urrent polarization In this case the current flowing in the neutral of the power transformer is used to polarize the relay As for voltage polarization the threshold value of the current polarizing quantity is influenced by the power system unbalance However the essential difference is that current polarization is not affected by voltage transformer errors nor indeed is it affected by neutral current transformer error Hence the threshold level for current polarization may be based on the maximum zero sequence current in a healthy system that is 0 5 of the neutral impedance rating However the neutral impedance rating is often greater than the feeder rating and hence a minimum operating current threshold of 0 5 of relay rating is required This results in a recommended range of say 0 5 to 5 0 of relay rating The characteristic angle adjustment phase shifts the voltage polarizing vector only and therefore has no effect on the characteristic at the time when the relay is polarized from current The characteristic angle for current polarization is fixed at 0 Only voltage polarized and dual polarized relays are available in the Type KCEG range of relays with the dual polarized version being supplied when current polarization is requested Dual polarized versions of the relay provide both current and voltage polarization via separate analogue digital inputs When the polarizing voltage exceeds the threshold setting Vop gt the relay will be
271. urther momentary presses of the F key will then move down the new column row by row In this way the full menu of the relay may be scanned with just one key and this key is accessible with the cover in place on the relay The other key that is accessible with the cover in place is the reset key 0 A momentary press of this key will switch on the back light for the LCD without changing the display in any way Following a protection trip the display will change automatically from the default display to that of the fault flags for that fault and the red trip LED will be lit to draw attention to the fact The trip LED can be reset by holding down the reset key 0 for at least one second Col 1 Col 2 F LONG Figure 3 Menu system of relay Page 17 3 2 1 The fault information is not lost by this action it is only cleared from the display The fault flags can be read by selecting FAULT RECORDS from the column headings and stepping down until the flag data the flags for the last fault are displayed The red trip LED can be reset by holding the reset key 0 depressed for 1 second whilst this cell is being displayed The next cell down contains the flags for the previous fault Fn 1 and so on to Fn 4 enough for a full four shot autoreclose cycle The currents and voltages measured during the last fault are also recorded on this page of the menu together with the circuit breaker opening time T
272. ut contacts must be connected to trip the test set Selective logic For the selective logic checks only the features that are to be used in the application should be tested Relay settings must not be changed to enable other logic functions that are not being used to be tested For detailed descriptions of the selective logic please refer to Section 3 4 of this manual Opto input checks This test is to check that all the opto inputs are functioning correctly The state of the opto isolated input can be viewed from the SYS Logic Stat display under the SYSTEM DATA heading Relays of the type 110 120 and 210 only have 3 opto inputs LO L1 and L2 All other relay types have the full 8 opto inputs LO L1 L2 L3 14 L5 L6 and L7 To enable energization of the opto inputs terminal 8 should be linked to terminals 52 and 55 The opto inputs can then be individually energized by connecting terminal 7 to the appropriate opto input listed in Table 6 34 Opto input number Terminal LO 46 L1 48 L2 50 L3 45 14 47 L5 49 L6 51 L7 53 Table 6 34 The status of each opto input can be viewed by displaying SYS Logic Stat which will be found towards the end of the SYSTEM DATA column of the menu When each opto is energized one of the characters on the bottom line of the display will change to indicate the new state of the inputs The number printed on the frontplate under the display will identify which o
273. ved via the serial communication port or an Page 41 3 4 7 2 34 13 3 4 8 external input via one of the opto isolated control inputs For reasons of operational safety it has not been made possible to control the setting group change both locally and remotely at the same time Link SD3 decides which method is to be used it is set to 1 for remote control of the change and to 0 for local control INP Stg Grp2 Select alternative setting GRP2 Figure 14 Change of setting group control Remote change of setting group Remote commands are not maintained so a set reset arrangement is used to store the last received command The setting group that is currently in use can be found by looking at SYS Setting Grp in the SYSTEM DATA column of the menu or Fnow in the FAULT RECORD of default display if selected The setting group remains as selected when the auxiliary supply is interrupted Local control of setting group Local control is asserted via the input mask INP Stg Gp2 and the control input that is set in this mask The relay will respond to the group 2 settings whilst this input is energized and the setting group 1 when it is de energized The setting group can also be changed by the cold load start circuit as described in the next section Note To enable individual settings to be changed remotely System Data Link SDO must be set to 1 If instead it is set to O th
274. via the serial communication port Time tagged event records An event may be a change of state of a control input or an output relay it may be a setting that has been changed locally or a protection or control function that has performed its intended function A total of 50 events may be stored in a buffer each with an associated time tag This time tag is the value of a timer counter that is incremented every 1 millisecond The event records can only be accessed via the serial communication port when the relay is connected to a suitable Master Station When the relay is not connected to a Master Station the event records can still be extracted within certain limitations the event records can only be read via the serial communication port and K BUS IEC60870 5 Interface Unit will be required to enable the serial port to be connected to an IBM or compatible PC Suitable software will be required to run on the PC so that the records can be extracted Page 60 3 7 1 7 when the event buffer becomes full the oldest record is overwritten by the next event records are deleted when the auxiliary supply to the relay is removed to ensure that the buffer does not contain invalid data Dual powered relays are most likely to be affected the time tag will be valid for 49 days assuming that the auxiliary supply has not been lost within that time However there may be an error of 4 3s in every 24 hour period due to the accuracy
275. which the START relay operates Reduce the current slowly and note the drop off value at which the START relay resets Check the pick up and drop off current is within the range shown in the Table 6 29 Current level Pick up 0 95 x Is 1 05 x Is Drop off 0 9 x pick up 1 0 x pick up Table 6 30 The test must be repeated on all the phase elements of the relay Table 6 31 lists the terminals into which current should be injected for each of the phases Phase Terminals A 21 22 B 23 24 25 26 addition with some site wiring it may be necessary to inject A N B N C N Table 6 31 Time characteristic for t gt The relay selected for the t gt trip can be found under the RELAY MASKS heading in RLY t gt The terminals for each relay are shown in the application diagram Connect the relay contacts for the t gt trip to both trip the test set and to stop a timer With the rated three phase polarizing voltage applied to the relay set to twice the threshold level and the phase shifter adjusted to the characteristic angle of the relay inject a 2 x rated current into one phase of the relay terminals numbers are given in Table 6 31 for each phase and measure the operation time If the test set used can inject sufficient current repeat the test at 10 x setting current Check the operating time against Table 6 32 Note The operating times given above are for TMS 1 Therefore to ob
276. will be explained in Section 3 4 13 When link LOGI is set to 1 a command to operate RLY3 via any output mask will also initiate the breaker fail time delay within the relay If the circuit breaker fails to trip within the set time tBF the start relays are reset to remove any block which they may be asserting on an upstream relay The circuit breaker fail time delay tBF can also be arranged to produce a back trip an output to directly trip the next circuit breaker back in the system To achieve this Page 40 3 4 6 4 3 4 7 3 4 7 1 Link LOG2 must be set to 1 and an output relay allocated via the RLY Aux 1 output mask for backtrip The INP Aux 1 input mask can be used to assign one of the control inputs to initiate the time delay tAUX1 By this means an externally initiated breaker fail function can be set up Time delay tAUX1 will be set to the required circuit breaker fail time setting and a backtrip output will be given via the RLY Aux 1 output mask Provided link LOG2 is set to 1 the output relay and the breaker fail timers are checked by the undercurrent element to ensure fast reset INP Blk t gt SERRE d amp z ET TESTES RLY I Start TTT Output relay 3 Trip 1081 operated to initiate O10 tBF I lt LOG2 a LOG2 INP Auxl O10 RLY Aux 1 ARBRE aD lt 10 lt Figure 13b Breaker fail protection Backtrip The breaker f
277. with Aux3 output SET Circuit breaker fail time setting SET Circuit breaker trip pulse setting SET Circuit breaker close pulse setting SET Load shed trip level 0 7 SET Load restoration time delay SET Selected display for default SET Description or User Defined Scheme Reference Plant Reference User Defined Ib Io Io Vo Input to block to Input to block to gt gt Input to block to gt gt gt Page 26 3 2 13 3 2 14 3 3 0A04 0A05 0A06 0A07 0A08 0A09 0A0A 10 INP t INP gt gt INP gt gt gt INP CB Open CLP INP 1 INP Aux2 INP Aux3 INP Stg Grp2 INP CB Open INP CB Closed INP CB to Bus2 INP LTrip CB INP LClose CB Relay mask PWP 0B03 0B04 0B05 0B06 0B07 0B08 0B09 OBOA OBOB OBOC OBOE OBOF 0B10 OB11 0812 0B13 RLY Io Fwd RLY Io Rev RLY to RLY to gt gt RLY to gt gt gt RLY I gt Fwd RLY I gt Rev RLY t gt RLY t gt gt RLY t gt gt gt RLY tV lt RLY 1 RLY Aux2 RLY Aux3 RLY V Reduct 1 RLY V Reduct 2 RLY V Reduct 3 RLY CB Trip RLY CB Close Recorder 0 01 0C02 0C03 0 05 Changing text and settings REC Control REC Capture REC Post Trigger REC Relay Trig To enter the setting mode Input to block t gt Input to block t gt gt Input to block t gt gt gt Input to initiate cold load pick up from C
278. x2 s PH7 IS tAUX2 ex QUO Aux3 1 RLY Aux3 tAUX3 4 gt 04 Stg Grp2 SD3 SELECT 22 ALTERNATIVE SETTING GP2 SEO REMOTE CHANGE 1 gt RESET REMOTE CHANGE 2 SET L Close CB L Trip CB 502 RLY CB Tri GTO TRIP tTRIP RLY CB Close CLOSE CB 4 tcLose INP CB Closed 34 INP CB Open TO PLANT STATUS T ERAN WORD CB STATUS EARTH GROUND FAULT SETTINGS PHASE FAULT SETTINGS LOGIC AND SYSTEM DATA SETTINGS Figure 66 Logic diagram Dual powered directional three phase overcurrent and sensitive wattmetric E F relay Type KCEU 241 Page 160 OLI 09204 9461 queo peordAL 7 9 oseo qr suoroouuoo PIMA 42014 eururro o npo K uo eord A3 Lo Z eur opo CONNECTION DIAGRAMS FOR KCGG KCGU KCEG and KCEU RELAYS Appendix 3 qod jeuruus p GDNOS 2205 pumua 8007 5 8c N Yeorq 110 46 q Drs 54 9c 5k Sc e gt yoouUodsIp pue q Ik Kes 162 ve 5k C oxeursqur
279. y generated earth fault current is above setting the forward start contacts will be closed Should the load current happen to be in the reverse direction then the current connections should be temporarily reversed to check the operation of the relay and then restored Note These tests alone are not conclusive that the phase connections to the relay are correct A phase angle measurement is required for conclusive testing 6 1 11 2 3 Earth fault directional relay KCEG KCEU 110 150 160 210 250 Earth fault directional relays are not energized under normal load conditions and it is therefore necessary to simulate operating conditions For relays with only earth fault elements the relay should be connected to an open delta winding of a voltage transformer and the residual circuit of the current transformers There are many ways of making the special connections on the CT and VT circuits to carry out an on load test but we recommend the temporary connections shown in Figure 45 which simulate a phase A to neutral fault If load current is flowing in the operating direction then provided that the correct phase relationships of the CTs and VTs have been proven and the artificially Page 128 generated earth fault current is above setting then the forward start contacts will be closed Should the load current happen to be in the reverse direction then the current connections should be temporarily reversed to check the operation of the
280. y charger with the batteries disconnected Note The application of the auxiliary voltage supply reduces the burden that is imposed by the relay on the current injection equipment For the secondary injection tests in Sections 6 6 to 6 9 inclusive it is recommended that the relay should be powered from an auxiliary supply rather than from the current circuit Energization from auxiliary voltage supply For secondary injection testing using the test block type MMLG insert test plug type MMLB 01 with CT shorting links fitted It may be necessary to link across the front of the test plug to restore the auxiliary supply to the relay Isolate the relay trip contacts and insert the module With the auxiliary disconnected from the relay use a continuity tester to monitor the state of the watchdog contacts as listed in Table 6 9 Page 103 Reconnect the auxiliary supply to the relay The relay should power up with the LCD showing the default display and the centre green LED being illuminated this indicates the relay is healthy The relay has a non volatile memory which remembers the state ON or OFF of the LED trip indicator when the relay was last powered and therefore the indicator may be illuminated With a continuity checker monitor the state of watchdog contacts as listed in Table 6 9 N B These contacts only change state for an internal fault within the relay Terminals With relay de energized With relay energized
281. y settings tAUXI 1 0 seconds tCLP 8 0 seconds tAUX2 2 0 seconds tBF 0 3 seconds tAUX3 3 0 seconds tTRIP 0 5 seconds tRESTORE 0 seconds tCLOSE 0 5 seconds Initial allocation of opto isolated control inputs LO Change setting group 11 1 gt gt gt gt L2 Block t gt gt gt to gt gt gt L3 Initiate auxiliary timer 1 14 Initiate auxiliary timer 2 15 Initiate auxiliary timer 3 L6 CB closed indication L7 CB open indication Page 48 3 5 2 5 3 5 3 3 5 4 Initial allocation of output relays RLYO Start Fwd Start directional only RLY1 Start Rev Start directional only RLY2 Trip t gt t gt gt gt gt gt to to gt gt to gt gt gt Aux 2 amp 3 trip RLY3 Trip t gt t gt gt gt gt gt to to gt gt to gt gt gt Aux 2 amp 3 main RLY4 Trip t gt gt gt gt gt gt to to gt gt to gt gt gt A R init RLY5 Aux 1 RLY6 Remote CB close RLY7 Remote CB trip Configuring for application Before attempting to change the configuration for a particular application it is strongly recommended that experience is first gained with the initial factory selected options as supplied For example practise moving through the menu and then changing some of the visible individual protection settings When familiar with the relay it will be easier to configure it for a specific application This involves selecting as described in Section 3 4 those available options that

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