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489 Generator Management Relay Instruction Manual *1601-0150-AD

1. 1000 100 10 MULTIPLIER oO 2 300 a 20 0 150 1 10 0 80 60 40 3 0 20 0 1 10 05 0 01 0 1 1 10 10 CURRENT I Ipu 808800A4 DWG FIGURE A 10 ANSI Very Inverse Curves 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL A 17 TRIP TIME sec CHAPTER A APPENDIX 99 489 ANSI c GEMuttilin EXTREME INVERSE 1000 100 NN VN VAI NNN VN AVA V NN NN MULTIPLIER 30 0 20 0 15 0 10 0 8 0 6 0 40 3 0 2 0 0 1 1 0 0 5 0 01 0 1 1 CURRENT 808799A4 CDR FIGURE A 11 ANSI Extremely Inverse Curves 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER A APPENDIX A 4 2 Definite Time Curves GE Multilin 1000 489 DEFINITE TIME 100 10 MULTIPLIER TRIP TIME sec 30 0 20 0 15 0 10 0 8 0 6 0 0 1 4 0 3 0 2 0 0 5 0
2. AUTOMATIC SHORTING COM 3E NEUTRAL 1A COM HGF COM COM COM PHASE VOLTAGE INPUTS NEUTRAL END CT s GROUND INPUTS OUTPUT CT s 808817A1 CDR FIGURE 7 2 Secondary Injection Setup 2 GE Multilin 50 0 025 Ground Accuracy The specification for GE Multilin HGF 50 0 025 ground current input accuracy is 0 5 of 2 x CT rated primary 25 A Perform the steps below to verify accuracy gt In the S2 SYSTEM SETUP gt CURRENT SENSING men set 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 7 15 C34 CHAPTER 7 TESTING GROUND CT 50 0 025 CT Measured values should be 0 25 A Inject the values shown in the table below either as primary values into a GE Multilin 50 0 025 Core Balance CT or as secondary values that simulate the core balance CT gt Verify accuracy of the measured values in the A2 METERING DATA gt CURRENT METERING menu Injected Current Current Reading Primary 50 0 025 CT Secondary Expected Measured 0 25A 0 125 mA 0 25A 1A 0 5 mA 1 00A 5A 2 5 mA 5 00A 10A 5 mA 10 00 A Neutral Voltage 3rd Harmonic Accuracy The 489 specification for neutral voltage 3rd harmonic accuracy is 0 5 of full scale 100 V Perform the steps below to verify accuracy gt In the 52 SYSTEM SETUP D gt V VOLTAGE SENSING me
3. 5 71 MOTOR STARS etit el REESE 5 23 Meer 5 23 MVA DEMAND die 5 93 6 20 5 93 6 20 MvanMETERING tenet t 5 17 5 23 6 18 MW DEMAND uuu L 5 93 6 20 MWh METERING au ss uba 5 17 5 23 6 18 N NAMEPLATE eiii timeret pea tu pcs uae rd dad petro au as 1 1 NEGATIVE SEQUENCE CURRENT ACCURACY TEST 7 6 NEGATIVE SEQUENCE OVERCURRENT senectae 5 36 NEGATIVE SEQUENCE CURRENT 6 17 NEUTRAL CURRENT ACCURACY TEST see cedi nas 7 5 NEUTRAL OVERVOLTAGE gt ede tse dt lette do d Dade 5 51 A 2 NEUTRAL UNDERVOLTAGE is tere cte cat ette ita 5 53 NEUTRAL VOLTAGE ACCURACY TEST te eed enit va 7 6 7 16 NUMERICAL SETPOINT S seuss tt e rende t tite ete tette Eg 1 10 OFFLINE OVERCURRENT u ttti esent erui e eden 5 33 OREN DELTA t nieto unas a tbe Soe 3 14 OPEN DELTA CONNECTED 5 02 0 5 54 OPEN RID SENSOR xcci HIE ud UU esu 5 68 ORDER CODES uuu u a 2 6 OUTPUT CURRENT ACCURACY TEST iiit eoe aite te reatus 7 4 OUTPUT RELAY EEDS uu ua rr Remedies 4 3
4. nies 2 6 LEELA NO A EA 7 4 VOLTAGE METERING ORE 6 17 VOLTAGE RESTRAINED OVERCURRENT Dm 5 35 TESTIN 7 20 VOLTAGE SENSING oriceon tte ene en a oec deed 5 18 VOLTS BERTZ 3 en teet 5 45 VIDEUSE EAIDURE L e reta het eodein ret cerne nt denote e ener ege 5 92 VIT RATIO S u Lu tee es E 5 18 E M 5 92 VTs MEL 5 54 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL INDEX 5 18 5 53 W WARRANT Y 27 31 WAVEFORM CAPTURE ete b beret ea a Eg teca dt 5 27 WIRING DIAGRAM uite repere ett onte gre aee re e tee eret te 3 10 WITEID RAWAL L 3 4 3 14 WYE CONNECTED VTS eet eiie tdt ete or Lee erre tds 5 53 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL
5. O to 50000 V Not seen if VT CONNECTION is None O to 50000 V Not seen if VT CONNECTION is None O to 50000 V Not seen if VT CONNECTION is Wye O to 50000 V Not seen if VT CONNECTION is Wye O to 50000 V 0 to 359 Not seen if VT CONNECTION is None as above as above O to 50000 V 0 to 359 Not seen if VT CONNECTION is Wye as above as above 0 00 to 2 00 Not seen if VT CONNECTION is None 0 00 to 90 00 Hz Not seen if VT CONNECTION is None 0 0 to 25000 0 V Seen only if there is a neutral VT CHAPTER 6 ACTUAL VALUES NEUTRAL VOLTAGE Range 0 0 to 25000 0 V Seen only if MESSAGE 2 2 3rd HARM 0 0 V there is a neutral VT TERMINAL VOLTAGE Range 0 0 to 25000 0 V Seen only if vT MESSAGE AS 3rd HARM 0 0 V CONNECTION is Wye IMPEDANCE Vab Iab Range 0 0 to 6553 5 Qsec 0 to 359 A 0 0 Q sec 0 Measured voltage parameters will be displayed here The V Hz measurement is a per unit value based on Vab voltage measured frequency divided by generator phase to phase nominal voltage nominal system frequency Polar coordinates for measured phase and or ine voltages are also shown using Va wye connection or Vab open delta connection as a zero angle reference vector In the absence of a voltage signal Va or Vab IA output current is used as the zero angle reference vector f VT CONNECTION TYPE is programmed as No
6. 5 18 WITSTO c 2 6 GROUND CURRENT ACCURACY 7 5 7 15 GROUND CURRENT INPUT e eo ett 3 12 GROUND DIRECTIONAL eR eet icles 5 40 A 4 GROUND EAUDT TS 13 GROUND L eet 5 38 3 GROUND SWITCH 5 5 2 7777 5 27 HELPK dee EE 1 10 HIGH SET PHASE OVERCURRENT 5 42 FU POW se E 3 18 HOT COLD SAFE STALL tette 5 87 AG CURVES 5 31 20 ONG R u I vierte ERE ERE SRI 3 2 EC CURVES 5 30 24 ED u eto EIE UM EE 4 13 NADVERTENT 2 2 9 5 34 NJECTION TEST SETUP Rp ERE 7 3 7 15 7 19 NPUTS 2 6 3 14 u hadas 2 7 3 11 3 12 ete aus 2 6 3 14 2 12 RTD 2 7 3 15 VOIP duces pie 2 7 3 14 INSERTION oc
7. Injected Expected Current Reading Measured Differential Current Current Differential Differential Phase A Phase B Phase C Phase A Phase B C 1 200A 100A 0 2 A 400 A 200 A 0 5 A 1000 A 500 A 1A 2000 A 1000 A NAGEMENT RELAY INSTRUCTION MANUAL 7 5 CHAPTER 7 TESTING 7 2 4 Neutral Voltage Fundamental Accuracy The specification for neutral voltage fundamental accuracy is 0 5 of full scale 100 V Perform the steps below to verify accuracy gt In the S2 SYSTEM SETUP gt V VOLTAGE SENSING menu set NEUTRAL VOLTAGE TRANSFORMER Yes NEUTRAL RATIO 10 00 1 In the S2 SYSTEM SETUP DV GEN PARAMETERS menu set GENERATOR NOMINAL FREQUENCY 60 Hz Measured values should be 5 0 V gt Apply the voltage values shown in the table and verify accuracy of the measured values View the measured values in the A2 METERING DATA gt V VOLTAGE METERING menu Applied Neutral Voltage Expected Neutral Voltage Measured Neutral at 60 Hz Voltage 10V 100V 30V 300 V 50V 500V 7 2 5 Negative Sequence Current Accuracy The 489 measures negative sequence current as a percent of Full Load Amperes FLA A sample calculation of negative sequence current is shown below Given the following generator parameters Rated MVA P4 1 04 Voltage Phase to Phase Vp 600 V We have P 6 FIA a A 10 10 EQ 7 1 V3 x
8. 3 4 INSPECTION CHECKLIST at deepen Rae eee ede 1 1 INSTALLATION E 3 3 IRIGEBa eee Eee Ld 3 17 5 13 K KEYPAD MI 4 3 eje 1 10 L LAST TRIP DATA uu eR nee 5 17 5 23 6 5 6 9 6 12 LEARNED PARAMETERS tee item terea iu 5 23 4 1 4 2 4 3 LONG TERM STORAGE certet ee Re tp ee E 2 16 LOOP POWERED TRANSDUCERS tte oet dem ree beca peek eU 3 14 LOSS OF iet a tute tren bee da hat e te te 2 9 5 55 LOSS OR LOAD i SURE EE UI 4 3 LOW FORWARD POWER titer te 5 63 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL INDEX M MACHINE COOLING etta irit ta Pe inta reno died 5 85 MESSAGE SCRATGEDPAD irme e teta m e eias 5 15 METERING eugr i 6 16 qhansti Ea ENERE 2 12 6 20 u IE I 5 17 5 23 6 18 Mule re musu n E 5 17 5 23 6 18 qure 2 13 COONS ERE ETE 2 4 eee ee a eee 6 17 MODEL INFORMATION eie eene et 6 31 MODEL SETUP 2
9. The 489 Site Device has now been configured via the Quick Connect feature for serial communications Proceed to Connecting to the Relay on page 4 19 to begin communications 4 3 3 Configuring Ethernet Communications gt Before starting verify that the Ethernet cable is properly connected to the RJ 45 Ethernet port 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 4 17 CHAPTER 4 INTERFACES gt Install and start the latest version of the EnerVista 489 Setup software available from the GE EnerVista CD See the previous section for the installation procedure gt Click on the Device Setup button to open the Device Setup window V Click the Add Site button to define a new site Enter the desired site name in the Site Name field If desired a short description of site can also be entered along with the display order of devices defined for the site In this example we will use Pumping Station 2 as the site name gt Click the OK button when complete The new site will appear in the upper left list gt Click the Add Device button to define the new device gt Enter the desired name in the Device Name field and a description optional gt Select Ethernet from the Interface drop down list This will display a number of interface parameters that must be entered for proper Ethernet functionality Device Setup E Pumping Station 1 Ei Pumping Station 2 489 Relay 2
10. sc dpt 3 14 act al valles ie bee 6 15 SOC POINTS as 5 24 field breaker discrepancy 2 2222 22 00000 000 5 26 g n ral 5 22 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL INDEX ground switch 5 27 n EC 5 23 sequential TP sosro S 5 25 1 2 6 gehomiueter s 5 26 OSE 5 23 ipee 7 9 herma Tese cect M 5 23 DIMENSIONS uu ua bate asnapa has bob 3 2 DISPLAY c 4 1 DISTANCE ELEMENTS u tti t te ettet tu n td eet 5 56 DRAWOUT INDICATOR ice i e te ende ter iet eed Hecate tna 3 17 DUAL SETPOINNITS 2 5 totiens 5 8 5 24 E EMERGENCY RESTARTS cre rident ated ec cds 5 23 ENERVISTA VIEWPOINT WITH THE 489 4 44 ENTERING TEXT iiic Damen UR pas 4 5 ENVIRONMENT ctr Ri n ene eer ta Pee ires 2 15 ETHERNET Vdlues tien cea etai euet ede tapes at ee ce ast
11. 5 31 20 fl 5 30 A 24 OVERFREOUENGNY sescenti heit ble ed tsp atq 2 10 5 50 OVERLOAD CURVE MULETIPEIERS 5 75 OVERLOAD CURVES CUSTOM mE 5 76 5 32 standard ree e ba veo e e P eddy 5 75 LOS WU RR REOR TEE 7 12 OVERVOLTAGE cette de alc Ug e Cet cds 2 10 5 44 P PACKAGING c nete eui 2 15 PARAMETER AVERAGES uuu l uuu u la reife tee eed 6 22 ss 5 12 5 13 PASSCODE a 5 9 6 1 PEAK DEMAND iier eet e Un De UE a 5 17 6 20 PHASE CT PRIMARY irren iere cepe mt nee ti eer px ERES 5 18 5 19 PHASE IS ete UE A 13 PHASE CURRENT INPUTS ioter tete n eee ete tete Pete Rete 3 11 PHASE DIFFERENTIAL ieri dre pe deb E 5 39 PHASE DIFFERENTIAL TRIP TEST tette e te ims 7 16 PHASE OVERCURRENT u usun an n ttes eta ge ent 5 35 PHASE REVERSAL cial cete pees pecans dy thas eed a xad te uses 5 48 PHASE REVERSAL TEST Lace eR e diesen imb 7 14 POSITIVE SEQUENCE CURRENT 6 17 POWER DEMAND tinte tete emet dem eek eta ees 5 93 PO
12. H H H H H H H H H H H H ta g j H P P ul aS w N P gt H p lt 3 gt 9 02 c lt gt UNDERFREQUENCY PICKUP Not Enabled OVERFREQUENCY PICKUP Not Enabled PICKUP Not Enabled NEUTRAL U V 3rd PICKUP Not Enabled REACTIVE POWER PICKUP Not Enabled REVERSE POWER PICKUP Not Enabled LOW FORWARD POWER PICKUP Not Enabled PICKUP Not Enabled PICKUP Not Enabled PICKUP Not Enabled PICKUP Not Enabled PICKUP Not Enabled PICKUP Not Enabled PICKUP Not Enabled PICKUP Not Enabled PICKUP Not Enabled PICKUP Not Enabled PICKUP Not Enabled PICKUP Not Enabled OPEN SENSOR PICKUP Not Enabled SHORT LOW TEMP PICKUP Not Enabled 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL Range Range Range Range Range Range Range Range Range Range Range Range Range Range Range Range Range Range Range Range Range Not Enabled Ina Active Alarm La Not Enabled Ina Active Alarm La Not Enabled Ina Active Alarm La Not Enabled Ina Active Alarm La Not Enabled Ina Active Alarm La Not Enabled Ina Active Alarm La Not Enabled Ina Active Alarm La Not Enabled Ina Active Alarm La Not Enabled Ina Active Alarm La Not Enabled Ina
13. 4 10 Tel fere Eiern 4 30 serial Do newest 4 15 4 17 SPECIFICATION iu itis u S e e aaa te 2 6 SPEED R u 6 21 STANDARD OVERLOAD CURVES UME uu uuu 5 75 STARTER 5 17 OPCIOLONS aD 5 23 SUGKUS mE 5 21 STATOR GROUND FAULT 000 1 STATUSEED See ee 4 2 TACHOMETER sorrera 2 12 5 26 6 21 6 19 TEMPERATURE DISPLAY eee re ends 5 10 TERMINAL LAYOUT 3 7 TERMINAL EIS uuu a 3 8 TERMINAL LOCATIONS uuu uu stt Ete L 3 7 TERMINAL SPECIFICATIONS 2 15 TEST ANACOG OUTPUT aite u u Ene utei et be 5 103 DI SOGMIZSC 5 23 TEST OUTPUT Skee gens 5 102 TESTS differential current accuracy 22222 20220006550000000 7 5 ground curremtee cur d6y s usui eate ce pese ro TR UR Rb ce 7 5 7 15
14. Pickup Trip Pickup Trip Pickup Trip Pickup Trip Time Illy Time M pkp Time Time ms ms ms ms 1 03 2 9 49 10 5 1 05 3 0 5 0 11 0 11 3 1 5 1 11 5 1 2 3 2 5 2 12 0 1 3 3 3 5 5 12 5 14 3 4 5 4 13 0 15 3 5 5 5 13 5 16 3 6 5 6 14 0 17 3 7 5 7 14 5 18 3 8 5 8 15 0 19 39 5 9 15 5 20 4 0 6 0 16 0 2 1 4 1 6 5 16 5 2 2 4 2 7 0 17 0 2 3 4 5 7 5 17 5 2 4 4 4 8 0 18 0 2 5 4 5 8 5 18 5 2 6 4 6 9 0 19 0 27 4 7 9 5 19 5 28 4 8 10 0 20 0 Definite Time Curve The definite time curve shape causes a trip as soon as the pickup level is exceeded for a specified period of time The base definite time curve delay is 100 ms The curve multiplier of 0 00 to 1000 00 makes this delay adjustable from instantaneous to 100 00 seconds in steps of 1 ms where Trip Time in seconds M Multiplier Setpoint l Input Current pickup Pickup Current Setpoint T Mx 100 ms when I gt 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL pickup EQ 0 7 CHAPTER 5 SETPOINTS 5 6 2 Overcurrent Alarm PATH SETPOINTS gt V S5 CURRENT ELEM gt OVERCURRENT ALARM 1 OVERCURRENT D 6 OVERCURRENT Range Off Latched Unlatched ALARM ALARM Off ASSIGN ALARM Range Any combination of Relays 2 to RELAYS 2 5 5 5 OVERCURRENT ALARM Range 0 10 to 1 50 x FLA in steps of ESSAGE LEVEL 1 01 x FLA 0 01 OVERCURRENT ALARM Range 0 1 to 250 0 s in steps of 0 1 DELAY 0 1 s Range
15. Temperature 100 O Pt 120 Q Ni 100 O Ni 10 O Cu oF DIN 43760 180 356 168 47 280 77 233 97 16 00 190 374 172 46 291 96 243 30 16 39 200 392 175 84 303 46 252 88 16 78 210 410 179 51 315 31 262 76 17 17 220 428 183 17 327 54 272 94 17 56 230 446 186 82 340 14 283 45 17 95 240 464 190 45 353 14 294 28 18 34 250 482 194 08 366 53 305 44 18 73 5 9 2 RTDs 1to6 PATH SETPOINTS D V S8 RTD TEMPERATURE PV RTD 1 6 1 RTD 1 D 1 APPLICATION Stator None RTD 1 NAME e ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE lt gt lt gt lt gt lt gt lt gt lt gt lt gt lt gt lt gt gt lt gt lt gt lt gt ESSAGE E gt RTD 1 ALARM ASSIGN ALARM RELAYS 2 5 RTD 1 ALARM TEMPERATURE RTD 1 ALARM EVENTS Off RTD 1 TRIP ASSIGN TRIP RELAYS 1 4 RTD 1 TRIP TEMPERATURE jj Fh Fh 5 130 C RTD 1 TRIP VOTING H Fh dese 155 C Stator Bearing Ambient Other Range 8 alphanumeric characters Range Off Latched Unlatched Range Any combination of Relays 2 to 5 Range 1 to 250 C in steps of 1 Range On Off Range Off Latched Unlatched Range RTD 1 to RTD 12 Range Any combination of Relays 1 to 4 Range 1 to 250 C in steps of 1 RTDs 1 through 6 default to Stator RTD type There are individual alarm and trip conf
16. PRESFAUET SETUP eh tee e ee e FAULT SETUP TEST OUTPUT RELAYS TEST ANALOG OUTPUT COMM PORT MONITOR nee e iet texte a WN FACTORY SERVICE erect yaka OVERVIEW ACTUAL VALUES MAIN MENU DESCRIPTIO pA PD ko Et EE MM an Le EI D E NETWORK STATUS GENERATOR STATUS LAST TRIP DATA HARM STATUS a a uay ented sect MM MD eM LARM PICKUPS IGITAL INPUTS EAL TIME CLOCK Ae METERING DUEB NUMEN C SE CURRENT METERING 02020 6 4004 VOLTAGE METERING POWER METERING a asalan n qa a qa qasi qq qamnaw akha qaqa ai TEMPERATURE iR petes m DEMAND METERING un cecssessssessssssssssscssesssssessssecssssesssssessesessesssseesssscessssessessssecsssecessssessesesseees gt DOL 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL TOC TABLE OF CONTENTS ANALOG SPEED RU QUU 6 22 PARAMETER AVERAGES ua cation Sau qa kanya Qua A D d ERE RUE 6 22 RIDUIMAXIMUMS zc cete ect reete e iet dete tib te u aan a ERREUR 6 22
17. 5 95 RUNNING HOURS ait tete eere ri e edi 5 23 S SEQUENTIAL TRIP ote iene ab 2 12 5 25 SERIAL PORTS uum trend ine d P EI I SS 5 12 SERIAL START STOP INITIATION 2 5 20 SERVICE RELAY ai mut EPUM 3 17 SETPOINT ENTR Yenerin mode tee atre e uska 4 6 SETPOINT MESSAGE MAP eet tator ir ir assis 5 1 SETPOINTS ds 1 9 asc 5 8 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL INDEX entering with EnerVista 489 setup software 4 21 loading from eee pue deett Geor ag telo 4 28 e 5 1 CA A a 1 10 m 4 30 1 15 SIMULATION MODE iint eee adie aretha preteen 5 100 SINGLE LINE DIAGRAM cn e te ete eere e e RR 2 1 SLAVE ADDRESS tectae Boop dpa ie 5 13 SOFTWARE entering tereti sepes Una Red 4 21 hardware 0 0 0000008 4 10 eL 4 12 s etpolfBlS 4 28 UII
18. 55 55 55 55 lt gt lt gt lt gt lt gt lt gt lt gt lt gt CLEAR LAST TRIP Range No Yes DATA No RESET MWh and Mvarh Range No Yes METERS No CLEAR PEAK DEMAND Range No Yes DATA No CLEAR RTD Range No Yes MAXIMUMS No CLEAR ANALOG I P Range No Yes MIN MAX No CLEAR TRIP Range No Yes COUNTERS No CLEAR EVENT Range No Yes RECORD No CLEAR GENERATOR Range No Yes INFORMATION No 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS CLEAR BREAKER Range No Yes MESSAGE A INFORMATION No These commands may be used to clear various historical data CLEAR LAST TRIP DATA The Last Trip Data may be cleared by executing this command CLEAR MWh and Mvarh METERS Executing this command will clear the MWh and Mvarh metering to zero CLEAR PEAK DEMAND DATA Execute this command to clear peak demand values CLEAR RTD MAXIMUMS All maximum RTD temperature measurements are stored and updated each time a new maximum temperature is established Execute this command to clear the maximum values CLEAR ANALOG I P MIN MAX The minimum and maximum analog input values are stored for each Analog Input Those minimum and maximum values may be cleared at any time CLEAR TRIP COUNTERS There are counters for each possible type of trip Those counters may be cleared by executing this command CLE
19. NEUTRAL UNDERVOLTAGE LOSS OF EXCITATION DISTANCE ELEMENT S7 POWER ELEMENT POWER MEASUREMENT CONVENTIONS 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUA 5 L TOC III TABLE OF CONTENTS 6 ACTUAL VALUES TOC IV REACTIVE POWER iinan n ib m REP 5 61 REVERSE POWER yah 5 62 LOW FORWARD POWER eerte PUE kaa a RO ED eo 5 63 S8 RTD TEMPERATURE UBND TIS RDS TETO RU M eT S RTDS 7 TO 10 5 esca caeco ed b ce cedet e ana unquq asal 5 66 a wa a D 5 67 REDE Sedat Sa 5 67 OPENIRUD SENSOR u uwa a aa Un ee ae LR e RE NR 5 68 RTD SHORT LOW TEMP ttt ttt ttt ttt tt ttt 5 69 S9 THERMAL MODEL 489 THERMAL MODEL MODEL SETUP THERMAL ELEMENTS SR La nun i eec ect at tiet iet xata DM RIP COUNTER BREAKER FAILURE TRIP COM MONITOR pet VAN BUSSE NU RE D PULSE OUTPUT RUNNING HOUR SETUP s na a aan aa aqha has nha aquy S11 ANALOG INPUTS OUTPUTS ANALOG OUTPUTS 1 TO 4 ANALOG INPUTS 1 TO 4 SEZ SIMULATION MODE erecto ere eor
20. 70 7 1 negative sequence current accuracy 7 6 reutcalcurrent ACCURACY vais ise cte eei ek deae ci i eS Varo e een ted 7 5 neutral voltage decUtFacy Seda ae 7 6 7 16 Output current deu dGy lt up Dev ead 7 4 OUUPUUTOIAYS 7 11 OVEFOO OU 7 12 pliase c rrent 7 4 DOWER medsuteitienb u ecce recte eet pe 7 13 io defe 0 fle E gc PEE 2 14 FECCUVE POWT Bors nhu 7 13 RED OCCU M S 7 7 secondary injection Setup isset ae tecta eo tr er da Some d ut le uet beg Ve ves 7 3 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL INDEX E 7 4 7 14 TEXT SETPOINT S tu th oa dote eed Gets 1 15 THERMAL CAPACITY USED ul eter E eec s 6 4 THERMAL ELEMENTS ele 5 89 THERMAL MODEL MOCMIME COON ING saka 5 85 cerent 5 70 for 2 10 tn 5
21. BREAKER AUX TRIP COIL CONTACTS ose 52a B TRIP COIL OPEN CLOSED SUPERVISION 52 Open Closed VALUE OF RESISTOR R SUPPLY OHMS WATTS 48 VDC 10K 2 125 VDC 25 5 808727A1 CDR 250 VDC 50K 5 FIGURE 5 25 Trip Coil Supervision 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 5 91 5 92 5 11 4 VT Fuse Failure CHAPTER 5 SETPOINTS PATH SETPOINTS V S10 MONITORING V VT FUSE FAILURE FUSE gt VT FUSE FAILURE Range Off Latched Unlatched FAILURE 0 ALARM Off ASSIGN ALARM Range Any combination of Relays 2 to RELAYS 2 5 5 5 VT FUSE FAILURE Range On Off MESSAGE ALARM EVENTS Off A fuse failure is detected when there are significant levels of negative sequence voltage without corresponding levels of negative sequence current measured at the output CTs Also if the generator is online and there is not significant positive sequence voltage it could indicate that all VT fuses have been pulled or the VTs are racked out If the alarm is enabled and a VT fuse failure detected elements that could nuisance operation are blocked and an alarm occurs These blocked elements include voltage restraint for the phase overcurrent undervoltage phase reversal and all power elements 1 1 lt 20 V3 V gt 25 gt 0 075 x CT V gt 0 05 x Full Scale Breaker Status Online lt 0 05 x Full Scale AND Appropriate Elements amp
22. FIGURE 7 3 Secondary Injection Test Setup 3 INSTRUCTION MANUAL 808822A2 CDR CHAPTER 7 TESTING 7 3 10 Voltage Restrained Overcurrent Accuracy Setup the relay as shown in FIGURE 7 3 Secondary Injection Test Setup 3 on page 7 19 gt In the S2 SYSTEM SETUP D V GEN PARAMETERS menu set GENERATOR RATED MVA 100 MVA GENERATOR VOLTAGE PHASE PHASE 12000 gt In the S2 SYSTEM SETUP gt V VOLTAGE SENSING menu set VT CONNECTION TYPE Open Delta VOLTAGE TRANSFORMER RATIO 100 1 gt In the 85 CURRENT ELEMENTS gt OVERCURRENT ALARM menu set OVERCURRENT ALARM Unlatched O C ALARM LEVEL 1 10 x FLA OVERCURRENT ALARM DELAY 2 s O C ALARM EVENTS On gt In the SS CURRENT ELEMENTS gt V PHASE OVERCURRENT menu set PHASE OVERCURRENT TRIP Latched ENABLE VOLTAGE RESTRAINT Yes PHASE O C PICKUP 1 5 x CT CURVE SHAPE ANSI Extremely Inv O C CURVE MULTIPLIER 2 00 O C CURVE RESET Instantaneous The trip time for the extremely inverse ANSI curve is given as B D E Time to Trip Mx P y l EQ 7 8 p _ K x lp K xl where M O C CURVE MULTIPLIER setpoint input current p PHASE O C PICKUP setpoint A B C D E curve constants where A 0 0399 B 0 2294 0 5000 D 3 0094 and E 0 7222 voltage restrained multiplier optional The voltage restrained multiplier is
23. signal is the input signal for the 489 neutral overvoltage protection element This element has an alarm and a trip function with separately adjustable operate levels and time delays The trip function offers a choice of timing curves as well as a definite time delay The neutral overvoltage function responds to fundamental frequency voltage at the generator neutral It provides ground fault protection for approximately 95 of the stator winding The limiting factor is the level of voltage signal available for a fault in the bottom 5 of the stator winding The element has a range of adjustment for the operate levels of 2 to 100 V n Generator 3 32 2 2 AAAS a L j R is selected for a maximum fault current of 10 A typically Overvoltage Relay Distribution Transformer AAAS 2 808739A1 CDR FIGURE A 1 Stator Ground Fault Protection The operating time of this element should be coordinated with protective elements downstream such as feeder ground fault elements since the neutral overvoltage element will respond to external ground faults if the generator is directly connected to a power grid without the use of a delta wye transformer In addition the time delay should be coordinated with the ground directional element discussed later if it is enabled by using a longer delay on the neutral overvoltage element than on the directional element It is recommende
24. Switch off the current Set pre fault current I and ly equal to 3 5 x CT At this value the conditions for CT saturation detection are set and the relay will enable the directional check Set fault current 1 equal to 0 95 x Iygpo Switch on the test set The relay should restrain Switch off the current Repeat steps from Minimum Pickup Check onward for phases B and C Test Results Test Phase A Phase B Phase C Calculated Measured Calculated Measured Calculated Measured Minimum Pickup Test Phase A Phase B Phase C CT 5x CT CT 5x CT CT 5x CT Single Infeed Fault 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 7 TESTING Test Phase A Phase B Phase C operate restrain operate restrain operate restrain Slope 1 lx ly Operation OK not OK Slope 2 lx ly Operation OK not OK Check Directional l N A N A N A ly N A N A N A Operation OK not N A N A N A 7 3 9 Injection Test Setup 3 Setup the 489 device as follows for the Voltage Restrained Overcurrent test 489 GENERATOR MANAGEMENT RELAY 3 PHASE VARIABLE AC TEST SET GROUND INPUTS SAREE AUTOMATIC CT NEUTRAL END CT s SHORTING BAR
25. Hom CD 6 Web Select Product to Add 239 Motor Protection Relay 269Plus Motor Management Relay 363 Motor Management Relay 469 Motor Management Relay 735 737 Feeder Relay 745 Transformer Management Relay 750 Feeder Management Relay 760 Feeder Management Relay ALPS Advanced Line Protection System B30 Bus Differential Relay B30 Bus Differential System C30 Controller C60 Breaker Management Relay D30 Line Distance Relay D60 Line Distance Relay El indicates Set up Program exists in Software Library 01 46 57 CHAPTER 4 INTERFACES EnerVista Launchpad will obtain the latest installation software from the Web or CD and automatically start the installation process A status window with a progress bar will be shown during the downloading process gt 92 GE Muttilin enerVista LAUNCH N PAD gt Select the complete path including the new directory name where the EnerVista 489 Setup software will be installed gt Click on Next to begin the installation The files will be installed in the directory indicated and the installation program will automatically create icons and add EnerVista 489 Setup software to the Windows start menu gt Click Finish to end the installation The 489 device will be added to the list of installed IEDs in the EnerVista Launchpad window as shown below gt enerVista Launchpad x e 9 GE Multilin enervVista LAUNCH J PAD
26. ae BY Dep 007 007 01 02 25 Di 02 18 2 5 10 SECONDARY EXCITING CURRENT A 60Hz ep ao lt v on ON 0 56 1 7 70 Pees 14 195 4 0 44 1 0 SLOTS 11 18 25 4 9 88 251 4 94 1 125 10 32 SCREWS n f CO oS 010 aN an s ales 7 50 Te 190 4 0 56 0 HOLES 14 22 Inches mm APPROX WEIGHT 50 lbs 3 3 Phase CTs 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL GCT16 SECONDARY VOLTAGE 50 Hz MODEL CORE BALANCE P N 0121825597 1000 901 002 005 DIMENSIONS 41 02 05 0 SECONDARY EXCITING F FRONT VIEW 22 20 INCHES 564 20 70 from 18 20 526 462 462 13 20 _ 335 21 20 538 18 20 462 16 20 411 0 42 Dia HOLES SIDE VIEW 9 60 244 2 50 63 5 808709A1 CDR EXCITATION CURVE SECONDARY VOLTAGE 60 Hz CHAPTER A APPENDIX Current transformers in most common ratios from 50 5 to 1000 5 are available for use as phase current inputs with motor protection relays These come with mounting hardware and are also available with 1 A secondaries Voltage class 600 V BIL 10 KV 01 02 05 01 02 05 10
27. z o TD 1 RTD 2 RTD 3 COMPENSATION 5 8 COMPENSATION D t TD 5 BH a RTD RETURN COMPENSATION HOT COMPENSATION RTD 6 TD 7 HE RTD RETURN COMPENSATION HOT COMPENSATION RTD RETURN 3 3 5 5 8 COMPENSATION HOT COMPENSATION RTD RETURN RTD 11 a a 3 2 COMPENSATION HOT ss 2l lx 5 AUTOMATIC CT SHORTING OUTPUT CT s VOLTAGE INPUTS POWER T O fo over crono fo 5 SWITCH 24 SWITCH O common O TRIGGER TRIGGER TECE TECCENI TECEN Pa esenee ZECCO migas ACCESS BREAKER E STATUS WUSA 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 9 SECONDARY INJECTION TEST SETUP GE Multilin COMPUTER AUXILIARY ANSHS 3 eo 5 RS485 D RS485 gt gt gt gt 808818A3 CDR FIGURE 7 1 Secondary Current Injection Testing 7 3 CHAPTER 7 TESTING 7 2 Hardware Functional Tests 7 2 1 Output Current Accuracy The specification for output and neutral end current input is 0 5 of 2 x CT
28. 2 6 ground Tegu C er eer ae 13 ssi c s A 13 SEPON Seni 5 18 Iberi 2 6 CURRENT ACCURACY TEST edet stone eee teta 7 4 CURRENT DEMAND itcr neta eer ena txt ue EE ecd a ue A S 5 93 CURRENT INPUTS iade tere tee eae ete t Eton aud 2 7 CURRENT METERING u u ec eterne rie cide tene 6 16 CURRENT SENSING u uu beast tat bauer ettet eget breed Lose seva 5 18 CURVES see OVERLOAD CURVES CUSTOM OVERLOAD CURVE iE edie ie 5 76 D DEFAULT MESSAGES ctt d nete dot 5 10 5 14 5 15 DEFINITE TIME CURVE 2 uuu trece ede pee dte dte 5 32 A 19 DEMAND DATA sass u 5 23 DEMAND METERING eec 2 12 5 93 6 20 DEMAND PERIOD ctt tet n tee e ek t aequ 5 94 DESCRIPTION 2 1 DEVICE NUMBERS hag redit ed IER ERR cr ane 2 2 DIAGNOSTIC MESSAGES cse teret inter ade Eo Se Pe te Ret ded 6 32 DIELECTRIC STRENGTH specications e HE 2 14 KSLA 3 18 DIFFERENTIAL CURRENT ACCURACY TEST 22 7 5 DIGITAL COUNTER iiie eate aod ceste t etes dee int citat kr d added 5 23 DIGITAL INPUTS u uu asset
29. 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 4 INTERFACES HOT STATOR Indicates that the generator stator is above normal temperature when one of the stator RTD alarm or trip elements is picked up or the thermal model trip element is picked up NEG SEQUENCE Indicates that the negative sequence current alarm or trip element is picked up GROUND Indicates that at least one of the ground overcurrent neutral overvoltage fundamental or neutral undervoltage 3rd harmonic alarm trip elements is picked up LOSS OF FIELD Indicates that at least one of the reactive power kvar or field breaker discrepancy alarm trip elements is picked up VT FAILURE Indicates that the VT fuse failure alarm is picked up BREAKER FAILURE Indicates that the breaker failure or trip coil monitor alarm is picked up Output Status LED Indicators 1 TRIP The 1 Trip relay has operated energized 2 AUXILIARY The 2 Auxiliary relay has operated energized 3 AUXILIARY The 3 Auxiliary relay has operated energized 4 AUXILIARY The 4 Auxiliary relay has operated energized 5 ALARM The 5 Alarm relay has operated energized 6 SERVICE The 6 Service relay has operated de energized 6 Service is fail safe normally energized 413 RS232 Program Port This port is intended for connection to a portable PC Setpoint files may be created at any location and downloaded through this port with the EnerVista 489 Setup software Local
30. ESSAG ESSAG ESSAG ESSAG ESSAG ESSAG 2 60 60 69 69 09 lt gt lt gt lt gt lt gt lt gt e lt gt lt gt lt gt lt gt lt gt lt gt lt gt lt gt 09 END OF PAGE Be RIP P gt BREAKER TRIP COIL MONITOR VT FUSE FAILURE CURRENT MW DEMAND Mvar DEMAND MVA DEMAND PULSE RUNNING END OF PAGE E E gt We We We We Ne Et E Et Et Et E E o o o o o o o Q Q Q Q Q Q Q 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL D D P gt D P gt D n ee See See See See See See See See See See See See See See See See page page page page page page page page page page page page page page page page page 5 90 5 90 5 91 5 92 5 93 5 93 5 93 5 93 5 94 5 95 5 96 5 96 5 96 5 96 5 98 5 98 5 98 5 5 5 6 SETPOINTS CHAPTER 5 SETPOINTS lt gt s MESSAGE 5 5 98 anatoc END OF PAGE t 5 100 S s gt SIMULATION gt gs m ESSAGE PRE See page 5 101 FAULT gt e ESSAGE 5 5 102 FAULT gt ESSAGE 5 5 102 x gt lt gt n ESSAG
31. Names as programmed NOTE The current level of the 12 RTDs will be displayed here If the RTD is not connected the value will be No RTD If the RTD is shorted then will be displayed If no RTDs are programmed in the 57 RTD TEMPERATURE setpoints menu the THIS FEATURE NOT PROGRAMMED flash message will appear when an attempt is made to enter this group of messages 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 6 19 CHAPTER 6 ACTUAL VALUES 6 3 5 Demand Metering PATH ACTUAL VALUES V 2 METERING DATA D V DEMAND METERING METERING DEMAND 0 Amps I MW DEMAND Range 0 to 2000 000 MW Not seen if ESSAGE 0 000 MW VT CONNECTION TYPE is None Mvar DEMAND Range 0 to 2000 000 Mvar Not seen if ESSAGE 0 000 Mvar VT CONNECTION TYPE is None MVA DEMAND Range 0 to 2000 000 MVA Not seen if ESSAGE EA 0 000 MVA VT CONNECTION TYPE is None Range 0 to 999999 A PEAK CURRENT g DEMAND 0 Amps I MW DEMAND Range 0 to 2000 000 MW Not seen if ESSAGE 0 000 MW VT CONNECTION TYPE is None _ lt PEAK Mvar DEMAND Range 0 to 2000 000 Mvar Not seen if ESSAGE 0 000 Mvar VT CONNECTION TYPE is None I PEAK MVA DEMAND Range 0 to 2000 000 MVA Not seen if ESSAGE 0 000 MVA VT CONNECTION TYPE is None The values for current and power demand are shown here This peak demand information be cleared using the 51 489 SETUP gt V CLEAR DATA V CLEAR PEAK DEMAND setpoint Demand is sho
32. TEMPERATURE DISPLAY Range Celsius Fahrenheit I e ESSAGE ESSAGE Some of the 489 characteristics can be modified to suit different situations Normally the S1 489 SETUP gt V PREFERENCES setpoints group will not require any changes DEFAULT MESSAGE CYCLE TIME If multiple default messages are chosen the display automatically cycles through these messages The messages display time can be changed to accommodate different reading rates DEFAULT MESSAGE TIMEOUT If no keys are pressed for a period of time then the relay automatically scans through a programmed set of default messages This time can be modified to ensure messages remain on the screen long enough during programming or reading of actual values PARAMETER AVERAGES CALCULATION PERIOD The period of time over which the parameter averages are calculated may be adjusted with this setpoint The calculation is a sliding window TEMPERATURE DISPLAY Measurements of temperature may be displayed in either Celsius or Fahrenheit Each actual value temperature message will be denoted by either C for Celsius or F for Fahrenheit RTD setpoints are always displayed in Celsius WAVEFORM TRIGGER The trigger setpoint allows the user to adjust how many pre trip and post trip cycles are stored in the waveform memory when a trip occurs A 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS value of 25 for example when the WAVEFORM MEMORY BUFFER i
33. The trip pickup messages may be very useful during testing They will indicate if a trip feature has been enabled if it is inactive not picked up timing out picked up and timing active trip still picked up timed out and causing a trip or latched tip no longer picked up but had timed out and caused a trip that is latched These values may also be particularly useful as data transmitted to a master device for monitoring 6 2 6 Alarm Pickups PATH ACTUAL VALUES gt STATUS V ALARM PICKUPS ALARM PICKUPS D Input A Range PICKUP Not Enabled lt gt Input gt PICKUP Not Enabled PICKUP Not Enabled PICKUP Not Enabled ESSAGE amp PICKUP Not Enabled essace FY Input idis 7 PICKUP Not Enabled ecsage gt Input Range PICKUP Not Enabled ecsage Input E Range PICKUP Not Enabled ESSAGE E PICKUP Not Enabled essace Input UMS x PICKUP Not Enabled ecsage TACHOMETER Range PICKUP Not Enabled ecsage gt JOVERCURRENT Range ESSAGE lt NEG SEQ OVERCURRENT Range ecsage GROUND OVERCURRENT Range PICKUP Not Enabled ecsage GROUND DIRECTIONAL Range gt gt PICKUP Not Enabled ecsage UNDERVOLTAGE Range gt gt PICKUP Not Enabled gt OVERVOLTAGE Range x PICKUP Not Enabled
34. VOLTS HERTZ Not Enabled Inactive Timing Out Active Alarm Latched Alarm Not Enabled Inactive Timing Out Active Alarm Latched Alarm Not Enabled Inactive Timing Out Active Alarm Latched Alarm Not Enabled Inactive Timing Out Active Alarm Latched Alarm Not Enabled Inactive Timing Out Active Alarm Latched Alarm Not Enabled Inactive Timing Out Active Alarm Latched Alarm Not Enabled Inactive Timing Out Active Alarm Latched Alarm Not Enabled Inactive Timing Out Active Alarm Latched Alarm Not Enabled Inactive Timing Out Active Alarm Latched Alarm Not Enabled Inactive Timing Out Active Alarm Latched Alarm Not Enabled Inactive Timing Out Active Alarm Latched Alarm Not Enabled Inactive Timing Out Active Alarm Latched Alarm Not Enabled Inactive Timing Out Active Alarm Latched Alarm Not Enabled Inactive Timing Out Active Alarm Latched Alarm Not Enabled Inactive Timing Out Active Alarm Latched Alarm 6 12 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 6 ACTUAL VALUES ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE lt gt gt 02 02 9 02 02 02 02 9 9 02 02 02 02 02 02 02
35. ace ean ug poss en ose Hn ii TH iii FIGURE 4 9 Actual Values Display shown unconnected 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 4 43 CHAPTER 4 INTERFACES 4 7 Using EnerVista Viewpoint with the 489 4 7 1 Plug and Play Example EnerVista Viewpoint is an optional software package that puts critical 489 information on any PC with plug and play simplicity EnerVista Viewpoint connects instantly to the 489 via serial ethernet or modem and automatically generates detailed overview metering power demand energy and analysis screens Installing EnerVista Launchpad see previous section allows the user to install a fifteen day trial version of EnerVista Viewpoint After the fifteen day trial period you will need to purchase a license to continue using EnerVista Viewpoint Information on license pricing can be found at http www EnerVista com gt Install the EnerVista Viewpoint software from the GE EnerVista CD gt Ensure that the 489 device has been properly configured for either serial or Ethernet communications see previous sections for details gt Click the Viewpoint window in EnerVista to log into EnerVista Viewpoint At this point you will be required to provide a login and password if you have not already done so enerVista VIEWPOINT DEVICE SETUP EDITOR VIEWER ANNUNCIATOR ADMINISTRATION FIGURE 4 10 EnerVista Viewpoint Main Window gt Click the
36. gt Enter the IP address assigned to the relay gt Enter the slave address and Modbus port values from the st 489 SETUP D gt V COMMUNICATIONS menu in the Slave Address and Modbus Port fields gt Click the Read Order Code button to connect to the 489 device and upload the order code If a communications error occurs ensure that the 489 Ethernet communications values entered in the previous step correspond to the relay setting values 4 18 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 4 INTERFACES gt Click OK when the relay order code has been received The new device will be added to the Site List window or Online window located in the top left corner of the main EnerVista 489 Setup window The 489 Site Device has now been configured for Ethernet communications Proceed to the following section to begin communications 4 3 4 Connecting to the Relay Now that the communications parameters have been properly configured the user can easily connect to the relay gt Expand the Site list by double clicking on the site name or clicking on the box to list the available devices for the given site for example in the Pumping Station 1 site shown below gt Expand the desired device trees by clicking the box The following list of headers is shown for each device Device Definitions Setpoints e Actual Values e Commands Communications gt Expand the Setpoints gt P
37. the RTD name as programmed Range RTDs 1 to 12 Range RTDs 1 to 12 Range 1 to 10096 Range 1 to 10000 Range Active Latched Range Active Latched Range Active Latched Range 1 to 999999 A Range 2000 000 to 2000 000 MW Range 2000 000 to 2000 000 Mvar Range 0 to 2000 000 MVA Range 0 to 1000000 hrs Seen only if Running Hr Alarm is enabled Range 50000 to 50000 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 6 ACTUAL VALUES ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE MESSAGE Any active or latched alarms may be viewed here lt gt gt lt gt lt gt lt gt lt gt gt lt gt gt E gt e H 4 ANALOG I P 2 ALARM 201 Units ANALOG I P 3 ALARM 201 Units ANALOG I P 4 ALARM 201 Units ALARM 489 NOT INSERTED PROPERLY 489 NOT IN SERVICE Simulation Mode IRIG B FAILURE Range Range Range Range Range Range 50000 to 50000 50000 to 50000 50000 to 50000 N A Not Programmed Simulation Mode Output Relays Forced Analog Output Forced Test Switch Shorted Active Seen only if IRIG B is enabled and the associated signal input is lost The various alarm and alarm status actual values reflect the Input Name as programmed in the first line of the message The status is Active if the condition that caused the alarm is still presen
38. 3 Press the ENTER key to store this change into memory As before confirmation of this action will momentarily flash on the display NEW SETPOINT HAS BEEN STORED 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 1 GETTING STARTED 1 3 6 Text Setpoints Text setpoints have data values which are fixed in length but user defined in character They may be comprised of uppercase letters lowercase letters numerals and a selection of special characters The editing and storing of a text value is accomplished with the use of the decimal VALUE and ENTER keys For example gt Move to the S3 DIGITAL INPUTS gt GENERAL INPUT A gt V INPUT NAME message INPUT NAME Input A The name of this user defined input will be changed in this example from the generic Input A to something more descriptive If an application is to be using the relay as a station monitor it is more informative to rename this input Stn Monitor gt Press the decimal key to enter the text editing mode The first character will appear underlined as follows INPUT NAME Input A Press the VALUE keys until the character S is displayed in the first position Press the decimal key to store the character and advance the cursor to the next position Change the second character to a t in the same manner Continue entering characters in this way until all characters of the text Stn Monitor are entered
39. 50 to 250 Top line displays the RTD name as programmed 50 to 250 Top line displays the RTD name as programmed 5 7 ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE 6 8 90209020902 00 09 09 09 07 09 07 09 09 9 lt gt gt lt gt gt lt gt gt lt gt lt gt lt gt lt gt OPEN SENSOR ALARM dk m N w gs Ui SHORT LOW TEMP ALARM H H o H H THERMAL MODEL TRIP COUNTER BREAKER FAILURE ALARM Active TRIP COIL MONITOR ALARM Active VT FUSE FAILURE ALARM Active CURRENT DEMAND MW DEMAND Mvar DEMAND MVA DEMAND GEN RUNNING HOURS ANALOG I P 1 201 Units CHAPTER 6 ACTUAL VALUES Range 50 to 250 C Top line displays the RTD name as programmed Range 50 to 250 C Top line displays the RTD name as programmed Range 50 to 250 C Top line displays the RTD name as programmed Range 50 to 250 Top line displays the RTD name as programmed Range 50 to 250 Top line displays the RTD name as programmed Range 50 to 250 Top line displays the RTD name as programmed Range 50 to 250 C Top line displays the RTD name as programmed Range 50 to 250 Top line displays
40. 55 See page 5 27 GROUND gt Sonne edi END OF PAGE lt gt gt 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS m SETPOINTS gt 09 RELAY P gt MESSAGE gt 1 SETPOINTS 51 ESSAGE ESSAG ESSAG ESSAG ESSAG ESSAG ESSAG ESSAG ESSAG gt 1 SETPOINTS P S6 VOLTAGE ELEM ESSAG ESSAG ESSAG ESSAG ESSAG ESSAG 090909 09 09 09 09 09 69 60 69 09 09 END OF PAGE 1 OVERCURRENT ALARM P gt 1 OFFLINE OVERCURRENT 1 INADVERTENT ENERGIZATION 1 PHASE OVERCURRENT 1 NEGATIVE SEQUENCE 1 GROUND OVERCURRENT 1 PHASE DIFFERENTIAL 1 GROUND DIRECTIONAL 1 HIGH SET END OF PAGE 1 UNDERVOLTAGE 1 OVERVOLTAGE 1 VOLTS HERTZ 1 PHASE REVERSAL 1 UNDERFREQUENCY 1 OVERFREQUENCY 1 NEUTRAL FUNDAMENTAL 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL D gt PHASE OVERCURRENT D gt gt gt gt D gt page page page page page page page page page page page page page page page 5 28 5 33 5 33 5 34 5 35 5 36 5 38 5
41. ALARM Off ASSIGN ALARM Range Any combination of Relays 2 to RELAYS 2 5 5 5 REVERSE POWER ALARM Range 0 02 to 0 99 x Rated MW in ESSAGE steps of 0 01 LEVEL 0 05 x Rated be REVERSE POWER ALARM Range 0 2 to 120 0 s in steps of O 1 DELAY 10 0 s REVERSE POWER ALARM Range On Off ESSAGE EVENTS Off duet REVERSE POWER Range Off Latched Unlatched TRIP Off ASSIGN TRIP Range Any combination of Relays 1 to RELAYS 1 4 1 4 REVERSE POWER TRIP Range 0 02 to 0 99 x Rated MW in ESSAGE steps of 0 01 LEVEL 0 05 x Rated REVERSE POWER TRIP Range 0 2 to 120 0 s in steps of 0 1 ESSAGE DELAY 20 0 s If enabled once the magnitude of 3 phase total power exceeds the Pickup Level in the reverse direction negative MW for a period of time specified by the Delay a trip or alarm will occur The level is programmed in per unit of generator rated MW calculated from the rated MVA and rated power factor If the generator is accelerated from the power system rather than the prime mover the reverse power element may be blocked from start for a specified period of time A value of zero for the block time indicates that the reverse power protection is active as soon as both current and voltage are measured regardless of whether the generator is online or offline If the VT type is selected as None or VT fuse loss is detected the reverse power protection is disabled The minimum mag
42. MEME EVENTS Off When enabled a trip counter alarm will occur when the TRIP COUNTER ALARM LEVEL is reached The trip counter must be cleared or the alarm level raised and the reset key must be pressed if the alarm was latched to reset the alarm For example it might be useful to set a Trip Counter alarm at 100 trips prompting the operator or supervisor to investigate the type of trips that have occurred A breakdown of trips by type may be found in the A4 MAINTENANCE TRIP COUNTERS actual values page If a trend is detected it would warrant further investigation 5 11 2 Breaker Failure PATH SETPOINTS V S10 MONITORING gt V BREAKER FAILURE IBREAKER FAILURE Range Off Latched Unlatched BREAKER gt ALARM Off BREAKER FAILURE Range On Off ESSAGE ALARM EVENTS Off ASSIGN ALARM Range Any combination of Relays 2 to RELAYS 2 5 5 5 BREAKER FAILURE Range 0 05 to 20 00 x CT in steps of ESSAGE LEVEL 1 00 x CT 0 01 BREAKER FAILURE Range 10 to 1000 ms in steps of 10 ESSAGE DELAY 100 ms If the breaker failure alarm feature may be enabled as latched or unlatched If the 1 Trip output relay is operated and the generator current measured at any of the three output CTs is above the level programmed for the period of time specified by the delay a breaker failure alarm will occur The time delay should be slightly longer than the breaker clearing time 489 GENERATOR MANAGEMENT REL
43. Max continuous 280 VAC OUTPUT AND NEUTRAL END CURRENT INPUTS CT primary 10 to 50000 A CT secondary 1 5 A specify with order Conversion range 0 02 to 20 x CT Accuracy at 2 x CT x0 596 of 2 x CT at gt 2 x CT 1 of 20 x CT Burden Less than 0 2 VA at rated load CT withstand 1 s at 80 x rated current 2 s at 40 x rated current continuous at 3 x rated current PHASE VOLTAGE INPUTS VT ratio 1 00 to 300 00 1 in steps of 0 01 VT secondary 200 V AC full scale Conversion range 0 02 to 1 00 x full scale Accuracy 0 5 of full scale Max continuous 280 VAC Burden gt 500 RTDs 3 wire type 100 Q Platinum DIN 43760 100 Q Nickel 120 Q Nickel 10 Q Copper RTD sensing current 5 mA Isolation 36 Vpk isolated with analog inputs and outputs Range 50 to 250 C Accuracy 2 C 4 F for Pt and Ni 5 C 9 F for Cu Lead resistance 25 max per lead Pt and Ni types 3 max per lead Cu type NO sensor gt 1 kQ Short low alarm lt 50 C ANALOG CURRENT OUTPUT Type Active Range 4 to 20mA 0 to 1 mA must be specified with order Accuracy 1 of full scale 4 to 20 mA max load 1 2 Oto 1 mA max load 10 kQ Isolation 36 Vpk isolated with RTDs and analog inputs 4 assignable outputs phase A B C output current three phase average current negative sequence current generator load hottest stator RTD hottest bearing RTDs 1 to 12 voltage AB BC
44. Operate Alarm Relay AND N FIGURE 5 26 VT Fuse Failure Logic 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS 5 11 5 Demand PATH SETPOINTS gt V S10 MONITORING gt V CURRENT DEMAND CURRENT DEMAND CURRENT gt PERIOD 15 min gt CURRENT DEMAND i ALARM Off lt ASSIGN ALARM ESSAGE gt gt RELAYS 2 5 5 gt CURRENT DEMAND u LIMIT 1 25 x FLA D H D bg Es lt 2 n Fh Fh ue vim CURRENT DEMAND MW DEMAND gt MW DEMAND PERIOD 15 min gt MW DEMAND ALARM Off gt ASSIGN ALARM RELAYS 2 5 5 5 MW DEMAND E lt 2 H n Fh Fh ESSAGE LIMIT 1 25 x Rated DEMAND Mvar DEMAND b Mvar DEMAND PERIOD 15 min escace gt DEMAND ALARM Off ASSIGN ALARM ESSAGE RELAYS 2 5 5 lt Mvar DEMAND ESSAGE LIMIT 1 25 x Rated ESSAGE lt gt p g ug 224 n Fh Fh MVA DEMAND Pb MVA DEMAND PERIOD 15 min MVA DEMAND MESSAGE ALARM Off lt ASSIGN ALARM MESSAGE x RELAYS 2 5 5 2 MvA DEMAND MESSAGE LIMIT 1 25 x Rated 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL Range Range Range
45. 1 GROUND DIR TRIP Range 0 05 to 20 00 x CT in steps of PICKUP 0 05 x CT 0 01 GROUND DIR TRIP Range 0 1 to 120 0 sec in steps of 0 1 ESSAGE DELAY 3 0 sec iy The SUPERVISE WITH DIGITAL INPUTS setpoint is seen only if a digital input assigned to Ground Switch Status NOTE The 489 detects ground directional by using two measurement quantities Vo and lo The angle between these quantities determines if a ground fault is within the generator or not This function should be coordinated with the 59GN element 95 stator ground protection to ensure proper operation of the element Particularly this element should be faster This element must use a core balance CT to derive the signal Polarity is critical in this element The protection element is blocked for neutral voltages below 2 0 V secondary 4 pickup level for the ground current elements is programmed as a multiple of ground CT The 50 0 025 CT is intended for measuring very small ground fault currents when connected to a sensitive ground CT having the same ratio For example a pickup to 0 2xCT translates into 0 2x0 0025A 0 5mA secondary on the terminals of the sensitive ground CT with a relay measuring 0 2x5A 1 A primary A pickup setting of 0 05xCT would lead to 0 05x0 0025A 0 125mA secondary or 0 05x5A 0 25A primary current NOTE It is strongly recommended not to exceed the CT continuous rating of 150mA for long periods of
46. 10 MULTIPLIER 30 0 20 0 15 0 TRIP TIME sec 10 0 1 80 6 0 4 0 3 0 2 0 0 1 0 5 0 01 CURRENT 808807A3 CDR FIGURE A 15 IAC Very Inverse Curves 0 1 A 22 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER A APPENDIX 7 489 IAC GE Multilin EXTREME INVERSE 1000 100 MULTIPLIER TRIP TIME sec 30 0 20 0 15 0 10 0 8 0 6 0 4 0 3 0 0 1 2 0 0 1 1 CURRENT I Ipu 808806A4 CDR FIGURE A 16 IAC Extreme Inverse Curves 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL A 23 A 24 A 4 4 CHAPTER A APPENDIX IEC Curves 489 GE Multilin IEC CURVE A 5142 1000 100 MULTIPLIER 1 00 0 80 TRIP TIME sec 0 60 0 50 0 40 0 30 0 20 0 15 0 10 0 05 0 1 0 01 0 1 1 10 100 CURRENT I Ipu
47. 100 100 754 75 3 3 Cool Time Constant 15 min 2 Cool Time Constant 15 min gt TCused_start 85 TCused_start 85 8 Hot Cold Ratio 80 H Hot Cold Ratio 80 8 50 Y leq Overload Pickup 80 8 50 V leq Overload Pickup 100 Y X s N 5 5 25 25 V 0 0 0 30 60 90 120 150 180 0 30 60 90 120 150 180 Time in Minutes Time in Minutes 80 LOAD 100 LOAD 100 100 3 18 Cool Time Constant 30 min 3 Cool Time Constant 30 min 5 TCused_start 85 3 TCused_start 100 2 Hot Cold Ratio 80 2 Hot Cold Ratio 80 H N Motor Stopped after running Rated Load H Motor Overload g 50 N TCused_end 0 g 50 TCused_end 0 N E E N N N F 25 y b s 0 0 0 30 60 90 120 150 180 0 30 60 90 120 150 180 Time in Minutes Time in Minutes MOTOR STOPPED MOTOR TRIPPED 808705A2 CDR FIGURE 5 23 Thermal Model Cooling 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS Hot Cold Safe Stall Ratio When thermal limit information is available for both a hot and cold machine the 489 thermal model will adapt for the conditions if the HOT COLD SAFE STALL RATIO is programmed The value entered for this setpoint dictates the level of thermal capacity used that the relay will settle at for levels of current that are below the OVERLOAD PICKUP LEVEL When the generator is running at a level below the OVERLOAD PICKUP LEVEL the thermal capacity us
48. 11 1 12 4 13 8 15 2 16 6 18 0 19 4 20 8 00 0 9 8 7 5 4 3 2 15 1 39 2 78 4 16 5 55 6 94 8 33 9 71 11 1 12 4 13 8 15 2 16 6 18 0 19 4 20 8 00 0 9 8 7 5 4 3 2 20 1 39 2 78 4 16 5 55 6 94 8 33 9 71 11 1 12 4 13 8 15 2 16 6 18 0 19 4 20 8 00 0 9 8 7 5 4 3 2 Custom Overload Curve If the induction generator starting current begins to infringe on the thermal damage curves it may become necessary to use a custom curve to tailor generator protection so successful starting may be possible without compromising protection Furthermore the characteristics of the starting thermal locked rotor and acceleration and the running thermal damage curves may not fit together very smoothly In this instance it may be necessary to use a custom curve to tailor protection to the thermal limits to allow the generator to be started successfully and utilized to its full potential without compromising protection The distinct parts of the thermal limit curves now become more critical For these conditions it is recommended that the 489 custom curve thermal model be used The custom overload curve allows users to program their own curves by entering trip times for 30 pre determined current levels The curves below show that if the running overload thermal limit curve were smoothed into one curve with the locked rotor thermal limit curve the induction generator could not be
49. 151 0 75 0 44 4 Pou 19 11 s Y CT DIMENSIONS B 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER A APPENDIX A 4 Time Overcurrent Curves A 4 1 ANSI Curves 489 ANSI GE Muttilin MODERATELY INVERSE 1000 100 MULTIPLIER 10 G 30 0 m 20 0 150 a 100 E 8 0 6 0 1 40 30 20 10 0 1 i 0 01 ii 19 100 CURRENT 808802A4 CDR FIGURE A 8 ANSI Moderately Inverse Curves 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL A 15 TRIP TIME sec CHAPTER A APPENDIX 489 ANSI GE Muttilin NORMALLY INVERSE 1000 100 10 MULTIPLIER 30 0 20 0 15 0 10 0 8 0 6 0 40 3 0 20 1 0 0 1 05 0 01 0 1 1 10 100 CURRENT I Ipu 808801A4 CDR FIGURE A 9 ANSI Normally Inverse Curves 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER A APPENDIX 489 ANSI GE Multilin VERY INVERSE
50. 50000 to 50000 MAX O Units ESSAGE ESSAGE ESSAGE 00 69 09 69 090 These messages are seen only if the corresponding Analog Inputs are programmed The i actual messages reflect the Analog Input Names as programmed NOTE The 489 learns the minimum and maximum values of the analog inputs since they were last cleared This information can be cleared using the 51 489 SETUP gt V CLEAR DATA V CLEAR ANALOG I P MIN MAX setpoint When the data is cleared the present value of each analog input will be loaded as a starting point for both minimum and maximum The name of the input and the units will reflect those programmed for each input Analog Input minimums and maximums will not update if a digital input programmed as Test Input is shorted 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 6 23 6 24 CHAPTER 6 ACTUAL VALUES If no Analog Inputs are programmed in the s11 ANALOG 1 0 setpoints menu the THIS FEATURE NOT PROGRAMMED flash message will appear when an attempt is made to enter this group of messages 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 6 ACTUAL VALUES 6 5 A4 Maintenance 6 5 1 Trip Counters PATH ACTUAL VALUES V A4 MAINTENANCE gt TRIP COUNTERS TOTAL NUMBER OF Range 0 to 50000 TRIP D TRIPS 0 2 DIGITAL INPUT TRIPS 0 escace gt SEQUENTIAL gt TRriPS 0 ESSAGE FIELD BKR DISCREP TRIPS 0 C TACHO
51. ENABLE VOLTAGE Range No Yes RESTRAINT No VOLTAGE LOWER Range 10 to 6096 Seen only if ENABLE 5 VOLTAGE RESTRAINT IS Yes DS e LIMIT 10 is Yes lt PHASE OVERCURRENT Range 0 15 to 20 00 x CT in steps of PICKUP 10 00 x CT 0 01 ange See Table 5 1 vercurrent CURVE SHAPE Range See Table 5 1 489 O ANSI Extremely Inv Curve Types on page 29 FLEXCURVE TRIP TIME Range 0 to 65535 ms Seen only if ESSAGE AT 1 03 x PU 65535 ms CURVE SHAPE is Flexcurve FLEXCURVE TRIP TIME Range 0 to 65535 ms Seen only if MESSAGE AT 20 0 x PU 65535 ms CURVE SHAPE is Flexcurve OVERCURRENT CURVE Range 0 00 to 1000 00 in steps of 0 01 MULTIPLIER 1 00 Range Instantaneous Linear MESSAGE OVERCURRENT CURVE RESET Instantaneous If the primary system protection fails to properly isolate phase faults the voltage restrained overcurrent acts as system backup protection The magnitude of each phase current measured at the output CTs is used to time out against an inverse time curve The 489 inverse time curve for this element may be either ANSI IEC or GE Type IAC standard curve shapes This allows for simplified coordination with downstream devices If these curve shapes are not adequate FlexCurves may be used to customize the inverse time curve characteristics The voltage restraint feature lowers the pickup value of each phase time overcurrent element in a fixed relationship see figure below with the corre
52. FIGURE 3 1 489 Dimensions To prevent unauthorized removal of the drawout unit a wire lead seal can be installed in the slot provided on the handle as shown below With this seal in place the drawout unit cannot be removed A passcode or setpoint access jumper can be used to prevent entry of setpoints but still allow monitoring of actual values If access to the front panel controls must be restricted a separate seal can be installed on the outside of the cover to prevent it from being opened Seal location FIGURE 3 2 Drawout Unit Seal Hazard may result if the product is not used for its intended purpose WARNING 3 1 2 Product Identification Each 489 unit and case are equipped with a permanent label This label is installed on the left side when facing the front of the relay of both unit and case The case label details which units can be installed The case label details the model number manufacture date and special notes The unit label details the model number type serial number file number manufacture date phase current inputs special notes overvoltage category insulation voltage pollution degree control power and output contact rating 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 3 INSTALLATION GE Power Management GE Power Manage SR489 RELAY SR489 CASE GENERATOR MANAGEMENT RELAY MODEL NO 10 1 MODEL NO SERIAL NO 83260 MFG DATE FIRMWARE REV 3 0 MFG DATE
53. Generator Load Negative Sequence Current Ground Current and Neutral Current Differential Currents A B and C System Frequency Voltages Vbc Van Vbn amp Vcn Power Power Factor Real kW Reactive kvar and Apparent kVA Power Positive Watthours Positive and Negative Varhours Temperature Hottest Stator RTD Thermal Capacity Used RTDs 1 through 12 Demand Current Peak Current Reactive Power Peak Reactive Power Apparent Power Peak Apparent Power Others Analog Inputs 1 2 3 and 4 Tachometer 4 37 CHAPTER 4 INTERFACES With EnerVista 489 Setup running and communications established gt Select the Actual Values gt Trending menu item to open the trending window The following window will appear Trending Pumping Station 1 469 Relay 1 Actual values eee gt Select Stop to stop the data logger and Reset to clear the screen i 7 1 7 1 ul I el To prepare for new trending gt Select the graphs to be displayed through the pull down menu beside each channel description gt Select the Sample Rate through the pull down menu If you want to save the information captured by trending gt Check the box besides Log Samples to File The following dialog box will appear requesting for file name and path The file is saved as csv comma delimited values file which can be viewed and manipulated with co
54. INPUT 1 0 gt PRE FAULT ANALOG Range 0 to 100 in steps of 1 INPUT 2 0 ESSAGE PRE FAULT ANALOG Range 0 to 100 in steps of 1 INPUT 3 0 ESSAGE PRE FAULT ANALOG Range 0 to 10096 in steps of 1 The values entered under Pre Fault Values will be substituted for the measured values in the 489 when the SIMULATION MODE is Simulate Pre Fault 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 5 101 CHAPTER 5 SETPOINTS 5 13 5 Fault Setup PATH SETPOINTS D V S12 489 TESTING gt V FAULT SETUP FAULT Iphase Range 0 00 to 20 00 x CT in steps of FAULT Poe l pox o 64 ee a OUTPUT 0 0 01 ESSAGE FAULT VOLTAGES Range 0 00 to 1 50 x Rated in steps of I Ped PHASE N 1 00 x Rated 0 01 Enter as a phase to neutral quantity ESSAGE lt FAULT CURRENT Range 0 to 359 in steps of 1 I lt gt LAGS VOLTAGE 0 gt FAULT Iphase Range 0 00 to 20 00 x CT in steps of E NEUTRAL 0 00 x CT 0 01 180 phase shift with respect to OUTPUT ESSAGE lt FAULT CURRENT Range 0 00 to 20 00 x CT in steps of I GROUND 0 00 x 0 01 CT is either XXX 1 50 0 025 FAULT VOLTAGE Range 0 0 to 100 0 Vsec in steps of 0 1 NEUTRAL 0 Vsec Fundamental value only in secondary volts gt FAULT STATOR Range 50 to 250 C in steps of 1 i RTD TEMP 40 gt FAULT BE
55. Range Range Range Range Range Range Range Range Range Range Range Range Range Range Range Range 5 to 90 min in steps of 1 Off Latched Unlatched Any combination of Relays 2 to 5 0 10 to 20 00 x FLA in steps of 0 01 On Off 5 to 90 min in steps of 1 Off Latched Unlatched Any combination of Relays 2 to 5 0 10 to 2 00 x Rated in steps of 0 01 On Off 5 to 90 min in steps of 1 Off Latched Unlatched Any combination of Relays 2 to 5 0 10 to 2 00 x Rated in steps of 0 01 On Off 5 to 90 min in steps of 1 Off Latched Unlatched Any combination of Relays 2 to 5 0 10 to 2 00 x Rated in steps of 0 01 5 93 CHAPTER 5 SETPOINTS MVA DEMAND Range On Off MESSAGE gt ALARM EVENTS Off The 489 can measure the demand of the generator for several parameters current MW Mvar MVA The demand values of generators may be of interest for energy management programs where processes may be altered or scheduled to reduce overall demand on a feeder The generator FLA is calculated as Generator FLA ___GeneratorRatedMVA Rated MVA EQ 5 40 x Generator Rated Phase Phase Voltage Power quantities are programmed as per unit calculated from the rated MVA and rated power factor Demand is calculated in the following manner Every minute an average magnitude is calculated for current MW Mvar and MVA based on samples taken every 5
56. 0 00 Hz CONNECTION 5 None I lt NEUTRAL VOLT FUND Range 0 0 to 25000 0 V Seen only if ESSAGE PRETRIP 0 0 V there is a neutral VT I NEUTRAL VOLT 3rd Range 0 0 to 25000 0 V Seen only if ESSAGE SS PRETRIP 0 0 V there is a neutral VT lt REAL POWER MW Range 0 000 to x2000 000 MW Not E Z PRETRIP 0 000 seen if VT CONNECTION is None lt REACTIVE POWER Mvar Range 0 000 to 2000 000 Mvar Not ESSAGE j PRETRIP 0 00 Hz seen if VT CONNECTION is None lt APPARENT POWER MVA Range 0 000 to 2000 000 MVA Not ESSAGE j PRETRIP 0 00 Hz HOTTEST STATOR RTD Range n to 250 C Seen oniy if at RTD 1 0 PreTrip east one RTD is Stator T lt gt HOTTEST BEARING RTD Range 50 to 250 C Seen only if at RTD 7 0 C PreTrip least one RTD is Bearing HOTTEST OTHER RTD Range 50 to 250 C Seen only if at gt RTD 11 0 PreTrip least one RTD is Other 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 6 5 CHAPTER 6 ACTUAL VALUES AMBIENT RTD Range 50 to 250 C Seen only if at E RTD 12 0 C PreTrip least one RTD is Ambient I ANALOG INPUT 1 Range 50000 to 50000 Not seen if ESSAGE e 0 Units ANALOG INPUT 1 is Disabled I ANALOG INPUT 2 Range 50000 to 50000 Not seen if ESSAGE lt 0 Units ANALOG INPUT 2 is Disabled I ANALOG INPUT 3 Range 50000 to 50000 Not seen if ESSAG
57. 1 1 1 1 2 1 3 1 4 1 5 1 6 17 1 8 1 9 2 Multiples of Overvoltage Pickup 808741A1 CDR FIGURE 5 8 Neutral Overvoltage Curves AUXILIARY CONTACT TO DIGITAL INPUT FOR NEUTRAL O V SUPERVISION 94 GROUNDING SWITCH N ye e eo Y 2 N 3 B C B C Ne B eI Dd GENERATOR 1 GENERATOR 2 808816A3 CDR ___ TO Vneutral OF EACH 489 v FIGURE 5 9 Neutral Overvoltage Detection If the ground directional element is enabled the Neutral Overvoltage element should be coordinated with it In cases of paralleled generator grounds through the same point with individual ground switches per sketch below it is recommended to use a ground switch status function to prevent maloperation of the element 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS 5 7 8 Neutral Undervoltage 1 NEUTRAL U V 3rd HARMONIC wv NOTE PATH SETPOINTS gt V S6 VOLTAGE ELEM gt V NEUTRAL U V 3RD HARMONIC Range 0 02 to 0 99 x Rated MW in gt LOW POWER BLOCKING steps of 0 01 LEVEL 0 05 x Rated LOW VOLTAGE BLOCKING Range 0 50 to 1 00 x Rated in steps of ESSAGE 0 01 LEVEL 0 75 x Rated NEUTRAL UNDERVOLTAGE Range Off Latched Unlatched ESSAGE gt Ep D Fh Fh ASSIGN ALARM Range Any combination of Relays 2 to ESSAGE 5 RELAYS 2 5 5 NEUTRAL U V ALARM Range 0 5 to 20 0 Vsec i
58. 19200 19200 ESSAGE ADDRESS Range standard IP address format amp 0 0 0 0 ESSAGE SUBNET IP MASK Range standard IP address format 255 255 255 000 ATEWAY IP ADDRESS Range standard IP address format ESSAGE lt gt x 0 0 0 Ps g The IP addresses are used with the Modbus protocol Enter the dedicated IP subnet IP and gateway IP addresses provided by the network administrator To ensure optimal response from the relay the typical connection timeout should be set as indicated in the following table TCP IP sessions Timeout setting up to 2 2 seconds up to 4 3 seconds iy The RS485 COM2 port is disabled if the Ethernet option is ordered NOTE 5 2 4 RealTime Clock PATH SETPOINTS gt S1 489 SETUP V REAL TIME CLOCK REAL TIME gt 01 DATE MM DD YYYY Range 01 01 1995 to 12 31 2094 CLOCK 01 01 1995 Range 00 00 00 to 23 59 59 TIME HH MM SS g amp 12 00 00 IRIG B SIGNAL TYPE Range None DC Shift Amplitude MESSAGE Z NONE Modulated For events that are recorded by the event recorder to be correctly time date stamped the correct time and date must be entered A battery backed internal clock runs continuously even when power is off It has the same accuracy as an electronic watch approximately 1 minute per month It must be periodically corrected either manually through the front 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 5
59. 52 negative sequence current in per unit based on FLA 1 positive sequence current in per unit based on FLA constant relating negative sequence rotor resistance to positive sequence rotor resistance not to be confused with the k indicating generator negative sequence capability for an inverse time curve The figure below shows induction machine derating as a function of voltage unbalance as recommended by NEMA National Electrical Manufacturers Association Assuming a typical inrush of 6 x FLA and a negative sequence impedance of 0 167 voltage unbalances of 1 2 5 4 and 596 equal current unbalances of 6 12 18 24 and 30 respectively Based on this assumption the GE curve illustrates the amount of machine derating for different values of k entered for the UNBALANCE BIAS K FACTOR setpoint Note that the curve created when 8 is almost identical to the NEMA derating curve 1 05 105 gt 1 00 x 1 00 0 95 E 0 95 2 0 85 2 0 85 0 80 0 80 0 75 0 75 0 70 0 70 0 1 2 3 4 5 0 1 2 3 4 5 PERCENT VOLTAGE UNBALANCE PERCENT VOLTAGE UNBALANCE NEMA GE MULTILIN 808728A1 CDR If a k value of 0 is entered the unbalance biasing is defeated and the overload curve will time out against the measured per unit motor current k may be calculated conservatively as k Us typi
60. 9 08 13 6 18 1 22 7 27 2 31 8 36 3 40 8 45 4 49 9 54 5 59 0 63 5 68 1 0 3 7 1 5 0 4 8 2 7 1 5 9 4 4 7 4 06 8 11 12 1 16 2 20 2 24 3 28 3 32 4 36 5 40 5 44 6 48 6 52 7 56 7 60 8 5 7 2 8 3 9 4 0 5 1 6 2 7 3 5 0 3 64 7 29 10 9 14 5 18 2 21 8 25 5 29 1 32 7 36 4 40 0 43 7 47 3 51 0 54 6 0 3 7 2 6 0 5 9 3 8 2 6 1 5 5 5 2 99 5 98 8 97 11 9 14 9 17 9 20 9 23 9 26 9 29 8 32 8 35 8 38 8 41 8 44 8 0 6 5 4 3 1 0 9 8 7 6 5 4 89 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 5 75 CHAPTER 5 SETPOINTS Table 5 7 489 Standard Overload Curve Multipliers PICKUP STANDARD CURVE MULTIPLIERS x FLA x1 x2 x3 x4 x5 x6 x7 x8 x9 x10 x 11 x 12 x 13 x 14 x15 6 0 2 50 5 00 7 49 9 99 12 4 14 9 17 4 19 9 22 4 24 9 27 4 29 9 32 4 34 9 37 4 0 9 9 9 9 8 8 8 8 8 7 7 6 5 2 12 4 24 6 36 8 48 10 6 12 7 14 8 16 9 19 0 21 2 23 3 25 4 27 5 29 6 31 7 0 0 2 4 6 8 0 2 4 5 7 9 7 0 1 82 3 64 5 46 7 29 9 11 10 9 12 7 14 5 16 3 18 2 20 0 21 8 23 6 25 5 27 3 0 3 5 7 9 1 4 6 8 0 2 7 5 1 58 3 16 4 75 6 33 7 91 9 49 11 0 12 6 14 2 15 8 17 4 18 9 20 5 22 1 23 7 0 8 6 4 2 1 9 7 5 4 8 0 1 39 2 78 4 16 5 55 6 94 8 33 9 71 11 1 12 4 13 8 15 2 16 6 18 0 19 4 20 8 0 0 9 8 7 5 4 3 2 10 1 39 2 78 4 16 5 55 6 94 8 33 9 71
61. Apply the fault Switch off the current Record the operating time Set the prefault current equal to 0 Set the fault current equal to 5 x CT Apply the fault Switch off the current Record the operating time Connect the relay test set to inject Channel Y current ly into the G6 terminal and out of H6 terminal The angle between and Iy will be 180 Set pre fault current and ly equal to zero Set fault current y equal to 1 CT At this value the relay should operate according to the following formula V gt _ 2 Slope 1setting 3 x CT l s 1 2 4 Slope 1 setting EE EQ 7 6 Set fault current 1 equal to 0 95 x 1 Apply the fault The relay should operate Switch off the current Set fault current I equal to 1 05 x 1 Apply the fault The relay should restrain Switch off the current 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 2 17 Slope 2 Check gt CHAPTER 7 TESTING Set fault current ly equal to 2 5 CT At this value the relay should operate according to the following formula gt gt V gt Directional Check gt _ Slope 2 setting 2 4 Slope 2 setting EQ 7 7 Set fault current I equal to 0 95 x Ivop2 Switch on the test set The relay should operate Switch off the current Set fault current I equal to 1 05 x lyop Switch on the test set The relay should restrain
62. DEMAND METERING Metered values ssignable Digital Inputs 1 to 7 0 1 to 5000 0 s in steps of 0 1 0 to 5000 s in steps of 1 100 ms or 0 5 of total time Trip Alarm and Control assignable to Digital Inputs 1 to 7 0 02 to 0 99 x rated MW in steps of 0 01 Low Forward Power Reverse Power 0 2 to 120 0 steps of 0 1 see power metering 100 ms or 0 5 of total time Trip assignable to Digital Inputs 4 to 7 0 to 7200 RPM gt 10 101 to 175 x rated speed in steps of 1 1 to 250s in steps of 1 0 5 s or 0 596 of total time Trip and Alarm maximum phase current 3 phase real power 3 phase apparent power 3 phase reactive power Measurement type Demand interval rolling demand 5 to 90 min in steps of 1 Update rate 1 minute Elements Alarm ENERGY METERING Description continuous total of watthours and varhours Range 0 000 to 4000000 000 Mvarh Timing accuracy 0 5 Update Rate 50 ms LOW FORWARD POWER Block from online Oto 15000 s in steps of 1 Pickup level 0 02 to 0 99 x rated MW Time delay 0 2 to 120 0 s in steps of 0 1 Pickup accuracy see power metering Timing accuracy 100 ms or 0 596 of total time Elements Trip and Alarm 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 2 INTRODUCTION POWER METERING Range 2000 000 to 2000 000 MW 2000 000 to 2000 000 Mvar 0 to 2000 000 MVA Accuracy at layg lt 2 X CT 1 of 3 x 2x CT x VTratio Accura
63. OUTPUT RELAYS o 3 16 3 17 3 e 3 17 amp 3 17 BAI 3 17 sega se D as 3 17 SOU 5 28 Ct 2 8 ROS UMM Pr 7 11 Ule HT 3 16 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL INDEX OUTPUTS rc 2 7 3 15 G 5 38 Ground sa 5 40 ses au 5 42 MEGOUIVE SEQUENCO EUH 5 36 hrs E aussi 5 35 phase diftereritidl 5 39 SOUD OMNES tensa 5 33 e 2 9 2 10 Tp 5 29 OVERCURRENT ALARM dert been ceret ber tre cete 5 33 OVERCURRENT CURVES des 15 5 MEET 5 29 19 15 2
64. On Off ESSAGE OVERCURRENT ALARM EVENTS Off If enabled as Latched or Unlatched the Overcurrent Alarm will function as follows If the average generator current RMS measured at the output CTs exceeds the level programmed for the period of time specified an alarm will occur If programmed as unlatched the alarm will reset itself when the overcurrent condition is no longer present If programmed as latched once the overcurrent condition is gone the reset key must be pressed to reset the alarm The generator FLA is calculated as Generator Rated MVA Generator FLA u xnx6 s 839 1 B x Generator Rated Phase Phase Voltage EQ 0 8 5 6 3 Offline Overcurrent PATH SETPOINTS gt V S5 CURRENT ELEM gt V OFFLINE OVERCURRENT 1 OFFLINE P 0 OFFLINE OVERCURRENT Range Off Latched Unlatched OVERCURRENT TRIP Off ASSIGN TRIP Range Any combination of Relays 1 to RELAYS 1 4 1 4 lt OFFLINE OVERCURRENT Range 0 05 to 1 00 x CT in steps of PICKUP 0 05 x CT 0 01 TT OFFLINE OVERCURRENT Range 3 to 99 cycles in steps of 1 TRIP DELAY 5 cycles When a synchronous generator is offline there should be no measurable current flow in any of the three phases unless the unit is supplying its own station load Also since the generator is not yet online differentiation between system faults and machine faults is easier The offline overcurrent feature is active only when the genera
65. SEQ CURRENT ALARM 15 FLA GROUND OVERCURRENT ALARM 5 00 A GROUND DIRECTIONAL ALARM 5 00 A UNDERVOLTAGE ALARM Vab 3245 V 78 OVERVOLTAGE ALARM Vab 4992 V 120 VOLTS HERTZ ALARM PER UNIT V Hz 1 15 UNDERFREQUENCY ALARM 59 4 Hz OVERFREQUENCY ALARM 60 6 Hz NEUTRAL O V FUND ALARM 0 0 V NEUTRAL U V 3rd ALARM 0 0 V REACTIVE POWER Mvar ALARM 20 000 REVERSE POWER ALARM 20 000 MW LOW FORWARD POWER ALARM 20 000 MW RTD 1 ALARM 135 C RTD 2 ALARM 135 C RTD 3 ALARM 135 C RTD 4 ALARM 135 C 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL Range Range Range Range Range Range Range Range Range Range Range Range Range Range Range Range Range Range Range Range Range Active Latched See Note below Active Latched See Note below Oto 3600 RPM 0 00 to 20 00 x FLA Oto 100 FLA 0 00 to 200000 00 A Seen only if the GE 50 0 025 CT is used 0 00 to 200000 00 A 0 to 20000 V 50 to 99 of Rated O to 20000 V 101 to 15096 of Rated 0 00 to 2 00 Not seen if VT CONNECTION is None 0 00 to 90 00 Hz 0 00 to 90 00 Hz 0 0 to 25000 0 V 0 0 to 25000 0 V 2000 000 to 2000 000 Mvar 2000 000 to 2000 000 MW 2000 000 to 2000 000 MW 50 to 250 Top line displays the RTD name as programmed 50 to 250 Top line displays the RTD name as programmed
66. Z247 lag la 1 56 A ZO la 7 8 A ZO Ib 2 A 2113 lag Ib 10 A Z113 lag 28 FLA Ic 2 A Z247 lag Ic 10 A 2472100 la 0 39 A ZO la 1 95 A ZO 16 0 5 A 4113 lag Ib 2 5 A 113 lag 7 FLA Ic 0 5 A 247 lag lc 2 5 A 247 lag 7 2 6 RTD Accuracy The specification for RTD input accuracy is 2 for Platinum Nickel and 5 for Copper Perform the steps below gt In the 58 RTD TEMPERATURE MENU set RTD TYPE STATOR RTD TYPE 100 Ohm Platinum select desired type RTD 1 gt RTD 1 APPLICATION Stator repeat for RTDs 2 to 12 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 757 CHAPTER 7 TESTING Measured values should be 2 C 4 F for platinum nickel and 5 C 9 F for copper gt Alter the resistance applied to the RTD inputs as shown below to simulate RTDs and verify accuracy View the measured values in 2 METERING DATA D V TEMPERATURE Applied Expected RTD Measured RTD Temperature Resistance Temperature Reading Select One C _ F 100 2 Platinum F 1 2 3 4 5 6 7 8 9 1 12 84 27 40 C 40 F 100 00 Q 0 C 32 F 119 39 Q 50 C 122 F 138 50 Q 100 C 212 F 157 32 Q 150 C 302 F 175 84 Q 200 C 39
67. communications with a 489 device gt From the main window select the File gt Print Settings menu item The Print Export Options dialog box will appear gt Select Settings in the upper section Select either Include All Features for a complete list or Include Only Enabled Features for a list of only those features which are currently used in the filtering section gt Click OK Print Export Options x Select Information to Print Export Settings C Valves Setings Use Definable Memory Map Settings Groups Group 1 Group 2 m Filtering Include Only Enabled Features C Include All Features OK Cancel The process for File gt Print Preview Settings is identical to the steps above Setpoints lists can be printed in the same manner by right clicking on the desired file in the file list or device in the device list and selecting the Print Device Information or Print Settings File options A complete list of actual values can also be printed from a connected device with the following procedure gt Establish communications with the desired 489 device gt From the main window select the File gt Print Settings menu item The Print Export Options dialog box will appear gt Select Actual Values in the upper section Select either Include All Features for a complete list or Include Only Enabled Features for a list of only those
68. 0 x 65535 ms CURVE SHAPE is Flexcurve lt OVERCURRENT CURVE Range 0 00 to 1000 00 in steps of 0 01 lt MULTIPLIER 1 00 MESSAGE MESSAGE MESSAGE OVERCURRENT CURVE Range Instantaneous Linear RESET Instantaneous The 489 ground overcurrent feature consists of both an alarm and a trip element The magnitude of measured ground current is used to time out against the definite time alarm or inverse time curve trip The 489 inverse time curve for this element may be either ANSI IEC or GE Type IAC standard curve shapes This allows for simplified coordination with downstream devices If however none of these curves shapes is adequate the FlexCurve may be used to customize the inverse time curve characteristics If the Ground CT is selected as None the ground overcurrent protection is disabled iy The pickup level for the ground current elements is programmable as a multiple of the CT The 50 0 025 CT is intended for very sensitive detection of ground faults and its nominal CT rating for the 489 is 50 0 025 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS For example if the ground CT is 50 0 025 a pickup of 0 20 would be 0 20 x 50 10 A primary If the ground CT is 50 0 025 a pickup of 0 05 would be 0 05 x 50 2 5 A primary 5 6 8 Phase Differential PATH SETPOINTS V S5 CURRENT ELEM gt V PHASE DIFFERENTIAL Eo E PHASE Prob a DIFFERENTIAL Range Off Latched Unla
69. 01 0 1 CURRENT I Ipu FIGURE A 12 Definite Time Curves 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 808798A4 CDR CHAPTER A APPENDIX A 4 3 IAC Curves I 489 IAC Vy GE Multilin SHORT INVERSE 1000 100 MULTIPLIER TRIP TIME sec 30 0 20 0 15 0 10 0 8 0 6 0 4 0 3 0 0 1 2 0 1 0 0 5 0 01 CURRENT 808811A4 CDR 0 1 FIGURE A 13 IAC Short Inverse Curves A 20 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER A APPENDIX GE Multilin 1000 489 IAC INVERSE 100 MULTIPLIER 30 0 20 0 15 0 10 0 TRIP TIME sec 8 0 6 0 40 3 0 2 0 1 0 0 1 0 5 0 01 0 1 CURRENT FIGURE A 14 IAC Inverse Curves 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 10 100 808810A4 CDR CHAPTER A APPENDIX 489 IAC GE Multilin VERY INVERSE 1000 100
70. 02530337 x Pickup 1 0 05054758 Pickup 1 5 74 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS Table 5 7 489 Standard Overload Curve Multipliers PICKUP STANDARD CURVE MULTIPLIERS x FLA x1 x2 x3 x4 x5 x6 x7 x8 x9 x10 x 11 x 12 x 13 x 14 x15 1 0 435 870 130 174 217 261 304 348 391 435 478 522 565 609 653 1 3 6 7 2 61 14 68 22 75 29 83 36 90 43 97 51 04 1 0 853 170 256 341 426 512 597 682 768 853 93 102 110 119 128 5 71 7 4 1 1 4 9 8 6 2 3 6 0 9 7 3 4 7 1 0 8 45 98 52 06 1 1 416 833 125 166 208 250 291 333 375 416 458 50 541 583 625 0 68 36 0 0 6 7 3 4 0 1 6 8 3 5 0 1 6 8 3 5 0 2 6 9 3 6 0 2 1 2 198 397 596 795 994 119 139 159 178 198 218 238 258 278 298 0 86 72 58 44 30 3 2 2 0 0 9 9 7 8 6 7 5 6 3 5 2 4 1 2 9 1 3 126 253 380 507 634 760 887 101 114 126 139 152 164 177 190 0 80 61 41 22 02 82 63 4 4 1 2 8 0 4 8 1 6 8 5 5 3 2 1 1 4 91 1 182 273 364 455 546 637 729 820 911 100 109 118 127 136 0 4 27 41 55 68 82 96 09 23 37 2 5 3 6 4 8 5 9 7 0 1 5 69 9 139 209 279 349 419 489 559 629 699 769 839 909 979 104 0 9 98 97 96 95 94 93 92 91 90 89 88 87 86 9 9 1 7 42 4 84 8 127 169 212 254 296 339 381 424 466 508 551 593 636 5 1 3 24 6
71. 14 The integrity of system input measurements is affected by this failure Self Test Warning 7 This warning is caused by out of range reading Replace Immediately Major of self test RTD15 The integrity of system input measurements is affected by this failure 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 4 INTERFACES Table 4 1 Self Test Warnings Message Severity Description Self Test Warning 8 This warning is caused by out of range reading Replace Immediately Major of self test RTD16 The integrity of system input measurements is affected by this failure Not sot Minor Occurs if the clock has not been set Program Date Time Unit Temp Exceeded Caused by the detection of unacceptably low Service CheckAmbient Minor less than 40 C or high greater than 85 C temperatures detected inside the unit Unit Not Calibrated Minor This warning occurs when the relay has not Replace Immediately been factory calibrated Relay Not Configured Minor This warning occurs when the 489 CT Primary Consult User Manual or Generator parameters are not set Service Required This warning is caused by a failure of the Real Schedule Maintenance Minor Time Clock circuit The ability of the relay to maintain the current date and time is lost 4 1 8 Flash Messages Flash messages are warning error or general information messages displayed in respons
72. 2 3 489 GENERATOR MA Applied Line Expected Voltage Measured Voltage Neutral Voltage Reading A N BN C N 200 V 2000 V Ground 1 A Neutral and Differential Current Accuracy The specification for neutral differential and 1 A ground current input accuracy is 0 5 of 2 x CT Perform the steps below to verify accuracy gt In the S2 SYSTEM SETUP gt CURRENT SENSING menu set GROUND CT 1A Secondary GROUND CT RATIO 1000 1 PHASE CT PRIMARY 1000 A gt In the 55 CURRENT ELEMENTS gt V PHASE DIFFERENTIAL menu set PHASE DIFFERENTIAL TRIP Unlatched DIFFERENTIAL TRIP MIN PICKUP 0 1 x CT The last two setpoints are needed to view the neutral and the differential current The trip element will operate when differential current exceeds 100 A Measured values should be 10 A gt Inject 4 only the values shown in the table below into one phase only and verify accuracy of the measured values gt View the measured values in the A2 METERING DATA gt CURRENT METERING menu or press the NEXT key to view the current values when differential trip element is active Table 7 1 Neutral and Ground Current Test Results Injected Expected Measured Measured Neutral Current Current Current Ground Current 1 A Unit Phase A Phase B Phase C 01 100A 0 2 A 200A 0 5A 500A 1A 1000 A Table 7 2 Differential Current Test Results
73. 2 5 10 SECONDARY EXCITING CURRENT 60Hz 755 T 20 sos HI 10 2 E x E 8 5 1 01 02 08 0 1 0 2 05 1 0 2 5 10 SECONDARY EXCITING CURRENT 60Hz 808712A1 CDR A 14 CURRENT TRANSFORMER SPECIFICATIONS CURRENT RATIO WINDOW SIZE CT CLASS MULTILIN No Dims 50 5 2 45 C10 911 0010 75 5 2 75 C10 911 0011 100 5 3 00 911 0012 B 150 5 3 00 C10 X911 0013 B 200 5 3 00 C20 911 0014 B 250 5 3 00 20 911 0015 B 300 5 3 00 C20 911 0016 B 400 5 3 00 20 911 0017 B 500 5 3 00 C50 x911 0018 B 600 5 3 00 C50 911 0019 750 5 5 00 C50 911 0020 B 1000 5 3 75 c50 X911 0021 B 90906BA1 DWG This test report is in accordance with ANSI IEEE 57 13 1993 ABOVE THIS LINE THE VOLTAGE FOR A GIVEN EXCITING CURRENT FOR ANY UNIT WILL NOT BE LESS THAN 95 OF THE CURVE VALUE BELOW THIS LINE THE EXCITING CURRENT FOR A GIVEN VOLTAGE FOR ANY UNIT WILL NOT EXCEED THE CURVE VALUE BY MORE THAN 25Z 07 6 82 173 ES j 4 0 44 x 1 00 SLOTS 11 x 25 m 7 00 178 4 0 56 0 75 i A NI 19 0n 1 14 Dio X AB 1 LABEL fay LU 8 e Tss 4 EI a 15 146 CT DIMENSIONS A 5 92 150 3 88 99 ed ee ane 4 0 44 x 1 00 SLOTS 11 x 25 5 96
74. 20 00 x FLA 0 01 0 00 1 25 Mvar Demand 0 00 to 2 00 x Rated 0 01 0 00 1 25 MW Demand 0 00 to 2 00 x Rated 0 01 0 00 1 25 MVA Demand 0 00 to 2 00 x Rated 0 01 0 00 1 25 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 5 97 5 98 5 12 2 Analog Inputs 1 to 4 PATH SETPOINTS V S11 ANALOG I O D V ANALOG INPUT 1 4 ANALOG INPUT1 Range ANALOG gt Disabled Range ESSAGE ED gt E o Q H d 5 ANALOG INPUT1 UNITS Range Bs Ble P w Ec O Q Q H H H H H a 0 5 E mw H E o d H 100 BLOCK ANALOG Range FROM ONLINE 0 s Pil gt nie z ni gt gt H De Ql Z H RELAYS 2 5 5 ANALOG INPUT1 ALARM Range LEVEL 10 Units ANALOG INPUT1 ALARM Range PICKUP Over ANALOG INPUT1 ALARM Range DELAY 0 15 ANALOG INPUT1 ALARM Range EVENTS Off alla 2 ujj H gt Qi o Q H H H RELAYS 1 4 1 ANALOG INPUT1 TRIP Range LEVEL 20 Units ANALOG INPUT1 TRIP Range PICKUP Over ANALOG INPUT1 TRIP Range DELAY 0 15 Range Range Range Range Range Range CHAPTER 5 SETPOINTS Disabled 4 20 mA 0 20 mA 0 1mA 12 alphanumeric characters 6 alphanumeric characters 50000 to 50000 in steps of 1 50000 to 5000
75. 50 x rated V in steps of 0 01 Curve shapes Inverse Time definite time alarm Time Delay 0 2 to 120 0 steps of 0 1 Pickup accuracy as per Voltage Inputs Timing accuracy 100 ms or 0 5 of total time Elements Trip and Alarm PHASE DIFFERENTIAL Pickup level 0 05 to 1 00 x CT in steps of 0 01 Curve shape Dual Slope Time delay 0 to 100 cycles in steps of 1 Pickup accuracy as per phase current inputs Timing accuracy 50 ms at 50 60 Hz or 0 5 total time Elements Trip PHASE OVERCURRENT Voltage restraint programmable fixed characteristic Pickup level 0 15 to 20 00 x CT in steps of 0 01 of any one phase Curve shapes ANSI IAC FlexCurve Definite Time Time delay 0 000 to 100 000 s in steps of 0 001 Pickup accuracy as per phase current inputs Timing accuracy 50 ms at 50 60 Hz or 0 5 total time Elements Trip RTDS 1 TO 12 Pickup 1 to 250 C in steps of 1 Pickup hysteresis 2 C Time delay 3 sec Elements Trip and Alarm 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 2 INTRODUCTION UNDERFREQUENCY Required voltage Block from online Pickup level Curve shapes Time delay Pickup accuracy Timing accuracy Elements UNDERVOLTAGE ckup level urve shapes ime Delay ickup accuracy iming accuracy ements gt 0 50 to 0 99 x rated voltage in Phase Oto 5 sec in steps of 1 20 00 to 60 00 in steps of 0 01 1 level alarm two le
76. 7 IS ALREADY IN USE USED FOR TACHOMETER TOP OF LIST TOP OF PAGE SETPOINT ACCESS IS NOW RESTRICTED SETPOINT ACCESS IS NOW PERMITTED THIS PARAMETER IS ALREADY ASSIGNED THIS FEATURE NOT PROGRAMMED TIME ENTRY TIME ENTRY WAS OUT OF RANGE NOT COMPLETE NEW SETPOINT HAS BEEN STORED This message appear each time a setpoint has been altered and stored as shown on the display e ROUNDED SETPOINT HAS BEEN STORED Since the 489 has a numeric keypad an entered setpoint value may fall between valid setpoint values The 489 detects this condition and store a value rounded to the nearest valid setpoint value To find the valid range and step for a given setpoint press the HELP key while the setpoint is being displayed OUT OF RANGE ENTER TO BY If a setpoint value outside the acceptable range of values is entered the 489 displays this message and substitutes proper values for that setpoint An appropriate value may then be entered 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 6 33 6 34 CHAPTER 6 ACTUAL VALUES ACCESS DENIED SHORT ACCESS SWITCH The Access Switch must be shorted to store any setpoint values If this message appears and it is necessary to change a setpoint short the Access terminals C1 and C2 ACCESS DENIED ENTER PASSCODE The 489 has a passcode security feature If this feature is enabled not only must the Access Switch terminals be shorted but a valid passcode must also
77. 808803A4 CDR FIGURE A 17 IEC Curves BS142 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER A APPENDIX 1000 489 GE Multilin IEC CURVE B BS142 100 TRIP TIME sec MULT IPLIER 1 00 0 80 0 60 0 50 0 40 0 30 0 1 0 20 0 15 0 10 0 05 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CURRENT I Ipu FIGURE A 18 IEC Curves BS142 10 100 808804A4 CDR A 25 TRIP TIME sec 1000 100 GE Multilin IEC CURVE C BS142 CHAPTER A APPENDIX 489 MULTIPLIER 1 00 0 80 0 60 0 50 0 40 0 30 0 20 0 15 0 10 0 05 0 1 100 CURRENT I Ipu 808805A4 CDR FIGURE A 19 IEC Curves C BS142 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER A APPENDIX A 5 Revision History A 5 1 Change Notes Table A 2 Revision History MANUAL P N REVISION RELEASE DATE ECO 1601 0150 A1 3 00 26 April 2004 489 249 1601 0150 A2 3 00 21 May 2004 16
78. Active Alarm La Not Enabled Ina Active Alarm La Not Enabled Ina Active Alarm La Not Enabled Ina Active Alarm La Not Enabled Ina Active Alarm La Not Enabled Ina Active Alarm La Not Enabled Ina Active Alarm La Not Enabled Ina Active Alarm La Not Enabled Ina Active Alarm La Not Enabled Ina Active Alarm La Not Enabled Ina Active Alarm La Not Enabled Ina Active Alarm La ctive Timing Out ched Alarm ctive Timing Out ched Alarm ctive Timing Out ched Alarm ctive Timing Out ched Alarm ctive Timing Out ched Alarm ctive Timing Out ched Alarm ctive Timing Out ched Alarm ctive Timing Out ched Alarm ctive Timing Out ched Alarm ctive Timing Out ched Alarm ctive Timing Out ched Alarm ctive Timing Out ched Alarm ctive Timing Out ched Alarm ctive Timing Out ched Alarm ctive Timing Out ched Alarm ctive Timing Out ched Alarm ctive Timing Out ched Alarm ctive Timing Out ched Alarm ctive Timing Out ched Alarm ctive Timing Out ched Alarm ctive Timing Out ched Alarm 6 14 ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE lt gt 000960009 00 09 09 09 09 09 09 00 Dp Dp Dp p lt 2 2 2 2 4 D D w E E E E H g HJ g Ed Q Q Q Q
79. Assignable Digital Inputs General Input Sequential Trip low forward power or reverse power Field Breaker discrepancy and Tachometer 7 assignable digital inputs general input and tachometer Overload Negative Sequence Offline Overcurrent protection during startup Ground Overcurrent Inadvertent Energization Ground Directional Phase Overcurrent with Voltage Restraint Undervoltage Negative Sequence Overcurrent Overvoltage Ground Overcurrent Volts Per Hertz Percentage Phase Differential Underfrequency Ground Directional Overfrequency High Set Phase Overcurrent Neutral Overvoltage Fundamental Undervoltage Neutral Undervoltage 3rd Harmonic Overvoltage Reactive Power kvar Volts Per Hertz Reverse Power Voltage Phase Reversal Low Forward Power Underfrequency two step RTD Stator Bearing Ambient Other Overfrequency two step Short Low RTD Neutral Overvoltage Fundamental Open RTD Neutral Undervoltage 3rd Harmonic Thermal Overload Loss of Excitation 2 impedance circles Trip Counter Distance Element 2 zones of protection Breaker Failure Reactive Power kvar for loss of field Trip Coil Monitor Reverse Power for anti motoring VT Fuse Failure Low Forward Power Demand Current MW Mvar MVA RTDs Stator Bearing Ambient Other Generator Running Ho
80. Device Setup button to open the Device Setup window V Click the Add Site button to define a new site gt Enter the desired site name in the Site Name field If desired a short description of site can also be entered along with the display order of devices defined for the site gt Click the OK button when complete The new site will appear in the upper left list in the EnerVista 489 Setup window gt Click the Add Device button to define the new device 4 44 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 4 INTERFACES gt Enter the desired name in the Device Name field and a description optional of the site gt Select the appropriate communications interface Ethernet or Serial and fill in the required information for the 489 See Connecting EnerVista 489 Setup to the Relay on page 4 15 for details 489 Relay Relay 2 Pumping Station 1 amp Pumping Station 2 489 Generator Management Relay Generator Management Relay z Ethemet FIGURE 4 11 Device Setup Screen Example gt Click the Read Order Code button to connect to the 489 device and upload the order code If an communications error occurs ensure that communications values entered in the previous step correspond to the relay setting values gt Click OK when complete gt From the EnerVista main window select the IED Dashboard item to open the Plug and Play IED dashboard An icon for the 489 will be displayed 489
81. Ej n 2 2 g hj g gt 2 D g H w N H H a d CHAPTER 6 ACTUAL VALUES THERMAL MODEL Range PICKUP Not Enabled TRIP COUNTER Range PICKUP Not Enabled BREAKER FAILURE Range PICKUP Not Enabled TRIP COIL MONITOR Range PICKUP Not Enabled PICKUP Not Enabled CURRENT DEMAND Range PICKUP Not Enabled PICKUP Not Enabled PICKUP Not Enabled PICKUP Not Enabled GEN RUNNING HOURS Range PICKUP Not Enabled PICKUP Not Enabled PICKUP Not Enabled PICKUP Not Enabled PICKUP Not Enabled Range Range Range Range Range Range Range Range Not Enabled Inactive Timing Out Active Alarm Latched Alarm Not Enabled Inactive Timing Out Active Alarm Latched Alarm Not Enabled Inactive Timing Out Active Alarm Latched Alarm Not Enabled Inactive Timing Out Active Alarm Latched Alarm Not Enabled Inactive Timing Out Active Alarm Latched Alarm Not Enabled Inactive Timing Out Active Alarm Latched Alarm Not Enabled Inactive Timing Out Active Alarm Latched Alarm Not Enabled Inactive Timing Out Active Alarm Latched Alarm Not Enabled Inactive Timing Out Active Alarm Latched Alarm Not Enabled Inactive Timing Out Active Alarm Latched Alarm Not Enabled Inactive Timing Out Active Alarm Latched Alarm Not Enabled Inactive Timing Out Active Alarm L
82. GENERAL gt INPUT None note below gt ASSERTED DIGITAL Range Closed Open amp INPUT STATE Closed ESSAGE lt INPUT NAME Range 12 alphanumeric characters I amp Input A ESSAGE BLOCK INPUT Range 0 to 5000 s in steps of 1 I lt gt FROM ONLINE 0 s ESSAGE lt GENERAL INPUT A Range Off On I CONTROL Off ESSAGE lt PULSED CONTROL RELAY Range 0 0 to 25 0 sin steps of 0 1 I DWELL TIME 0 0 s ESSAGE lt ASSIGN CONTROL Range Any combination of Relays 1 to I RELAYS 1 5 5 ESSAGE lt GENERAL INPUT Range Off On I CONTROL EVENTS Off ESSAGE lt GENERAL INPUT Range Off Latched Unlatched I ALARM off ESSAGE lt ASSIGN ALARM Range Any combination of Relays 2 to I RELAYS 2 5 5 5 ESSAGE GENERAL INPUT A Range 0 1 to 5000 0 s in steps of 0 1 I ALARM DELAY 0 5 s ESSAGE lt GENERAL INPUT Range Off On I ALARM EVENTS Off ESSAGE GENERAL INPUT Range Off Latched Unlatched I TRIP off ESSAGE lt ASSIGN TRIP Range Any combination of Relays 1 to I RELAYS 1 4 1 4 ESSAGE y GENERAL INPUT A Range 0 1 to 5000 0 in steps of 0 1 I TRIP DELAY 5 0 s iy If an input is assigned to the Tachometer function it may not be assigned via the ASSIGN DIGITAL INPUT setpoint NOTE The seven General Input functions are flexible enough to meet most of the desired digital input re
83. GENERAL WIRING CONSIDERATIONS CONTROL POWER CURRENT INPUTS aa am ama e ELE 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL TABLE OF CONTENTS RS485 PORTS DIELECTRIC STRENGTH 3 18 4 INTERFACES FALEPLATE Er E u u unu uu ae Pet aus Rasu DISPLAY LED INDICATORS RS252 PROGRAM PORT ctii SETPOINT ENTRY DIAGNOSTIC MESSAGES SELF TEST WARNINGS E FLASH MESSAGES AE EAA EA E S E ENERVISTA SOFTWARE INTERFACE RENREN OVERVIEW pM ns cM NSTALLING THE ENERVISTA 489 SETUP SOFTWARE CONNECTING ENERVISTA 489 SETUP TO THE RELAY CONFIGURING SERIAL COMMUNICATIONS USING THE QUICK CONNECT FEATURE CONFIGURING ETHERNET COMMUNICATIONS a annassa CONNECTING TO THE RELAY a WORKING WITH SETPOINTS AND SETPOINT FILES uu uu ENGAGING A DEVICE ENTERING SETPOINTS USING SETPOINT FILES is UPGRADING RELAY FIBNIVVARBE DESCRIPTION M EP SAVING SETPOINTS EO A FILE Go terere it E
84. GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 4 45 CHAPTER 4 INTERFACES PlugAndPlay_A FIGURE 4 12 Plug and Play Dashboard gt Click the Dashboard button below the 489 icon to view the device information We have now successfully accessed our 489 through EnerVista Viewpoint 4 46 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL E PoM_Overview_Wye MultiNET 1 Overview Metering Power Demand Analysis Phase B Phase Phase ies esv L Loser oster ostre oster ieta E 265 Degrees LAG LEAD E m Metering Jan 10 2001 Jan 10 2001 Feb 28 2002 Jul 3 2003 03 39 66pm Jul 3 2003 03 37 17 pm FIGURE 4 13 EnerVista Plug and Play Screens For additional information on EnerVista viewpoint please visit the EnerVista website at ENT CHAPTER 4 INTERFACES 4 48 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL Digital Energy Multilin 5 1 Overview Chapter 5 Setpoints 5 1 1 Setpoint Message Map 489 Generator Management Relay The 489 has a considerable number of programmable setpoints which makes it extremely flexible The setpoints have been grouped into a number of pages and sub pages as shown below Each page of setpoints e g S2 SYSTEM SETUP has a section which describes in detail all the setpoints found on that page 1 SETPOINTS gt lt gt ESSAGE ES
85. GROUND FAULT CTS FOR 5 A SECONDARY CT aaa A 13 PHAS ECI S T TIME OVERCURRENT CURVES ANSI CURVES DEFINITE TIME CURVES m CURVES 296o i REVINE 5 u w Sus Su CHANGE NOTES s temet Q ti ive Qaya CHANGES TO THE 489 MANUAL EU DECLARATION OF CONFORMITY EU DECLARATION OF CONFORMITY 2 WARRANTY assieme obi ol PNIS HRS DRE te A 31 GE MULTILIN WARRANTY esses inimi A 31 TOC VI 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL Digital Energy Multilin 489 Generator Management Relay Chapter 1 Getting Started 11 Important Procedures 111 Cautions and Warnings Please read this chapter to guide you through the initial setup of your new relay Before attempting to install or use the relay it is imperative that all WARNINGS and CAUTIONS in this manual are reviewed to help WARNING CAUTION prevent personal injury equipment damage and or downtime 1 12 Inspection Checklist e Open the relay packaging and inspect the unit for physical damage View the rear nameplate and verify that the correct model has been ordered e Ensure that the following items are included e Instruction Manual e GE EnerVista CD includes software and relay documentation e mounting screws e For product information instruction manua
86. HOTTEST STATOR 0 001 HOTTEST BEARING 09 001 Range month day year Range 1 2 Range 0 to 3600 RPM Seen only if a Digital Input set as Tachometer Range 0 to 999999 A Range 0 to 999999 NA Represents neutral end current Range 0 to 200096 FLA Range 0 to 20000 0 A Not seen if GROUND CT TYPE is None Range 0 to 50000 V Not seen if VT CONNECTION is None Range 0 00 to 90 00 Hz Not seen if vT CONNECTION is None Range 0 0 to 25000 0 V Seen only if there is a neutral VT Range 0 0 to 25000 0 V Seen only if there is a neutral VT Range 0 0 to 6553 5 Osec O to 359 Seen only if the Loss of Excitation element is Enabled Range 0 to x2000 000 MW Not seen if VT CONNECTION is None Range to 2000 000 Mvar Not seen if VT CONNECTION is None Range 0 to 2000 000 MVA Not seen if VT CONNECTION is None Range 50 to 250 Seen only if 1 or more RTDs are set as Stator Range 50 to 250 Seen only if 1 or more RTDs are set as Bearing 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 6 ACTUAL VALUES HOTTEST OTHER Range 50 to 250 C Seen only if 1 or ESSAGE SS 11 0 C E001 more RTDs are set as Other AMBIENT Range 50 to 250 C Seen only if 1 or ESSAGE 2 2 12 0 C 001 more RTDs are set as Ambient ANALOG INPUT 1 Range 50000 to 50000 Reflects the ESSAGE e 001 0 0 Units
87. Headers for each setpoint message subgroup that has dual settings will be denoted by a superscript number indicating which setpoint group is being viewed or edited Also when a setpoint that has dual settings is stored the flash message that appears will indicate which setpoint group setting has been changed 5 4 8 Sequential Trip PATH SETPOINTS D V S3 DIGITAL INPUTS gt V SEQUENTIAL TRIP m ASSIGN DIGITAL Range None Input 1 to Input 7 SEQUENTIAL 1 INPUT None NOTE T SEQUENTIAL TRIP TYPE Range Low Forward Power Reverse Low Forward Power Power ASSIGN TRIP Range Any combination of Relays 1 to RELAYS 1 4 1 4 SEQUENTIAL TRIP Range 0 02 to 0 99 x Rated MW in ESSAGE steps of 0 01 LEVEL 0 05 x Rated SEQUENTIAL TRIP Range 0 2 to 120 0 s in steps of 0 1 pen qu DELAY 1 0 If an input is assigned to the tachometer function it may not be used here During routine shutdown and for some less critical trips it may be desirable to use the sequential trip function to prevent overspeed If an input is assigned to the sequential trip function shorting that input will enable either a low forward power or reverse power function Once the measured 3 phase total power falls below the low forward power level or exceeds the reverse power level for the period of time specified a trip will occur This time delay will typically be shorter than that used for the standard reverse power or low forward power elements The
88. Ju PHASE CT NONE 68tus SPECIAL NUMBER OF MANUALS gz P 0S TAG NONE MOD NONE CUSTOMER USE OVERVOLTAGE CATEGORY INSULATION VOLTAGE 300V POLLUTION DEGREE 2 IP 20 X CONTROL POWER 20 60VDC 1 75 Max 20 48VAC 1 75A OUTPUT RELAY CONTACTS 48 62Hz NOLLNVD 5 lt 9 m Z E 83849 Gs CE LISTED IND CONT EQ 5211 000 8VOOPAZE MADE IN CANADA FIGURE 3 3 Product Case and Unit Labels 3 1 3 Installation The 489 case alone or adjacent to another SR series unit can be installed in a standard 19 inch rack panel see 489 Dimensions on page 3 2 Provision must be made for the front door to swing open without interference to or from adjacent equipment The 489 unit is normally mounted in its case when shipped from the factory and should be removed before mounting the case in the supporting panel Unit withdrawal is described in the next section After the mounting hole in the panel has been prepared slide the 489 case into the panel from the front Applying firm pressure on the front to ensure the front bezel fits snugly against the front of the panel bend out the pair of retaining tabs to a horizontal position from each side of the case as shown below The case is now securely mounted ready for panel wiring 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 3 3 3 4 CHAPTER 3 INSTALLATION 808704A1 CDR FIGURE 3 4 Bend Up Mountin
89. MANAGEMENT RELAY INSTRUCTION MANUAL 5 42 CHAPTER 5 SETPOINTS 5 7 56 Voltage Elements 5 7 1 Undervoltage PATH SETPOINTS gt S6 VOLTAGE ELEM gt UNDERVOLTAGE 1 UNDERVOLTAGE gt UNDERVOLTAGE Range Off Latched Unlatched ALARM Off ASSIGN ALARM Range Any combination of Relays 2 to RELAYS 2 5 5 5 Range 0 50 to 0 99 x Rated in steps of ESSAGE E gt UNDERVOLTAGE ALARM 0 amp PICKUP 0 85 x Rated Range 0 2 to 120 0 s in steps of 0 1 ESSAGE UNDERVOLTAGE ALARM g DELAY 3 0 s Range Off ESSAGE UNDERVOLTAGE ALARM g EVENTS Off Range Off Latched Unlatched gt UNDERVOLTAGE 4 TRIP Off are lt ASSIGN TRIP Range Any combination of Relays 1 to gt gt RELAYS 1 4 1 4 Range 0 50 to 0 99 x Rated in steps of ESSAGE UNDERVOLTAGE TRIP 1 x PICKUP 0 80 x Rated Range 0 2 to 10 0 s in steps of 0 1 ESSAGE UNDERVOLTAGE TRIP 4 DELAY 1 0 s Range 0 0 to 999 9 s in steps of 0 1 ESSAGE UNDERVOLTAGE CURVE RESET RATE 1 4 s Range Curve Definite Time ESSAGE eA UNDERVOLTAGE CURVE ELEMENT Curve The undervoltage elements may be used for protection of the generator and or its auxiliary equipment during prolonged undervoltage conditions They are active only when the generator is online The alarm element is definite time and the trip element can be definite time or a curve When the magnitude of the average phase phase voltage is less than
90. MESSAGE V RATIO 5 00 1 Press the VALUE keys until 115 00 1is VOLTAGE TRANSFORMER displayed or enter the value directly via thelparto 115 0 1 numeric keypad Press the ENTER key to store the setpoint NEW SIE INDORE BEEN STORED If an entered setpoint value is out of range the relay displays a message with the following format OUT OF RANGE ENTER 1 300 1 indicates the range and 0 01 1 indicates the 1 300 1 by 0 01 1 step value In this case 1 is the minimum setpoint value 300 is the maximum and 0 01 is the step value To have access to information on maximum minimum and step value press the HELP key 1 3 5 Output Relay Setpoints The output relays 1 Trip and 5 Alarm can be associated to auxiliary relays 2 to 4 Each can be selected individually or in combination in response to customer specific requirements These relays are initiated through the ASSIGN ALARM RELAYS ASSIGN TRIP RELAYS setpoints specific to a protection element or function gt Select the 56 VOLTAGE ELEMENTS gt UNDERVOLTAGE PV ASSIGN TRIP RELAYS 1 4 setpoint message ASSIGN TRIP RELAYS 1 4 1 If an application requires the undervoltage protection element to trip the 3 Auxiliary relay Select this output relay by pressing the 5 key pressing the 5 key again disables the 3 Auxiliary relay Enable disable relays 1 3 and 4 in the same manner until the desired combination appear in the display ASSIGN TRIP RELAYS 1 4
91. Note that a space is selected like a character If a character is entered incorrectly press the decimal key repeatedly until the cursor returns to the position of the error Re enter the character as required Once complete press the ENTER key to remove the solid cursor and view the result Once a character is entered by pressing the ENTER key it is automatically saved in flash memory as a new setpoint INPUT NAME Stn Monitor 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 1 15 CHAPTER 1 GETTING STARTED 1 4 Installation 14 1 Placing the Relay in Service The relay is defaulted to the Not Ready state when it leaves the factory A minor self test warning message informs the user that the 489 Generator Management Relay has not yet been programmed If this warning is ignored protection will be active using factory default setpoints and the Relay In Service LED Indicator will be on 14 2 Testing Extensive commissioning tests are available in Chapter 7 Tables for recording required settings are available in Microsoft Excel format from the GE Multilin website at http www GEmultilin com The website also contains additional technical papers and FAQs relevant to the 489 Generator Management Relay 1 16 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL Digital Energy Multilin 489 Generator Management Relay Chapter 2 Introduction 2 1 Overview 2 1 1 Description The 489 Generator Management Rela
92. RTD 4 Hot E03 2 Auxiliary Common A11 RTD 5 Hot E04 3 Auxiliary NC 12 RTD 5 Compensation E05 3 Auxiliary NO A13 RTD Return E06 4 Auxiliary Common A14 RTD 6 Compensation E07 5 Alarm NC 15 6 E08 5 Alarm NO 16 Analog Output Common E09 6 Service Common 17 Analog Output 1 E10 Neutral VT Common A18 Analog Output 2 E11 Coil Supervision 19 Analog Output 3 E12 IRIG B A20 Analog Output 4 F01 1 Trip Common A21 Analog Shield F02 2 Auxiliary NO A22 Analog Input 24 V DC Supply F03 2 Auxiliary NC A23 Analog Input 1 FO4 3 Auxiliary Common A24 Analog Input 2 FOS 4 Auxiliary NO A25 Analog Input 3 F06 4 Auxiliary NC A26 Analog Input 4 F07 5 Alarm Common A27 Analog Input Common F08 6 Service NO B01 RTD Shield F09 6 Service NC B02 Auxiliary RS485 F10 eutral VT 03 Auxiliary RS485 11 Coil Supervision 04 Auxiliary RS485 Common 12 RIG B C01 ACCeSS 601 Phase VT Common C02 Access G02 Phase A VT C03 Breaker Status G03 eutral Phase e C04 Breaker Status G04 Neutral Phase 001 7 G05 eutral Phase C CT 002 RTD 7 Compensation G06 Output Phase A CT D03 RTD Return G07 Output Phase B CT 004 RTD 8 Compensation G08 Output Phase C CT e D05 8 Hot G09 1A Ground CT e D06 9 Hot G10 HGF Ground D07 9 Compensation G11 Filter Ground D08 RTD Return G12 Safety Ground D09 10 Compensation 01 Phase B VT e D10 10 Ho
93. Range 50 to 250 C I MAX TEMP 40 ESSAGE RTD 10 Range 50 to 250 C MAX TEMP 40 6 22 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 6 ACTUAL VALUES MESSAGE RTD 11 Range 50 to 250 C MAX TEMP 40 C RTD 12 Range 50 to 250 C MAX TEMP 40 C MESSAGE iy These messages seen only if the corresponding RTDs are programmed The actual messages reflect the RTD Names as programmed NOTE The 489 will learn the maximum temperature for each RTD This information can be cleared using the 61 489 SETUP gt V CLEAR DATA gt V CLEAR RTD MAXIMUMS setpoint The RTD maximums will not update if a digital input programmed as Test Input is shorted If no RTDs are programmed in the 57 RTD TEMPERATURE Setpoints page the THIS FEATURE NOT PROGRAMMED flash message will appear when an attempt is made to enter this group of messages 6 4 3 Analog Input Min Max PATH ACTUAL VALUES V LEARNED DATA D V ANALOG INPUT MIN MAX ANALOG INPUT b ANALOG I P 1 Range 50000 to 50000 MIN MAX MIN O Units ANALOG I P 1 Range 50000 to 50000 ESSAGE 0 Units ANALOG I P 2 Range 50000 to 50000 ESSAGE MIN Units ANALOG I P 2 Range 50000 to 50000 ESSAGE 0 Units ANALOG 3 Range 50000 to 50000 ESSAGE i MIN O Units ANALOG I P 3 Range 50000 to 50000 MAX O Units ANALOG 4 Range 50000 to 50000 MIN Units ANALOG I P 4 Range
94. Relays 2 to 5 0 02 to 0 99 x Rated MW in steps of 0 01 0 2 to 120 0 s in steps of 0 1 On Off Off Latched Unlatched Any combination of Relays 1 to 4 0 02 to 0 99 x Rated MW in steps of 0 01 0 2 to 120 0 s in steps of 0 1 If enabled once the magnitude of 3 phase total power in the forward direction MW falls below the Pickup Level for a period of time specified by the Delay an alarm will occur The level is programmed in per unit of generator rated MW calculated from the rated MVA and rated power factor The low forward power element is active only when the generator is online and will be blocked until the generator is brought online for a period of time defined by the setpoint Block Low Fwd Power From Online The pickup level should be set lower than expected generator loading during normal operations If the VT type is selected as None or VT fuse loss is detected the low forward power protection is disabled 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS 5 9 58 Temperature 5 9 1 RTD Types PATH SETPOINTS V S8 RTD TEMPERATURE gt RTD TYPES 100 Ohm Platinum 120 Ohm Nickel 100 Ohm Nickel 10 Ohm MM RTD TYPES 2 RTD TYPE Range 100 2 Platinum The table below lists RTD resistance vs temperature Table 5 6 RTD Temperature vs Resistance Temperature 100 Q Pt 120 Q Ni 100 O Ni 10 Q Cu DIN 43760 50 58 80 31 86 17 7181 7 10 40 40 84 27 92 76 77 3
95. Setpoints Pre Trip Data Event Recorder Waveform Memory Fault Simulation VT Failure Trip Counter Breaker Failure Trip Coil Monitor Generator Running Hours Alarm IRIG B Failure Alarm OVERCURRENT ALARM Pickup level 0 10 to 1 50 x FLA in steps of 0 01 average phase current 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 2 9 CHAPTER 2 INTRODUCTION Time delay 0 1 to 250 0 s in steps of 0 1 Pickup accuracy as per phase current inputs Timing accuracy 100 ms or 0 5 of total time Elements Alarm OVERFREQUENCY Required voltage 0 50 to 0 99 x rated voltage in Phase A Block from online Oto 5 sec steps of 1 Pickup level 25 01 to 70 00 in steps of 0 01 Curve shapes 1 level alarm 2 level trip definite time Time delay 0 1 to 5000 0 s in steps of 0 1 Pickup accuracy 0 02 Hz Timing accuracy 150 ms or 1 of total time at 50Hz and 60Hz 300 ms or 2 of total time at 25Hz Elements Trip and Alarm OVERLOAD STALL PROTECTION THERMAL MODEL verload curves 15 Standard Overload Curves Custom Curve and Voltage Dependent Custom Curve all curves time out against average phase current Curve biasing Phase Unbalance Hot Cold Curve Ratio Stator RTD Online Cooling Rate Offline Cooling Rate Line Voltage Overload pickup 1 01 to 1 25 Pickup accuracy as per phase current inputs Timing accuracy 100 ms or 2 of total time Elements Trip and Alarm OVERVOLTAGE Pickup level 1 01 to 1
96. This may interfere with proper insertion to the case terminal blocks and damage the cable FIGURE 3 8 Ethernet Cable Connection To ensure optimal response from the relay the typical connection timeout should be set as indicated in the following table TCP IP sessions Timeout setting up to 2 2 seconds up to 4 3 seconds The RS485 COM2 port is disabled if the Ethernet option is ordered 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 3 INSTALLATION 3 1 6 Terminal Locations T eee EE EEE Hos iD 02022220222222022222022220022 SSSSSSSSSSSSSSSSSSSSSSSSISSS Was s sus s ss F 2220525250258 808759E7 DWG FIGURE 3 9 Terminal Layout 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 3 7 CHAPTER 3 INSTALLATION Table 3 1 489 Terminal List Terminal Description Terminal Description 01 RTD 1 Hot D21 Assignable Switch 6 A02 RTD 1 Compensation D22 Assignable Switch 7 A03 RTD Return D23 Switch Common A04 RTD 2 Compensation D24 Switch 24 V DC 05 RTD 2 Hot D25 Computer RS485 A06 RTD 3 Hot D26 Computer RS485 7 RTD 3 Compensation D27 Computer RS485 Common 08 RTD Return E01 1 Trip NC A09 4 Compensation E02 1 Trip NO A10
97. When one of the inputs is assigned to the Waveform Capture function shorting that input will trigger the waveform 5 4 12 Ground Switch Status PATH SETPOINTS D V S3 DIGITAL INPUTS gt V GND SWITCH STATUS ASSIGN DIGITAL Range None Input 1 to Input 7 Ec 318853 2 GROUND SWITCH Range Auxiliary a Auxiliary b MESSAGE gs 5 CONTACT Auxiliary If an input is assigned to the tachometer function it may not be used here This function is used to detect the status of a grounding switch for the generator for which the relay is installed Refer to Stator Ground Fault on page A 1 for additional details 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 5 27 CHAPTER 5 SETPOINTS 5 5 54 Output Relays 5 5 1 Description Five of the six output relays are always non failsafe the 6 Service relay is always failsafe As a failsafe the 6 Service relay will be energized normally and de energize when called upon to operate It will also de energize when control power to the 489 is lost and therefore be in its operated state All other relays being non failsafe will be de energized normally and energize when called upon to operate Obviously when control power is lost to the 489 the output relays must be de energized and therefore they will be in their non operated state Shorting bars in the drawout case ensure that when the 489 is drawn out no trip or alarm occurs The 6 Service output will however indicate
98. and average phase phase voltage volts hertz frequency third harmonic neutral voltage power 3 phase Mvar MW power factor analog inputs 1 to 4 tachometer thermal capacity used demand I Mvar MW and MVA torque PULSE OUTPUT Parameters kwh kvarh kvarh Interval 1 to 50000 in steps of 1 Pulse width 200 to 1000 ms in steps of 1 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 2 4 2 8 2 2 5 WARNING Protection CHAPTER 2 INTRODUCTION RELAYS Relay contacts must be considered unsafe to touch when the relay is energized If the output relay contacts are required for low voltage accessible applications it is the customer s responsibility to ensure proper insulation levels Configuration 6 electromechanical Form C relays Contact material silver alloy Operate time 10 ms Make carry 30 A for 0 2 s 10 A continuous for 100000 operations Maximum ratings for 100000 operations Voltage Break Max Load 30V 500 W DC Resistive 125V D5A 62 5 W 250V 75 W 30V 1150 W DC inductive 4 L R 40 ms 25V 25 51 5 W 250V 15 57 5 W 120 10 2770 VA AC Resistive 250V 0 2770 VA AC Inductive 120V HA 80 VA 04 250 750 VA PHASE DISTANCE IMPEDANCE Characteristics offset mho Reach secondary Q 0 1 to 500 0 Q in steps of 0 1 Reach accuracy 5 Characteristic angle 5
99. and MESSAGE A keys are used to navigate through the sub pages A summary of the setpoints and actual values can be found in the chapters 5 and 6 respectively The ENTER key is dual purpose It is used to enter the sub pages and to store altered setpoint values into memory to complete the change The MESSAGE gt key can also be used to enter sub pages but not to store altered setpoints The ESCAPE key is also dual purpose It is used to exit the sub pages and to cancel a setpoint change The MESSAGE key can also be used to exit sub pages and to cancel setpoint changes The VALUE keys are used to scroll through the possible choices of an enumerated setpoint They also decrement and increment numerical setpoints Numerical setpoints may also be entered through the numeric keypad Press the HELP key to display context sensitive information about setpoints such as the range of values and the method of changing the setpoint Help messages will automatically scroll through all messages currently appropriate The RESET key resets any latched conditions that are not presently active This includes resetting latched output relays latched Trip LEDs breaker operation failure and trip coil failure 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 4 INTERFACES The MESSAGE Y and MESSAGE keys scroll through any active conditions in the relay Diagnostic messages are displayed indicating the state of protection and monitori
100. any given voltage there is only one value of line current 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS 1000 900 800 700 600 500 400 300 200 100 80 70 60 50 40 30 TIME TO TRIP SECONDS 20 m A GE Multilin 489 THERMAL LIMITS FOR HIGH INERTIAL LOAD 1 Running Overload Thermal Limit O 2 Acceleration Thermal Limit 80 V 3 Acceleration Thermal Limit 100 V 4 Locked Rotor Thermal Limit 5 Machine Acceleration Curve 80 V 6 Machine Acceleration Curve 100 V 1 2 3 4 MULTIPLES OF FULL LOAD AMPS FIGURE 5 17 Thermal Limits for High Inertial Load 5 808826A3 CDR To illustrate the Voltage Dependent Overload Curve feature the thermal limits shown in Thermal Limits for High Inertial Load on page 5 79 will be used gt Construct a custom curve for the running overload thermal limit If the curve does not extend to the acceleration thermal limits extend it such that the curve intersects the acceleration thermal limit curves see the custom curve below 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 5 80 1000 900 800 700 600 500 400 300 200 100 80 70 60 50 CHAPTER 5 SETPOINTS 489 VOLTAGE DEPENDENT OVERLOAD GE Multilin CUSTOM
101. assigning features to relays 2 3 and 4 it is a good idea to decide early on what is required since features that may be assigned may conflict For example if relay 2 is to be dedicated as a relay for sequential tripping it cannot also be used to annunciate a specific alarm condition In order to ensure that conflicts in relay assignments do not occur several precautions have been taken All trips default to the 1 Trip output relay and all alarms default to the 5 Alarm relay It is recommended that relay assignments be reviewed once all the setpoints have been programmed 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 8 4 CHAPTER 5 SETPOINTS 5 1 4 Dual Setpoints The 489 has dual settings for the current voltage power RTD and thermal model protection elements setpoints pages 55 to 59 These setpoints are organized two groups the main group Group 1 and the alternate group Group 2 Only one group of settings is active in the protection scheme at a time The active group can be selected using the ACTIVATE SETPOINT GROUP Setpoint or an assigned digital input in the 53 Digital Inputs setpoints page The LED indicator on the faceplate of the 489 will indicate when the alternate setpoints are active in the protection scheme Independently the setpoints in either group can be viewed and or edited using the EDIT SETPOINT GROUP setpoint Headers for each setpoint message subgroup that has dual settings will be denoted by a supe
102. calculated as _ __phase to phase voltage EO 7 9 rated phase to phase voltage 2679 and has a range of 0 1 to 0 9 gt Using Secondary Injection Test Setup 3 on page 7 19 inject current and apply voltage as per the table below gt Verify the alarm trip elements and view the event records in the 5 EVENT RECORD menu 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 7 TESTING Current voltage 5 A unit Alarm Trip Trip Delay Current Voltage expected observed delay expected observed expected observed an 5 AZ0 ab 120 VX0 lag bn 5 4120 lag bc 120 VZ120 lag 8 N A N A N A cn 5 AZ240 lag ca 120VZ240 lag an 6AZ0 ab 120 VX0 bn 6 AZ120 lag bc 120 VZ120 lag N A N A cn 6 AZ240 lag ca 120VZ240 lag an 10 AZO ab 120 VX0 bn210AZ120 lag Wbc 120VZ120 lag 4 11 8s cn 10 A lt 240 lag Vca 120 VZ240 lag an 10 AZO ab 100 VX0 bn 10A120 lag Vbc 100VZ120 lag 4 6 65 cn 10AZ240 lag Vca 100 VZ240 lag an 10 AZO ab 60 VZ0 bn 10 4120 lag Vbc 60V120 lag 175 cn 10 240 lag 60 VZ240 lag 4 activated 8 Not Activated 7 5 11 Distance Element Accuracy The theoretical impedance on the R X plane can be calculated as 2 2 PN 0 875 2 cos 0 9 0 875 x Zy x cos 0 0 4 2 0 125 i 2 where Zg programmed distance impedance 04 prog
103. common return The polarity of these outputs must be observed for proper operation Shielded cable should be used with only one end of the shield grounded to minimize noise effects The analog output circuitry is isolated as a group with the Analog Input circuitry and the RTD circuitry Only one ground reference should be used for the three circuits Transorbs limit this isolation to 36 V with respect to the 489 safety ground If a voltage output is required a burden resistor must be connected at the input of the SCADA measuring device Ignoring the input impedance of the input VEULL SCALE Rice EQ 3 1 Imax For example for a 0 to 1 mA input if 5 V full scale corresponds to 1 mA then 5 0 001 A 5000 Q For a 4 to 20 mA input this resistor would be Rj gap 5 V 0 020 250 3 2 9 Sensor Connections The 489 can monitor up to 12 RTD inputs for Stator Bearing Ambient or Other temperature monitoring The type of each RTD is field programmable as 100 Q Platinum DIN 43760 100 Q Nickel 120 Q Nickel or 10 Q Copper RTDs must be three wire type Every two RTDs shares common return 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 3 15 wv NOTE CHAPTER 3 INSTALLATION The 489 RTD circuitry compensates for lead resistance provided that each of the three leads is the same length Lead resistance should not exceed 25 per lead for platinum and nickel RTDs and 3 Q per lead for cop
104. features The EnerVista 489 Setup help file provides details for getting started and using the software interface With the EnerVista 489 Setup running on your PC it is possible to Program and modify setpoints e Load save setpoint files from to disk Read actual values and monitor status Perform waveform capture and log data Plot print and view trending graphs of selected actual values e Download and playback waveforms Gethelp on any topic Communications from the EnerVista 489 Setup to the 489 can be accomplished three ways RS232 RS485 and Ethernet requires the MultiNet adapter communications The following figures below illustrate typical connections for RS232 and RS485 communications For additional details on Ethernet communications please see the MultiNet manual GE Publication number GEK 106498 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 4 INTERFACES FIGURE 4 2 Communications using The Front RS232 Port 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 4 INTERFACES Computer F485 Connections GE Multilin F485 Converter RS232 Connector to Computer COM Port Typically COM1 or COM2 Rear RS485 Connections FIGURE 4 3 Communications using Rear RS485 Port 4 2 3 Installing the EnerVista 489 Setup Software The following minimum requirements must be met for the EnerVista 489 Setup software to operate on your computer e Pentium class or highe
105. features which are currently used in the filtering section gt Click OK Actual values can be printed in the same manner by right clicking on the desired device in the device list and selecting the Print Device Information option 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 4 27 CHAPTER 4 INTERFACES Loading Setpoints from a File An error message will occur when attempting to download a setpoint file with a revision number that does not match the relay firmware If the firmware has been upgraded since saving the setpoint file see Upgrading Setpoint Files to a New Revision on page 4 25 for instructions on changing the revision number of a setpoint file WARNING The following procedure illustrates how to load setpoints from a file Before loading a setpoint file it must first be added to the EnerVista 489 Setup environment as described in Adding Setpoints Files to the Environment on page 4 24 gt Select the previously saved setpoint file from the File pane of the EnerVista 489 Setup software main window gt Select the File gt Properties menu item and verify that the corresponding file is fully compatible with the hardware and firmware version of the target relay If the versions are not identical see Upgrading Setpoint Files to a New Revision on page 4 25 for details on changing the setpoints file version gt Right click on the selected file gt Select the Write Settings to Device item The software w
106. from its normal state The appropriate relay indicator will illuminate at that time Selecting Disabled places the output relays back in service If the 489 measures current or control power is cycled the force operation of relays setpoint will automatically become disabled and the output relays will revert back to their normal states If any relay is forced the 489 In Service indicator will flash indicating that the 489 is not in protection mode 5 13 5 Test Analog Output PATH SETPOINTS D V S12 489 TESTING gt V TEST ANALOG OUTPUT FORCE ANALOG OUTPUTS Range Enabled Disabled restr SY FUNCTION Disabled gt ANALOG OUTPUT 1 Range 0 to 100 in steps of 1 FORCED VALUE 0 ESSAGE ANALOG OUTPUT 2 Range 0 to 100 in steps of 1 FORCED VALUE 0 ANALOG OUTPUT 3 Range 0 to 10096 in steps of 1 FORCED VALUE 0 ANALOG OUTPUT 4 Range 0 to 10096 in steps of 1 ESSAGE gs FORCED VALUE 0 These setpoints may be used during startup or testing to verify that the analog outputs are functioning correctly The analog outputs can be forced only if the generator is offline no current is measured and there are no trips or alarms active When the FORCE ANALOG OUTPUTS FUNCTION is Enabled the output reflects the forced value as a percentage of the range 4 to 20 mA or 0 to 1 mA Selecting Disabled places all four analog output channels back in service reflecting their programmed parameters I
107. ground CT ratio of 10000 1 The ground CT must be capable of driving the ground CT burden The HGF ground CT input is designed for sensitive ground current detection on high resistance grounded systems where the GE Multilin HGF core balance CT 50 0 025 is used In applications such as mines where earth leakage current must be measured for personnel safety primary ground current as low as 0 25 A may be detected with the GE Multilin HGF CT Only one ground CT input tap should be used on a given unit The HGF CT has a rating of 50 0 025 However if the HGF CT is used in conjunction with the 489 the relay assumes a fixed ratio of 5 0 0025 Therefore the pickup level in primary amps will be Pickup x CT where CT is equal to 5 Only one ground input should be wired The other input should be unconnected PHASE A PHASE B 1A 5A COM 1A 5A 1 5 COM COM HGF COM PHASE A PHASE B PHASE C GROUND INPUTS OUTPUT CTs gt FIGURE 3 13 Residual Ground Connection DO NOT INJECT OVER THE RATED CURRENT TO HGF TERMINAL 0 25 to 25 A PRIMARY The exact placement of a zero sequence CT to detect ground fault current is shown below If the core balance CT is placed over shielded cable capacitive coupling of phase current into the cabl
108. kvarh PULSE OUT RELAYS 2 5 5 94 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS POS kvarh PULSE OUT Range 1 to 50000 kvarh in steps of 1 ESSAGE INTERVAL 10 kvarh NEG kvarh PULSE OUT Range Any combination of Relays 2 to gt RELAYS 2 5 5 7 NEG kvarh PULSE OUT Range 1 to 50000 kvarh in steps of 1 INTERVAL 10 kvarh PULSE WIDTH Range 200 to 1000 ms in steps of 1 ESSAGE 489 can perform pulsed output of positive kWh and both positive and negative kvarh Each output parameter can be assigned to any one of the alarm or auxiliary relays Pulsed output is disabled for a parameter if the relay setpoint is selected as OFF for that pulsed output The minimum time between pulses is fixed to 400 milliseconds This feature should be programmed so that no more than one pulse per 600 milliseconds is y required or the pulsing will lag behind the interval activation Do not assign pulsed outputs e to the same relays as alarms and trip functions status status status normally open NO contact OPEN CLOSED OPEN normally closed NC contact CLOSED OPEN gt CLOSED PULSE WIDTH FIGURE 5 28 Pulse Output 808738A1 CDR 5 11 7 Running Hour Setup PATH SETPOINTS gt V S10 MONITORING D V RUNNING HOUR SETUP INITIAL GEN RUNNING Range 0 to 999999 h in steps of 1 RUNNING gt HOURS 0 h lt GEN RUNNING HOURS
109. level is programmed in per unit of generator rated MW calculated from the rated MVA and rated power factor If the VT type is selected as None the sequential trip element will operate as a simple timer Once the input has been shorted for the period of time specified by the delay a trip will occur The minimum magnitude of power measurement is determined by the phase CT minimum of 2 rated CT primary If the level for reverse power is set below that level a trip will only occur once the phase current exceeds the 2 cutoff Users are cautioned that a reverse power element may not provide reliable indication when set to a very low setting particularly under conditions of large reactive loading on the generator Under such conditions low forward power is a more reliable element 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 5 25 5 4 9 Field Breaker PATH CHAPTER 5 SETPOINTS SETPOINTS D V S3 DIGITAL INPUTS gt V FIELD BREAKER DISCREPANCY FIELD ASSIGN DIGITAL Range None Input 1 to Input 7 BREAKER P INPUT None If an Thef a dig field will o possi ESSAGE FIELD STATUS Range Auxiliary a Auxiliary b CONTACT Auxiliary ESSAGE ASSIGN TRIP Range Any combination of Relays 1 to RELAYS 1 4 1 4 FIELD BKR DISCREP Range 0 1 to 500 0 s in steps of 0 1 ESSAGE TRIP DELAY 1 0 input is assigned to the tachometer function it may not be used here ield breaker discrepancy
110. lt gt lt gt lt gt lt gt lt gt lt gt lt gt lt gt lt gt BLOCK OVERFREQUENCY Range FROM ONLINE VOLTAGE LEVEL Range CUTOFF 0 50 x Rated OVERFREQUENCY Range ALARM Off ASSIGN ALARM Range RELAYS 2 5 5 OVERFREQUENCY Range ALARM LEVEL 60 50 Hz OVERFREQUENCY Range ALARM DELAY 5 0 OVERFREQUENCY Range OVERFREQUENCY Range gt nji H nji H a Q II 2 H r lt zijn Ed H 4 n Fh RELAYS 1 4 1 OVERFREQUENCY Range TRIP LEVEL1 60 50 Hz OVERFREQUENCY Range TRIP DELAY1 60 0 s OVERFREQUENCY Range TRIP LEVEL2 62 00 Hz OVERFREQUENCY Range TRIP DELAY2 30 0 s Range CHAPTER 5 SETPOINTS Oto5sin stepsof 1 0 50 to 0 99 x Rated in steps of 0 01 Off Latched Unlatched Any combination of Relays 2 to 5 25 01 to 70 00 Hz in steps of 0 01 0 1 to 5000 0 s in steps of 0 1 On Off Off Latched Unlatched Any combination of Relays 1 to 4 25 01 to 70 00 Hz in steps of 0 01 0 1 to 5000 0 s in steps of 0 1 25 01 to 70 00 Hz in steps of 0 01 0 1 to 5000 0 s in steps of 0 1 It may be undesirable to enable the overfrequency elements until the generator is online This feature can be blocked until the generator is online and the block time expires From that point forward the overfrequency trip and alarm elements will be active A value of zero for the bl
111. near the generator neutral has proved feasible on generators with unit transformers Its usefulness in other generator applications is unknown 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS 5 7 9 Loss of Excitation 1 LOSS OF EXCITATION v NOTE PATH SETPOINTS D V S6 VOLTAGE ELEM gt V LOSS OF EXCITATION gt ENABLE VOLTAGE Range Yes No SUPERVISION Yes Range 0 70 to 1 00 x Rated in steps of ESSAGE lt gt 0 01 amp LEVEL 0 70 x Rated Range Off Latched Unlatched CIRCLE 1 TRIP off ASSIGN CIRCLE 1 TRIP Range Any combination of Relays 1 to ESSAGE RELAYS 1 4 1 4 CIRCLE 1 Range 2 5 to 300 0 Qsec in steps of 0 1 I DIAMETER 25 0 CIRCLE 1 Range 1 0 to 500 0 Qsec in steps of 0 1 I x OFFSET 2 5 Osec CIRCLE 1 TRIP Range 0 1 to 10 0 s in steps of 0 1 DELAY 5 0 s lt CIRCLE 2 Range Off Latched Unlatched TRIP Off ASSIGN CIRCLE 2 TRIP Range Any combination of Relays 1 to ESSAGE ESSAGE RELAYS 1 4 1 4 lt CIRCLE 2 Range 2 5 to 300 0 Qsec in steps of 0 1 ESSAGE DIAMETER 35 0 T CIRCLE 2 Range 1 0 to 300 0 Qsec in steps of 0 1 OFFSET 2 5 CIRCLE 2 TRIP Range 0 1 to 10 0 s in steps of 0 1 DELAY 5 0 s ESSAGE The VOLTAGE LEVEL setpoint is seen only if ENABLE VOLTAGE SUPERVISION is set to Yes Loss of excitation is detected with
112. number of different functions Some of those functions are very specific others may be programmed to adapt to user requirements Terminals C1 and C2 must be shorted to allow changing of any setpoint values from the front panel keypad This safeguard is in addition to the setpoint passcode feature which functions independently see the s1 489 SETUP gt PASSCODE menu The access switch has no effect on setpoint programming from the RS232 and RS485 serial communications ports 5 4 2 Breaker Status BREAKER WARNING PATH SETPOINTS gt S3 DIGITAL INPUTS gt BREAKER STATUS BREAKER STATUS Range Breaker Auxiliary a Breaker Auxiliary b Breaker Auxiliary b This input is necessary for all installations The 489 determines when the generator is online or offline based on the Breaker Status input Once Breaker Auxiliary a is chosen terminals C3 and C4 will be monitored to detect the state of the machine main breaker open signifying the breaker is open and shorted signifying the breaker is closed Once Breaker Auxiliary b is chosen terminals C3 and C4 will be monitored to detect the state of the breaker shorted signifying the breaker is open and open signifying the breaker is closed D 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 5 21 CHAPTER 5 SETPOINTS 5 4 3 General Input A to G PATH SETPOINTS V S3 DIGITAL INPUTS gt V GENERAL INPUT A G ASSIGN DIGITAL Range None Input 1 to Input 7 See
113. of the 489 model information be viewed here when the unit is powered up In the event of a product software upgrade or service question the information shown here should be jotted down prior to any inquiry 6 7 2 Calibration Info PATH ACTUAL VALUES V A6 PRODUCT INFO D V CALIBRATION INFO CALIBRATION gt ORIGINAL CALIBRATION Range month day year INFORMATION v 47 DATE Jan 01 1996 LAST CALIBRATION Range month day year MESSAGE IDATE Jan 01 1996 The date of the original calibration and last calibration may be viewed here 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 6 31 CHAPTER 6 ACTUAL VALUES 6 8 Diagnostics 6 8 1 Diagnostic Messages In the event of a trip or alarm some of the actual value messages are very helpful in diagnosing the cause of the condition The 489 will automatically default to the most important message The hierarchy is trip and pretrip messages then alarm messages In order to simplify things for the operator the Message LED indicator will flash prompting the operator to press the MESSAGE gt key When the MESSAGE P key is pressed the 489 will automatically display the next relevant message and continue to cycle through the messages with each keypress When all of these conditions have cleared the 489 will revert back to the normal default messages Any time the 489 is not displaying the default messages because other actual value or setpoint messages are being v
114. of the case gt Slide the unit into the case until the guide pins on the unit have engaged the guide slots on either side of the case gt Grasp the locking handle from the center and press down firmly rotating the handle from the raised position toward the bottom of the unit When the unit is fully inserted the latch will be heard to click locking the handle in the final position 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 3 5 CHAPTER 3 INSTALLATION 3 1 5 Ethernet Connection CAUTION CAUTION If using the 489 with the Ethernet 10Base T option ensure that the network cable is disconnected from the rear RJ45 connector before removing the unit from the case This prevents any damage to the connector The unit may also be removed from the case with the network cable connector still attached to the rear RJ45 connector provided that there is at least 16 inches of network cable available when removing the unit from the case This extra length allows the network cable to be disconnected from the RJ45 connector from the front of the switchgear panel Once disconnected the cable can be left hanging safely outside the case for re inserting the unit back into the case The unit may be re inserted by first connecting the network cable to the rear RJ45 connector of the 489 see step 3 of Unit Withdrawal and Insertion on page 3 4 Ensure that the network cable does not get caught inside the case while sliding in the unit
115. ports RS485 baud rates RS232 baud rate Parity Protocol 1 front panel non isolated 2 isolated together at 36 Vpk CHAPTER 2 INTRODUCTION 300 1200 2400 4800 9600 19200 9600 None Odd Even Modbus RTU half duplex DNP 3 0 PRODUCTION TESTS Thermal cycling Dielectric strength Operational test at ambient reducing to 40 C and then increasing to 60 C 1 9 kV AC for 1 second or 1 6 kV AC for one minute per UL 508 DO NOT CONNECT FILTER GROUND TO SAFETY GROUND DURING ANY PRODUCTION TESTS TYPE TESTING The table below lists the 489 type tests Standard Test Name Level EIA 485 RS485 Communications Test 32 units at 4000 ft GE Multilin Temperature Cycling 50 C 80 C EC 60068 2 38 Composite Temperature Humidity 65 10 C at 93 RH EC 60255 5 Dielectric Strength 2300 V AC EC 60255 5 Impulse Voltage 5kV EC 60255 5 Insulation Resistance 100 500 V AC 105 EC 60255 21 1 Sinusoidal Vibration 2g EC 60255 22 2 Electrostatic Discharge Direct 8kV EC 60255 22 3 Radiated RF Immunity 10 V m EC 60255 22 4 Electrical Fast Transient Burst Immunity 4 kV EC 60255 22 5 Surge Immunity 4kV 2 kV EC 60255 22 6 Conducted RF Immunity 150 kHz to 80 MHz 10 V m EC 60255 25 Radiated RF Emission Group 1 Class A EC 60255 25 Conducted RF Emission Group 1 Class A EC 60529 ngress of Solid Objects and Water IP 40 front IP20 back EC
116. properly defined and configured as shown in Connecting EnerVista 489 Setup to the Relay on page 4 15 Select the desired device from the site list 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 4 23 4 24 CHAPTER 4 INTERFACES Select the File gt Read Settings from Device menu item to obtain settings information from the device After a few seconds of data retrieval the software will request the name and destination path of the setpoint file The corresponding file extension will be automatically assigned gt Press Save to complete the process Anew entry will be added to the tree in the File pane showing path and file name for the setpoint file Adding Setpoints Files to the Environment The EnerVista 489 Setup software provides the capability to review and manage a large group of setpoint files Use the following procedure to add a new or existing file to the list gt In the files pane right click on Files gt Select the Add Existing Setting File item as shown User Map Actual Values Communications SP ar Allow Docking Hide Add Existing Settings File New Settings File Remove Settings File Edit Settings File Properties Select Item Set Tio Factory Default Values Write Settings to Device Print Settings File Print Preview Settings File Float In Main Window For Help press F1 The Open dialog box will appear prompting
117. received from the monitored communications port is stored in Rx1 and Rx2 If the 489 transmits a message it appears in the Tx1 and Tx2 buffers In addition to these buffers there is a message indicating the status of the last received message 5 13 7 Factory Service PATH SETPOINTS D V S12 489 TESTING V FACTORY SERVICE ENTER FACTORY Range N A FACTORY gt PASSCODE 0 This section is for use by GE Multilin personnel for testing and calibration purposes 5 104 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL Digital Energy Multilin 6 1 Overview 6 1 1 Actual Values Main Menu The actual values message map is shown below ACTUAL VALUES P 6 Al STATUS NETWORK STATUS A s 55 gt essace lt gt LAST TRIP P DATA E gt ALARM STATUS gt gt Ei TRIP PICKUPS gt J pacc gt ALARM PICKUPS gt essace x DIcITAL D essage gt REAL TIME P lt CLOCK ESSAGE END OF PAGE lt gt gt 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL Chapter 6 Actual Values See page See page See page See page See page See page See page See page 489 Generator Management Relay ACTUAL VALUES 51 A2 METERING DATA ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE gt ACTUAL VALUES gt LEAR
118. seconds These values are stored in a FIFO First In First Out buffer The size of the buffer is dictated by the period that is selected for the setpoint The average value of the buffer contents is calculated and stored as the new demand value every minute Demand for real and reactive power is only positive quantities MW and Mvar N 1 Demand N EQ 5 41 n where N programmed Demand Period in minutes n time in minutes 160 140 1j 120 4 100 4 80 4 60 4 40 20 0 MAGNITUDE 50 t 10 t 20 1 30 40 1 50 t 60 t 70 t 80 t 90 t 100 TIME 808717A1 CDR FIGURE 5 27 Rolling Demand 15 Minute Window 5 11 6 Pulse Output PATH SETPOINTS gt V S10 MONITORING V PULSE OUTPUT POS kWh PULSE OUT Range Any combination of Relays 2 to PULSE gt RELAYS 2 5 5 Range 1 to 50000 kWh in steps of 1 MESSAGE POS kWh PULSE OUT g INTERVAL 10 kWh gt Range Any combination of Relays 2 to MESSAGE POS
119. that the 489 has been drawn out 5 5 2 Relay Reset Mode PATH SETPOINTS V S4 OUTPUT RELAYS gt RELAY RESET MODE 1 Range All Resets Remote Reset Only RELAY 51 All Resets I 2 AUXILIARY Range All Resets Remote Reset Only ESSAGE 7 Resets 3 AUXILIARY Range All Resets Remote Reset Only 7 All Resets TEER 4 AUXILIARY Range All Resets Remote Reset Only A11 Resets 5 ALARM Range All Resets Remote Reset Only I 11 Resets 6 SERVICE Range All Resets Remote Reset Only 7 All Resets Unlatched trips and alarms will reset automatically once the condition is no longer present Latched trip and alarm features may be reset at any time providing that the condition that caused the trip or alarm is no longer present and any lockout time has expired If any condition may be reset the Reset Possible LED will be lit The relays may be programmed to All Resets which allows reset from the front keypad or the remote reset digital input or the communications port Optionally they may be programmed to reset by the Remote Reset Only by the remote reset digital input or the communications port For example selected trips such as Instantaneous Overcurrent and Ground Fault may be assigned to output relay 2 so that they may only be reset via the Remote Reset digital input or the communication port The Remote Reset terminals would be connected to a keyswitch so that only authorized person
120. the full stator The setting of this element must be above the maximum unbalance current that normally flows in the neutral circuit Having the element respond only to the fundamental frequency component allows an increase in sensitivity 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL A 3 CHAPTER A APPENDIX The core balance CT be a conventional CT or a 50 0 025 Ground CT allowing the measurement of primary side current levels down to 0 25 A Using a Core Balance CT on the output side of the transformer will provide protection against stator ground faults in ungrounded generators provided that there is a source of zero sequence current from the grid Though in theory one could use this element with a zero sequence current signal obtained from a summation of the three phase currents neutral end or output end by connecting it in the star point of the phase CTs Options 4 and 5 in the figure below this approach is not very useful The main drawback for impedance grounded generators is that the zero sequence current produced by the CT ratio and phase errors could be much larger than the zero sequence current produced by a real ground fault inside the generator Again the time delay on this element must be coordinated with protection elements downstream if the generator is grounded Refer to Ground Directional on page 5 40 for the range of settings of the pickup levels and the time delays The time delay on this element should a
121. the phase CT primary should be chosen such that the FLA is 100 of the phase CT primary or slightly less This will ensure maximum accuracy for the current measurements The maximum phase CT primary current is 50000 A The 489 will measure correctly up to 20 times the phase current nominal rating Since the conversion range is large 1 A or 5 ACT secondaries must be specified at the time of order such that the appropriate interposing CT may be installed in the unit CTs chosen must be capable of driving the 489 phase CT burden see SPECIFICATIONS for ratings Verify that the 489 nominal phase current of 1 A or 5 A matches the secondary rating and connections of the connected CTs Unmatched CTs may result in equipment damage or inadequate protection Polarity of the phase CTs is critical for phase differential negative sequence power measurement and residual ground current detection if used CAUTION 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 3 11 v NOTE CAUTION CHAPTER 3 INSTALLATION Ground Current The 489 has a dual primary isolating transformer for ground CT connections There are no internal ground connections on the ground current inputs The ground CT circuits are shorted by automatic mechanisms on the case if the unit is withdrawn The 1 A tap is used for 1 A or 5 A secondary CTs in either core balance or residual ground configurations If the 1 A tap is used the 489 measures up to 20 A secondary with a maximum
122. third harmonic voltage at the generator terminals Vp and are the corresponding voltage transformer secondary values Permissive Threshold is 0 15 V for the alarm element and 0 1875 V for the trip element In addition the logic for this element verifies that the generator positive sequence terminal voltage is at least 3096 of nominal to ensure that the generator is actually excited This method of using 3rd harmonic voltages to detect stator ground faults near the generator neutral has proved feasible larger generators with unit transformers Its TO usefulness in other generator applications is unknown If the phase VT connection is Open Delta it is not possible to measure the third harmonic voltage at the generator terminals and a simple third harmonic neutral undervoltage element is used In this case the element is supervised by both a terminal voltage level and by a power level When used as a simple undervoltage element settings should be based on measured 3rd harmonic neutral voltage of the healthy machine It is recommended that the element only be used for alarm purposes with open delta VT connections A 1 6 References 1 C R Mason The Art amp Science of Protective Relaying John Wiley amp Sons Inc 1956 Chapter 10 2 J Lewis Blackburn Protective Relaying Principles and Applications Marcel Dekker Inc New York 1987 chapter 8 3 GEMultilin Instruction Manual for the 489 Generator Man
123. time has expired and the condition that caused the alarm or trip is no longer present If an input is assigned to the tachometer function it may not be used here PATH SETPOINTS D V S3 DIGITAL INPUTS V TEST INPUT TEST INPUT D amp ASSIGN DIGITAL Range None Input 1 Input 2 Input 3 INPUT None Input 4 Input 5 Input 6 Input 7 Once the 489 is in service it may be tested from time to time as part of a regular maintenance schedule The unit will have accumulated statistical information relating historically to generator and breaker operation This information includes last trip data peak demand data MWh and Mvarh metering parameter averages RTD maximums analog input minimums and maximums number of trips number of trips by type number of breaker operations the number of thermal resets total generator running hours and the event record When the unit is under test and one of the inputs is assigned to the Test Input function shorting that input will prevent all of this data from being corrupted or updated If an input is assigned to the tachometer function it may not be used here 5 4 6 Thermal Reset PATH SETPOINTS V S3 DIGITAL INPUTS gt V THERMAL RESET THERMAL RESET 1 JASSIGN DIGITAL Range None Input 1 Input 2 Input 5 INPUT None Input 4 Input 5 Input 6 Input 7 During testing or in an emergency it may be desirable to reset the thermal memory used to zero If an input is assigned to
124. 0 100 Negative Sequence Current Rated Current 808791A2 CDR FIGURE 5 3 Negative Sequence Inverse Time Curves 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 5 37 CHAPTER 5 SETPOINTS 5 6 7 Ground Overcurrent PATH SETPOINTS V S5 CURRENT ELEM gt V GROUND OVERCURRENT 1 GROUND 51 GROUND OVERCURRENT Range Off Latched Unlatched OVERCURRENT ALARM Off HD ASSIGN ALARM Range Any combination of Relays 2 to I RELAYS 2 5 5 5 essace gt GROUND O C ALARM Range 0 05 to 20 00 x CT in steps of PICKUP 0 20 x CT 0 01 oes lt GROUND O C ALARM Range 0 to 100 cycles in steps of 1 I x DELAY 0 cycles 8 GROUND OVERCURRENT Range On Off I ALARM EVENTS Off lt GROUND OVERCURRENT Range Off Latched Unlatched I TRIP Off SEAGE gs ASSIGN TRIP Range Any combination of Relays 1 to amp RELAYS 1 4 1 4 55 Z3 GROUND O C TRIP Range 0 05 to 20 00 x CT in steps of i PICKUP 0 20 x CT 0 01 CURVE SHAPE Range see Table 5 1 489 Overcurrent ANSI Extremely Inv Curve Types on page 29 FLEXCURVE TRIP TIME Range 0 to 65535 ms Seen only if er AT 1 03 x PU 65535 ms CURVE SHAPE is Flexcurve ESSAGE lt gt FLEXCURVE TRIP TIME Range 0 to 65535 ms Seen only if gt 1 05 x PU 65535 ms CURVE SHAPE is Flexcurve Range 0 to 65535 ms Seen only if 9 FLEXCURVE TRIP TIME gt 20
125. 0 7 49 30 22 88 22 99 41 82 84 7 88 20 4 92 16 106 15 88 45 8 26 10 14 96 09 113 00 94 17 8 65 0 32 100 00 120 00 100 00 9 04 10 50 103 90 127 17 105 97 942 20 68 107 79 134 52 112 10 9 81 30 86 111 67 142 06 118 38 10 19 40 104 115 54 149 79 124 82 10 58 50 122 119 39 157 74 131 45 10 97 60 140 123 24 165 90 138 25 11 35 70 158 127 07 174 25 145 20 11 74 80 176 130 89 182 84 152 37 12 12 90 194 134 70 191 64 159 70 12 51 100 212 138 50 200 64 167 20 12 90 110 230 142 29 209 85 174 87 13 28 120 248 146 06 219 29 182 75 13 67 130 266 149 82 228 96 190 80 14 06 140 284 153 58 238 85 199 04 14 44 150 302 157 32 248 95 207 45 14 83 160 320 161 04 259 30 216 08 15 22 170 338 164 76 269 91 224 92 15 61 5 64 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL Copper gt BEARING RTD TYPE Range as above 100 Ohm Platinum C AMBIENT RTD TYPE Range as above amp 100 Ohm Platinum MESSAGE OTHER RTD TYPE Range as above 100 Ohm Platinum Each of the twelve RTDs may be configured as None or any one of four application types Stator Bearing Ambient or Other Each of those types may in turn be any one of four different RTD types 100 ohm Platinum 120 ohm Nickel 100 ohm Nickel 10 ohm Copper CHAPTER 5 SETPOINTS Table 5 6 RTD Temperature vs Resistance
126. 0 in steps of 1 O to 5000 sec in steps of 1 Off Latched Unlatched Any combination of Relays 2 to 5 50000 to 50000 in steps of 1 Units reflect ANALOG INPUT 1 UNITS above Over Under 0 1 to 300 0 s in steps of 0 1 On Off Off Latched Unlatched Any combination of Relays 1 to 4 50000 to 50000 in steps of 1 Units reflect ANALOG INPUT 1 UNITS above Over Under 0 1 to 300 0 s in steps of 0 1 There are 4 analog inputs 4 to 20 mA 0 to 20 mA or 0 to 1 mA that may be used to monitor transducers such as vibration monitors tachometers pressure transducers etc These inputs may be used for alarm and or tripping purposes The inputs are sampled every 50 ms The level of the analog input is also available over the communications port With the EnerVista 489 Setup program the level of the transducer may be trended and graphed 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS Before the input may be used it must be configured Aname may be assigned for the input units may be assigned and a minimum and maxi mum value must be assigned Also the trip and alarm features may be blocked until the generator is online for a specified time delay If the block time is 0 seconds there is no block and the trip and alarm features will be active when the generator is offline or online If a time is programmed other than 0 seconds the feature will be disabled when the generator is offline and al
127. 0 s in steps of 0 1 DELAY 3 0 OVERVOLTAGE ALARM Range On Off EVENTS Off OVERVOLTAGE Range Off Latched Unlatched TRIP ASSIGN TRIP Range Any combination of Relays 1 to RELAYS 1 4 1 4 OVERVOLTAGE TRIP Range 1 01 to 1 50 x Rated in steps of i PICKUP 1 20 x Rated 0 01 OVERVOLTAGE TRIP Range 0 1 to 10 0 s in steps of 0 1 i DELAY 1 0 s 5 44 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS Range 0 0 to 999 9 s in steps of 0 1 MESSAGE OVERVOLTAGE CURVE 4 RESET RATE 1 4 _ OVERVOLTAGE CURVE Range Curve Definite Time MESSAGE aD ELEMENT Curve The overvoltage elements may be used for protection of the generator and or its auxiliary equipment during prolonged overvoltage conditions They are always active when the generator is offline or online The alarm element is definite time and the trip element can be either definite time or an inverse time curve When the average of the measured phase phase voltages rises above the pickup level x the generator rated phase phase voltage the element will begin to time out If the time expires a trip or alarm will occur The reset rate is a linear reset time from the threshold of trip The pickup levels are insensitive to frequency over the range of 5 to 90 Hz The formula for the curve is when V V EE pickup EQ 5 19 T V Voickup where T trip time in seconds D OVERVOLTAGE TRIP DELAY s
128. 0 to 85 in steps of 1 Time delay 0 15 to 150 0 s in steps of 0 1 Timing accuracy 50 ms or 0 5 of total time Number of zones 2 GROUND DIRECTIONAL Pickup level 0 05 to 20 00 x CT in steps of 0 01 Time delay 0 1 to 120 0 s in steps of 0 1 Pickup accuracy as per phase current inputs Timing accuracy 100 ms or 0 5 of total time Elements Trip and Alarm GROUND OVERCURRENT Pickup level 0 05 to 20 00 x CT in steps of 0 01 Curve shapes ANSI IEC IAC Flexcurve Definite Time Time delay 0 00 to 100 00 s in steps of 0 01 Pickup accuracy per ground current input Timing accuracy 50 ms at 50 60 Hz or 0 5 total time Elements Trip HIGH SET PHASE OVERCURRENT Pickup level 0 15 to 20 00 x CT in steps of 0 01 Time delay 0 00 to 100 00 s in steps of 0 01 Pickup accuracy as per phase current inputs 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 2 INTRODUCTION Timing accuracy 50 ms at 50 60 Hz or 0 5 total time Elements Trip INADVERTENT ENERGIZATION Arming signal undervoltage and or offline from breaker status Pickup level 0 05 to 3 00 x CT in steps of 0 01 of any one phase Time delay no intentional delay Pickup accuracy as per phase current inputs Timing accuracy 50 ms at 50 60 Hz Elements Trip LOSS OF EXCITATION IMPEDANCE Pickup level 2 5 to 300 0 secondary in steps of 0 1 with adjustable impedance offset 1 0 to 300 0 Q secondary in steps of 0 1 Time delay 0 1 to 10 0 s i
129. 00 The generator full load amps is calculated as generator rated MVA 3 x generator phase to phase voltage Polar coordinates for measured currents are also shown using Va wye connection or Vab lopen delta connection as a zero angle reference vector In the absence of a voltage signal Va or Vab the IA output current is used as the zero angle reference vector 6 3 2 Voltage Metering PATH ACTUAL VALUES V 2 METERING DATA gt V VOLTAGE METERING VOLTAGE gt ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE lt gt lt gt lt gt gt Vab Volts AVERAGE LINE VOLTAGE 0 Volts Van 0 Vbn Ven 0 Volts AVERAGE PHASE lt gt lt gt lt gt gt lt gt lt gt lt gt lt gt lt gt lt gt lt gt gt FUND VOLTAGE 0 Volts LINE A B VOLTAGE 0 Lag LINE VOLTAGE 0 Lag LINE C A VOLTAGE 0 Lag PHASE A N VOLTAGE 0 Lag PHASE B N VOLTAGE 0 Lag PHASE C N VOLTAGE 0 Lag PER UNIT MEASUREMENT OF V Hz 0 00 FREQUENCY 0 00 Hz NEUTRAL VOLTAGE 0 0 V 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL oo Q 0
130. 01 0150 A3 3 00 22 July 2004 1601 0150 A4 1601 0150 A5 4 0x 21 July 2006 1601 0150 A6 4 0x 9 February 2007 1601 0150 A7 4 0x 31 March 2007 1601 0150 A8 4 0x 3 April 2008 1601 0150 A9 4 0x 12 June 2008 1601 0150 AA 4 0x 10 September 2008 1601 0150 AB 4 0x 2 December 2008 1601 0150 AC 4 0x 23 April 2009 1601 0150 AD 4 0x 21 July 2009 A 5 2 Changes to the 489 Manual 489 GENERATOR MANAGEMENT RELAY INSTRUCTIO Table A 3 Major Updates for 489 Manual Revision AD SECT SECT CHANGE DESCRIPTION AC AD Title Title Update Manual part number to 1601 0150 AD 3 1 6 3 1 6 Revision Figure 3 9 revised 3 2 1 3 2 1 Revision Figure 3 10 revised Table A 4 Major Updates for 489 Manual Revision AC SECT SECT CHANGE DESCRIPTION AB AC Title Title Update Manual part number to 1601 0150 AC MANUAL A 27 CHAPTER A APPENDIX Table A 4 Major Updates for 489 Manual Revision AC SECT SECT CHANGE DESCRIPTION AB AC Self test Warnings table Relay Not Configured 4 1 7 4 1 7 Revision revised Table A 5 Major Updates for 489 Manual Revision AB SECT SECT CHANGE DESCRIPTION AA AB Title Title Update Manual part number to 1601 0150 AB 2 2 5 2 2 5 Revision Power Metering changes to spec 7 3 2 7 3 2 Revision Change
131. 1 0 01 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS iy The NEUTRAL VT RATIO Setpoint is seen only if NEUTRAL VOLTAGE TRANSFORMER setpoint is Yes NOTE The voltage transformer connections and turns ratio are entered here The VT should be selected such that the secondary phase phase voltage of the VTs is between 70 0 and 135 0 V when the primary is at generator rated voltage The Neutral VT ratio must be entered here for voltage measurement across the neutral grounding device Note that the neutral VT input is not intended to be used at continuous voltages greater than 240 V If the voltage across the neutral input is less than 240 V during fault conditions an auxiliary voltage transformer is not required If this is not the case use an auxiliary VT to drop the fault voltage below 240 V The NEUTRAL VT RATIO entered must be the total effective ratio of the grounding transformer and any auxiliary step up or step down VT For example if the distribution transformer ratio is 13200 480 and the auxiliary VT ratio is 600 120 the NEUTRAL VT RATIO setpoint is calculated as NEUTRAL VT RATIO Distribution Transformer Ratio x Auxiliary VT Ratio 1 13200 600 _ 0 1 Therefore set NEUTRAL VT RATIO to 137 50 1 5 3 3 Generator Parameters PATH SETPOINTS D gt V S2 SYSTEM SETUP gt V GENERATOR PARAMETERS GENERATOR RATED Range 0 050 to 2000 000 MVA or Not GENERATOR gt Progra
132. 1 0 85 52 7 Mvar gt Alter the following reactive power setpoints in the 57 POWER ELEMENTS gt REACTIVE POWER menu 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 7 TESTING REACTIVE POWER ALARM Unlatched ASSIGN ALARM RELAYS 2 5 5 POSTIVE MVAR ALARM LEVEL 0 6 x Rated NEGATIVE MVAR ALARM LEVEL 0 6 x Rated REACTIVE POWER ALARM DELAY 5 s REACTIVE POWER ALARM EVENT On REACTIVE POWER TRIP Unlatched ASSIGN TRIP RELAYS 1 4 1 POSTIVE MVAR TRIP LEVEL 0 75 x Rated NEGATIVE MVAR TRIP LEVEL 0 75 x Rated REACTIVE POWER TRIP DELAY 10 s gt Inject current and apply voltage as per the table below gt Verify the alarm trip elements and the accuracy of the measured values gt View the measured values in the 2 METERING DATA gt POWER METERING page gt View the Event Records in the 5 EVENT RECORD menu Current Voltage Mvar Alarm Trip Expected Tolerance Measured Expected Observed Delay Expected Observed Delay Vab 120VZ0 Vbc 120V 2120 lag Vca 120Vz240 lag lan 5 AZ 10 lag Ibn 5 AZ130 lag Icn 5 AZ250 lag Vab 120VZ0 Vbc 120V 2120 lag Vca 120Vz240 lag lan 5 AZ340 lag Ibn 5 AZ100 lag Icn 5 AZ220 lag Vab 120VZ0 Vbc 120VZ120 lag Vca 120Vz240 lag lan 5 AZ330 lag Ibn 5 AZ90 lag Icn 5 AZ210 lag Vab 120V Z0 Vbc 120VZ120 lag Vca 120Vz240 lag lan 5 AZ30 lag Ibn 5 AZ150 l
133. 1 to g lt UNDERFREQUENCY Range 20 00 to 60 00 Hz in steps of ESSAGE aD E LEVEL1 59 50 Hz Po ER UTE Range 0 1 to 5000 0 s in steps of 0 1 TRIP DELAY1 60 0 s lt UNDERFREQUENCY Range 20 00 to 60 00 Hz in steps of UNDERFREQUENCY Range 0 1 to 5000 0 s in steps of 0 1 TRIP DELAY2 30 0 It may be undesirable to enable the underfrequency elements until the generator is online This feature can be blocked until the generator is online and the block time expires From that point forward the underfrequency trip and alarm elements will be active A value of zero for the block time indicates that the underfrequency protection is active as soon as voltage exceeds the cutoff level programmed as a multiple of the generator rated phase phase voltage Frequency is then measured Once the frequency of Vab is less than the underfrequency setpoints for the period of time specified a trip or alarm will occur There are dual level and time setpoints for the trip element 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 5 49 5 7 6 Overfrequency PATH SETPOINTS gt 56 VOLTAGE ELEM gt V OVERFREQUENCY 1 OVERFREQUENCY gt ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE lt gt lt gt lt gt lt gt lt gt lt gt lt gt lt gt lt gt gt lt lt gt lt gt gt
134. 11 Range Any combination of Relays 1 to gt ASSIGN TRIP lt gt RELAYS 1 4 1 Range 1 to 250 C in steps of 1 ESSAGE zs 11 TRIP TEMPERATURE 90 RTD 11 defaults to Other RTD type The Other selection allows the RTD to be used to monitor any temperature that might be required either for a process or additional bearings or other There are individual alarm and trip configurations for this RTD Trip voting has been added for extra reliability in the event of RTD malfunction If enabled a second RTD must also exceed the trip temperature of the RTD being checked before a trip will be issued If the RTD is chosen to vote with itself the voting feature is disabled The RTD name may be changed if desired 5 9 5 RTD 12 PATH SETPOINTS D V 58 RTD TEMPERATURE D V RTD 12 1 RTD 12 gt 9 RTD 12 APPLICATION Ambient Range Stator Bearing Ambient Other None MESSAGE RTD 12 NAME Range 8 alphanumeric characters z MESSAGE Range Off Latched Unlatched amp MESSAGE 9 pcs Range Any combination of Relays 2 to RELAYS 2 5 5 5 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS escage gt RTD 12 ALARM Range 1 to 250 C in steps of 1 I TEMPERATURE 60 C gt RTD 12 ALARM Range On Off I EVENTS Off ESSAGE RTD 12 TRIP Range Off Latched Unlatched I escage gt RTD 12 TRIP VOTING Range
135. 13 5 14 5 2 5 CHAPTER 5 SETPOINTS panel or via the clock update command over the RS485 serial link If the approximate time an event occurred without synchronization to other relays is sufficient then entry of time date from the front panel keys is adequate If the RS485 serial communication link is used then all the relays can keep time in synchronization with each other A new clock time is pre loaded into the memory map via the RS485 communications port by a remote computer to each relay connected on the communications channel The computer broadcasts address 0 a set clock command to all relays Then all relays in the system begin timing at the exact same instant There can be up to 100 ms of delay in receiving serial commands so the clock time in each relay is 100 ms the absolute clock accuracy in the PLC or PC See the chapter on Communications for information on programming the time preload and synchronizing commands An IRIG B signal receiver may be connected to 489 units with hardware revision G or higher The relay will continuously decode the time signal and set its internal time correspondingly The signal type setpoint must be set to match the signal provided by the receiver Default Messages PATH SETPOINTS gt S1 489 SETUP gt V DEFAULT MESSAGES GENERATOR STATUS Range N A DEFAULT P Stopped ESSAGE 0 0 Range N A i 0 Amps ESSAGE Vab 0 Vbc 0 Range N A I Vca 0
136. 2 F 194 08 250 C 482 F Applied Expected RTD Measured RTD Temperature Resistance Temperature Reading Select One F 120 2 Nickel C oF 1 273 4 5 e6 7 8 9 wl u 12 92760 40 C 40 F 120 00 Q 0 C 32 F 157 74 Q 50 C 122 F 200 64 Q 100 C 212 F 248 95 Q 150 C 302 F 303 46 Q 200 C 392 F 366 53 Q 250 C 482 F Applied Expected RTD Measured RTD Temperature Resistance Temperature Reading Select One _ F 100 2 Nickel oF 11213 415 6 7 89 77 30 Q 40 40 100 00 Q 0 C 32 F 131450 50 122 167 20 Q 100 C 212 F 207 45 150 C 302 F 252 88 200 C 392 F 305 44 Q 250 C 482 F Applied Expected RTD Measured RTD Tempeature Resistance Temperature Reading Select _ C _ F Cone C F 112 3 415 617 8 19 n 2 7490 40 40 9 04 Q 0 32 F 10 97 Q 50 C 122 F 12 90 Q 100 C 212 F 14 83 Q 150 C 302 F 16 78 Q 200 C 392 F 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 7 TESTING Applied Expected RTD Measured RTD Tempeature Resistance Temperature Reading Select One C F 10 Copper oF 1I 2 l 3 4 5 6 7 8 9 10 1 1 18 73 Q 250 C 482 7 2 7 Digital Inputs and Trip Coil Supervision The digital inputs and trip coil supervision can be verified easily with a simple switch or pushbutton Verify the Switch 24 V
137. 3 6 02 0 1 808792 4 0 0 01 02 03 04 05 06 07 08 0 9 1 Phase Phase Voltage Rated Phase Phase Voltage FIGURE 5 2 Voltage Restraint Characteristic 5 6 6 Negative Sequence PATH SETPOINTS gt V S5 CURRENT ELEM gt V NEGATIVE SEQUENCE 1 NEGATIVE gt NEGATIVE SEQUENCE Range Off Latched Unlatched SEQUENCE ALARM Off lt gt ASSIGN ALARM Range Any combination of Relays 2 to 2 RELAYS 2 5 5 5 lt NEG SEQUENCE ALARM Range 3 to 10096 FLA in steps of 1 I PICKUP 3 FLA lt NEGATIVE SEQUENCE Range 0 1 to 100 0 s in steps of 0 1 E ALARM DELAY 0 5 s NEGATIVE SEQUENCE Range On Off ALARM EVENTS Off lt NEGATIVE SEQUENCE Range Off Latched Unlatched E 0 C TRIP Off ASSIGN TRIP Range Any combination of Relays 1 to ESSAGE RELAYS 1 4 1 4 lt NEG SEQUENCE Range 3 to 10096 FLA in steps of 1 TRIP PICKUP 8 FLA e gt NEG SEQUENCE O C Range 1 to 100 in steps of 1 CONSTANT K 1 NEG SEQUENCE Range 10 to 1000 s in steps of 1 MAX TIME 1000 s 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS NEG SEQUENCE O C Range 0 0 to 999 9 s in steps of 0 01 RESET RATE 227 0 s Rotor heating in generators due to negative sequence current is a well known phenomenon Generators have very specific capability limits where unbalanced cu
138. 39 5 40 5 42 5 43 5 44 5 45 5 48 5 49 5 50 5 51 2 3 CHAPTER 5 SETPOINTS ESSAGE lt gt U V P See page 5 53 gt 3rd HARMONIC ESSAGE L LOSS OF gt See page 5 55 gt EXCITATION ESSAGE 1 DISTANCE P See page 5 56 lt ELEMENT ESSAGE END OF PAGE lt gt gt 1 SETPOINTS gt 1 REACTIVE gt See page 5 61 S7 POWER ELEMENTS POWER MESSAGE lt gt T REVERSE gt See page 5 62 gt MESSAGE T TON FORWARD gt See page 5 63 gt POWER MESSAGE gt END OF PAGE gt 1 SETPOINTS gt 1 RTD TYPES gt See page 5 64 S8 RTD TEMPERATURE MESSAGE 3 1 RTD 1 gt See page 5 65 gt MESSAGE 1 2 gt See page 5 65 gt MESSAGE 1 RTD 3 gt See page 5 65 e ESSAGE 3 1 RTD 12 P See page 5 67 lt gt ESSAGE lt gt T OPEN P See page 5 68 gt SENSOR ESSAGE 1 RTD gt See page 5 69 gt SHORT LOW TEMP ESSAGE END OF PAGE gt 1 SETPOINTS gt 1 MODEL SETUP P See page 5 71 S9 THERMAL MODEL 1 THERMAL gt MESSAGE See page 5 89 lt gt ELEMENTS 5 4 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS MESSAGE lt gt lt gt m ESSAGE ESSAG ESSAG ESSAG ESSAG ESSAG ESSAG ESSAG ESSAG ESSAG lt gt gt SETPOINTS P
139. 4 Alarm Status PATH ACTUAL VALUES gt A1 STATUS gt V ALARM STATUS ALARM STATUS gt NO ALARMS Range N A Message seen when no alarms are active ESSAGE Input A ALARM Range Active Latched See Note I STATUS Active below ESSAGE Input ALARM Range Active Latched See Note I STATUS Active below ESSAGE Input C ALARM Range Active Latched See Note I STATUS Active below ESSAGE gy Input D ALARM Range Active Latched See Note I STATUS Active below ESSAGE lt Input E ALARM Range Active Latched See Note I STATUS Active below 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 6 ACTUAL VALUES ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE lt gt gt lt gt lt gt lt gt lt gt bad gt lt gt lt gt lt gt lt gt gt lt gt lt gt lt gt lt gt lt gt lt gt gt lt gt lt gt lt gt gt lt gt lt gt lt gt lt gt lt gt lt gt lt gt lt gt lt gt lt gt lt gt gt lt gt gt lt gt lt gt Input ALARM STATUS Active Input G ALARM STATUS Active TACHOMETER ALARM 3000 RPM OVERCURRENT ALARM 10 00 x FLA NEG
140. 5000 s in steps of 1 FROM ONLINE lt REACTIVE POWER Range Off Latched Unlatched ALARM Off lt ASSIGN ALARM Range Any combination of Relays 2 to ESSAGE RELAYS 2 5 5 5 lt POSITIVE Mvar ALARM Range 0 02 to 2 01 x Rated in steps of ESSAGE LEVEL 0 85 x Rated 0 01 lt NEGATIVE Mvar ALARM Range 0 02 to 2 01 x Rated in steps of LEVEL 0 85 x Rated 0 01 lt POSITIVE Mvar ALARM Range 0 2 to 120 0 s in steps of 0 1 S DELAY 10 0 s lagging vars overexcited n lt NEGATIVE Mvar ALARM Range 0 2 to 120 0 s in steps of 0 1 ESSAGE DELAY 1 0 s leading vars underexcited REACTIVE POWER ALARM Range On Off n ESSAGE EVENTS Off lt REACTIVE POWER Range Off Latched Unlatched i TRIP Off T ASSIGN TRIP Range Any combination of Relays 1 to RELAYS 1 4 1 4 T lt POSITIVE Mvar TRIP Range 0 02 to 2 01 x Rated in steps of i LEVEL 0 80 x Rated 0 01 lt NEGATIVE Mvar TRIP Range 0 02 to 2 01 x Rated in steps of LEVEL 0 80 x Rated 0 01 POSITIVE Mvar TRIP Range 0 2 to 120 0 s in steps of 0 1 ESSAGE lt gt DELAY 20 0 s lagging vars overexcited NEGATIVE Mvar TRIP Range 0 2 to 120 0 s in steps of 0 1 ESSAGE DELAY 20 0 s leading vars underexcited In a motor generator application it may be desirable not to trip or alarm on reactive power until the machine is online an
141. 6 07 49 90 32 73 15 56 98 39 81 22 2 0 29 1 58 3 87 4 116 145 174 204 233 262 291 320 349 379 408 437 0 6 2 7 63 79 95 11 26 42 58 74 90 05 21 37 2 2 21 5 43 0 64 5 86 1 107 129 150 172 193 215 236 258 279 301 322 5 3 6 9 2 65 18 72 25 78 31 84 37 90 43 96 2 5 16 6 33 3 49 9 66 6 83 3 99 9 116 133 149 166 183 199 216 233 249 0 6 2 8 4 0 6 62 28 94 60 26 92 58 24 90 2 7 13 3 26 6 39 9 53 3 66 6 79 9 93 2 106 119 133 146 159 173 186 199 5 3 5 8 1 4 6 9 62 95 27 60 93 25 58 91 3 0 10 9 21 8 32 8 43 7 54 6 65 5 76 5 87 4 98 3 109 120 131 142 153 163 0 3 6 0 3 6 9 2 6 9 32 25 19 12 05 98 3 2 9 15 18 2 27 4 36 5 45 7 54 8 64 0 73 1 82 3 91 4 100 109 118 128 137 5 9 4 8 3 7 2 6 1 6 60 75 89 04 18 3 5 7 77 15 5 23 3 31 0 38 8 46 6 54 4 62 1 69 9 77 7 85 5 93 2 101 108 116 0 5 2 9 7 4 1 9 6 3 1 8 05 83 60 3 7 6 69 13 3 20 0 26 7 33 4 40 1 46 8 53 5 60 2 66 9 73 6 80 3 87 0 93 7 100 5 9 8 8 7 7 6 6 5 5 4 4 3 3 42 4 0 5 83 11 6 17 4 23 3 29 1 34 9 40 8 46 6 52 4 58 3 64 1 69 9 75 7 81 6 87 4 0 6 9 2 5 8 1 4 7 0 3 6 9 2 5 4 2 5 12 10 2 15 3 20 5 25 6 30 7 35 8 41 0 46 1 51 2 56 3 61 5 66 6 71 7 76 8 5 5 7 0 2 5 7 0 2 5 7 0 2 5 7 4 5 4 54
142. 600 With the following output currents lg 80209 10007115 lag 10007247 lag EQ 7 2 The negative sequence current Ins is calculated as 7 6 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 7 TESTING Ins Ed t Oly al where a 121209 0 5 j0 866 780 Z0 1 2120 1000 2 113 12120 1000 2113 1 780 20 1000 Z127 1000 2233 3 EQ 7 3 780 601 8 J798 6 601 8 798 6 141 2 X 100 14 Therefore the negative sequence current is 14 of FLA The specification for negative sequence current accuracy is per output current inputs Perform the steps below to verify accuracy gt Inthe S2 SYSTEM SETUP D V GEN PARAMETERS menu set GENERATOR RATED MVA 1 04 VOLTAGE PHASE PHASE 600 Note that setting VOLTAGE PHASE PHASE to 600 is equivalent to setting FLA 1000 A This is for testing purposes only gt In the s2 SYSTEM SETUP gt CURRENT SENSING menu set PHASE CT PRIMARY 1000 gt Inject the values shown in the table below and verify accuracy of the measured values View the measured values in the A2 METERING DATA gt CURRENT METERING menu Injected Current Expected Negative Measured Negative 1A Unit 5 A Unit Sequence Current Sequence Current la 0 78 A ZO la 3 9 A ZO Ib 1 A lt 113 lag Ib 5 A 11327100 14 FLA Ic 1 A Z247 lag Ic 5
143. 61000 4 8 Power frequency magnetic field immunity 30 A m EC 61000 4 11 Voltage Dip Voltage Interruption 0 40 100 EEE C37 90 ake and carry 30 ADC EEE C37 90 1 Fast Transient SWC 4 kV EEE C37 90 1 Oscillatory Transient SWC 2 5 kV 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 2 INTRODUCTION 2 2 9 Certification 2 2 10 Physical CERTIFICATION IEC 1010 1 LVD CE for Europe EN 50263 EMC CE for Europe ACA Tick Mark RF emissions for Australia FCC part 15 RF emissions for North America UL listed E83849 ISO 9001 registered CASE Drawout Fully drawout automatic CT shorts Seal Seal provision Door Dust tight door Mounting Panel or 19 rack mount IP Class IP20 X PACKAGING Shipping box 12 x 11 x 10 IW x H x D 30 5cm x 27 9cm x 25 4cm Shipping weight 17 lbs 7 7 kg max TERMINALS Low voltage A B C D terminals 12 AWG max High voltage E F G H terminals 8 ring lug 10 AWG wire standard 2 2 11 Environmental NOTE ENVIRONMENTAL Ambient operating temperature 40 C to 60 Ambient storage temperature 40 C to 80 Humidity up to 9096 non condensing Altitude up to 2000 m Pollution degree 2 At temperatures less than 20 C the LCD contrast may be impaired 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 2 INTRODUCTION 2 2 12 Long term Storage LONG TERM STORAGE Environment In addition to the ab
144. 84 THERMAL RESET tote tenebo orbe ettet eet dud 5 23 THIRD HARMONIC VOLTAGE et fette c dete A 6 TIME s 5 13 6 15 TIME OVERCURRENT CURVES ici cte vete ene secat oed qn A 15 TIMERS uuu 6 27 TOC CHARACTERISTICS t ett tetra redet ne tt ped dus 5 29 TOC CURVES etta tacitae tribes dant e aaea dakat A 15 TRIP GOIL MONITOR iiit iiec er pep ete er tr dte pta 5 91 TRIP COIL SUPERVIS ION eee unas ce et 2 13 7 9 TRIP COUNTER qu 5 17 5 90 6 25 412718 40 cec 6 9 RELAY 3 16 5 28 TRIP TIME ON OVERLOAD ESTIMATED ceca tet e te 6 4 ui c 5 6 TYPE TESTS RR 2 15 TYPICAL WIRING DIAGRAM net oet p ee et 3 9 U UNBALANGE BIAS tette dee xe e nete ete een 5 84 UNDERFREOUENGY iu ul ll u eei ip HI m Ort E 5 49 UNDERVOLPAGE ee b Refer S petet unten unies 2 11 5 43 UNPACKING THE RELAY u u u td e eee 1 1 UPGRADING FIRMWARE cicne ianen enne nennen nennen 4 30 V VIBRATION Pepe RE ete addet nde qalan d er e pet pdf 3 14 VOLTAGE DEPENDENT OVERLOAD 5 77 VOLTAGE INPUTS 1 EE 3 14
145. 9 User Map Modbus addresses 0180h to 01F7h Refer to GE Publication GEK 106491 489 Communications Guide for additional information on the User Map gt Select a connected device in EnerVista 489 Setup gt Select the Setpoint gt User Map menu item to open the following window User Map Quick Connect 489 Quick Connect Settings User Map 65535 SPP T TTT TTT TERE T User Asssigned Address 07 ooma o User Asssigned Address 29 o User Asssigned Address 20 5 ooma o User Asssigned Address 1 ome o 6 52 0 53 54 1 655 55 0 90 58 0004 0 37 5 59 1 0 2 90 552 009 f es 0 ss co 0 95 0 57 1 s coo 929 con 4 150 2 5 _ o 52 9 0 ss cos 546 cos o SS coo 9 S6 cos 0 sy 0 I This window allows the desired addresses to be written to User Map locations The User Map values thot correspond to these addresses are then displayed 4 6 7 Viewing Actual Values You can view real time relay data such as input output status and measured parameters From the main window menu bar selecting Act
146. AD LOCKOUT BLOCK 25 min When the RESET has been pressed and the hot RTD condition is no longer present the display will revert back to the normal default messages 6 8 2 Flash Messages Flash messages are warning error or general information messages that are temporarily displayed in response to certain key presses These messages are intended to assist with navigation of the 489 messages by explaining what has happened or by prompting the user to perform certain actions Table 6 2 Flash Messages KEY IS USED TO ACCESS DENIED ACCESS DENIED ADVANCE THE CURSOR ENTER PASSCODE SHORT ACCESS SWITCH DATA CLEARED DATE ENTRY DATE ENTRY WAS SUCCESSFULLY OUT OF RANGE NOT COMPLETE END OF LIST ARE YOU SURE PRESS ENTER TO VERIFY ALL POSSIBLE RESETS HAVE BEEN PERFORMED DEFAULT MESSAGE HAS BEEN REMOVED DEFAULT MESSAGE HAS BEEN ADDED ENTER A NEW END OF PAGE DEFAULT MESSAGE DEFAULT MESSAGES LIST IS FULL 6 TO 20 ARE ASSIGNED PASSCODE FOR ACCESS INVALID PASSCODE INVALID SERVICE CODE KEY PRESSED IS NEW PASSCODE NEW SETPOINT HAS ENTERED ENTERED INVALID HERE HAS BEEN ACCEPTED BEEN STORED NO ALARMS ACTIVE NO TRIPS OR ALARMS OUT OF RANGE ENTER PASSCODE SECURITY PRESS ENTER TO ADD TO RESET TO BY d NOT ENABLED ENTER 0 DEFAULT MESSAGE PRESS ENTER TO RESET PERFORMED ROUNDED SETPOINT REMOVE MESSAGE SUCCESSFULLY HAS BEEN STORED TACHOMETER MUST USE THAT DIGITAL INPUT THAT INPUT ALREADY INPUT 4 5 6 OR
147. ANALOG INPUT MIN MAX ctt 6 23 A4 MAINTENANCE 06 25 TRIP COUNTERS 6 25 GENERAL COUNTERS 6 27 TIMERS 6 27 AS EVENT RECORDER 2412 oe ce 6 28 EVENT RECORDER circ a Ere REUS 6 28 AG PRODUCE INFORME 6 31 489 MODEL INFO CALIBRATION INFO DIAGNOSTICS ES DIAGNOSTIC MESSAGES ive c roter o aen nde a eti 6 32 FLASH MESSAGES retire terit akana a Gana a cmd ee e Nee na a 6 55 7 TESTING TEST SEMP 7 1 DESCRIPTION p 7 1 HARDWARE FUNCTIONAL TESTS a usu 7 4 OUTPUT CURRENT ACCURACY s 1 4 PHASE VOLTAGE INPUT ACCURACY sse s 4 GROUND 1 A NEUTRAL AND DIFFERENTIAL CURRENT ACCURACY 7 5 NEUTRAL VOLTAGE FUNDAMENTAL ACCURACY ettet 7 6 NEGATIVE SEQUENCE CURRENT ACCURACY 7 6 RID ACCURACY 55 RE ER 7 7 DIGITAL INPUTS AND TRIP COIL SUPERVISION aa 7 9 ANALOG INPUTS AND OUTPUTS OUTPUT RELAYS ADDITIONAL FUNCTIONAL TESTS M OVERLOAD CURVE ACCURACY 2 22 2222 POWER MEASUREMENT TEST v
148. ANSI time overcurrent curve shapes conform to industry standard curves and fit into the ANSI C37 90 curve classifications for extremely very normally and moderately inverse The 489 ANSI curves are derived from the formula E 0 4 pickup C U l pickup U l pickup O where T Trip Time in seconds M Multiplier setpoint I Input Current pickup Pickup Current setpoint A B C E Constants Table 5 2 ANSI Inverse Time Curve Constants ANSI Curve Shape Constants A B Extremely Inverse 0 0399 0 2294 0 5000 3 0094 0 7222 Very Inverse 0 0615 0 7989 0 3400 0 2840 4 0505 Normally Inverse 0 0274 2 2614 0 3000 4 1899 9 1272 Moderately Inverse 0 1735 0 6791 0 8000 0 0800 0 1271 IEC Curves For European applications the relay offers the four standard curves defined in IEC 255 4 and British standard BS142 These are defined as IEC Curve A IEC Curve B IEC Curve C and Short Inverse The formula for these curves is K 0 0 5 amor where T Trip Time in seconds M Multiplier setpoint l Input Current Ipickup Pickup Current setpoint K E Constants Table 5 3 IEC BS Inverse Time Curve Constants IEC BS Curve Shape Constants K IEC Curve A 5142 0 140 0 020 IEC Curve 5142 13 500 1 000 IEC Curve BS142 80 000 2 000 Short Inverse 0 050 0 040 489 GENERATOR
149. AR EVENT RECORD The event recorder saves the last 256 events automatically overwriting the oldest event If desired all events can be cleared using this command to prevent confusion with old information CLEAR GENERATOR INFORMATION The number of thermal resets and the total generator running hours can be viewed in actual values On a new installation or if new equipment is installed this information is cleared through this setpoint CLEAR BREAKER INFORMATION The total number of breaker operations can be viewed in actual values On a new installation or if maintenance work is done on the breaker this accumulator can be cleared with this setpoint 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 5 77 5 3 CHAPTER 5 SETPOINTS S2 System Setup 5 3 1 Current Sensing PATH SETPOINTS D V S2 SYSTEM SETUP gt CURRENT SENSING A PHASE CT PRIMARY Range 1 to 5000 in steps of 1 Not CURRENT D Programmed lt lt Range None 1A Secondary 5A MESSAGE i gt 4 Secondary 50 0 025 GROUND CT RATIO Range 10 to 10000 in steps of 1 Seen MESSAGE amp 100 1 only if Ground CT is 1 A GROUND CT RATIO Range 10 to 10000 in steps of 1 Seen MESSAGE 100 5 only if Ground CT Type is 5 As a safeguard the PHASE CT PRIMARY and GENERATOR PARAMETERS setpoints are defaulted to when shipped indicating that the 489 was never programmed Once these values are entered the 489 will be in service Select the
150. ARING Range 50 to 250 C in steps of 1 i RTD TEMP 40 ESSAGE FAULT OTHER Range 50 to 250 C in steps of 1 I RTD TEMP 40 ESSAGE FAULT AMBIENT Range 50 to 250 C in steps of 1 I RTD TEMP 40 C gt FAULT SYSTEM Range 5 0 to 90 0 Hz in steps of 0 1 I FREQUENCY 60 0 Hz e gt FAULT ANALOG Range 0 to 10096 in steps of 1 I 1 0 gt FAULT ANALOG Range 0 to 100 in steps of 1 I INPUT 2 0 gt FAULT ANALOG Range 0 to 100 in steps of 1 I INPUT 3 0 ESSAGE FAULT ANALOG Range 0 to 100 in steps of 1 INPUT 4 0 The values entered here are substituted for the measured values in the 489 when the SIMULATION MODE is Simulate Fault 5 13 4 Test Output Relays PATH SETPOINTS D V S12 489 TESTING gt V TEST OUTPUT RELAYS FORCE OPERATION OF Range Disabled 1 Trip 2 Auxiliary 4 22 RELAYS 3 Auxiliary 4 Auxiliary 5 Alarm 6 Service All Relays No Relays 5 102 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS The test output relays setpoint may be used during startup or testing to verify that the output relays are functioning correctly The output relays can be forced to operate only if the generator is offline no current is measured and there are no trips or alarms active If any relay is forced to operate the relay will toggle
151. AUTOMATIC OPTIONAL VOLTAGE TRANSDUCER REGULATOR TO 4 20 mA INPUT FOR DC OVEREXCITATION mips FIELD PHASE A DO NOT INJECT OVER RATED CURRENT PHASE a ON G10 amp H10 PHASE b aa gt PHASE B B C GENERATOR AUTOMATIC CT SHORTING TERMINALS 0 0 06 vS vL WOO vs VL noo Woo V o gt gt gt NEUTRAL gt IO PHASE 5 5 OUTPUT CTs PHASE b PHASE NEUTRAL END CTs GROUND INPUTS 808821A5 DWG FIGURE 3 11 Typical Wiring Detail 3 2 5 Control Power CAUTION CAUTION Control power supplied to the relay must match the installed power supply range If the applied voltage does not match damage to the unit may occur All grounds MUST be connected for normal operation regardless of control power supply type The label found on the left side of the relay specifies its order code or model number The installed power supply s operating range will be one of the following LO 20 to 60 V DC or 20 to 48 V AC HI 88 to 300 V DC or 70 to 265 VAC The relay should be connected directly to the ground bus using the shortest practical path A tinned copper braided shielding and bon
152. AY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS 5 11 3 Trip Coil Monitor PATH SETPOINTS D V S10 MONITORING gt V TRIP COIL MONITOR TRIP COIL D 9 TRIP COIL MONITOR Range Off Latched Unlatched MONITOR Y ALARM Off ASSIGN ALARM Range Any combination of Relays 2 to RELAYS 2 5 5 5 SUPERVISION OF TRIP Range 52 Closed 52 Open Closed COIL 52 Closed TRIP COIL MONITOR Range On Off MESSAGE gt ALARM EVENTS Off If the trip coil monitor alarm feature is enabled as latched or unlatched the trip coil supervision circuitry will monitor the trip coil circuit for continuity any time that the breaker status input indicates that the breaker is closed If that continuity is broken a trip coil monitor alarm will occur in approximately 300 ms MESSAGE MESSAGE If 52 Open Closed is selected the trip coil supervision circuitry monitors the trip coil circuit for continuity at all times regardless of breaker state This requires an alternate path around the 52a contacts in series with the trip coil when the breaker is open See the figure below for modifications to the wiring and proper resistor selection If that continuity is broken a Starter Failure alarm will indicate Trip Coil Supervision TRIP COIL SUPERVISION TRIP COIL SUPERVISION R1 TRIP CONTACT 52a TRIP COIL 52a OPEN CLOSED Rip SUPERVISION COIL 52 Open Closed RIP WITH MULTIPLE
153. Analog Input name Not seen if Analog Input 1 is disabled ANALOG INPUT 2 Range 50000 to 50000 Reflects the ESSAGE e 001 0 0 Units Analog Input name Not seen if Analog Input 2 is disabled ANALOG INPUT 3 Range 50000 to 50000 Reflects the ESSAGE E001 0 0 Units Analog Input name Not seen if lt gt Analog Input 3 is disabled ANALOG INPUT 4 Range 50000 to 50000 Reflects the ESSAGE E001 0 0 Units Analog Input name Not seen if Analog Input 4 is disabled The 489 Event Recorder stores generator and system information each time an event occurs The description of the event is stored and a time and date stamp is also added to the record The event recorder data may be inaccurate if 489 relay power on time is less than B 2 seconds NOTE The date and time stamping feature allows reconstruction of the sequence of events for troubleshooting Events include all trips any alarm optionally except Service Alarm and 489 Not Inserted Alarm which always records as events loss of control power application of control power thermal resets simulation serial communication starts stops and general input control functions optionally E001 is the most recent event and E256 is the oldest event Each new event bumps the other event records down until the 256th event is reached The 256th event record is lost when the next event occurs This information can be cleared using 51 489 SETUP V CLEAR DATA D V CLEAR EVENT RE
154. B AND C ARE THE 1 80 ACCELERATION THERMAL LIMIT 60 CURVES 100 90 AND 80 VOLTAGE REPECTIVELY 40 a 20 gt 10 8 4 AND G ARE THE SAFE STALL THERMAL LIMIT 2 TIMES AT 100 90 AND 809 VOLTAGE REPECTIVELY LLL 0 100 200 300 400 500 600 CURRENT 806827A1 CDR FIGURE 5 14 Typical Time Current and Thermal Limit Curves ANSI IEEE C37 96 5 10 2 Model Setup Setpoints PATH SETPOINTS gt V S9 THERMAL MODEL gt MODEL SETUP 1 MODEL SETUP gt ENABLE THERMAL Range No Yes gt Y MODEL No OVERLOAD PICKUP Range 1 01 to 1 25 x FLA in steps of LEVEL 1 01 x FLA 0 01 UNBALANCE BIAS Range 0 to 12 in steps of 1 A value of iiai K FACTOR 0 0 disables this feature ESSAGE COOL TIME CONSTANT Range 0 to 500 min in steps of 1 ONLINE 15 min ESSAGE COOL TIME CONSTANT Range 0 to 500 min in steps of 1 OFFLINE 30 min ESSAGE HOT COLD SAFE Range 0 01 to 1 00 in steps of 0 01 STALL RATIO 1 00 ESSAGE lt ENABLE RTD Range No Yes BIASING No ESSAGE RTD BIAS Range 0 to 250 C in steps of 1 MINIMUM 40 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 5 71 CHAPTER 5 SETPOINTS ESSAGE RTD BIAS CENTER Range 0 to 250 C in steps of 1 I POINT 130 ESSAGE RTD BIAS Range 0 to 250 C in steps of 1 I MAXIMUM 155 ESSAGE lt SELECT CURVE STYLE Range Standard Custom Voltage I Standar
155. CHAPTER 5 SETPOINTS The 489 takes the information provided and create protection curves for any voltage between the minimum and 100 For values above the voltage in question the 489 extrapolates the safe stall protection curve to 110 voltage This current level is calculated by taking the locked rotor current at 100 voltage and multiplying by 1 10 For trip times above the 110 voltage level the trip time of 110 will be used see the figure below 489 VOLTAGE DEPENDENT GE Multilin OVERLOAD PROTECTION CURVES 1000 900 800 700 600 500 Custom Curve 400 300 Acceleration Intersect at 80 V 200 gt Acceleration Intersect at 100 V 100 80 70 60 50 40 30 Safe Stall Time at 80 V 20 80 V Stall Current Safe Stall Time at 100 V va 100 V Stall Current Nus Stall Points Extrapolated to 110 V TIME TO TRIP SECONDS A 1 2 3 4 5 6 7 8 MULTIPLES OF FULL LOAD AMPS 808831A3 CDR FIGURE 5 20 Voltage Dependent Overload Protection Curves iy The safe stall curve is in reality a series of safe stall points for different voltages For a given voltage there can be only one value of stall current and therefore only one safe stall time NOTE 5 92 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS The fo
156. CORD setpoint The event record will not update if a digital input programmed as Test Input is shorted Table 6 1 Cause of Events Sheet 1 of 2 TRIPS Ambient RTD12 Trip Analog P 1 to 4 Trip Bearing RTD 7 Trip Bearing RTD 8 Trip Bearing RTD 9 Trip Bearing RTD 10 Trip Differential Trip Distance Zone 1 Trip Distance Zone 2 Trip Field Bkr Discr Trip Gnd Directional Trip Ground O C Trip Hiset Phase O C Trip Too Energization Input A to G Trip Loss of Excitation 1 Loss of Excitation 2 Low Fwd Power Trip Neg Seq O C Trip Neutral O V Trip Neut U V 3rd Trip Offline O C Trip Overfrequency Trip Overvoltage Trip reflects the name as programmed 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 6 29 CHAPTER 6 ACTUAL VALUES Table 6 1 Cause of Events Sheet 2 of 2 TRIPS Phase O C Trip Phase Reversal Trip Reactive Power Trip Reverse Power Trip RTD11 Trip Sequential Trip Stator RTD 1 Trip Stator RTD 2 Trip Stator RTD 3 Trip Stator RTD 4 Trip Stator RTD 5 Trip Stator RTD 6 Trip Tachometer Trip Thermal Model Trip Underfrequency Trip Undervoltage Trip Volts Hertz Trip ALARMS OPTIONAL EVENTS 489 Not Inserted Ambient RTD12 Alarm Analog P 1 to 4 Alarm Bearing RTD 7 Alarm Bearing RTD 8 Alarm Bearing RTD 9 Alarm Bearing RTD 10 Alarm Breaker Failure Current Demand Alarm Gnd Directional Alarm Gro
157. CTUAL VALUES ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE 000906009 00 09520902 09 09 00 07 60 07 60 09 09 02 H H H H H H H H H H H H Ei D g g g g D E 4 4 Q Q Q Q H H H gt P H H o lt H H H H O D w N H z Ei PICKUP Not Enabled REVERSE POWER PICKUP Not Enabled LOW FORWARD POWER PICKUP Not Enabled PICKUP Not Enabled PICKUP Not Enabled PICKUP Not Enabled PICKUP Not Enabled PICKUP Not Enabled PICKUP Not Enabled PICKUP Not Enabled PICKUP Not Enabled PICKUP Not Enabled PICKUP Not Enabled PICKUP Not Enabled PICKUP Not Enabled THERMAL MODEL PICKUP Not Enabled PICKUP Not Enabled PICKUP Not Enabled PICKUP Not Enabled PICKUP Not Enabled 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL Range Range Range Range Range Range Range Range Range Range Range Range Range Range Range Range Range Range Range Range Not Enabled Inactive Timing Out Active Trip Latched Trip Not Enabled Inactiv
158. CURVE Vann Acceleration Intersect at 80 V Acceleration Intersect at 100 V TIME TO TRIP SECONDS 40 30 20 A 1 2 3 4 5 6 7 8 MULTIPLES OF FULL LOAD AMPS MOTA FIGURE 5 18 Voltage Dependent Overload Curve Custom Enter the per unit current value for the acceleration overload curve intersect with the custom curve for 8096 voltage Enter the per unit current and safe stall protection time for 80 voltage see the acceleration curves below Enter the per unit current value for the acceleration overload curve intersect with the custom curve for 10096 voltage Enter the per unit current and safe stall protection time for 100 voltage see the acceleration curves below 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS 489 e VOLTAGE DEPENDENT OVERLOAD GE Multilin ACCELERATION CURVES 89 Custom 100 80 70 60 50 40 30 TIME TO TRIP SECONDS 20 ES 1 2 3 4 5 6 7 8 MULTIPLES OF FULL LOAD AMPS 808828A3 CDR FIGURE 5 19 Voltage Dependent Overload Curve Acceleration Curves 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 5 81
159. DC with a voltmeter Perform the steps below to verify functionality of the digital inputs gt Open switches of all of the digital inputs and the trip coil supervision circuit View the status of the digital inputs and trip coil supervision in the A1 STATUS gt V DIGITAL INPUTS menu Close switches of all of the digital inputs and the trip coil supervision circuit View the status of the digital inputs and trip coil supervision in the A1 STATUS gt V DIGITAL INPUTS menu Input Expected Status 4 Pass Expected Status 4 Pass Switch Open 8 Fail Switch Closed 8 Fail Access Open Shorted Breaker Status Open Shorted Assignable Input 1 Open Shorted Assignable Input 2 Open Shorted Assignable Input 3 Open Shorted Assignable Input 4 Open Shorted Assignable Input 5 Open Shorted Assignable Input 6 Open Shorted Assignable Input 7 Open Shorted Trip Coil Supervision No Coil Coil 7 2 8 Analog Inputs and Outputs The specification for analog input and analog output accuracy is 1 of full scale Perform the steps below to verify accuracy Verify the Analog Input 24 V DC with a voltmeter 4to 20 mA Inputs gt In the S11 ANALOG I O D V ANALOG INPUT 1 menu set ANALOG INPUT 1 4 20 mA ANALOG INPUT 1 MINIMUM 0 ANALOG INPUT 1 MAXIMUM 1000 repeat all for Analog Inputs 2 to 4 Analog output values should be 0 2 mA on the ammeter Measure
160. Digital Energy Multilin 489 Generator Management Relay Instruction Manual Firmware Revision 4 0X Manual Part Number 1601 0150 AD Manual Order Code GEK 106494M Copyright 2009 GE Multilin GE Multilin 215 Anderson Avenue Markham Ontario Canada L6E 1B3 Tel 905 294 6222 Fax 905 201 2098 GE Multilin s Quality Management Internet http www GEindustrial com muttilin Quality System is registered to 1809001 2000 005094 UL A3775 2009 GE Multilin Incorporated All rights reserved GE Multilin 489 Generator Management Relay instruction manual for revision 4 0x 489 Generator Management Relay is a registered trademark of GE Multilin Inc The contents of this manual are the property of GE Multilin Inc This documentation is furnished on license and may not be reproduced in whole or in part without the permission of GE Multilin The content of this manual is for informational use only and is subject to change without notice Part numbers contained in this manual are subject to change without notice and should therefore be verified by GE Multilin before ordering Part number 1601 0150 AD September 2009 Multilink Hardened Ethernet Switch A Dependable way to Network your Relays and Meters Multilink TI EET Q ez eemo T T Ability to withstand Harsh Environments SENTIR MUI NE IEC 61850 3 compliant for electric utility substotions IEEE 1613 C
161. E lt 0 Units ANALOG INPUT 3 is Disabled I ANALOG INPUT 4 Range 50000 to 50000 Not seen if ESSAGE e 0 Units ANALOG INPUT 4 is Disabled I Vab Iab PreTrip Range 0 to 65535 Qsec 0 to 359 ESSAGE 0 0 Qsec 0 Seen only if Loss of Excitation is enabled The range for the CAUSE OF LAST TRIP setpoint is No Trip to Date General Inputs A to G Sequential Trip Field Bkr Discrep Tachometer Thermal Model Offline Overcurrent Phase Overcurrent Neg Seq Overcurrent Ground Overcurrent Phase Differential RTDs 1 to 12 Overvoltage Undervoltage Volts Hertz Phase Reversal Underfrequency Overfrequency Neutral O V Neutral U V 3rd Reactive Power Reverse Power Low Forward Power Inadvertent Energ and Analog Inputs 1 to 4 NOTE Immediately prior to issuing a trip the 489 takes a snapshot of generator parameters and stores them as pre trip values this allows for troubleshooting after the trip occurs The cause of last trip message is updated with the current trip and the screen defaults to that message All trip features are automatically logged as date and time stamped events as they occur This information can be cleared using the 51 489 SETUP gt V CLEAR DATA gt V CLEAR LAST TRIP DATA setpoint If the cause of last trip is No Trip To Date the subsequent pretrip messages will not appear Last Trip Data will not update if a digital input programmed as Test Input is shorted 6 2
162. E 5 5 103 x TEST gt lt gt m ESSAGE See page 5 104 COMMUNICATION lt gt m ESSAGE See page 5 104 FAcTORY P END OF PAGE 5 1 2 Trips Alarms Control Features The 489 Generator Management Relay has three basic function categories TRIPS ALARMS and CONTROL Trips A 489 trip feature may be assigned to any combination of the four output relays 1 Trip 2 Auxiliary 3 Auxiliary and 4 Auxiliary If a Trip becomes active the appropriate LED indicator on the 489 faceplate illuminates to indicate which output relay has operated Each trip feature may be programmed as latched or unlatched Once a latched trip feature becomes active the RESET key must be pressed to reset that trip If the condition that caused the trip is still present for example hot RTD the trip relay s will not reset until the condition disappears On the other hand if an unlatched trip feature becomes active that trip resets itself and associated output relay s after the condition that caused the trip ceases and the Breaker Status input indicates that the breaker is open If there is a lockout time the trip relay s will not reset until the lockout time has expired Immediately prior to issuing trip the 489 takes a snapshot of generator parameters and stores them as pre trip values allowing for troubleshooting after the trip The cause of last trip message is updated with the current trip and the 489
163. E Range 0 0 to 999 9 in steps of 0 1 RESET RATE 0 0 NEUTRAL O V TRIP ELEM Time Range Curve Definite Time ESSAGE The SUPERVISE WITH DIGITAL INPUT setpoint is seen only if a digital input assigned to Ground Switch Status The neutral overvoltage function responds to fundamental frequency voltage at the generator neutral It provides ground fault protection for approximately 9596 of the stator windings 10096 protection is provided when this element is used in conjunction with the Neutral Undervoltage 3rd harmonic function The alarm element is definite time and the trip element can be either definite time or an inverse time curve When the neutral voltage rises above the pickup level the element will begin to time out If the time expires an alarm or trip will occur The reset rate is a linear reset time from the threshold of trip The alarm and trip levels are programmable in terms of Neutral VT secondary voltage The formula for the curve is when V V pickup EQ 5 23 f 2 V Vpickup 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 5 51 wv NOTE CHAPTER 5 SETPOINTS where T trip time in seconds D NEUTRAL OVERVOLTAGE TRIP DELAY setpoint V neutral voltage Vpickup NEUTRAL TRIP LEVEL setpoint The neutral overvoltage curves are shown below Refer to Appendix B for Application Notes 1000 Time to Trip seconds S TIME DELAY SETTING 0 3 0 1 0 1
164. EIPOINTS TION PLACING THE RELAY IN SERVICE 2 INTRODUCTION a IDE mud LI MD LUN DM sss 2 1 DESCRIP ION tra rimam m RUE atem DERE 2 1 ORDERING db d HOA S 2 4 OTHER ACCESSORIES ua a n ERROR 2 5 SPECIFICATIONS INPUTS OUTPUTS PROTECTION E MEI DIGITAL INPUTS MONITORING NONE POWER SUPPLY lt 9 2 13 COMMUNICATIONS ici RR ROSE HERE HEURE ERR REFER 2 14 Nu cmm 2 14 CERTIFICATION a a pet e emitur tiet RATE 2 15 LET 2 15 55555 2 15 LONG TERM 2 16 3 INSTALLATION MECHANICAL INSTALLATION Ert trt envi 3 1 DESCRIPTION Ea a 3 1 PRODUGTIDENTIEIGATION sq a a aha 3 2 INSTALLATION a umn TN E OTE NIE M SE 3 3 UNIT WITHDRAWAL AND INSERTION tent 3 4 ETHERNET CONNECTION TERMINAL LOCATIONS ureei ni aT a eet tet b ct t ELECTRICAL INSTALLATION LLL L u L u u eee exce TYPICAL WIRING sees
165. ES V 2 METERING DATA D V TEMPERATURE HOTTEST STATOR RTD Range 50 to 250 C No RTD Seen only TEMPERATURE D 4 RTD 1 40 if at least 1 RTD programmed as Stator RTD 1 Range 50 to 250 C No RTD open shorted lt TEMPERATURE 40 C RTD 2 Range 50 to 250 C No RTD open shorted TEMPERATURE 40 C RID 3 Range 50 to 250 C No RTD open shorted x TEMPERATURE 40 C RTD 4 Range 50 to 250 C No RTD open em o shorted TEMPERATURE 40 C 9 RTD 5 Range 50 to 250 C No RTD open E o shorted TEMPERATURE 40 C RTD 6 Range 50 to 250 C No RTD open nies o shorted TEMPERATURE 40 E 7 Range 50 to 250 C No RTD open ees o shorted lt TEMPERATURE 40 C 8 Range 50 to 250 C No RTD open TENER o shorted TEMPERATURE 40 C essage RID 9 Range 50 to 250 C No RTD open i gt gt TEMPERATURE 40 shorted E 10 Range 50 to 250 C No RTD lopen shorted TEMPERATURE 40 C E 11 Range 50 to 250 C No RTD open sales shorted TEMPERATURE 40 C ESSAGE RTD 12 Range 50 to 250 C No RTD open TEMPERATURE 40 C shorted These messages are seen only if the corresponding RTDs are programmed The actual 17 messages reflect the
166. ETTING STARTED Pressing the MESSAGE or MESSAGE A keys will scroll the display up and down through the sub page headers Pressing the lt MESSAGE or ESCAPE key at any sub page heading will return the display to the heading of the corresponding setpoint or actual value page and pressing it again will return the display to the main menu header gt Press the MESSAGE Y key until the DEMAND METERING sub page heading appears DEMAND gt METERING At this point pressing MESSAGE gt or ENTER key will display the messages under this sub page If instead you press the MESSAGE A key it will return to the previous sub page heading In this case TEMPERATURE gt When the symbols gt appear on the top line it indicates that additional sub pages are available and can be accessed by pressing the MESSAGE P or ENTER key gt Press the MESSAGE P or ENTER while at the Demand Metering sub page heading to display the following CURRENT DEMAND 0 Amps gt Press lt MESSAGE key to return to the Demand Metering sub page heading gt Press the MESSAGE Y key to display the next actual value of this sub page Actual values and setpoints messages always have a colon separating the name of the value and the actual value or setpoint This particular message displays the current demand as measured by the relay The menu path to the value shown above is indicated as 2 METERING DATA gt V DEMAND METERING CU
167. El 5 CURRENT 0 Amps GENERATOR LOAD Range 0 to 200096 FLA 0 FLA NEGATIVE SEQUENCE Range 0 to 200096 FLA CURRENT 0 FLA PHASE A CURRENT Range 0 to 999999 A 0 to 359 0A 0 Lag PHASE B CURRENT Range 0 to 999999 A 0 to 559 0A 0 Lag PHASE C CURRENT Range 0 to 999999 A 0 to 559 0A 0 Lag NEUT END A CURRENT Range 0 to 999999 A 0 to 359 0A 0 Lag NEUT END B CURRENT Range 0 to 999999 A 0 to 359 0A 0 Lag NEUT END C CURRENT Range 0 to 999999 A 0 to 359 0A 0 Lag DIFF A CURRENT Range 0 to 999999 A 0 to 559 0A 0 Lag DIFF B CURRENT Range 0 to 999999 A 1 559 0A 0 Lag DIFF C CURRENT Range 0 to 999999 A 0 to 559 0A 0 Lag GROUND CURRENT Range 0 0 to 200000 0 A 0 to 359 0 0 A 0 Lag Seen only if 1 A or 5 A Ground CT is used GROUND CURRENT Range 0 00 to 100 00 A O to 359 0 00 A 0 Lag Seen only if 50 0 025 CT is used 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 6 ACTUAL VALUES All measured current values are displayed here A B C AMPS represent the output side CT measurements A B AMPS the neutral end CT measurements and A B C DIFF AMPS the differential operating current calculated as the vector difference between the output side and the neutral end CT measurements on a per phase basis The 489 negative sequence current is defined as the ratio of negative sequence current to generator rated FLA I5 FLA x 1
168. EnerVista 489 Setup software This program may be used for downloading and uploading setpoint files viewing measured parameters and upgrading the 489 firmware to the latest revision For RS485 communications each relay must have a unique address from 1 to 254 Address O is the broadcast address monitored by all relays Addresses do not have to be sequential but no two units can have the same address or errors will occur Generally each unit added to the link will use the next higher address starting at 1 Baud rates can be selected as 300 1200 2400 4800 9600 or 19200 The data frame is fixed at 1 start 8 data and 1 stop bits while parity is optional The computer RS485 port is a general purpose port for connection to a DCS PLC or PC The Auxiliary RS485 port may also be used as another general purpose port or it may be used to talk to Auxiliary GE Multilin devices in the future 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS Ethernet Communications The following setpoints appear when the relay is ordered with the Ethernet T option PATH SETPOINTS D S1 489 SETUP gt V COMMUNICATIONS SLAVE ADDRESS Range 1 to 254 in steps of 1 COMMUNICATIONS DP 254 ESSAGE COMPUTER RS485 Range 300 1200 2400 4800 9600 gt BAUD RATE 9600 19200 escage gt RS485 Range None Odd Even PARITY None ESSAGE 9 FRONT PORT RS232 Range 300 1200 2400 4800 9600 gt BAUD RATE
169. Fuse Failure MW Mvar and xMVarh demand Simulation Frequency for easy firmware Power Factor RTD Speed in RPM with a Key Phasor Input User Programmable Analog Inputs All features of the 489 are standard there are no options The phase CT secondaries control power and analog output range must be specified at the time of order There are two ground CT inputs one for a 50 0 025 CT and one for a ground CT with a 1 A secondary may also accommodate a 5 A secondary The VT inputs accommodate VTs in either a delta or wye configuration The output relays are always non failsafe with the exception of the service relay The EnerVista 489 Setup software is provided with each unit A metal demo case may be ordered for demonstration or testing purposes 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 2 INTRODUCTION Table 2 3 489 Order Codes nae Base unit 489 489 Generator Management Relay 1A phase CT secondaries i current P5 5 A phase secondaries Lo 20 to 60 V DC OR 20to48V ACat48to 62 Hz I 90to300V DC 70to 265 VAC at 48 to 62 Hz Al Oto 1 mA analog outputs outputs A20 4 to 20 mA analog outputs Basic display Display E Enhanced display larger LCD T Enhanced with Ethernet 10Base T Harsh chemical environment conformal Harsh environment H coating For example the 489 P1 LO A20 E
170. L 2 OVERCURRENT gt 2 UNDERVOLTAGE gt 2 REACTIVE gt 2 RTD gt 2 MODEL gt ALARM POWER TYPES SETUP 2 OFFLINE gt 2 OVERVOLTAGE P 2 REVERSE gt 2 RTD 1 P 2 THERMAL gt OVERCURRENT POWER ELEMENTS 2 INADVERTENT gt 2 VOLTS HERTZ gt 2 LOW gt ENERGIZATION FORWARD POWER 2 PHASE gt 2 PHASE gt 2 RTD 12 gt OVERCURRENT REVERSAL 2 NEGATIVE gt 2 UNDERFREQUENCY D 2 OPEN gt SEQUENCE RTD SENSOR 2 GROUND gt 2 OVERFREQUENCY gt 2 RTD OVERCURRENT SHORT LOW TEMP 2 NEUTRAL 2 PHASE DIFFERENTIAL CVERVOLTAGE Fund 2 NEUTRAL U P 3rd HARMONIC 2 GROUND DIRECTIONAL 2 HIGH SET gt 2 Loss gt PHASE OVERCURRENT OF EXCITATION 2 DISTANCE gt ELEMENT 5 24 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS The active group can be selected using the ACTIVATE SETPOINT GROUP setpoint or the assigned digital input shorting that input will activate the alternate set of protection setpoints Group 2 In the event of a conflict between the ACTIVATE SETPOINT GROUP setpoint or the assigned digital input Group 2 will be activated The LED indicator on the faceplate of the 489 will indicate when the alternate setpoints are active in the protection scheme Changing the active setpoint group will be logged as an event Independently the setpoints in either group can be viewed and or edited using the EDIT SETPOINT GROUP setpoint
171. L CHAPTER 5 SETPOINTS 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL Characteristic R gt 808838A2 CDR FIGURE 5 12 Distance Element Characteristics CHAPTER 5 SETPOINTS 5 8 S7 Power Elements 5 8 1 Power Measurement Conventions Generation of power will be displayed on the 489 as positive watts By convention an induction generator normally requires reactive power from the system for excitation This is displayed on the 489 as negative vars A synchronous generator on the other hand has its own source of excitation and can be operated with either lagging or leading power factor This is displayed on the 489 as positive vars and negative vars respectively All power quantities are measured from the phase phase voltage and the currents measured at the output CTs ONE LINE DIAGRAM POWER PLANE DIAGRAMS Q I 4 i I 4 p 1 POSITIVE DIRECTION SOURCE LOAD RELAY PER IEEE DEFINITIONS PHASOR DIAGRAM POSITIVE ROTATION Bus Voltage E 2 93 ls 54 _ i Watt Watt iot Var ood PF Lead PF Lag 2 Angle By Which Voltage Leads Current 818773AC CDR FIGURE 5 13 Power Measurement Conventions 5 60 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS Reactive Power 1 REACTIVE PATH SETPOINTS gt V S7 POWER ELEMENTS D REACTIVE POWER D BLOCK Mvar ELEMENT Range 0 to
172. L INPUT A TO Gat tren e tee te re mete ete tib ite 5 22 REMOTE RESET rectc decree t estet qaqam De Da TES Sin RR THERMAL RESET DUAL SETPOINTS SEQUENTIAL TRIP FIELD BREAKER TACHOMETER WAVEFORM CAPTURE recette eei Pee ERA 5 27 GROUND SWITCH STATUS en 5 27 S4 OUTPUT RELAYS 5 28 DESCRIPTION 5 28 RELAY RESET MODE 5 28 SS CURRENT ELEMENTS UL ORE 5 29 VERSE TIME OVERCURRENT CURVE CHARACTERISTICS 5 29 QOVERCURRENT ALARM sci ch inpet deett ira Eu 5 33 OFFLINE OVERCURRENT sq ect ec met etu le eb ERE 5 55 ADVERTENT ENERGIZATION 5 54 PHASE OVERCURRENT 5 35 NEGATIVE SEQUENCE 5 36 GROUND QVERGUBRENT 552 aaa dana kaa coat Arti leet ev prete 5 38 PHASEIDIFFERENTIAL Lana aqa a rete rettet lee an ecl d 5 39 GROUND DIRECTION AME 5 40 HIGH SET PHASE OG 5 42 S6 VOLTAGE ELEMENTS UNDERVOLTAGE OVERVOLTAGE VOLTS HERTZ ia ter eee t mtr i PHASE REVERSAL UNDEREREQUENCY tecta tet edi rte cte maaan asqa huuu CUEREREGUIENE Vos as etait da t rut NN M M du E EN NT DE NEUTRAL OVERVOLTAGE
173. LTAGE Range Not Enabled Inactive Timing ESSAGE PICKUP Not Enabled Out Active Trip Latched Trip I VOLTS HERTZ Range Not Enabled Inactive Timing ESSAGE Not Enabled Out Active Trip Latched Trip _ PHASE REVERSAL Range Not Enabled Inactive Timing ESSAGE PICKUP Not Enabled Out Active Trip Latched Trip I UNDERFREQUENCY Range Not Enabled Inactive Timing ESSAGE PICKUP Not Enabled Out Active Trip Latched Trip I ovERFREQUENCY Range Not Enabled Inactive Timing ESSAGE PICKUP Not Enabled Out Active Trip Latched Trip NEUTRAL O V FUND Range Not Enabled Inactive Timing ESSAGE Z PICKUP Not Enabled Out Active Trip Latched Trip NEUTRAL U V 3rd Range Not Enabled Inactive Timing ESSAGE PICKUP Not Enabled Out Active Trip Latched Trip 1055 EXCITATION 1 Range Not Enabled Inactive Timing ESSA PICKUP Not Enabled Out Active Trip Latched Trip 1055 OF EXCITATION 2 Range Not Enabled Inactive Timing ESSAGE gt PICKUP Not Enabled Out Active Trip Latched Trip DISTANCE ZONE 1 Enabled 4 PICKUP Not Enabled Out Active Trip Latched Trip DISTANCE ZONE 2 Range Not Enabled Inactive Timing E Z PICKUP Not Enabled Out Active Trip Latched Trip 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 6 A
174. MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS IAC Curves The curves for the General Electric type IAC relay family are derived from the formula T where Trip Time seconds Multiplier setpoint l Input Current Ipickup Pickup Current setpoint A B C D E Constants D E Table 5 4 IAC Inverse Time Curve Constants P UT S EQ 0 6 IAC Curve Shape Constants A B Extreme Inverse 0 0040 0 6379 0 6200 1 7872 0 2461 Very Inverse 0 0900 0 7955 0 1000 1 2885 7 9586 Inverse 0 2078 0 8630 0 8000 0 4180 0 1947 Short Inverse 0 0428 0 0609 0 6200 0 0010 0 0221 FlexCurve The custom FlexCurve has setpoints for entering times to trip at the following current levels 1 03 1 05 1 1 to 6 0 in steps of 0 1 and 6 5 to 20 0 in steps of 0 5 The relay then converts these points to a continuous curve by linear interpolation between data points To enter a custom FlexCurve read off each individual point from a time overcurrent coordination drawing and enter it into a table as shown Then transfer each individual point to the 489 using either the EnerVista 489 Setup software or the front panel keys and display 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL Table 5 5 FlexCurve Trip Times CHAPTER 5 SETPOINTS
175. METER TRIPS 0 OFFLINE OVERCURRENT TRriPS 0 PHASE OVERCURRENT TRriPS 0 lt NEG SEQ OVERCURRENT TRIPS 0 GROUND OVERCURRENT TRriPS 0 PHASE DIFFERENTIAL TRIPS 0 lt GROUND DIRECTIONAL TRIPS 0 gt HIGH SET PHASE O C TRIPS 0 gt UNDERVOLTAGE TRIPS 0 ESSAGE OVERVOLTAGE TRriPS 0 VOLTS HERTZ TRIPS 0 PHASE REVERSAL TRIPS 0 UNDERFREQUENCY TRriPS 0 OVERFREQUENCY TRriPS 0 ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL Range Range Range Range Range Range Range Range Range Range Range Range Range Range Range Range Range O to 50000 Caused by the General Input Trip feature 0 to 50000 0 to 50000 0 to 50000 0 to 50000 0 to 50000 0 to 50000 0 to 50000 0 to 50000 0 to 50000 0 to 50000 0 to 50000 0 to 50000 0 to 50000 0 to 50000 0 to 50000 0 to 50000 ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE CHAPTER 6 ACTUAL VALUES
176. Major Updates for 489 Manual Revision A6 PAG PAG CHANGE DESCRIPTION E E 5 6 Title Title Update Manual part number to 1601 0150 A6 2 14 2 14 Update Changes to ELECTROSTATIC DISCHARGE value Table A 11 Major Updates for 489 Manual Revision A4 PAG PAG CHANGE DESCRIPTION E E A3 A4 Title Title Update Manual part number to 1601 0150 A4 2 2 Update Updated ORDERING section 2 2 Update Updated SPECIFICATIONS section 3 4 Add Added ETHERNET COMMUNICATION section 5 522 Removed SERIAL PORTS section 5 Add Added COMMUNICATIONS section 5 44 5 44 Update Updated DISTANCE ELEMENT section 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER A APPENDIX Table A 11 Major Updates for 489 Manual Revision A4 PAG PAG CHANGE DESCRIPTION E E A3 A4 6 3 Add Added NETWORK STATUS section 7 16 Add Added DISTANCE ELEMENT ACCURACY section Table A 12 Major Updates for 489 Manual Revision A3 PAG PAG CHANGE DESCRIPTION E E A2 A3 Title Title Update Manual part number to 1601 0150 A3 5 67 5 67 Update MODEL COOLING diagram to Table A 13 Major Updates for 489 Manual Revision A2 PAG PAG CHANGE DESCRIPTION E E 1 2 Title Title Update Manual part number to 1601 0150 A2 Additional changes for revision A2 were cosmetic There was no change to content 489 GE
177. NED DATA MESSAGE MESSAGE MESSAGE lt gt gt ACTUAL VALUES 51 A4 MAINTENANCE MESSAGE MESSAGE MESSAGE 9 e ACTUAL VALUES P A5 EVENT RECORD MESSAGE 6 2 CURRENT gt lt gt VOLTAGE P lt gt lt gt POWER P lt gt TEMPERATURE P lt gt DEMAND P lt gt aNALOG D A x SPEED D END OF PAGE PARAMETER 92 Y E ANALOG INPUT gt MIN MAX END OF PAGE lt gt a H N H tg x 02 ib lt gt s GENERAL TIMERS M END OF PAGE 9 o 254 P 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL See See See See See See See See See See See See See See See CHAPTER 6 ACTUAL VALUES page 6 16 page 6 17 page 6 18 page 6 19 page 6 20 6 20 page page 6 21 page 6 22 6 22 page page 6 23 page 6 25 6 27 page page 6 27 page 6 28 page 6 28 CHAPTER 6 ACTUAL VALUES MESSAGE See page 6 28 E000 D MESSAGE END OF PAGE ACTUAL VALUES gt 489 MODEL gt See page 6 31 A6 PRODUCT INFO INFORMATION HN MESSAGE S 6 31 CALIBRATION D SUMUS MESSAGE END OF PAGE 6 1 2 Description Measured values maintenance and fault analysis information are accessed in the actual values Actual values may be accessed via one of the foll
178. NERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER A APPENDIX A 6 EU Declaration of Conformity A 6 1 EU Declaration of Conformity General Electric Multilin 215 Anderson Ave Markham Ontario Canada L6E 1B3 Tel 905 294 6222 Fax 905 294 8512 EU DECLARATION OF CONFORMITY Applicable Council Directive s 1 73 23 The Low Voltage Directive 2 89 336 EEC The EMC Directive Standard s to Which Conformity is Declared 1 EN 60947 1 1999 Low voltage switchgear and control gear EN 1010 1 1990 A 1 1992 2 1995 Safety Requirements for Electrical Equipment for Measurement Control and Laboratory Use 2 EN 50263 1999 EMC Product Standard for Measuring Relays and Protection Equipment Manufacturer s Name General Electric Multilin Manufacturer s Address 215 Anderson Ave Markham Ontario Canada L6E 1B3 Manufacturer s Representative inthe EU Jokin Galletero GE Multilin Avenida Pinoa 10 48170 Zamudio Spain Tel 34 94 4858817 Fax 34 94 4858838 Type of Equipment Protection amp Control Relay Model Number SR489 First Year of Manufacture 1999 I the undersigned hereby declare that the equipment specified above conforms to the above Directives and Standards Full Name Jeff Mazereeuw Position Technology Manager Signature il Place Multilin Date February 13 2006 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER A APPENDIX A 7 Warranty A 7 1 GE Multilin
179. OK to continue The software will prompt with another Upload Firmware Warning window This will be the final chance to cancel the firmware upgrade before the flash memory is erased gt Click Yes to continue or No to cancel the upgrade 489Setup gt A X 489 Workcell Manufacturing_Objects EPR OM 32E 100A0 000 will be uploaded to relay continue Yes No The EnerVista 489 Setup software now prepares the 489 to receive the new firmware file The 489 will display a message indicating that it is in Upload Mode While the file is being loaded into the 489 a status box appears showing how much of the new firmware file has been transferred and how much is remaining as well as the upgrade status The entire transfer process takes approximately five minutes The EnerVista 489 Setup software will notify the user when the 489 has finished loading the file gt Carefully read any displayed messages and click OK to return the main screen Note Cycling power to the relay is recommended after a firmware upgrade 17 After successfully updating the 489 firmware the relay will not be in service and will require setpoint programming To communicate with the relay the following settings will have to be manually programmed MODBUS COMMUNICATION ADDRESS BAUD RATE PARITY if applicable 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 4 31 CHAPTER 4 INTERFACES When communications is established the saved setpoints must be
180. ONAL COMPUTER UNIT 1 UNIT 2 UNIT 32 RS485 85485 CONVERTER m x nd 806815A5 DWG 120 Ohm Inf TERMINATING TERMINATING RESISTOR CAPACITOR FIGURE 3 18 RS485 Communications Wiring 3 2 13 Dielectric Strength It may be required to test a complete motor starter for dielectric strength flash or hi pot with the 489 installed The 489 is rated for 1 9 kV AC for 1 second or 1 6 kV AC for 1 minute per UL 508 isolation between relay contacts CT inputs VT inputs trip coil supervision and the safety ground terminal G12 Some precautions are required to prevent damage to the 489 during these tests Filter networks and transient protection clamps are used between control power trip coil supervision and the filter ground terminal G11 This filtering is intended to filter out high voltage transients radio frequency interference RFI and electromagnetic interference EMI The filter capacitors and transient suppressors could be damaged by application continuous high voltage Disconnect filter ground terminal G11 during testing of control 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 3 INSTALLATION power and trip coil supervision CT inputs VT inputs and output relays do not require any special precautions Low voltage inputs lt 30 V RTDs analog inputs analog outputs digital inputs and RS485 co
181. Off _ ASSIGN TRIP Range Any combination of Relays 1 to MESSAGE 9 gt RELAYS 1 4 1 4 The 489 can detect the phase rotation of the three phase voltages A trip will occur within 200 ms if the Phase Reversal feature is turned on the generator is offline each of the phase phase voltages is greater than 50 of the generator rated phase phase voltage 5 48 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS and the phase rotation is not the same as the setpoint Loss of VT fuses cannot be detected when the generator is offline and could lead to maloperation of this element If the VT type is selected as None the phase reversal protection is disabled 5 7 5 Underfrequency PATH SETPOINTS gt V S6 VOLTAGE ELEM gt V UNDERFREQUENCY 1 UNDERFREQUENCY BLOCK UNDERFREQUENCY Range 0 to 5 sin steps of 1 FROM ONLINE 1 s Range 0 50 to 0 99 x Rated in steps of lt VOLTAGE LEVEL x CUTOFF 0 50 x Rated E gt UNDERFREQUENCY Range Off Latched Unlatched ALARM Off n lt ASSIGN ALARM Range Any combination of Relays 2 to ESSAGE aD P 2 5 5 5 lt UNDERFREQUENCY Range 20 00 to 60 00 Hz in steps of lt gt Range 0 1 to 5000 0 s in steps of 0 1 ALARM DELAY 5 0 s Eure Range On Off ALARM EVENTS Off Range Off Latched Unlatched TRIP Off lt ASSIGN TRIP Range Any combination of Relays
182. Options Log Fie 750 760 MII Family M Family 489 4 14 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 4 INTERFACES 4 5 Connecting EnerVista 489 Setup to the Relay 4 3 1 Configuring Serial Communications Before starting verify that the serial cable is properly connected to either the RS232 port on the front panel of the device for RS232 communications or to the RS485 terminals on the back of the device for RS485 communications See Hardware on page 4 10 for connection details This example demonstrates an RS232 connection For RS485 communications the GE Multilin F485 converter will be required Refer to the F485 manual for additional details To configure the relay for Ethernet communications see Configuring Ethernet Communications on page 4 17 gt Install and start the latest version of the EnerVista 489 Setup software available from the GE EnerVista CD See the previous section for the installation procedure gt Click on the Device Setup button to open the Device Setup window V Click the Add Site button to define a new site Enter the desired site name in the Site Name field If desired a short description of site can also be entered along with the display order of devices defined for the site In this example we will use Pumping Station 1 as the site name gt Click the OK button when complete The new site will appear in the upper left list in the En
183. PERATURE 90 C RTDs 7 through 10 default to Bearing RTD type There are individual alarm and trip configurations for each RTD This allows one of the RTDs to be turned off if it malfunctions The alarm level and the trip level are normally set slightly above the normal running temperature but below the bearing temperature rating Trip voting has been added for extra reliability in the event of RTD malfunction If enabled a second RTD must also exceed the trip temperature of the RTD being checked before a trip will be issued If the RTD is chosen to vote with itself the voting feature is disabled Each RTD name may be changed if desired 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS 5 9 4 RTD 11 PATH SETPOINTS V S8 RTD TEMPERATURE PV RTD 11 1 RTD 11 b 11 APPLICATION Other Stator Bearing Ambient Other None Range 8 alphanumeric characters gt RTD 11 NAME gt Range Off Latched Unlatched essas gt RTD 11 ALARM g Range Any combination of Relays 2 to ESSAGE 9 ASSIGN ALARM g RELAYS 2 5 5 Range 1 to 250 C in steps of 1 gt RTD 11 ALARM g p TEMPERATURE 80 gt RTD 11 ALARM Range On Off EVENTS Off z Range Off Latched Unlatched escage gt RID 11 TRIP g Hewes RTD 11 TRIP VOTING Range RTD 1 to 12 I RTD
184. Phase CT so that the maximum fault current does not exceed 20 times the primary rating When relaying class CTs are purchased this precaution helps prevent CT saturation under fault conditions The secondary value of 1 or 5 A must be specified when ordering so the proper hardware will be installed The PHASE CT PRIMARY setpoint applies to both the neutral end CTs as well as the output CTs For high resistance grounded systems sensitive ground current detection is possible if the 50 0 025 Ground CT is used To use the 50 0 025 CT input set GROUND CT to 50 0 025 No additional ground CT messages will appear On solid or low resistance grounded systems where fault currents may be quite large the 489 1 A 5 A secondary Ground CT input should be used Select the Ground CT primary so that potential fault current does not exceed 20 times the primary rating When relaying class CTs are purchased this precaution will ensure that the Ground CT does not saturate under fault conditions The 489 uses a nominal CT primary rating of 5 A for calculation of pickup levels 5 3 2 Voltage Sensing PATH SETPOINTS gt S2 SYSTEM SETUP gt V VOLTAGE SENSING i VT CONNECTION TYPE Range Open Delta Wye None VOLTAGE gt ewer VOLTAGE TRANSFORMER Range 1 00 1 to 300 00 1 in steps of RATIO 5 00 1 0 01 NEUTRAL VOLTAGE Range No Yes MESSAGE TRANSFORMER No NEUTRAL VT Range 1 00 1 to 240 00 1 in steps of MESSAGE RATIO 5 00
185. R 5 SETPOINTS See Table 5 8 Analog Output Parameters on page 97 0 00 to 2 00 x Rated in steps of 0 01 0 00 to 2 00 x Rated in steps of 0 01 See Table 5 8 Analog Output Parameters on page 97 0 00 to 2 00 x Rated in steps of 0 01 0 00 to 2 00 x Rated in steps of 0 01 See Table 5 8 Analog Output Parameters on page 97 0 00 to 20 00 x Rated in steps of 0 01 0 00 to 20 00 x Rated in steps of 0 01 See Table 5 8 Analog Output Parameters on page 97 0 00 to 1 50 x Rated in steps of 0 01 0 00 to 1 50 x Rated in steps of 0 01 The 489 has four analog output channels 4 to 20 mA or 0 to 1 mA as ordered Each channel may be individually configured to represent a number of different measured parameters as shown in the table below The minimum value programmed represents the 4 mA output The maximum value programmed represents the 20 mA output All four of the outputs are updated once every 50 ms Each parameter may only be used once The analog output parameter may be chosen as Real Power MW for a 4 to 20 mA output If rated power is 100 MW the minimum is set for 0 00 x Rated and the maximum is set for 1 00 x Rated the analog output channel will output 4 mA when the real power 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS measurement is 0 MW When the real power measurement is 50 MW the analog output channel will output 12 mA When the real power measurement is 100 MW the ana
186. R 6 ACTUAL VALUES The number of trips by type is displayed here When the total reaches 50000 all counters reset This information can be cleared with the St 489 SETUP gt V CLEAR DATA gt V CLEAR TRIP COUNTERS setpoint Trip counters will not update if a digital input programmed as Test Input is shorted In the event of multiple trips the only the first trip will increment the trip counters 6 5 2 General Counters GENERAL COUNTERS PATH ACTUAL VALUES V 4 MAINTENANCE gt V GENERAL COUNTERS gt NUMBER OF BREAKER Range 0 to 50000 7 OPERATIONS 0 6 5 3 Timers NUMBER OF THERMAL Range 0 to 50000 Seen only if a RESETS 0 Digital Input is assigned to Thermal Reset MESSAGE One of the 489 general counters will count the number of breaker operations over time This may be useful information for breaker maintenance The number of breaker operations is incremented whenever the breaker status changes from closed to open and all phase currents are zero Another counter counts the number of thermal resets if one of the assignable digital inputs is assigned to thermal reset This may be useful information when troubleshooting When either of these counters exceeds 50000 that counter will reset to 0 The NUMBER OF BREAKER OPERATIONS counter can also be cleared using the s1 489 SETUP D V CLEAR DATA gt CLEAR BREAKER INFORMATION Setpoint The NUMBER OF THERMAL RESETS counter be cleared using the 61 489 SET
187. REAKER OPEN 1TRIP SETPOINT ACCESS BREAKER CLOSED 2 AUXILIARY COMPUTER RS232 HOT STATOR 3 AUXILIARY COMPUTER RS485 NEG SEQUENCE 4 AUXILIARY AUXILIARY RS485 GROUND 5 ALARM ALT SETPOINT LOSS OF FIELD 6 SERVICE RESET FAIL POSSIBLE puas MESSAGE BREAKER FAILURE 808732A3 CDR FIGURE 4 1 489 LED Indicators 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 4 1 4 2 CHAPTER 4 INTERFACES 489 Status LED Indicators 489 IN SERVICE Indicates that control power is applied all monitored input output and internal systems are OK the 489 has been programmed and is in protection mode not simulation mode When in simulation or testing mode the LED indicator will flash SETPOINT ACCESS Indicates that the access jumper is installed and passcode protection has been satisfied Setpoints may be altered and stored COMPUTER RS232 Flashes when there is any activity on the RS232 communications port Remains on continuously if incoming data is valid COMPUTER RS485 AUXILIARY RS485 Flashes when there is any activity on the computer auxiliary RS485 communications port These LEDs remain on continuously if incoming data is valid and intended for the slave address programmed in the relay ALT SETPOINTS Flashes when the alternate setpoint group is being edited and the primary setpoint group is active Remains on continuously if the alternate setpoint group is active The alternate setpoint group feature is enabled as one of the assigna
188. RELAY INSTRUCTION MANUAL 6 35 CHAPTER 6 ACTUAL VALUES END OF LIST This message will indicate when the bottom of a subgroup has been reached NO ALARMS ACTIVE If an attempt is made to enter the Alarm Status message subgroup but there are no active alarms this message will appear THIS FEATURE NOT PROGRAMMED If an attempt is made to enter an actual value message subgroup when the setpoints are not configured for that feature this message will appear THIS PARAMETER IS ALREADY ASSIGNED A given analog output parameters can only be assigned to one output If an attempt is made to assign a parameter to a second output this message will appear THAT INPUT ALREADY USED FOR TACHOMETER If a digital input is assigned to the tachometer function it cannot be used for any other digital input function If an attempt is made to assign a digital input to a function when it is already assigned to tachometer this message will appear TACHOMETER MUST USE INPUT 4 5 6 or 7 Only digital inputs 4 5 6 or 7 may be used for the tachometer function If an attempt is made to assign inputs 1 2 3 or 4 to the tachometer function this message will appear THAT DIGITAL INPUT IS ALREADY IN USE If an attempt is made to assign a digital input to tachometer when it is already assigned to another function this message will appear To edit use VALUE UP or VALUE DOWN key If a numeric key is pressed on a setpoint parameter that is not numeric this m
189. RRENT DEMAND Setpoints and actual values messages are referred to in this manner throughout the manual For example the A4 MAINTENANCE gt TRIP COUNTERS gt TOTAL NUMBER OF TRIPS path representation describes the following key press sequence gt Press the MENU key until the actual value header appears on the display m ACTUAL VALUES gt gt Press MESSAGE gt or the ENTER key and then MESSAGE Y key until the A4 MAINTENANCE message is displayed m ACTUAL VALUES gt A4 MAINTENANCE 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 1 GETTING STARTED gt Press the MESSAGE P or ENTER key to display TRIP COUNTERS message m TRIP 51 COUNTERS gt Press the MESSAGE P or ENTER key to reach the TOTAL NUMBER OF TRIPS message and the corresponding actual value TOTAL NUMBER OF TRIPS 0 gt Press the MESSAGE Y key to display the next actual value message as shown below DIGITAL INPUT TRIPS 0 gt Press the MESSAGE or MESSAGE A keys to scroll the display up and down through all the actual value displays in this corresponding sub page gt Press the lt MESSAGE key to reverse the process described above and return the display to the previous level m TRIP gt COUNTERS gt Press the lt MESSAGE key twice to return to the A4 MAINTENANCE page header m ACTUAL VALUES gt A4 MAINTENANCE 1 2 2 Panel Keying Example The following figure provides a graphical example of how
190. RTD 1 to RTD 12 I gt RTD 12 ESSAGE ASSIGN TRIP Range Any combination of Relays 1 to i RELAYS 1 4 1 4 RTD 12 TRIP Range 1 to 250 C in steps of 1 ESSAGE E gt TEMPERATURE 80 C RTDs 12 defaults to Ambient RTD type The Ambient selection allows the RTD to be used to monitor ambient temperature There are individual alarm and trip configurations for this RTD Trip voting has been added for extra reliability in the event of RTD malfunction If enabled a second RTD must also exceed the trip temperature of the RTD being checked before a trip will be issued If the RTD is chosen to vote with itself the voting feature is disabled The RTD name may be changed if desired 5 9 6 Open RTD Sensor SETPOINTS D V S8 RTD TEMPERATURE D V OPEN RTD SENSOR 1 OPEN RTD gt 0 OPEN RTD SENSOR Range Off Latched Unlatched SENSOR Off lt ASSIGN ALARM Range Any combination of Relays 2 to RELAYS 2 5 5 5 OPEN RTD SENSOR Range On Off A ALARM EVENTS Off The 489 has an Open RTD Sensor Alarm This alarm will look at all RTDs that have either an alarm or trip programmed and determine if an RTD connection has been broken Any RTDs that do not have a trip or alarm associated with them will be ignored for this feature When a broken sensor is detected the assigned output relay will operate and a message will appear on the display identifying the RTD that is broken It is recommended that if thi
191. Range Off Latched Unlatched MESSAGE ALARM Off Range Any combination of Relays 2 to ASSIGN ALARM g RELAYS 2 5 5 Range 1 to 1000000 h in steps of 1 MESSAGE A GEN RUNNING HOURS LIMIT 1000 h The 489 can measure the generator running hours This value may be of interest for periodic maintenance of the generator The initial generator running hour allows the user to program existing accumulated running hours on a particular generator the relay is protecting This feature switching 489 relays without losing previous generator running hour values 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 5 95 5 12 11 Analog Inputs Outputs 5 96 5 12 1 Analog Outputs 1 to 4 PATH SETPOINTS V S11 ANALOG I O gt ANALOG OUTPUT 1 4 ANALOG OUTPUT 1 Range ANALOG gt Real Power MW REAL POWER MW Range MESSAGE MESSAGE ANALOG gt MESSAGE MESSAGE ANALOG gt MESSAGE MESSAGE ANALOG gt MESSAGE MESSAGE 0 00 x Rated REAL POWER MW Range 1 25 x Rated ANALOG OUTPUT 2 Range Apparent Power MVA APPARENT POWER MVA Range 0 00 x Rated APPARENT POWER MVA Range 1 25 x Rated ANALOG OUTPUT 3 Range Avg Output Current AVG OUTPUT CURRENT Range 0 00 x FLA AVG OUTPUT CURRENT Range 1 25 x FLA ANALOG OUTPUT 4 Range Average Voltage AVERAGE VOLTAGE Range 0 00 x Rated AVERAGE VOLTAGE Range 1 25 x Rated CHAPTE
192. S VOLTAGE 60 Hz CHAPTER A APPENDIX HGF5C SECONDARY VOLTAGE 60 Hz 001 002 005 01 02 05 031 02 05 1 0 2 5 SECONDARY EXCITING CURRENT 60Hz 808841A1 1 001 002 005 01 02 05 01 02 05 1 0 25 SECONDARY EXCITING RMS AMPS 60 Hz le 808842A1 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER A APPENDIX A 3 2 Ground Fault CTs for 5 A Secondary CT For low resistance or solidly grounded systems a 5 A secondary CT should be used Two sizes are available with 5 or 13 x 16 windows Various Primary amp CTs can be chosen 50 to 250 GCT5 1000 NUON CURRENT TURNS SEE NO RATIO RATIO RES X021 0251 2505 80 1 0 097 021 0201 200 5 40 1 0 078 021 0151 150 5 30 1 0 058 021 0101 100 5 20 1 0 039 X021 0076 759 15 1 0 029 5 x X021 0051 50 5 10 1 0 019 90 250 F x OHMS 75 C 8 100 75 F 5o z PES This test report is in accordance with gt ANSI IEEE 57 13 1993 ABOVE TS UNE THE VOLTAGE 8 FOR EXCITING CURRENT FoR Ave Gh MAL Kor GE iios 8 TOAN ANa E vate Se TSE POT ir Sa DUN
193. S232 COMMUNICATIONS 4 3 5 12 configuring with EnerVista 469 setup 2 2 lt 4 17 configuring with EnerVista 489 setup 2 2 2 2 9 4 15 configuring with EnerVista 750 760 4 17 CONNECLIONS fe 4 11 RS485 COMMUNICATIONS 3 17 5 12 configuring with EnerVista 469 s tup uuu uU 4 17 configuring with EnerVista 489 setup 2 4 15 configuring with EnerVista 750 760 4 17 eec RE 4 12 RTD atual To Ui 6 19 6 23 a 5 17 5 23 6 22 SENSOF CONNECTIONS m 3 15 SOLD 5 65 5 66 5 67 6 c 2 7 2 11 7 7 RT D ACCURACY TEST iiie crt 7 7 e O 5 87 MAXIMUMS niit tee e Co 6 22 SENSOR OPEN cii i ene ten rende ete eet ed Hed ya 5 68 RTD SHORT LOW TEMPERATURE sssini 5 69 TYPES cese ru ev P dad RR CR 5 64 RUNNING HOUR SETUP ii leet De et aqa ciu red
194. SAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE lt gt gt PREFERENCES P lt gt cowmwuNIicATIONS DP E REAL TIME gt gt DEFAULT P CLEAR DATA P See END OF PAGE 59029 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL page page page page page page page 9 4 CHAPTER 5 SETPOINTS s 5 18 SETPOINTS gt CURRENT D lt gt m ESSAGE See page 5 18 VOLTAGE P gt ESSAGE See page 5 19 lt gt GENERATOR D B ESSAGE S 5 20 x sERIAL gt ka RERR 55 gt END OF PAGE lt gt gt E 5 21 5 SETPOINTS gt BREAKER gt MESSAGE See page 5 22 GENERAL gt n MESSAGE See page 5 22 GENERAL P L coan 8 ESSAGE s 5 22 lt gt cENERAL gt ESSAGE lt gt REMOTE P See page 5 23 gt lt gt n ESSAGE TEST INPUT gt See page 5 23 e ESSAGE lt THERNMAD P See page 5 23 gt cac 8 S 5 24 gt DUAL gt n ESSAGE See page 5 25 SEQUENTIAL gt lt gt m ESSAGE See page 5 26 BREAKER D lt gt ESSAGE See page 5 26 amp TACHOMETER 51 uo ED m ESSAGE S 5 27 gt m gt 8
195. SSIGNABLE INPUT 7 COMMON SWITCH 24Vde 3E SQOCX pr prs prie rh vs ri SINANI WLA ACCESS FRONT PANEL LOCAL PROGRAMMING PORT XXXXXXXXXXXXXXXXXXXXXXXXXXXXXXX BREAKER STATUS COMPUTER AUXILIARY ANALOG 1 0 RS485 RS485 ANALOG OUTPUTS ANALOG INPUTS 1 2 3 44 Yaa 1 2 4 026 B3 B4 A16 A17 A18 A19 A20 22 A23 A24 A25 A26 X X X X X X X X X X X X X X X X X X 808760E6 DWG FIGURE 3 19 Testing the 489 for Dielectric Strength 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 3 19 CHAPTER 3 INSTALLATION 3 20 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL Digital Energy Multilin 489 Generator Management Relay Chapter 4 Interfaces 4 1 Faceplate Interface 4 1 1 Display All messages appear on a 40 character liquid crystal display Messages are in plain English and do not require the aid of an instruction manual for deciphering When the user interface is not being used the display defaults to the user defined status messages Any trip or alarm automatically overrides the default messages and is immediately displayed 4 1 2 LED Indicators There are three groups of LED indicators They are 489 Status Generator Status and Output Status TATI RELAY IN SERVICE B
196. T ACCESS Permitted message appears Setpoints can now be entered Exit the passcode message with the ESCAPE key and program the appropriate setpoints If no keypress occurs for 30 minutes access will be disabled and the passcode must be re entered Removing the setpoint access jumper or setting SETPOINT ACCESS to Restricted also disables setpoint access immediately 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 559 CHAPTER 5 SETPOINTS If a new passcode is required gain setpoint access as follows 5 2 2 Preferences Enter the current valid passcode gt Press MESSAGE DOWN to display the CHANGE PASSCODE message and follow the directions If an invalid passcode is entered the encrypted passcode is viewable by pressing HELP gt Consult GE Multilin with this number if the currently programmed passcode is unknown The passcode can be determined with deciphering software PATH SETPOINTS gt S1 489 SETUP gt V PREFERENCES DEFAULT MESSAGE Range 0 5 to 10 0 s in steps of 1 PREFERENCES gt CYCLE TIME 2 0 s DEFAULT MESSAGE Range 10 to 900 s in steps of 1 E TIMEOUT 300 s PARAMETER AVERAGES Range 1 to 90 min in steps of 1 CALC PERIOD 15 min ESSAGE Celsius WAVEFORM TRIGGER Range 1 to 10096 in steps of 1 POSITION 25 WAVEFORM MEM BUFFER Range 1x64 2x42 3x32 4x35 5x21 8x14 cycles 6x18 7x16 8x14 9x12 10x11 11x10 12x9 13x9 14x8 15x8 16x7 cycles gt
197. T MESSAGES setpoint page This message prompts the user to press ENTER to remove a default message To remove the default message ENTER must be pressed while this message is being displayed e DEFAULT MESSAGE HAS BEEN REMOVED Appears anytime a default message is removed from the default message list e DEFAULT MESSAGES 6 of 20 ARE ASSIGNED Appears anytime the 51 489 SETUP gt V DEFAULT MESSAGES setpoint page is entered notifying the user of the number of default messages assigned e INVALID SERVICE CODE ENTERED Appears if an invalid code is entered in the s12 489 TESTING D gt V FACTORY SERVICE setpoints page e KEY PRESSED HERE IS INVALID Under certain situations certain keys have no function for example any number key while viewing actual values This message appears if a keypress has no current function e DATA CLEARED SUCCESSFULLY Confirms that data is reset in the s1489 SETUP gt V CLEAR DATA setpoints page KEYIS USED TO ADVANCE THE CURSOR Appears immediately to prompt the use of the key for cursor control anytime a setpoint requiring text editing is viewed If the setpoint is not altered for 1 minute this message flashes again e TOP OF PAGE This message will indicate when the top of a page has been reached BOTTOM OF PAGE This message will indicate when the bottom of a page has been reached e TOP OF LIST This message will indicate when the top of subgroup has been reached 489 GENERATOR MANAGEMENT
198. UCTION MANUAL CHAPTER 5 SETPOINTS 5 13 2 Pre Fault Setup PATH SETPOINTS D V S12 489 TESTING gt V PRE FAULT SETUP B PRE PRE FAULT Iphase Range 0 00 to 20 00 x CT in steps of FAULT P OUTPUT 0 00 x CT 0 01 INPUT 4 0 gt PRE FAULT VOLTAGES Range 0 00 to 1 50 x Rated in steps of e PHASE N 1 00 x Rated 0 01 Enter asa phase to neutral quantity essage PRE FAULT CURRENT Range 0 to 359 in steps of 1 gt gt LAGS VOLTAGE 0 ESSAGE PRE FAULT Iphase Range 0 00 to 20 00 x CT in steps of I NEUTRAL 0 00 x CT 0 01 180 phase shift with respect to OUTPUT ESSAGE PRE FAULT CURRENT Range 0 00 to 20 00 x CT in steps of I GROUND 0 00 x CT 0 01 CT is either XXX 1 or 50 0 025 E PRE FAULT VOLTAGE Range 0 0 to 100 0 Vsec in steps of 0 1 m x NEUTRAL 0 Vsec Fundamental value only in secondary units gt PRE FAULT STATOR Range 50 to 250 C in steps of 1 I RTD TEMP 40 ESSAGE PRE FAULT BEARING Range 50 to 250 C in steps of 1 I RTD TEMP 40 gt PRE FAULT OTHER Range 50 to 250 C in steps of 1 i RTD TEMP 40 C ESSAGE PRE FAULT AMBIENT Range 50 to 250 C in steps of 1 RTD TEMP 40 gt PRE FAULT SYSTEM Range 5 0 to 90 0 Hz in steps of 0 1 i FREQUENCY 60 0 Hz e gt PRE FAULT ANALOG Range 0 to 10096 in steps of 1
199. UP gt V CLEAR DATA D V CLEAR GENERATOR INFORMATION setpoint The number of breaker operations will not update if a digital input programmed as Test Input is shorted PATH ACTUAL VALUES V A4 MAINTENANCE D V TIMERS TIMERS P 6 GENERATOR HOURS Range 1 to 1000000 hrs ONLINE Oh The 489 accumulates the total online time for the generator This may be useful for scheduling routine maintenance When this timer exceeds 1000000 it resets to 0 This timer can be cleared using the S1 489 SETUP gt V CLEAR DATA gt V CLEAR GENERATOR INFORMATION setpoint The generator hours online will not update if a digital input programmed as Test Input is shorted 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 6 27 6 6 5 Event Recorder 6 6 1 Event Recorder CHAPTER 6 ACTUAL VALUES PATH ACTUAL VALUES V 5 EVENT RECORDER D V E001 E256 E E001 gt TIME OF EOOL Range hour minutes seconds lt Cause gt 7 00 00 00 0 ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE lt gt gt lt gt lt gt lt gt gt DATE OF 001 GROUP E001 1 TACHOMETER Q gt SEQ CURRENT E001 0 FLA GROUND CURRENT FREQUENCY NEUTRAL VOLT FUND NEUTRAL VOLT 3rd Vab Iab E001 0 0 REAL POWER MW REACTIVE POWER Mvar APPARENT POWER MVA
200. Va for wye Vab for open delta 6 V minimum 10 Hz s DIGITAL INPUTS Inputs 9 opto isolated inputs External switch dry contact 400 Q or open collector NPN transistor from sensor 6 mA sinking from internal 4K pull up at 24 V DC with Vce 4 V DC 489 sensor supply 24 V DC at 20 mA max GROUND CURRENT INPUT CT primary 10 to 10000 A 1A 5 A CTs CT secondary u aa 1A 5 Aor 50 0 025 HGF CTs Conversion range 0 02 to 20 x CT for 1A 5A CTs 0 0 to 100 A primary for 50 0 025 CTs HGF 50 0 025 CT accuracy 0 1Aat lt 10A 1 0 A at gt 10 to 100A 1A 5ACT accuracy at lt 2 x CT 0 5 of 2 x CT at gt 2 x CT 1 of 20 x CT GROUND CT BURDEN Ground CT Input Burden VA 1 0 024 0 024 1 5 5 0 605 0 024 20 9 809 0 024 0 025 0 057 90 7 50 0 025 HGF 0 1A 0 634 90 7 05A 18 9 75 6 GROUND CT CURRENT WITHSTAND SECONDARY Ground CT Withstand Time 1 sec 2 sec continuo us 1A 5A 80xCT 40 x CT 3xCT 50 0 025 HGF N A N A 150 mA NEUTRAL VOLTAGE INPUT VT ratio 1 00 to 240 00 1 in steps of 0 01 VT secondary 100 V full scale Conversion range 0 005 to 1 00 x Full Scale ACCUFQGV stt deti Fundamental 0 5 of Full Scale 3rd Harmonic at gt 3V secondary 5 of reading 3rd Harmonic at 3V secondary 0 1596 of full scale 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 2 INTRODUCTION 2 2 2 Outputs
201. Volts ESSAGE FREQUENCY Range N A I 0 00 Hz ESSAGE POWER FACTOR Range N A I 0 00 escage gt REAL POWER Range N A I 0 MW REACTIVE POWER Range N A I 0 Mvar ESSAGE DATE 01 01 1995 Range N A I TIME 12 00 00 GE MULTILIN Range N A 489 GENERATOR RELAY The 489 displays default messages after a period of keypad inactivity Up to 20 default messages can be selected for display If more than one message is chosen they will automatically scroll at a rate determined by the S1 489 SETUP gt V PREFERENCES gt DEFAULT MESSAGE CYCLE TIME setpoint Any actual value can be selected for display In addition up to 5 user programmable messages can be created and displayed with the message 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS scratchpad For example the relay could be set to alternately scan a generator identification message the current in each phase and the hottest stator RTD Currently selected default messages can be viewed in DEFAULT MESSAGES subgroup Default messages can be added to the end of the default message list as follows gt Enter the correct passcode at 51 489 SETUP gt PASSCODE gt ENTER PASSCODE FOR ACCESS to allow setpoint entry unless it has already been entered or is 0 defeating the passcode security feature gt Select the message to be add to the default message list using the MESSAGE keys The selected message can be any actual value or messa
202. WER MEASUREMENT CONVENTIONS 5 60 POWER MEASUREMENT TEST e Reed UR TC ERR UA 7 13 POWER METERING uuu uu uu eene oer xeu unt 2 13 6 18 dedz sce 2 13 3 11 POWER SYSTEM uuu AM Ra eth te ttg 5 19 5 20 PRE FAULET SETUP tee Sus 5 101 PREFERENCES sak 5 10 RRESSURE rer mau m ee t ME 3 14 PRODUCT IDENTIFICATION c ht e tt rentrer Ri c ener 3 2 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL INDEX PRODUCTION TESTS ie oe 2 14 PROTECTION FEATURES igs uuu ancien u ete 2 3 PROXIMITY PROBE Zuna L E aa cases 3 14 PULSE OUTPUT erue tee tte re there eren iei 2 8 5 94 R REACTIVE POWER tete HU teen ulcera dete Roo die LIA a aed 5 61 REACTIVE POWER TEST rtt aaa te en den t gie dn 7 13 REAL TIME CEQCHI 2 dy t added 5 13 6 15 RELAY ASSIGNMENT PRACTICES u ect d rtt d edi eda tube 5 7 RELAY RESET MODE tie Re cere dedisti te te Moret te o eens 5 28 REMOTE RESET irte tet rs etd etant erste cae e veg ttn 5 23 RESETTING THE 489 edet ete teste bnt tesa eee tabe 5 28 RESIDUAL GROUND CONNECTION a nenne 3 12 REVERSE POWER reete e te net albe i b e nep eere e eit 5 62 REVISION HISTORY een ee i ee c A 27 R
203. Warranty General Electric Multilin Inc GE Multilin warrants each relay it manufactures to be free from defects in material and workmanship under normal use and service for a period of 24 months from date of shipment from factory In the event of a failure covered by warranty GE Multilin will undertake to repair or replace the relay providing the warrantor determined that it is defective and it is returned with all transportation charges prepaid to an authorized service centre or the factory Repairs or replacement under warranty will be made without charge Warranty shall not apply to any relay which has been subject to misuse negligence accident incorrect installation or use not in accordance with instructions nor any unit that has been altered outside a GE Multilin authorized factory outlet GE Multilin is not liable for special indirect or consequential damages or for loss of profit or for expenses sustained as a result of a relay malfunction incorrect application or adjustment For complete text of Warranty including limitations and disclaimers refer to GE Multilin Standard Conditions of Sale A 32 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL INDEX Index Numerics O TmMA ANALOG INPUT ir eed tte eU teet tiec pes uide 3 15 4 20mA ANALEOG INTPU T iiir eee ed te eter ed ee teet 3 15 500 025 CT m 3 12 A ACCESS SWITCH sarie 5 21 ACCESSORIES a ee qu eee eee eee 2 5 ACTUAL VALUES ausit To
204. aa cientes tecto cie t Qan e dcc REACTIVE POWER ACCURACY sse ttes tret titt VOLTAGE PHASE REVERSAL ACCURACY wiesssessssesssssssssesssseessssesssssesseceessessssersnsesseseenseeeeses 7 14 INJECTION TEST SETUP 2 7 15 GE MULTILIN 50 0 025 GROUND ACCURACY we 7 15 NEUTRAL VOLTAGE 3RD HARMONIC ACCURACY 227 16 PHASE DIFFERENTIAL TRIP ACCURACY ccssssssssssssscsssssessessesssssssssessecsscsscsscssssseessesaneeneens 7 16 INJECTION TEST SETUP 3ES J 7 19 VOLTAGE RESTRAINED OVERCURRENT ACCURACY I aasan 7 20 DISTANCE ELEMENT ACCURACY asas 7 21 APPENDIX SIATON GROUND FAULT u Uu Sede n Mea a NEUTRAL OVERVOLTAGE ELEMENT GROUND OVERCURRENT ELEMENT GROUND DIRECTIONAL ELEMENT tete aaa a asua t b epatis THIRD HARMONIC VOLTAGE ELEMENT ttti A 6 REFERENCES aot caedi t er ce pecu tl bn dece ER ER A 7 STATOR DIFFERENTIAL PROTECTION SPECIAL APPLICATION A 8 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL TOC V TABLE OF CONTENTS BACKGROUND C STATOR DIFFERENTIAL LOGIC CURRENT TRANSFORMER S u uu u GROUND FAULT CTS FOR 50 0 025 A CT eerte ttes A 11
205. access is automatically disabled on an interface if no activity is detected for thirty minutes The EnerVista 489 Setup software incorporates a facility for programming the relay passcode as well as enabling and disabling setpoint access For example when an attempt is made to modify a setpoint but access is restricted the software will prompt the user to enter the passcode and send it to the relay before the setpoint is actually written to the relay If a SCADA system is used for relay programming it is the programmer s responsibility to incorporate appropriate security for the application 1 3 2 The HELP Key Pressing the HELP key displays context sensitive information about setpoints such as the range of values and the method of changing the setpoint Help messages will automatically scroll through all messages currently appropriate 13 3 Numerical Setpoints Each numerical setpoint has its own minimum maximum and step value These parameters define the acceptable setpoint value range Two methods of editing and storing a numerical setpoint value are available The first method uses the 489 numeric keypad in the same way as any electronic calculator number is entered one digit at a time with the 0 to 9 and decimal keys The left most digit is entered first and the right most digit is entered last Pressing ESCAPE before the ENTER key returns the original value to the display The second method uses the VALUE key to increment the
206. ag Icn 5 AZ270 lag 4 Activated 8 Not Activated 18 13 to 23 4 8 N A 35 40 to 30 4 8 N A 52 H57 to 47 4 4 52 47 to 57 4 4 7 3 4 Voltage Phase Reversal Accuracy The relay can detect voltage phase rotation and protect against phase reversal To test the phase reversal element perform the following steps gt In the 52 SYSTEM SETUP gt V VOLTAGE SENSING menu set VT CONNECTION TYPE Wye gt In the S2 SYSTEM SETUP D V GEN PARAMETERS menu set 7 14 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 7 TESTING 72 9 7 3 6 GENERATOR PHASE SEQUENCE gt In the 63 DIGITAL INPUTS gt BREAKER STATUS men u set BREAKER STATUS Breaker Auxiliary a gt In the 56 VOLTAGE ELEMENTS gt V PHASE REVERSAL menu set PHASE REVERSAL TRIP Unlatched ASSIGN TRIP RELAYS 1 gt Apply voltages as per the table below Verify the operation on voltage phase reversal Applied Voltage Expected Result Observed Result Va 120 VZ0 Vb 120VZ120 lag No Trip Vc 120 VZ240 lag 120VZ0 Vb 120 VZ240 lag Phase Reversal Trip Vc 120 VZ120 lag Injection Test Setup 2 Set up the 489 device as follows for the GE Multilin HGF Ground Accuracy Test Neutral Voltage 3rd Harmonic Accuracy Test and the Phase Differential Trip Test 3 PHASE VARIABLE AC TEST SET
207. aga use en raa 6 4 5 13 JU M NP A 30 EU Declaration of 2 222 A 30 EVENT RECORD COUSE Of I II E M 6 29 EVENT RECORDER cit tet e e er e ce 5 17 5 23 6 28 F FACTORY SERVICE 5 104 FAUCET SEPUR SS u saan m 5 102 FEATURES 2 2 2 3 2 10 FIEED BREAKER DISCREPANCY uuu 2 11 upgrading via EnerVista 489 setup software 4 30 FLASH MESSAGES eet tee eit ene nt tate Db ee tede eus 6 33 FCEXCURVE notet a E 5 31 FLOW a a ou teas 3 14 FREQUENCY TRACKING ZR u eee 2 6 FRONT PANEL EE E A 1 3 EES E EN OEA E ee REM LR 2 13 G GENERAL COUNTERS 2 2 22 nnti asa pte ste td Dee 6 27 enc MIDI 2 12 5 22 GENERATOR INFORMATION siisii tne Utt ite chu tete iz tae pec tdt 5 17 GENERATOR LOAD Peter ta tees edt a kuwa 6 22 GENERATOR PARAMETERS eoe dette ete 5 19 GENERATOR STAT UIS oerte dee Per eda deo dod 6 4 GETTING STARTED cete ese te eee Ue hr espe prota ebbe dee etus 1 1 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL INDEX GROUND CT LT 2 6
208. agement Relay 4 R J Marttila Design Principles of a New Generator Stator Ground Relay for 100 Coverage of the Stator Winding IEEE Transactions on Power Delivery Vol PWRD 1 No 4 October 1986 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL A 7 CHAPTER A APPENDIX A 2 Stator Differential Protection Special Application A 8 A 2 1 Background The 489 relay is applied in a dual breaker arrangement as shown in the figure below In this configuration one breaker is closed at a time eliminating a danger of through fault conditions However the customer prefers not to sum up the two breaker currents to obtain effectively the terminal side current of the generator nor to install an extra CT at the generator to measure the terminal side current explicitly Instead the customer applies two 489 relays each spanning its differential zone between the neutral side CT of the generator and the CT at the corresponding breaker In this application when a breaker is closed the other opposite relay would measure the neutral side current without the matching terminal side current as the latter flows via the other closed breaker and it not visible to the opposite relay Block 87 when CB closed FIGURE A 6 Considered application of two 489s protecting a dual breaker generator configura tion When both breakers are opened both relays be operational with the differential function enabled The application is based on b
209. an impedance element When the impedance falls within the impedance circle for the specified delay time a trip will occur if it is enabled Circles 1 and or 2 can be tuned to a particular system The larger circle diameter should be set to the synchronous reactance of the generator and the circle offset to the generator transient reactance 4 2 Typically the smaller circle if used is set to minimum time with a diameter set to 0 7 and an offset of x 4 2 This feature is blocked if voltage supervision is enabled and the generator voltage is above the VOLTAGE LEVEL setpoint The trip feature is supervised by minimum current of 0 05 x CT Note that the Loss of Excitation element will be blocked if there is a VT fuse failure or if the generator is offline Also it uses output CT inputs The secondary phase phase loss of excitation impedance is defined as z A 7g m loe loe EQ 5 26 lA where Zoe secondary phase to phase loss of excitation impedance Secondary impedance phasor magnitude and angle 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 5 55 CHAPTER 5 SETPOINTS All relay quantities are in terms of secondary impedances The formula to convert primary impedance quantities to secondary impedance quantities is provided below Zari x CT Ratio p y 2 secondary E Ratio EQ 5 27 Where Zprimary Primary ohms impedance CT Ratio programmed CT ratio if CT ratio is 1200 5 use a va
210. ans amp dC Input Input Resistor _ Isolating Transformer Neutral Ground ON O C Element Element Grounding A GS Breaker Coni Status Status k 808734A1 CDR FIGURE 5 Ground Element Conceptuql Arrangement The operating principle of this element is quite simple for internal ground faults the two signals will be 180 out of phase and for external ground faults the two signals will be in phase This simple principle allows the element to be set with a high sensitivity not normally possible with an overcurrent element The current pickup level of the element can be adjusted down to 0 05 x CT primary allowing an operate level of 0 25 A primary if the 50 0 025 ground CT is used for the core balance The minimum level of V eutraj at which the element will operate is determined by hardware limitations and is internally set at 2 0 V Because this element is directional it does not need to be coordinated with downstream protections and a short operating time can be used Definite time delays are suitable for this element 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL A 5 6 CHAPTER A APPENDIX Applications with generators operated in parallel and grounded through a common impedance require special considerations If only one gen
211. atched Alarm Not Enabled Inactive Timing Out Active Alarm Latched Alarm Not Enabled Inactive Timing Out Active Alarm Latched Alarm The various alarm pickup actual values reflect the Input Name as programmed in the first line of the message The various digital and analog input functions are shown only if the function has been assigned as an input The alarm pickup messages may be very useful during testing They will indicate if a alarm feature has been enabled if it is inactive not picked up timing out picked up and timing active alarm still picked up timed out and causing an alarm or latched alarm no longer picked up but had timed out and caused a alarm that is latched These values may also be particularly useful as data transmitted to a master device for monitoring 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 6 ACTUAL VALUES 6 2 7 Digital Inputs PATH ACTUAL VALUES gt A1 STATUS V DIGITAL INPUTS DIGITAL D ACCESS Range Open Shorted INPUTS SWITCH STATE Open Range Open Shorted esce gt STATUS ge Op SWITCH STATE Open Esci ASSIGNABLE DIGITAL Range Open Shorted INPUT1 STATE Open lt ASSIGNABLE DIGITAL Range Open Shorted x INPUT2 STATE Open ASSIGNABLE DIGITAL Range Open Shorted INPUT3 STATE Open lt ASSIGNABLE DIGITAL Range Open Shorted INPUT4 STATE Open ASSIGNABLE DIGITAL Ran
212. ator and rotor thermal capacity used The values for ESTIMATED TRIP TIME ON OVERLOAD will appear whenever the 489 thermal model picks up on the overload curve 6 4 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 6 ACTUAL VALUES 6 2 3 Last Trip Data PATH ACTUAL VALUES gt A1 STATUS V LAST TRIP DATA LAST TRIP P CAUSE OF LAST TRIP Range see Note below DATA No Trip to Date lt OF LAST TRIP Range hour min sec 09 00 00 00 DATE OF LAST TRIP Range Month Day Year Jan 01 1995 TACHOMETER Range 0 to 5600 RPM Seen only if ESSAGE lt gt PRETRIP 3600 RPM Tachometer is assigned a 0 B 0 Range 0 to 999999 A Represents ESSAGE 0 A PreTrip current measured from output CTs Seen only if a trip has occurred 0 b 0 Range 0 to 999999 A Represents ESSAGE e 0 A PreTrip differential current Seen only if differential element is enabled I SEQ CURRENT Range 0 to 200096 FLA Seen only if ESSAGE 5 PRETRIP 0 FLA there has been a trip o GROUND CURRENT Range 0 00 to 20000000 A Not seen if E Z PRETRIP 0 00 A GROUND CT is None lt gt GROUND CURRENT Range 0 0 to 5000 0 A gt PRETRIP 0 00 Amps _ vab 0 Vbc 0 Range 0 to 50000 V Not seen if VT ESSAGE gt 0 V PreTrip CONNECTION is None ERR FREQUENCY Range 0 00 to 90 00 Hz Not seen if VT Z PRETRIP
213. be entered If the correct passcode has been lost or forgotten contact the factory with the encrypted access code All passcode features may be found in the 51 489 SETUP gt PASSCODE setpoints menu INVALID PASSCODE ENTERED This flash message appears if an invalid passcode is entered for the passcode security feature NEW PASSCODE HAS BEEN ACCEPTED This message will appear as an acknowledge that the new passcode has been accepted when changing the passcode for the passcode security feature PASSCODE SECURITY NOT ENABLED ENTER The passcode security feature is disabled whenever the passcode is zero factory default Any attempts to enter a passcode when the feature is disabled results in this flash message prompting the user to enter 0 as the passcode When this has been done the feature may be enabled by entering a non zero passcode ENTER A NEW PASSCODE FOR ACCESS The passcode security feature is disabled if the passcode is zero If the CHANGE PASSCODE SETPOINT is entered as yes this flash message appears prompting the user to enter a non zero passcode and enable the passcode security feature SETPOINT ACCESS IS NOW PERMITTED Any time the passcode security feature is enabled and a valid passcode is entered this flash message appears to notify that setpoints may now be altered and stored SETPOINT ACCESS IS NOW RESTRICTED If the passcode security feature is enabled and a valid passcode entered this message appears when t
214. ble digital inputs The alternate setpoints group can be selected by setting the S3 DIGITAL INPUTS gt V DUAL SETPOINTS gt V ACTIVATE SETPOINT GROUP setpoint to Group 2 RESET POSSIBLE A trip or latched alarm may be reset Pressing the RESET key clears the trip alarm MESSAGE Under normal conditions the default messages selected during setpoint programming are displayed If any alarm or trip condition is generated a diagnostic message overrides the displayed message and this indicator flashes If there is more than one condition present MESSAGE Y can be used to scroll through the messages Pressing any other key return to the normally displayed messages While viewing normally displayed messages the Message LED continues to flash if any diagnostic message is active Toreturn to the diagnostic messages from the normally displayed messages press the MENU key until the following message is displayed TARGET MESSAGES w Now press the MESSAGE P key followed by the message Y key to scroll through the messages Note that diagnostic messages for alarms disappear with the condition while diagnostic messages for trips remain until cleared by areset Generator Status LED Indicators BREAKER OPEN Uses the breaker status input signal to indicate that the breaker is open and the generator is offline BREAKER CLOSED Uses the breaker status input signal to indicate that the breaker is closed and the generator is online
215. bled ANALOG OUTPUT 1 FORCED VALUE 0 enter repeat for Outputs 2 to 4 gt Verify the ammeter readings as well as the measured analog input readings gt View the measured values in the A2 METERING DATA gt V ANALOG INPUTS menu Analog Expected Measured Ammeter Expected Measured Analog Input Output Force Ammeter Reading mA Analog Input Reading units Value Reading 1 2 3 4 Reading 1 2 3 4 096 0 mA units 2596 0 25 mA 250 units 5096 0 50 mA 500 units 7596 0 75 mA 750 units 10096 1 00 mA 1000 units 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 7 TESTING 7 2 9 Output Relays To verify the functionality of the output relays perform the following steps Using the setpoint 812 TESTING gt V TEST OUTPUT RELAYS gt V FORCE OPERATION OF RELAYS 1 Trip gt Select and store values as per the table below verifying operation Force Expected Measurement 4 for short Actual Measurement 4 for short paar 1 2 3 4 5 6 1 2 3 4 5 6 no nc nc no nc no nc nc nc no ne 1 Trip 4 4 4 4 2 Auxiliary 4 4 4 4 4 3 Auxiliary 4 4 4 4 4 4 Auxiliary 4 4 4 4 4 5 Alarm 4 4 4 4 6 Service 4 4 4 All Relays 4 4 4 4 4 No Relays 4 4 4 4 4 4 The 6 Service relay is failsafe or energized no
216. cal estimate k 239 conservative estimate EQ 5 33 LR LR where is the per unit locked rotor current Machine Cooling The 489 thermal capacity used value is reduced exponentially when the motor current is below the OVERLOAD PICKUP setpoint This reduction simulates machine cooling The cooling time constants should be entered for both stopped and running cases the 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 5 85 5 86 CHAPTER 5 SETPOINTS generator is assumed to be running if current is measured or the generator is online A machine with a stopped rotor normally cools significantly slower than one with a turning rotor Machine cooling is calculated using the following formulae t t TC seg TCused_start TC used_end TCused_end EQ 5 34 I hot TCused end se n 1 zold x 100 EQ 5 35 where TCuseg thermal capacity used TCused start TCyseg value caused by overload condition TCused end TCyseq Value dictated by the hot cold safe stall ratio when the machine is running 0 when the machine is stopped t time in minutes t Cool Time Constant running or stopped leg equivalent heating current overload_pickup overload pickup setpoint as a multiple of FLA hot cold hot cold safe stall ratio
217. citation analog input e 81 overfrequency underfrequency e 86 electrical lockout e 87G percentage differential e e e e generator running hours alarm FIGURE 2 1 Single Line Diagram 2 CHAPTER 2 INTRODUCTION 489 PUAN Supervision Output relays Output relays 5232 4 RS485 gt 5 lt Yy Analog outputs inputs 808783E8 CDR Fault diagnostics are provided through pretrip data event record waveform capture and statistics Prior to issuing a trip the 489 takes a snapshot of the measured parameters and stores them in a record with the cause of the trip This pre trip data may be viewed using the NEXT key before the trip is reset or by accessing the last trip data in actual values page 1 The event recorder stores a maximum of 256 time and date stamped events including the pre trip data Every time a trip occurs the 489 stores a 16 cycle trace for all measured AC quantities Trip counters record the number of occurrences of each type of trip Minimum and maximum values for RTDs and analog inputs are also recorded These features allow the operator to pinpoint a problem quickly and with certainty A complete list protection features is shown below 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 2 INTRODUCTION Table 2 1 Trip and Alarm Protection Features Trip Protection Alarm Protection Seven 7
218. code specifies a 489 Generator Management Relay with 1 A CT inputs 20 to 60 V DC or 20 to 48 V AC control voltage 4 to 20 mA analog outputs and an enhanced display 2 1 3 Other Accessories Additional 489 accessories are listed below EnerVista 489 Setup software no charge software provided with the 489 SR 19 1 PANEL single cutout for 19 panel SR 19 2 PANEL double cutout for 19 panel SCI MODULE RS232 to RS485 converter box designed for harsh industrial environments Phase CT 50 75 100 150 200 250 300 350 400 500 600 750 1000 phase CT primaries HGF3 HGF5 HGF8 For sensitive ground detection on high resistance grounded systems 489 1 3 8 inch Collar For shallow switchgear reduces the depth of the relay by 1 3 8 inches 489 3 inch Collar For shallow switchgear reduces the depth of the relay by 3 inches 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 2 5 2 2 2 6 Specifications 2 2 Inputs CHAPTER 2 INTRODUCTION ANALOG CURRENT INPUTS NAPUS estetico eter 0 to 1 mA 0 to 20 mA 4 to 20mA setpoint Input impedance 226 Q 10 Conversion range O to 20 mA AGGUFOCV datei e 1 of full scale Passive Analog input supply 24 V DC at 100 mA max Sampling Interval 50 ms ANALOG INPUTS FREQUENCY TRACKING Frequency tracking
219. communication link are not uncommon For this reason surge protection devices are internally installed across all RS485 terminals Internally an isolated power supply with an optocoupled data interface is used to prevent noise coupling B To ensure that all devices in a daisy chain are at the same potential it is imperative that the common terminals of each RS485 port are tied together grounded only once at the master Failure so may result intermittent or failed communications The source computer PLC SCADA system should have similar transient protection devices installed either internally or externally to ensure maximum reliability Ground the shield at one point only as shown below to avoid ground loops Correct polarity is also essential All 489s must be wired with all terminals connected together and all terminals connected together Each relay must be daisy chained to the next one Avoid star or stub connected configurations The last device at each end of the daisy chain should be terminated with a 120 Q W resistor in series with a 1 nF capacitor across the and terminals Observing these guidelines will result in a reliable communication system that is immune to system transients 120 Ohm Inf TERMINATING TERMINATING RESISTOR CAPACITOR na A wri com Xu D26 27 025 026 027 025 PERS
220. create or edit relay setpoint files for later download to communicating relays Directly modifying relay setpoints while connected to communicating relay then saving the setpoints when complete Creating editing setpoint files while connected to a communicating relay then saving them to the relay when complete Settings files are organized on the basis of file names assigned by the user A settings file contains data pertaining to the following types of relay settings Device Definition Product Setup System Setup Digital Inputs Output Relays Voltage Elements Power Elements RTD Temperature Thermal Model Monitoring Functions Analog Inputs and Outputs Relay Testing User Memory Map Setting Tool Factory default values are supplied and can be restored after any changes The EnerVista 489 Setup display relay setpoints with the same hierarchy as the front panel display For specific details on setpoints refer to Chapter 5 Downloading and Saving Setpoints Files Setpoints must be saved to a file on the local PC before performing any firmware upgrades Saving setpoints is also highly recommended before making any setpoint changes or creating new setpoint files The EnerVista 489 Setup window setpoint files are accessed in the Setpoints List control bar window or the Files window Use the following procedure to download and save setpoint files to a local PC gt Ensure that the site and corresponding devicels have been
221. curve test to ensure that the thermal capacity used is zero Failure to do so will result in shorter trip times Inject the current of the proper amplitude to obtain the values as shown and verify the trip times Motor load may be viewed in the 2 METERING DATA gt CURRENT METERING menu The thermal capacity used and estimated time to trip may be viewed in the A1 STATUS V GENERATOR STATUS menu Average Phase Pickup Level Expected Tolerance Range Measured Time Current Time to Trip to Trip sec Displayed 1050A 1 05 x FLA never n a 1200A 1 20 x FLA 795 44 s 779 53 to 811 35 s 1750A 1 75 x FLA 169 66 s 166 27 to 173 05 s 3000 A 3 00 x FLA 43 73 5 42 86 to 44 60 s 6000 A 6 00 x FLA 9 995 9 79 to 10 19 s 10000 A 10 00 x FLA 5 555 5 44 to 5 66 s FLA Generator Rated MVA EQ 7 4 B x Generator Phase to Phase Voltage 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 7 TESTING 7 3 2 Power Measurement Test The specification for reactive and apparent power is 1 of 3 x 2 x CT x VTrotio xX VTiull scale At lgyg lt 2 x CT Perform the steps below to verify accuracy gt In the S2 SYSTEM SETUP gt CURRENT SENSING menu set PHASE CT PRIMARY 1000 gt In the S2 SYSTEM SETUP gt V VOLTAGE SENSING menu set VT CONNECTION TYPE Wye VOLTAGE TRANSFORMER RATIO 10 00 1 gt Inject current and apply voltage as per the table below V Verif
222. cy at log gt 2 x gt 15 3 x 20x CT x VT REACTIVE POWER Block from online Oto 5000 s in steps of 1 Pickup level 0 02 to 1 50 x rated Mvar positive and negative Time delay 0 2 to 120 0 s in steps of 0 1 Pickup accuracy see power metering Timing accuracy 100ms or 0 5 of total time Elements Trip and Alarm REVERSE POWER Block from online Oto 5000 s in steps of 1 Pickup level 0 02 to 0 99 x rated MW Time delay 0 2 to 120 0 s in steps of 0 1 Pickup accuracy see power metering Timing accuracy 100 ms or 0 5 of total time Elements Trip and Alarm TRIP COIL SUPERVISION Applicable voltage 20 to 300 V DC AC Trickle current 2to5mA 2 2 6 Power Supply WARNING WARNING CONTROL POWER Options LO HI specify with order LO range 20 to 60 V DC 20 to 48 V AC at 48 to 62 Hz HI range 90 to 500 V DC 70to 265 V AC at 48 to 62 Hz Power 45 VA max 25 VA typical Total loss of voltage ride through time 096 control power 16 7 ms It is recommended that the 489 be powered up at least once per year to prevent deterioration of electrolytic capacitors in the power supply FUSE Current rating 25 5x20mm HRC SLO BLO Littelfuse Model 215 025 An external fuse must be used if the supply voltage exceeds 250 V 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 2 13 2 27 Communications COMMUNICATIONS PORTS 2 2 8 Testing A WARNING RS232 port RS485
223. d I TRIP Off ESSAGE ASSIGN TRIP Range Any combination of Relays 1 to I amp RELAYS 1 4 1 4 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS MESSAGE TACHOMETER TRIP Range 101 to 175 in steps of 1 SPEED 110 Rated I TACHOMETER TRIP Range 1 to 250 s in steps of 1 DELAY 15 of assignable digital inputs 4 to 7 may be assigned the tachometer function to measure mechanical speed The time between each input closure is measured and converted to an RPM value based on one closure per revolution If an overspeed trip or alarm is enabled and the measured RPM exceeds the threshold setpoint for the time specified by the delay a trip or alarm will occur The RPM value can be viewed with the a2 METERING DATA V SPEED gt V TACHOMETER actual value For example an inductive proximity probe or hall effect gear tooth sensor may be used to sense the key on the generator The probe could be powered from the 24V from the digital input power supply The NPN transistor output could be taken to one of the assignable digital inputs assigned to the tachometer function 5 4 11 Waveform Capture PATH SETPOINTS D V S3 DIGITAL INPUTS gt V WAVEFORM CAPTURE m ASSIGN DIGITAL Range None Input 1 to Input 7 WAVEFORM gt INPUT None If an input is assigned to the tachometer function it may not be used here This feature may be used to trigger the waveform capture from an external contact
224. d Dependent STANDARD OVERLOAD Range 1 to 15 in steps of 1 See Note ESSAGE gt below x CURVE NUMBER 4 ESSAGE lt TO TRIP AT Range 0 5 to 99999 9 in steps of 0 1 I 1 01 x FLA 17414 5 See Notes below 1 ESSAGE TIME TO TRIP AT Range 0 5 to 99999 9 in steps of 0 1 I amp 20 0 x FLA 5 6 s See Notes below ESSAGE MINIMUM ALLOWABLE Range 70 to 95 in steps of 1 See I VOLTAGE 80 Notes below ESSAGE STALL CURRENT MIN Range 2 00 to 15 00 x FLA in steps of I VOLTAGE 4 80 x FLA 0 01 See Notes below ESSAGE SAFE STALL TIME Range 0 5 to 999 9 in steps of 0 1 See I MIN VOLTAGE 20 0 s Notes below ESSAGE lt ACCEL INTERSECT Range 2 00 to STALL CURRENT MIN MIN VOLT 3 80 x FLA VOLTAGE in steps of 0 01 See Notes below ESSAGE STALL CURRENT 100 Range 2 00 to 15 00 x FLA in steps of VOLTAGE 6 00 x FLA 0 01 See Note below SAFE STALL TIME G Range 0 5 to 999 9 in steps of 0 1 See Notes below 100 VOLTAGE 10 0 s ACCEL INTERSECT Range 2 00 to STALL CURRENT 100 100 VOLT 5 00 x FLA VOLTAGE in steps of 0 01 See Notes below The RTD BIAS MINIMUM RTD BIAS CENTER RTD BIAS MAXIMUM setpoints is are seen only if ENABLE RTD BIASING is set to Yes The STANDARD OVERLOAD CURVE NUMBER is seen only if SELECT CURVE STYLE is set to Standard If the SELECT CURVE STYLE is set to Voltage Dependent all setpoints shown aft
225. d analog input values should be 10 units 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 7 9 CHAPTER 7 TESTING gt Force the analog outputs using the following setpoints from the 512 TESTING gt V TEST ANALOG OUTPUT menu FORCE ANALOG OUTPUTS FUNCTION Enabled ANALOG OUTPUT 1 FORCED VALUE 0 enter repeat for Outputs 2 to 4 gt Verify the ammeter readings and the measured analog input readings For the purposes of testing the analog input is fed in from the analog output see Secondary Current Injection Testing on page 7 3 gt View the measured values in the A2 METERING DATA gt ANALOG INPUTS menu Analog Expected Measured Ammeter Expected Measured Analog Input Output Ammeter Reading ma Analog Input Reading units Force Value Reading 1 2 3 4 Reading 1 2 3 4 0 4mA 0 units 25 8mA 250 units 5096 12 mA 500 units 7596 16 mA 750 units 10096 20 mA 1000 units Oto 1 mA Analog Inputs gt In the s11 ANALOG VO D V ANALOG INPUT 1 menu set ANALOG INPUT 1 0 1 mA ANALOG INPUT 1 MINIMUM 0 ANALOG INPUT 1 MAXIMUM 1000 repeat for Analog Inputs 2 to 4 Analog output values should be 0 01 mA on the ammeter Measured analog input values should be 10 units Force the analog outputs using the following setpoints in the s12 TESTING gt V TEST ANALOG OUTPUT menu FORCE ANALOG OUTPUTS FUNCTION Ena
226. d that an isolation transformer be used between the relay and the grounding impedance to reduce common mode voltage problems particularly on installations requiring long leads between the relay and the grounding impedance When several small generators are operated in parallel with a single step up transformer all generators may be grounded through the same impedance the impedance normally consists of a distribution transformer and a properly sized resistor It is possible that only one generator is grounded while the others have a floating neutral point when connected to the power grid see the figure below This operating mode is often adopted to prevent circulation of third harmonic currents through the generators if the installation is such that all the star points would end up connected together ahead of the common grounding impedance if each generator has its own grounding impedance the magnitude of the 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER A APPENDIX circulating third harmonic current will be quite small With a common ground point the same Signal is brought to all the relays but only the one which is grounded should have the neutral overvoltage element in service For these cases the neutral overvoltage element has been provided with a supervising signal obtained from an auxiliary contact off the grounding switch When the grounding switch is opened the element is disabled The grounding switch au
227. d the field has been applied Therefore this feature can be blocked until the machine is online and adequate time has expired during which the field had been applied From that point forward the reactive power trip and alarm elements will be active A value of zero for the block time indicates that the reactive power protection is active as soon as both current and voltage are measured regardless of whether the generator is online or offline Once the 3 phase total reactive power exceeds the positive or negative level for the specified delay a trip or alarm will occur indicating a positive or negative Mvar condition The level is programmed in per unit of generator rated Mvar calculated from the rated MVA and rated power factor The reactive power elements can be used to detect loss of excitation If the VT type is selected as None or VT fuse loss is detected the reactive power protection is disabled Rated Mvars for the system can be calculated as follows 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 5 61 CHAPTER 5 SETPOINTS For example given Rated MVA 100 MVA and Rated Power Factor 0 85 we have Rated Mvars Rated MVA x sin cos Rated PF 100 x sin cos 10 85 EQ 5 28 52 67 Mvars 5 8 5 Reverse Power PATH SETPOINTS D gt V S7 POWER ELEMENTS D V REVERSE POWER 1 REVERSE gt BLOCK REVERSE POWER Range 0 to 5000 s in steps of 1 POWER FROM ONLINE 1 s NOTE REVERSE POWER Range Off Latched Unlatched
228. ding cable should be used As a minimum 96 strands of number 34 AWG should be used Belden catalog number 8660 is suitable 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 3 INSTALLATION Ensure applied control voltage and rated voltage on drawout case terminal label match For example the power supply will work with any DC voltage from 90 to 300 V or AC voltage from 70 to 265 V The internal fuse may blow if the applied voltage exceeds this range Extensive filtering and transient protection are built into the 489 to ensure proper operation in harsh industrial environments Transient energy must be conducted back to the source through the filter ground terminal A separate safety ground terminal is provided for hi pot testing e CONTROL POWER HEAVY COPPER CONDUCTOR OR BRAIDED WIRE SWITCHGEAR GROUND BUS E 11 12 GROUND N GROUND SAFETY FILTER CONTROL POWER FIGURE 3 12 Control Power Connection 3 2 4 Current Inputs Phase Current The 489 has six phase current transformer inputs three output side and three neutral end each with an isolating transformer There are no internal ground connections on the CT inputs Each phase CT circuit is shorted by automatic mechanisms on the 489 case if the unit is withdrawn The phase CTs should be chosen such that the FLA is no less than 50 of the rated phase CT primary Ideally
229. display defaults to that message All trip features are automatically logged and date and time stamped as they occur In addition all trips are counted and logged as statistics such that any long term trends may be identified 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS Note that a lockout time will occur due to overload trip see Model Setup on page 5 71 for additional details Alarms A 489 alarm feature may be assigned to operate any combination of four output relays 2 Auxiliary 3 Auxiliary 4 Auxiliary and 5 Alarm When an alarm becomes active the appropriate LED indicator on the 489 faceplate will illuminate when an output relay s has operated Each alarm feature may be programmed as latched or unlatched Once a latched alarm feature becomes active the reset key must be pressed to reset that alarm If the condition that has caused the alarm is still present for example hot RTD the Alarm relay s will not reset until the condition is no longer present If on the other hand an unlatched alarm feature becomes active that alarm will reset itself and associated output relay s as soon as the condition that caused the alarm ceases As soon as an alarm occurs the alarms messages are updated to reflect the alarm and the 489 display defaults to that message Since it may not be desirable to log all alarms as events each alarm feature may be programmed to log as an event or not If an alarm is programmed
230. displayed value by the step value up to maximum allowed value Likewise the VALUE W key decrements the displayed value by the step value down to a minimum value For example gt Select the S1 489 SETUP gt V PREFERENCES gt V DEFAULT MESSAGE TIMEOUT setpoint message DEFAULT MESSAGE TIMEOUT 300 s Press the 1 2 and 0 keys The display message will change as shown DEFAULT MESSAGE TIMEOUT 120 s Until the ENTER key is pressed editing changes are not registered by the relay Therefore 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 1 GETTING STARTED gt Press the ENTER key to store the new value in memory The following message will momentarily appear as confirmation of the storing process NEW SETPOINT HAS BEEN STORED 134 Enumeration Setpoints The example shown in the following figures illustrates the keypress sequences required to enter system parameters such as the phase CT primary rating ground CT primary rating bus VT connection type secondary voltage and VT ratio The following values will be entered Phase CT primary rating 600 A Ground CT type 1 A secondary Ground CT ratio 200 1 Neutral Voltage Transformer None Voltage Transformer Connection Type Open Delta VT Ratio 115 1 To set the phase CT primary rating modify the s2 SYSTEM SETUP gt CURRENT SENSING gt PHASE CT PRIMARY Setpoint as shown below gt Press the MENU key until the relay displays the setpoints
231. e Timing Out Active Trip Latched Trip Not Enabled Inactive Timing Out Active Trip Latched Trip Not Enabled Inactive Timing Out Active Trip Latched Trip Not Enabled Inactive Timing Out Active Trip Latched Trip Not Enabled Inactive Timing Out Active Trip Latched Trip Not Enabled Inactive Timing Out Active Trip Latched Trip Not Enabled Inactive Timing Out Active Trip Latched Trip Not Enabled Inactive Timing Out Active Trip Latched Trip Not Enabled Inactive Timing Out Active Trip Latched Trip Not Enabled Inactive Timing Out Active Trip Latched Trip Not Enabled Inactive Timing Out Active Trip Latched Trip Not Enabled Inactive Timing Out Active Trip Latched Trip Not Enabled Inactive Timing Out Active Trip Latched Trip Not Enabled Inactive Timing Out Active Trip Latched Trip Not Enabled Inactive Timing Out Active Trip Latched Trip Not Enabled Inactive Timing Out Active Trip Latched Trip Not Enabled Inactive Timing Out Active Trip Latched Trip Not Enabled Inactive Timing Out Active Trip Latched Trip Not Enabled Inactive Timing Out Active Trip Latched Trip CHAPTER 6 ACTUAL VALUES The various trip pickup actual values reflect the Input as programmed in the first line of the message The various digital and analog input functions shown only if the function has been assigned as an input
232. e to certain key presses The length of time these messages remain displayed can be programmed in S1 RELAY SETUP gt V PREFERENCES gt V DEFAULT MESSAGE CYCLE TIME The factory default flash message time is 4 seconds For additional information and a complete list of flash messages refer to Flash Messages on page 6 33 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 4 9 CHAPTER 4 INTERFACES 4 2 EnerVista Software Interface 4 2 1 4 2 2 Overview Hardware The front panel provides local operator interface with a liquid crystal display The EnerVista 489 Setup software provides a graphical user interface GUI as one of two human interfaces to a 489 device The alternate human interface is implemented via the device s faceplate keypad and display see the first section in this chapter The EnerVista 489 Setup software provides a single facility to configure monitor maintain and trouble shoot the operation of relay functions connected over serial communication networks It can be used while disconnected i e off line or connected i e on line to a 489 device In off line mode setpoint files can be created for eventual downloading to the device In on line mode you can communicate with the device in real time This no charge software provided with every 489 relay can be run from any computer supporting Microsoft Windows 95 or higher This chapter provides a summary of the basic EnerVista 489 Setup software interface
233. e MESSAGE Y or MESSAGE A keys to scroll through all the available actual values page headers Actual values page headers look as follows m ACTUAL VALUES gt Al STATUS To enter a given actual values page gt gt Press the MESSAGE P or ENTER key Press the MESSAGE Y or MESSAGE A keys to scroll through sub page headers until the required message is reached The end of a page is indicated by the message END OF PAGE The beginning of a page is indicated by the message TOP OF PAGE Similarly to access additional sub pages gt Press the MESSAGE gt or ENTER key to enter the first sub page gt Press the MESSAGE Y or MESSAGE A keys to scroll through the available sub pages until the desired message is reached The process is identical for both setpoints and actual values The following procedure illustrates the key sequence to access the Current Demand actual values gt Press the MENU key until you reach the actual values main menu m ACTUAL VALUES gt gt Press MESSAGE P or ENTER key to enter the first actual values page gt Press the MESSAGE or MESSAGE key to scroll through pages until the A2 METERING DATA page appears m ACTUAL VALUES gt 2 METERING DATA gt Press the MESSAGE P or ENTER key to display the first sub page heading for the Metering Data actual values page m CURRENT gt METERING 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 1 5 CHAPTER 1 G
234. e Time Units i Prefere nce button Automatic Soli Automatic Soli Automatic Soli Automatic Soli Automatic Automatic Soli None Soli None None None Phasor Display Select Reference Phase Van j Scale Magnitudes Graph Background Iu gt Change the Color of each graph as desired and select other options as required by checking the appropriate boxes gt Click OK to store these graph attributes and to close the window The Waveform Capture window will reappear with the selected graph attributes available for use 4 6 5 The EnerVista 489 Setup software can be used to view the phasor diagram of three phase currents and voltages The phasors are for Phase Voltages Va Vb and Vc Phase Currents la Ib and Ic 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 4 35 4 36 CHAPTER 4 INTERFACES gt With the EnerVista 489 Setup software running and communications established open the Actual Values gt Metering Data window gt Click on the Phasors tab The EnerVista 489 Setup software will display the following window Current Metering Quick Connect 489 Quick Connect Actual Valdes Metering Data mije x Phase ACurent Angle o Phase Curent Angle 0 Phase Output Curent D ese ure Ange 489 Quick Connect Actual Values Meter
235. e is shown to be an item in the TRIP COUNTERS sub menu which itself is an item in the A4 MAINTENANCE menu which is an item of ACTUAL VALUES Sub menu levels are entered by pressing the MESSAGE or ENTER key When inside submenu the lt MESSAGE or ESCAPE key returns to the previous sub menu The MESSAGE Y and MESSAGE A keys are used to scroll through the settings in a sub menu The display indicates which keys can be used at any given point 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 1 GETTING STARTED 12 Using the Relay 1 2 1 Menu Navigation The relay has three types of display messages actual value setpoint and target messages A summary of the menu structure for setpoints and actual values can be found at the beginning of chapters 5 and 6 respectively Setpoints are programmable settings entered by the user These types of messages are located within a menu structure that groups the information into categories Navigating the menu structure is described below Actual values include the following information 1 Generator and System Status b d Generator status either online offline or tripped The status of digital inputs Last trip information including values such as cause of last trip time and date of trip pre trip temperature measurements pre trip analog inputs values and pre trip instantaneous values of power system quantities Active alarms Relay date and ti
236. e ree LOADING NEW FIRMWAREQ a a a GY ADVANCED ENERVISTA 489 SETUP FEATURES TRIGGERED EVENTS 1200 WAVEFORM CAPTURE TRACE MEMORY PHASORS ar TRENDING DATA LOGGER EVENT RECORDER a MODBUS USER MAP cerca erect tette ttu en VIEWING ACTUAL VALUES USING ENERVISTA VIEWPOINT WITH THE 489 PLUS PEAY EXAMPLE t ahua a aka 5 SETPOINTS 5 1 SETPOINT MESSAGE aka Qan aqa 5 1 TRIPS ALARMS CONTROL FEATURES 5 6 RELAY ASSIGNMENT PRACTICES sessssessssssssesssssesssssessssesssssessssesseeessseessssessssesssneessesssneessases 5 7 DUADSETPBOINIS aqa ana aan 5 8 TOC II 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL TOC 155 51 489 SETUP PASSCODE PREFERE Com DEFAULT MESSAGE SC CLEAR S2 SYSTEM SETUP CURRE 53 DIGITAL INPUTS DESCRIPTION UNICATIONS REAL TIME CLOCK MESSAGES SENSING VOLTAGE SENSING GENERATOR PARAMETERS SERIAL START STOP INITIATION TABLE OF CONTENTS RATCHPAD BREAKER STATUS dtr ptt ee be e Po d tb a RAE 5 21 GENERA
237. e shield may be detected as ground current unless the shield wire is also passed through the CT window Twisted pair cabling on the zero sequence CT is recommended 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 3 INSTALLATION CABLE LUGS TO GENERATOR J TERMINATION CORE BALANCE SECONDARY CONNECTION TO 489 RELAY 7 HGF CORE BALANCE CT FOR GROUND SENSING GROUND CONDUCTOR DOES NOT PASS THROUGH CT AS IS NOT MOUNTED OVER GROUND WITHIN THE CABLE JACKET TO GROUND BUS 808787A2 DWG CABLE LUGS TO GENERATOR TERMINATION SIRESS CONE SHIELD GROUND CONNECTION SPLIT BOLT CONNECTOR IMPORTANT FOR SHIELDED CABLE THE GROUND WIRE INL MUST PASS THROUGH THE CT WINDOW CORE BALANCE CT SECONDARY CONNECTION 5 TO 489 RELAY HGF CORE BALANCE CT FOR GROUND SENSING Z fee TWISTED PAIR 5 DRBUNDC BS 4 5 2 808788A2 DWG FIGURE 3 15 Core Balance Ground CT Installation Shielded Cable 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 3 INSTALLATION 3 2 5 Voltage Inputs The 489 has four voltage transformer inputs three for generator terminal voltage and one for neutral voltage There are no internal fuses or ground connections on the voltage inputs The maximum phase VT ratio is 300 00 1 and the maximum neutral VT ratio is 240 00 1 The two possible VT connections for generator term
238. ed will rise or fall to a value based on the average phase current and the entered HOT COLD SAFE STALL RATIO Thermal capacity used will either rise at a fixed rate of 5 per minute or fall as dictated by the running cool time constant hot vised end leg x 1 x 10096 EQ 5 36 where TCused_end Thermal Capacity Used if le unit remains steady state leg equivalent generator heating current hot cold 2 HOT COLD SAFE STALL RATIO setpoint The hot cold safe stall ratio may be determined from the thermal limit curves if provided or the hot and cold safe stall times Simply divide the hot safe stall time by the cold safe stall time If hot and cold times are not provided there can be no differentiation and the HOT COLD SAFE STALL RATIO should be entered as 1 00 RTD Bias The thermal replica created by the features described in the sections above operates as a complete and independent model However the thermal overload curves are based solely on measured current assuming a normal 40 ambient and normal machine cooling If there is an unusually high ambient temperature or if machine cooling is blocked generator temperature will increase If the stator has embedded RTDs the 489 RTD bias feature should be used to correct the thermal model The RTD bias feature is a two part curve constructed using 3 points If the maximum stator RTD temperature is below the RTD BIAS MINIMUM setpoint typically 40 C no biasing occurs If
239. ence quantities 5 3 4 Serial Start Stop Initiation PATH SETPOINTS V S2 SYSTEM SETUP D V SERIAL START STOP SERIAL START STOP Range On Off SERIAL INITIATION Off Off Range Any Combination of Relays 2 to ieee lt STARTUP INITIATION amp RELAYS 2 5 MESSAGE SHUTDOWN INITIATION Range Any Combination of Relays 1 to RELAYS 1 4 4 SERIAL START STOP Range On Off MESSAGE EVENTS Off If enabled this feature will allow the user to initiate a generator startup or shutdown via the RS232 RS485 communication ports Refer to GE publication number GEK 106495 489 Communications Guide for command formats When a startup command is issued the auxiliary relay s assigned for starting control will be activated for 1 second to initiate startup When a stop command is issued the assigned relay s will be activated for 1 second to initiate a shutdown 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS 5 4 53 Digital Inputs 5 4 1 Description WARNING The 489 has nine 9 digital inputs for use with external contacts Two of the 489 digital inputs have been pre assigned as inputs having a specific function The Access Switch does not have any setpoint messages associated with it The Breaker Status input may be configured for either an a or b auxiliary contact The remaining seven digital inputs are assignable that is to say each input may be assigned to any of a
240. ended operation 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER A APPENDIX Current Transformers A 3 1 Ground Fault CTs for 50 0 025 A CT CTs that are specially designed to match the ground fault input of GE Multilin motor protection relays should be used to ensure correct performance These CTs have a 50 0 025A 2000 1 ratio and can sense low leakage currents over the relay setting range with minimum error Three sizes are available with 34 inch 5 inch or 8 inch diameter windows 5 95 F psi 1 8 i 48 10 P 10000 1 25 113 31 65 28 58 1 x2 fl 1000 ES 6 00 152 40 94 25 9107 9 6 38 10 162 05 g 5 3 38 85 85 H 10 EU H i tH 5 25 T 26 92 ee 6 00 152 40 bor 002 005 01 002 05 02 05 10 2 5 10 SECONDARY EXCITING RMS AMPS 60 Hz le 2 28 X 38 SLOTS 7 X 10 808840A1 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL A 11 0 56 4 0 44 X 1 00 SLOTS 14 2 11 2 25 4 6 75 171 5 CUP n 14 2 0 56 4 0 44 X 1 00 SLOTS 14 2 11 21 25 41 11 10 282 0 44 4241 11 2 0 75 1 Lis a T fA Fn 1 A 12 SECONDARY EXCITING RM
241. energized normally and de energize when called upon to operate It will also de energize when control power to the 489 is lost and therefore be in its operated state All other relays being non failsafe will be de energized normally and energize when called upon to operate Obviously when control power is lost to the 489 these relays must be de energized and therefore they will be in their non operated state Shorting bars in the drawout case ensure that when the 489 is drawn out no trip or alarm occurs The 6 Service output will however indicate that the 489 has been drawn out Each output relay has an LED indicator on the 489 front panel that comes on while the associated relay is in the operated state e 1 trip relay should be wired such that the generator is taken offline when conditions warrant For a breaker application the NO 1 Trip contact should be wired in series with the Breaker trip coil Supervision of a breaker trip coil requires that the supervision circuit be paralleled with the 1 Trip relay output contacts as shown in the Typical Wiring Diagram on page 3 10 With this connection made the supervision input circuits will place an impedance across the contacts that will draw a current of 2 to 5 mA for an external supply 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 3 INSTALLATION voltage from 30 to 250 V DC through the breaker trip coil The supervision circuits respond to a loss of this
242. equency of Vab generator voltage setpoint Fs generator frequency setpoint Pickup VOLTS HERTZ TRIP PICKUP setpoint The V Hz Curve 2 trip curves are shown below for delay settings of 0 1 0 5 1 5 and 10 seconds 1000 Time to Trip seconds wo TIME DELAY SETTING o w 2 m 1 00 1 20 1 40 1 60 1 80 Multiples of Volts Hertz Pickup 808743A1 X2 CDR 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 5 47 CHAPTER 5 SETPOINTS The formula for Volts Hertz Curve 3 is D when Es Pickup EQ 5 22 V F 9 ud a Vhom Fs x Pickup where T trip time in seconds D VOLTS HERTZ TRIP DELAY setpoint V RMS measurement of Vab F frequency of Vab generator voltage setpoint Fs generator frequency setpoint Pickup VOLTS HERTZ TRIP PICKUP setpoint The V Hz Curve 3 trip curves are shown below for delay settings of 0 1 0 5 1 5 and 10 seconds 10000 1000 zx Time to Trip seconds 0 3 TIME DELAY SETTING 0 1 0 1 1 00 1 20 1 40 1 60 1 80 2 00 Multiples of Voltz Hertz Pickup 808743A1 X3 CDR Volts Hertz is calculated per unit as follows WW NOTE _ phase phase voltage rated phase phase voltage Volts Hertz 2 2 frequency rated frequency 5 7 4 Phase Reversal PATH SETPOINTS gt V S6 VOLTAGE ELEM gt V PHASE REVERSAL 1 PHASE P1 A PHASE REVERSAL Range Off Latched Unlatched REVERSAL TRIP
243. er the STANDARD OVERLOAD CURVE NUMBER are displayed If the SELECT CURVE STYLE is set to Custom the setpoints shown after TIME TO TRIP AT 20 0 X FLA are not displayed The current measured at the output CTs is used for the thermal model The thermal model consists of five key elements the overload curve and overload pickup level the unbalance biasing of the generator current while the machine is running the cooling time constants and the biasing of the thermal model based on hot cold generator information and measured stator temperature Each of these elements are described in detail in the sections that follow 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS The generator FLA is calculated as 17 Generator Rated MVA EQ 5 29 A 3 x Rated Generator Phase Phase Voltage The 489 integrates both stator and rotor heating into one model Machine heating is reflected in a register called Thermal Capacity Used If the machine has been stopped for a long period of time it will be at ambient temperature and thermal capacity used should be zero If the machine is in overload once the thermal capacity used reaches 100 a trip will occur The overload curve accounts for machine heating during stall acceleration and running in both the stator and the rotor The Overload Pickup setpoint defines where the running overload curve begins as the generator enters an overload condition This is useful to accommodate a
244. erVista 489 Setup window gt Click the Add Device button to define the new device Enter the desired name in the Device Name field and a description optional of the site 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 4 15 CHAPTER 4 INTERFACES gt Select Serial from the Interface drop down list This will display a number of interface parameters that must be entered for proper RS232 functionality Device Setup MeReey Relay 1 eee 489 Generator Management Relay gt Enter the slave address and COM port values from the 51 489 SETUP gt V COMMUNICATIONS menu in the Slave Address and COM Port fields gt Enter the physical communications parameters baud rate and parity setpoints in their respective fields Note that when communicating to the relay from the front port the default communications setpoints are a baud rate of 9600 with slave address of 1 no parity 8 bits and 1 stop bit These values cannot be changed gt Click the Read Order Code button to connect to the 489 device and upload the order code If a communications error occurs ensure that the 489 serial communications values entered in the previous step correspond to the relay setting values gt Click OK when the relay order code has been received The new device will be added to the Site List window or Online window located in the top left corner of the main EnerVista 489 Setup window The 489 Site Device has now been co
245. erator is grounded and the other ones left floating the directional element for the floating generators does not receive a correct Vreytra Signal and therefore cannot operate correctly In those applications the element makes use of auxiliary contacts off the grounding switch and the unit breaker to turn the element into a simple overcurrent element with the pickup level set for the directional element note that the ground directional element and the ground overcurrent elements are totally separate elements In this mode the element can retain a high sensitivity and fast operate time since it will only respond to internal stator ground faults The table below illustrates the status of different elements under various operating conditions Table A 1 Detection Element Status Generator Unit Ground Element Condition Breaker Switch Ground Neutral Ground Directional Overvoltage Overcurrent Shutdown Open Open Out of service Out of service In service Open Circuit In service but will and Open Closed notoperatedueto In service In service grounded lack of Io Loaded and Grounded Closed Closed In service In service In service Loaded and In service as a Not Closed Open simple overcurrent Out of service In service Grounded element A 1 5 Third Harmonic Voltage Element The conventional neutral overvoltage element or the ground overcurrent element are not capable of reliably detecting stator g
246. es will be restricted until the passcode is entered again To prevent setpoint access before the 5 minutes expires the unit may be turned off and back on the access jumper may be removed or the SETPOINT ACCESS setpoint may be changed to Restricted The passcode cannot be entered until terminals C1 and C2 access terminals are shorted When setpoint access is allowed the Setpoint Access LED indicator on the front of the 489 will be lit Setpoint changes take effect immediately even when generator is running However changing setpoints while the generator is running is not recommended as any mistake may cause a nuisance trip The following procedure may be used to access and alter setpoints This specific example refers to entering a valid passcode to allow access to setpoints if the passcode was 489 gt Press the MENU key to access the header of each menu which will be displayed in the following sequence SETPOINTS w ACTUAL VALUES w TARGET MESSAGES w gt Press the MENU key until the display shows the header of the setpoints menu gt Press the MESSAGE gt or ENTER key to display the header for the first setpoints page The set point pages are numbered have an S prefix for easy identification and have a name which gives a general idea of the setpoints available in that page 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 4 INTERFACES gt Press the MESSAGE Y or MESSAGE keys to scro
247. essage will prompt the user to use the value keys GROUP 1 SETPOINT HAS BEEN STORED This message appear each time a setpoint has been altered and stored to setpoint Group 1 as shown on the display GROUP 2 SETPOINT HAS BEEN STORED This message appear each time a setpoint has been altered and stored to setpoint Group 2 as shown on the display 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL Digital Energy Multilin 489 Generator Management Relay Chapter 7 Testing 7 1 Test Setup 7 1 1 Description The purpose of this testing description is to demonstrate the procedures necessary to perform a complete functional test of all the 489 hardware while also testing firmware hardware interaction in the process Since the 489 is packaged in a drawout case a demo case metal carry case in which the 489 may be mounted may be useful for creating a portable test set with a wiring harness for all of the inputs and outputs Testing of the relay during commissioning using a primary injection test set will ensure that CTs and wiring are correct and complete The 489 tests are listed below For the following tests refer to Secondary Current Injection Testing on page 7 3 1 Output Current Accuracy Test Phase Voltage Input Accuracy Test Ground Neutral and Differential Current Accuracy Test Neutral Voltage Fundamental Accuracy Test Negative Sequence Current Accuracy Test 2 5 4 5 6 Accuracy Test 7 Digital Input a
248. esult in an error message The jumper does not restrict setpoint access via serial communications The relay has a programmable passcode setpoint which may be used to disallow setpoint changes from both the front panel and the serial communications ports This passcode consists of up to eight 8 alphanumeric characters The factory default passcode is 0 When this specific value is programmed into the relay it has the effect of removing all setpoint modification restrictions Therefore only the setpoint access jumper can be used to restrict setpoint access via the front panel and there are no restrictions via the communications ports When the passcode is programmed to any other value setpoint access is restricted for the front panel and all communications ports Access is not permitted until the passcode is entered via the keypad or is programmed into a specific register via communications Note that enabling setpoint access on one interface does not automatically enable access for any of the other interfaces i e the passcode must be explicitly set in the relay via the interface from which access is desired 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 1 9 CHAPTER 1 GETTING STARTED A front panel command can disable setpoint access once all modifications are complete For the communications ports writing an invalid passcode into the register previously used to enable setpoint access disables access In addition setpoint
249. etpoint V actual average phase phase voltage Vpickup OVERVOLTAGE TRIP PICKUP setpoint 1000 Time to Trip seconds 0 3 TIME DELAY SETTING 0 1 1 1 1 12 13 1 4 1 5 1 6 17 18 1 9 2 Multiples of Overvoltage Pickup 808741A1 CDR FIGURE 5 7 Overvoltage Curves 5 7 3 Volts Hertz PATH SETPOINTS D gt V S6 VOLTAGE ELEM gt VOLTS HERTZ 1 VOLTS HERTZ Pb VOLTS HERTZ Range Off Latched Unlatched 2 ALARM Off Range Any combination of Relays 2 to MESSAGE ASSIGN ALARM g y RELAYS 2 5 5 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 5 45 CHAPTER 5 SETPOINTS 7 VOLTS HERTZ ALARM Range 0 50 to 1 99 xNominal in steps PICKUP 1 00 xNominal of 0 01 VOLTS HERTZ ALARM Range 0 1 to 150 0 s in steps of 0 1 DELAY 3 0 EVENTS Off O Range Off Latched Unlatched u TRIP Off 5 ASSIGN TRIP Range Any combination of Relays 1 to E RELAYS 1 4 1 4 _ VOLTS HERTZ TRIP Range 0 50 to 1 99 xNominal in steps lle PICKUP 1 00 xNominal of 0 01 VOLTS HERTZ TRIP Range 0 1 to 150 0 s in steps of 0 1 DELAY 1 0 s lt VOLTS HERTZ CURVE Range 0 0 to 999 9 s in steps of O 1 RESET RATE 1 4 s ESSASE gt Range Curve 1 Curve 2 Curve 3 ELEMENT Curve 1 Definite Time The Volts Per Hertz elements may be used generator and unit transformer protection They are active as soon as the magnitude and f
250. f the 489 measures current or control power is cycled the force analog output function is automatically disabled and all analog outputs will revert back to their normal state Any time the analog outputs are forced the In Service indicator will flash indicating that the 489 is not in protection mode 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 5 105 CHAPTER 5 SETPOINTS 5 13 6 Comm Port Monitor PATH SETPOINTS V S12 489 TESTING gt V COMMUNICATION PORT MONITOR m MONITOR COMM PORT Range Computer RS485 Auxiliary COMMUNICATION D Computer RS485 RS485 Front Panel RS232 Range No Yes message gt CLEAR COMM g BUFFERS No E gt Range Buffer Cleared Received MESSAGE Wrong Slave Adar Illegal Function Illegal Count Illegal Reg Addr CRC Error Illegal Data lt Range received data in HEX Rx1 02 03 00 67 00 g 03 4 27 Range received data in HEX ESSAGE lt gt 7 Range transmit data in HEX Tx1 02 03 06 00 64 9 00 0A 00 0F Range transmit data HEX ESSAGE peer d During communications troubleshooting it can be useful to see the data being transmitted to the 489 from some master device as well as the data transmitted back to that master device The messages shown here make it possible to view that data Any of the three communications ports may be monitored After the communications buffers are cleared any data
251. for a previously saved setting file As for any other Windows application Browse for the file to add gt Click Open The new file and complete path will be added to the file list Creating a New Setpoint File The EnerVista 489 Setup software allows the user to create new setpoint files independent of a connected device These can be uploaded to a relay at a later date The following procedure illustrates how to create new setpoint files gt In the File pane right click on File 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 4 INTERFACES gt Select the New Settings File item The EnerVista 489 Setup software displays the following box allowing for the configuration of the setpoint file for the correct firmware version It is important to define the correct firmware version to ensure that setpoints not available in particular version are not downloaded into the relay File Name wer Management 489PC Untied 489 E Version 3 0x Description OK Cancel gt Select the Firmware Version for the new setpoint file gt For future reference enter some useful information the Description box to facilitate the identification of the device and the purpose of the file gt To select a file name and path for the new file click the button beside the Enter File Name box gt Select the file name and path to store the file or select any displayed file name to update an exi
252. function is intended for use with synchronous generators If ital input is assigned to this function any time the field status contact indicates the is not applied and the breaker status input indicates that the generator is online a trip ccur once the time delay has expired The time delay should be used to prevent ble nuisance tripping during shutdown The field status contact may be chosen as Auxi the fi as A iary open signifying the field breaker or contactor is open and shorted signifying eld breaker or contactor is closed Conversely the field status contact may be chosen uxiliary b shorted signifying the field breaker or contactor is open and open signifying it is closed 5 4 10 Tachometer PATH SETPOINTS DV S3 DIGITAL INPUTS gt V TACHOMETER m ASSIGN DIGITAL Range None Inputs 4 to 7 TACHOMETER gt INPUT None lt gt RATED SPEED Range 100 to 3600 RPM in steps of 1 I 3600 RPM ESSAGE TACHOMETER Range Off Latched Unlatched I ALARM Off gt ASSIGN ALARM Range Any combination of Relays 2 to ESSA RELAYS 2 5 5 5 ESSAGE lt TACHOMETER ALARM Range 101 to 17596 in steps of 1 amp SPEED 110 Rated gt TACHOMETER ALARM Range 1 to 250 s in steps of 1 I DELAY 1 s ESSAGE lt ALARM Range Off I EvENTS off ESSAGE TACHOMETER Range Off Latched Unlatche
253. g Tabs 3 1 4 Unit Withdrawal and Insertion TURN OFF CONTROL POWER BEFORE DRAWING OUT OR RE INSERTING THE RELAY TO PREVENT MALOPERATION CAUTION If an attempt is made to install a unit into a non matching case the mechanical key will prevent full insertion of the unit Do not apply strong force in the following step or damage may result CAUTION To remove the unit from the case gt Open the cover by pulling the upper or lower corner of the right side which will rotate about the hinges on the left Release the locking latch located below the locking handle by pressing upward on the latch with the tip of a screwdriver FIGURE 3 5 Press Latch to Disengage Handle 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 3 INSTALLATION gt Grasp the locking handle in the center and pull firmly rotating the handle up from the bottom of the unit until movement ceases FIGURE 3 6 Rotate Handle to Stop Position Once the handle is released from the locking mechanism the unit can freely slide out of the case when pulled by the handle It may sometimes be necessary to adjust the handle position slightly to free the unit FIGURE 3 7 Slide Unit out of Case To insert the unit into the case gt Raise the locking handle to the highest position gt Hold the unit immediately in front of the case and align the rolling guide pins near the hinges of the locking handle to the guide slots on either side
254. ge Open Shorted INPUT5 STATE Open gt ASSIGNABLE DIGITAL Range Open Shorted x INPUT6 STATE Open lt ASSIGNABLE DIGITAL Range Open Shorted INPUT7 STATE Open ESSAGE ESSAGE ESSAGE TRIP COIL Range Open Shorted SUPERVISION No Coil ESSAGE gt n The messages shown here may be used to monitor digital input status This may be useful during relay testing or during installation 6 2 8 Real Time Clock PATH ACTUAL VALUES gt A1 STATUS V REAL TIME CLOCK REAL TIME D DATE 01 01 1995 Range 01 01 1995 to 12 31 2094 CLOCK TIME 12 00 00 00 00 00 to 23 59 59 The time and date from the 489 real time clock may be viewed here 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 6 15 6 3 A2 Metering Data 6 3 1 Current Metering CHAPTER 6 ACTUAL VALUES PATH ACTUAL VALUES V 2 METERING DATA gt CURRENT METERING 0 0 Range to 999999 CURRENT P 0 Amps 0 b 0 ESSAGE ESSAGE ESSAGE ESSAG rm ESSAG rn ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE lt gt lt gt lt gt lt gt lt gt lt gt lt gt lt gt lt gt gt 00 07 00 07 00 07 00 09 6d 0 Range to 999999 A o Neut Amps a 0 b 0 Range 0 to 999999 A c 0 Diff Amps Range 0 to 999999 A gt lt El Q
255. ge scratchpad message gt Press ENTER The PRESS ENTER TO ADD DEFAULT MESSAGES message will be displayed for 5 seconds gt Press ENTER again while this message is displayed to add the current message to the end of the default message list If the procedure was followed correctly the DEFAULT MESSAGE HAS BEEN ADDED flash message is displayed gt To verify that the message was added view the last message under the 51 489 SETUP gt V DEFAULT MESSAGES menu Default messages can be removed from the default message list as follows gt Enter the correct passcode at 1 489 SETUP gt PASSCODE gt ENTER PASSCODE FOR ACCESS to allow setpoint entry unless the passcode has already been entered or unless the passcode is 0 defeating the passcode security feature gt Select the message to remove from the default message list under the 1 489 SETUP gt V DEFAULT MESSAGES menu gt Select the default message to remove and press ENTER The relay will display PRESS ENTER TO REMOVE MESSAGE gt Press ENTER while this message is displayed to remove the current message out of the default message list If the procedure was followed correctly the DEFAULT MESSAGE HAS BEEN REVOVED flash message is displayed 5 2 6 Message Scratchpad PATH SETPOINTS gt S1 489 SETUP gt V MESSAGE SCRATCHPAD i LL TEXT Range 40 alphanumeric characters TEXT 2 Range 40 alphanumeric characters TEXT 3 Range 40 alphanume
256. ground current detection Using the HGF CT allows measurement of ground current values as low as 0 25 A primary With impedance grounded generators a single ground fault on the stator does not require that the unit be quickly removed from service The grounding impedance limits the fault current to a few amperes A second ground fault can however result in significant damage to the unit Thus the importance of detecting all ground faults even those in the bottom 596 of the stator The fault detection methods depend on the grounding arrangement the availability of core balance CT and the size of the unit With modern full featured digital generator protection relays such as the 489 users do not incur additional costs for extra protection elements as they are all part of the same device This application note provides general descriptions of each of the elements in the 489 suitable for stator ground protection and discusses some special applications 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL A 1 2 CHAPTER A APPENDIX A 1 2 Neutral Overvoltage Element The simplest and one of the oldest methods to detect stator ground faults on high impedance grounded generators is to sense the voltage across the stator grounding resistor See References 1 2 at the end of this section This is illustrated in a simplified form in the figure below The voltage signal is connected to the Vneutra input of the 489 terminals E10 and F10 The
257. he 489 relay at the instance of a trip maximum of 128 cycles can be captured and the trigger point can be adjusted to anywhere within the set cycles A maximum of 16 waveforms can be buffered stored with the buffer cycle trade off The following waveforms can be captured Phase A B and C currents Iq Ip and Neutral end A B and C currents Ineurra neutral_b Qd Ineutral_c Ground currents Ig e Phase A N B N and C N voltages Vg Vp and V gt With EnerVista 489 Setup running and communications established select the Actual Waveform Capture menu item to open the waveform capture setup window Waveform Capture Pumping Station 1 489 Relay 1 Actual Launch Viewer Total Triggers Trigger waveform Select Trigger 1 Save to file Select which trigger you would like to read values then click the Launch Viewer button to view the waveform 469 Relay 1 Actual Values Number of available files Files to be saved or viewed Save waveform to a file gt Click on Trigger Waveform to trigger a waveform capture The waveform file numbering starts with the number zero in the 489 therefore the maximum trigger number will always be one less then the total number triggers available 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 4 33 CHAPTER 4 INTERFACES gt Click on the Save to File button to save the selected waveform to the local PC Anew wind
258. he 51 489 SETUP gt PASSCODE gt V SETPOINT ACCESS setpoint is altered to Restricted This message also appears any time that setpoint access is permitted and the access jumper is removed DATE ENTRY WAS NOT COMPLETE Since the DATE setpoint has a special format entered as MM DD YYYY this message appears and the new value will not be stored if the ENTER key is pressed before all of the information has been entered Another attempt will have to be made with the complete information DATE ENTRY WAS OUT OF RANGE Appears if an invalid entry is made for the DATE for example 15 entered for the month TIME ENTRY WAS NOT COMPLETE Since the TIME setpoint has a special format entered as HH MM SS s this message appears and the new value will not be stored if the ENTER key is pressed before all of the information has been entered Another attempt will have to be made with the complete information TIME ENTRY WAS OUT OF RANGE Appears if an invalid entry is made for the TIME for example 35 entered for the hour NO TRIPS OR ALARMS TO RESET Appears if the RESET key is pressed when there are no trips or alarms present RESET PERFORMED SUCCESSFULLY If all trip and alarm features that are active can be cleared that is the conditions that caused these trips and or alarms are no longer 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 6 ACTUAL VALUES present then this message appears when a reset is performed indicat
259. he event of fault conditions The SIMULATION MODE setpoint may be entered only if the generator is offline no current is measured and there are no trips or alarms active The values entered as Pre Fault Values will be substituted for the measured values in the 489 when the SIMULATION MODE is Simulate Pre Fault The values entered as Fault Values will be substituted for the measured values in the 489 when the SIMULATION MODE is Simulate Fault If the SIMULATION MODE is set to Pre Fault to Fault the Pre Fault values will be substituted for the period of time specified by the delay followed by the Fault values If a trip occurs the SIMULATION MODE reverts to Off Selecting Off for the SIMULATION MODE places the 489 back in service If the 489 measures current or control power is cycled the SIMULATION MODE automatically reverts to Off If the 489 is to be used for training it might be desirable to allow all parameter averages statistical information and event recording to update when operating in simulation mode If however the 489 has been installed and will remain installed on a specific generator it might be desirable assign a digital input to Test Input and to short that input to prevent all of this data from being corrupted or updated In any event when in simulation mode the 489 In Service LED indicator will flash indicating that the 489 is not in protection mode 489 GENERATOR MANAGEMENT RELAY INSTR
260. he firmware has been upgraded it will be necessary to load this file back into the 489 Refer to Downloading and Saving Setpoints Files on page 4 23 for details on saving relay setpoints to a file Loading New Firmware Loading new firmware into the 489 flash memory is accomplished as follows Connect the relay to the local PC and save the setpoints to a file as shown in Downloading and Saving Setpoints Files on page 4 23 gt Select the Communications gt Update Firmware menu item The following warning message will appear 489Setup 2 All settings will be LOST Do you want to proceed J x gt Select Yes to proceed or No to cancel the process Do not proceed unless you have saved the current setpoints An additional message will be displayed to ensure the PC is connected to the relay front port as the 489 cannot be upgraded via the rear RS485 ports 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 4 INTERFACES The EnerVista 489 Setup software will request the new firmware file Locate the file to load into the 489 The firmware filename has the following format 32 J 300 8 000 Modification Number 000 none GE Multilin use only Firmware version Required 489 hardware revision Product code 32 489 FIGURE 4 5 Firmware File Format The EnerVista 489 Setup software automatically lists all filenames beginning with 32 gt Select the appropriate file gt Click
261. hen programming setpoints from the front panel keypad and setpoints may be altered using the RS232 and RS485 serial ports without access protection If however the passcode is changed to a non zero value passcode protection is enabled The access jumper must be installed and the passcode must be entered to program setpoints from the front panel keypad The passcode must also be entered individually from each serial communications port to gain setpoint programming access from that port The ENTER PASSCODE FOR ACCESS setpoint is seen only if the passcode is not 0 and SETPOINT ACCESS is Restricted The SETPOINT ACCESS and CHANGE PASSWORD setpoints are seen only if the passcode is 0 and the SETPOINT ACCESS is Permitted To enable passcode protection on a new relay follow the procedure below gt Press ENTER then MESSAGE DOWN until CHANGE PASSCODE message is displayed gt Select Yes and follow directions to enter a new passcode 1 to 8 digits in length Once a new passcode other than 07 is programmed it must be entered to gain setpoint access whenever setpoint access is restricted Assuming that a non zero passcode has been programmed and setpoint access is restricted then selecting the passcode subgroup causes the ENTER PASSCODE AGAIN message to appear Enterthe correct passcode A flash message will advise if the code is incorrect and allow a retry If it is correct and the setpoint access jumper is installed the SETPOIN
262. icates off There is also a blinking indication The box under LNK column indicates the Ethernet link status If it is on the Ethernet port is connected to the network if it is off the port is disconnected This indicator is normally on The box under the column indicates the connection status If on the Ethernet port is configured and ready to transmit and receive data If blinking the Ethernet port is either active transmitting or receiving data or indicating an error if the diagnostic status is also on or blinking The box under the column indicates the diagnostic status If it is on then either a fatal Ethernet port error has occurred or there is a duplicate IP address on the network If blinking then there is a non fatal network error Off indicates no errors 6 2 2 Generator Status PATH ACTUAL VALUES gt A1 STATUS gt GENERATOR STATUS GENERATOR STATUS Range Online Offline Tripped GENERATOR gt Offline lt gt Range 0 to 100 Seen only if the MESSAGE 22 Thermal Model is enabled ESTIMATED TRIP TIME Range 0 to 10000 sec Never Seen MESSAGE ON OVERLOAD Never only if the Thermal Model is enabled These messages describe the status of the generator at any given point in time If the generator has been tripped is still offline and the 489 has not yet been reset the GENERATOR STATUS will be Tripped The GENERATOR THERMAL CAPACITY USED value reflects an integrated value of both the st
263. iewed and there are no trips or alarms the Message LED indicator will be on solid From any point in the message structure pressing the MESSAGE P key will cause the 489 to revert back to the normal default messages When normal default messages are being displayed pressing the MESSAGE P key will cause the 489 to display the next default message immediately EXAMPLE If a thermal model trip occurred an RTD alarm may also occur as a result of the overload The 489 would automatically default to the CAUSE OF LAST TRIP message at the top of the A1 STATUS V LAST TRIP DATA queue and the Message LED would flash Pressing the MESSAGE gt key cycles through the time and date stamp information as well as all of the pre trip data When the bottom of this queue is reached an additional press of the MESSAGE gt key would normally return to the top of the queue However because there is an alarm active the display will skip to the alarm message at the top of the A1 STATUS gt V ALARM STATUS queue Finally another press of the MESSAGE gt key will cause the 489 to return to the original CAUSE OF LAST TRIP message and the cycle could be repeated LAST TRIP DATA CAUSE OF LAST TRIP Overload TIME OF LAST TRIP 12 00 00 0 DATE OF LAST TRIP Jan 01 2002 L ANALOG INPUT 4 PreTrip 0 Units 6 32 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 6 ACTUAL VALUES ACTIVE ALARMS STATOR RTD 1 ALARM 135 C START BLOCK OVERLO
264. igurations for each RTD This allows one of the RTDs to be turned off if it malfunctions The alarm level is normally set slightly above the normal running temperature The trip level is normally set at the insulation rating Trip voting has been added for extra reliability in the event of RTD malfunction If enabled a second RTD must also exceed the trip temperature of the RTD being checked before a trip will be issued If the RTD is chosen to vote with itself the voting feature is disabled Each RTD name may be changed if desired 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS 5 9 3 RTDs 7 to 10 PATH SETPOINTS D V S8 RTD TEMPERATURE D V RTD 7 10 1 RTD 7 Pb RTD 7 APPLICATION Range Stator Bearing Ambient Other Bearing None Range 8 alphanumeric characters RTD 7 NAME Range Off Latched Unlatched escage gt RTD 7 ALARM 9 amp lt ASSIGN ALARM Range Any combination of Relays 2 to i RELAYS 2 5 5 5 Range 1 to 250 C in steps of 1 gt RTD 7 ALARM g p TEMPERATURE 80 C gt RTD 7 ALARM Range On Off EVENTS Off Range Off Latched Unlatched RTD 7 TRIP g RTD 47 TRIP VOTING Range RTD 1 to RTD 12 i amp 7 ASSIGN TRIP Range Any combination of Relays 1 to i gt gt RELAYS 1 4 1 4 Range 1 to 250 C in steps of 1 ESSAGE RTD 7 TRIP TEM
265. ill prompt for a target device Select the desired device Click Send Select Target Device 1 6 489 C Program Files GE 48 E Target Devices Ei Quick Connect 489 Quick Connect E Pumping Station 2 489 Relay 2 Ei Pumping Station 1 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 4 INTERFACES If there is an incompatibility an error of the following type will occur 489Setup Incompatible device order codes or versions Target 489 Version 1 50 Source 489 Version 3 00 Please use Properties in File menu to convert version If there are no incompatibilities between the target device and the Setpoints file the data will be transferred to the relay An indication of the percentage completed will be shown in the bottom of the main menu 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 4 29 4 5 CHAPTER 4 INTERFACES Upgrading Relay Firmware 4 5 1 4 5 2 4 5 3 Description To upgrade the 489 firmware follow the procedures listed in this section Upon successful completion of this procedure the 489 will have new firmware installed with the original setpoints The latest firmware files are available from the GE Multilin website at http www GEmultilin com Saving Setpoints to a File Before upgrading firmware it is very important to save the current 489 settings to a file on your PC After t
266. inal voltage measurement are open delta or wye see Typical Wiring Diagram on page 3 10 The voltage channels are connected in wye internally which means that the jumper shown on the delta source connection of the Typical Wiring Diagram between the phase B input and the 489 neutral terminal must be installed for open delta VTs Polarity of the generator terminal VTs is critical for correct power measurement and voltage phase reversal operation CAUTION 3 2 6 Digital Inputs There are 9 digital inputs that are designed for dry contact connections only Two of the digital inputs Access and Breaker Status have their own common terminal the balance of the digital inputs share one common terminal see Typical Wiring Diagram on page 3 10 CAUTION In addition the 24 V DC switch supply is brought out for control power of an inductive or capacitive proximity probe The NPN transistor output could be taken to one of the assignable digital inputs configured as a counter or tachometer Refer to the Specifications section of this manual for maximum current draw from the 24 V DC switch supply DO NOT INJECT VOLTAGES TO DIGITAL INPUTS DRY CONTACT CONNECTIONS ONLY CAUTION 3 2 7 Analog Inputs Terminals are provided on the 489 for the input of four 0 to 1 mA 0 to 20 mA or 4 to 20 mA current signals field programmable This current signal can be used to monitor any external quantity such as vibration pressure field current etc The fo
267. ing Data gt Press the View button to display the following window VOLTAGE LEVEL CURRENT LEVEL Displays the value Displays the value and the angle of and angle of the the voltage phasors current phasor Phasors New Site 1 489 Relay 1 Actual Values Metering Data x es oo 2 323 kv 0 2 323 kV 119 489 Relay 1 Phasors New Phasors New Gite 1 489 Relay 1 Actual Values Metering Data LO VOLTAGE VECTORS CURRENT VECTORS Assigned to Phasor Assigned to Phasor Set 1 Graph 1 Set 2 Graph 2 The 489 Generator Management Relay was designed to display lagging angles Therefore if a system condition would cause the current to lead the voltage by 45 the 489 relay will display such angle as 315 Lag instead of 45 Lead 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 4 INTERFACES When the currents and voltages measured by the relay are zero the angles displayed by the relay and those shown by the EnerVista 489 Setup software are not fixed values WARNING 4 6 4 Trending Data Logger The trending or data logger feature is used to sample and record up to eight actual values at an interval defined by the user Several parameters can be trended and graphed at sampling periods ranging from 1 second up to 1 hour The parameters which can be trended by the EnerVista 489 Setup software are 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL Currents Voltages Phase Currents A B and C
268. ing starting and the acceleration thermal 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 5 77 CHAPTER 5 SETPOINTS limit curve adjusted accordingly If the VT Connection setpoint is set to none or if a VT fuse failure is detected the acceleration thermal limit curve for the minimum allowable voltage will be used The voltage dependent overload curve is comprised of the three characteristic thermal limit curve shapes determined by the stall or locked rotor condition acceleration and running overload The curve is constructed by entering a custom curve shape for the running overload protection curve Next a point must be entered for the acceleration protection curve at the point of intersection with the custom curve based on the minimum allowable starting voltage as defined by the minimum allowable voltage Locked Rotor Current and safe stall time must also be entered for that voltage A second point of intersection must be entered for 100 voltage Once again the locked rotor current and the safe stall time must be entered this time for 100 voltage The protection curve that is created from the safe stall time and intersection point will be dynamic based on the measured voltage between the minimum allowable voltage and the 100 voltage This method of protection inherently accounts for the change in speed as an impedance relay would The change in impedance is reflected by machine terminal voltage and line current For any given speed at
269. ing that all trips and alarms have been cleared ALL POSSIBLE RESETS HAVE BEEN PERFORMED If only some of the trip and alarm features that are active can be cleared that is the conditions that caused some of these trips and or alarms are still present then this message appears when a reset is performed indicating that only trips and alarms that could be reset have been reset ARE YOU SURE PRESS ENTER TO VERIFY If the RESET key is pressed and resetting of any trip or alarm feature is possible this message appears to verify the operation If RESET is pressed again while this message is displayed the reset will be performed e PRESS ENTER TO ADD DEFAULT MESSAGE Appears if the decimal key immediately followed by the ENTER key is entered anywhere in the actual value message structure This message prompts the user to press ENTER to add a new default message To add a new default message ENTER must be pressed while this message is being displayed e DEFAULT MESSAGE HAS BEEN ADDED Appears anytime a new default message is added to the default message list e DEFAULT MESSAGE LIST IS FULL Appears if an attempt is made to add a new default message to the default message list when 20 messages are already assigned To add a new message one of the existing messages must be removed e PRESS ENTER TO REMOVE MESSAGE Appears if the decimal key immediately followed by the ENTER key is entered in the 51 489 SETUP gt V DEFAUL
270. int TCused at used defined by the HOT COLD SAFE STALL RATIO setpoint In simple terms the RTD bias feature is real feedback of measured stator temperature This feedback acts as correction of the thermal model for unforeseen situations Since RTDs are relatively slow to respond RTD biasing is good for correction and slow generator heating The rest of the thermal model is required during high phase current conditions when machine heating is relatively fast It should be noted that the RTD bias feature alone cannot create a trip If the RTD bias feature forces the thermal capacity used to 100 the machine current must be above the over load pickup before an overload trip occurs Presumably the machine would trip on stator RTD temperature at that time No biasing occurs if the hottest stator RTD is open or short 100 80 60 40 RTD Thermal Capacity Used 20 RTD Bias Maximum Rated Temperature 130 C Insulation Rating 155 C ot Cold 0 85 RTD Bias Minimum RTD Bias Center Poin 0 50 100 150 200 250 Maximum Stator RTD Temperature 808721A1 CDR FIGURE 5 24 RTD Bias Curve 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS 5 10 3 Thermal Elements SETPOINTS D V S9 THERMAL MODEL D V THERMAL ELEMENTS 1 THERMAL Pb THERMAL MODEL Range Off Latched Unlatched ELEMENTS ALARM Off lt ASSIGN ALARM Range An
271. interrogation of setpoint and actual values is also possible New firmware may be downloaded to the 489 flash memory through this port Upgrading the relay firmware does not require a hardware EEPROM change 4 1 4 Keypad Description The 489 display messages are organized into main menus pages and sub pages There are three main menus labeled Setpoints Actual Values and Target Messages gt Press the MENU key followed by the MESSAGE Y key to scroll through the three main menu headers which appear in sequence as follows SETPOINTS w 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 4 3 CHAPTER 4 INTERFACES ACTUAL VALUES w TARGET MESSAGES w gt Press the MESSAGE P key or the ENTER key from these main menu pages to display the corresponding menu page Use the MESSAGE Y and MESSAGE A keys to scroll through the page headers When the display shows SETPOINTS gt Pressthe MESSAGE gt key or the ENTER key to display the page headers of programmable parameters referred to as setpoints in the manual When the display shows ACTUAL VALUES Pressthe MESSAGE gt key or the ENTER key to display the page headers of measured parameters referred to as actual values in the manual When the display shows TARGET MESSAGES gt Pressthe MESSAGE gt key or the ENTER key to display the page headers of event messages or alarm conditions Each page is broken down further into logical sub pages The MESSAGE W
272. ion 50 ms TCused used t time to trip x 10096 EQ 5 30 where time to trip time taken from the overload curve at leg as a function of FLA The overload protection curve should always be set slightly lower than the thermal limits provided by the manufacturer This will ensure that the machine is tripped before the thermal limit is reached If the starting times are well within the safe stall times it is recommended that the 489 Standard Overload Curve be used The standard overload curves are series of 15 curves with a common curve shape based on typical generator thermal limit curves see the following figure and table When the generator trips offline due to overload the generator will be locked out the trip relay will stay latched until generator thermal capacity reaches 15 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 5 73 CHAPTER 5 SETPOINTS 100000 10000 TIME IN SECONDS 10 1 00 0 10 1 00 10 100 1000 MULTIPLE FULL LOAD AMPS FIGURE 5 15 489 Standard Overload Curves iy Above 8 0 x Pickup the trip time for 8 0 is used This prevents the overload curve from acting as an instantaneous element NOTE The standard overload curves equation is Time to Trip Multiplier x 2 2116623 EQ 5 31 0
273. ion motors However some of the thermal model features may be used to model the heating that occurs in synchronous generators during overload conditions One of the principle enemies of generator life is heat Generator thermal limits are dictated by the design of both the stator and the rotor Induction generators that start on the system bus have three modes of operation locked rotor or stall when the rotor is not turning acceleration when the rotor is coming up to speed and generating when the rotor turns at super synchronous speed Heating occurs in the generator during each of these conditions in very distinct ways Typically during the generator starting locked rotor and acceleration conditions the generator will be rotor limited That is to say that the rotor will approach its thermal limit before the stator Under locked rotor conditions voltage is induced in the rotor at line frequency 50 or 60 Hz This voltage causes a current to flow in the rotor also at line frequency and the heat generated R is a function of the effective rotor resistance At 50 or 60 Hz the reactance of the rotor cage causes the current to flow at the outer edges of the rotor bars The effective resistance of the rotor is therefore at a maximum during a locked rotor condition as is rotor heating When the generator is running at above rated speed the voltage induced in the rotor is at a low frequency approximately 1 Hz and therefore the effective resis
274. l updates and the latest software updates please visit the GE Multilin website at http www GEmultilin com If there is any noticeable physical damage or any of the contents listed are missing please contact GE Multilin immediately NOTE 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 1 1 1 2 CHAPTER 1 GETTING STARTED Manual Organization Reading a lengthy instruction manual on a new product is not a task most people enjoy To speed things up this introductory chapter provides guidelines for basic relay usability Important wiring considerations and precautions discussed in Electrical Installation on page 3 9 should be observed for reliable operation Detailed information regarding accuracy output relay contact ratings and so forth are detailed in Specifications on page 2 6 The remainder of this manual should be read and kept for reference to ensure maximum benefit from the 489 Generator Management Relay For further information please consult your local sales representative or the factory Comments about new features or modifications for your specific requirements are welcome and encouraged Setpoints and actual values are indicated as follows in the manual A4 MAINTENANCE gt V TRIP COUNTERS gt TOTAL NUMBER OF TRIPS This path representation illustrates the location of an specific actual value or setpoint with regards to its previous menus and sub menus In the example above the TOTAL NUMBER OF TRIPS actual valu
275. lass 2 compliant for transient immunity i m 40 C to 85 C Operating temperature m High Degree of network and management Security ML1600 SNMPv3 Encryption Supported P n Secure Web Management 9 Rack mounted Managed Switch m Enhanced network reliability with fast fault recovery a Less than Sms recovery per hop Link Loss Alert for detecting broken connections Simple Switch Configuration ML600 Powerful Graphical Interface simplifying network management Unmanaged Compact Switch Enhanced web statistics alarm management and security configurations Support of all Common Network Communication Ports 10 Mb ST multimode 100 Mb 5T or SC multimode and singlemade 10 100 Mb RJ45 Copper n 1000 Mb SC multimode or singlemode fiber and R45 Copper S Pg age GE Mulltilin 1 800 547 8629 Website www GEMultilin com multilink TOC TABLE OF CONTENTS Table of Contents 1 GETTING STARTED eg pp aun CAUTIONS AND WARNINGS INSPECTION CHECKLIST MANUAL ORGANIZATION VING THE S Aa qaa MENU NAVIGATION tnb tetti tiet PANEL KEYING EXAMPLE CHANGING SETPOINTS TRODUCTION THE FIEEP ish terne tetris ibtd NUMERICAESETPOINTS ace eee nde tiles ec ENUMERATION SETPOINTS TEXIES
276. ll through all the available setpoint page headers Setpoint page headers look as follows SETPOINTS w 51 489 SETUP To enter a given setpoints page gt Press the MESSAGE gt or ENTER key gt Press the MESSAGE Y or MESSAGE A keys to scroll through sub page headers until the required message is reached The end of a page is indicated by the message END OF PAGE The beginning of a page is indicated by the message TOP OF PAGE Each page is broken further into subgroups gt Press MESSAGE Y or MESSAGE A to cycle through subgroups until the desired subgroup appears on the screen Pressthe MESSAGE gt or ENTER key to enter a subgroup PASSCODE w Each sub group has one or more associated setpoint messages gt Press the MESSAGE Y or MESSAGE A keys to scroll through setpoint messages until the desired message appears ENTER PASSCODE The majority of setpoints are changed by pressing the VALUE keys until the desired value appears and then pressing ENTER Numeric setpoints may also be entered through the numeric keys including decimals If the entered setpoint is out of range the original setpoint value reappears If the entered setpoint is out of step an adjusted value will be stored e g 101 for a setpoint that steps 95 100 105 is stored as 100 If a mistake is made entering the new value pressing ESCAPE returns the setpoint to its original value Text editing is a special case described in detail in Ente
277. llowing curves illustrate the resultant overload protection for 80 and 100 voltage respectively For voltages between these levels the 489 shifts the acceleration curve linearly and constantly based upon the measured voltage during generator start 489 B E VOLTAGE DEPENDENT GE Multilin OVERLOAD PROTECTION at 80 V 1000 900 800 700 600 500 400 300 200 100 90 80 70 60 50 40 30 20 TIME TO TRIP SECONDS a 1 2 3 4 5 6 7 8 MULTIPLES OF FULL LOAD AMPS 808830A3 CDR FIGURE 5 21 Voltage Dependent Overload Protection at 80 Voltage 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 5 83 5 84 CHAPTER 5 SETPOINTS 489 VOLTAGE DEPENDENT GE Multilin OVERLOAD PROTECTION at 100 V 1000 900 800 700 600 500 400 300 200 100 80 70 60 50 40 30 TIME TO TRIP SECONDS 20 a 1 2 3 4 5 6 7 8 MULTIPLES OF FULL LOAD AMPS 808829A3 CDR FIGURE 5 22 Voltage Dependent Overload Protection at 100 Voltage Unbalance Bias Unbalanced phase currents will cause additional rotor heating that will not be accounted for by electromechanical relays and may not be accounted for in some electronic pr
278. locking the differential function using the position of the opposite breaker via the multiple setting group mechanism of the relay When both breakers are opened both relays are in their setting group 1 with the differential functions operational When a breaker is closed its relay remains in group 1 so that no setting group switching takes place and therefore continuous uninterrupted protection is provided for the generator At the same time the opposite relay is blocked by switching to group 2 in which the differential function is disabled This prevents mis operation There is no provision for an advanced close signal and the breaker position signal is used instead 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER A APPENDIX In addition enhanced differential protection algorithm takes care the timing offset between the main and auxiliary contacts of the breaker As a result maximum of 50ms timing offset between the main and auxiliary contacts of the breaker will block the differential function A 2 2 Stator Differential Logic The differential function uses an internal timer of 130ms as shown in the figure below This timer is a common timer for all three phases of the differential function Normally the timer is not engaged ensuring instantaneous operation and backward compatibility with the previous firmware revisions of the product The timer is engaged only when the terminal side currents in all three phases are zer
279. log output channel will output 20 mA Table 5 8 Analog Output Parameters Parameter Name Range Units Step Default Min Max IA Output Current 0 00 to 20 00 x FLA 0 01 0 00 1 25 Output Current 0 00 to 20 00 x FLA 0 01 0 00 1 25 IC Output Current 0 00 to 20 00 x FLA 0 01 0 00 1 25 Avg Output Current 0 00 to 20 00 x FLA 0 01 0 00 1 25 Neg Seq Current 0 to 200096 FLA 1 0 100 Averaged Gen Load 0 00 to 20 00 x FLA 0 01 0 00 1 25 Hottest Stator RTD 50 to 250 C or 58 to 482 F 1 0 200 Hottest Bearing RTD 50 to 250 C or 58to 482 F 1 0 200 Ambient RTD 50 to 250 C or 58 to 482 F 1 0 70 RTDs 1 to 12 50 to 250 C or 58to 482 F 1 0 200 AB Voltage 0 00 to 1 50 x Rated 0 01 0 00 1 25 BC Voltage 0 00 to 1 50 x Rated 0 01 0 00 1 25 CA Voltage 0 00 to 1 50 x Rated 0 01 0 00 1 25 Volts Hertz 0 00 to 2 00 x Rated 0 01 0 00 1 50 Frequency 0 00 to 90 00 Hz 0 01 59 00 61 00 Neutral Volt 3rd 0 to 25000 V 0 1 0 0 45 0 Average Voltage 0 00 to 1 50 x Rated 0 01 0 00 1 25 Power Factor 0 01 to 1 00 lead lag 0 01 0 8 lag 0 8 lead Reactive Power Mvar 2 00 to 2 00 x Rated 0 01 0 00 1 25 Real Power 2 00 to 2 00 x Rated 0 01 0 00 1 25 Apparent Power 0 00 to 2 00 x Rated 0 01 0 00 1 25 Analog Inputs 1 to 4 50000 to 50000 1 0 50000 Tachometer 0 to 7200 RPM 1 3500 3700 Thermal Capacity Used 0 to 100 1 0 100 Current Demand 0 00 to
280. lt NEUTRAL O V Fund Range x TRIPS 0 lt NEUTRAL U V 3rd Range TRIPS 0 lt LOSS OF EXCITATION 1 Range x TRIPS 0 LOSS OF EXCITATION 2 Range x TRIPS 0 lt DISTANCE ZONE 1 Range TRIPS 0 lt DISTANCE ZONE 2 Range x TRIPS 0 REACTIVE POWER Range x TRIPS 0 REVERSE POWER Range TRIPS 0 lt LOW FORWARD POWER Range x TRIPS 0 STATOR RTD Range x TRIPS 0 BEARING RTD Range TRIPS 0 lt OTHER RTD Range x TRIPS 0 AMBIENT RTD Range x TRIPS 0 lt THERMAL MODEL Range TRIPS 0 INADVERTENT ENERG Range x TRIPS 0 ANALOG I P 1 Range x TRIPS 0 lt ANALOG I P 2 Range TRIPS 0 lt ANALOG I P 3 Range x TRIPS 0 lt ANALOG I P 4 Range x TRIPS 0 COUNTERS CLEARED Range lt gt Jan 1 1995 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 01050000 0 to 50000 0 to 50000 0 to 50000 0 to 50000 0 to 50000 0 to 50000 0 to 50000 0 to 50000 0 to 50000 0 to 50000 0 to 50000 0 to 50000 0 to 50000 0 to 50000 Name units as programm Name units as programm Name units as programm Name units as programm Date in format shown 0 to 50000 Reflects Analog In ed O to 50000 Reflects Analog In ed 0 to 50000 Reflects Analog In ed O to 50000 Reflects Analog In ed CHAPTE
281. lue of 1200 5 240 VT Ratio programmed VT ratio if VT ratio is 100 1 use a value of 100 Diameter i N 80881941 0WG FIGURE 5 10 Loss of Excitation Diagram 5 7 10 Distance Element PATH SETPOINTS D gt V S6 VOLTAGE ELEM D gt V DISTANCE ELEMENT 1 DISTANCE 51 STEP UP TRANSFORMER Range None Delta Wye ELEMENT SETUP None gt FUSE FAILURE Range On Off suPERVISION On ZONE 1 Range Off Latched Unlatched x TRIP Off ESSAGE lt ASSIGN ZONE 1 TRIP Range Any combination of Relays 1 to RELAYS 1 4 1 4 ESSAGE ZONE 1 Range 0 1 to 500 0 Osec in steps of 0 1 I REACH 10 0 Qsec ESSAGE ZONE 1 Range 50 to 85 in steps of 1 I ANGLE 75 ESSAGE Range 0 0 to 150 0 s in steps of 0 1 gt DELAY 0 4 s pomis E gt zoNE 2 Range Off Latched Unlatched TRIP Off lt ASSIGN ZONE 2 TRIP Range Any combination of Relays 1 to RELAYS 1 4 1 4 ESSAGE 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS MESSAGE ZONE 2 Range 0 1 to 500 0 Qsec in steps of 0 1 REACH 15 0 Qsec MESSAGE ZONE 2 Range 50 to 85 in steps of 1 ANGLE 75 ZONE 2 TRIP Range 0 0 to 150 0 s in steps of 0 1 DELAY 2 0 s MESSAGE The distance protection function ANSI device 21 implements two zones of mho phase to phase distance protection six elements to
282. lways be longer than the longest delay on line protection downstream GENERATOR CORE ge c CORE Phase CTs BREAKER BALANCE Er BALANCE 5 i s f 5 N a VA S S f N 2 Option 5 NL similar to Option 3 rica Option 1 Option 4 un 489 Option 4 lt d m 7 Ground current input Ground from one of the five Overcurrent options Element 808736A1 CDR FIGURE A 3 Ground Overcurrent Element with Different Current Source Signals A 1 4 Ground Directional Element The 489 can detect internal stator ground faults using a Ground Directional element implemented using the and the ground current inputs The voltage signal is obtained across the grounding impedance of the generator The ground or zero sequence current is obtained from a core balance CT as shown below due to CT inaccuracies it is generally not possible to sum the outputs of the conventional phase CTs to derive the generator high side zero sequence current for an impedance grounded generator If correct polarities are observed in the connection of all signals to the relay the Vpeutral signal will be in phase with the ground current signal The element has been provided with a setting allowing the user to change the plane of operation to cater to reactive grounding impedances or to pola
283. me 2 Metering Data a Instantaneous current measurements including phase neutral and ground rents Instantaneous phase to phase and phase to ground voltages depending on the VT connections average voltage and system frequency Power quantities including apparent real and reactive power Current and power demand including peak values Analog inputs Generator speed System phasors RTD temperatures 3 Learned Data Average magnitudes of generator load negative sequence current and phase phase voltage RTD learned data which includes the maximum temperature measured by each of the twelve 12 RTDs Minimum and maximum values of analog inputs 4 Maintenance data This is useful statistical information that may be used for preventive maintenance It includes a Trip counters 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 1 3 CHAPTER 1 GETTING STARTED b General counters such as number of breaker operations and number of thermal resets c Generator hours online timer 5 Event recorder downloading tool 6 Product information including model number firmware version additional product information and calibration dates 7 Oscillography and data logger downloading tool Alarm trip conditions diagnostics and system flash messages are grouped under Target Messages gt Press the MENU key to access the header of each menu which will be di
284. menu header SETPOINTS gt Press MESSAGE or ENTER SETPOINTS gt 81 489 SETUP Press MESSAGE Y B SETPOINTS D Press B CURRENT D Press PHASE CT PRIMARY 52 SYSTEM SETUP MESSAGE gt SENSING MESSAGE or ENTER or ENTER Press the VALUE keys until 600 A is displayed PHASE CT PRIMARY or enter the value directly via the numeric a keypad Press the ENTER key to store the setpoint NEW SETPOINT HAB BEEN STORED To select the Ground CT type modify the 62 SYSTEM SETUP gt CURRENT SENSING gt V GROUND CT setpoint as shown below gt Press the MENU key until the relay displays the setpoints menu header 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 1 71 SETPOINTS gt Press MESSAGE gt or ENTER SETPOINTS gt 81 489 SETUP Press MESSAGE V MESSAGE p SETPOINTS D gt Press 82 SYSTEM SETUP or ENTER CHAPTER 1 GETTING STARTED CURRENT gt Press PHASE CT PRIMARY SENSING MESSAGE gt 600 A or ENTER Press GROUND CT MESSAGE Y 50 0 025 Press the VALUE keys until lGROUND 1 A Secondary is displayed 1 secondary NEW SETPOINT HAS Press the ENTER key to store the setpoint BEEN STORED 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 1 GETTING STARTED To set the ground CT ratio modify the S2 SYSTEM SETUP gt CURRENT SENSING gt V GROUND CT RATIO setpoint as shown below gt Press the MENU key until the relay displa
285. mmed Range 0 05 to 0 99 or Not ESSAGE bo Programmed Range 100 to 30000 V in steps of 1 ESSAGE or Not Programmed GENERATOR NOMINAL Range 25 Hz 50 Hz 60 Hz or ESSAGE SS FREQUENCY Not Programmed GENERATOR PHASE Range ABC ACB or Not Programmed ESSAGE SEQUENCE As a safeguard when a unit is received from the factory the PHASE CT PRIMARY and Generator Parameters setpoints will be defaulted to indicating they are not programmed The 489 indicates that it was never programmed Once these values are entered the 489 will be in service All elements associated with power quantities are programmed in per unit values calculated from the rated MVA and power factor The generator full load amps FLA is calculated as Generator FLA Generator Rated MVA EQ 0 2 1 3 x Generator Rated Phase Phase Voltage All voltage protection features that require a level setpoint are programmed in per unit of the rated generator phase phase voltage The nominal system frequency must be entered here This setpoint allows the 489 to determine the internal sampling rate for maximum accuracy If the sequence of phase rotation for a given system is ACB rather than the 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 5 19 CHAPTER 5 SETPOINTS standard ABC the system phase sequence setpoint may be used to accommodate this rotation This setpoint allows the 489 to properly calculate phase reversal and negative sequ
286. mmunication ports are not to be tested for dielectric strength under any circumstance see below ORC me WS 62 H1 Ui n 2 amp 5 AUTOMATIC SHORTING TERMINALS PrAse A PrASE B PHASE PHASE GROUND INPUTS NEUTRAL END Gis TAGE RTD SHIELD z HOT CONTROL POWER COMPENSATION 870 1 RTD RETURN COMPENSATION Rro g2 HOT FILTER GROUND HOT COMPENSATION 570 5 2 RTD RETURN GE Multilin COMPENSATION pyp pq HOT RTD 5 489 GE RATOR COMPENSATION RID RETURN MANAG ENT COMPENSATION 6 m em RELAY COMPENSATION RTD RETURN COMPENSATION COMPENSATION 870 9 RETURN 2 AUXILIARY COMPENSATION RTD 10 HOT 3 AUXILIARY COMPENSATION 870 411 RTD RETURN COMPENSATION 4 AUXILIARY HOT RTD 12 war SAFETY GROUND T x RTD 8 A DO NOT HIPOT TEST x HIPOT TEST AT 1900 VAC for 1 Second OR 1600 V AC FOR 1 MINUTE AS PER UL 508 w REMOVE FILTER GROUND G11 DURING TEST 5 ALARM ASSIGNABLE INPUT 1 ASSIGNABLE INPUT 2 ASSIGNABLE INPUT 3 ASSIGNABLE INPUT 4 6 SERVICE ASSIGNABLE INPUT 5 ASSIGNABLE INPUT 6 A
287. mpatible third party software gt Ensure that the sample rate is not less than 5 seconds otherwise some data may not get written to the file Trending File Setup X Filename Program Files GE Power Manag Cancel Limit File Capacity To H K Samples Approximate File Size 0 01 MB NOTE If Sample Rate is less than 5 secs some data may not get written to the file 4 38 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 4 INTERFACES To limit the size of the saved file gt Enter a number in the Limit File Capacity To box The minimum number of samples is 1000 At a sampling rate of 5 seconds or 1 sample every 5 seconds the file will contain data collected during the past 5000 seconds The EnerVista 489 Setup software will automatically estimate the size of the trending file gt Press Run to start the data logger If the Log Samples to File item is selected the EnerVista 489 Setup software will begin collecting data at the selected sampling rate and will display it on the screen The data log will continue until the Stop button is pressed or until the selected number of samples is reached whichever occurs first During the process of data logging the trending screen appears as shown below SAVE DATA TO FILE MODE SELECT BUTTONS Select to save the Select to view Cursor 1 Zoom In enlarges the graph information to a CSV Cursor 2 or the Delta Zoom Out shrinks the graph file on the PC diffe
288. n steps of 0 1 LEVEL 0 5 Vsec ESSAGE NEUTRAL UNDERVOLTAGE Range 5 to 120 s in steps of 1 ALARM DELAY 30 s ESSAGE NEUTRAL UNDERVOLTAGE Range On Off ALARM EVENTS Off ESSAGE NEUTRAL UNDERVOLTAGE Range Off Latched Unlatched TRIP Off ESSAGE ASSIGN TRIP Range Any combination of Relays 1 to ESSAGE 4 RELAYS 1 4 1 NEUTRAL U V TRIP Range 0 5 to 20 0 Vsec in steps of 0 1 LEVEL 1 0 Vsec ESSAGE NEUTRAL UNDERVOLTAGE Range 5 to 120s in steps of 1 TRIP DELAY 30 s ESSAGE 06009 00 00 09 09 07 09 02 The LOW POWER BLOCKING LEVEL NEUTRAL U V ALARM LEVEL And NEUTRAL U V TRIP LEVEL setpoints are seen only if the S2 SYSTEM SETUP gt V VOLTAGE gt V VT CONNECTION setpoint is Delta The neutral undervoltage function responds to 3rd harmonic voltage measured at the generator neutral and output terminals When used in conjunction with the Neutral Overvoltage fundamental frequency function it provides 10096 ground fault protection of the stator windings For Wye connected VTs Since the amount of third harmonic voltage that appears in the neutral is both load and machine dependent the protection method of choice is an adaptive method If the phase VT connection is wye the following formula is used to create an adaptive neutral undervoltage pickup level based on the amount of third harmonic that appears at the generator terminals A EQ 5 24 Vos 3 Vus ware
289. n steps of 0 1 Pickup accuracy as per voltage and phase current inputs Timing accuracy 100 ms or 0 5 of total time Elements Trip 2 zones using impedance circles NEGATIVE SEQUENCE OVERCURRENT Pickup level 3 to 100 FLA in steps of 1 Curve shapes trip defined by definite time alarm Time delay 0 1 to 100 0 s in steps of 0 1 Pickup accuracy as per phase current inputs Timing accuracy 100ms or 0 5 of total time Elements Trip and Alarm NEUTRAL OVERVOLTAGE FUNDAMENTAL Pickup level 2 0 to 100 0 V secondary in steps of 0 01 Time delay 0 1 to 120 0 steps of 0 1 Pickup accuracy as per neutral voltage input Timing accuracy 100 ms or 0 596 of total time Elements Trip and Alarm NEUTRAL UNDERVOLTAGE 3RD HARMONIC Blocking signals low power and low voltage if open delta Pickup level 0 5 to 20 0 V secondary in steps of 0 01 if open delta VT adaptive if wye VT Time delay 5to 120s in steps of 1 Pickup accuracy as per Neutral Voltage Input Timing accuracy 3 05 Elements Trip and Alarm OFFLINE OVERCURRENT Pickup level 0 05 to 1 00 x CT in steps of 0 01 of any one phase Time delay 3 to 99 cycles in steps of 1 Pickup accuracy as per phase current inputs Timing accuracy 50ms at 50 60 Hz Elements Trip OTHER FEATURES Serial Start Stop Initiation Remote Reset configurable digital input Test Input configurable digital input Thermal Reset configurable digital input Dual
290. nd Trip Coil Supervision Accuracy Test 8 Analog Input and Outputs Test 9 Output Relay Test 10 Overload Curve Test 11 Power Measurement Test 12 Reactive Power Test 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 7 8 15 14 15 16 17 18 19 CHAPTER 7 TESTING Voltage Phase Reversal Test For the following tests refer to Secondary Injection Setup 2 on page 7 15 GE Multilin HGF Ground Current Accuracy Test Neutral Voltage 3rd Harmonic Accuracy Test Phase Differential Trip Test For the following test refer to Secondary Injection Test Setup 3 on page 7 19 Voltage Restrained Overcurrent Test 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 7 TESTING RTD SIMULATION RESISTORS OR RESISTANCE DECADE BOX ny 500 Ohms 500 Ohms 500 Ohms 500 Ohms 500 Ohms 500 Ohms 500 Ohms 500 Ohms 500 Ohms 500 Ohms 500 Ohms 500 Ohms 3 PHASE VARIABLE AC TEST SET Va W Ve W fase ae as vo gt PHASE a PHASE b PHASE GROUND INPUTS PHASE a PHASE D PHASE NEUTRAL END CT s 4 7 A13 4 7 8 12 13 p14 a a 3 S PN PN PN NEUTRAL RTD SHIELD HOT COMPENSATION RTD RETURN COMPENSATION x 5 8 COMPENSATION RTD RETURN e AUS
291. ne and NEUTRAL VOLTAGE TRANSFORMER iS No in S2 SYSTEM the THIS FEATURE NOT PROGRAMMED flash message will appear when an attempt is made to enter this group of messages 6 3 3 Power Metering PATH ACTUAL VALUES gt V 2 METERING DATA gt V POWER METERING POWER D POWER FACTOR Range 0 01 to 0 99 Lead or Lag 0 00 METERING 0 00 100 REAL POWER Range 0 000 to x2000 000 MW I 0 000 MW REACTIVE POWER Range 0 000 to 2000 000 Mvar I 0 000 Mvar APPARENT POWER Range 0 000 to 2000 000 MVA I 0 000 MVA lt PosrTIVE WATTHOURS Range 0 000 to 4000000 000 MWh I lt 0 000 MWh POSITIVE VARHOURS Range 0 000 to 4000000 000 Mvarh I 0 000 Mvarh NEGATIVE VARHOURS Range 0 000 to 4000000 000 Mvarh A 0 000 Mvarh The values for power metering appear here Three phase total power quantities are displayed here Watthours and varhours are also shown here Watthours and varhours will not update if a digital input programmed as Test Input is shorted iy An induction generator by convention generates Watts and consumes vars W vars A synchronous generator can also generate vars vars NOTE If the CONNECTION is programmed as None the THIS FEATURE NOT PROGRAMMED flash message will appear when an attempt is made to enter this group of messages 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 6 ACTUAL VALUES 6 3 4 Temperature PATH ACTUAL VALU
292. nel could reset such a critical trip gt Assign only Short Circuit and Ground Fault to relay 2 gt Program relay 2 to Remote Reset Only 5 28 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS 5 6 55 Current Elements 5 6 1 Inverse Time Overcurrent Curve Characteristics Description The 489 inverse time overcurrent curves may be either ANSI or GE Type IAC standard curve shapes This allows for simplified coordination with downstream devices If however none of these curve shapes is adequate the FlexCurve may be used to customize the inverse time curve characteristics Definite time is also an option that may be appropriate if only simple protection is required Table 5 1 489 Overcurrent Curve Types ANSI Other Extremely Inverse Curve BS142 Extremely Inverse FlexCurve Very Inverse Curve B BS142 Very Inverse Definite Time Normally Inverse Curve 5142 Inverse Moderately Inverse Short Inverse Short Inverse A multiplier setpoint allows selection of a multiple of the base curve shape that is selected with the curve shape setpoint Unlike the electromechanical time dial equivalent trip times are directly proportional to the time multiplier setting value For example all trip times for a multiplier of 10 are 10 times the multiplier 1 or base curve values Setting the multiplier
293. nfigured for serial communications Proceed to Connecting to the Relay on page 4 19 to begin communications 4 3 2 Using the Quick Connect Feature The Quick Connect button can be used to establish a fast connection through the front panel RS232 port of a 489 relay 4 16 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 4 INTERFACES gt Press the Quick Connect button The following window will appear Quick Connect Quickly connect 489 Setup to a 489 Device through the 489 s front port at 9600 N 8 1 Select your Computer s COM Port EE y ea As indicated by the window the Quick Connect feature quickly connects the EnerVista 489 Setup software to a 489 front port with the following setpoints 9600 baud no parity 8 bits 1 stop bit gt Select the PC communications port connected to the relay gt Press the Connect button The EnerVista 489 Setup software will display a window indicating the status of communications with the relay When connected a new Site called Quick Connect will appear in the Site List window The properties of this new site cannot be changed 7 enervista 489Setup Active Screen File Setpoint Actual Communications View Help W i 8 amp H 2 lt Pumping Station 1 Pumping Station 2 Quick Connect 489 Quick Connect Device Definition Settings Actual Values Communications
294. ng elements that are picked up operating or latched When the Message LED is on there are messages to be viewed with the MENU key by selecting target messages as described Entering Alphanumeric Text Text setpoints have data values that are fixed in length but user defined in character They may be comprised of upper case letters lower case letters numerals and a selection of special characters The editing and storing of a text value is accomplished with the use of the decimal VALUE and ENTER keys gt Moveto message S3 DIGITAL INPUTS gt V GENERAL INPUT gt ASSIGN DIGITAL INPUT and scrolling with the VALUE keys select Input 1 The relay will display the following message ASSIGN DIGITAL INPUT Input 1 Press the MESSAGE V key to view the INPUT NAME Setpoint The name of this user defined input will be changed in this example from the generic Input A to something more descriptive If an application is to be using the relay as a station monitor it is more informative to rename this input Stn Monitor gt Press the decimal to enter the text editing mode The first character will appear underlined as follows INPUT NAME Input A gt Pressthe VALUE keys until the character S is displayed in the first position Press the decimal key to store the character and advance the cursor to the next position Change the second character to a t in the same manner Continue enteri
295. ng characters in this way until all characters of the text Stn Monitor are entered Note that a space is selected like a character If a character is entered incorrectly press the decimal key repeatedly until the cursor returns to the position of the error Re enter the character as required Once complete press the ENTER key to remove the solid cursor and view the result Once a character is entered by pressing the ENTER key it is automatically saved in Flash Memory as a new setpoint INPUT NAME Stn Monitor 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 4 5 CHAPTER 4 INTERFACES The 489 does not have or keys Negative numbers may be entered one of two manners Immediately pressing of the VALUE keys causes the setpoint to scroll through its range including any negative numbers After entering at least one digit of a numeric setpoint value pressing the VALUE keys changes the sign of the value where applicable 4 1 5 Setpoint Entry To store any setpoints terminals C1 and C2 access terminals must be shorted a keyswitch may be used for security There is also a setpoint passcode feature that restricts access to setpoints The passcode must be entered to allow the changing of setpoint values A passcode of 0 effectively turns off the passcode feature in this case only the access jumper is required for changing setpoints If no key is pressed for 5 minutes access to setpoint valu
296. nitude of power measurement is determined by the phase CT minimum of 2 rated CT primary If the level for reverse power is set below that level a trip or alarm will only occur once the phase current exceeds the 296 cutoff 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS Users are cautioned that a reverse power element may not provide reliable indication when set to a very low setting particularly under conditions of large reactive loading on the generator Under such conditions low forward power is a more reliable element 5 8 4 Low Forward Power PATH SETPOINTS D gt V S7 POWER ELEMENTS gt V LOW FORWARD POWER 1 LOW FORWARD POWER ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE gt 9 lt gt gt lt gt lt gt lt gt lt gt gt lt gt lt gt gt lt gt gt lt gt BLOCK LOW FWD POWER FROM ONLINE 0 s LOW FORWARD POWER ALARM Off ASSIGN ALARM RELAYS 2 5 5 LOW FWD POWER ALARM LEVEL 0 05 x Rated LOW FWD POWER ALARM DELAY 10 0 LOW FWD POWER ALARM EVENTS Off LOW FORWARD POWER TRIP Off ASSIGN TRIP RELAYS 1 4 1 u i Range Range Range Range Range Range Range Range LOW FWD POWER TRIP Range LEVEL 0 05 x Rated LOW FWD POWER TRIP DELAY 20 0 s Range Oto 15000 s in steps of 1 Off Latched Unlatched Any combination of
297. nu set NEUTRAL VOLTAGE TRANSFORMER Yes NEUTRAL RATIO 10 00 1 In the S2 SYSTEM SETUP D V GEN PARAMETERS menu set GENERATOR NOMINAL FREQUENCY 60 Hz Measured values should be 5 0 V gt Apply the voltage values shown in the table and verify accuracy of the measured values View the measured values in the A2 METERING DATA gt V VOLTAGE METERING menu Applied Neutral Voltage Expected Neutral Voltage Measured Neutral at 180 Hz Voltage 10V 100V 30V 300V 50V 500 V 7 3 8 Phase Differential Trip Accuracy v NOTE These tests will require a dual channel current source The unit must be capable of injecting prefault currents and fault currents of a different value Application of excessive currents greater than 3 x CT for extended periods will cause damage to the relay 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 7 TESTING Minimum Pickup Check gt gt gt Connect the relay test set to inject Channel X current into the G3 terminal and out of H3 terminal Phase Increase until the differential element picks up Record this value as pickup Switch off the current The theoretical pickup can be computed as follows lypy Pickup setting x CT EQ 7 5 Single Infeed Fault gt V V V V V V V V V Slope 1 Check gt gt Set the prefault current equal to 0 Set the fault current equal to CT
298. o 6 3 ABARNMUPICKUPS pee E dE 6 12 Dulddilid m 3 17 5 28 ALARM STATUS stetit ceste E te ON Medius 6 6 AEARMS cric I E ME hu S 5 6 5 7 ANALOG IN MIN MAX iicet tette ett teet tere N 6 23 ANALOG INPUTS 3 14 5 eaves 6 20 6 23 ANGLO GIP 5 17 6 23 MINIMUMS GAG maxim lris J uu idis 5 23 5 98 SPECICATION EET 2 6 STING UTEM 7 9 ANALOG OUTPUTS iiie eet a dte semp te ER 3 15 SOLPOINTS E 5 96 SBeGIICCUDDINS 2 7 ejm 5 97 Cp M CHE 7 9 ANSI GURVES UL ps 5 30 15 ANSI DEVICE NUMBERS tet i iet ree eg eR iis 2 2 APPLICATION NOTES Current transfor MEFS E P A 11 Stator ground pese ebd eb dr qe A 1 AUXILIARY RELAY diio trece e Fade be Pura Pede de dpt epist 3 17 5 28 B BAUD RATE e E 2 14 5 12 cuc HM 5 13 BREAKER FAILURE deena 5 90 BREAKER STATUS 5 21 BURDEN Z Z u u u uum m Sua Qata ha
299. o If any of the terminal currents is above 596 of CT nominal the timer is by passed Also if any of the neutral side current is above 5 times CT nominal the timer is by passed as well In this logic the current magnitudes are filtered fundamental frequency components T stands for terminal side currents and N stands for neutral side currents PKP denotes the pickup state of the element prior to any user set delay that may or may not be used ina particular application A B and C designate phases The differential element works as follows With the machine under load the terminal currents are above 596 of CT nominal and no delay is applied to the differential function With the machine on line but with no load below 596 the delay is applied However should a fault occur at that time at least one of the terminal current would get elevated cancelling the delay and resulting in an instantaneous trip With the opposite breaker being closed as in the considered dual breaker application a current is drawn either transformer inrush or load or both This will activate the differential characteristic However the timer remains engaged because all the terminal currents are zero and all the neutral side currents ABC are below 5 times CT nominal The timer keeps timing out However before it expires the relay switches to group 2 and blocks the differential f
300. ock time indicates that the overfrequency protection is active as soon as voltage exceeds the cutoff level programmed as a multiple of the generator rated phase phase voltage Frequency is then measured Once the frequency of Vab exceeds the overfrequency setpoints for the period of time specified a trip or alarm will occur There are dual level and time setpoints for the trip element 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS 5 7 7 Neutral Overvoltage 1 NEUTRAL PATH SETPOINTS V S6 VOLTAGE ELEM gt V NEUTRAL O V FUNDAMENTAL FUNDAMENTAL gt SUPERVISE WITH Range Yes No DIGITAL INPUT No lt gt v NOTE NEUTRAL OVERVOLTAGE Range Off Latched Unlatched ALARM Off m ASSIGN ALARM Range Any combination of Relays 2 to RELAYS 2 5 5 5 ESSAGE NEUTRAL O V ALARM Range 2 0 to 100 0 Vsec in steps of 0 1 ESSAGE LEVEL 3 0 Vsec lt NEUTRAL OVERVOLTAGE Range 0 1 to 120 0 s in steps of 0 1 ALARM DELAY 1 0 s NEUTRAL OVERVOLTAGE Range On Off ALARM EVENTS Off NEUTRAL OVERVOLTAGE Range Off Latched Unlatched TRIP Off ASSIGN TRIP Range Any combination of Relays 1 to RELAYS 1 4 1 4 ee NEUTRAL O V TRIP Range 2 0 to 100 0 Vsec in steps of 0 1 x LEVEL 5 0 Vsec 2 NEUTRAL OVERVOLTAGE Range 0 1 to 120 0 s in steps of 0 1 TRIP DELAY 1 0 s essace NEUTRAL O V CURV
301. ommunications established gt Select the Actual gt A4 Event Recorder item from the main menu This displays the Event Recorder window indicating the list of recorded events with the most current event displayed first EVENT LISTING EVENT SELECTION EVENT NUMBER CLEAR EVENTS Lists the last 256 Select an event row to view The event data Click the Clear events with the most event data information information is related Events button to recent displayed at which will be displayed in to the selected event clear the event list the window to the right as shown from memory top of list Event Recorder Quick Connect 4 3 Quick Connect Actual Values Event Rzcorder onmens 10383595 g rtrol Power Lost 0718006 10355811 Cont Power 09045211 09045121 DEVICE ID EVENT DATA SAVE EVENTS The events shown System information as Click the Save Events here correspond to measured by the relay at button to save the event the device shown the instant of the event record to the PC as a occurrence CSV file FIGURE 4 8 Event Recorder Window shown unconnected 4 40 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 4 INTERFACES To view detailed information for a given event and the system information at the moment of the event occurrence gt Change the event number on the Select Event box 4 6 6 Modbus User The EnerVista 489 Setup software provides a means to program the 48
302. otective relays When the generator is running the rotor will rotate in the direction of the positive sequence current at near synchronous speed Negative sequence current which has a phase rotation that is opposite to the positive sequence current and hence opposite to the rotor rotation will generate a rotor voltage that will produce a substantial rotor current This induced current will have a frequency that is approximately twice the line frequency 100 Hz for a 50 Hz system or 120 Hz for a 60 Hz system Skin effect in the rotor bars at this frequency will cause a significant increase in rotor resistance and therefore a 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS significant increase in rotor heating This extra heating is not accounted for in the thermal limit curves supplied by the generator manufacturer as these curves assume positive sequence currents only that come from a perfectly balanced supply and generator design The 489 measures the ratio of negative to positive sequence current The thermal model may be biased to reflect the additional heating that is caused by negative sequence current when the machine is running This biasing is done by creating an equivalent heating current rather than simply using average current This equivalent current is calculated using the equation shown below leq i EQ 5 32 where leg equivalent motor heating current in per unit based on FLA
303. ove environmental considerations the relay should be stored in an environment that is dry corrosive free and not in direct sunlight Correct storage Prevents premature component failures caused by environmental factors such as moisture or corrosive gases Exposure to high humidity or corrosive environments will prematurely degrade the electronic components in any electronic device regardless of its use or manufacturer unless specific precautions such as those mentioned in the Environmental section above are taken iy It is recommended that all relays be powered up once per year for one hour continuously to avoid deterioration of electrolytic capacitors and subsequent relay failure NOTE 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL Digital Energy Multilin 489 Generator Management Relay Chapter 3 Installation 3 1 Mechanical Installation 3 1 1 Description The 489 is packaged in the standard GE Multilin SR series arrangement which consists of a drawout unit and a companion fixed case The case provides mechanical protection to the unit and is used to make permanent connections to all external equipment The only electrical components mounted in the case are those required to connect the unit to the external wiring Connections in the case are fitted with mechanisms required to allow the safe removal of the relay unit from an energized panel such as automatic CT shorting The unit is mechanically held in the case b
304. ow the undervoltage pickup level and the unit is offline This would be the case when the VTs are on the generator side of the disconnect device If however the VTs are on the power system side of the disconnect device the feature should be armed if all of the phase voltages fall below the undervoltage pickup level or the unit is offline When the feature is armed if any one of the phase currents measured at the output CTs exceeds the overcurrent level programmed a trip will occur iy This feature requires 5 seconds to orm 250 ms to disorm NOTE Protection can be provided for poor synchronization by using the U V or Offline arming signal During normal synchronization there should be relatively low current measured If however synchronization is attempted when conditions are not appropriate a large current that is measured within 250 ms after the generator is placed online would result in a trip Iphase gt O C Level Operate Vphase lt U V Level Breaker Status Offline oR Arming Signal U V or Offline FIGURE 5 1 Inadvertent Energization Logic 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS 5 6 5 1 PHASE OVERCURRENT v NOTE Phase Overcurrent PATH SETPOINTS D V S5 CURRENT ELEM gt V PHASE OVERCURRENT b PHASE OVERCURRENT Range Off Latched Unlatched TRIP Off ASSIGN TRIP Range Any combination of Relays 1 to ESSAGE RELAYS 1 4 1 4
305. ow will appear requesting for file name and path The file is saved as a CSV comma delimited values file which can be viewed and manipulated with compatible third party software To view a previously saved file gt Click the Open button and select the corresponding CSV file To view the captured waveforms gt Click the Launch Viewer button A detailed Waveform Capture window will appear as shown below TRIGGER TIME amp DATE CURSOR LINE POSITION Display the time amp date of the VECTOR DISPLAY SELECT Indicate the cursor line position Trigger Click here to open a new graph in time with respect to the to display vectors trigger time DELTA Indicates time difference between the two cursor lines bem een AA AAAAAAAAAAAAAA VV dk VVVV VV WA V eee dn Bl 6 AU Ground Current VV d A l WWW Se _ EM Ee a MA T m pw Mo File CADocuments and Settings 10001352 Documents 760 Wavetorm Capture EE Display graph values CURSOR at the corresponding FILE NAME LINES TRIGGER LINE cursor line Cursor Indicates the To move lines locate the mouse pointer Indicates the lines are identified by file name and over the cursor line then click and drag point in time for their colors complete path the cursor to the new location the trigge
306. owing methods 1 Front panel using the keys and display 2 Front program port and a portable computer running the EnerVista 489 Setup software supplied with the relay 3 Rearterminal RS485 port and a PLC SCADA system running user written software Any of these methods can be used to view the same information However a computer makes viewing much more convenient since many variables may be viewed simultaneously Actual value messages are organized into logical groups or pages for easy reference as shown below All actual value messages are illustrated and described in blocks throughout this chapter All values shown in these message illustrations assume that no inputs besides control power are connected to the 489 In addition to the actual values there are also diagnostic and flash messages that appear only when certain conditions occur They are described later in this chapter 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 6 3 CHAPTER 6 ACTUAL VALUES 6 2 Ai Status 6 2 1 Network Status PATH ACTUAL VALUES D A1 STATUS D V NETWORK STATUS NETWORK STATUS P A Ethernet Lnk Con Dia Range see description below 9 Status This actual value appears when the relay is ordered with the Ethernet T option The ETHERNET STATUS actual value message indicates the status of the Ethernet link connection and diagnostic via three indicators The tm symbol indicates on and the 1 symbol ind
307. p Not Enabled Inactive Timing Out Active Trip Latched Trip Not Enabled Inactive Timing Out Active Trip Latched Trip 6 9 CHAPTER 6 ACTUAL VALUES I TACHOMETER Range Not Enabled Inactive Timing ESSAGE 5 PICKUP Not Enabled Out Active Trip Latched Trip I OFFLINE OVERCURRENT Range Not Enabled Inactive Timing ESSAGE Z PrcKUP Not Enabled Out Active Trip Latched Trip I lt INADVERTENT ENERG Range Not Enabled Inactive Timing ESSAGE PICKUP Not Enabled Out Active Trip Latched Trip I PHASE OVERCURRENT Range Not Enabled Inactive Timing ESSAGE IPICKUP Not Enabled Out Active Trip Latched Trip _ lt NEG SEQ OVERCURRENT Range Not Enabled Inactive Timing ESSAGE IPICKUP Not Enabled Out Active Trip Latched Trip I GROUND OVERCURRENT Range Not Enabled Inactive Timing ESSAGE gt pIcKUP Not Enabled Out Active Trip Latched Trip I _ gt PHASE DIFFERENTIAL Range Not Enabled Inactive Timing ESSAGE IPICKUP Not Enabled Out Active Trip Latched Trip I GROUND DIRECTIONAL Range Not Enabled Inactive Timing ESSAGE Z IPICKUP Not Enabled Out Active Trip Latched Trip I gt HIGH SET PHASE O C Range Not Enabled Inactive Timing ESSAGE PrcKUP Not Enabled Out Active Trip Latched Trip I UNDERVOLTAGE Range Not Enabled Inactive Timing ESSAGE PICKUP Not Enabled Out Active Trip Latched Trip _ ovERVO
308. pe1 if ls lt 2 x CT k Slope2 if ln 2 2 x CT EQ 5 15 I phase current measured at the output CT EQ 5 16 I phase current measured at the neutral end CT EQ 5 17 Differential elements for phase B and phase C operate in the same manner 0 9 0 8 0 7 Slope 2 20 OPERATE 06 REGION 0 5 4 0 4 7 0 3 0 2 OPERATE multiples of CT Slope 1 10 5 6 9 Ground Directional Minimum Pickup 0 10 x CT 0 1 IEEE RE 0 0 5 1 1 5 2 2 5 3 3 5 4 4 5 5 I RESTRAINT multiples of CT 808790A2 CDR FIGURE 5 4 Differential Elements PATH SETPOINTS gt S5 CURRENT ELEM gt V GROUND DIRECTIONAL 1 GROUND 51 SUPERVISE WITH Range Yes No DIRECTIONAL DIGITAL INPUTS Yes ESSAGE ESSAGE ESSAGE ESSAGE Range 0 90 180 270 MTA Maximum Torque Angle GROUND DIRECTIONAL MTA 0 GROUND DIRECTIONAL Range Off Latched Unlatched ALARM Off ASSIGN ALARM Range Any combination of Relays 2 to RELAYS 2 5 5 5 GROUND DIR ALARM Range 0 05 to 20 00 x CT in steps of PICKUP 0 05 x 0 01 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS GROUND DIR ALARM Range 0 1 to 120 0 sec in steps of 0 1 DELAY 3 0 sec ESSAGE GROUND DIR ALARM Range On Off EVENTS Off GROUND DIRECTIONAL Range Off Latched Unlatched TRIP Off ASSIGN TRIP Range Any combination of Relays 1 to ESSAGE RELAYS 1 4
309. per RTDs Shielded cable should be used to prevent noise pickup in the industrial environment RTD cables should be kept close to grounded metal casings and avoid areas of high electromagnetic or radio interference RTD leads should not be run adjacent to or in the same conduit as high current carrying wires 489 RELAY SHIELD BN COMPENSATION A 3 WIRE SHIELDED CABLE Route cable in separate conduit from current carrying conductors RTD TERMINALS AT GENERATOR NG RTD IN GENERATOR STATOR RTD SENSI RTD 1 OR BEARING lelle OPTIONAL GROUND RTD Shield is internally TERMINALS Maximum total lead resistance connected to safety 25 ohms Platinum amp Nickel RTDs ground terminal G12 3 ohms Copper RTDs 808761E4 CDR FIGURE 3 17 RTD Wiring IMPORTANT NOTE The RTD circuitry is isolated as a group with the Analog Input circuitry and the Analog Output circuitry Only one ground reference should be used for the three circuits Transorbs limit this isolation to 36 V with respect to the 489 safety ground If code requires that the RTDs be grounded locally at the generator terminal box that will also be the ground reference for the analog inputs and outputs 3 2 10 Output Relays There are six Form C output relays see Outputs on page 2 7 Five of the six relays are always non failsafe the 6 Service relay is always failsafe As a failsafe the 6 Service relay will be
310. point Files 4 4 1 Engaging a Device The EnerVista 489 Setup software may be used in on line mode relay connected to directly communicate with a 489 relay Communicating relays are organized and grouped by communication interfaces and into sites Sites may contain any number of relays selected from the SR or UR product series 4 4 2 Entering Setpoints The System Setup page will be used as an example to illustrate the entering of setpoints In this example we will be changing the current sensing setpoints gt Establish communications with the relay gt Select the Setpoint gt System Setup menu item This can be selected from the device setpoint tree or the main window menu bar gt Select the Current Sensing menu item gt Select the PHASE CT PRIMARY Setpoint by clicking anywhere in the parameter box This will display three arrows two to increment decrement the value and another to launch the numerical calculator current Sensing Quick Connect 489 Quick I xl Current Sensing SETTING PARAMETER PHASE CURRENT Save Phase CT Primary EE GROUND CURRENT Ground CT Secondary Default Ground CT Ratio 100 5 25 Restore 489 Quick Connect Settings System Setup 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 4 21 CHAPTER 4 INTERFACES gt Click the arrow at the end of the box to display a numerical keypad interface that allow
311. quirements The asserted state and the name of the digital inputs are programmable To disable the input functions when the generator is offline until some time after the generator is brought online a block time should be set The input functions will be enabled once the block delay has expired A value of 0 s for the BLOCK INPUT FROM ONLINE block time indicates that the input functions are always enabled while the generator is offline as well as online 9 22 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS Inputs may be configured for control alarm or trip If the control feature is enabled the assigned output relay s operate when the input is asserted If the PULSED CONTROL RELAY DWELL TIME is set to 0 the output relay s operate only while the input is asserted However if a dwell time is assigned the output relay s operate as soon as the input is asserted for a period of time specified by the setpoint If an alarm or trip is enabled and the input is asserted an alarm or trip will occur after the specified delay 5 4 4 Remote Reset PATH SETPOINTS D V S3 DIGITAL INPUTS gt V REMOTE RESET REMOTE RESET D ASSIGN DIGITAL Range None Input 1 Input 2 Input 3 INPUT None Input 4 Input 5 Input 6 Input 7 5 45 Test Input Once an input is assigned to the Remote Reset function shorting that input will reset any latched trips or alarms that may be active provided that any thermal lockout
312. r if saved FIGURE 4 6 Waveform Capture Window Attributes The red vertical line indicates the trigger point of the relay The date and time of the trigger is displayed at the top left corner of the window To match the captured waveform with the event that triggered it gt Make note of the time and date shown in the graph gt Find the event that matches the same time and date in the event recorder 4 34 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 4 INTERFACES The event record will provide additional information on the cause and the system conditions at the time of the event Additional information on how to download and save events is shown in Event Recorder on page 4 40 gt From the window main menu bar press the Preference button to open the Setup page to change the graph attributes J enerVista 489Setup Active Screen Waveform C DOCUME 1 410001 1 LOCALS 1 Temp File Setpoint Actual Communications View Help aS c s The following window will appear Comtrade Setup CHANNEL IDENTIFIER COLOR SCALE GROUP LINE STYLE DISPLAY ORDER Solid Phasela Fhaseib J Phase la Neutral MENIH Phase Ib Neutral ESEmN Phase lc Neutral L Ground Current WNNNG PhaseVan Phasevbn MENEE PhaseVcn _ 4 gt A Comments m Graph Display Iv Display Axis Names C ms dd hh mm ss sss p
313. r processor Pentium 400 MHz or better recommended e Microsoft Windows 95 98 98SE ME NT 4 0 SP4 or higher 2000 e Internet Explorer version 4 0 or higher required libraries 128 MB of RAM 256 MB recommended Minimum of 200 MB hard disk space A list of qualified modems for serial communications is shown below e US Robotics external 56K Faxmodem 5686 US Robotics external Sportster 56K X2 e PCTEL 2304WT V 92 MDC internal modem After ensuring these minimum requirements use the following procedure to install the EnerVista 489 Setup software from the enclosed GE EnerVista CD 4 12 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 4 INTERFACES JE GE Multilin Insert the GE EnerVista CD into your CD ROM drive Click the Install Now button and follow the installation instructions to install the no charge EnerVista software on the local PC When installation is complete start the EnerVista Launchpad application Click the IED Setup section of the Launch Pad window LAUNCH PAD In the EnerVista Launch Pad window click the Add Product button and select the 489 Generator Management Relay from the Install Software window as shown below Select the Web option to ensure the most recent software release or select CD if you do not have a web connection Click the Add Now button to list software items for the 489 Q 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL
314. rammed distance characteristic angle variable angle on the R X plane at point i for which boundary impedance is to be calculated EQ 7 10 It is recommended that voltage is kept constant while increasing the current magnitude at certain angles referenced to voltage phase A until element operates Then the expected operating current assuming that current in the two phases are 180 apart can be calculated as EN 0 where Z Z x P 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL EQ 7 11 CHAPTER 7 TESTING 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL Digital Energy Multilin 489 Generator Management Relay Appendix A 1 Stator Ground Fault A 1 1 Description This application note describes general protection concepts and provides guidelines on the use of the 489 to protect a generator stator against ground faults Detailed connections for specific features must be obtained from the relay manual Users are also urged to review the material contained in the 489 manual on each specific protection feature discussed here CAUTION The 489 Generator Management Relay offers a number of elements to protect a generator against stator ground faults Inputs are provided for a neutral point voltage signal and for a zero sequence current signal The zero sequence current input can be into a nominal 1A secondary circuit or an input reserved for a special GE Multilin type HGF ground CT for very sensitive
315. ransformer or a sudden change of load could cause a large dc offset on even very small currents that would saturate poor quality or mismatched CTs within a few power system cycles In order to provide additional security against maloperations during these events an internal flag SC is set when either an ac or a dc saturation condition is indicated Once the SC flag has been set a comparison of the phase angles of the currents on either side of the generator is carried out An external fault is inferred if the phase comparison indicates both currents are flowing in the same direction An internal fault is inferred if the phase comparison indicates that the currents are flowing in opposite directions In this case an internal flag DIR is set If the SC flag is not set then the relay will operate for a DIFF flag alone If the SC flag is set then the directional flag supervises the differential flag The requirement for both the DIFF flag and the DIR flag during the period where CT saturation is likely therefore enhances the security of the scheme 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 2 39 5 40 CHAPTER 5 SETPOINTS The differential element for phase A will operate when I gt kxl operate restraint EQ 5 12 where the following hold loperate 1 operate current EQ 5 13 restraint t restraint 5 restraint curren EQ 5 14 k 2 characteristic slope of the differential element in percent k Slo
316. reloaded back into the relay See Loading Setpoints from a File on page 4 28 for details Modbus addresses assigned to firmware modules features settings and corresponding data items i e default values min max values data type and item size may change slightly from version to version of firmware The addresses are rearranged when new features are added or existing features are enhanced or modified The EEPROM DATA ERROR message displayed after upgrading downgrading the firmware is a resettable self test message intended to inform users that the Modbus addresses have changed with the upgraded firmware This message does not signal any problems when appearing after firmware upgrades 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 4 INTERFACES 4 6 Advanced EnerVista 489 Setup Features 4 6 1 Triggered Events While the interface is in either on line or off line mode data generated by triggered specified parameters can be viewed and analyzed via one of the following Event Recorder The event recorder captures contextual data associated with the last 256 events listed in chronological order from most recent to the oldest Oscillography The oscillography waveform traces provide a visual display of power system and relay operation data captured during specific triggered events 4 6 2 Waveform Capture Trace Memory The EnerVista 489 Setup software can be used to capture waveforms lor view trace memory from t
317. rence values for Reset clears the screen the graph Run Stop starts and stops the data logger D xl Sample Rate sec Print Trending Please close all other views if Graph select 1 second as interval Log samples to file C Cursor Cursor2 Delta 805 105 Cursor values are relative to the latest rightmost sample time Phase Current 426 Phase Current 448 Phase C Current 4124 Vab 9999 v N N GRAPH CHANNEL LEVEL CURSOR LINES WAVEFORM Select the desired Displays the value Click and drag the The trended data channel to be captured at the active cursor lines with from the 469 relay from the pull down menu cursor line the left mouse button FIGURE 4 7 Trending Screen 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 4 39 CHAPTER 4 INTERFACES 4 6 5 Event Recorder The 489 event recorder can be viewed through the EnerVista 489 Setup software The event recorder stores generator and system information each time an event occurs e g breaker failure A maximum of 256 events can be stored Each event is assigned an event number from E001 to E256 When the E256 is reached E001 is assigned to the next event Refer to Event Recorder on page 6 28 for additional information on the event recorder Use the following procedure to view the event recorder with EnerVista 489 Setup With EnerVista 489 Setup running and c
318. requency of Va is measurable The alarm element is definite time the trip element can be definite time or a curve Once the V Hz measurement Vos exceeds the pickup level for the specified time a trip or alarm will occur The reset rate is a linear reset time from the threshold of trip and should be set to match cooling characteristics of the protected equipment The measurement of V Hz will be accurate through a frequency range of 5 to 90 Hz Settings less than 1 00 only apply for special generators such as short circuit testing machines The formula for Volts Hertz Curve 1 is Te when v Pickup EQ 5 20 _ A _ 20 1 F F s x Pickup where T trip time in seconds D VOLTS HERTZ TRIP DELAY setpoint V RMS measurement of Vab F frequency of Vab Vom generator voltage setpoint Fs generator frequency setpoint Pickup VOLTS HERTZ TRIP PICKUP setpoint 5 46 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS The V Hz Curve 1 trip curves are shown below for delay settings of 0 1 0 3 1 3 and 10 seconds 1000 z 8 EJ g 10 8 3 l e gt a c 0 3 2 0 1 1 00 1 20 1 40 1 60 1 80 2 00 Multiples of Volts Hertz Pickup 808743A1 X1 CDR The formula for Volts Hertz Curve 2 is D V when gt Pickup EQ 5 21 V F _ F Fs x Pickup where T trip time in seconds D VOLTS HERTZ TRIP DELAY setpoint V RMS measurement of Vab F fr
319. ric characters MESSAGE 4 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 5 15 MESSAGE MESSAGE lt gt CHAPTER 5 SETPOINTS TEXT 4 Range 40 alphanumeric characters GE MULTILIN Range 40 alphanumeric characters 489 GENERATOR RELAY Up to 5 message screens can be programmed under the message scratchpad area These messages may be notes that pertain to the installation of the generator In addition these notes may be selected for scanning during default message display This might be useful for reminding operators to perform certain tasks The messages may be entered from the communications ports or through the keypad To enter a 40 character message 5 2 7 Clear Data gt gt Select the user message to be changed Press the decimal key to enter text mode An underscore cursor will appear under the first character Use the VALUE keys to display the desired character Aspace is selected like a character Press the 1 key to advance to the next character To skip over a character press the key If an incorrect character is accidentally stored press the key enough times to scroll the cursor around to the character When the desired message is displayed press the ENTER key to store or the ESCAPE key to abort The message is now permanently stored Press ESCAPE to cancel the altered message PATH SETPOINTS gt S1 489 SETUP V CLEAR DATA po Te lt gt 55 55 55
320. ring Alphanumeric Text on page 4 5 Each time a new setpoint is successfully stored a message will flash on the display stating NEW SETPOINT HAS BEEN STORED Pressthe 4 8 9 keys then press ENTER The following flash message is displayed NEW SETPOINT HAS BEEN STORED SETPOINT ACCESS PERMITTED Press ESCAPE or MESSAGE to exit the subgroup Pressing ESCAPE or MESSAGE 4 numerous times will always return the cursor to the top of the page and the display returns to 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 4 7 CHAPTER 4 INTERFACES 4 1 6 Diagnostic Messages Diagnostic messages are automatically displayed for any active conditions in the relay such as trips alarms or asserted logic inputs These messages provide a summary of the present state of the relay The Message LED flashes when there are diagnostic messages available press the MENU key until the relay displays TARGET MESSAGES then press the MESSAGE P key followed by the MESSAGE Y key to scroll through the messages For additional information and a complete list of diagnostic messages refer to Diagnostic Messages on page 6 32 4 17 Self Test Warnings The 489 relay performs self test diagnostics at initialization after power up and continuously as a background task to ensure every testable unit of the hardware and software is functioning correctly There are two types of self test warnings indicating either minor or major problem Minor problem
321. rity inversions This element s normal plane of operation for a resistor grounded generator is the 180 plane as shown in FIGURE A 4 Ground Directional Element Polarities and Plane of Operation for an internal ground fault That is for an internal stator to ground fault the V signal is 180 away from the 1 signal if the polarity convention is observed If the 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER A APPENDIX grounding impedance is inductive the plane of operation will be the 270 plane again with the polarity convention shown below If the polarity convention is reversed on one input the user will need to change the plane of operation by 180 GENERATOR CORE 90 y TN lo lo CT Plane of operation gt for resistive IR grounding impedance lo 180 0 Vo 3 489 5 Relay _ 1 0 un d 270 Isolating Transformer 808735A1 CDR FIGURE A 4 Ground Directional Element Polarities and Plane of Operation GENERATOR CORE BREAKER 7 CT e t Contact CO TUNES a 1 Grounding s Switch Aux To Relay 489 Breaker Grounding Ground Impedance 2 Vneutral Directions Current lt gt El t Tr
322. rmally Operating output relay 6 causes it to B de energize NOTE 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 7 71 7 3 CHAPTER 7 TESTING Additional Functional Tests 7 3 1 Overload Curve Accuracy v NOTE The specification for overload curve timing accuracy is 100 ms or 2 of time to trip Pickup accuracy is as per the current inputs 0 5 of 2 x CT when the injected current is less than 2 x CT and 1 of 20 x CT when the injected current is equal to or greater than 2 x CT Perform the steps below to verify accuracy gt In the S2 SYSTEM SETUP D V GEN PARAMETERS menu set GENERATOR RATED MVA 1 04 GENERATOR VOLTAGE PHASE PHASE 600 Note that setting GENERATOR VOLTAGE PHASE PHASE to 600 is equivalent to setting FLA 1000 A For testing purposes ONLY gt In the s2 SYSTEM SETUP gt CURRENT SENSING menu set PHASE CT PRIMARY 1000 gt In the 89 THERMAL MODEL gt MODEL SETUP menu set SELECT CURVE STYLE Standard OVERLOAD PICKUP LEVEL 1 10 x FLA UNBALANCE BIAS FACTOR 0 HOT COLD SAFE STALL RATIO 1 00 ENABLE RTD BIASING No STANDARD OVERLOAD CURVE NUMBER 4 ENABLE THERMAL MODEL Yes gt Inthe 59 THERMAL MODEL gt THERMAL ELEMENTS menu set THERMAL MODEL TRIP Latched or Unlatched Any trip must be reset prior to each test Short the emergency restart terminals momentarily immediately prior to each overload
323. rned Data 6 4 1 Parameter Averages PATH ACTUAL VALUES V LEARNED DATA D PARAMETER AVERAGES PARAMETER gt AVERAGE GENERATOR Range 0 to 2000 FLA AVERAGES LOAD 100 FLA Range 0 to 200096 FLA AVERAGE NEG SEQ g CURRENT 0 FLA Range 0 to 50000 V Not seen if VT MESSAGE CONNECTION is None VOLTAGE 489 calculates the average magnitude of several parameters over a period of time This time is specified by S1 489 SETUP D V PREFERENCES gt V PARAMETER AVERAGES CALC PERIOD setpoint default 15 minutes The calculation is a sliding window and is ignored when the generator is offline that is the value that was calculated just prior to going offline will be held until the generator is brought back online and a new calculation is made Parameter averages will not update if a digital input programmed as Test Input is shorted 6 4 2 Maximums PATH ACTUAL VALUES gt V A3 LEARNED DATA gt V RTD MAXIMUMS RTD 1 Range 50 to 250 C RTD gt MAX TEMP 40 C ESSAGE RTD 2 Range 50 to 250 C I MAX TEMP 40 ESSAGE RTD 3 Range 50 to 250 C I TEMP 40 ESSAGE RTD 4 Range 50 to 250 C I MAX TEMP 40 essage gt RID 5 Range 50 to 250 C I MAX TEMP 40 ESSAGE RTD 6 Range 50 to 250 C I MAX TEMP 40 ESSAGE RTD 7 Range 50 to 250 C I TEMP 40 ESSAGE RTD 8 Range 50 to 250 C I MAX TEMP 40 ESSAGE RTD 9
324. rotection gt Current Elements list item and select the Phase Overcurrent tab to open the Phase Overrcurrent setpoint window as shown below nt Pumping Station 1 489 Relay 1 Settings Protection Current Elements Wu a p 2 gt 99A 36 GE Multilin Communications Status Indicator Green OK Red No Comms Expand the Site List by double clicking or by selecting the box Pose ov For Help press F1 Edt Group 1 DeweMode FIGURE 4 4 Main Window after Connection 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 4 19 CHAPTER 4 INTERFACES The Phase Overcurrent setpoint window will open with a corresponding status indicator on the lower left of the EnerVista 489 Setup window gt Ifthe status indicator is red verify that the serial cable is properly connected to the relay and that the relay has been properly configured for communications steps described earlier Setpoints can now be edited printed or changed according to user specifications Other setpoint and commands windows can be displayed and edited in a similar manner Actual values windows are also available for display These windows can be locked arranged and resized at will Note Refer to the EnerVista 489 Setup help file for additional information about using the 17 software NOTE 4 20 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 4 INTERFACES 4 4 Working with Setpoints and Set
325. round faults in the bottom 5 of the stator due to lack of sensitivity In order to provide reliable coverage for the bottom part of the stator protective elements utilizing the third harmonic voltage signals in the neutral and at the generator output terminals have been developed see Reference 4 In the 489 relay the third harmonic voltage element Neutral Undervoltage 3rd Harmonic derives the third harmonic component of the neutral point voltage signal from the Vpeutral signal as one signal called The third harmonic component of the internally summed phase voltage signals is derived as the second signal called Vp For this element to perform as originally intended it is necessary to use wye connected VTs Since the amount of third harmonic voltage that appears in the neutral is both load and machine dependent the protection method of choice is an adaptive method The following formula is used to create an adaptive third harmonic scheme Vp3 3 lt 0 15 which simplifies to Vp 2 17 1 1 489 tests the following conditions prior to testing the basic operating equation to ensure that Vy is of a measurable magnitude 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER A APPENDIX Neutral CT Ratio Phase CT Ratio EQ 1 2 Vp 2 0 25 V and Vpz 2Permissive_Threshold x 17 x where Vy is the magnitude of third harmonic voltage at the generator neutral Vp is the magnitude of
326. rrent is concerned see ANSI C50 13 A generator should have a rating for both continuous and also short time operation when negative sequence current components are present The short time negative sequence capability of the generator is defined as follows K EQ 5 10 where K constant from generator manufacturer depending on size and design l negative sequence current as a percentage of generator rated FLA as measured at the output CTs t time in seconds when I gt gt pickup minimum 250 ms maximum defined by setpoint The 489 has a definite time alarm and inverse time overcurrent curve trip to protect the generator rotor from overheating due to the presence of negative sequence currents Pickup values are negative sequence current as a percent of generator rated full load current The generator FLA is calculated as Generator FLA __ Generator RateaMVA_ Rated MVA EQ 5 11 5 x Rated Generator Phase Phase Voltage Negative sequence overcurrent maximum time defines the maximum time that any value of negative sequence current in excess of the pickup value will be allowed to persist before atrip is issued The reset rate provides a thermal memory of previous unbalance conditions It is the linear reset time from the threshold of trip 4 Unusually high negative sequence current levels be caused by incorrect phase CT wiring NOTE K 1 0 4 0 15 40 100 1000 100 Time Seconds 0 1 0 01 0 1 1 1
327. rscript number indicating which setpoint group is being viewed or edited Also when a setpoint that has dual settings is stored the flash message that appears will indicate which setpoint group setting has been changed If only one setting group is required edit and activate only Group 1 that is do not assign a digital input to Dual Setpoints and do not alter the ACTIVATE SETPOINT GROUP setpoint or EDIT SETPOINT GROUP setpoint in 63 DIGITAL INPUTS 5 1 5 Commissioning Tables for recording of 489 programmed setpoints are available as a Microsoft Word document from the GE Multilin website at http www GEmultilin com See the Support Documents section of the 489 Generator Management Relay page for the latest version This document is also available in print from the GE Multilin literature department request publication number GET 8445 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS 5 2 51489 Setup 5 2 1 Passcode PATH SETPOINTS gt S1 489 SETUP gt PASSCODE ENTER oo FOR Range 1 to 8 numeric digits oo Range Permitted Restricted MESSAGE SETPOINT ACCESS g Permitted Range No Yes MESSAGE lt gt uz PASSCODE A passcode access security feature is provided with the 489 The passcode is defaulted to 0 without the quotes at the time of shipping Passcode protection is ignored when the passcode is 0 In this case the setpoint access jumper is the only protection w
328. s 0 15 which simplifies to gt 17 The 489 tests the following permissives prior to testing the basic operating equation to ensure that Vyz should be of a measurable magnitude for an unfaulted generator 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 5 53 5 54 v NOTE CHAPTER 5 SETPOINTS Neutral VT Ratio Phase VT Ratio EQ 5 25 Vps gt 0 25 V Vp gt Threshold x 17 x where Vy magnitude of the third harmonic voltage at generator neutral Vp magnitude of the third harmonic voltage at the generator terminals Vp3 VT secondary magnitude of the third harmonic voltage measured at the generator terminals Vus VT sec magnitude of 34 harmonic voltage at generator neutral Threshold 0 15 V for the alarm element and 0 1875 V for the trip element For Open Delta connected VTs If the phase VT connection is open delta it is not possible to measure the third harmonic voltages at the generator terminals and a simple third harmonic neutral undervoltage element is used The level is programmable in terms of Neutral VT secondary voltage In order to prevent nuisance tripping at low load or low generator voltages two blocking functions are provided They apply to both the alarm and trip functions When used as a simple undervoltage element settings should be based on measured 3rd harmonic neutral voltage of the healthy machine This method of using 3rd harmonic voltages to detect stator ground faults
329. s 7 16 cycles would produce a waveform of 4 pre trip cycles and 12 post trip cycles e WAVEFORM MEMORY BUFFER Selects the partitioning of the waveform memory The first number indicates the number of events and the second number the number of cycles The relay captures 12 samples per cycle When more waveform captures occur than the available storage the oldest data will be discarded 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 5 71 CHAPTER 5 SETPOINTS 5 2 3 Communications Serial Communications The following setpoints appear when the relay is ordered with the regular enhanced E option PATH SETPOINTS gt S1 489 SETUP gt V COMMUNICATIONS SERIAL PORTS P SLAVE ADDRESS Range 1 to 254 in steps of 1 254 ESSAGE COMPUTER RS485 Range 300 1200 2400 4800 9600 BAUD RATE 9600 19200 ESSAGE COMPUTER RS485 Range None Odd Even I PARITY None ESSAGE AUXILIARY RS485 Range 300 1200 2400 4800 9600 I BAUD RATE 9600 19200 AUXILIARY RS485 Range None Odd Even ESSAGE 9 PARITY None The 489 is equipped with 3 independent serial communications ports supporting a subset of Modbus RTU protocol The front panel RS232 has a fixed baud rate of 9600 and a fixed data frame of 1 start 8 data 1stop no parity The front port is intended for local use only and will respond regardless of the slave address programmed The front panel RS232 program port may be connected to a personal computer running the
330. s feature is used the alarm be programmed as latched so that intermittent RTDs are detected and corrective action may be taken 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS 5 9 7 RTD Short Low Temp PATH SETPOINTS D V S8 RTD TEMPERATURE gt V RTD SHORT LOW TEMP 1 RTD Pb RTD SHORT LOW TEMP Range Off Latched Unlatched SHORT LOW TEMP gt 47 ALARM Off Range Any combination of Relays 2 to ASSIGN ALARM g y y RELAYS 2 5 5 RTD SHORT LOW TEMP Range On Off MESSAGE 9 ALARM EVENTS Off The 489 has an RTD Short Low Temperature alarm This alarm will look at all RTDs that have either an alarm or trip programmed and determine if an RTD has either a short or a very low temperature less than 50 C Any RTDs that do not have a trip or alarm associated with them will be ignored for this feature When a short low temperature is detected the assigned output relay will operate and a message will appear on the display identifying the RTD that caused the alarm It is recommended that if this feature is used the alarm be programmed as latched so that intermittent RTDs are detected and corrective action may be taken 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 5 69 CHAPTER 5 SETPOINTS 5 10 S9 Thermal Model 5 10 1 489 Thermal Model The thermal model of the 489 is primarily intended for induction generators especially those that start on the system bus in the same manner as induct
331. s S 2 6 C CALIBRATION INFOSZ u uuu rhe tee er ege i elei ers 6 31 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL INDEX M MM 2 15 3 1 CAUSE OF EVENTS TABLE snema e 6 29 CERTIFICATIORS 54 u 2 15 CHANGING SETPOINTS uuu uu u het 1 9 CREAR DATA 5 16 aos O 5 13 6 15 COMM PORT MONITOR ua u ea tet bee tb dins 5 104 COMMUNICATIONS 5 104 RS 23 2 4 11 4 15 4 17 e M Can 4 12 4 15 4 17 SOLD ONES uu ukan i u 5 12 rm 2 14 4 11 4 12 CONTROL FEATURES uu itte er opc e ze od 5 6 CONTROL POWER attese ie etti e epe prede citet e tapas 3 10 geeMiccm 5 85 COOLING TIME CONSTANTS iii ete rtr tae ket Eg erts 5 85 CORE BALANCE certet tee e P Re eco eed 3 12 CT CoL 5 18 CTs
332. s indicate a problem with the relay that does not compromise protection Major problems indicate a very serious relay problem which comprises all aspects of relay operation Upon detection of either a minor or a major problem the relay will De energize the self test warning relay e Light the self test warning LED e Flash a diagnostic message periodically on the display screen The 489 self test warnings are shown below Table 4 1 Self Test Warnings Message Severity Description Self Test Warning 1 This warning is caused by detection of a Replace Immediately corrupted location in the program memory as Major determined by a CRC error checking code Any function of the relay is susceptible to malfunction from this failure Self Test Warning 2 This warning is caused by a failure of the Replace Immediately Major analog to digital converter The integrity of system input measurements is affected this failure Self Test Warning 3 This warning is caused by a failure of the Replace Immediately Major analog to digital converter The integrity of system input measurements is affected this failure Self Test Warning 5 This warning is caused by out of range reading Replace Immediately Major of self test RTD 13 The integrity of system input measurements is affected by this failure Self Test Warning 6 This warning is caused by out of range reading Replace Immediately Major of self test RTD
333. s the user to enter a value within the setpoint range displayed near the top of the keypad Current Sensing Quick Connect 489 Quick conn PHASE CURRENT OOOO o o Phase CT Primary GROUND CURRENT Ground CT Ground CT Ratio 489 Quick Connect s Click Accept to exit from the keypad and keep the new value gt Click on Cancel to exit from the keypad and retain the old value For setpoints requiring non numerical pre set values e g vr CONNECTION TYPE below in the Voltage Sensing window gt Click anywhere within the setpoint value box to display a drop down selection menu arrow gt Click on the arrow to select the desired setpoint Voltage Sensing VOLTAGE TRANSFORMER Transformer Ratio 5003 Neutral Voltage Connection 489 Quick Connect Settings System Setup A For setpoints requiring an alphanumeric text string e g message scratchpad messages the value may be entered directly within the setpoint value box gt Inthe Setpoint System Setup dialog box click on Save to save the values into the 489 gt Click Yes to accept any changes gt Click No and then Restore to retain previous values and exit 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 4 INTERFACES 4 4 5 Using Setpoint Files Overview The EnerVista 489 Setup software interface supports three ways of handling changes to relay setpoints In off line mode relay disconnected to
334. s to specs Table A 6 Major Updates for 489 Manual Revision AA SECT SECT CHANGE DESCRIPTION A9 AA Title Title Update Manual part number to 1601 0150 AA 5 6 9 5 6 9 Change Note Pickup Level Table A 7 Major Updates for 489 Manual Revision A9 SECT SECT CHANGE DESCRIPTION A8 A9 Title Title Update Manual part number to 1601 0150 A9 5 6 5 5 6 5 Fig 5 2 Change graph Table A 8 Major Updates for 489 Manual Revision A8 SECT SECT CHANGE DESCRIPTION A7 A8 Title Title Update Manual part number to 1601 0150 A8 2 1 2 2 1 2 225 225 Update Changes to DC Power Supply range fig 5 2 fig 5 2 Change graph 8 2 1 Add New Section Stator Differential Protection 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER A APPENDIX Table A 8 Major Updates for 489 Manual Revision A8 SECT SECT CHANGE DESCRIPTION A7 A8 8 2 1 8 3 1 Update Drawings changed Equn 7 7 7 7 Update Change equation Table A 9 Major Updates for 489 Manual Revision A7 PAGE SECT CHANGE DESCRIPTION A5 A6 Title Title Update Manual part number to 1601 0150 A6 5 31 5 6 8 Correction Changes to step value Differential Trip Delay 2 9 2 2 6 Correction Changes to Littelfuse SLO BLO data 2 7 8 2 2 3 Update Changes to OverFrequency Underfrequency 5 39 40 5 7 5 6 parameters Table A 10
335. service factor The curve is effectively cut off at current values below this pickup Generator thermal limits consist of three distinct parts based on the three conditions of operation locked rotor or stall acceleration and running overload Each of these curves may be provided for both a hot and cold machine A hot machine is defined as one that has been running for a period of time at full load such that the stator and rotor temperatures have settled at their rated temperature A cold machine is defined as a machine that has been stopped for a period of time such that the stator and rotor temperatures have settled at ambient temperature For most machines the distinct characteristics of the thermal limits are formed into one smooth homogeneous curve Sometimes only a safe stall time is provided This is acceptable if the machine has been designed conservatively and can easily perform its required duty without infringing on the thermal limit In this case the protection can be conservative If the machine has been designed very close to its thermal limits when operated as required then the distinct characteristics of the thermal limits become important The 489 overload curve can take one of three formats Standard Custom Curve or Voltage Dependent Regardless of which curve style is selected the 489 will retain thermal memory in the form of a register called Thermal Capacity Used This register is updated every 50 ms using the following equat
336. so from the time the machine is placed online until the time entered expires Once the input is setup both the trip and alarm features may be configured In addition to programming a level and time delay the PICKUP setpoint may be used to dictate whether the feature picks up when the measured value is over or under the level If a vibration transducer is to be used program the name as Vib Monitor the units as mm s the minimum as 0 the maximum as 25 and the Block From Online as 0 s Set the alarm for a reasonable level slightly higher than the normal vibration level Program a delay of 3 s and the pickup as Over 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 5 99 5 13 12 Testing 5 100 CHAPTER 5 SETPOINTS 5 13 1 Simulation Mode PATH SETPOINTS D V S12 489 TESTING gt SIMULATION MODE SIMULATION MODE Range Off Simulate Pre Fault iones 14 ma Ie iC oo Simulate Fault Pre Fault to Fault PRE FAULT TO FAULT Range 0 to 300 s in steps of 1 MESSAGE gt TIME DELAY 15 The 489 may be placed in several simulation modes This simulation may be useful for several purposes First it may be used to under stand the operation of the 489 for learning or training purposes Second simulation may be used during startup to verify that control circuitry operates as it should in the event of a trip or alarm In addition simulation may be used to verify that setpoints had been set properly in t
337. splayed in the following sequence SETPOINTS gt m ACTUAL VALUES gt i TARGET MESSAGES gt press the MENU key until the display shows the header of the setpoints menu To access setpoints Press the MESSAGE or ENTER key to display the header for the first setpoints page The setpoint pages are numbered have an S prefix for easy identification and have a name which provides a general idea of the settings available in that page gt Press the MESSAGE Y and MESSAGE A keys to scroll through all the available setpoint page headers Setpoint page headers look as follows SETPOINTS gt S1 489 SETUP To enter a given setpoints page gt Press the MESSAGE gt or ENTER key gt Press the MESSAGE Y or MESSAGE A keys to scroll through sub page headers until the required message is reached The end of a page is indicated by the message END OF PAGE The beginning of a page is indicated by the message TOP OF PAGE To access actual values 1 4 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 1 GETTING STARTED gt gt Press the MENU key until the display shows the header of the actual values menu Press the MESSAGE gt or ENTER key to display the header for the first actual values page The actual values pages are numbered have an prefix for easy identification and have a name which gives a general idea of the information available in that page Press th
338. sponding input voltage to a minimum pickup of 0 15 x CT The VOLTAGE LOWER LIMIT setpoint prevents very rapid tripping prior to primary protection clearing a fault when voltage restraint is enabled and severe close in fault has occurred If voltage restraint is not required select No for this setpoint If the VT type is selected as None or a VT fuse loss is detected the voltage restraint is ignored and the element operates as simple phase overcurrent A fuse failure is detected within 99 ms therefore any voltage restrained overcurrent trip should have a time delay of 100 ms or more or nuisance tripping on fuse loss could occur For example to determine the voltage restrained phase overcurrent pickup level under the following situation PHASE OVERCURRENT PICKUP 2 00 x CT 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 5 35 CHAPTER 5 SETPOINTS ENABLE VOLTAGE RESTRAINT Yes VOLTAGE LOWER LIMIT 10 e Phase Phase Voltage Rated Phase Phase Voltage 0 4 V The voltage restrained phase overcurrent pickup level is calculated as follows ect Phase OC Pickup x Voltage Rest Pickup Multiplier x CT 2x04 xCT 0 8x CT EQ 5 9 The 489 phase overcurrent restraint voltages and restraint characteristic are shown below Phase Overcurrent Restraint Voltages 1 CURRENT VOLTAGE 0 9 IA Vab 5 08 07 Vea 06 S o5 04 0
339. started at 8096 voltage A custom curve is required 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS 2x 489 ce muii TYPICAL CUSTOM CURVE 10000 PROGRAMMED 469 CUSTOM CURVE RUNNING SAFETIME STATOR LIMIT 9 ACCELERATION SAFETIME ROTOR LIMIT 4 MACHINE CURRENT 100 VOLTAGE 1000 5 MACHINE CURRENT 80 VOLTAGE 100 TIME TO TRIP IN SECONDS MULTIPLE FULL LOAD CURRENT SETPOINT 0 5 1000 808825A3 CDR FIGURE 5 16 Custom Curve Example Voltage Dependent Overload Curve It is possible and acceptable that the acceleration time exceeds the safe stall time bearing in mind that a locked rotor condition is quite different than an acceleration condition In this instance each distinct portion of the thermal limit curve must be known and protection coordinated against that curve The protection relay must be able to distinguish between a locked rotor condition an accelerating condition and a running condition The 489 voltage dependent overload curve feature is tailored to protect these types of machines Voltage is monitored constantly dur
340. sting file All 489 setpoint files should have the extension 489 for example motor1 489 gt Click Save and OK to complete the process Once this step is completed the new file with a complete path will be added to the EnerVista 489 Setup software environment Upgrading Setpoint Files to a New Revision It is often necessary to upgrade the revision code for a previously saved setpoint file after the 489 firmware has been upgraded for example this is required for firmware upgrades This is illustrated in the following procedure gt Establish communications with the 489 relay gt Select the Actual gt Product Information menu item and record the Software Revision identifier of the relay firmware as shown below 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 4 25 CHAPTER 4 INTERFACES Product Information Quick Connect 489 D xl Product Information Order Code wh Save Serial Number 3277777 Main Revision 32J300A8 000 r Restore Boot Revision 32J300AD 000 Default Original Calibration Date 05 26 2003 Last Calibration Date 05 26 2003 Hardware Revision Modification Number Boot Software gt Load the setpoint file to be upgraded into the EnerVista 489 Setup environment as described in Adding Setpoints Files to the Environment on page 4 24 In the File pane select the saved setpoint file From
341. system This element uses the phase to phase voltage measured at the generator terminals and phase currents measured at the neutral side of the generator As such this element will provide coverage for the generator step up transformer and will also provide a degree of protection for stator phase to phase faults The element has a offset mho characteristic as shown in FIGURE 5 12 Distance Element Characteristics on page 59 Offset in the third quadrant is 1 8th of the forward reach to provide better resistive fault coverage for close in faults The element provides a separate measurement in three loops for AB BC and CA faults There is a setting for specification of 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 5 57 CHAPTER 5 SETPOINTS the step up transformer connection If this setting is chosen as None then it is assumed that the transformer is Wye Wye connected or that there is no step up transformer In this case the element will use the following operating quantities Element Voltage Current AB Va Vb la Ib BC Vb Vc Ib Ic CA Vc Va Ic la If this setting is chosen as Delta Wye then it is assumed that the transformer is Yd1 or Yd11 In this case the following operating quantities are used Element Voltage Current 3 xia BC Vbc 3 43 x Ib CA 3 The first zone is typicall
342. t If the 489 chassis is only partially engaged with the case the ALARM 489 NOT INSERTED PROPERLY service alarm appears after 1 sec Secure the chassis handle to ensure that all contacts mate properly 6 2 5 Trip Pickups PATH ACTUAL VALUES gt STATUS gt V TRIP PICKUPS TRIP PICKUPS gt Input A Range PICKUP Not Enabled ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE ESSAGE lt gt lt gt lt gt lt gt lt gt lt gt lt gt lt gt lt gt gt lt gt lt gt lt gt lt gt Input PICKUP Not Enabled Input C PICKUP Not Enabled Input D PICKUP Not Enabled Input E PICKUP Not Enabled Input F PICKUP Not Enabled Input G PICKUP Not Enabled SEQUENTIAL TRIP PICKUP Not Enabled FIELD BKR DISCREP PICKUP Not Enabled 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL Range Range Range Range Range Range Range Range Not Enabled Inactive Timing Out Active Trip Latched Trip Not Enabled Inactive Timing Out Active Trip Latched Trip Not Enabled Inactive Timing Out Active Trip Latched Trip Not Enabled Inactive Timing Out Active Trip Latched Trip Not Enabled Inactive Timing Out Active Trip Latched Trip Not Enabled Inactive Timing Out Active Trip Latched Trip Not Enabled Inactive Timing Out Active Trip Latched Tri
343. t H02 Phase D11 RTD 11 Hot H03 Neutral Phase A CT D12 11 Compensation HO4 eutral Phase B CT D13 RTD Return HOS eutral Phase C CT D14 RTD 12 Compensation 06 Output Phase 015 RTD 12 Hot H07 Output Phase B CT D16 Assignable Switch 1 H08 Output Phase C CT D17 Assignable Switch 2 H09 1A Ground CT D18 Assignable Switch 3 H10 HGF Ground CT D19 Assignable Switch 4 H11 Control Power D20 Assignable Switch 5 H12 Control Power 3 8 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 3 INSTALLATION 3 2 Electrical Installation 3 2 1 Typical Wiring ly B3 d HL C B e mL dA HA LI Izv l ee jj la He H OG CEH UI Is amam 1202 1nF COMMON STATOR RTDs FIGURE 3 10 Typical Wiring Diagram 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 3 9 CHAPTER 3 INSTALLATION 3 2 2 General Wiring Considerations A broad range of applications are available to the user and it is not possible to present typical connections for all possible schemes The information in this section will cover the important aspects of interconnections in the general areas of instrument transformer inputs other inputs outputs communications and grounding See Terminal Layout on page 3 7 and 489 Terminal List on page 3 8 for terminal arrangement and Typical Wiring Diagram on page 3 10 for typical connections EXCITER AND
344. tal using the conventional phase comparator approach with the polarizing voltage derived from the pre fault positive sequence voltage of the protected loop This protection is intended as backup for the primary line protection The elements make use of the neutral end current signals and the generator terminal voltage signals see figure below thus providing some protection for internal and unit transformer faults In systems with a delta wye transformer DY330 the appropriate transformations of voltage and current signals are implemented internally to allow proper detection of transformer high side phase to phase faults The reach setting is the positive sequence impedance to be covered per phase expressed in secondary ohms The same transformation shown for the Loss of Excitation element can be used to calculate the desired settings as functions of the primary side impedances The elements have a basic operating time of 150 ms A VT fuse failure could cause a maloperation of a distance element unless the element is supervised by the VTFF element In order to prevent nuisance tripping the elements require a minimum phase current of 0 05 x CT i Protection Zone 1 Protection Zone 2 Neutral End CT Terminal VT 489 Relay 808740A1 CDR FIGURE 5 11 Distance Element Setup The 489 phase distance element is intended to provide backup protection for phase to phase faults on the electric power
345. tance of the rotor is reduced quite dramatically During overloads the generator thermal limit is typically dictated by stator parameters Some special generators might be all stator or all rotor limited During acceleration the dynamic nature of the generator slip dictates that rotor impedance is also dynamic and a third thermal limit characteristic is necessary The figure below illustrates typical thermal limit curves for induction motors The starting characteristic is shown for a high inertia load at 80 voltage If the machine started quicker the distinct characteristics of the thermal limit curves would not be required and the running overload curve would be joined with locked rotor safe stall times to produce a single overload curve The generator manufacturer should provide a safe stall time or thermal limit curves for any generator that is started as an induction motor These thermal limits are intended to be used as guidelines and their definition is not always precise When operation of the generator exceeds the thermal limit the generator insulation does not immediately melt rather the rate of insulation degradation reaches a point where continued operation will significantly reduce generator life 5 70 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 5 SETPOINTS 400 HIGH 300 INERTIA 58 MOTOR RUNNING OVERLOAD 100 A
346. tched Eo E TRIP Prob a ASSIGN TRIP Range Any combination of Relays 1 to ESSAGE 4 RELAYS 1 4 1 Range 0 05 to 1 00 x CT in steps of ESSAGE DIFFERENTIAL TRIP MIN PICKUP 0 10 x I Range 1 to 100 in steps of 1 ESSAGE DIFFERENTIAL TRIP g p SLOPE 1 10 Range 1 to 100 steps of 1 ESSAGE DIFFERENTIAL TRIP g p SLOPE 2 20 Range 0 to 100 cycles in steps of 1 ESSAGE DIFFERENTIAL TRIP DELAY 0 cycles The 489 differential element consists of the well known dual slope percent restraint characteristic A differential signal is derived from the phasor sum of the currents on either side of the machine A restraint signal is derived from the average of the magnitudes of these two currents An internal flag DIFF is asserted when the differential signal crosses the operating characteristic as defined by the magnitude of the restraint signal The DIFF flag produces a relay operation External faults near generators typically result in very large time constants of dc components in the fault currents This creates a real danger of CT saturation The external fault currents will be large and the CTs will initially reproduce the fault current without distortion Consequently the relay will see a large restraint signal coupled with a small differential signal This condition is used as an indication of the possible onset of ac saturation of the CTs Magnetizing Inrush current due to the energizing of a step up t
347. the Thermal Reset function shorting that input will reset the thermal memory used to zero All Thermal Resets will be recorded as events If an input is assigned to the tachometer function it may not be used here 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 5 23 CHAPTER 5 SETPOINTS 5 4 7 Dual Setpoints PATH SETPOINTS gt V S3 DIGITAL INPUTS gt V DUAL SETPOINTS m ASSIGN DIGITAL Range None Input 1 Input 2 Input 3 DUAL P INPUT None Input 4 Input 5 Input 6 Input 7 2 ACTIVATE SETPOINT Range Group 1 Group 2 x GROUP Group 1 Range Group 1 Group 2 MESSAGE EDIT SETPOINT GROUP Group 1 If an input is assigned to the tachometer function it may not be used here This feature allows for dual settings for the current voltage power RTD and thermal model protection elements setpoint pages S5 to S9 These settings are organized in two setpoint groups the main group Group 1 and the alternate group Group 2 Only one group of settings are active in the protection scheme at a time When accessing the Group 2 setpoints the block character for the setpoints menu header will be replaced by the number two 2 as indicated below The following chart illustrates the available Group 2 alternate group setpoints 2 SETPOINTS 2 SETPOINTS gt 2 SETPOINTS P 2 SEIPOINTS gt 2 SETPOINTS gt 55 CURRENT ELEM S6 VOLTAGE ELEM S7 POWER ELEMENTS a BIO TEMPERA S9 THERMAL MODE
348. the keypad is used to navigate through the menu structure Specific locations are referred to throughout this manual by using a path representation The example shown in the figure gives the key presses required to read the average negative sequence current denoted by the path A3 LEARNED DATA gt PARAMETER AVERAGES D gt V AVERAGE NEG SEQ CURRENT gt Press the menu key until the relay displays the actual values page 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 1 7 CHAPTER 1 GETTING STARTED m ACTUAL VALUES P gt Press the MESSAGE m ACTUAL VALUES P Al STATUS Press the MESSAGE key m ACTUAL VALUES gt A2 METERING DATA Press the MESSAGE key ACTUAL VALUES P MESSAGE PARAMETER gt MESSAGE AVERAGE GENERATOR A3 LEARNED DATA AVERAGES LOAD 100 FLA MESSAGE AVERAGE NEG SEQ CURRENT 0 FLA 1 8 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 1 GETTING STARTED 13 Changing Setpoints 1 3 1 Introduction There are several classes of setpoints each distinguished by the way their values are displayed and edited The relay s menu is arranged in a tree structure Each setting in the menu is referred to as a setpoint and each setpoint in the menu may be accessed as described in the previous section The settings are arranged in pages with each page containing related settings for example all the Phase Overcurrent settings are contained within
349. the main window menu bar select the File gt Properties menu item and note the version code of the setpoint file If this version e g 4 0X shown below is different than the Software Revision code noted in step 2 select a New File Version that matches the Software Revision code from the pull down menu For example if the software revision is 3 00 and the current setpoint file revision is 1 50 change the setpoint file revision to 3 0 as shown below Convert Settings File Settings File Name Description File Version C Program Files GE Power Management 489PC model15 489 Plant 15 original setpoints 150 New File Version 1 5 Enter any special comments about the setpoint file here Select the desired setpoint version from this menu The 3 0x indicates versions 3 00 3 01 3 02 etc gt When complete click Convert to convert the setpoint file to the desired revision A dialog box will request confirmation See Loading Setpoints from a File on page 4 28 for instructions on loading this setpoint file into the 489 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 4 INTERFACES Printing Setpoints and Actual Values The EnerVista 489 Setup software allows the user to print partial or complete lists of setpoints and actual values Use the following procedure to print a list of setpoints gt Select a previously saved setpoints file in the File pane or establish
350. the maximum stator RTD temperature is above the RTD BIAS MAXIMUM setpoint typically at the stator insulation rating or slightly higher then the thermal memory is fully biased and thermal capacity is forced to 100 used At values in between the present thermal capacity used created by the overload curve and other elements of the thermal model is compared to the RTD Bias thermal capacity used from the RTD Bias curve If the RTD Bias thermal capacity used value is higher then that value is used from that point onward The RTD BIAS CENTER POINT should be set at the rated running temperature of the machine The 489 automatically determines the thermal capacity used value for the center point using the HOT COLD SAFE STALL RATIO setpoint hot TCusedat RBC a 100 EQ 5 37 At temperatures less that the RTD Bias Center temperature TeMP actual E TEMP min RTD_Bids_TCyseg TEMP center TEMP min X TC at RBC EQ 5 38 At temperatures greater than the RTD Bias Center temperature TEMP actual ni TEMP center RTD_Bias_TC TEMP max B TEMP center x 100 TC cea at RBC TC ce at RBC EQ 5 39 used 7 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 5 97 5 88 Wy NOTE CHAPTER 5 SETPOINTS where RTD_Bias_TCyceg TC used due to hottest stator RTD Tempoctual current temperature of the hottest stator RTD TeMPmin RTD Bias minimum setpoint TeMPcenter RTD Bias center setpoint TeMPmax RTD Bias maximum setpo
351. the pickup x the generator rated phase phase voltage the element will begin to time out If the time expires a trip or alarm will occur The curve reset rate is a linear reset time from the threshold of trip If the VT type is selected as None VT fuse loss is detected or the magnitude of I lt 7 5 CT the undervoltage protection is disabled The pickup levels are insensitive to frequency over the range of 5 to 90 Hz The formula for the undervoltage curve is D 1 V V ickup when V lt Voickup EQ 5 18 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 5 43 CHAPTER 5 SETPOINTS where T trip time in seconds D UNDERVOLTAGE TRIP DELAY setpoint V actual average phase phase voltage Vpickup UNDERVOLTAGE TRIP PICKUP setpoint 1000 10 100 1 TIME DELAY SETTING 0 3 10 Time to Trip seconds 0 1 0 0 2 04 0 6 0 8 1 Multiples of Undervoltage Pickup 808742A1 CDR FIGURE 5 6 Undervoltage Curves 5 7 2 Overvoltage PATH SETPOINTS D V S6 VOLTAGE ELEM gt V OVERVOLTAGE 1 OVERVOLTAGE gt OVERVOLTAGE Range Off Latched Unlatched ALARM Off _ ASSIGN ALARM Range Any combination of Relays 2 to ESSAGE rio 5 RELAYS 2 5 5 OVERVOLTAGE ALARM Range 1 01 to 1 50 x Rated in steps of ESSAGE 4 PICKUP 1 15 x Rated cor OVERVOLTAGE ALARM Range 0 2 to 120
352. the same page As previously explained the top menu page of each setting group describes the settings contained within that page Pressing the MESSAGE keys allows the user to move between these top menus All of the 489 settings fall into one of following categories device settings system settings digital input settings output relay settings current element settings voltage element settings power element settings RTD temperature settings thermal model settings monitoring settings analog input output settings and testing settings IMPORTANT NOTE Settings stored and used by the relay immediately after they are entered As such caution must be exercised when entering settings while the relay is in service Modifying or storing protection settings is not recommended when the relay is in service since any incompatibility or lack of coordination with other previously saved settings may cause unwanted operations NOTE Now that we have become more familiar with maneuvering through messages we can learn how to edit the values used by all setpoint classes Hardware and passcode security features are designed to provide protection against unauthorized setpoint changes Since we will be programming new setpoints using the front panel keys a hardware jumper must be installed across the setpoint access terminals C1 and C2 on the back of the relay case Attempts to enter a new setpoint without this electrical connection will r
353. time during tests 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 5 41 CHAPTER 5 SETPOINTS AUXILIARY CONTACT GROUNDING SWITCH C B 59G it le gt gt 10 TO 50 0 025 TO Vneutral OF EACH 489 50 0 025 GROUND e INPUTS 808812A3 CDR FIGURE 5 5 Ground Directional Detection 5 6 10 High Set Phase OC PATH SETPOINTS D V S5 CURRENT ELEM V HIGH SET PHASE OVERCURRENT 1 HIGH SET gt HIGH SET PHASE oo Range Off Latched Unlatched PHASE OVERCURRENT TRIP oo Range Any combination of Relays 1 to message ASSIGN TRIP x RELAYS 1 4 1 Range 0 15 to 20 00 x CT in steps of T HIGH SET PHASE O C 7 PICKUP 5 00 x CT HIGH SET PHASE 0 C Range 0 00 to 100 00 s in steps of 0 01 es qug DELAY 1 00 s If any individual phase current exceeds the pickup level for the specified trip time a trip will occur if the feature is enabled The element operates in both online and offline conditions This element can be used as a backup feature to other protection elements situations where generators are connected in parallel this element would be set above the maximum current contribution from the generator on which the protection is installed With this setting the element would provide proper selective tripping The basic operating time of the element with no time delay is 50 ms at 50 60 Hz 489 GENERATOR
354. to zero results in an instantaneous response to all current levels above pickup Regardless of the trip time that results from the curve multiplier setpoint the 489 cannot trip any quicker than one to two cycles plus the operate time of the output relay B Time overcurrent tripping time calculations are made with an internal energy capacity memory variable When this variable indicates that the energy capacity has reached 100 a time overcurrent trip is generated If less than 100 is accumulated in this variable and the current falls below the dropout threshold of 97 to 98 of the pickup value the variable must be reduced Two methods of this resetting operation are available Instantaneous and Linear The Instantaneous selection is intended for applications with other relays such as most static units which set the energy capacity directly to zero when the current falls below the reset threshold The Linear selection can be used where the 489 must coordinate with electromechanical units With this setting the energy capacity variable is decremented according to the following equation Ex Mx Cp Tegser 77100 0 3 where reset time in seconds E energy capacity reached in 96 M curve multiplier Cg characteristic constant 5 for ANSI IAC Definite Time and FlexCurves 8 for curves 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 5 29 CHAPTER 5 SETPOINTS ANSI Curves The
355. to log as an event when it becomes active it is automatically logged as a date and time stamped event Control A 489 control feature may be assigned to operate any combination of five output relays 1 Trip 2 Auxiliary 3 Auxiliary 4 Auxiliary and 5 Alarm The combination of relays available for each function is determined by the suitability of each relay for that particular function The appropriate LED indicator on the 489 faceplate will illuminate when an output relayls has been operated by a control function Since it may not be desirable to log all control function as events each control feature may be programmed to log as an event or not If a control feature is programmed to log as an event each control relay event is automatically logged with a date and time stamp 5 13 Relay Assignment Practices There are six output relays Five of the relays are always non failsafe the other Service is failsafe and dedicated to annunciate internal 489 faults these faults include setpoint corruption failed hardware components loss of control power etc The five remaining relays may be programmed for different types of features depending on what is required One of the relays 1 Trip is intended to be used as a trip relay wired to the unit trip breaker Another relay 5 Alarm is intended to be used as the main alarm relay The three remaining relays 2 Auxiliary 3 Auxiliary and 4 Auxiliary are intended for special requirements When
356. tor Load e Average Negative Sequence Current e Phase Phase Voltage e Maximum Values 4 Maintenance data This is useful statistical information that may be used for preventive maintenance It includes e Trip counters General counter such as Number of Breaker Operations Timers such as Generator Running Hours 5 RTD Learned Data includes the maximum temperature measured by each of the 12 RTDs 6 Event recorder downloading tool 7 Product information including model number firmware version additional product information and calibration dates 8 Oscillography and Data Logger downloading tool 4 42 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 4 INTERFACES Selecting an actual values window also opens the actual values tree from the corresponding device in the site list and highlights the current location in the hierarchy For complete details on actual values refer to Chapter 6 To view a separate window for each group of actual values select the desired item from the tree and double click with the left mouse button Each group will be opened separate tab The windows can be re arranged to maximize data viewing as shown in the following figure showing actual current voltage and generator status values tiled in the same window o 07 aao aasan 0A ze O FLA Negative Sequence Current 000A a iOS
357. tor is offline and uses the neutral end CT measurements la Ib Ic It may be set much more sensitive than the differential element to detect high impedance phase faults Since the breaker auxiliary contacts wired to the 489 Breaker Status input may not operate at exactly the same time as the main breaker contacts the time delay should be coordinated with the difference of the operation times In the event of a low impedance fault the differential element will still shutdown the generator quickly 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 5 33 5 34 CHAPTER 5 SETPOINTS iy If the unit auxiliary transformer is on the generator side of the breaker the pickup level must be set greater than the unit auxiliary load NOTE 5 6 4 Inadvertent Energization PATH SETPOINTS gt V S5 CURRENT ELEM DV INADVERTENT ENERG 1 INADVERTENT Pb 6 INADVERTENT ENERGIZE Range Off Latched Unlatched ENERGIZATION TRIP Off ASSIGN TRIP Range Any combination of Relays 1 to RELAYS 1 4 1 4 ARMING SIGNAL Range U V and Offline U V or Offline i U V and Offline INADVERTENT ENERGIZE Range 0 05 to 3 00 x CT in steps of ESSAGE O C PICKUP 0 05 x CT 0 01 Range 0 50 to 0 99 x Rated Voltage in ESSAGE INADVERTENT ENERGIZE e PICKUP 0 50 x Rated ps or The logic diagram for the inadvertent energization protection feature is shown below The feature may be armed when all of the phase voltages fall bel
358. trickle current as a failure condition Circuit breakers equipped with standard control circuits have a breaker auxiliary contact permitting the trip coil to be energized only when the breaker is closed When these contacts are open as detected by the Breaker Status digital input trip coil supervision circuit is automatically disabled This logic provides that the trip circuit is monitored only when the breaker is closed e 2 AUXILIARY 3 AUXILIARY 4 AUXILIARY The auxiliary relays may be programmed for numerous functions such as trip echo alarm echo trip backup alarm or trip differentiation control circuitry etc They should be wired as configuration warrants e 5 ALARM The alarm relay should connect to the appropriate annunciator or monitoring device e 6 SERVICE The service relay will operate if any of the 489 diagnostics detect an internal failure or on loss of control power This output may be monitored with an annunciator PLC or DCS The service relay NC contact may also be wired in parallel with the trip relay on a breaker application This will provide failsafe operation of the generator that is the generator will be tripped offline in the event that the 489 is not protecting it Simple annunciation of such a failure will allow the operator or the operation computer to either continue or do a sequenced shutdown Relay contacts must be considered unsafe to touch when the system is energized If the customer requires the rela
359. ual Values opens a window with tabs each tab containing data in accordance with the following list 1 Generator and System Status 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 4 41 CHAPTER 4 INTERFACES e Generator status either stopped starting or running It includes values such as generator load thermal capacity used generator speed and instantaneous values of power system quantities The status of digital inputs Last trip information including values such as cause of last trip time and date of trip generator speed and load at the time of trip pre trip temperature measurements pre trip analog inputs values and pre trip instantaneous values of power system quantities Active alarms e Relay date and time e Present blocking conditions General system status indication including the status of output relays active pickup alarm and trip conditions 2 Metering Data e Instantaneous current measurements including phase differential unbalance ground average generator load and differential currents e RTD Temperatures including hottest RTDs e Instantaneous phase to phase and phase to ground voltages depending on the VT connections average voltage and system frequency Generator Speed Power Quantities including Apparent Real and Reactive Power e Current and power demand including peak values e Analog inputs Vector information 3 Generator Learned Data Average Genera
360. unction This prevents misoperation gt 0 05 34 Oms IT mag B gt 0 05pu m mag C gt 0 05 gt 5 2 mag B 5pu 5 lt gt 5 5 87 PKP 87 PKP A 87 PKP B OR 8 87 PKPC With no terminal sde currents delay of an extra 130ms is applied to the differential function FIGURE A 7 Enhancements to the stator differential logic 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL A 9 CHAPTER A APPENDIX Should a fault occur during the first 50 60ms after closing the breaker the corresponding relay would trip instantly Before closing the breaker the corresponding relay too applies a delay However once the load inrush current exceeds 5 of CT nominal its timer is by passed and instantaneous protection is provided Should a fault occur during generator start up with both breakers opened both relays would operate after the extra time delay of 130ms This delay is acceptable under such conditions Even this delay will be eliminated if the fault is heavy enough to draw more than 5 times CT nominal from the neutral side of the generator For proper implementation the internal timer is cleared each time the 87 function becomes enabled so that a partial time out from the previous enabled period does not affect the int
361. und O C Alarm Input A to G Alarm Low Fwd Power Alarm MVA Demand Alarm Mvar Demand Alarm MW Demand Alarm NegSeq Current Alarm Neut U V 3rd Alarm Neutral O V Alarm Open RTD Alarm Overcurrent Alarm Overfrequency Alarm Overvoltage Alarm Reactive Power Alarm Reverse Power Alarm RTD11 Alarm Service Alarm Short Low RTD Alarm Stator RTD 1 Alarm Stator RTD 2 Alarm Stator RTD 3 Alarm Stator RTD 4 Alarm Stator RTD 5 Alarm Stator RTD 6 Alarm Tachometer Alarm Thermal Model Alarm Trip Coil Monitor Trip Counter Alarm Underfrequency Alarm Undervoltage Alarm Volts Per Hertz Alarm VT Fuse Fail Alarm OTHER Control Power Applied Control Power Lost Dig I P Waveform Trig Input A to G Control Serial Comm Start Serial Comm Stop Serial Waveform Trip Setpoint 1 Active Setpoint 2 Active Simulation Started reflects the name as programmed Simulation Stopped 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL Thermal Reset Close CHAPTER 6 ACTUAL VALUES 6 7 Product Information 6 7 1 489 Model Info PATH ACTUAL VALUES gt V A6 PRODUCT INFO D 489 MODEL INFO 489 MODEL gt ORDER CODE Range N A INFORMATION 489 5 20 489 SERIAL NO Range N A A3260001 C 489 REVISION Range N A 32E100A4 000 BOOT REVISION W N A MESSAGE 9 30 401 0 000 All
362. ur inputs share one common return Polarity of these inputs must be observed for proper operation The analog input circuitry is isolated as a group with the Analog Output circuitry and the RTD circuitry Only one ground reference should be used for the three circuits Transorbs limit this isolation to x36 V with respect to the 489 safety ground In addition the 24 V DC analog input supply is brought out for control power of loop powered transducers Refer to the Specifications section of this manual for maximum current draw from this supply 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 3 INSTALLATION gt ALOG 1 0 ANALOG INPUTS 4 SHIELD 1 2 3 4 COM SIGNAL SIGNAL SIGNAL SIGNAL VIBRATION VIBRATION FIELD PRESSURE MOTOR MOTOR CURRENT BEARING BEARING LOOP POWERED TRANSDUCERS 808789A2 DWG FIGURE 3 16 Loop Powered Transducer Connection 3 2 8 Analog Outputs The 489 provides four analog output channels which when ordered provide a full scale range of either 0 to 1 mA into a maximum 10 impedance or 4 to 20 mA into a maximum 1 2K impedance Each channel can be configured to provide full scale output sensitivity for any range of any measured parameter As shown in the Typical Wiring Diagram on page 3 10 these outputs share one
363. urs Thermal Overload Analog Inputs 1 to 4 Analog Inputs 1 to 4 Service Self Test Failure Electrical Lockout IRIG B Failure The following protection elements require neutral end current inputs Distance Element Offline Overcurrent e Phase Differential 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 2 3 2 1 2 Ordering CHAPTER 2 INTRODUCTION Power metering is a standard feature in the 489 The table below outlines the metered parameters available to the operator through the front panel and communications ports The 489 is equipped with three independent communications ports The front panel RS232 port may be used for setpoint programming local interrogation or control and firmware upgrades The computer RS485 port may be connected to a PLC DCS or PC based interface software The auxiliary RS485 port may be used for redundancy or simultaneous interrogation and or control from a second PLC DCS or PC program There are also four 4 to 20 mA transducer outputs that may be assigned to any measured parameter The range of these outputs is scalable Additional features are outlined below Table 2 2 Metering and Additional Features Metering Additional Features Voltage phasors Drawout Case maintenance and testing Current phasors and Amps Demand Breaker Failure Real Power MW Demand MWh Trip Coil Supervision Apparent Power and MVA demand VT
364. vel trip definite time 0 1 to 5000 0 sec in steps of 0 1 0 02 Hz 150 ms or 1 of total time at 50Hz and 60Hz 300 ms or 2 of total time at 25Hz Trip and Alarm 0 50 to 0 99 x rated V in steps of 0 01 Inverse Time definite time alarm 0 2 to 120 0 steps of 0 1 as per voltage inputs 100 ms or 0 5 of total time Trip and Alarm VOLTAGE PHASE REVERSAL Configuration Timing accuracy Elements VOLTS PER HERTZ ckup level Curve shapes Time delay T 0 accuracy iming accuracy ements 2 2 4 Digital Inputs ABC or ACB phase rotation 200 to 400 ms Trip 1 00 to 1 99 x nominal in steps of 0 01 Inverse Time definite time alarm 0 1 to 120 0 s in steps of 0 1 as per voltage inputs 100 ms at 2 1 2 x Pickup 300 ms at 1 2 x Pickup Trip and Alarm FIELD BREAKER DISCREPANCY Configurable Time delay Timing accuracy Elements 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL assignable to Digital Inputs 1 to 7 0 1 to 500 0 s in steps of 0 1 100 ms or 0 596 of total time Trip CHAPTER 2 INTRODUCTION GENERAL INPUT ATOG Configurable Time delay Block from online Timing accuracy Elements SEQUENTIAL TRIP Configurable Pickup level Time delay Pickup accuracy Timing accuracy Elements TACHOMETER Configurable RPM measurement Duty cycle of pulse Pickup level Time delay Timing accuracy Elements 2 2 5 Monitoring
365. when the injected current is less than 2 x CT Perform the steps below to verify accuracy gt Alter the following setpoint S2 SYSTEM SETUP gt CURRENT SENSING gt V PHASE CT PRIMARY 1000 A Measured values should be 10 A gt Inject the values shown in the table below verify accuracy of the measured values gt View the measured values in the 2 METERING DATA gt V CURRENT METERING menu Injected Current Expected Measured Current 1AUnit 5A Unit Current Phase A Phase B Phase C 0 1 A 0 5 A 100 A 0 2 A 10A 200A 0 5 A 2 5A 500A 1A 5A 1000A 15A 7 5 A 1500 A 2 10 2000 7 2 2 Phase Voltage Input Accuracy The specification for phase voltage input accuracy is 0 5 of full scale 200 V Perform the steps below to verify accuracy gt Alter the following setpoints in the S2 SYSTEM SETUP gt V VOLTAGE SENSING menu VT CONNECTION TYPE Wye VOLTAGE TRANSFORMER RATIO 10 00 1 Measured values should be 1 0 V gt Apply the voltage values shown in the table and verify accuracy of the measured values gt View the measured values in the 2 METERING DATA gt V VOLTAGE METERING menu Applied Line Expected Voltage Measured Voltage Neutral Voltage Reading A N BN CN 30V 300V 50V 500 V 100V 1000 V 150V 1500 V 7 4 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 7 TESTING 7
366. wn only for positive real and positive reactive power Watts vars Peak demand will not update if a digital input programmed as Test Input is shorted 6 3 6 Analog Inputs PATH ACTUAL VALUES V 2 METERING DATA D V ANALOG INPUTS ANALOG P ANALOG I P 1 Range 50000 to 50000 INPUTS 0 Units ANALOG I P 2 Range 50000 to 50000 0 Units ANALOG I P 3 Range 50000 to 50000 0 Units ANALOG I P 4 Range 50000 to 50000 0 Units MESSAGE MESSAGE These messages are seen only if the corresponding Analog Inputs are programmed The 1 actual messages reflect the Analog Input Names as programmed NOTE The values for analog inputs are shown here The name of the input and the units will reflect those programmed for each input If no analog inputs are programmed in the s11 ANALOG I O setpoints page the THIS FEATURE NOT PROGRAMMED flash message will appear when an attempt is made to enter this group of messages 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL CHAPTER 6 ACTUAL VALUES 6 3 7 Speed PATH ACTUAL VALUES V 2 METERING DATA D V SPEED If the Tachometer function is assigned to one of the digital inputs its speed be viewed here If no digital input is configured for tachometer the THIS FEATURE NOT PROGRAMMED flash message will appear when an attempt is made to enter this group of messages 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 6 21 CHAPTER 6 ACTUAL VALUES 6 4 Lea
367. xiliary contact is also used in the ground directional element as is the breaker auxiliary contact as discussed later If all the generators are left grounded through the same impedance the neutral overvoltage element in each relay will respond to a ground fault in any of the generators For this reason the ground directional element should be used in each relay in addition to the neutral overvoltage element Common Grounding G1 Breaker Impedance FFF Y 1 Aux Isolating Contact Aux Trans d Contact 489 Vneutral Relay Grounding G2 Tix Breaker Switch CN YA jore ec D VY YY Y l Aux Hes EN 489 Vneutral Relay Other Generators as the case may be 808737A1 CDR FIGURE A 2 Parallel Generators with Common Grounding Impedance 1 3 Ground Overcurrent Element The ground overcurrent element can be used as a direct replacement or a backup for the neutral overvoltage element with the appropriate current signal from the generator neutral point for grounded generators This element can also be used with a Core Balance CT either in the neutral end or the output end of the generator as shown below The use of the special CT with its dedicated input to the relay offers very sensitive current detection but still does not offer protection for
368. y accuracy of the measured values View the measured values in the 2 METERING DATA D V POWER METERING menu Injected Current Applied Voltage Power Quantity Power Factor Ia is the reference vector 1A UNIT 5 A UNIT Expected Tolerance Measured Expected Measured la 1AZ0 la 5AZ0 Ib 1AZ120 lag Ib 5 AZ120 lag Ic 1AZ240 lag Ic 5 4240 lag 3355 to 120V 2342 lag la 120VZ342 lag 342 W 3493 kw 0 95 lag Vb 120VZ102 lag Vb 120 VZ102 lag 120VZ222 lag Vc 120 VZ222 lag la 1AZ0 la 5AZ0 Ib 1AZ120 lag Ib 5 AZ120 lag Ic 1AZ240 lag Ic 5 AZ240 lag 3355 to Va 120VZ288 lag Va 120V 2288 lag 3424 kvar 3493 kvar 0 31 lag Vb 120 VZ48 lag Vb 120 VZ48 lag Vc 120 VZ168 lag Vc 120 VZ168 lag 7 3 3 Reactive Power Accuracy The specification for reactive power is 1 of 3 x 2 x CT x VT X VT full scale Ot lavg lt 2 x CT Perform the steps below to verify accuracy and trip element gt In the S2 SYSTEM SETUP gt CURRENT SENSING menu set PHASE CT PRIMARY 5000 gt In the S2 SYSTEM SETUP D V VOLTAGE SENSING menu set VT CONNECTION TYPE Wye VOLTAGE TRANSFORMER RATIO 100 1 gt In the S2 SYSTEM SETUP D V GEN PARAMETERS menu set GENERATOR RATED MVA 100 GENERATOR RATED POWER FACTOR 0 85 GENERATOR VOLTAGE PHASE PHASE 12000 The rated reactive power is 100sin cos
369. y combination of Relays ESSAGE EM MENI 24s RELAYS 2 5 5 ESSAGE THERMAL ALARM Range 10 to 10096 Used in steps of 1 LEVEL 75 Used ESSAGE THERMAL MODEL Range On Off ALARM EVENTS Off escace gt THERMAL MODEL Range Off Latched Unlatched TRIP Off ASSIGN TRIP Range Any combination of Relays ESSAGE RELAYS 1 4 1 1to4 Once the thermal model is setup an alarm and or trip element can be enabled If the generator has been offline for a long period of time it will be at ambient temperature and thermal capacity used should be zero If the generator is in overload once the thermal capacity used reaches 10096 a trip will occur The thermal model trip will remain active until a lockout time has expired The lockout time will be based on the reduction of thermal capacity from 10096 used to 1596 used This reduction will occur at a rate defined by the offline cooling time constant The thermal capacity used alarm may be used as a warning indication of an impending overload trip 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 5 89 CHAPTER 5 SETPOINTS 5 11 10 Monitoring 5 90 5 11 1 Trip Counter PATH SETPOINTS V S10 MONITORING gt TRIP COUNTER TRIP COUNTER Range Off Latched Unlatched TRIP gt ALARM Off ASSIGN ALARM Range Any combination of Relays 2 to RELAYS 2 5 5 5 TRIP COUNTER ALARM Range 1 to 50000 Trips in steps of 1 LEVEL 25 Trips TRIP COUNTER ALARM Range On Off
370. y contacts for low voltage accessible applications it is their responsibility to ensure proper insulation levels 3 2 11 IRIG B IRIG B is a standard time code format that allows stamping of events to be synchronized among connected devices within 1 millisecond The IRIG B time codes are serial width modulated formats which are either DC level shifted or amplitude modulated AM Third party equipment is available for generating the IRIG B signal This equipment may use a GPS satellite system to obtain the time reference enabling devices at different geographic locations to be synchronized Terminals E12 and F12 on the 489 unit are provided for the connection of an IRIG B signal 3 2 12 RS485 Ports Two independent two wire RS485 ports are provided Up to 32 489 relays can be daisy chained together on a communication channel without exceeding the driver capability For larger systems additional serial channels must be added It is also possible to use commercially available repeaters to increase the number of relays on a single channel to more than 32 A suitable cable should have a characteristic impedance of 120 e g Belden 9841 and total wire length should not exceed 4000 feet approximately 1200 metres Commercially available repeaters will allow for transmission distances greater than 4000 ft 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 3 17 CHAPTER 3 INSTALLATION Voltage differences between remote ends of the
371. y is a microprocessor based relay designed for the protection and management of synchronous and induction generators The 489 is equipped with 6 output relays for trips and alarms Generator protection fault diagnostics power metering and RTU functions are integrated into one economical drawout package The single line diagram illustrates the 489 functionality using ANSI American National Standards Institute device numbers 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 2 1 2 2 MOnoyg lion sequential tripping logic trip coil supervision 5 amp ANSI PROTECTION e 12 overspeed e 21 distance e 24 volts hertz e 21 undervoltage 50 27 inadvertent generator energization 32 reverse power low forward power 38 bearing overtemperature RTD 39 bearing vibration analog inputs 40 loss of excitation impedance e 400 loss of field reactive power e 46 negative sequence overcurrent Ft 47 voltage phase reversal 49 stator thermal RTD thermal model 50 high set phase overcurrent 50 breaker failure detection 50 offline overcurrent 50 51GN ground overcurrent 51V voltage restrained phase overcurrent e 59 overvoltage 59GN 27TN 100 stator ground 60 VT fuse failure 67 ground directional 76 overex
372. y pins on the locking handle which cannot be fully lowered to the locked position until the electrical connections are completely mated Any 489 can be installed in any 489 case except for custom manufactured units that are clearly identified as such on both case and unit and are equipped with an index pin keying mechanism to prevent incorrect pairings No special ventilation requirements need to be observed during the installation of the unit but the unit should be wiped clean with a damp cloth 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 3 1 CHAPTER 3 INSTALLATION 7 25 184 i E 999 225255202 29295 5555000095 55552 MP 5555000095 le ii P 9 209090006 M 9 93 i d b 252 Uu 532405255 229 555559595 000000000 r D o 925220500 000000000 E soo Go Ge eoe E 000000000000000009 X 999999000099990009 9 909090900000000000 ccr k 9555500099 Ec 292899998 999999 1 y 1 I 1 808750E6 DWG Panel INCHES SIDE VIEW REAR VIEW kar isa PANEL CUTOUT mm
373. y used to provide a backup protection for a step up transformer and generator system bus protection generator impedance should not be included into reach setting The reach is set to cover the step up transformer impedance with some margin say 25 The time delay should be coordinated with step up transformer and bus backup protection The second zone reach is typically set to cover the longest transmission line or feeder leaving the generating station Care must be taken for possible under reaching effects due to the fault contribution from other lines or generators The element is intended for backup protection and therefore time delay should always be included This element is typically set to coordinate with the longest operating time of the system distance relays protecting lines leaving station The measuring point of the element is defined by the location of the VT and CT as shown in FIGURE 5 11 Distance Element Setup on page 57 Therefore the impedance of the step up transformer should be included and the impedance of the generator should not be included Care should also be taken to ensure the apparent impedance seen by the element when the machine is operating at worst case load and power factor does not encroach into the operating characteristic The reach setting is in secondary ohms The minimum operating time of the element is 150 ms to coordinate with VTFF operating time 99 ms 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUA
374. ys the setpoints menu header SETPOINTS P gt Press MESSAGE or ENTER SETPOINTS gt 81 489 SETUP Press MESSAGE Y SETPOINTS gt gt Press m CURRENT gt Press PHASE CT PRIMARY S2 SYSTEM SETUP MESSAGE gt SENSING MESSAGE gt 600 A or ENTER or ENTER Press GROUND CT MESSAGE Y 1 A Secondary Press GROUND CT RATIO MESSAGE V 100 1 Press the VALUE keys until 200 1 is displayed GROUND CT RATIO or enter the value directly via the numeric 299 1 keypad NEW SETPOINT HA Press the ENTER key to store the setpoint BEEN STORED To set the VT connection type and ratings modify the 52 SYSTEM SETUP gt V VOLTAGE SENSING gt V VT CONNECTION TYPE and the S2 SYSTEM SETUP gt V VOLTAGE SENSING gt V VOLTAGE TRANSFORMER RATIO Setpoints as shown below gt Press the MENU key until the relay displays the setpoints menu header SETPOINTS gt Press MESSAGE p or ENTER SETPOINTS gt 81 489 SETUP Press MESSAGE Y SETPOINTS gt Press m CURRENT D S2 SYSTEM SETUP MESSAGE gt SENSING or ENTER Press VOLTAGE gt Press VT CONNECTION TYPE MESSAGE SENSING MESSAGE P None or ENTER Press the VALUE keys until VI CONNECTION TYPE Open Delta is displayed Jopen Delta NEW SETPOINT HAS Press the ENTER key to store the setpoint BEEN STORED 489 GENERATOR MANAGEMENT RELAY INSTRUCTION MANUAL 1 13 CHAPTER 1 GETTING STARTED Press VOLTAGE TRANSFORMER

489 Generator Management Relay Instruction Manual *1601-0150-AD

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