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1. 35D Voltage protection 355 Circuit breaker failure protection CBFP 358 Magnetizing inrush 68F2 359 Over exieitauorn 695 359 Frequency protection 360 l OWer DIOIG CIO ados tit Eod vim Ee 362 oynchrocheck function 362 Arc fault detection option 363 SUPDOMING TUNG HONS totus 364 366 TT TT 368 E ee eee eee LM MM LI MEM LM ME 371 2015 Schneider Electric All rights reserved 7 Table of Contents 2015 Schneider Electric All rights reserved 63230 218 205 Section 1 General Abbreviations Section 1 General safety precautions A DANGER HAZARD OF ELECTRIC SHOCK EXPLOSION OR ARC FLASH e Apply appropriate personal protective equipment PPE and follow safe electrical work practices See NFPA 70E NOM 029 STPS 2011 and CSA Z462 e This unit must be installed and serviced only by qualified electrical personnel Turn off all power supplying this unit before working on or inside the unit e Always use a properly rated voltage sensing device to confirm that the power is off A live current transformer secondary circuit must not be opened without turning off the primary sid
2. 0 2 0 1 k 20 k 10 0 08 0 06 k 0 5 k 1 k 2 5 O 4 5 6 I Iset 7 8 10 20 I Figure 5 54 ANSI IEEE short time extremely inverse delay 2015 Schneider Electric All rights reserved 157 Inverse time operation oection 6 Supporting functions IEEE2 inverse time operation Before the year 1996 and ANSI standard C37 112 microprocessor relays were using equations approximating the behavior of various induction disc type relays A popular approximation is Equation 5 Which in VAMP relays is called IEEE2 Another name could be IAC because the old General Electric IAC relays have been modeled using the same equation There are four different delay types according Table 5 54 The old electromechanical induction disc relays have inverse delay for both trip and release operations However in VAMP relays only the trip time is inverse the release time being constant The operation delay depends on the measured value and other parameters according Equation 5 7 Actually this equation can only be used to draw graphs or when the measured value l is constant during the fault A modified version is implemented in the relay for real time usage Equation 5 7 NN D E l Le ae I C Dow i J vi PICKUP ecko t Operation delay in seconds User s multiplie
3. Parameter Value Unit Description Measured value f Hz Frequency df dt Hz s Frequency rate of change Recorded values SCntr Start counter Start reading TCntr Trip counter Trip reading Fit Hz s Max rate of change fault value EDly Elapsed time as compared to the set operating time 100 tripping 63230 218 204 2014 Schneider Electric All rights reserved 129 Synchrocheck 25 Section 5 Protection functions oynchrocheck 25 130 The device includes a function that will check synchronism when the circuit breaker is closed The function will monitor voltage amplitude frequency and phase angle difference between two voltages Since there are two stages available it is possible to monitor three voltages The voltages can be busbar and line or busbar and busbar bus coupler Note For NEMA U V While using the synchrocheck function normal measuring modes cannot be used Therefore 2LL LLy 1LL U LLy or LL LLy LLz voltage measuring mode must be selected to enable synchrocheck function If 2LL LLy or 1LL U LLy mode is selected one stage is available The LL LLy LLz mode enables using two stages The voltage used for sychrochecking is always phase to phase voltage V42 The sychrocheck stage 1 compares V1 with 2 always The compared voltages for the stage 2 can be selected 2014 Schneider Electric All rights reserved 63230 218 204 Section 5 Prote
4. 36 Configuration and parameter setting 38 Parameter setting 40 Setting range limits seeesseeesseseees 41 Disturbance recorder menu DR 41 Configuring digital inputs DI 42 Configuring digital outputs DO 43 Protection menu Prot 43 Configuration menu CONF 43 Protocol menu Bus 45 Single line diagram editing 50 Blocking and Interlocking configuration 50 Section 3 VAMPSET PC software ccccccsecccseeceseeeeseeceseeeeseeeeseeeeeeeeeseeceseeeeseeeeseeeeseeeesees 51 DECHOM A MU UCO 52 UOI at Il GB 5 Principles of numerical protection techniques 54 F COC CHOM UCT OMS 56 Maximum number of protection stages in one application MAARN EEEE E EEEE EE 56 63230 218 205 2015 Schneider Electric All rights reserved 3 section 6 Supporting functions Table of Contents General features of protection stages 56 APDIICATIOMIMOOES 61 Current protection function dependencies 62 Overcurrent
5. Parameter Value Unit Description Protocol Protocol selection for extension port Set None SPA bus SPA bus slave ProfibusDP Profibus DB slave ModbusSla Modbus RTU slave ModbusTCPs IEC Modbus TCP slave 103 IEC 60870 5 103 slave ExternallO Modbus RTU master for external I O modules DNP3 DNP 3 0 Msg 0 232 1 Message counter since the device has restarted Clr since last clearing Errors 0 216 1 Detected protocol errors since the device has Clr restarted or since last clearing Tout 0 216 1 Detected timeout errors since the device has Clr restarted or since last clearing speed DPS Display of current communication parameters 1 Default 38400 8N1 Speed bit s for VAMPSET D number of data bits P parity none even odd S number of stop bits Set An editable parameter password needed Clr Clearing to zero is possible 1 The communication parameters are set in the protocol specific menus For the local port command line interface the parameters are set in configuration menu 63230 218 205 2015 Schneider Electric All rights reserved 263 Communication ports Ethernet port Section 9 Communication TCP port 1 INST and TCP port 2nd INST are ports for ethernet communication protocols Ethernet communication protocols can be selected to these ports when such hardware option is installed The parameters for these ports are set via local HMI or with VAMPSET in menus TCP po
6. 63230 218 205 2015 Schneider Electric All rights reserved 151 Inverse time operation Section 6 Supporting functions IEC inverse time operation The operation time depends on the measured value and other parameters according Equation 5 5 Actually this equation can only be used to draw graphs or when the measured value l is constant during the fault A modified version is implemented in the relay for real time usage t Operation delay in seconds Equation 5 5 un User s multiplier kA Measured value t I User s pick up setting PICKUP VT pickup J A B Constants parameters according Table 5 52 There are three different delay types according IEC 60255 3 Normal inverse NI Extremely inverse El Very inverse VI and a VI extension Additional there is a de facto standard Long time inverse LTI Table 5 52 Constants for IEC inverse delay equation Delay type Parameter Normal inverse Extremely inverse Very inverse Long time inverse 152 2015 Schneider Electric All rights reserved 63230 218 205 oection 5 Protection functions Inverse time operation Example for Delay type Normal inverse NI k 0 50 2 4 pu constant current IPickuP 2 pu A 0 14 0 02 0 50 0 14 t 5 0 4 eet 2 The operation time in this example will be 5 seconds The same result can be read from Figure 5 45 63230 218 205
7. Min 0 1 1 2 3 4 Measured slope df dt Hz s Figure 5 37 Three examples of possible inverse df dt operation time characteristics The slope and operation delay settings define the knee points on the left A common setting for tMin has been used in these three examples This minimum delay parameter defines the knee point positions on the right 2014 Schneider Electric rights reserved 63230 218 204 Section 5 Protection functions FREQUENCY Hz 50 0 49 7 TRIP Rate of change of frequency ROCOF 81R v3 Settings df dt 0 5 Hz s 7o 0 60 s tin 0 15 8 v f amp TIME P S 5 Figure 5 38 An example of inverse df dt operation time The time to trip will be 0 3 s although the setting is 0 6 s because the average slope 1 Hz s is steeper than the setting value 0 5 Hz s Table 5 35 Setting parameters of df dt stage Parameter Value Unit Default Description df dt 0 2 10 0 Hz s 5 0 df dt pick up setting gt 0 14 10 0 0 50 df dt operational delay tMin gt 0 14 10 0 S 0 50 df dt minimum delay o On Enabled Disabled Enabled Start on event S_ Off Enabled Disabled Enabled Start off event T On Enabled Disabled Enabled Trip on event T Off Enabled Disabled Enabled Trip off event Table 5 36 Measured and recorded values of df dt stage
8. S cc 5 NOTE For the phases L1 A L2 B and L3 C Figure 11 18 Connection example of VAMP 255 without an open delta voltage transformer The device is calculating the zero sequence voltage The voltage measurement mode is set to 3LN 390 2015 Schneider Electric All rights reserved 63230 218 205 Section 11 Connections Block optional diagrams coc cn eral 1999999999 99 9 599 3 15 Xa 12 X3 13 XT 17 XT 18 XT 15 XT 16 X3 9 X4 X5 e X3 14 NES JS e d i Oem sf Cc F gt E 7 v on o LI 0707090000009 F F OE OK OK OK OK OK OS 34D E IT HE NOTE For the phases L1 A L2 B and L3 C Figure 11 19 Connection example of VAMP 255 with V connected voltage transformers The voltage measurement is set to 2LL Upo Directional ground fault stages are not available without the polarizing Ug voltage 63230 218 205 2015 Schneider Electric All rights reserved 331 Block diagrams of option modules Section 11 Connections O9Lznrnnzus CEC o x E X XXX XX X RLV e ds N i lt 1 gt _ mm 8 dao 000000 000000 8 600006 8 XXX EO0XX oiostioor coc
9. Fundamental value ho 15 2 Harmonics Example h 100A h 10 hz 3A h4 8 A THD N10 3 8 _ 132 100 For reference the RMS value is RMS 100 10 3 8 100 9A Another way to calculate THD is to use the RMS value as reference instead of the fundamental frequency value In the example above the result would then be 13 0 2015 Schneider Electric All rights reserved 213 Demand values Section 7 Measurement functions Demand values The relay calculates average i e demand values of phase currents la lc and power values 5 P and Q The demand time is configurable from 10 minutes to 30 minutes with parameter Demand time Table 7 10 Demand value parameters Parameter Value Description Time 10 30 Demand time averaging time Fundamental frequency values IL1da Demand of phase current IL 1 IL2da Demand of phase current IL2 IL3da Demand of phase current IL3 Pda Demand of active power P PFda Demand of power factor PF Qda Demand of reactive power Q Sda Demand of apparent power S RMS values IL1da A Demand of phase current IL1 IL2da A Demand of phase current IL2 IL3da A Demand of phase current IL3 Set An editable parameter password needed L1 L2 and L3 are IEC phase names For NEMA the phases are as follows L1 A L2 B and L3 C Minimum and maximum values Minimum and maximum val
10. Parameter Value Unit Description Note Status Current status of the stage Blocked Start F Trip SCntr Cumulative start counter C TCntr Cumulative trip counter C SetGrp 1or2 Active setting group Set SGrpDI Digital signal to select the active setting group Set None DIx Digital input VIx Virtual input LEDx LED indicator signal VOx Virtual output Force Off Force flag for status forcing for test purposes This is a Set common flag for all stages and output relays Automat On ically reset by a 5 minute timeout 2 1 Imot The supervised value l2 Imot Pick up setting Set t gt S Definite operation time Type DT Set Type DT Definite time Set INV Inverse time Equation 5 1 K1 S Delay multiplier Type INV Set Set An editable parameter password needed C Can be cleared to zero Editable when force flag is on For details of setting ranges see section Protection functions Hecorded values of the latest eight faults There is detailed information available of the eight latest faults Time stamp unbalance current elapsed delay and setting group Table 5 10 Recorded values of the current unbalance stage 8 latest faults l5 46 in motor mode Parameter Value Unit Description yyyy mm dd Time stamp of the recording date hh mm ss ms Time stamp time of day Fit Imot Maximum unbalance current EDly Elapsed time of the operating time setting 100 tri
11. M Beuotot Herena E FO00000 do0000 8 X7 11 0116 Ar 14 comm f X7 12 DI17 X7 13 0118 c Figure 5 43 Two synchrocheck stages needed with LL LLy LLz mode 63230 218 205 2015 Schneider Electric All rights reserved 137 Magnetishing inrush gt 68F2 Section 5 Protection functions Magnetishing inrush lp gt 68F2 This stage is mainly used to block other stages The ratio between the second harmonic component and the fundamental frequency component is measured on all the phase currents When the ratio in any phase exceeds the setting value the stage gives a start signal After a settable delay the stage gives a trip signal The start and trip signals can be used for blocking the other stages The trip delay is irrelevant if only the start signal is used for blocking The trip delay of the stages to be blocked must be more than 60 ms to help ensure a proper blocking 2ndHarm Setting 2 Harm Delay Enable events Figure 5 44 Block diagram of the magnetishing inrush stage Table 5 40 Setting parameters of magnetishing inrush blocking 68F2 Parameter Value Unit Default Description If2 gt 10 100 10 Setting value If2 Ifund t f2 0 05 300 0 S 0 05 Definite operating time o On Enabled Disabled Enabled Start on event o Off Enabled Disabled Enabled Start off event T On Enabled Disabled Enabled
12. 20 88 V VMAX 7 Uaux 1096 121 V HcoiL U2 Aux P 242 Note For NEMA U V 63230 218 205 2015 Schneider Electric All rights reserved 287 288 Rear panel Section 11 Connections The external resistance value is calculated using Equation 10 1 Equation 10 1 nol SIN R 88 18 0 003 242 0 003 23 1 In practice the coil resistance has no effect By selecting the next smaller standard size we get 22 kO The power rating for the external resistor is estimated using Equation 10 2 and Equation 10 3 The Equation 10 2 is for the CB open situation including a 100 margin to limit the maximum temperature of the resistor Equation 10 2 2 15 2 0 003 2x22000 0 40 W Select the next bigger standard size for example 0 5 W When the trip contacts are still closed and the CB is already open the resistor has to withstand much higher power Equation 10 3 for this short time Equation 10 3 p Ul R 121 2 22000 0 67 W A 0 5 W resistor will be enough for this short time peak power too However if the trip relay is closed for longer time than a few seconds a 1 W resistor should be used NOTE The final resistor selection is dependent on the specifications of the application Using any of the non dry digital inputs DI1 DI6 In this scheme an auxiliary relay is needed to connect the wet digital input to the trip circuit Figure 10 10 The rated coil vo
13. using the other inputs of the same group sharing a common terminal is limited e When using the wet digital inputs DI1 DI6 an auxiliary relay is needed 2015 Schneider Electric All rights reserved 63230 218 205 Section 10 Application Trip circuit supervision Using any of the dry digital inputs DI7 NOTE In VAMP 230 only the optional digital inputs DI19 and DI20 are dry see the ordering code for this option r TT Vax 24 Vdc 240 Vdc Digital input Trip relay Alarm relay for trip circuit failure relay compariment trip circuit failure alarm circuit breaker compartment relay compartment e e e u cm circuit breaker compartment CB close control TR ve OPEN COIL eee ue CLOSE COIL TCS1Diclosed Figure 10 6 Trip circuit supervision using a single digital input and an external resistor R The circuit breaker is in the closed position The supervised circuitry in this CB position is double lined The digital input is in active state when the trip circuit is complete This is applicable for dry inputs DIZ DI20 63230 218 205 2015 Schneider Electric All rights reserved 285 Rear panel Section 11 Connections VAMP relay tV 24 Vdc 240 Vdc Trip relay Alarm relay for trip circuit failure trip circuit failure alarm EO LLLA eee 1
14. 2015 Schneider Electric All rights reserved 153 Inverse time operation 600 400 100 60 40 20 delay s 0 8 0 6 0 4 0 2 0 1 0 08 0 06 k 20 k 10 k 5 k 2 k 1 k 0 5 k 0 2 k 0 1 k 0 05 3 4 5678 I Iset 10 Figure 5 45 IEC normal inverse delay 600 400 200 100 80 60 40 20 delay s 0 8 0 6 0 4 0 2 0 1 0 08 0 06 20 VI k 20 k 10 k 5 k 2 1 k 0 5 k 0 2 k 0 1 k 0 05 3 4 5678 I Iset 10 Figure 5 47 IEC very inverse delay 154 20 600 400 100 80 60 40 20 delay s 0 8 0 6 0 4 0 2 0 1 0 08 0 06 Section 6 Supporting functions IEC EI k 20 k 10 k 5 k 2 k 1 k 0 5 0 05 0 1 NC k 0 2 3 4 5678 I Iset 10 20 Figure 5 46 IEC extremely inverse delay 600 400 200 100 80 60 40 20 delay s 0 8 0 6 0 4 0
15. 68 2015 Schneider Electric All rights reserved 63230 218 205 Section 5 Protection functions Directional phase overcurrent lo gt 67 63230 218 205 NOTE If the maximum possible ground fault current is greater than the most sensitive directional over current setting used the device has to be connected to the line to neutral voltages instead of line to line voltages in order to get the right direction for ground faults For networks having the maximum possible ground fault current less than the over current setting use 67N the directional ground fault stages res Re SER IPAREA 30 BASEANGLE FAULT cap ind 90 Idir angle2 Figure 5 8 Example of protection area of the directional overcurrent function Three modes are available dirctional non direct and directional back up Figure 5 9 In the non directional mode the stage is acting just like an ordinary overcurrent 50 51 stage Directional back up mode works the same way as directional mode but it has undirectional back up protection in case a close up fault will force all voltages to about zero After the angle memory hold time the direction would be lost Basically the directional backup mode is required when operation time is set longer than 0 5 s and no other undirectional back up protection is in use 2015 Schneider Electric All rights reserved 69 Directional phase overcurrent lj 67 Section 5 Protection functions 4 90
16. Changed phase angle of the unbalance current after automatic compensation 11 12 and L3 are IEC phase names For NEMA the phases are as follows L1 A L2 B and L3 C 63230 218 205 2015 Schneider Electric All rights reserved 107 Zero sequence voltage protection Ug 59 Section 5 Protection functions Zero sequence voltage protection Vo 59N 108 The zero sequence voltage protection is used as unselective backup for ground faults and also for selective ground fault protections for motors having a unit transformer between the motor and the busbar This function is sensitive to the fundamental frequency component of the zero sequence voltage The attenuation of the third harmonic is more than 60 dB This is essential because 3n harmonics exist between the neutral point and ground also when there is no ground fault Whenever the measured value exceeds the user s pick up setting of a particular stage this stage picks up and a start signal is issued If the fault situation remains on longer than the user s operation time delay setting a trip signal is issued Measuring the zero sequence voltage The zero sequence voltage is either measured with three voltage transformers e g open delta connection one voltage transformer between the motor s neutral point and ground or calculated from the measured phase to neutral voltages according to the selected voltage measurement mode see the section Voltage measur
17. Description Measured values recor ded values Fault ph Fault phase information X Fault reactance Date Fault date Time Fault time Time ms Fault time Count Number of faults 210 2015 Schneider Electric All rights reserved 63230 218 205 oection 7 Measurement functions Measurement accuracy Section 7 Measurement functions All the direct measurements are based on fundamental frequency values The exceptions are frequency and instantaneous current for arc detection The figure shows a current waveform and the corresponding fundamental frequency component f1 second harmonic f2 and rms value in a special case when the current deviates significantly from a pure sine wave 4 4 02d 0 og fef 6 5 TN 1 ur WE M my P gt SS AT oe E E E E 1 Lb A E Lp AB2a 424 Relative 2nd harmoic f2 f1 96 005 O10 015 020 025 030 Time s Figure 7 1 Example of various current values of a transformer inrush current Measurement accuracy Table 7 1 Phase current inputs A B C Measuring range 0 025 250A Inaccuracy IS 7 5 0 5 96 of value or 15 mA gt 7 5 3 96 of value The specified frequency range is 45 Hz 65 Hz Squelch limit Phase current inputs 0 5 of Inom tolerance 0 0
18. E E E pulse TEST Test the exported energy pulse Eq E E pulse TEST Test the exported reactive energy E E E pulse TEST Test the imported energy Eq E E pulse TEST Test the imported reactive energy IL1 I PHASE CURRENTS Phase current ILA A IL2 I PHASE CURRENTS Phase current ILB A IL3 I PHASE CURRENTS Phase current ILC A IL1da I PHASE CURRENTS 15 min average for A A IL2da I PHASE CURRENTS 15 min average for B A I PHASE CURRENTS 15 min average for C A lo SYMMETRIC CURRENTS Primary value of zero sequence residual current lo A lo2 SYMMETRIC CURRENTS Primary value of zero sequence residual current lo2 A loC SYMMETRIC CURRENTS Calculated lo A 1 SYMMETRIC CURRENTS Positive sequence current A 12 SYMMETRIC CURRENTS Negative sequence current A 12 11 SYMMETRIC CURRENTS Negative sequence current related to positive sequence current for unbalance protection THDIL I HARM DISTORTION Total harmonic distortion of the mean value of phase currents THDIL 1 I HARM DISTORTION Total harmonic distortion of phase current A 96 THDIL2 I HARM DISTORTION Total harmonic distortion of phase current B 96 THDIL3 I HARM DISTORTION Total harmonic distortion of phase current C 95 Diagram I HARMONICS of IL 1 Harmonics of phase current A 96 See Figure 2 12 Diagram I HARMONICS of IL2 Harmonics of phase current B 95 See Figure 2 12 Diagram I HARMONICS of IL3 Harmonics of phase current C
19. HeclT RECLAIMTIME STARTTIME DEADTIME DISCRIMINATIONTIME The currently running time or last executed Total start counter Fail The counter for unsuccessful AR shots Shot1 Shot1 start counter Shot2 Shot2 start counter Shot3 Shot3 start counter Shot4 Shot4 start counter Shot5 Shot5 start counter 2015 Schneider Electric All rights reserved 63230 218 205 Section 8 Control functions Auto reclose function 79 c amp E E o T lt CN G O O o s E SE OE 0 a O a E X gt settlng oon o M Current Close CB CBclose state CBopen state 1 2 3 4 5 6 7 8 9 10 AR Signals Figure 8 5 Example sequence of two shots After shot 2 the fault is cleared Current exceeds the I setting the start delay from shot 1 starts After the start delay an OpenCB relay output closes A CB opens The dead time from shot 1 starts and the OpenCB relay output opens 4 The dead time from shot 1 runs out a CloseCB output relay closes 5 The CB closes The CloseCB output relay opens and the discrimination time from shot 1 starts The current is still over the gt setting 6 The discrimination time from the shot 1 ru
20. Protection menu Prot The following functions can be read and set via the submenus of the Prot menu 1 Reset all the counters PROTECTION SET CIAII 2 Read the status of all the protection functions PROTECT STATUS 1 x 2 Enable and disable protection functions ENABLED STAGES 1 m X 4 Define the interlockings using block matrix only with VAMPSET Each stage of the protection functions can be disabled or enabled individually in the Prot menu When a stage is enabled it will be in operation immediately without a need to reset the relay The relay includes several protection functions However the processor capacity limits the number of protection functions that can be active at the same time Configuration menu CONF 63230 218 205 The following functions and features can be read and set via the submenus of the configuration menu Device setup e Bit rate for the command line interface in ports X4 and the front panel The front panel is always using this setting If SPABUS is selected for the rear panel local port X4 the bit rate is according SPABUS settings 2015 Schneider Electric All rights reserved 43 Configuration and parameter setting Section 2 Local panel user interface e Access level Acc Language e List of available languages in the relay Current scaling e Rated phase CT primary current Inom e Rated phase CT secondary current Isec e Rated input of the relay linput 5 A or
21. Related documents Document Tite Website VAMPSET Setting and Configuration http www schneider electric us sites us en support 63230 218 207 Tool User Manual documents downloads page Communication parameters for VAMP http www schneider electric com ww en download document FA225826 255 Modbus Profibus SPA bus VAMP 210 230 255 257 259 260 265 cp showAslframe DNE OD IEC101 IEC103 Modubus true amp xtmc IEC962520101962520profile 62520checklist amp xtcr 2 Master ProfibusDP Download the latest software at http www schneider electric com products ww en 2300 ied user software 2320 vamp user software 62050 vamp software xtmc vamp amp xtcr 2 2015 Schneider Electric All rights reserved 12 63230 218 205 Section 1 General Abbreviations Abbreviations E UJ Alarm Contact 1 ANSI American National Standards Institute a standardization organization O Circuit breaker CBFP Circuit breaker failure protection Active power divided by apparent power P S See power factor PF Negative sign COSQ indicates reverse power Current transformer Nominal primary value of current transformer Nominal secondary value of current transformer See hysteresis Digital input Digital output output relay Stores information about the IED settings events and fault logs Data set ready An RS232 signal Input in front panel port of VAMP relays to disable CT pri CT sec
22. The pin assignments of communication connectors including internal communication converters are presented in the following figures and tables Front panel connector U 3 RS232 signal Not connected Rx in Tx out DTR out 8 V GND DSR in activates this port and disables the X4 RS232 port RTS in Internally connected to pin 8 Figure 11 5 Pin numbering of the front panel D9S connector CTS out Internally connected to pin 7 IRIG B input Oo O N O oo A C PD NOTE DSR must be connected to DTR to activate the front panel connector and disable the rear panel X4 RS232 port The other port in the same X4 connector will not be disabled 63230 218 205 2015 Schneider Electric All rights reserved 311 Serial communication connection Section 11 Connections Rear panel connector X5 REMOTE The X5 remote port communication connector options are shown in Figure 11 6 The connector types are listed in Table 11 1 Without any internal options X5 is a T TL port for external converters some external converters VSE are attached directly to the rear panel and X5 Some other types VEA VPA need various TTL RS 232 converter cables The available accessories are listed in Section 14 Order information 2 amp 4 wire galvanically isolated RS 485 Figure 11 7 internal options for fiber optic Figure 11 8 and Profibus Figure 11 9 are available oee ordering code in Section 14 Order information Tabl
23. ZA x mA option mA i X211 NI X2 2 MM AO2 1 X2 5 Lo x2 6 i s o xaa Figure 11 12 Block diagram of VAMP 255 with the mA option included 2015 Schneider Electric All rights reserved 325 Block optional diagrams Section 11 Connections VAMP 230 0 6 dINVA X3 1 Figure 11 13 Block diagram of VAMP 230 326 2015 Schneider Electric All rights reserved 63230 218 205 Section 11 Connections Block optional diagrams X3 17 T Front N Local X1 1 lt lA gt 4 5 e Remote X1 3 e 4i As OU TL X3 14 c 5 X1 6 NO T2 n X1 8 E 0 2 D C X3 13 X1 9 lien C Al X3 9 X1 10 Mn Z X3 11 X1 11 A2 vie 3t X2 13 X1 12 71 CU X1 13 X245 X2 10 X1 14 Z 2 11 X1 17 a Vo jit X1 18 E SF 2 16 Option Block X2 17 zo X2 18 X6 2 X6 4 mA option X6 5 X6 6 m X2 1 X2 2 qud48V X2 3 p AO X2 4 X3 3 012 X34 D3 _ Hee X3 5 014 AO3 yo X3 6 DI5 NE X3 7 DIG m X2 7 X2 8 Figure 11 14 Block diagram of VAMP 230 with mA option included 63230 218 205 2015 Schneider Electric All rights reserved 32 Block diagrams of option modules Section 11 Connections Block diagrams of option modules Block diagrams of optional arc modules Options odds BI OY 7A I S
24. dics K1Min R 104 5 96 0 0048 242 1529 O By selecting the next smaller standard size we get 1 5 kQ The power rating for the external resistor is calculated using Equation 10 5 This equation includes a 100 margin to limit the maximum temperature of the resistor because modern resistors are extremely hot at their rated maximum power Equation 10 5 2 P 2 Ikim R P 2 0 0061 2x1500 0 11 W Select the next bigger standard size for example 0 5 W When the trip contacts are still closed and the CB is already open the resistor has to withstand much higher power Equation 10 3 for this short time P 121 2 1500 9 8 W A 1 W resistor should be selected to withstand this short time peak power However if the trip relay can be closed for longer time than a few seconds a 20 W resistor should be used NOTE The final resistor selection is dependent on the specifications of the application 63230 218 205 2015 Schneider Electric All rights reserved 291 Rear panel Section 11 Connections Trip circuit supervision with two digital inputs NOTE 292 The benefits of this scheme is that no external resistor is needed The drawbacks are that two digital inputs from two separate groups are needed and two extra wires from the relay to the CB compartment is needed Additionally the minimum allowed auxiliary voltage is 48 Vdc which is more than twice the threshold voltage of the dry digital
25. 1 Example of limitation VAMP 255 CT 750 5 Application mode is Feeder CTo2 100 1 cable CT is used for residual current The CTg is connected to a 1 A terminals of input 103 For overcurrent stage I gt the table above gives 12 5 A Thus the maximum setting for I stage giving full inverse delay range is 125A 5A 2 5 Xl y 1875 A Primary For ground fault stage l gt the table above gives 0 5 A Thus the maximum setting for l gt stage giving full inverse delay range is 0 5A 1A20 5 Xlon 50 A Primary 2 Example of limitation VAMP 255 CT 750 5 Application mode is Motor Rated current of the motor 600 A locale la Ip Ic is used for residual current At secondary level the rated motor current is 600 750 5 4 For overcurrent stage I gt the table above gives 12 5 A Thus the maximum setting giving full inverse delay range is 12 5 A 4 A 3 13 x 1875 A Primary For ground fault stage l gt the table above gives 12 5 A Thus the maximum setting for l gt stage giving full inverse delay range is 12 5 5 2 5 lon 1875 A Primary 3 Example of limitations VAMP 230 CT 2750 5 Application mode is Feeder CTo 100 5 cable CT is used for residual current For overcurrent stage I gt the table above gives 12 5 A Thus the maximum setting giving full inverse delay range is 12 5 A 5A 2 5X IN 18 5 A Primary For ground fault stage l gt the table above gives 1 25 A Thus the maximum
26. 4 wire connection Echo on L L ECL 2 Left 2 wire connection Light on in idle state 2 Right 4 wire connection Light off in idle state 3 Left Termination On Not applicable 3 Right Termination Off Not applicable 4 Left Termination On Not applicable 4 Right Termination Off Not applicable Figure 11 10 Dip switches in RS 485 and optic fiber options 316 2015 Schneider Electric All rights reserved 63230 218 205 oection 11 Connections Optional two channel arc protection card X4 rear panel connector local RS232 and extension R8485 ports Rear panel port Pin Signal LOCAL No connection Rx in RS232 local Tx out RS232 local DTR out 8 V GND X4 No connection B 5485 extension port RS485 extension port OD NOKO A Co No connection NOTE In VAMP devices a positive RS485 voltage from A to B corresponds to bit value 1 In X4 connector the RS485 extension port is not galvanically isolated Optional two channel arc detection card NOTE When this option card is installed the parameter Arc card type has value 2 Please check the ordering code in Section 14 Order information If the slot X6 is already occupied with the 0119 0120 digital input card this option is not available but there is still one arc sensor channel available See the section Optional digital I O card
27. 46 lo gt gt 47 Ilgr 48 N gt 66 are always dependent on Iyot and they are only available when application mode is in the motor protection Overcurrent protection gt 50 51 62 Overcurrent protection is used against short circuit faults and overloads The overcurrent function measures the fundamental frequency component of the phase currents The protection is sensitive for the highest of the three phase currents Whenever this value exceeds the user s pick up setting of a particular stage this stage picks up and a start signal is issued If the fault situation remains on longer than the user s operation delay setting a trip signal is issued and the operation delay timer starts when the start signal is issued Three independent stages There are three separately adjustable overcurrent stages I I gt gt and gt gt gt The first stage 1 gt can be configured for definite time DT or inverse time operation characteristic IDMT The stages gt gt and gt gt gt have definite time operation characteristic By using the definite delay type and setting the delay to its minimum an instantaneous ANSI 50 operation is obtained Figure 5 5 shows a functional block diagram of the I gt overcurrent stage with definite time and inverse time operation time Figure 5 6 shows a functional block diagram of the gt gt and gt gt gt overcurrent stages with definite time operation delay Inverse operation time
28. Editable when force flag is on For details of setting ranges see section Protection functions L1 L2 and L3 are IEC phase names For NEMA the phases are as follows L1 A L2 B and L3 C Table 5 18 Parameters of the undirectional ground fault stage gt gt gt gt gt lo gt gt gt gt 5ON 51N Parameter Value Unit Description Note Status Current status of the stage Blocked Start F Trip TripTime S Estimated time to trip SCntr Cumulative start counter Clr TCntr Cumulative trip counter Clr SetGrp 1or2 Active setting group Set SgrpDI Digital signal to select the active setting group Set None Dix Digital input Vix Virtual input LEDx LED indicator signal VOx Virtual output Force Off Force flag for status forcing for test purposes This Set is acommon flag for all stages and output relays On Automatically reset by a 5 minute timeout lo The supervised value according the parameter In T put below loCalc lo gt gt lo gt gt gt lo gt gt gt gt A Pick up value scaled to primary value 96 2015 Schneider Electric All rights reserved 63230 218 205 Section 5 Protection functions Directional ground fault protection lg 67N lo gt gt lo gt gt gt lo gt gt gt gt pu Pick up setting relative to the parameter Input Set and the corresponding CT value t gt Definite operation time for
29. Inaccuracy starting 20 mHz starting LV block 3 of the set value or 0 5 V operating time 1 or 30 ms Table 12 36 Rate of change of frequency ROCOF stage df dt 81H Pick up setting df dt 1 2 10 0 Hz s step 0 1 Hz s Definite time delay t gt and tyi are equal operating time t 0 14 10 00 s step 0 02 s Inverse time delay t gt is more than tyi minimum operating time tyin gt 0 14 10 00 s step 0 02 s Start time Typically 140 ms Reset time 150 ms Retardation time 90 ms Reset ratio 1 Inaccuracy 10 of set value or 0 1 Hz s starting 35 ms when area is 0 2 1 0 Hz s operating time overshoot 2 0 2Hz s NOTE ROCOF stage 1 using the same low voltage blocking limit as the frequency stages 63230 218 205 2015 Schneider Electric All rights reserved 361 Protection functions Power protection Section 12 Technical data Table 12 37 Directional power stages P P 32 Pick up setting range 200 0 200 0 5 Definite time function Operating time 0 3 300 0 s Start time Typically 200 ms Heset time 500 ms Heset ratio 1 05 Inaccuracy Starting 3 96 of set value or 0 5 96 of rated value Operating time at definite time function 1 or 150 ms NOTE When pick up setting is 1 200 an internal block will be activated if max voltage of all phases d
30. Powerquadrant Current related Power direction coso Power factor to voltage PF inductive Lagging Forward capacitive Leading Forward inductive Leading Reverse capacitive Lagging Reverse 2015 Schneider Electric All rights reserved 63230 218 205 oection 7 Measurement functions 7 10 Symmetric components oymmetric components In a three phase system the voltage or current phasors may be divided in symmetric components according to C L Fortescue 1918 The symmetric components are e Positive sequence 1 Negative sequence 2 e Zero sequence 0 oymmetric components are calculated according the following equations e So Zero sequence component 9 positive sequence component So negative sequence component 5 14120 t 2 a phasor rotating constant Note L1 L2 and L3 are IEC phase names For NEMA the phases are as follows L1 A L2 B and L32C U V U phasor of phase L1 phase current or line to neutral voltage V phasor of phase L2 W phasor of phase L3 In case the voltage measurement mode is 2LL U i e two line to line voltage are measured the following equation is used instead HJ e que U 3 1 a 0 63230 218 205 2015 Schneider Electric All rights reserved 221 Symmetric components 222 NOTES Section 7 Measurement functions Voltage between phases L1 and L2 Us53 Voltage between phases L2 and L3
31. Ring network protection LOAD 2 LOAD 3 SUPPLY 0 650 ms 350 ms LOAD 4 200 ms 500 ms RIO LOAD 5 ring network Figure 10 5 Feeder terminals used for protection of ring main circuit with one feeding point Ring networks can be protected with complete selectivity using directional overcurrent relays as long as there is only one feeding point in the network Figure 10 5 shows an example of a ring main with five nodes using one circuit breaker at each end of each line section e g a ring main unit When there is a short circuit fault in any line section only the detected faulty section will be disconnected The calculating time in this example is 150 ms 63230 218 205 2015 Schneider Electric All rights reserved 283 Rear panel Section 11 Connections Trip circuit supervision Trip circuit supervision is used to monitor the wiring from the protective device to a circuit breaker This circuit is unused most of the time but when a protection device detects a fault in the network it is too late to detect that the circuit breaker cannot be tripped because of an open trip circuitry The digital inputs of the device can be used for trip circuit monitoring The dry digital inputs are most suitable for trip circuit supervision The first six digital inputs of VAMP 200 series relays are not dry and an auxiliary miniature relay is needed if these inputs are used for trip circuit supervision Also the
32. Table 6 17 Running hour counter parameters Parameter Value Unit Description Note Runh 0 876000 h Total active time hours Set Note The label text Runh can be edited with VAMPSET Runs 0 3599 S Total active time seconds Set Starts 0 65535 Activation counter Set Status Stop Current status of the selected digital signal Run DI Select the supervised signal Set None DI1 Din Physical inputs Vili Vin Virtual inputs LedAl Output matrix out signal Al LedTr Output matrix out signal Tr LedA Output matrix out signal LA LedB Output matrix out signal LB LedC Output matrix out signal LC LedDR Output matrix out signal DR VO1 VO6 Virtual outputs Started at Date and time of the last activation Stopped at Date and time of the last inactivation Set An editable parameter password needed Set An informative value which can be edited as well 63230 218 205 2015 Schneider Electric All rights reserved 197 lt Section 6 Supporting functions Timers The VAMP protection platform includes four settable timers that can be used together with the user s programmable logic or to control setting groups and other applications that require actions based on calendar time Each timer has its own settings The selected on time and off time is set and then the activation of the timer can be set to be as daily or according the day of week See
33. Trigger mode triggering based on sudden increase of phase current ES otherwise sudden increase of phase VH VIA current DIx VIx VO1 VO6 NI1 NI64 POC1 POC16 Line reactance 0 010 10 000 Ohms km _ 0 389 Line reactance of the line This is used only to convert the fault reactance to kilometers ditrig 10 800 9e Imode 50 Trigger current Sudden increase of phase current Blocked before next trig 10 600 70 Blocks function for the next trigger time This is used for blocking calculation in autoreclose Xmax limit 0 5 500 0 Ohm 11 0 Limit for maximum reactance If reactance value is above set limit calculation result will not be shown Event Disabled Enabled Enabled Event mask Table 6 21 Measured and recorded values of short circuit fault locator Parameter Value Unit Description Measured values Distance km Distance to the fault recorded values Xfault ohm Fault reactance Date Fault date Time Fault time Time ms Fault time Cntr Number of faults Pre A Pre fault current load current Fault A Current during the fault Post A Post fault current Udrop Un Voltage dip during the fault Durati Fault duration Type Fault type 1 2 2 3 1 3 1 2 3 63230 218 205 2015 Schneider Electric All rights reserved 205 Incomer short circuit fault locator Section 6 Supporting fun
34. t f5 0 05 300 0 0 05 Definite operating time S On Enabled Disabled Enabled Start on event o Off Enabled Disabled Enabled Start off event T On Enabled Disabled Enabled Trip on event T Off Enabled Disabled Enabled Trip off event Table 5 43 Measured and recorded values of over exicitation blocking 68F5 Parameter Value Unit Description Measured values IL1H5 5 harmonic of IL1 pro portional to the funda mental value of IL1 IL2H5 96 5 harmonic of IL2 IL3H5 5 harmonic of IL3 Recorded values Fit The max fault value EDly Elapsed time as com pared to the set operat ing time 10096 trip ping L1 L2 and L3 are IEC phase names For NEMA the phases are as follows L1 A L2 B and L3 C 63230 218 205 2015 Schneider Electric All rights reserved 139 Circuit breaker failure protection CBFP 50 Section 5 Protection functions Circuit breaker failure protection CBFP 50 The circuit breaker failure protection can be used to trip any upstream circuit breaker CB if the fault has not disappeared within a given time after the initial trip command A different output contact of the device must be used for this backup trip The operation of the circuit breaker failure protection CBFP is based on the supervision of the signal to the selected trip relay and the time the fault remains on after
35. when DL LD closing live The voltage higher than the live voltage limit setting DD DL LD Example DL mode for stage 1 The U12 side must be dead and the U12y side must be live Cbtime 0 04 0 6 S 0 1 Typical closing time of the circuit breaker Dibypass Digital inputs Bypass input If the input is active the func tion is bypassed Bypass 0 1 0 The bypass status 1 means that the func tion is bypassed This parameter can also be used for manual bypass CBCtrl Open Close Circuit breaker control Showlnfo Off On On Additional information display about the sychrocheck status to the mimic display SGrpDI Digital inputs The input for changing the setting group SetGrp 1 2 1 The active setting group 63230 218 204 2014 Schneider Electric All rights reserved 131 Synchrocheck 25 section 5 Protection functions Table 5 38 Measured and recorded values of synchrocheck stages SyC1 SyC2 25 Parameter Values Unit Description Measured values df Hz Measured frequency difference dU Un deg Measured voltage amplitude and phase angle difference UState Voltage status e g DD SState Synchrocheck status ReqTime Request time status 1 2 Measured frequency reference side fy1 Hz Measured frequency comparison side U121 Un Measured voltage reference side U12
36. 10 Using Equation 6 1 the relay gets the number of permitted operations for current 6 kA _ 454 10 945 B 6000 5938 Thus the maximum number of current breaking at 6 kA is 945 This can be verified with the original breaker curve in Figure 6 4 Indeed the figure shows that at 6 kA the operation count is between 900 and 1000 A useful alarm level for operation left could be in this case for example 50 being about five per cent of the maximum 2015 Schneider Electric All rights reserved 185 Circuit breaker condition monitoring oection 6 Supporting functions Example of operations counter decrementing when the CB is breaking a current Alarm2 is set to 6 kA CBFP is supervising trip relay T1 and trip signal of an overcurrent stage detecting a two phase fault is connected to this trip relay T1 The interrupted phase currents are 12 5 kA 12 5 kA and 1 5 kA How many are Alarm2 counters decremented Using Equation 6 1 and values n and from the previous example the relay gets the number of permitted operation at 10 kA _454 10 313 1250029 At alarm level 2 6 kA the corresponding number of operations is calculated according Equation 6 4 Cds Thus Alarm2 counters for phases and B are decremented by 3 In phase A the currents is less than the alarm limit current 6 kA For such currents the decrement is one Ac 1 2015 Schneider Electric All rights reserved 186 63230
37. 100 A for 10 s 500 A for 1 s 0 2 VA loi input option C 10 input option D Hated residual current Current measuring range Thermal withstand Burden See Section 14 Order information 1 A configurable for CT secondaries 0 1 10 0 A 0 10 A for VAMP 255 0 5 A for VAMP 230 4 continuously 20 A for 10 s 100 A for 1 s 0 1 VA lor input option D Rated residual current optional Current measuring range Thermal withstand Burden See Section 14 Order information 0 2 A configurable for CT secondaries 0 1 10 0 A 0 2 for VAMP 255 0 1 A for VAMP 230 0 8 A continuously 4 A for 10 s 20 A for 1 s lt 0 1 VA 2015 Schneider Electric All rights reserved 63230 218 205 Section 12 Technical data Connections Rated voltage Un Voltage measuring range Continuous voltage withstand Burden 100 V configurable for VT secondaries 50 120 V 0 250 V 100 V 110 V for VAMP 230 0 190 V 100 V 110 V for VAMP 255 250 V lt 0 5VA Rated frequency fy 45 65 Hz Terminal block Solid or stranded wire Maximum wire dimension 4 mm 10 12 AWG Auxiliary power supply Type A standard Type B option Rated voltage 40 265 V ac dc 18 36 Note Polarity X3 172 negative X3 18 positive Start up peak DC 110V Type A 220V
38. 2 Modbus value X 32000 32000 Y 1000 1000 Y1 Scaled value Point 1 n X1 Modbus value 9 32000 32000 Offset Subtracted from Modbus value before running XY scaling un LL mess i q 2 g 2 InputR or HoldingR Modbus register type PHE ES II ce ui 1 9999 Modbus register for the measurement 1 247 Modbus address of the I O device C F K mA Ohm or V A Unit selection Active value On Off Enabling for measurement 63230 218 205 2015 Schneider Electric All rights reserved 319 External option modules Section 11 Connections Alarms for external analog inputs Range Description 0 10000 Hysteresis for alarm limits Alarm gt gt 21x107 21 107 Limit setting Alarm Active state Ww a Alarm gt 5 21x107 21 107 Limit setting T o z e c E a Alarm Active state Active value 1 9999 Modbus register for the measurement 1 247 Modbus address of the I O device On Off Enabling for measurement Analog input alarms have also matrix signals Ext Aix Alarm1 and Ext Aix Alarm2 320 2015 Schneider Electric All rights reserved 63230 218 205 Section 11 Connections ur c I LE External option modules External digital inputs configuration VAMPSET only Range De
39. 2015 Schneider Electric All rights reserved 369 Section 14 Order Information Accessories VERSES Ethernet adapter VPA 3CG Profibus DP fieldbus option board VSE001PP Fiber optic Interface Module plastic plastic Max distance 0 62 mile 1 km VSE002 RS485 Interface Module re VSE003 Local port RS 485 interface module Ext I O interface Be VSE009 External DeviceNet interface module VIO 12 AB RTD Module 12pcs RTD inputs RS 485 Communication 24 230 Vac dc RTD mA Module 12pcs RTD inputs PTC mA inputs outputs RS232 RS485 and Optical Tx Rx Communication 24 Vdc RTD mA Module 12pcs RTD inputs PTC mA inputs outputs RS232 RS485 and Optical Tx Rx Communication 48 230 3P025 USB to RS232 adapter a l VX004 M3 TTL RS232 converter cable PLC VEA 3CGi Cable length 10 ft 3 m VX007 F3 TTL RS232 converter cable VPA 3CG Cable length 10 ft 3 m VA 1 DA 6 Cable length 20 ft 6 m VAM 16D Disables rear local VYX076 oye Height 1 6 in 40 mm Projection for 200 series VYX077 Height 2 4 in 60 mm Projection for 200 series VYX233 Height 4 in 100 mm Projection for 200 series V200WAF V200 wall assembly frame ee 3 0 2015 Schneider Electric All rights reserved 63230 218 205 Section 15 Revision history oection 15 Revision history Table 15 1 Firmware revision history 10 58 New features in IEC 61850 added Outputs vef files with suomi amp
40. 63230 218 205 Table of Contents RUNAINO NOUMGCOUNLCK den ien 197 RR INS 198 Combined overcurrent status 200 ru 202 202 Short CICUIETAUIEIOCALON 204 Feeder seii eee Pb ERN 207 Ground fault locato Nesine od md ue th re Ra x pes 209 Section 7 Measurement functions 211 Measurement 211 RNS Vales 213 Harmonics and Total Harmonic Distortion THD 213 Demand ditatus that ace ee eee 214 Minimum and maximum values 214 Maximum values of the last 31 days and twelve months 215 Voltage measurement modes 216 POWER CAC UAV ONG qn 217 Direction of power and current 219 Symmetric components 221 Primary secondary and per unit scaling 226 Current scaling 226 VONAGS 56 ER NR M E 229 Analog output option 233 MA scaling examples 233 COMUONUNCHONG 235 amp ventu a dale ini
41. Freely configurable single line diagram 2 Controllable objects max six objects 2015 Schneider Electric All rights reserved 17 Configuration and parameter setting Section 2 Local panel user interface ES Object status max eight objects including the six controllable objects Bay identification Local Remote selection Auto reclose on off selection if applicable Freely selectable measurement values max six values Av ENERGY 7 OMWh OMvarh OMWh OMvarh Figure 2 2 Sections of the LCD dot matrix display en Ser d X Ye Main menu column The heading of the active menu The cursor of the main menu Possible navigating directions push buttons Measured setting parameter Measured set value Backlight control Display backlight can be switched on with a digital input virtual input or virtual output LOCALPANEL CONF Display backlight ctrl setting is used for selecting trigger input for backlight control When the selected input activates rising edge display backlight is set on for 60 minutes Adjusting display contrast The readability of the LCD varies with the brightness and the temperature of the environment The contrast of the display can be adjusted via the PC user interface 18 2015 Schneider Electric All rights reserved 63230 218 205 section 2 Local panel user interface Local panel operations Local panel operations Main menu 63230 218 205
42. Heset time 95 ms Inaccuracy Operating time 20 ms 358 2015 Schneider Electric All rights reserved 63230 218 205 Section 12 Technical data Protection functions Magnetizing inrush 68F2 Table 12 32 Magnetizing inrush 68F2 Settings Setting range magnetizing inrush 10 100 926 Operating time 0 05 300 00 s step 0 01 s Inaccuracy Starting 1 unit NOTE The amplitude of second harmonic content has to be at least 296 of the nominal of CT If the nominal current is 5 A the 100 Hz component needs to exceed 100 mA Over exicitation 68F5 Table 12 33 Over exicitation 68F5 Settings Setting range over exicitation 10 100 926 Operating time 0 05 300 00 s step 0 01 s Inaccuracy Starting 2 unit NOTE The amplitude of fifth harmonic content has to be at least 296 of the nominal of CT If the nominal current is 5 A the 250 Hz component needs to exceed 100 mA 63230 218 205 2015 Schneider Electric All rights reserved 359 Protection functions Frequency protection 360 Section 12 Technical data Table 12 34 Overfrequency and underfrequency stages f gt lt f gt gt lt lt 81H 81L Frequency measuring area 16 0 75 0 Hz Current and voltage meas Range 45 0 65 0 Hz Frequency stage setting range 40 1 70 0 Hz Low voltage blocking 10 100 Un Suitable frequency area for low voltage blocking
43. O all the time Daily The timer switches on and off once every day Monday The timer switches on and off every Monday Tuesday The timer switches on and off every Tuesday Wednesday The timer switches on and off every Wednesday Thursday The timer switches on and off every Thursday Friday The timer switches on and off every Friday Saturday The timer switches on and off every Saturday Sunday The timer switches on and off every Sunday MTWTF The timer switches on and off every day except Saturdays and Sundays MTWTFS The timer switches on and off every day except Sundays SatSun The timer switches on and off every Saturday and Sunday 63230 218 205 2015 Schneider Electric All rights reserved 199 Combined overcurrent status oection 6 Supporting functions Combined overcurrent status This function is collecting faults fault types and registered fault currents of all enabled overcurrent stages Table 6 19 Line fault parameters Parameter Value Unit Description Note IFltLas xlmode Current of the latest overcurrent fault Set LINE ALARM AlrL1 Start alarm status for each phase AlrL2 0 O No start since alarm ClrDly AlrL3 1 1 Start is on OCs Combined overcurrent start status 0 AlrL1 AlrL2 AlrL3 0 1 AlrL121 orAlrL2 1 AlrL3 1 LxAlarm On Event enabling for AlrL1 3 Set On Events are enabled Off Events are disabled LxAlarmOff Off E
44. X6 1 0119 X6 2 DI19 X6 3 DI20 X6 4 DI20 X6 5 NC X6 6 L4 6 7 L External option modules External LED module VAM 16D The optional external VAM 16D led module provides 16 extra led indicators in external casing Module is connected to the serial port of the device s front panel Please refer the User manual VAM 16D for details External input output module 318 The device supports optional external input output modules used to extend the number of digital inputs and outputs Also modules for analog inputs and outputs are available The following types of devices are supported e Analog input modules RTD e Analog output modules mA output e Binary input output modules 2015 Schneider Electric All rights reserved 63230 218 205 Section 11 Connections External option modules EXTENSION port is primarily designed for I O modules This port is found in the LOCAL connector of the device backplane and I O devices should be connected to the port with VSE003 adapter NOTE If External I O protocol is not selected to any communication port VAMPSET doesn display the menus required for configuring the I O devices After changing EXTENSION port protocol to External I O restart the relay and read all settings with VAMPSET External analog inputs configuration VAMPSET only Range Description Detected communication read errors S Scaled value Point 2
45. lt 95 ms Retardation time lt 50 ms Reset ratio 0 97 Inaccuracy Starting Operation time DT 1 ratio gt 1 5 Operation time DT ly lagz ratio 1 03 1 5 3 of the set value or 5 mA secondary 1 or 15 ms 1 or 25 ms 2015 Schneider Electric All rights reserved 347 Protection functions NOTE 348 Section 12 Technical data Table 12 10 Stall protection stage 48 in motor mode Setting range Motor start detection current Nominal motor start current 1 30 10 00 x step 0 01 1 50 10 00 x step 0 01 Delay type DT INV Definite time characteristic DT operating time 1 0 300 0 s step 0 1 Inverse time characteristic INV operation delay Inverse time coefficient k 1 0 300 0 s step 0 1 1 0 200 0 s step 0 1 Minimum motor stop time to activate stall 500 ms protection Maximum current raise time from motor stop to start 200 ms Motor stopped limit 0 10 x Motor running lower limit 0 20 x Motor running limit after starting 1 20 x Start time Typically 60 ms Reset time 95 ms Reset ratio 0 95 Inaccuracy Starting Operating time at definite time function Operating time at IDMT function 3 of the set value or 5 mA secondary 1 or at 30 ms 5 or at least 30 ms Motor stopped and running limits are based on th
46. m o MED j j j j Critical 0 300s i i 0 300 i D i i e i ui S i Shot 1 ARI n use gt o3 0 300 s 0 300 5 0 300 s 0 300 s AR2 In use Ag i i i o o 85 i ac e Not in use 0 300s 0 300s Shot 2 meme cnc 5309 0 98625 PREG o lt 2 T D T gt Oo 2 0 5 5 aa 2 2558 8 dj o A a o e e Shot 3 5 e e e Figure 8 4 Auto reclose matrix The AR matrix above defines which signals the start and trip signals from protection stages or digital input are forwarded to the auto reclose function In the AR function the AR signals can be configured to initiate the reclose sequence Each shot from 1 to 5 has its own enabled disabled flag If more than one AR signal activates at the same time AR1 has highest priority and AR2 the lowest Each AR signal has an independent start delay for the shot 1 If a higher priority AR signal activates during the start delay the start delay setting will be changed to that of the highest priority AR signal After the start delay the circuit breaker CB will be opened if it is closed When the CB opens a dead time timer is started Each shot from 1 to 5 has its own dead time setting After the dead time the CB will be closed and a discrimination time t
47. undir dir back up 74 2015 Schneider Electric All rights reserved 63230 218 205 Section 5 Protection functions Current unbalance stage I5 gt 46 in feeder mode Current unbalance stage l2 46 in feeder mode Parameter Value The purpose of the unbalance stage is to detect unbalanced load conditions for example an open conductor of a heavy loaded overhead line in case there is no ground fault The operation of the unbalanced load function is based on the negative phase sequence of component 12 relative to the positive phase sequence component l4 This is calculated from the phase currents using the method of symmetrical components The function requires that the measuring inputs are connected correctly so that the rotation direction of the phase currents are as shown in the section Connection examples If the rotation direction is incorrect a trip will occur The unbalance protection has definite time operation characteristic l4 lA alg 21 1 lo lA a lg alc 3 a 17120 4 j 2 2 phasor rotating constant Table 5 7 Setting parameters of the current unbalanced stagel 46 in feeder mode Default Description 12 11 2 70 20 Setting value 12 11 1 0 600 0 Definite operating time The selection of time characteristics Enabled Disabled Enabled Start on event Enabled Disabled Enabled Start off event Enabled Disabled Enab
48. 0 3 300 0 S 1 0 P lt P lt lt operational delay S On Enabled Disabled Enabled Start on event S Off Enabled Disabled Enabled Start off event T On Enabled Disabled Enabled Trip on event T Off Enabled Disabled Enabled Trip off event Table 5 32 Measured and recorded values of P and P stages Parameter vaule Unit Description Measured value P kW Active power Recorded values SCntr Start counter Start reading TCntr Trip counter Trip reading Fit Sn Max value of fault EDly Elapsed time as compared to the set operating time 100 tripping 122 2014 Schneider Electric All rights reserved 63230 218 204 Section 5 Protection functions 63230 218 204 Frequency Protection f gt lt f gt gt lt lt 81 Frequency Protection f2 f gt gt lt lt 81 Frequency protection is used for load sharing loss of mains detection and as a backup protection for over speeding The frequency function measures the frequency from the two first voltage inputs At least one of these two inputs must have a voltage connected to be able to measure the frequency Whenever the frequency crosses the user s pick up setting of a particular stage this stage picks up and a start signal is issued If the fault situation remains on longer than the user s operation delay setting a trip signal is issued For situations where no voltage is present an adapted frequency is used See the section Principles of numerical protec
49. 01 s Inrush settings Pickup for 2nd harmonic 0 99 Table 12 42 Current transformer supervision Pick up current 1 2 10 00 x Definite time function DT Operating time 0 06 600 00 s step 0 02 s Reset time 60 ms Reset ratio lix 0 97 Reset ratio Iyin lt 1 03 Inaccuracy Activation 3 of the set value Operating time at definite time function 1 or 30 ms 364 2015 Schneider Electric All rights reserved 63230 218 205 Section 12 Technical data Supporting functions Table 12 43 Voltage transformer supervision Us gt setting 0 0 200 0 lo setting 0 0 200 0 Definite time function DT Operating time 0 04 600 00 step 0 02s Reset time 60 ms Reset ratio 3 of the pick up value Inaccuracy Activation Us gt Activation lo lt Operating time at definite time function 1 unit 1 unit 1 or 30 ms Table 12 44 Voltage sag and swell Measurement mode Default L L L N Voltage sag limit 10 120 Un Voltage swell limit 20 150 Un Definite time function Operating time DT 0 08 1 00 s step 0 02 s Low voltage blocking 0 50 Voltage low limit 10 120 Un Definite time function DT Operating time 60 ms Fixed Reset time 60 ms Heset ration Sag 1 03 Swell 0 97 Block l
50. 0119 0120 The optional arc detection card includes two arc sensor channels The arc sensors are connected to terminals X6 4 5 and 6 7 The arc information can be transmitted and or received through digital input and output channels This is a 48 V dc signal Connections X6 1 Binary input BI X6 2 Binary output BO X6 3 Common for BI and BO X6 4 5 Sensor 1 X6 6 7 Sensor 2 The binary output of the arc option card may be activated by the arc sensors or by any available signal in the output matrix The binary output can be connected to an arc binary input of another VAMP protection device 63230 218 205 2015 Schneider Electric All rights reserved 317 Optional digital 1 0 0119 0120 oection 11 Connections Optional digital I O card 0119 0120 NOTE When this option card is installed the parameter Arc card type has value Arc 2DI With DI19 DI20 option only one arc sensor channel is available Please check the ordering code in Section 14 Order information If the slot X6 is already occupied with the two channel arc sensor card the section Optional two channel arc detection card this option is not available The 0119 0120 option enables two more digital inputs These inputs are useful in applications where the contact signals are not potential free For example trip circuit supervision is such application The inputs are connected to terminals X6 1 X6 2 and X6 3 X6 4 Connections
51. 04 28 11112522251 12 Fit 0 55 Load 0 02 xin EDly 24 Figure 2 9 Example of fault log To see the values of for example log two press then to select the current log log one The current log number is then indicated in the down left corner of the display SeeFigure 2 10 Log2 log two The log two is selected by pressing once log2 I gt log buffer 2003 04 24 03 08 21 342 Date Type 12 Fit 1 69 xin Load 0 95 EDIy 13 Figure 2 10 Example of selected fault log 2015 Schneider Electric All rights reserved 27 Configuration and parameter setting Section 2 Local panel user interface Operating levels 28 The relay has three operating levels User level Operator level and Configurator level The purpose of the access levels is to help prevent accidental change of relay configurations parameters or settings USER level Use Possible to read e g parameter values measurements and events Opening Level permanently open Closing Closing not possible OPERATOR level Use Possible to control objects and to change e g the settings of the ume stages The level is automatically closed after 10 minutes idle time Giving the password 9999 can also close the level CONFIGURATOR level Use The configurator level is needed during the commissioning of the relay E g the scaling of the voltage and current transform
52. 1 A This is specified in the order code of the device e Rated value of Ip CT primary current lonom e Rated value of lg CT secondary current losec e Rated Ip input of the relay loinp 5 A or 1 A This is specified in the order code of the device e Rated value of loo CT primary current lo2nom e Rated value of loo CT secondary current lo2sec e Rated 10 input of the relay lo2inp 5A 1 A or 0 2 A This is specified in the order code of the device The rated input values are usually equal to the rated secondary value of the CT The rated CT secondary may be greater than the rated input but the continuous current must be less than four times the rated input In compensated high impedance grounded and isolated networks using cable transformer to measure residual current lo it is quite usual to use a relay with 1 A or 0 2 A input although the CT is 5 Aor 1A This increases the measurement accuracy The rated CT secondary may also be less than the rated input but the measurement accuracy near zero current will decrease Voltage scaling e Rated VI primary voltage Vprim e Rated VT secondary voltage Vsec e Rated V VT secondary voltage Vosec e Voltage measuring mode Vmode 44 2015 Schneider Electric All rights reserved 63230 218 205 oection 2 Local panel user interface Configuration and parameter setting Motor setting e Rated current of the motor Imot Units for mimic display e Unit for voltage
53. 12000 110 The device displays Ug 20 96 If Ug Uc 0 then secondary voltages at is Usec 43X0 2x110 38 1 V 232 2015 Schneider Electric All rights reserved 63230 218 205 oection 7 Measurement functions Analog output option Analog output option A device with the mA option has four configurable analog outputs that take up two of the output relays A4 and A5 Thus a device with the mA option has two output relays less than the version without mA option The resolution of the analog output is 12 bits resulting current steps less than 6 pA The output current range is configurable allowing e g the following ranges 0 20 mA and 4 20 mA More exotic ranges like 0 5 mA or 10 2 mA can be configured freely as long as the boundary values are within 0 20 mA NOTE All positive poles X2 1 3 5 and 7 are internally connected together see figures in the section Block optional diagrams mA scaling examples Example of mA scaling for IL Coupling IL Scaled minimum 0 A Scaled maximum 300 mA Analog output minimum value 0 mA Analog output maximum value 20 mA Analog mAScaling 1 output mA Figure 7 6 The average of the three phase currents At 0 A the transducer ouput is 0 mA at 300 A the output is 20 mA 63230 218 205 2015 Schneider Electric All rights reserved 233 Analogue output option 234 Section 7 Measurement functions Example of mA scaling for Uline Coupling Ul
54. 123 Frequency Protection f gt lt f gt gt lt lt 81 Section 5 Protection functions Table 5 33 Parameters of the over amp underfrequency stages Parameter Value Unit Description Note Status Current status of the stage Blocked Start F Trip SCntr Cumulative start counter C TCntr Cumulative trip counter C SetGrp 1 2 Active setting group Set f Hz The supervised value Hz Pick up value Set fX Over under stage f gt lt See row Mode fXX Over under stage f gt gt lt lt f lt Under stage f lt f lt lt Under stage f lt lt S Definite operation time Set tX f gt lt stage tXX f gt gt lt lt stage t lt f lt stage lt lt lt lt stage Operation mode only for f and f gt gt lt lt Set gt Overfrequency mode lt Underfrequency mode LVbIck Un Low limit for self blocking This is a common setting for all Set four stages Set An editable parameter password needed C Can be cleared to zero F Editable when force flag is on For details of setting ranges see the section Protection functions 124 2014 Schneider Electric rights reserved Hecorded values of the latest eight faults There is detailed information available for the eight latest faults Time stamp frequency during fault elapsed delay and setting group 63230 218 204 oection 5 Protection functions Rate of change of frequency ROCOF 81
55. 2 0 1 0 08 0 06 IEC LTI k 20 k 10 k 5 k 2 k 0 5 k 0 2 k 0 1 3 4 5678 I Iset 10 20 Figure 5 48 IEC long time inverse delay 2015 Schneider Electric All rights reserved 63230 218 205 Section 5 Protection functions Equation 5 6 M ibi k I pickup C RB Inverse time operation IEEE ANSI inverse time operation There are three different delay types according IEEE Std C37 112 1996 MI VI El and many de facto versions according Table 5 53 The IEEE standard defines inverse delay for both trip and release operations However in the VAMP relay only the trip time is inverse according the standard but the release time is constant The operation delay depends on the measured value and other parameters according Equation 5 6 Actually this equation can only be used to draw graphs or when the measured value l is constant during the fault A modified version is implemented in the relay for real time usage t Operation delay in seconds User s multiplier Measured value lbickup User s pick up setting Constant parameter according Table 5 53 Delay type Table 5 53 Constants for IEEE ANSI inverse delay equation Parameter A B Long time inverse 0 086 0 185 Long ti
56. 205 2015 Schneider Electric All rights reserved 289 290 Section 11 Connections OUTPUT MATRIX T1 T3 T4 M M connected amp connected and latched fa Fa Figure 10 12 An example of output matrix configuration for trip circuit supervision with one wet digital input Example of dimensioning the external resistor R using Phoenix Contact component connector P CO 1N4007 L R 3032460 and the Phoenix Disconnect terminal block UT 2 5 TG 3046388 on at least terminals UT 2 5 TG and UT 4 TG VAUX 110 Vdc 5 10 Auxiliary voltage with tolerance Short time voltage dips more than 5 are not critical from the trip circuit supervision point of view Relay type for the K1 auxiliary relay Phoenix Contact 2941455 EMG 17 REL KSR 120 21 21 LC Au V k 120 Vac dc 20 10 Coil voltage of the auxiliary relay K1 6 mA Nominal coil current of the auxiliary relay K1 P CBoil 50 W Rated power of the open coil of the circuit breaker VMN Wa 5 104 5 V 00 Vaux 1096 121 V KIMIN y 109 96 Rk1Coil Via l4 20 1 4 8 mA 1 VkiMAx Ficicoii 6 1 mA PCBCol7 jo qux P 242 0 for NEMA U V 2015 Schneider Electric All rights reserved 63230 218 205 Section 11 Connections Rear panel The external resistance value is calculated using Equation 10 4 Equation 10 4 R V iMin
57. 4 5 S2 Sensor 2 at terminals X6 6 7 51 52 Sensor terminals 1 and 2 Bl Terminals X6 1 S1 BI Sensor 1 and BI in use 52 Sensor 2 and BI in use 51 52 Sensor 1 2 and Bl use Delayed light signal output Ldly S Delay for delayed light output signal Set LdlyCn Light indication source selection Set No sensor selected 51 Sensor 1 at terminals X6 4 5 52 Sensor 2 at terminals X6 6 7 51 52 Sensor in terminals 1 and 2 Terminals X6 1 3 S 1 BI Sensor 1 and Bl in use 52 2 51 52 Sensor 1 2 and use Set An editable parameter password needed C Can be cleared to zero F Editable when force flag is on For details of setting ranges see section Protection functions Parameter Hecorded values of the latest eight faults There is detailed information available of the eight latest faults Time stamp fault type fault value load current before the fault and elapsed delay Table 5 50 Recorded values of the arc detection stages Value Description yyyy mm dd Time stamp of the recording date hh mm ss ms Time stamp time of day Fault type value Only for Arcl gt stage Fault value Pre fault current Only for Arcl gt stage Elapsed time of the operating time setting 100 trip 63230 218 205 2015 Sc
58. All recordings are time stamped Heading recordings The recordings can be uploaded viewed and analysed with the VAMPSET program The recording is in COMTRADE format This also means that other programs can be used to view and analyse the recordings made by the relay For more details please see the VAMPSET manual doc no 63230 218 207 Number of channels At the maximum there can be 12 recordings and the maximum selection of channels in one recording 12 limited in wave form and digital inputs reserve one channel includes all the inputs Also the digital outputs reserve one channel includes all the outputs If digital inputs and outputs are recorded there will be still 10 channels left for analog waveforms DISTURBANCERECORDER RECORDER CHANNELS IL 1 1L2 1L3 101 Uo DI DO Add recorder channel Delete recorder channel Remove all channels 2015 Schneider Electric All rights reserved 167 Disturbance recorder oection 6 Supporting functions Table 6 2 Disturbance recorder waveform Channel Description Available for waveform Voltage measurement mode 2LL Uo 3LN 1LL Uo LLy 2LL LLy L LLy LLz IL1 IL2 IL3 Phase current Yes Yes Yes Yes Yes lo1 lo2 Measured residual current Yes Yes Yes Yes Yes U12 Line to line voltage Yes Yes Yes Yes U23 Line to line v
59. Also undefined event is generated Local Remote selection A WARNING LOSS OF CONTROL 63230 218 205 e The designer of any control scheme must consider the potential failure modes of control paths and for certain ciritical control functions provide a means to achieve a safe state during and after a path failure Example Emergency Stop Separate or redundant control paths must be provided for critical control functions System control paths may include communication links Consideration must be given to the implications of anticipated transmission delays or failures of the link Failure to follow these instructions can result in death or serious injury In Local mode the output relays can be controlled via a local HMI but they cannot be controlled via a remote serial communication interface In Remote mode the output relays cannot be controlled via a local HMI but they can be controlled via a remote serial communication interface 2015 Schneider Electric All rights reserved 243 Auto reclose function 79 Section 8 Control functions The selection of the Local Remote mode is done by using a local HMI or via one selectable digital input The digital input is normally used to change a whole station to a local or remote mode The selection of the L R digital input is done in the Objects menu of the VAMPSET software NOTE A password is not required for a remote control operation Controlling with D
60. External Analog input 1 16 Set An editable parameter password needed C Can be cleared to zero F Editable when force flag is on For details of setting ranges see the section Protection functions 114 2014 Schneider Electric All rights reserved 63230 218 205 Section 5 Protection functions Overvoltage protection U gt 59 63230 218 205 Overvoltage protection V 59 The overvoltage function measures the fundamental frequency component of the line to line voltages regardless of the voltage measurement mode see the section Voltage measurement modes By using line to line voltages any phase to ground over voltages during ground faults have no effect The ground fault protection functions will detect ground faults Whenever any of these three line to line voltages exceeds the user s pick up setting of a particular stage this stage picks up and a start signal is issued If the fault situation remains on longer than the user s operation time delay setting a trip signal is issued In solidly grounded 4 wire networks with loads between phase and neutral overvoltage protection may be needed for phase to ground voltages too In such applications the programmable stages can be used See the section Programmable stages 99 Three independent stages There are three separately adjustable stages V V gt gt and V gt gt gt All the stages can be configured for definite time DT oper
61. HMI or with a VAMPSET user interface Easy connection to power plant automation system due to a versatile serial connection and several available communication protocols Built in self regulating ac dc converter for auxiliary power supply from any source within the range from 40 to 265 Vdc or Vac Optional power supply for 40 265 Vac dc or 18 36 Vdc Built in disturbance recorder for evaluating all the analog and digital signals 2015 Schneider Electric All rights reserved 53 Principles of numerical protection techniques section 4 Introduction Principles of numerical protection techniques 54 The device is fully designed using numerical technology This means that all the signal filtering protection and control functions are implemented through digital processing The numerical technique used in the device is primarily based on an adapted Fast Fourier Transformation FFT In FFT the number of calculations multiplications and additions which are required to filter out the measuring quantities remains reasonable By using synchronized sampling of the measured signal voltage or current and a sample rate according to the 2 series the FFT technique leads to a solution which can be realized with just a 16 bit micro controller without using a separate DSP Digital Signal Processor The synchronized sampling means an even number of 2 samples per period e g 32 samples per a period This means that the frequency
62. Hight after closing a circuit breaker a given amount of overload can be allowed for a given limited time to take care of concurrent thermostat controlled loads Cold load pick up function does this for example by selecting a more coarse setting group for over current stage s It is also possible to use the cold load detection signal to block any set of protection stages for a given time Inrush current detection Inrush current detection is quite similar with the cold load detection but it does also include a condition for second harmonic relative content of the currents When all phase currents have been less than a given idle value and then at least one of them exceeds a given pick up level within 80 ms and the ratio 2nd harmonic ratio to fundamental frequency 1 15 of at least one phase exceeds the given setting the inrush detection signal is activated This signal is available for output matrix and blocking matrix Using virtual outputs of the output matrix setting group control is possible By setting the 2nd harmonic pickup parameter for l l to zero the inrush signal will behave equally with the cold load pick up signal Application for inrush current detection The inrush current of transformers usually exceeds the pick up setting of sensitive overcurrent stages and contains a lot of even harmonics Right after closing a circuit breaker the pick up and tripping of sensitive overcurrent stages can be avoided by selecting a more coars
63. L1 A L2 B and L3 C Figure 5 29 Typical capacitor bank protection application with VAMP devices Compensation method The method for unbalance protection is to compensate the natural unbalance current The compensation is triggered manually when commissioning 2015 Schneider Electric All rights reserved 63230 218 205 oection 5 Protection functions Capacitor bank unbalance protection 63230 218 205 The phasors of the unbalance current and one phase current are recorded This is because one polarizing measurement is needed When the phasor of the unbalance current is always related to l4 the frequency changes or deviations have no effect on the protection After recording the measured unbalance current corresponds to the zero level and therefore the setting of the stage can be very sensitive Compensation and location The most sophisticated method is to use the same compensation method as mentioned above but the add on feature is to locate the branch of each detected issue or to be more precise the open fuse This feature is implemented to the stage lo while the other stage lg can still function as normal unbalance protection stage with compensation method Normally the l gt gt gt gt could be set as an alarming stage while stage l gt gt gt will trip the circuit breaker The stage l gt gt gt gt should be set based the calculated unbalance current change of one detected is
64. MATRIX Figure 8 9 Logic creation 2015 Schneider Electric All rights reserved 255 Logic functions oection 8 Control functions 1 Selectinput signals can be done by pressing the following button or by clicking mouse left on top of the logic input line 2 Select outputs can be done by pressing the following button or by clicking mouse left on top of the logic output line 3 his deletes the logic function When logic is created and settings are written to the IED the unit requires a restart After restarting the logic output is automatically assigned in output matrix as well NOTE During commissioning whenever writing new logic to the IED the unit has to be restarted 256 2015 Schneider Electric All rights reserved 63230 218 205 oection 9 Communication Communication ports Section 9 Communication A DANGER HAZARD OF ELECTRIC SHOCK EXPLOSION OR ARC FLASH e Apply appropriate personal protective equipment PPE and follow safe electrical work practices See NFPA 70E NOM 029 STPS 2011 and CSA Z462 e This unit must be installed and serviced only by qualified electrical personnel Turn off all power supplying this unit before working on or inside the unit e Always use a properly rated voltage sensing device to confirm that the power is off A live current transformer secondary circuit must not be opened without turning off the primary side of the transformer and short circuiting transformer
65. NC Active edge is 1 gt 0 Indication display no No pop up display Set yes Indication display is activated at active DI edge On event On Active edge event enabled Set Off Active edge event disabled Off event On Inactive edge event enabled Set Off Inactive edge event disabled NAMES for DIGITAL INPUTS editable with VAMPSET only Label String of max 10 characters Short name for 015 on the local display Default Set is Din n21 6 Description String of max 32 characters Long name for Dls Default is Set Digital input n n2 1 6 Set An editable parameter password needed 238 2015 Schneider Electric All rights reserved 63230 218 205 oection 8 Control functions Virtual inputs and outputs Virtual inputs and outputs There are four virtual inputs and six virtual outputs The four virtual inputs acts like normal digital inputs The state of the virtual input can be changed from display communication bus and from VAMPSET For example setting groups can be changed using virtual inputs Table 8 4 Parameters of virtual inputs Parameter Value Unit Description 11 14 0 1 Status of virtual input Events On Off Event enabling NAMES for VIRTUAL INPUTS editable with VAMPSET only Label String of max 10 characters Short name for Vls on the local display Set Default is VIn n 1 4 Description String of max 32 characters Long name for VIs Default is Virtual inpu
66. Note 1 Interactive mimic display 1 5 Double size measurements defined by the user 1 1 Title screen with device name time and firmware version P 14 Power measurements E 4 Energy measurements 13 Current measurements U 15 Voltage measurementsa Dema 15 Demand values Umax 5 Time stamped min amp max of voltages Imax 9 Time stamped min amp max of currents Pmax 5 Time stamped amp max of power and frequency Mont 21 Maximum values of the last 31 days and the last twelve months Evnt 2 Events DR 2 Disturbance recorder 2 Runh 2 Running hour counter Active time of a selected digital input and time stamps of the latest start and stop TIMR 6 Day and week timers 5 Digital inputs including virtual inputs DO 4 Digital outputs relays and output matrix ExtAI 3 External analog inputs 3 ExDI 3 External digital inputs 3 ExDO 3 External digital outputs 3 Prot 27 Protection counters combined overcurrent status protection status protection enabling cold load and inrush detectionlf2 gt and block matrix gt 5 151 overcurrent stage 50 51 4 gt gt 3 2nd overcurrent stage 50 51 4 gt gt gt 3 overcurrent stage 50 51 4 gt 6 1st directional overcurrent stage 67 4 Ip gt gt 6 2nd directional overcurrent stage 67 4 Ip gt gt gt 4 3rd directional overcurrent stage 67 4 Ip gt gt gt gt 4 4th directional overcurrent stage 67 4 I lt 3 Undercurrent stage 37 4 12 gt 3 Current unbalance stage 46 4 T gt 3 Thermal over
67. Object close command given minic or bus actually make only sync request B Request going down when real object close being requested Synchronizing time if timeout happens Sync Fail signal activates Timeout defined in synchrocheck D Normal object close operation Figure 5 39 The principle of the synchrocheck function Please note that the control pulse of the selected object should be long enough For example if the voltages are in opposite direction the synchronising conditions are met after several seconds 1 Object close command v 2 _ 3 4 2 Synchrocheck H 3 Object A B A Sync Fail signal if sync timeout happen 4 CB B Object Fail signal if real object control does not complete in time Time settings e Synchrocheck Max synchronize time seconds e Object Max object control pulse length 200 ms Figure 5 40 The block diagram of the synchrocheck and the controlling object Please note that the wiring of the secondary circuits of voltage transformers to the device terminal depends on the selected voltage measuring mode 63230 218 204 2014 Schneider Electric All rights reserved 133 Synchrocheck 25 134 Section 5 Protection functions Table 5 39 Voltage measurement modes for synchrocheck function Voltage input Terminals Signals in Signals in Signals in mode mode mode 1LL Up LLy 2LL LLy LL LLy LLz Ua X1 11 12
68. Prot The front panel can be used to control objects change the local remote status read the measured values set parameters and to configure relay functions Some parameters however can only be set by means of a PC connected to the local communication port Some parameters are factory set Moving in the menus Submenus l pick up setting 4 v UB moving in the menus relay Figure 2 3 Moving in the menus using local HMI move in the main menu push or EA move in submenus push or To enter a submenu push E and use or for moving down or up in the menu To edit a parameter value push 1 03 go back to the previous menu push e To go back to the first menu item in the main menu push for at least three seconds To enter the parameter edit mode give the password When the value is in edit mode its background is dark 2015 Schneider Electric All rights reserved 19 Configuration and parameter setting Section 2 Local panel user interface Main menu The menu is dependent on the user s configuration and the options according the order code For example only the enabled protection stages will appear in the menu A list of the local main menu Main menu Number of menus Description ANSI code
69. THDUb Total harmonic distortion of Ua Ub or Uc THDUc Prms Active power rms value Qrms Reactive power rms value Srms Apparent power rms value fy Frequency behind circuit breaker fz Frequency behind 2nd circuit breaker U12y Voltage behind circuit breaker U12z Voltage behind 2nd circuit breaker IL1 RMS IL2MRS IL1 IL2 IL8 RMS for average sampling IL3RMS ILmin ILmax Min and max of phase currents ULLmin ULLmax Min and max of line to line voltages ULNmin ULNmax Min and max of phase voltages Delete Delete selected channel recorder ClrCh Clear Remove all channels Set 63230 218 205 2015 Schneider Electric All rights reserved 171 Disturbance recorder Section 6 Supporting functions Parameter Value Unit Description Note Ch List of selected channels This is the fundamental frequency rms value of one cycle updated every 10 ms This is the fundamental frequency rms value of one cycle updated every 20 ms L1 L2 and L3 are IEC phase names For NEMA the phases are as follows L1 A L2 B and L3 C Set An editable parameter password needed For details of setting ranges see the section Supporting functions Running virtual comtrade files Virtual comtrade files can be run with VAMP relays with the v 10 74 software or a later version Relay behavior can be analysed by playing the recorder data over and over again in the relay memory Steps of opening the VAMPSET setting tool 1 Goto D
70. The other setting group can be seen by pressing push buttons EZS and then 2 or EB Setting groups are explained in the section Setting groups ILmax 403A The maximum of three measured phase currents is at the moment 403 A This is the value the stage is supervising otatus otatus of the stage This is just a copy of the status value in the first menu gt gt 1013 A The pick up limit is 1013 A in primary value gt 2 50xlyw The pick up limit is 2 50 times the rated current of the generator This value can be edited if the operating level is at least Operator Operating levels are explained in the section Operating levels gt gt 0 605 The total operation delay is set to 600 ms This value can be edited if the operating level is at least Operator 2015 Schneider Electric All rights reserved 63230 218 205 section 2 Local panel user interface Local panel operations 63230 218 205 Third menu of Il gt gt 50 51 stage third menu gt gt 1 50 51 FAULT LOG 1 ExDI 2006 09 14 ExDO 12 25 10 288 Prot 1 2 Fit 2 86xIn CBWE Load 0 99xIn EDly 81 SetGrp 1 Figure 2 6 Third and last menu next on the right of I 50 51 stage This is the menu for registered values by the 1 gt gt stage Fault logs are explained in the section Fault logs FAULT LOG 1 This is the latest of the eight available logs You may move between the logs by pressing push buttons and the
71. Type A 15A with time constant of 1ms 25A with time constant of 1ms Power consumption Max permitted interruption time lt 15 W normal conditions lt 25 W output relays activated lt 50 ms 110 V dc Terminal block Phoenix MVSTBW or equivalent Maximum wire dimension 2 5 mm2 14 AWG 63230 218 205 2015 Schneider Electric All rights reserved 339 Block diagrams of option modules Digital inputs Trip contacts 340 Internal operating voltage Number of inputs Section 12 Technical data 6 Internal operating voltage 48 V dc Current draw when active max approx 20 mA Current draw average value 1 mA Terminal block Phoenix MVSTBW or equivalent Maximum wire dimension 2 5 mm 13 14 AWG External operating voltage Only VAMP 255 12 Number of inputs External operating voltage Rated voltage selectable in order code 3 24V dc ac max 265 V 6 110V dc ac max 265 V 7 220V dc ac max 265 V Current draw approx 2 mA Activation time dc ac lt 11 ms 15 ms Reset time dc ac lt 11 ms 15 ms Terminal block Phoenix MVSTBW or equivalent Maximum wire dimension 2 5 mm 13 14 AWG Number of contacts 2 or 4 depends on the ordering code Rated voltage 250 V ac dc Continu
72. Us5V 30 U 0 1 5 0 V Operate time at definite time function 1 or 25 ms 2015 Schneider Electric All rights reserved 353 Protection functions 354 Section 12 Technical data Table 12 21 Directional ground fault stages los log gt gt 67N Pick up current 0 005 8 0 pu for log gt 0 01 8 0 pu for log gt gt 0 005 20 0 pu When locat for log gt 1 1 20 0 pu When locat for log gt gt Start voltage 1 50 Uon Input signal lo input X1 7 8 lo input X1 9 10 locate lii he lia Mode Non directional Sector ResCap Base angle setting range 180 4179 Operation angle 88 Definite time function Operating time 0 10 300 00 s step 0 02 s IDMT function Delay curve family Curve type Time multiplier k DT IEC IEEE RI Prg El VI NI LTI MI depends on the family 0 05 20 0 except 0 50 20 0 for RI IEEE and IEEE2 Start time Typically 60 ms Reset time 95 ms Reset ratio 0 95 Reset ratio angle 2 Inaccuracy Starting Up amp lo rated value In 1 5A 3 of the set value or 0 3 of the rated value Starting Up amp lg Peak Mode when rated value lon 1 10A 5 of the set value or 2 of the rated value Sine wave 65 Hz Starting Uo amp lo locaic 3 of the set value or 0 5 of the rated value Ang
73. V gt gt gt Table 5 27 Parameters of the overvoltage stages V gt V gt gt V gt gt gt Parameter Value Unit Description Note Status Current status of the stage Blocked Start F Trip SCntr Cumulative start counter C TCntr Cumulative trip counter C SetGrp 1or2 Active setting group Set SGrpDI Digital signal to select the active setting group Set None DIx Digital input VIx Virtual input LEDx LED indicator signal VOx Virtual output Force Off Force flag for status forcing for test purposes This Set is a common flag for all stages and output relays On Automatically reset by a 5 minute timeout Umax V The supervised value Max of U12 U23 and U31 U gt U gt gt U gt gt gt V Pick up value scaled to primary value U gt U gt gt U gt gt gt Un Pick up setting relative to Un Set t gt t gt gt b Definite operation time Set RisDly Release time U stage only Dead Set Hyster 3 default band size i e hysteresis Set Set An editable parameter password needed C Can be cleared to zero Editable when force flag is on For details of setting ranges see the section Protection functions 116 Hecorded values of the latest eight faults There are detailed information available of the eight latest faults Time stamp fault voltage elapsed delay and setting group 2014 Schneider Electric All r
74. activate e g the START by one of the signals For more signal is reset The resetting depends information about output matrix please onthe type of configuration connected see Configuring digital outputs DO or latched Trip LED lit One or several signals of the output relay The LED is not lit when the signal matrix have been assigned to output Tr that caused output Trip Indication Tr and the output has been activated by activate e g the TRIP signal is of the signals For more information about reset The resetting depends on the output relay configuration please see type of configuration connected or Configuring digital outputs DO latched A C LED lit Application related status indicators Configurable One or several signals of the output relay matrix have been assigned to output LED A LED B or LED C LA LB or LC and the output has been activated by one of the signals For more information about output relay configuration please see Configuring digital outputs DO Adjusting LCD contrast 1 5 On the local HMI push 1 and 3 2 Enter the four digit password and push a Push 2 and adjust the contrast To increase the contrast push To decrease the contrast push v To return the main menu push 16 2015 Schneider Electric All rights reserved 63230 218 205 section 2 Local panel user interface Local panel operations Display 63230 218 205 Resetting latched indicato
75. alarms one for each phase The smallest of three is supervised by the two alarm functions 2015 Schneider Electric All rights reserved 183 Circuit breaker condition monitoring oection 6 Supporting functions Logarithmic interpolation The permitted number of operations for currents in between the defined points are logarithmically interpolated using equation Equation 6 1 a Qi Mp I C permitted operations interrupted current a constant according Equation 6 2 n constant according Equation 6 3 Equation 6 2 Equation 6 3 In C a CI C n k 1 184 2015 Schneider Electric All rights reserved 63230 218 205 Section 6 Supporting functions 6 7 Voltage transformer supervision 63230 218 205 In natural logarithm function permitted operations row 2 7 in Table 6 13 corresponding current k row 2 7 in Table 6 13 permitted operations k row 2 7 in Table 6 13 1 corresponding current row 2 7 in Table 6 13 Example of the logarithmic interpolation Alarm 2 current is set to 6 kA What is the maximum number of operations according Table 6 13 The current 6 kA lies between points 2 and 3 in the table That gives value for the index k Using K 2 10000 80 Ik 31 I 1 25 kA and the Equation 6 2 and Equation 6 3 the relay calculates 10000 In 80 1 5038 1 31000 1250 a 10000 1250 9 454
76. and then curve family is changed to IEEE the detected setting error will activate because there is no NI type available for IEEE curves After changing valid delay type for IEEE mode for example MI the Setting Error signal will release 2 There are detected errors in formula parameters A E and the device is not able to build the delay curve 3 here are detected errors in the programmable curve configuration and the device is not able to interpolate values between the given points Limitations The maximum measured secondary phase current is 50 x ly and the maximum directly measured ground fault current is 10 x loy for VAMP 255 and 5 x for VAMP 230 for residual current input The full scope of inverse delay curves goes up to 20 times the setting At high setting the maximum measurement capability limits the scope of inverse curves according the following table Current input Maximum measured Maximum secondary scaled set secondary current ting enabling inverse delay times up to full 20x setting VAMP 255 lon 5 A 50 A 2 5A VAMP 255 Ibn 1 A 10A 0 5 A VAMP 255 lon 0 2A 2A 0 1A VAMP 230 lon 2 5A 25 A 1 25 A The available loy values depend on the order code The VAMP 255 3C7___ has 1A and 5 A l inputs while the VAMP 255 3D7 has 0 2 A and 1 A lg inputs 63230 218 205 2015 Schneider Electric All rights reserved 149 Inverse time operation Section 6 Supporting functions
77. close control pe x Maux OPEN COIL i b n ul ME NEN R 61 o CLOSE COIL uie em SS e ue ee TCS1Dlopen Figure 10 7 Trip circuit supervision using a single digital input when the circuit breaker is in open position NOTE If for example DI7 is used for trip circuit supervision the usage of DI8 0114 is limited to the same circuitry sharing the Vay in the common terminal DIGITAL INPUTS Figure 10 8 An example of digital input DI7 configuration for trip circuit supervision with one dry digital input 286 2015 Schneider Electric All rights reserved 63230 218 205 Section 11 Connections Rear panel OUTPUT MATRIX connected connected and latched DI Figure 10 9 An example of output matrix configuration for trip circuit supervision with one digital input Example of dimensioning the external resistor R using Phoenix Contact component connector P CO 1N4007 L R 3032460 and the Phoenix Disconnect terminal block UT 2 5 TG 30463868 on at least terminals UT 2 5 TG and UT 4 TG VAUX 110 Vdc 20 10 Auxiliary voltage with tolerance Vp 18 Vdc Threshold voltage of the digital input 3 mA Typical current needed to activate the digital input including a 1 mA margin 50 W Rated power of the open coil of the circuit breaker If this value is not known 0 can be used for the VMN Uaux
78. closing circuit can be supervised using the same principle In many applications the optimum digital inputs for trip circuit supervision are the optional inputs DI19 and DI20 They don t share their terminals with any other digital inputs Trip circuit supervision with one digital input 284 The benefits of this scheme is that only one digital inputs is needed and no extra wiring from the relay to the circuit breaker CB is needed Also supervising a 24 Vdc trip circuit is possible The drawback is that an external resistor is needed to supervise the trip circuit on both CB positions If supervising during the closed position only is enough the resistor is not needed e The digital input is connected parallel with the trip contacts Figure 10 6 e The digital input is configured as Normal Closed NC The digital input delay is configured longer than maximum fault time to inhibit any superfluous trip circuit fault alarm when the trip contact is closed e The digital input is connected to a relay in the output matrix giving out any trip circuit alarm e The trip relay should be configured as non latched Otherwise a superfluous trip circuit fault alarm will follow after the trip contact operates and the relay remains closed because of latching e By utilizing an auxiliary contact of the CB for the external resistor also the auxiliary contact in the trip circuit can be supervised e When using the dry digital inputs DI7
79. curve family Set DT Definite time IEC IEEE Inverse time Chapter 5 30 Inverse time operation IEEE2 RI PrgN Type Delay type Set DT Definite time NI VI El LTI Inverse time Chapter 5 30 Inverse time operation Parameters gt Definite operation time for definite time only ResCap Inverse delay multiplier for inverse time only High impedance grounded Sector nets Low impedance Undir grounded nets Offset Angle offset MTA for RecCap and Sector modes Set Sector Default 88 ER Half sector size of the trip area on both sides of the Set offset angle ChCtrl Res Cap control in mode ResCap Set Res Fixed to Resistive characteristic Cap Fixed to Capacitive characteristic DIx Controlled by digital input VI1 4 Controlled by virtual input InUse Selected submode in mode ResCap Mode is not ResCap Res Submode resistive Cap Submode capacitive Input lo1 X1 7 8 see Section 11 Connections Set lo2 X1 9 10 loCalc IL1 IL2 IL3 lo1Peak X1 7 8 peak mode gt only lo2Peak X1 9 10 peak mode gt only Intrmt S Intermittent time Se Dly20x Delay at 20xlon Dly4x Delay at 4xlon Dly2x S Delay at 2xlon Dly1x Delay at 1xlow A B C D E User s constants for standard equations Set Type Parameters See Chapter 5 30 Inverse time operation 63230 218 205 2015 Schneider Electric All rights reserve
80. definition In VAMP devices IEC 60870 5 101 communication protocol is available via menu selection The VAMP unit works as a controlled outstation slave unit in unbalanced mode oupported application functions include process data transmission event transmission command transmission general interrogation clock synchronization transmission of integrated totals and acquisition of transmission delay For more information on IEC 60870 5 101 in VAMP devices refer to the IEC 101 Profile checklist amp datalist pdf document 2 4 2015 Schneider Electric All rights reserved 63230 218 205 Section 9 Communication Table 9 13 Parameters Communication protocols Parameter Value Unit Description Note bit s 1200 bps Bitrate used for serial communication Set 2400 4800 9600 Parity None Parity used for serial communication Set Even Odd LLAddr 1 65534 Link layer address Set LLAddrSize 1 2 Bytes Size of Link layer address Set ALAddr 1 65534 ASDU address Set ALAddrSize 1 2 Bytes Size of ASDU address Set lOAddrSize 2 3 Bytes Information object address size 3 octet Set addresses are created from 2 octet addresses by adding MSB with value 0 COTsize 1 Bytes Cause of transmission size TTFormat Short The parameter determines time tag format Set 3 octet time tag or 7 octet time tag Full MeasFormat Scaled The parameter determines measurement Set data format n
81. detection Short ground faults make the protection to start to pick up but will not cause a trip Here a short fault means one cycle or more For shorter than 1 ms transient type of intermittent ground faults in compensated networks there is a dedicated stage lor 67 When starting happens often enough such intermittent faults can be cleared using the intermittent time setting When a new start happens within the set intermittent time the operation delay counter is not cleared between adjacent faults and finally the stage will trip Four or six independent undirectional ground fault overcurrent stages There are four separately adjustable ground fault stages lo lg lp gt gt gt and l gt gt gt gt The first stage lo can be configured for definite time DT or inverse time operation characteristic IDMT The other stages have definite time operation characteristic By using the definite delay type and setting the delay to its minimum an instantaneous ANSI 50N operation is obtained Using the directional ground fault stages section Directional ground fault protection lg 67N in undirectional mode two more stages with inverse operation time delay are available for undirectional ground fault protection Inverse operation time l gt stage only Inverse delay means that the operation time depends on the amount the measured current exceeds the pick up setting The bigger the fault current is the faster
82. factor angle 60 60 10 Angle of calculated ground factor from line specifications Event enabling Off On On Event mask Table 6 23 Measured and recorded values of feeder fault locator Parameter Value Unit Description Measured values recor Distance km Distance to the fault Xfault ohm Fault reactance Date Fault date Time Fault time Cntr Number of faults Fault A Current during the fault Udrop Un Voltage dip during the fault Type Fault type 1 2 2 3 1 3 1 2 3 1 N 2 N 3 N 1 N 2 N 2 N 3 N 3 N 1 N 1 N 2 N 3 N 208 2015 Schneider Electric All rights reserved 63230 218 205 Section 6 Supporting functions Feeder fault locator FEEDER FAULT LOCATOR d Enable Xfault calc 2 Fault reactance 22340 ohm Distance to fault 44 8 km Fault type 1 H Number of faults Algorithm eonditiom Pick up setting 800 Pick up setting 0 80 xin Triggering digital input 1 Ling reactance unit 0 492 ohm Earth factor 0 961 Earth factor angle 34 Unit km km Event enabling 4 FAULT LOG 17 22 38 07 4 Km s 17 22 58 653 44 9 km 17 22 20 074 3 E3 1 km 1 2242 088 45 1 km 17 24 12 689 47 5 km 0 0 km 0 0 km 0 0 km 4 ADVANCED SETTINGS limit ao a e MEUS 20 Un lo limit 650 xn ha limit 500 Di timeout 100 sx Release timeout 050 s Ground fault location 63230 218 205 The device includes a sophisticated stand alone g
83. input because when the CB is in open position the two digital inputs are in series The first digital input is connected parallel with the auxiliary contact of the open coil of the circuit breaker Another auxiliary contact is connected in series with the circuitry of the first digital input This makes it possible to supervise also the auxiliary contact in the trip circuit The second digital input is connected in parallel with the trip contacts Both inputs are configured as normal closed NC The user s programmable logic is used to combine the digital input signals with an AND port The delay is configured longer than maximum fault time to inhibit any superfluous trip circuit fault alarm when the trip contact is closed The output from the logic is connected to a relay in the output matrix giving out any trip circuit alarm The trip relay should be configured as non latched Otherwise a superfluous trip circuit detected fault alarm will follow after the trip contact operates and the relay remains closed because of latching Both digital inputs must have their own common potential Using the other digital inputs in the same group as the upper DI in the Figure 10 13 is not possible in most applications Using the other digital inputs in the same group as the lower DI in the Figure 10 13 is limited because the whole group will be tied to the auxiliary voltage V Aux In many applications the optimum digital inputs for trip ci
84. interruptions IEC 60255 11 100ms 100 Voltage alternative component IEC 60255 11 1296 of operating voltage DC Voltage dips and short interruptions EN 61000 4 11 30 10ms 100 10ms 60 100ms gt 95 5000ms Test Table 12 2 Electrical safety tests Standard amp Test class level Test value Impulse voltage withstand EN 60255 5 Class III 5 kV 1 2 50 us Dielectric test EN 60255 5 Class III 2 kV 50 Hz Insulation resistance EN 60255 5 Protective bonding resistance EN 60255 27 Power supply burden IEC 60255 1 Table 12 3 Mechanical tests Vibration IEC 60255 21 1 Class 10 60 Hz amplitude 0 035 mm 60 150 Hz acceleration 0 5g sweep rate 1 octave min 20 periods in X Y and Z axis direction Shock IEC 60255 21 1 Class half sine acceleration 5 g duration 11 ms 3 shocks in X Y and Z axis direction Table 12 4 Environmental conditions Ambient temperature in service 40 55 C 40 131 F Ambient temperature storage 40 70 C 40 158 F Relative air humidity 75 1 year average value 95 344 2015 Schneider Electric All rights reserved 63230 218 205 Section 12 Technical data Test and environmental conditions Table 12 5 Casing Degree of protection IEC 60529 Standard front panel NEMA 2 IP30 IP20 rear pa
85. inverse operation time delay of the stall protection stage If the measured current is less than the specified start current 1 the operation time will be longer than the specified start time TsrAgr and vice versa Table 5 12 Parameters of the stall protection stage 1 gt 48 Parameter Value unit Description Setting values ImotSt Nominal motor starting current Ist Imot Motor start detection current Must be less than initial motor starting current Type DT Delay type Definite time Inv Delay type inverse time t Definete operation time k Time multiplier Teranr for inverse delay characteristics Recorded values SCnt Start counter Start reading r Trip counter Trip reading TCntr Max value of fault EDly Elapsed time as compared to the set operate time 100 tripping 63230 218 205 2015 Schneider Electric All rights reserved 81 Stall protection lsr 48 Motor status 82 Section 5 Protection functions There are three possible statuses for a motor stopped starting or running e Motor stopped Motor average current is less than 10 of the motor nominal current e Motor starting To reach the starting position the motor has to be stopped for least 500 ms before starting Motor average current has to increase above the motor start detection current setting value within 200ms Motor will remai
86. is connected to line to line voltages U12 and Us3 and to zero sequence voltage Up For NEMA U V The phase to ground voltages are calculated See Figure 11 17 for VAMP 255 and Figure 11 21 for VAMP 230 The network must use only three wires Any neutral wire must not exist e OLN The device is connected to phase to ground voltages Va Vp and Vc The zero sequence voltage is calculated See Figure 11 18 for VAMP 255 and Figure 11 22 for VAMP 230 There may exist a neutral wire 1LE UyLLy This mode is used with the synchrocheck function See Table 5 39 2LL LLy This mode is used with the synchrocheck function See Table 5 39 LL LLy LLz This mode is used with the synchrocheck function See Table 5 39 The overvoltage protection is always based on the line to line voltage regardless of the measurement mode 216 2015 Schneider Electric All rights reserved 63230 218 205 Section 7 Measurement functions Power calculations Power calculations 63230 218 205 The power calculation in VAMP devices are dependent on the voltage measurement mode see section Voltage measurement modes The equations used for power calculations are described in this section The device is connected to line to line voltages When the device is connected to line to line voltages the voltage measurement mode is set to equal to 2LL Ug The following Aron equation is used for power calculation Note L1 L2 and L3 are IEC phase
87. is constant during the fault Modified versions are implemented in the relay for real time usage Equation 5 8 RI Equation 5 9 RXIDG k I CERE ho 5 0339 0 236 loe t Operation delay in seconds k User s multiplier Measured value pickup User s pick up setting 2015 Schneider Electric All rights reserved 63230 218 205 Section 5 Protection functions Inverse time operation Example for Delay type RI k 0 50 4 pu Pickup 2 pu The operation time in this example will be 2 3 seconds The same result can be read from Equation 5 8 Example for Delay type RXIDG k 0 50 4 pu IPickuP 2 PU Ssg 30 0 5 2 RXIDG The operation time in this example will be 3 9 seconds The same result can be read from Figure 5 60 600 RI 600 RKIDG 400 400 200 200 100 100 20 80 60 60 20 pem 20 10 10 8 8 A 6 Ee 6 20 _ 10 4 4 5 2 k 1 Zo k 2 D D 2 k 0 5 2 k 1 1 1 k 0 8 0 8 0 5 0 6 0 6 0 4 0 4 0 2 0 2 0 1 0 1 0 08 0 08 0 06 0 06 1 2 4 5678 10 20 1 2 3 4 5678 10 20 I Iset I Iset Figure 5 59 Inve
88. lt 50 ms Reset ratio Block limit 0 5 V or 1 03 3 Heset ratio 1 3 depends on the hysteresis setting Inaccuracy starting 3 of the set value blocking 3 of set value or 0 5 V operate time 1 or 30 ms 2015 Schneider Electric All rights reserved 63230 218 205 Section 12 Technical data 63230 218 205 Protection functions Table 12 27 Undervoltage stage U lt lt 27 Undervoltage setting range 20 120 Un Definite time characteristic operating time 0 06 300 00 s step 0 02 Hysteresis 1 001 1 200 0 1 20 0 step 0 1 95 Self blocking value of the undervoltage 0 80 Un Start time Typically 60 ms Heset time 95 ms Retardation time lt 50 ms Reset ratio Block limit 0 5 V or 1 03 3 96 Heset ratio 1 8 depends on the hysteresis setting Inaccuracy starting blocking operate time 3 of the set value 3 of set value or 0 5 V 1 or 30 ms Table 12 28 Undervoltage stage U 27 Undervoltage setting range 20 120 Un Definite time characteristic operating time 0 04 300 00 s step 0 01 Hysteresis 1 001 1 200 0 1 20 0 step 0 1 95 Self blocking value of the undervoltage 0 80 Un Start time Typically 30 ms Heset time 95 ms Retardation time lt 50 ms Reset ratio B
89. measurement function Parameter Value Unit Default Description U1 10 0 120 0 64 Setting value Period 8h Day Month Length of the observation period Week Month Date Date Time Time Table 6 8 Measured and recorded values of voltage sag measurement function Parameter Value Unit Description Measured value Voltage LOW Current voltage status OK U1 Measured positive sequence voltage Recorded values Count Number of voltage sags during the current observation period Prev Number of voltage sags during the previous observation period Total S Total summed time of voltage sags during the current observation period Prev S Total summed time of voltage sags during the previous observation period For details of setting ranges see the section Supporting functions 178 2015 Schneider Electric All rights reserved 63230 218 205 Section 6 Supporting functions Current transformer supervision Current transformer supervision A DANGER HAZARD OF ELECTRIC SHOCK EXPLOSION OR ARC FLASH e Apply appropriate personal protective equipment PPE and follow safe electrical work practices See NFPA 70E NOM 029 STPS 2011 and CSA Z462 e This unit must be installed and serviced only by qualified electrical personnel Turn off all power supplying this unit before working on or inside the unit Always use a properly rated voltage sen
90. oo Z __ Vi t I kx8l 63230 218 205 The device includes a stand alone fault locator algorithm The algorithm can locate a short circuit and ground fault in radial operated networks The fault location is given in reactance ohms and kilometers or miles Fault value can then be exported for example with event to a DMS Distribution Management System The system can then localize the fault If a DMS is not available the distance to the fault is displayed as kilometers or miles as well as a reactance value However the distance value is valid only if the line reactance is set correctly Furthermore the line should be homogenous that is the wire type of the line should be the same for the whole length If there are several wire types on the same line an average line reactance value can be used to get an approximate distance value to the fault examples of line reactance values Overhead wire 0 408 ohms km and 0 378 ohms km This fault locator cannot be used in incoming because this locator has not ability to compensate healthy feeders away When feeder fault locator is calculating short circuit impedance following formula is used Va Vector between the voltage and the ground Vp Vector between the voltage and the ground la Vector between the current and the ground Vector between the current and the ground When feeder fault locator is calculating ground fault impedance following formula is used V
91. rights reserved 63230 218 205 oection 5 Protection functions Programmable stages 99 Table 5 45 Recorded values of the circuit breaker failure stage 8 latest faults CBFP 50BF Parameter Value Description yyyy mm dd Time stamp of the recording date hh mm ss ms Time stamp time of day Elapsed time of the operating time setting 100 trip Programmable stages 99 For special applications the user can build their own protection stages by selecting the supervised signal and the comparison mode The following parameters are available e Priority If operation times less than 80 milliseconds are needed select 10 ms For operation times under one second 20 ms is recommended For longer operation times and THD signals 100 ms is recommended e Coupling A The name of the supervised signal in gt and lt modes see table below Also the name of the supervised signal 1 in Diff and AbsDiff modes e Coupling B The name of the supervised signal 2 in Diff and AbsDiff modes e Compare condition Compare mode gt for over or lt for under comparison Diff and AbsDiff for comparing Coupling and Coupling e Pick up Limit of the stage The available setting range and the unit depend on the selected signal e Operation delay Definite time operation delay e Hysteresis Dead band hysteresis e Compare limit for mode lt Only use
92. setting for l gt stage giving full inverse delay range is 1 25A 5A 0 25 Xlon 25 A Primary 150 2015 Schneider Electric All rights reserved 63230 218 205 oection 5 Protection functions Inverse time operation otandard inverse delays IEC IEEE IEEE2 HI The available standard inverse delays are divided in four categories IEC IEEE IEEE2 and RI called delay curve families Each category of family contains a set of different delay types according the following table Inverse time setting detected error signal The inverse time setting detected error signal will be activated if the delay category is changed and the old delay type doesn t exist in the new category See the section Inverse time operation for more details Limitations The minimum definite time delay starts latest when the measured value is twenty times the setting However there are limitations at high setting values due to the measurement range See the section Inverse time operation for more details Table 5 51 Available standard delay families and the available delay types within each family Delay type Curve family IEC IEEE Definite time Normal inverse Very inverse Extremely inverse Long time inverse Long time extremely inverse Long time very inverse Moderately inverse Short time inverse X Short time extremely inverse Old ASEA type Old ASEA type
93. status forcing for test purposes This Set is a common flag for all stages and output relays On Automatically reset by a 5 minute timeout lo pu The supervised value according the parameter In ies put below loCalc loPeak lo2Peak lo A Pick up value scaled to primary value lo pu Pick up setting relative to the parameter Input and Set the corresponding CT value Curve Delay curve family Set DT Definite time IEC IEEE Inverse time Section Inverse time operation IEEE2 RI PrgN Type Delay type Set DT Definite time NI VI EI LTI Inverse time See section Inverse time operation Parameters t gt S Definite operation time for definite time only Set 63230 218 205 2015 Schneider Electric All rights reserved 95 Ground fault protection lg 50N 51N Section 5 Protection functions Parameter Value Unit Description Note gt Inverse delay multiplier for inverse time only Set Input lo1 X1 7 8 See Section 11 Connections Set lo2 X1 9 10 loCalc IL1 IL2 IL3 loi Peak 1 7 8 peak mode log gt only lo2Peak X1 9 10 peak mode log only Intrmt S Intermittent time Set Dly20x Delay at 20xlon Dly4x Delay at 4xlon Dly2x S Delay at 2xlon Dly1x Delay at 1xlon D E User s constants for standard equations Set Type Parameters See section Inverse time operation Set An editable parameter password needed C Can be cleared to zero F
94. the setting parameters for details The timer outputs are available for logic functions and for the block and output matrix Monday Tuesday Wednesday Thursday Friday Saturday Sunday not in use Daily Lf Monday Tuesday Wednesday Thursday A p Saturday p Sunday MTWTF Ss MTWTES pA pL p SatSun 7 Figure 6 9 Timer output sequence in different modes The user can force any timer which is in use on or off The forcing is done by writing a new status value No forcing flag is needed as in forcing i e the output relays The forced time is valid until the next forcing or until the next reversing timed act from the timer itself The status of each timer is stored in non volatile memory when the auxiliary power is switched off At start up the status of each timer is recovered 198 2015 Schneider Electric All rights reserved 63230 218 205 oection 6 Supporting functions Timers Table 6 18 Setting parameters of timers Parameter Value Description TimerN Timer status Not in use 0 Output is inactive 1 Output is active On hh mm ss Activation time of the timer Off hh mm ss De activation time of the timer Mode For each four timers there are 12 different modes available The timer is off and not running The output is off i e
95. this is indicated with string OVF after the event code Table 6 1 Setting parameters for events Parameter Description Count Number of events ClrEn Clear event buffer Set Clear Order Old New Order of the event buffer for local display Set New Old FVSca Scaling of event fault value Set PU Per unit scaling Pri Primary scaling Display On Indication dispaly is enabled Set Alarms Off No indication display FORMAT OF EVENTS ON THE LOCAL DISPLAY Code CHENN CH event channel NN event code Event description Event channel and code in plain text yyyy mm dd Date for available date formats see section System clock and synchronization hh mm ss nnn Time 166 2015 Schneider Electric All rights reserved 63230 218 205 Section 6 Supporting functions Event log Disturbance recorder 63230 218 205 The disturbance recorder can be used to record all the measured signals that is currents voltage and the status information of digital inputs DI and digital outputs DO The digital inputs include also the arc detection signals S1 S2 BI and BO if the optional arc detection is available Triggering the recorder The recorder can be triggered by any start or trip signal from any protection stage or by a digital input The triggering signal is selected in the output matrix vertical signal DR The recording can also be triggered manually
96. time zone 5 45 is given as 5 75 DST No Yes Daylight saving time for SNTP Set SySrc Clock synchronisation source Internal No sync recognized since 200s DI Digital input SNTP Protocol sync SpaBus Protocol sync ModBus Protocol sync ModBus TCP Protocol sync ProfibusDP Protocol sync IEC101 Protocol sync IEC103 Protocol sync DNP3 Protocol sync IRIG B003 IRIG timecode 7 MsgCnt 0 65535 The number of received synchronisation messages or pulses 0 etc Dev 32767 ms Latest time deviation between the system clock and the received synchronization SyOS 10000 000 S Synchronisation correction for any constant deviation Set in the synchronizing source AAIntv 10000 S Adapted auto adjust interval for 1 ms correction Set AvDrtt Lead Lag Adapted average clock drift sign Set FilDev 125 ms Filtered synchronization deviation Set Set An editable parameter password needed A range of 11 h 12 h would cover the whole Ground but because the International Date Line does not follow the 180 meridian a more wide range is needed If external synchronization is used this parameter will be set automatically Set the DI delay to its minimum and the polarity such that the leading edge is the synchronizing edge Relay needs to be equipped with suitable hardware option module to receive IRIG B clock synchronization signal See Section 14 Order information 194 2015 Schneider Electric All rights rese
97. trip Active setting group during fault 144 2015 Schneider Electric All rights reserved 63230 218 205 oection 5 Protection functions Arc fault protection 50ARC 50NARC optional Arc fault detection BOARC 50NARO optional 63230 218 205 NOTE This protection function needs optional hardware in slot X6 More details of the hardware can be found in sections Optional two channel arc detection card and Arc protection interface option Arc detection is used for fast arc detection The function is based on simultaneous light and current measurement Special arc sensors are used to measure the light of an arc Three stages for arc faults There are three separate stages for the various current inputs e Arcl for phase to phase arc faults Current inputs Ip lc are used e Arclg4 for phase to ground arc faults Current input Ip is used e Arclgo for phase to ground arc faults Current input 102 is used Light channel selection The light information source to the stages can be selected from the following list e No sensor selected The stage will not work e 1 Light sensor 51 e 52 Light sensor S2 e 51 52 Either one of the light sensors S1 or S2 e Binary input of the arc card 48 Vdc e 1 Bl Light sensor S1 or the binary input e 52 Light sensor S2 or the binary input e 51 52 Light sensor 51 or S2 or the binary input Binary input The bi
98. will be the operation Accomplished inverse delays are available for the l gt stage The inverse delay types are described in the section Inverse time operation The device will show a scaleable graph of the configured delay on the local panel display Inverse time limitation The maximum measured secondary residual current is 10 x lg and maximum measured phase current is 50 x ly This limits the scope of inverse curves with high pick up settings See section Inverse time operation for more information 2015 Schneider Electric All rights reserved 63230 218 205 Section 5 Protection functions Setting groups Directional ground fault protection lg 67N There are two settings groups available for each stage Switching between setting groups can be controlled by digital inputs virtual inputs communication logic and manually Table 5 17 Parameters of the undirectional ground fault stage lg bON 51N Parameter Value Unit Description Note Status E Current status of the stage Blocked Start F Trip TripTime Estimated time to trip SCntr Cumulative start counter Clr TCntr Cumulative trip counter Clr SetGrp 1or2 Active setting group Set SGrpDI Digital signal to select the active setting group Set None DIx Digital input VIx Virtual input LEDx LED indicator signal VOx Virtual output Force Off Force flag for
99. 0 324 Block diagrams of option modules 328 Block diagrams of optional arc modules 328 Block diagram of optional DI19 DI20 328 Connection examples 329 VAMP 25S MT HM 329 VAMIP 2 OU e esaet queens 333 Bap eat dk 336 CONNECHONS T ETT 336 Measuring CIRCUITS suisses vir Sou Sou rita EUR 338 Auxiliary power supply 339 EE ES gettin oto oo o Seu Gore ed 340 2015 Schneider Electric All rights reserved 63230 218 205 Table of Contents Section 13 Construction Section 14 Order information section 15 Revision history 63230 218 205 TIO COMMAGI TU 340 DIG Mal COMACS suet sc eye 341 Ethernet connection 341 Local serial communication port 341 Remote control connection option 342 Arc detection interface Option 342 Analog output connection option 343 Test and environmental conditions 344 Protection TUNCIONS ecd toi tui Eie Pet n edt 346 Non directional current protection 346 Directional current protection 352 Frequent start protection
100. 0 8 E 7 Slope setting df dt Hz s 0 Figure 5 36 At very sensitive slope settings the fastest possible operation time is limited according the figure Inverse operation time characteristics By setting the second delay parameter tmn smaller than the operational delay t an inverse type of operation time characteristics is achieved Figure 5 38 shows one example where the frequency behavior is the same as in the first figure but the ty setting is 0 15 s instead of being equal with t The operation time depends of the measured average slope according the following equation 2014 Schneider Electric All rights reserved 127 Rate of change of frequency ROCOF 81R Section 5 Protection functions Equation 5 4 128 f _ TRIP s trrip Resulting operation time seconds SseT Cf dt i e slope setting hertz seconds tset Operation time setting t seconds s Measured average frequency slope hertz seconds The minimum operation time is always limited by the setting parameter tmin In the example of the fastest operation time 0 15 s is achieved when the slope is 2 Hz s or more The leftmost curve in Figure 5 37 shows the inverse characteristics with the same settings as in Figure 5 38 Slope and delay settings 0 5 Hz s 1 Hz s 1 5 Hz s 0 6 0 6 5 0 5 S 0 4 S ROCOF6 v3 0 5 0 7 0 6 0 5 0 4 Operation time s 0 2 Setting for minimum delay t7 0 15 5
101. 0 ms Operating time Delayed Arc L gt 0 01 0 15s BO operating time lt 3 ms Reset time 95 ms Reset time Delayed ARC L lt 120 ms Reset time BO lt 85 ms Reset ratio 0 90 Inaccuracy Starting 10 of the set value Operating time Delayed ARC light 5 ms 10 ms Inaccuracy Activation Activation block limit Operating time at definite time function 0 5 V or 3 of the set value 5 of the set value 1 or 30 ms 2015 Schneider Electric All rights reserved 363 Supporting functions Section 12 Technical data Supporting functions This is the instantaneous time i e the minimum total operational time including the fault detection time and operation time of the trip contacts The operation of disturbance recorder depends on the following settings The recording time and the number of records depend on the time setting and the number of selected channels Table 12 40 Disturbance recorder DR Mode of recording Saturated Overflow Sample rate Waveform recording 32 cycle 16 cycle 8 cycle Trend curve recording 10 20 200 ms 1 5 10 15 30s 1 min Recording time one record 0 1 s 12 000 min According recorder setting Pre trigger rate 0 100 Table 12 41 Inrush current detection Cold load settings dle current 0 01 0 50 x In Pickup current 0 30 10 00 x Ix Maximum time 0 01 300 00 s step 0
102. 1 0 2 0 2 k 1 k 0 5 0 1 0 1 0 08 0 08 k 0 5 0 06 0 06 1 2 3 4 5678 10 20 1 9 3 4 5678 10 20 I Iset Iset Figure 5 55 IEEE2 moderately inverse delay 63230 218 205 2015 Schneider Electric All rights reserved Figure 5 56 IEEE2 normal inverse delay 159 Inverse time operation 600 400 200 100 80 60 40 20 delay s 0 8 0 6 0 4 0 2 0 1 0 08 0 06 Figure 5 57 IEEE2 very inverse delay 160 2 3 4 5 6 Iset Section 6 Supporting functions IEEE2 VI IEEE2 EI 400 200 100 80 60 40 20 10 8 B 6 gt 4 k 20 2 k 10 20 0 8 5 0 6 k 10 4 k 5 k 2 0 2 _ k 2 E 0 1 0 08 ts MS k 0 5 0 06 k 0 5 k 1 78 10 20 2 3 4 5 678 10 20 I Iset I Figure 5 58 IEEE2 extremely inverse delay RI and RXIDG type inverse time operation These two inverse delay types have their origin in old ASEA ABB ground fault relays The operation delay of types RI and RXIDG depends on the measured value and other parameters according Equation 5 8 and Equation 5 9 Actually these equations can only be used to draw graphs or when the measured value
103. 20 mA step 1 mA Minimum output current 0 19 mA step 1 mA Resolution 12 bit Current step lt 6 uA Inaccuracy 20 uA Response time normal mode lt 400 ms fast mode lt 50 ms Burden lt 6000 63230 218 205 2015 Schneider Electric All rights reserved 343 Test and environmental conditions Test and environmental conditions Table 12 1 Disturbance tests Section 12 Technical data Test Standard amp Test class level Test value Emission EN 61000 6 4 IEC 60255 26 Conducted EN 55011 Class A IEC 60255 25 0 15 30 MHz Emitted EN 55011 Class A IEC 60255 25 CISPR 11 30 1000 MHz Immunity EN 61000 6 2 IEC 60255 26 1Mhz damped oscillatory wave IEC 60255 22 1 2 5kVp CM 1 0kVp DM Static discharge ESD EN 61000 4 2 Level 4 IEC 60255 22 2 Class 4 8 kV contact discharge 15 kV air discharge Emitted HF field EN 61000 4 3 Level IEC 60255 22 3 80 1000 MHz 10 V m Fast transients EFT EN 61000 4 4 Level IEC 60255 22 4 Class B 2 kV 5 50 ns 5 kHz Surge EN 61000 4 5 Level 3 IEC 60255 22 5 2 kV 1 2 50 us CM 1 kV 1 2 50 us DM Conducted HF field EN 61000 4 6 Level 3 IEC 60255 22 6 0 15 80 MHz 10 Vemf Power frequency magnetic field EN 61000 4 8 300A m continuous Pulse magnetic field EN 61000 4 9 Level 5 1000A m 1 2 50 us Voltage
104. 218 205 Section 6 Supporting functions 6 7 Voltage transformer supervision Table 6 14 Local panel parameters of CBWEAR function Parameter Description CBWEAR STATUS Operations left for AliL1 Alarm 1 phase L1 Al1L2 Alarm 1 phase L2 Al1L3 Alarm 1 phase L3 Al2L1 Alarm 2 phase L1 Al2L2 Alarm 2 phase L2 Al2L3 Alarm 2 phase L3 Latest trip Date Time stamp of the latest trip operation time IL1 A Interrupted current of phase L1 IL2 A Interrupted current of phase L2 IL3 A Interrupted current of phase L3 CBWEAR SET Alarm1 Current 0 00 100 00 kA Alarm1 current level Set Cycles 100000 1 Alarm1 limit for operations left Set Alarm2 Current 0 00 100 00 kA Alarm2 current level Set Cycles 100000 1 Alarm1 limit for operations left Set CBWEAR SET2 63230 218 205 2015 Schneider Electric All rights reserved 187 Energy pulse outputs oection 6 Supporting functions Al1On On Alarm1 on event enabling Set Off Al1Off On Alarm1 off event enabling Set Off Al2On On Alarm2 on event enabling Set Off Al2Off On Alarm2 off event enabling Set Off Clear Clearing of cycle counters Set Clear Set An editable parameter password needed The breaker curve table is edited with VAMPSET L1 L2 and L3 are IEC phase names For NEMA the phases are a
105. 24 00 year 1st January 00 00 31st December 24 00 After each period the number of interruptions and the total interruption time are stored as previous values The interruption counter and the total time are cleared for a new period The old previous values are overwritten The voltage interruption is based on the value of the positive sequence voltage and a user given limit value Whenever the measured V goes below the limit the interruption counter is increased and the total time counter starts increasing Shortest recognized interruption time is 40 ms If the voltage off time is shorter it may be recognized depending on the relative depth of the voltage dip If the voltage has been significantly over the limit U lt and then there is a small and short under swing it will not be recognized Figure 6 2 Note For NEMA U V Voltage Ul Time 10 20 30 40 50 6 70 80 90 Figure 6 2 A short voltage interruption which is probably not recognized If the limit V4 is high and the voltage has been near this limit and then there is a short but very deep dip it will be recognized Figure 6 3 63230 218 205 2015 Schneider Electric All rights reserved 177 Voltage sags and swells Voltage U Section 6 Supporting functions gt Time 10 20 60 70 80 90 ins Figure 6 3 A short voltage interrupt that will be recognized Table 6 7 Setting parameters of the voltage sag
106. 3 DNP TCP nnn Ip port for protocol default 502 Set nnn Message counter nnn Detected error nnn Timeout counter Table 9 6 CP PORT 2nd INST Parameter Value Unit Description Note Ethernet port protocol Protocol selection for the extension port Set TCP PORT 2nd INST None Command line interface for VAMPSET ModbusTCPs Modbus TCP slave IEC 61850 IEC 61850 protocol EtherNet IP Ethernet IP protocol DNP3 DNP TCP Port nnn Ip port for protocol default 502 Set Msg nnn Message counter Errors nnn Detected error Tout nnn Timeout counter Set An editable parameter password needed 63230 218 205 2015 Schneider Electric All rights reserved 265 Communication protocols Section 9 Communication Communication protocols PC communication 266 The protocols enable the transfer of the following type of data events status information measurements control commands clock synchronizing Settings SPA bus and embedded SPA bus only PC communication is using a VAMP specified command line interface The VAMPSET program can communicate using the local HS 232 port or using ethernet interface It is also possible to select SPA bus protocol for the local port and configure the VAMPSET to embed the command line interface inside SPA bus messages For Ethernet configuration see the section Ethernet port 2015 Schneider Electric All rights reserved 63230 218 205 oection 9 Communication Communication
107. 4 90 ind ind Cap 2 JEN B DIRECTIONAL NON DIRECTIONAL res BASE ANGLE 0 TRIP AREA TRIP AREA cap ind cap ind Idir_modeA 15 90 Figure 5 9 Difference between directional mode and non directional mode The grey area is the trip region An example of bi directional operation characteristic is shown in Figure 5 10 The right side stage in this example is the stage I and the left side is j The base angle setting of the I is 0 and the base angle of Iy gt gt is set to 180 Ip gt gt TRIP AREA BASEANGLE 0 BASEANGLE 2 180 I gt TRIP AREA cap ind 90 Idir modeBiDir 15 Figure 5 10 Bi directional application with two stages ly and gt gt When any of the three phase currents exceeds the setting value and in directional mode the phase angle including the base angle is within the active 88 wide sector the stage picks up and issues a start signal If this fault situation remains on longer than the delay setting a trip signal is issued 70 2015 Schneider Electric All rights reserved 63230 218 205 oection 5 Protection functions Directional phase overcurrent lo gt 67 Four independent stages There are four separately adjustable stages available l gt gt gt gt gt gt and lp gt gt gt gt Inverse operation time Stages l gt and gt gt can be configured for definite ti
108. 5 Residual current 0 2 of lonom tolerance 0 05 63230 218 205 2015 Schneider Electric All rights reserved 241 Measurement accuracy 212 Section 7 Measurement functions Table 7 2 Voltage inputs V4 Vg Vc Measuring range 0 5 175V Inaccuracy 0 5 96 or 0 3 V The usage of voltage inputs depends on the configuration parameter voltage measurement mode For example Uc is the zero sequence voltage input Ug if the mode 2LL is selected The specified frequency range is 45 Hz 65 Hz Table 7 3 Residual current inputs lo loe Measuring range 0 10 x I VAMP 255 0 5xIN VAMP 230 Inaccuracy 1 5 0 3 of value or 0 2 of In gt 1 5 3 96 of value The rated input ly is 5A 1 A or 0 2 A It is specified in the order code of the relay The specified frequency range is 45 Hz 65 Hz Table 7 4 Frequency Measuring range 16Hz 75Hz Inaccuracy 10 mHz In VAMP 255 230 the frequency is measured from voltage signals Table 7 5 Power measurements Q S Inaccuracy PF gt 0 5 1 of value or 3 VAsgc The specified frequency range is 45 Hz 65 Hz Table 7 6 Power factor Inaccuracy PF gt 0 5 2 or 0 02 The specified frequency range is 45 Hz 65 Hz Table 7 7 Energy counters E Eq E Eq Inaccuracy PF gt 0 5 1 96 of value or 3 Whseconpary 1 h The specif
109. 5 Schneider Electric All rights reserved 63230 218 205 oection 5 Protection functions Inverse time operation Programmable inverse time curves 63230 218 205 The current time curve points are programmed using VAMPSET software Once programmed the relay will require a reboot for the changes to take effect Rules for defining the curve points e configuration must begin from the topmost line e ine order must be as follows the smallest current longest operation time on the top and the largest current shortest operation time on the bottom e all unused lines on the bottom should be filled with 1 00 0 005 Here is an example configuration of curve points Current l Ipickup Operation delay 1 00 10 00 s 2 00 6 50 s 5 00 4 00 s 10 00 3 00 s 20 00 2 00 s 40 00 1 00 s 1 00 0 00 s 1 00 0 00 s 1 00 0 00 s 1 00 0 00 s 1 00 0 00 s 1 00 0 00 s 1 00 0 00 s 1 00 0 00 s 1 00 0 00 s 1 00 0 00 s 2 3 4 5 6 7 8 9 2015 Schneider Electric All rights reserved 163 Inverse time operation Section 6 Supporting functions Inverse time setting detected error signal The inverse time setting detected error signal will be activated if interpolation with the given points does not calculate properly See the section Inverse time operation for more details Limitations The minimum definite time delay start latest when the measured value is twenty ti
110. 66 Parameter Value unit Description Measured value Mot strs Motor starts in last hour T Min Elapsed time from motor start Setting values Sts h Max starts in one hour Interval Min Min interval between two consecutive starts Recorded values SCntr Start counter Start reading TCntr Trip counter Trip reading Descr 1StartLeft 1 start left activates the N gt start signal MaxStarts Max start trip activates the N gt trip signal Interval Min interval between two consecutive starts has not yet been elapsed activates the N gt trip signal Tot Mot Sirs Number of total motor starts Mot Strs h Number of motor starts in last hour El Time from mot Strt Min Elapsed time from the last motor start 63230 218 205 2015 Schneider Electric All rights reserved 85 Undercurrent protection l lt 37 Section 5 Protection functions Undercurrent protection I lt 37 The undercurrent unit measures the fundamental frequency component of the phase currents The stage I lt can be configured for definite time characteristic The undercurrent stage is protecting rather the device driven by the motor e g a submersible pump than the motor itself Table 5 14 Parameters of the undercurrent stage I lt 37 Parameter Value unit Description Measured value ILmin A Min value of phase currents IL1 IL3 in primary value Setting
111. 8 3 Blocking matrix and output matrix 63230 218 205 2015 Schneider Electric All rights reserved 241 Controllable objects oection 8 Control functions Controllable objects The device allows the control of six objects that is circuit breakers disconnects and grounding switches Controlling can be done by select execute or direct control principle The object block matrix and logic functions can be used to configure interlocking before the output pulse is issued The objects 1 6 are controllable while the objects 7 8 are only able to show the status Controlling is possible by the following ways e through the local e through a remote communication e through a digital input The connection of an object to specific output relays is done via an output matrix object 1 6 open output object 1 6 close output There is also an output signal Object failed which is activated if the control of an object is not completed Object states Each object has the following states Setting Value Description Object state Undefined 00 Actual state of the object Open Close Undefined 11 Basic settings for controllable objects Each controllable object has the following settings Setting Value Description Open DI for obj open None any digital input virtual input or virtual information Close output DI for obj close information DI for obj
112. 96 See Figure 2 12 Uline U LINE VOLTAGES Average value for the three line voltages V U12 U LINE VOLTAGES Phase to phase voltage V12 V U23 U LINE VOLTAGES Phase to phase voltage V23 V U31 U LINE VOLTAGES Phase to phase voltage V31 V UL U PHASE VOLTAGES Average for the three phase voltages V 63230 218 205 2015 Schneider Electric All rights reserved 39 Configuration and parameter setting Section 2 Local panel user interface Value Menu Submenu Description UL1 U PHASE VOLTAGES Phase to ground voltage VA UL2 U PHASE VOLTAGES Phase to ground voltage VB UL3 Phase to ground voltage VC U PHASE VOLTAGES Uo Residual voltage Vo 95 U SYMMETRIC VOLTAGES U1 Positive sequence voltage U SYMMETRIC VOLTAGES U2 Negative sequence voltage 95 U SYMMETRIC VOLTAGES U2 U1 U SYMMETRIC VOLTAGES Negative sequence voltage related to positive sequence voltage 76 THDU U HARM DISTORTION Total harmonic distortion of the mean value of voltages 96 THDUa U HARM DISTORTION Total harmonic distortion of the voltage input a 96 THDUb U HARM DISTORTION Total harmonic distortion of the voltage input b THDUc U HARM DISTORTION Total harmonic distortion of the voltage input c Diagram U HARMONICS of Ua Harmonics of voltage input Ua 96 See Figure 2 12 Diagram U HARMONICS of Ub Harmonics of voltage input Ub 96 See Figure 2 12 Diagram U HARMONICS
113. A bus slave ProfibusDP Profibus DB slave ModbusSla Modbus RTU slave ModbusTCPs IEC Modbus TCP slave 103 IEC 60870 5 103 slave ExternallO Modbus RTU master for external I O modules DNP3 DNP 3 0 Msg 0 232 1 Message counter since the device has restarted or Clr since last clearing Errors 0 216 1 Detected protocol errors since the device has Clr restarted or since last clearing Tout 0 216 1 Detected timeout errors since the device has restarted Clr or since last clearing Display of current communication parameters 1 speed DPS Speed bit s D number of data bits P parity none even odd S number of stop bits Debug Echo to local port Set No No echo Binary For binary protocols ASCII For SPA bus protocol Set An editable parameter password needed Clr Clearing to zero is possible 1 The communication parameters are set in the protocol specific menus For the local port command line interface the parameters are set in configuration menu 262 2015 Schneider Electric All rights reserved 63230 218 205 Section 9 Communication Extension port X4 Communication ports This is a non isolated RS 485 port for external I O devices The port is located in the same rear panel 095 connector X4 as the local port but pins 7 8 5 are used instead of the standard RS 232 pins 2 3 5 used by the local port See Figure 9 1 Table 9 3 Parameters
114. Customer Care Center and ask for a password break A device specific break code is sent back to you That code will be valid for the next two weeks Description set break 4435876 Restore the factory default passwords 4435876 is just an example The actual code should be asked from from your nearest Schneider Electric Customer Care Center Now the passwords are restored to the default values See Operating levels 63230 218 205 2015 Schneider Electric All rights reserved 29 Configuration and parameter setting Section 2 Local panel user interface Operating measures Control functions 30 The default display of the local panel is a single line diagram including relay identification Local Remote indication Auto reclose on off selection and selected analog measurement values Please note the following e the control functions directly control the contacts assigned to it and will operate the equipment attached to it e the operator password must be active in order to be able to control the objects Please refer to Opening access A DANGER HAZARD OF ELECTRIC SHOCK EXPLOSION OR ARC FLASH Remove the cause of the event that resulted in the latched output relay Failure to follow these instructions will result in death serious injury or equipment damage Toggling Local Remote control NOTE If the relay is in local mode the remote commands are rejected 1 2 Push The previous
115. Dead band Document file DSR rear panel local port Daylight saving time Adjusting the official local time forward by one hour for summer DST time DTR Data terminal ready An RS232 signal Output and always true 8 Vdc in front panel port of VAMP relays EFT Fast Fourier transform Algorithm to convert time domain signals to frequency domain or to phasors Human machine interface i e dead band Used to avoid oscillation when comparing two near by values Nominal current of the selected mode In feeder mode VTPRIMARv In motor mode IMOT Nominal current of the protected motor Nominal current Rating of CT primary or secondary Another name for pick up setting value I gt Another name for pick up setting value lo Nominal current of lo input in general Nominal current of the lot input of the device M Hysteresis MODE MoT SET osET on oon Nominal current of the loe input of the device International Electrotechnical Commission An international standardization organization Abbreviation for communication protocol defined in standard IEC 60870 5 101 Abbreviation for communication protocol defined in standard IEC 60870 5 103 Intelligent electronic device Institute of Electrical and Electronics Engineers LED A Local area network Ethernet based network for computers and IEDs Output relays and indication LEDs can be latched which means that they are not releas
116. Digital input 1 Digital input 2 Digital input 3 Digital input 4 Digital input 5 Digital input 6 Alarm relay 1 common connector Alarm relay 1 normal open connector Alarm relay 1 normal closed connector Trip relay 2 Trip relay 2 Trip relay 1 Trip relay 1 Auxiliary voltage Auxiliary voltage 2015 Schneider Electric All rights reserved 63230 218 205 Section 11 Connections Terminal X7 0 2 3 4 4 5 5 6 6 7 7 8 8 9 9 10 10 11 11 12 12 13 13 us 14 17 18 17 18 2 3 4 5 6 7 63230 218 205 Symbol DI7 DI8 DI9 DI10 DI11 DI12 COM1 DI13 0114 0115 0116 0117 0118 COM2 T4 T4 T3 Symbol BI BO COM S1 gt S1 gt S2 gt S2 gt Rear panel Description Digital input 7 Digital input 8 Digital input 9 Digital input 10 Digital input 11 Digital input 12 Common potential of digital inputs 7 12 Digital input 13 Digital input 14 Digital input 15 Digital input 16 Digital input 17 Digital input 18 Common potential of digital inputs 13 18 Trip relay 4 Trip relay 4 Trip relay 3 Trip relay 3 Description External arc light input Arc light output Common connector of arc light I O Arc sensor 1 positive connector Arc sensor 1 negative connector Arc sensor 2 positive connector Arc sensor 2 negative connector Arc sensor itself is polarity free 2015 Schneider Elect
117. Electric All rights reserved 63230 218 205 Section 6 Supporting functions 6 7 Voltage transformer supervision 63230 218 205 setting alarm points There are two alarm points available having two setting parameters each e Current The first alarm can be set for example to nominal current of the CB or any application typical current The second alarm can be set for example according a typical fault current Operations left alarm limit An alarm is activated when there are less operations left at the given current level than this limit Any actual interrupted current will be logarithmically weighted for the two given alarm current levels and the number of operations left at the alarm points is decreased accordingly When the operations left i e the number of remaining operations goes under the given alarm limit an alarm signal is issued to the output matrix Also an event is generated depending on the event enabling Clearing operations left counters After the breaker curve table is filled and the alarm currents are defined the wearing function can be initialised by clearing the decreasing operation counters with parameter Clear Clear oper left cntrs After clearing the relay will show the maximum allowed operations for the defined alarm current levels Operation counters to monitor the condition The operations left can be read from the counters Al1Ln Alarm 1 and Al2Ln Alarm2 There are three values for both
118. Fit pu Maximum detected ground fault current EDly Elapsed time of the operating time setting 100 trip Uo Max Up voltage during the fault SetGrp 1 Active setting group during fault 2 63230 218 205 2015 Schneider Electric All rights reserved 103 Intermittent transient ground fault protection lor Section 5 Protection functions Capacitor bank unbalance protection 104 The device enables capacitor filter and reactor bank protection with Its five current measurement inputs The fifth input is typically useful for unbalance current measurement of a double wye connected ungrounded bank Furthermore the unbalance protection is highly sensitive to detect internal faults of a bank because of the sophisticated natural unbalance compensation However the location method gives the protection a new dimension and enables easy maintenance monitoring for a bank This protection scheme is specially used in double wye connected capacitor banks The unbalance current is measured with a dedicated current transformer could be like 5A 5A between two starpoints of the bank The unbalance current is not affected by system unbalance However due to manufacturing tolerances some amount of natural unbalance current exists between the starpoints This natural unbalance current affects the settings thus the setting has to be increased C NOTE L1 L2 and L3 IEC phase names For NEMA the phases are as follows
119. I Objects can be controlled with digital input virtual input or virtual output There are four settings for each controllable object Setting Active DI for remote open close control In remote state DI for local open close control In local state If the device is in local control state the remote control inputs are ignored and vice versa Object is controlled when a rising edge is detected from the selected input Length of digital input pulse should be at least 60 ms Auto reclose function 79 The VAMP protection relays include a sophisticated Auto reclosing AR function The AR function is normally used in feeder protection relays that are protecting an overhead line Most of the overhead line faults are temporary in nature 8596 can be cleared by using the AR function General The basic idea is that normal protection functions will detect the fault Then the protection function will trigger the AR function After tripping the circuit breaker CB the AR function can reclose the CB Normally the first reclose or shot is so short in time that consumers cannot detect anything However the fault is cleared and the feeder will continue in normal service Terminology Even though the basic principle of AR is very simple there are a lot of different timers and parameters that have to be set In VAMP relays there are five shots shot consists of open time so called dead time and close time so cal
120. IEEE RI Prg Curve type El VI NI LTI MI depends on the family Time multiplier k 0 05 20 0 except 0 50 20 0 for RXIDG IEEE and IEEE2 Start time Typically 30 ms Reset time lt 95 ms Reset ratio 0 95 Inaccuracy Starting 2 of the set value or 0 3 of the rated value Starting Peak mode 5 of the set value or 2 of the rated value Sine wave lt 65 Hz Operating time at definite time function 1 or 25 ms Operating time at IDMT function 5 or at least 25 ms L1 L2 and L3 are IEC phase names For NEMA the phases are as follows L1 A L2 B and L3 C 350 2015 Schneider Electric All rights reserved 63230 218 205 Section 12 Technical data Protection functions Table 12 17 Ground fault stages lg lg lg bON 51N Input signal input X1 8 loo input X1 9 1 0 locale 11 3 Setting range 0 01 8 00 pu When lo or Igo 0 05 20 0 pu When loca Definite time function Operating time 0 04 300 00 s step 0 02 s Start time Typically 30 ms Reset time lt 95 ms Reset ratio 0 95 Inaccuracy Starting 2 of the set value or 0 3 of the rated value Starting Peak mode 5 of the set value or 2 of the rated value Sine wave 65 Hz Operate time 1 or 25 ms Table 12 18 Directional inter
121. Inverse delay means that the operation time depends on the amount that the measured current exceeds the pick up setting The more intense the fault current is the faster will be the operation Accomplished inverse delays are available for the stage The inverse delay types are described in the section Inverse time operation The device will show the currently used inverse delay curve graph on the local panel display 2015 Schneider Electric All rights reserved 63230 218 205 Section 5 Protection functions Overcurrent protection I gt 50 51 Inverse time limitation The maximum measured secondary current is 5O0xly This limits the scope of inverse curves with high pick up settings See Inverse time operation for more information Cold load and inrush current handling oee Cold load pick up and inrush current detection Setting groups There are two settings groups available for each stage Switching between setting groups can be controlled by digital inputs virtual inputs communication logic and manually Setting I gt s Delay Definite inverse Inverse time Multiplier Enable events time characteristics Figure 5 5 Block diagram of the three phase overcurrent stage I gt SV Issblock Figure 5 6 Block diagram of the three phase overcurrent stage I and gt gt gt 63230 218 205 2015 Schneider Electric All rights reserved 63 Overcurrent protection I 50 51 oection 5 Protection functions Tab
122. MA the phases are as follows L1 A L2 B and L3 C 72 2015 Schneider Electric All rights reserved 63230 218 205 oection 5 Protection functions Directional phase overcurrent lo 67 Table 5 5 Parameters of the directional overcurrent stages ly lg gt gt gt gt 67 Parameter Value Unit Description Note Status Current status of the stage Blocked Start F Trip F SCntr Cumulative start counter C TCntr Cumulative trip counter C SetGrp 1 or2 Active setting group Set Digital signal to select the active setting group None Digital input Virtual input LED indicator signal Virtual output Force flag for status forcing for test purposes This is a common flag for all stages and output relays too Automatically reset by a 5 minute timeout A The supervised value Max of IL1 IL2 and IL3 lp gt gt gt gt Pick up value scaled to primary value Ip 222 gt gt gt gt xlmode Pick up setting Set Ip 222 gt gt gt Definite operation time for definite time only Set t gt gt gt gt Mode Dir Directional 67 Set Undir Undirectional 50 51 Dir back up Directional and undirectional back up Offset Angle offset in degrees Set U I angle 9 Measured 0 1 angle U1 Un Measured positive sequence voltage Set An editable parameter password needed C Can be cleared to zero F Editable w
123. O COM S1 gt S1 gt S2 gt S2 gt Section 11 Connections Description Internal control voltage for digital inputs 1 6 Digital input 1 Digital input 2 Digital input 3 Digital input 4 Digital input 5 Digital input 6 Alarm relay 1 common connector Alarm relay 1 normal open connector Alarm relay 1 normal closed connector Trip relay 2 Trip relay 2 Trip relay 1 Trip relay 1 Auxiliary voltage Auxiliary voltage Description External arc light input Arc light output Common connector of arc light I O Arc sensor 1 positive connector Arc sensor 1 negative connector Arc sensor 2 positive connector Arc sensor 2 negative connector Arc sensor itself is polarity free 2015 Schneider Electric All rights reserved 63230 218 205 Section 11 Connections Auxiliary voltage Terminal X6 with 0119 0120 option NO Symbol Description 1 DI19 Digital input 19 2 DI19 Digital input 19 3 DI20 Digital input 20 4 DI20 Digital input 20 5 6 S1 gt Arc sensor 1 positive connector 7 S1 gt Arc sensor 1 negative connector Arc sensor itself is polarity free Auxiliary voltage The external auxiliary voltage Vay standard 40 265 V ac dc or optional 18 36 Vdc for the terminal is connected to the terminals X3 17 18 NOTE When optional 18 36 Vdc power module is used the polarity is as follows X3 17 negative X3 18 positive Serial communication connection
124. OCHECK 29 130 Magnetishing inrush 1 gt 68F2 138 Transformer over exicitation lg 68F5 139 Circuit breaker failure protection CBFP 140 Programmable stages 99 141 Arc fault detection 50ARC 50NARC optional 145 Inverse time operation 148 Standard inverse delays IEC IEEE IEEE2 HI 151 Free parameterization using IEC IEEE and IEEE2 Saina 153 Programmable inverse time curves 163 165 mnes EE 165 Disturbance recorder 167 Running virtual comtrade files 172 Cold load pick up and inrush current detection 173 Voltage sags and swells 175 Voltage interruptions E 177 Current transformer supervision 179 Voltage transformer supervision 180 Circuit breaker condition monitoring 181 Energy 188 System clock and synchronization 191 4 2015 Schneider Electric All rights reserved
125. Obj6 Obj1 Breaker object in use CB1 Obj1 Obj6 Obj1 Breaker 1 object CB2 Obj1 Obj6 Breaker 2 object AutoCBSel On Off off Enabling disabling the auto CB selection CB2Sel None any digital The digital input for selecting the CB2 input virtual input or virtual output ARreq On Off Off AR request event ShotS On Off Off AR shot start event ARlock On Off Off AR locked event CritAr On Off Off AR critical signal event ARrun On Off Off AR running event FinTrp On Off Off AR final trip event RegEnd On Off Off AR end of request event ShtEnd On Off Off AR end of shot event CriEnd On Off Off AR end of critical signal event ARUnI On Off Off AR release event ARStop On Off Off AR stopped event FTrEnd On Off Off AR final trip ready event ARon Off Off AR enabled event ARoff On Off Off AR disabled event 250 2015 Schneider Electric All rights reserved 63230 218 205 Section 8 Control functions Auto reclose function 79 Parameter Value Unit Default Description CRITri On Off On AR critical final trip on event AR1 Tri On Off On AR AR1 final trip on event AR2Tri On Off On AR ARe final trip on event Shot settings DeadT 0 02 300 00 S 5 00 The dead time setting for this shot This is a common setting for all the AR lines in this shot AR1 On Off Off Indicates if this AR signal starts this shot AR2 On O
126. PAM Va X6 4 11 EN X65ll 0 X6 6 L2 X6702 option block diagram Figure 11 15 Block diagram of optional arc detection module Block diagram of optional 0119 0120 Options X6 1 DI19 DI X6 2 DI19 X6 3 DI 20 X6 4 DI 20 X6 5 X6 6 L gt X6 7 L Figure 11 16 Block diagram of optional DI19 DI20 module with one arc channel 328 2015 Schneider Electric All rights reserved 63230 218 205 Section 11 Connections Block optional diagrams Fu OQ c e rco ererrrrrrhY OD 0 freer A3 13 X3 14 X3 15 X3 12 XT 17 X7 18 XT 15 7 16 oor ot 000000 600000 8500000 8 ort st TW COO KATO Oe eS ee MOM P PII Ie eer XXX XXX 26 OK 0 2 amp 0 OR 6 DEO NOTE For the phases L1 A L2 B and L3 C Figure 11 17 Connection example of VAMP 255 The voltage measurement mode is set to 2LL Up 63230 218 205 2015 Schneider Electric All rights reserved 329 Block diagrams of option modules Section 11 Connections T T i 2 0 2 amp LDOPIZPPELTM dius us SCS 9 SIS OR RR KR 6 NN AAW d x x o XX X X XX X ae a a a AX X AM ACC MM M MM M M x E m m T gt d gt lt pd X lt Qoo Doo XXX EQUXX eor rrr oI T_T
127. R Parameter Value Table 5 34 Recorded values of the over amp under frequency stages 8 latest faults f gt lt f gt gt lt lt f f Description yyyy mm dd Time stamp of the recording date hh mm ss ms Time stamp time of day Detected faulty frequency Elapsed time of the operating time setting 100 trip Active setting group during fault Rate of change of frequency ROCOF 81R 63230 218 204 Rate of change of frequency ROCOF or df dt function is used for fast load shedding to speed up operation time in over and under frequency situations and to detect loss of grid For example a centralized dedicated load shedding relay can be omitted and replaced with distributed load shedding if all outgoing feeders are equipped with VAMP devices A special application for ROCOF is to detect loss of grid loss of mains islanding The more the remaining load differs from the load before the loss of grid the better the ROCOF function detects the situation Frequency behavior during load switching Load switching and fault situations may generate change in frequency A load drop may increase the frequency and increasing load may decrease the frequency at least for a while The frequency may also oscillate after the initial change After a while the control system of any local generator may drive the frequency back to the original value However in case of a heavy short circuit fault
128. Several events of an increasing fault is disabled CIrDly 0 65535 Duration for active alarm status FItL1 FIt2 FItL3 and OCt Set Set An editable parameter password needed Used with IEC 60870 105 103 communication protocol The alarm screen will show the latest if it s the biggest registered fault current Not used with Spabus because Spabus masters usually don t like to have unpaired On Off events Used with SPA bus protocol because most SPA bus masters do need an off event for each corresponding on event 63230 218 205 2015 Schneider Electric All rights reserved 201 Self supervision oection 6 Supporting functions oelf supervision Diagnostics 202 The functions of the microcontroller and the associated circuitry as well as the program execution are supervised by means of a separate watchdog circuit Besides supervising the relay the watchdog circuit attempts to restart the micro controller in an inoperable situation If the micro controller does not restart the watchdog issues a self supervision signal indicating a permanent internal condition When the watchdog circuit detects a permanent internal condition it always blocks any control of other output relays except for the self supervision output relay In addition the internal supply voltages are supervised Should the auxiliary supply of the IED disappear an indication is automatically given because the IED status inoperative SF output
129. T Polarity of all output relays can be changed in VAMPSET or from Local display Table 8 1 Parameters of output relays Parameter Value Unit Description Note T1 Tn 0 Status of trip output relay F 1 A1 A5 0 Status of signal output relay F 1 SF 0 Status of the SF relay F 1 In VAMPSET it is called as Service status output Force On Force flag for output relay forcing for test Set purposes This is a common flag for all Off output relays and detection stage status Any forced relay s and this flag are automatically reset by a 5 minute timeout REMOTE PULSES 1 5 0 00 99 98 S Pulse length for direct output relay control Set via communications protocols Or 99 99 s Infinite Release by writing O 99 99 to the direct control parameter NAMES for OUTPUT RELAYS editable with VAMPSET only Description String of max 32 characters Names for DO on VAMPSET screens Set Default is Trip relay n or Signal relay n Set An editable parameter password needed F Editable when force flag is on 63230 218 205 2015 Schneider Electric All rights reserved 235 Digital inputs Digital inputs 236 Section 8 Control functions HAZARD OF ELECTRIC SHOCK EXPLOSION OR ARC FLASH Connect only dry potential free contacts to digital inputs 016 Failure to follow these instructions will result in death serious injury or equipment damage The
130. The voltage measurement is set 2LL U Directional ground fault stages are not available without the polarizing Ug voltage 63230 218 205 2015 Schneider Electric All rights reserved 395 Block diagrams of option modules Section 12 Technical data Section 12 Technical data Connections Torque for Terminal Connections For panel mounted or semi flush where the terminals are fixed in the relay the torque is 10 6 in lb 1 2 Nem For detachable terminals the torque is 4 4 5 3 in Ib 0 5 0 6 Nem T max 1 2Nem 10 6lb in _ T max 0 5 0 63 4 4 5 3 b in JA t AA L p c al 4 at ae 2015 Schneider Electric All rights reserved 336 63230 218 205 Section 12 Technical data max 0 5 0 6Nem 4 4 5 3 Ib in 2015 Schneider Electric All rights reserved 63230 218 205 Connections 337 Block diagrams of option modules Measuring circuits 338 Section 12 Technical data Rated phase current Current measuring range Thermal withstand Burden 5 A configurable for CT secondaries 1 10 A 0 250A 20 A continuously 100 A for 10 s 500 A for 1 s 0 2 VA loe input option C Rated residual current optional Current measuring range Thermal withstand Burden See Section 14 Order information 5 A configurable for CT secondaries 1 10 A 0 50A 20 A continuously
131. This is not regarded as an under voltage situation The voltage Vitmin is above the block limit but below the pick up level This is an undervoltage situation Voltage is OK because it is above the pick up limit This is an under voltage situation Voltage is OK Three independent stages Section 5 Protection functions This is an under voltage situation The voltage Vitmin is under block limit and this is not regarded as an under voltage situation This is an under voltage situation Voltage is OK Same as G Voltage is OK There are three separately adjustable stages V V and V lt lt lt All these stages can be configured for definite time DT operation characteristic Setting groups There are two settings groups available for all stages Switching between setting groups can be controlled by digital inputs virtual inputs mimic display communication logic and manually 2014 Schneider Electric rights reserved 120 63230 218 204 oection 5 Protection functions Undervoltage protection U 27 Table 5 29 Parameters of the under voltage stages V V V Parameter Value Unit Description Note Status Current status of the stage Blocked Start F Trip SCntr Cumulative start counter C TCntr Cumulative trip counter C SetGrp 1or2 Active setting group Set SGrpDI Digital signal to select the active setti
132. Trip on event T Off Enabled Disabled Enabled Trip off event Table 5 41 Measured and recorded values of magnetishing inrush blocking 68F2 Parameter Value Unit Description Measured values IL1H2 2 harmonic of IL1 proportional to the fundamental value of IL1 IL2H2 2 harmonic of IL2 adde 2 harmonic of IL3 Recorded values Fit The max fault value EDly Elapsed time as compared to the set operating time 100 tripping 11 12 and L3 are IEC phase names For NEMA the phases are as follows L1 A L2 B and L3 C 138 2015 Schneider Electric All rights reserved 63230 218 205 section 5 Protection functions Transformer over exicitation gt 68F5 Transformer over exicitation 1 5 gt 68F5 Parameter Overexiting for example a transformer creates odd harmonics This over exicitation stage can be used to detect overexcitation This stage can also be used to block some other stages The ratio between the over exicitation component and the fundamental frequency component is measured on all the phase currents When the ratio in any phase exceeds the setting value the stage gives a start signal After a settable delay the stage gives a trip signal The trip delay of the stages to be blocked must be more than 60 ms to help ensure a proper blocking Table 5 42 Setting parameters of over exicitation blocking 68F5 Value Default Description If5 10 100 10 Setting value If2 Ifund
133. Uy U42 Ui Up X1 13 14 Ujoy Uc X1 17 18 Uo U42 Number of synchrocheck stages 1 1 2 Availability of Ug and directional l Yes stages Power measurement 1 phase power symmetrical loads 3 phase power unsymmetrical loads 1 phase power symmetrical loads The following application examples show the correct connection of the voltage inputs In the Figure 5 41 and Figure 5 42 the applications require only one stage Voltage measuring modes 1LL Up LLy and 2LL LLy Two stages are needed for the application presented in Figure 5 43 Voltage measuring mode is LL LLy LLz 2014 Schneider Electric rights reserved 63230 218 204 Section 5 Protection functions Synchrocheck 25 Figure 5 41 One synchrocheck stage needed with 1LL Ug LLy mode 2014 Schneider Electric All rights reserved 63230 218 204 135 Magnetishing inrush l gt 68F2 Section 5 Protection functions 2 OrNe exor oE CO 0O ru 0D P CO aoaoaaaoaaoaaaaS8aoaoaaaoa8 E ni e IUD TANE HET Ts SESE SK D 5505456505058 5454565505054 Figure 5 42 One synchrocheck stage needed with 2LL LLy mode 136 2015 Schneider Electric All rights reserved 63230 218 205 Section 5 Protection functions Transformer over exicitation l 5 68F5 e T Y e e X X Infeed 1 Infeed 2
134. VAMP 255 and 230 Feeder and Motor Manager User manual 63230 218 205 04 2015 Retain for future use Hazard Categories and Special Symbols Read these instructions carefully and look at the equipment to become familiar with the device before trying to install operate service or maintain it The following special messages may appear throughout this bulletin or on the equipment to warn of potential hazards or to call attention to information that clarifies or simplifies a procedure The addition of either symbol to a Danger or Warning safety label indicates that an electrical hazard exists which will result in personal injury if the instructions are not followed This is the safety alert symbol It is used to alert you to potential personal injury hazards Obey all safety messages that follow this symbol to avoid possible injury or death A DANGER DANGER indicates an imminently hazardous situation which if not avoided will result in death or serious injury A WARNING WARNING indicates a hazardous situation which if not avoided could result in death or serious injury A CAUTION CAUTION indicates a hazardous situation which if not avoided could result in minor or moderate injury NOTICE NOTICE is used to address practices not related to physical injury The safety alert symbol is not used with this signal word Electrical equipment should be installed operated serviced and maintained onl
135. Voltage measurement modes 15 17 Uc See the section Voltage measurement modes 19 No Symbol Description 2 IL1 S2 Phase current L1 S2 4 IL2 S2 Phase current L2 S2 6 IL3 S2 Phase current L3 S2 8 lo1 1A S2 Residual current lo1 S2 10 lo2 5A S2 Residual current lo2 S2 12 Ua See the section Voltage measurement modes 14 Ub See the section Voltage measurement modes 16 18 Uc See the section Voltage measurement modes 20 11 12 and L3 are IEC phase names For NEMA the phases are as follows L1 A L2 B and L3 C 63230 218 205 2015 Schneider Electric All rights reserved 299 Rear panel Terminal X2 VO VP 6 300 O N OO A CO 10 11 12 13 14 15 16 7 18 5 5 4 4 2 A2 NC A2 NO SF COM SF NC SF NO 2015 Schneider Electric All rights reserved Section 11 Connections Description Alarm relay 5 Alarm relay 5 Alarm relay 4 Alarm relay 4 Alarm relay 3 common connector Alarm relay 3 normal closed connector Alarm relay 3 normal open connector Alarm relay 2 common connector Alarm relay 2 normal closed connector Alarm relay 2 normal open connector Detected internal fault relay common connector Detected internal fault relay normal closed connector Detected internal fault relay normal open connector 63230 218 205 Section 11 C
136. When using line to line voltages any zero sequence voltage can not be calculated The zero sequence or residual measurement signals connected to the device are Uo and 3lg However usually the name lo is used instead of the correct name L1 L2 and L3 are IEC phase names For NEMA the phases are as follows L12A L2 B and L3 C Also U V Examples 1 oingle phase injection Un 100 V Voltage measurement mode is 2LL Ug Injection Ua 100 V Up 0 l 21100 0 0 1 100 0 33 dod au al o T boz os U 33 U 33 96 0 0 100 When using a single phase test device the relative unbalance U U will always be 100 9 Two phase injection with adjustable phase angle 100 V Voltage measurement mode is 2LL Ug Injection Un U42 100 V 70 Up U23 100 43 V 7 150 57 7 V z 150 0 1 a 10020 100 170 1 J34 90 U 3 1 a 100 3 150 3 140 174 32 30 _100 2 nd _ 2015 Schneider Electric All rights reserved 63230 218 205 oection 7 Measurement functions Symmetric components 3 1 432430 19 2 7 30 U 38 5 96 Us 19 2 96 U U 50 Figure 7 4 shows a geometric solution The input values have been scaled with 43 100 to make the calculation easier 2015 Schneider Electric All rights reserved 63230 218 205 2253 Symmetric components Injected line to line voltages 224 Se
137. a Vector between the voltage and the ground la Vector between the current and the ground k Ground factor k needs to be set by user 3lg Residual current calculated from phase currents localo Ground factor k is calculated with following formula Ko 401 411 3 441 Zo Zero sequence line imedance Zi Positive sequence line impedance 2015 Schneider Electric All rights reserved 207 Feeder fault locator oection 6 Supporting functions Triggering of the fault reactance calculation happens when Pick up setting value is exceeded if user wants both Pick up setting and Triggering digital input terms are fulfilled When used Triggering digital input can be either digital or virtual input Table 6 22 Setting parameters of feeder fault locator Parameter Value Unit Default Description Pick up setting 0 10 5 00 xIn 1 2 Current limit for triggering Triggering digital input Trigger mode triggering based on sudden increase of phase current otherwise sudden 011 0118 increase of phase current VH V14 DIx VIxX VOx NIx POCx VO1 VO6 NI1 NI64 POC1 POC16 Line reactance 0 010 10 000 Ohms km 0 491 Line reactance of the line This is used only to convert the fault reactance to feet Ground facto 0 000 10 000 0 678 Calculated ground factor from line specifications Ground
138. able can be displayed on the main view next to the single line diagram Up to six measurements can be shown Value Menu Submenu Description P P POWER Active power kW Q P POWER Reactive power kvar S P POWER Apparent power kVA P POWER Active power angle P F P POWER Power factor f P POWER Frequency Hz Pda P 15 MIN POWER Active power kW Qda P 15 MIN POWER Reactive power kvar Sda P 15 MIN POWER Apparent power kVA Pfda P 15 MIN POWER Power factor fda P 15 MIN POWER Frequency Hz PL1 P POWER PHASE 1 Active power of phase A kW PL2 P POWER PHASE 1 Active power of phase B kW PL3 P POWER PHASE 1 Active power of phase C kW QL1 P POWER PHASE 1 Reactive power of phase A kvar QL2 P POWER PHASE 1 Reactive power of phase B kvar QL3 P POWER PHASE 1 Reactive power of phase C kvar SL1 P POWER PHASE 2 Apparent power of phase A kVA SL2 P POWER PHASE 2 Apparent power of phase B kVA SL3 P POWER PHASE 2 Apparent power of phase C kVA PF L1 P POWER PHASE2 Power factor of phase PF L2 P POWER PHASE 2 Power factor of phase PF L3 P POWER PHASE 2 Power factor of phase C COS P COS amp TAN Cosine phi tan P COS amp TAN Tangent phi cosL 1 P COS amp TAN Cosine phi of phase A cosL2 P COS amp TAN Cosine phi of phase cosL3 P COS amp TAN Cosine phi of ph
139. actance per kilometre of the line The algorithm functions in the following order 1 The needed measurements phase currents and voltages are continuously available 2 The fault distance calculation can be triggered in two ways by switching ON or OFF the secondary resistor that is by using a digital input or the calculation can be triggered if there is a change in ground fault or negative sequence current 3 The fault phase is identified by that the voltage of the faulted phase is decreased at least by half 4 The fault distance is calculated by dividing the change of the voltage by the change of the negative sequence current 5 Only the imaginary part is used so then the reactance is solved Table 6 24 Setting parameters of ground fault location EFDi Value Default Description EFMode Normal Reverse Normal Normal The resistor is switched ON during a fault Reverse The resistor is switched OFF during a fault TrigIn lo l2 DI1 Triggering input lo ground fault current will trigger the function 12 negative phase sequence current will trigger the function DI1 the function is triggered by activating the digital input 1 UoTrig 1 80 Uon Trigger level for Uo Itrig 10 800 96 In Trigger level for current Event On Off Event mask Table 6 25 Measured and recorded values of ground fault location EFDi Parameter
140. acts as a centralized unit for a point to multiple point connection Note Daisy chain connection of IRIG B signal inputs in multiple relays must be avoided 2015 Schneider Electric All rights reserved 195 System clock and synchronization Section 6 Supporting functions GPS Clock IRIG B signal from clock IRIG B Distribution Module VAMP50 VAMP300 VAMP200 VAMP Relay Series with IRIG B synchronization capability Recommended wiring shielded cable of twisted pair or coaxialtype with a maximum length of 10 meters The recommended cable must be shielded and either of coaxial or twisted pair type Its length should not exceed a maximum of 10 meters Deviation The time deviation means how much system clock time differs from sync source time Time deviation is calculated after receiving new sync message The filtered deviation means how much the system clock was really adjusted Filtering takes care of small deviation in sync messages Auto lag lead The device synchronizes to the sync source meaning it starts automatically leading or lagging to stay in perfect sync with the master The learning process takes few days 196 2015 Schneider Electric All rights reserved 63230 218 205 Section 6 Supporting functions Running hour counter Running hour counter This function calculates the total active time of the selected digital input virtual I O or output matrix output signal The resolution is ten seconds
141. ails see Modbus TCP and Modbus RTU 2015 Schneider Electric All rights reserved 47 Configuration and parameter setting oection 2 Local panel user interface External I O protocol This is a Modbus master protocol to communicate with the extension modules connected to the extension port Only one instance of this protocol is possible e Bit rate bit s Default is 9600 e Parity Parity Default is Even For details see External I O Modbus RTU master SPA bus Several instances of this protocol are possible e SPA bus address for this device Addr This address has to be unique within the system Bit rate bit s Default is 9600 e Event numbering style Emode Default is Channel For details see SPA bus IEC 60870 5 103 Only one instance of this protocol is possible e Address for this device Addr This address has to be unique within the system e Bitrate bit s Default is 9600 e Minimum measurement response interval MeasInt e ASDU6 response time mode SyncRe For details see IEC 60870 5 103 IEC 103 Disturbance recordings For details see Table 9 11 48 2015 Schneider Electric All rights reserved 63230 218 205 oection 2 Local panel user interface Configuration and parameter setting 63230 218 205 Profibus Only one instance of this protocol is possible e Mode e Bitrate bit s Use 2400 bps This parameter is the bit rate between the main CPU and t
142. al of the relay is 625 us at 50 Hz 32 samples cycle The lg current spikes can be quite short compared to this sampling interval Fortunately the current spikes in cable networks are high and while the anti alias filter of the relay attenuates the amplitude the filter also makes the pulses wider Thus when the current pulses are high enough it is possible to detect pulses which have duration of less than twenty per cent of the sampling interval Although the measured amplitude can be only a fraction of the actual peak amplitude it doesn t disturb the direction detection because the algorithm is more sensitive to the sign and timing of the lg transient than sensitive to the absolute amplitude of the transient Thus a fixed value is used as a pick up level for the lo Coordination with Vo back up protection Especially in a fully compensated situation the zero sequence voltage back up protection stage Vo for the bus may not release between consecutive faults and the Vo might finally do an unselective trip if the intermittent transient stage loj r doesn t operate fast enough The actual operation time of the lgjyr stage is very dependent the behavior of the fault and the intermittent time setting To make the co ordination between Vo and lgjyr more simple the start signal of the transient stage lor in an outgoing feeder can be used to block the Vo backup protection Co ordination with the normal directional ground fault
143. ardware is required There is a free of charge PC program called VAMPSET available for configuration and setting of VAMP relays Please download the latest VAMPSET exe from www schneider electric com For more information about the VAMPSET software please refer to the user s manual doc no 63230 218 207 2015 Schneider Electric All rights reserved 51 Principles of numerical protection techniques section 4 Introduction Section 4 Introduction The VAMP device a digital micro processor based relay includes all the essential protection functions needed to protect feeders and motors in distribution networks of utilities industry power plants and offshore applications Further the device includes several programmable functions such as arc detection option thermal trip circuit Supervision and circuit breaker protection and communication protocols for various protection and communication situations 400kV 200 kV pibe ER 110 kV network Transmission d substations row plants Q Distribution 3 Remote Control Interface substation CB Protection relay fm UE _ lt Circuit Protection I O breaker relay Remote control e SS 20 kV overheadline E M 20 kV cable Secondary substation a network V Distribution transformer distribution transformer 230 400V 230 400V VAMP200 series sovelluskuva Figure 4 1 Application of the feeder and motor protection de
144. ase current of fundamental frequency Nominal current of the motor Pick up setting lo in pu The maximum allowed degree of unbalance Example 15s lo 22 9 96 2 0 229 X IMOT Ko 9 9o 0 05 XI MoT 15 300 4 0 229 0 05 END id y The operation time in this example will be five minutes More stages definite time delay only If more than one definite time delay stage is needed for current unbalance protection the freely programmable stages can be used section Programmable stages 99 2015 Schneider Electric All rights reserved 63230 218 205 Section 5 Protection functions Current unbalance stage I2 gt 46 in motor mode Setting groups There are two settings groups available Switching between setting groups can be controlled by digital inputs virtual inputs communication logic and manually CurrentUnbalanceChar 2000 r7 1000 Operation time s L 0 20 40 60 80 100 Negative sequence current I 26 Figure 5 11 Inverse operation delay of current unbalance stage l gt The longest delay is limited to 1000 seconds 16min 40s 2015 Schneider Electric All rights reserved 63230 218 205 11 Current unbalance stage l5 46 in motor mode Section 5 Protection functions Table 5 9 Parameters of the current unbalance stage l gt 46 in motor mode
145. ase C Iseq P PHASE SEQUENCIES Actual current phase sequency OK Reverse Useq P PHASE SEQUENCIES Actual voltage phase sequency OK Reverse P PHASE SEQUENCIES lo Vo angle lo2 P PHASE SEQUENCIES lo2 Vo angle 9 fAdop P PHASE SEQUENCIES Adopted frequency Hz E E ENERGY Exported energy MWh Eq E ENERGY Exported reactive energy Mvar E E ENERGY Imported energy MWh 32 2015 Schneider Electric All rights reserved 63230 218 205 oection 2 Local panel user interface Operating measures Value Menu Submenu Description Eq E ENERGY Imported reactive energy Mvar E DECIMAL COUNT Decimals of exported energy Eq nn E DECIMAL COUNT Decimals of reactive energy E nn E DECIMAL COUNT Decimals of imported energy Ewrap E DECIMAL COUNT Energy control E E E PULSE SIZES Pulse size of exported energy kWh Eqt E E PULSE SIZES Pulse size of exported reactive energy kvar E E E PULSE SIZES Pulse size of imported energy kWh Eq E E PULSE SIZES Pulse duration of imported reactive energy ms E E E PULSE DURATION Pulse duration of exported energy ms Eq E E PULSE DURATION Pulse duration of exported reactive energy ms E E E PULSE DURATION Pulse duration of imported energy ms Eq E E PULSE DURATION Pulse duration of imported reactive energy ms
146. ation characteristic Configurable release time The V stage has a settable release time which enables detecting intermittent faults This means that the time counter of the protection function does not reset immediately after the fault is cleared but resets after the release time has elapsed If the fault appears again before the release time time has elapsed the delay counter continues from the previous value This means that the function will eventually trip if faults are occurring often enough Configurable hysteresis The dead band is 3 96 by default It means that an overvoltage fault is regarded as a fault until the voltage drops below 97 of the pick up setting In a sensitive alarm application a smaller hysteresis is needed For example if the pick up setting is about only 2 above the normal voltage level hysteresis must be less than 2 9e Otherwise the stage will not release after fault Setting groups There are two settings groups available for each stage Switching between setting groups can be controlled by digital inputs virtual inputs communication logic and manually Figure 5 33 shows the functional block diagram of the overvoltage function stages V V gt gt and V gt gt gt 2015 Schneider Electric All rights reserved 115 5 19 Overvoltage protection U gt 59 Section 5 Protection functions Um2 Um3 Figure 5 33 Block diagram of the three phase overvoltage stages V V gt gt and
147. axle eden 235 DIGIEal IDDULS 236 Virtual inputs and outputs cessie 239 CONDIT ATI IUD asa 240 BIOC KINO MAUX 241 Colhtiollable oDB G66lS tis m eb etes 242 Local Remote selection 243 CONTON WI DI seissen 244 Auto reclose function 79 244 LOGICIUNCUONS MEER 254 9 ComiHlhli dtloRt 257 GOMMMUNMICATION otio dioi 257 OM AA EN 259 Cor Pc 261 Extension port X4 o DR ELE 263 DOPL acces Gavia irrita de ixi Ede mud 264 Communication protocols 266 PG comtnilhi6allOl susc iesus Cn ie tout 266 Modbus TCP and Modbus RTU 267 268 63230 218 205 2015 Schneider Electric All rights reserved 5 Section 10 Application Section 11 Connections Section 12 Technical data Table of Contents SPASDUS crine n ami detinent im esi Unum m ON E ns 270 IEG 60970 5 109 sesso att aout dates e te Seba EEUU 271 e M 273 IEG et ou an 274 External I O Modbus RTU master 276 276
148. cannot be used because they share the same common terminal with DI13 294 2015 Schneider Electric All rights reserved 63230 218 205 Section 11 Connections Rear panel DIGITAL INPUTS Figure 10 15 An example of digital input configuration for trip circuit supervision with two dry digital inputs DIZ and 0113 Figure 10 16 An example of logic configuration for trip circuit supervision with two ary digital inputs DI1 and DI2 Figure 10 17 An example of output matrix configuration for trip circuit supervision with two digital inputs 63230 218 205 2015 Schneider Electric All rights reserved 295 Rear panel Section 11 Connections Section 11 Connections A DANGER HAZARD OF ELECTRIC SHOCK EXPLOSION OR ARC FLASH e Apply appropriate personal protective equipment PPE and follow safe electrical work practices See NFPA 70E NOM 029 STPS 2011 and CSA Z462 e This unit must be installed and serviced only by qualified electrical personnel Turn off all power supplying this unit before working on or inside the unit e Always use a properly rated voltage sensing device to confirm that the power is off A live current transformer secondary circuit must not be opened without turning off the primary side of the transformer and short circuiting transformer secondary circuits first Replace all devices doors and covers before turning on power to this unit Failure to follow these instructions will
149. ce U 2 3 U aU Injected line to neutral voltages U 0 1 0 WU Negative sequence J120 aU ad U aUi 5 173 Figure 7 5 Example of symmetric component calculation using line to neutral voltages Unscaling the geometric results gives U 100 43 x 2 3 38 5 U 100 43 1 3 19 2 96 0 0 1 3 2 3 50 63230 218 205 2015 Schneider Electric All rights reserved 225 Primary secondary and per unit scaling oection 7 Measurement functions NOTE Primary secondary and per unit scaling Many measurement values are shown as primary values although the relay is connected to secondary signals Some measurement values are shown as relative values per unit or per cent Almost all pick up setting values are using relative scaling The scaling is done using the given CT VT in feeder mode and furthermore motor name plate values in motor mode The following scaling equations are useful when doing secondary testing Current scaling The rated value of the device s current input for example 5 A or 1A does not have any effect in the scaling equations but it defines the measurement range and the maximum allowed continuous current oee the section Measuring circuits for details Primary and secondary scaling Current scaling secondary primary CT I I PRI PRI SEC CT uc primary secondary 1 PEE SEC PRI CT 226 For residual current to input I
150. cg iic nm 277 FTP SONET UU M 2 8 DRE 279 Substation feeder protection 279 Industrial feeder protection 280 Parallel liie 281 RING network protection 283 TEID CIFCUHE SUDEIVISION cand bam oci edt 204 Trip circuit supervision with one digital input 204 Trip circuit Supervision with two digital inputs 292 296 Meal DANG a au ides 296 DM DE 296 ZOU 296 AUM VONAGE Bodo E 311 Serial communication connection 311 Front panel connector 311 Rear panel connector X5 REMOTE 312 X4 rear panel connector local RS232 and extension RS485 ports 317 Optional two channel arc protection Card 317 Optional digital 1 0 card DI19 DI20 318 External option modules 318 External LED module VAM 16D 318 External input output Module 318 Block optional diagrams 324 VAMP 250 P dees 324 VAMP 28
151. cleared to zero F Editable when force flag is on For details of setting ranges see Protection functions 64 2015 Schneider Electric All rights reserved 63230 218 205 Section 5 Protection functions Overcurrent protection I 50 51 Table 5 2 Parameters of the overcurrent stages I gt gt gt 50 51 Parameter Value Unit Description Note Status Current status of the stage Blocked Start F Trip F Cumulative start counter C Cumulative trip counter C Active setting group Set Digital signal to select the active setting group Set None Digital input Virtual input LED indicator signal Virtual output Force flag for status forcing for test purposes This is acommon Set flag for all stages and output relays Automatically reset by a 5 minute timeout ILmax The supervised value Max of IA IB and IC Pick up value scaled I gt gt gt gt gt xlmode to primary value I gt gt gt gt gt P Pick up setting Set t gt gt t gt gt gt Definite operation time Set Set An editable parameter password needed C Can be cleared to zero F Editable when force flag is on For details of setting ranges see Protection functions 11 12 and L3 are IEC phase names For NEMA the phases are as follows L1 A L2 B and L3 C 63230 218 205 2015 Schneider Electric All rights reserved 65 Overcurrent protection I gt 50 51 o
152. co e SESS ICICI 9 DEDEDE DE DEDEDE SEDC DE DE DEDEDE gt H CH ilh 2 dE NOTE For the phases L1 A L2 B and L3 C Figure 11 20 Connection example of VAMP 255 as a motor detection device The voltage measurement mode is set 2LL4 Ug 332 2015 Schneider Electric All rights reserved 63230 218 205 Section 11 Connections Block optional diagrams On O c OC t roo ONAN ANA on O rr 299999999 99 9 999 X3 15 A413 X3 14 NOTE For the phases L1 A L2 B and L3 C Figure 11 21 Connection example of VAMP 230 The voltage measurement mode is set to 2LL Up 63230 218 205 2015 Schneider Electric All rights reserved 333 Block diagrams of option modules Section 11 Connections X3 15 X3 13 X3 12 X3 10 X2 13 X2 14 X2 15 X2 10 X2 12 X2 16 X2 17 X2 18 N E lt x ON co lt T ON JI I NOTE For the phases L1 A L2 B and L3 C Figure 11 22 Connection example of VAMP 230 without an open delta voltage transformer The device is calculating the zero sequence voltage The voltage measurement mode is set 3LN 394 2015 Schneider Electric All rights reserved 63230 218 205 Section 11 Connections Connection examples T WN C2 _ J NOTE For the phases L1 A L2 B and L3 C Figure 11 23 Connection example of VAMP 230 with V connected voltage transformers
153. conds INFO push button for viewing additional information for entering the password view and for adjusting the LCD contrast ENTER push button for activating or confirming a function arrow UP navigation push button for moving up in the menu or increasing a numerical value DOWN navigation push button for moving down in the menu or decreasing a numerical value arrow LEFT navigation push button for moving backwards in a parallel menu or selecting a digit in a numerical value arrow RIGHT navigation push button for moving forwards in a parallel menu or selecting a digit in a numerical value 2015 Schneider Electric All rights reserved 15 Relay front panel LED indicators Section 2 Local panel user interface The relay is provided with eight LED indicators LED indicator Meaning Measure Remarks Power LED lit The auxiliary power has been switched on Normal operation state Error LED lit Internal detected fault operates in The relay attempts to reboot RE parallel with the self supervision output BOOT If the error LED remains lit call relay for maintenance Com LED lit or flashing The serial bus is in use and transferring Normal operation state information Alarm LED lit One or several signals of the output relay The LED is not lit when the signal matrix have been assigned to output LED that caused output Alarm Contact 1 A LA and the output has been activated A1 to
154. configurable GOOSE publisher data sets configurable filters for GOOSE subscriber inputs GOOSE inputs available in the application logic matrix Additional information can be obtained from the separate documents IEC 61850 conformance statement pdf IEC 61850 Protocol data pdf and Configuration of IEC 61850 interface pdf 2015 Schneider Electric All rights reserved 63230 218 205 oection 9 Communication Communication protocols Header Consuming EtherNet IP The device supports communication using EtherNet IP protocol which is a part of CIP Common Industrial Protocol family EtherNet IP protocol is available with the optional built in Ethernet port The protocol can be used to read write data from the device using request response communication or via cyclic messages transporting data assigned to assemblies sets of data EtherNet IP main features e Static data model 2 standard objects Overload and Control oupervisor 2 private objects one for digital data and one for analog data and 4 configuration objects for protection functions configuration e Two configurable assemblies one producing and one consuming with the maximum capacity of 128 bytes each EDS file that can be fed to any client supporting EDS files can be generated at any time all changes to EtherNet IP configuration see configuration parameters in Table 9 14 or to assemblies conte
155. ction 7 Measurement functions FortescueEx2 Positive sequence U 2 3 Negative sequence aU U aU Figure 7 4 Example of symmetric component calculation using line to line voltages Unscaling the geometric results gives U 100 43 x 2 3 38 5 96 Us 100 43 x 1 3 19 2 0 0 1 3 2 3 50 Two phase injection with adjustable phase angle 100 V Voltage measurement mode is 3LN Injection Ua UL 100 43 V 40 57 7 V Z0 Up 100 43 V 7 120 57 7 V 7 120 0 This is actually identical case with example 2 because the resulting line to line voltages U45 4 2 100 V 430 and 100 v3 V 7 120 are the same as in example 2 The only difference is a 30 phase angle difference but without any absolute angle reference this phase angle difference is not seen by the device 2015 Schneider Electric All rights reserved 63230 218 205 oection 7 Measurement functions Symmetric components 100 ze 70 AT 3 100 0 1002 120 2 EE U a a 120 3 10020 10020 ra a i y 0 1002 60 19 27 60 aor in eae TA Y 1007602 19 2 60 Ug 19 2 96 38 5 96 Us 19 2 96 05 0 50 Figure 7 5 shows a graphical solution The input values have been scaled with 43 100 to make the calculation easier FortescueEx3 Positive sequen
156. ction functions Synchrocheck 25 Table 5 37 Setting parameters of synchrocheck stages SyC1 SyC2 25 Parameter Values Unit Default Description Side U12 U12y U12 U12z Voltage selection The stage 1 has fixed voltages U12 U12y U12 U12z U12y U12z CBObj Obj1 Obj6 Obj1 The selected object for CB control The synchrocheck closing command will use the closing command of the selected object CBObj2 Obj1 Obj6 Obj2 The selected object for CB control The synchrocheck closing command will use the closing command of the selected object ObjSel Digital inputs Input for selecting between CBObj1 and CBObj2 When active CBObj2 is in use omode Async Sync Off Sync Synchrocheck mode Off only voltage check Async the function checks dU df and dangle Furthermore the frequency slip df determines the remaining time for closing This time must be longer than CB time Sync mode Synchronization is tried to make exactly when angle difference is zero In this mode df setting should be small enough 0 3Hz Umode Voltage check mode DD The first letter refers to the reference voltage and the second letter refers to the comparis DL on voltage LD D means that the side must be dead when losi Th low th DD DL closing dead vo tage below the dead voltage limit setting DDILD L means that the side must be live
157. ctions Below is presented an application example where the fault location algorithm is used at the incoming side Observe the following things while commissioning the relay PRE FAULT TIME MORE THAN 2 FAULT TIME WITH THE BREAKER OPERATION TIME INCLUDED HAS TO TO BE 0 08 1 SECONDS CYCLES SECONDS Lon P IN CASE THE DIGITAL INPUT IS USED TOGETHER WITH THE CURRENT CHANGE THE INPUT SIGNAL HAS TO BE ACTIVATED AT LEAST 0 5 SECONDS AFTER THE FAULT OCCURS Below is an application example where the fault location algorithm is used at the feeder side Observe the following things while commissioning the relay 206 CPRE FAULT TIME Voltages y A i i 4 V i 1 1 i I d i 1 j A ngu i i y j il 1 i it Uu CN NXOY M NON NO PX Y ARN Y Y y FAULT TIME WITH THE BRE ARER POST FAULT MORE THAN 2 OPERATHOS TIME MIU DED HAS TO ONLY FEW IN CASE THE DIGITAL INPUT IS USED TOGETHER WITH THE CURRENT CHANGE THE INPUT SIGNAL HAS TO BE ACTIVATED AT LEAST 0 5 SECONDS AFTER THE FAULT OCCURS 2015 Schneider Electric All rights reserved 63230 218 205 Section 6 Supporting functions Feeder fault locator Feeder fault locator Z
158. ctions are voltage sag and swell monitoring VAMP provides separate monitoring logs for sags and swells The voltage log is trigged if any voltage input either goes under the sag limit V or exceeds the swell limit V gt There are four registers for both sags and swells in the fault log Each register will have start time phase information duration minimum average maximum voltage values of each sag and swell event Furthermore there are total number of sags and swells counters as well as total timers for sags and swells The voltage power quality functions are located under the submenu un us Table 6 5 Setting parameters of sags and swells monitoring Default Description 20 150 110 Setting value of swell limit 10 120 Setting value of sag limit 0 04 1 00 Delay for sag and swell detection On Off Sag on event On Off Sag off event On Off Swell on event On Off Swell off event 63230 218 205 2015 Schneider Electric All rights reserved 175 Voltage sags and swells oection 6 Supporting functions Table 6 6 Recorded values of sags and swells monitoring Parameter Value Unit Description Recorded values Count Cumulative sag counter Total Cumulative sag time counter Count Cumulative swell counter Total Cumulative swell time counter Sag swell logs 1 Date Date of t
159. current phasor U _ Measured voltage phasor corresponding the fundamental frequency voltage of phase L3 I Complex conjugate of the measured phase L3 fundamental 7 frequency current phasor 218 2015 Schneider Electric All rights reserved 63230 218 205 oection 7 Measurement functions Direction of power and current Apparent power active power and reactive power are calculated similarly as with line to line voltages dali P real S imag S i S Direction of power and current Figure 7 2 shows the concept of three phase current direction and sign of cos and power factor PF Figure 7 3 shows the same concepts but on a PQ power plane Forward capacitive power current is leading 1 Reverse inductive power current is leading T i Reverse capacitive power current is Cap ind lagging cosp cos IV Forward inductive power current is lagging Figure 7 2 Quadrants of voltage current phasor plane 4 90 cap ind Forward inductive power current is lagging Il Reverse capacitive power current is lagging IIl Reverse inductive power current is leading IV Forward capacitive power current is leading coso COSH PF PF Figure 7 3 Quadrants of power plane 63230 218 205 2015 Schneider Electric All rights reserved 219 Power calculations 220 Table 7 13 Power quaarants Section 7 Measurement functions
160. d Frequent start protection stage will provide N alarm signal when the second last start has been done and remains active until the maximum amount of motor starts are reached or one hour of time is passed The N motor start inhibit signal activates after starting the motor and remains active a period of time that is defined for parameter Min time between motor starts After the given time has passed inhibit signal returns to inactive state When start counter of stage reaches the value defined for Max motor starts hour N gt motor start inhibit signal activates and remains active until one hour has passed Frequent start protection stage correlation to output contacts is defined in output matrix menu See section Output matrix Figure 5 18 shows an application 2015 Schneider Electric All rights reserved 63230 218 205 Section 5 Protection functions Frequent start protection N gt 66 STOP START VAMP relay Output matnx rE I7 sta rt trip N alam N gt motor start inhibit NStageAppl 40 Figure 5 18 Application for helping prevent starting too frequently using the N stage The signal relay A1 has been configured to normal closed NC in device relays menu and is controlled by N motor start inhibit signal Whenever N motor start inhibit signal becomes active it prevents the circuit breaker from closing Table 5 13 Parameters of the frequent start protection N
161. d user FTP password Set config configurator MAC address 001ADnnnnnnn MAC address VS Port nn IP port for Vampset Set 23 default Msg nnn Message counter Detected error Errors nnn counter Detected timeout counter Tout en 264 2015 Schneider Electric All rights reserved 63230 218 205 Section 9 Communication Communication ports Parameter Value Unit Description Note EthSffEn on off Sniffer port enable Set SniffPort Port2 Sniffer port Set An editable parameter password needed 1 KeepAlive The KeepAlive parameter sets in seconds the time between two keepalive packets that are sent from the IED The setting range for this parameter is between zero 0 and 20 seconds with the exception that zero 0 means actually 120 seconds 2 minutes A keep alive s packet purpose is for the VAMP IED to send a probe packet to a connected client for checking the status of the TCP connection when no other packet is being sent e g client does not poll data from the IED If the keepalive packet is not acknowledged the IED will close the TCP connection Connection must be resumed on the client side Table 9 5 TCP PORT 1st INST Parameter Value Description Protocol Protocol selection for the extension port Set None Command line interface for VAMPSET ModbusTCPs Modbus TCP slave IEC 61850 IEC 61850 protocol Ethernet IP Ethernet IP protocol DNP
162. d by the standard e g the status of the digital inputs and the control of the objects 63230 218 205 2015 Schneider Electric All rights reserved 271 Communication protocols oection 9 Communication The function type and information number used in private range messages is configurable This enables flexible interfacing to different master systems For more information on IEC 60870 5 103 in VAMP devices refer to the IEC103 Interoperability List document Table 9 10 Parameters 1 254 HN 19200 200 10000 Record reading timeout Unit p Sync i ASDU6 response time mode Description Note A unique address within the system Sync Proc Msg Msg Proc Set An editable parameter password needed Table 9 11 Parameters for disturbance record reading Parameter Value ASDU23 Enable record info message S Off On ompls msg 1 25 Record samples in one message 10 10000 Record reading timeout Unit Descrption O une Fault Fault identifier number for IEC 103 Starts trips of all stages Channel read position Fault numbering NEN Total number of faults GridFlts NEN Fault burst indentifier number Time window to classify faults together to the same burst 2015 Schneider Electric All rights reserved 2 2 63230 218 205 oection 9 Communication Communication protocols DNP 3 0 The relay supports communication us
163. d 63230 218 205 Section 13 Construction Vamp 230 ordering code v230 JL JL IL IL IL L Feeder and Motor Manager Nominal phase current nominal DI 19 20 activation voltage 1A 5A 24V 6 1A 5A 110V 7 1A 5A 220V Nominal earth fault current 101 amp 102 A C 1A amp 5A D 02A amp 1A Frequency Hz 7 Standard relay Supply voltage V 40 265Vac de B 18 36Vdc C 40 2605Vac dc 1 x BI BO 2 x Arc sensor D 18 36Vdc 1 x BI BO 2 x Arc sensor E 40 265Vac dc 0119 0120 1 x Arc sensor F 18 36Vdc 0119 0120 1 x Arc sensor ptional hardware None Plastic Plastic serial fibre interface Profibus interface RS 485 interface 4 wire Glass Glass serial fibre interface Rx Plastic Tx Glass serial fibre interface Rx Glass Tx Plastic serial fibre interface RJ 45 10Mbps ethernet interface RJ 45 10Mbps ethernet inc IEC 61850 LC 100 Mbps ethernet fibre interface inc IEC 61850 RJ 45 100Mbps ethernet interface inc IEC 61850 2 x LC 100 Mbps ethernet fibre interface inc 61850 C D E F G H M R S 2 x RJ 45 100 Mbps ethernet interface inc IEC 61850 Analog Outputs amp firmware E None standard firmware F 4pcs standard firmware Ingress protection rating IP30 default IP54 option NOTES 1 DI activation voltage selection applies to DI 7 DI20 only NEMA rating for IP30 NEMA 1 NEMA rating for IP54 NEMA 2 63230 218 205
164. d 91 Directional ground fault protection lg oection 5 Protection functions Set An editable parameter password needed C Can be cleared to zero F Editable when force flag is on For details of setting ranges see section Protection functions L1 L2 and L3 are IEC phase names For NEMA the phases are as follows L1 A L2 B and L3 C Recorded values of the latest eight faults There is detailed information available of the eight latest ground faults Time stamp fault current elapsed delay and setting group Table 5 16 Recorded values of the directional ground fault stages 8 latest faults loo loo 67N Parameter Value Description yyyy mm dd Time stamp of the recording date hh mm ss ms Time stamp time of day Fit pu Maximum ground fault current Resistive part of l only when InUse Res Capacitive part of lg only when InUse Cap EDly Elapsed time of the operating time setting 100 trip Angle Fault angle of lg Ug 0 Uo Max Up voltage during the fault SetGrp 1 Active setting group during fault 2 92 2015 Schneider Electric All rights reserved 63230 218 205 Section 5 Protection functions Directional ground fault protection lg 67N Ground fault protection gt 50N 51N 63230 218 205 The undirectional ground fault protection is to detect ground faults in low impedance grounded networks In high impe
165. d with compare mode under lt This is the limit to start the comparison Signal values under NoCmp are not regarded as fault 63230 218 205 2015 Schneider Electric All rights reserved 141 Programmable stages 99 142 Section 5 Protection functions Table 5 46 Available signals to be supervised by the programmable stages IL1 IL2 IL3 Phase currents lo1 lo2 Residual current inputs U12 U23 U31 Line to line voltages UL1 UL2 UL3 Phase to ground voltages Uo Zero sequence voltage Frequency P Active power Q Reactive power S Apparent power Cos Fii Cosine loCalc Phasor sum I lis 1 Positive sequence current 2 Negative sequence current 12 11 Relative negative sequence current I2 In Negative sequence current in pu U1 Positive sequence voltage U2 Negative sequence voltage U2 U1 Helative negative sequence voltage IL Average Ii 4 lio t I 3 3 TanFii Tangent J ztan arccos Prms Active power rms value Qrms Reactive power rms value orms Apparent power rms value Uphase Average of UL1 UL2 UL3 Uline Average of U12 U23 U32 THDIL Total harmonic distortion of I THDIL2 Total harmonic distortion of 1 2 THDIL3 in Total harmonic distortion of THDUa nu Total harmonic distortion of input THDUb A Total harmonic distortion of input Up THDUc m To
166. dance grounded networks compensated networks and isolated networks undirectional ground fault can be used as back up protection The undirectional ground fault function is sensitive to the fundamental frequency component of the residual current 3lg The attenuation of the third harmonic is more than 60 dB Whenever this fundamental value exceeds the user s pick up setting of a particular stage this stage picks up and a start signal is issued If the fault situation remains on longer than the user s operation time delay setting a trip signal is issued 1051 Block Figure 5 23 Block diagram of the ground fault stages gt gt l gt gt gt and gt gt gt gt Figure 5 22 shows a functional block diagram of the l gt ground overcurrent stage with definite time and inverse time operation time Figure 5 23 shows a functional block diagram of the Ip gt gt gt gt gt and lo ground fault stages with definite time operation delay 2015 Schneider Electric All rights reserved 93 Ground fault protection lo 50N 51N section 5 Protection functions 94 Input signal selection Each stage can be connected to supervise any of the following inputs and signals e Input l for all networks other than solidly grounded e Input 102 for all networks other than solidly grounded e Calculated signal loCaic for solidly and low impedance grounded networks loca lA Ip lc Intermittent ground fault
167. de below to learn basics of logic creation LOGIC 0 4 LOGIC 15 LOGIC 3 LOGIC PX AND AND Fi E Figure 8 7 How to create logical nodes 254 2015 Schneider Electric All rights reserved 63230 218 205 oection 8 Control functions Logic functions 63230 218 205 LOGIC P 1 Press empty area to add a logic gate confirm new function by pressing Yes Logic function is always AND gate as a default While logic increases the capacity is increasing as well To joint logic functions go on top of the output line of gate and hold down mouse left gt make the connection to other logic functions input 000 S select opersbon Select input signals Select ouiputs Delete Cancel Figure 8 8 Logic creation 1 Left click on top of any logic function to activate the Select operation view 2 Edit properties button opens the Function properties window 3 Generally it is possible to choose the type of logic function between and or counter swing gate 4 When counter is selected count setting may be set here 5 Separate delay setting for logic activation and dis activation 6 Possible to invert the output of logic Inverted logic output is marked with circle Select operation a z F E RN JNNN S MENOS zx oap 1 PEET a Bins enn NT RESET 4 1 OUTPUT
168. ded 61850 File Transfer Added Difference of 2 signals compare mode in programmable stage Stages renamed e 2 gt MAGNETIZING INRUSH 68F2 If5 gt OVER EXCITATION 68F5 e P lt DIRECTIONAL POWER 32 e P lt lt DIRECTIONAL POWER 32 Harmonic and waveform displays have real input channel names not Ua Ud IEC 101 over Ethernet ModbusTCP and ModbusSlv can be used simultaneously Enable sending of analog data in GOOSE message Added for distance protection Low current block Added FTP passive mode Added second CB object to syncrocheck 63230 218 205 2015 Schneider Electric All rights reserved Section 15 Revision history Schneider Electric USA Inc 800 Federal Street Andover MA 01810 USA 888 778 2733 www schneider electric us Standards specifications and designs may change so please ask for confirmation that the information in this publication is current Schneider Electric and Square D are owned by Schneider Electric Industries SAS or its affiliated companies All other trademarks are the property of their respective owners 2015 Schneider Electric All Rights Reserved 63230 218 205 05 2015
169. definite time only Set Input lo1 X1 7 8 See Section 11 Connections Set lo2 X1 9 10 loCalc IL1 IL2 IL3 Set An editable parameter password needed C Can be cleared to zero F Editable when force flag is on For details of setting ranges see section Protection functions L1 L2 and L3 are IEC phase names For NEMA the phases are as follows L1 A L2 B and L3 C Recorded values of the latest eight faults There is detailed information available of the eight latest ground faults Time stamp fault current elapsed delay and setting group Table 5 19 Recorded values of the undirectional ground fault stages 8 latest faults lg gt gt Ip gt gt gt lo gt gt gt gt 50N 51N Parameter Value Unit Description yyyy mm dd Time stamp of the recording date hh mm ss ms Time stamp time of day Fit pu Maximum ground fault current EDly Elapsed time of the operating time setting 100 trip SetGrp 1 Active setting group during fault 2 63230 218 205 2015 Schneider Electric All rights reserved 97 Intermittent transient ground fault protection lor Section 5 Protection functions Intermittent transient ground fault protection loi 67NI 98 NOTE This function is available only in voltage measurement modes see section Voltage measurement modes which include direct Vo measurement like for example 2U Vo but not for example in
170. der an incoming I O messages 63230 218 205 2015 Schneider Electric All rights reserved 277 Communication protocols oection 9 Communication FIP server The FTP server is available on VAMP IEDs equipped with an built in or optional Ethernet card The server enables downloading of the following files from an IED e Disturbance recordings e MasterlCD MasterlCDEd2 files The MasterlCD and MasterlCDEd2 files are VAMP specific reference files that can be used for offline IEC61850 configuration The built in FTP client in Microsoft Windows or any other compatible FTP client may be used to download files from the device Parameter Value Unit Description Note Enable FTP server Yes Enable or disable the FTP server Set No FTP password Max 33 characters Required to access the FTP server with an FTP Set client Default is config The user name is al ways vamp FTP max speed 1 10 KB s The maximum speed at which the FTP server Set will transfer data 278 2015 Schneider Electric All rights reserved 63230 218 205 Section 10 Application Industrial feeder protection oection 10 Application The following examples illustrate the versatile functions in different applications oubstation feeder protection Figure 10 1 VAMP feeder and motor devices used in substation feeder protection The feeder device includes three phase overcurrent protection dir
171. e 11 1 Physical interface and connector types of remote port X5 with various options Serial interface A is the default Order Communication interface Connector type Pin usage Code A Serial interface for external converters only D9S 1 reserved REMOTE port 2 X out TTL 3 RX in TTL 4 RTS out TTL 7 9 8V out B Plastic fiber interface REMOTE port HFBR 0500 C Profibus interface REMOTE port D9S 3 RXD TXD P 4 RTS 5 GND 6 5V 8 RXD TXD N D RS 485 isolated REMOTE port screw terminal 1 Signal ground 2 Receiver 3 Receiver 4 Transmitter 5 Transmitter E Glass fiber interface 62 5 125 um REMOTE ST port F Plastic glass 62 5 125 um fiber interface HFBR 0500 ST Plastic Rx REMOTE port Glass Tx G Glass 62 5 125 um plastic fiber interface ST HFBR 0500 Glass Rx REMOTE port Plastic Tx 312 2015 Schneider Electric All rights reserved 63230 218 205 Section 11 Connections Serial communication connection Order Code Communication interface Connector type Pin usage Ethernet interface and Serial interface for extern al converters only REMOTE port D9S and RJ 45 D connector 1 reserved 2 TX out TTL in TTL 4 RTS out TTL 7 GND 9 8V out RJ 45 connector 1 Transmit 2 Transmit 3 Receive 4 Reserved 5 Reserved 6 Receive 7 Reserved 8 Reserved 10Mbps Eth
172. e 5 32 Example of the thermal model behavior 63230 218 205 2015 Schneider Electric All rights reserved 113 Thermal overload protection gt 49 Section 5 Protection functions Table 5 26 Parameters of the thermal overload stage T 49 Parameter Value Unit Description Note Status Current status of the stage Blocke d Start F Trip Time hh mm ss Estimated time to trip SCntr Cumulative start counter C TCntr Cumulative trip counter Off Force flag for status forcing for test purposes Set This is a common flag for all stages and output On relays Automatically reset by a 5 minute timeout Calculated temperature rise Trip limit is 100 96 F MaxRMS Arms Measured current Highest of the three phases Imax A kxIn Current corresponding to the 100 96 temper ature rise gt xlmode Allowed overload service factor Set Alarm Alarm level Set tau min Thermal time constant Set ctau xtau Coefficient for cooling time constant Default Set 1 0 kTamb xlmode Ambient temperature corrected max allowed continuous current Imax40 9e Imode Allowed load at Tamb 40 Default 100 96 Set Imax70 Imode Allowed load at Tamb 70 Set Tamb C Ambient temperature Editable Samb n a Default Set 40 Samb Sensor for ambient temperature Set n a No sensor in use for Tamb ExtAl1 16
173. e Options see respective ordering code Vamp 255 ordering code v255 Feeder and Motor Manager Nominal phase current nominal DI 7 20 activation voltage 1A 5A 24V 1A 5A 110V 1 5 220V Nominal earth fault current 101 amp 102 A om Hu Hn MH 1A amp 5A D 02A amp 1A Frequency Hz Standard relay Supply voltage V 265Vac dc 18 36Vdc 40 265 Vac dc 1 x BIBO 2 x Arc sensor 18 36Vdc 1 x BI BO 2 x Arc sensor 40 265Vac dc 0119 0120 1 x Arc sensor 6 18 36Vdc 0119 0120 1 x Arc sensor ptional hardware I p e amo cDDP None Plastic Plastic serial fibre interface Profibus interface RS 485 interface 4 wire Glass Glass serial fibre interface Rx Plastic Tx Glass serial fibre interface Rx Glass Tx Plastic serial fibre interface RJ 45 10Mbps ethernet interface RJ 45 10Mbps ethernet inc IEC 61850 LC 100 Mbps ethernet fibre interface inc IEC 61850 RJ 45 100Mbps ethernet interface inc IEC 61850 2 X LC 100 Mbps ethernet fibre interface inc IEC 61850 2 X RJ 45 100 Mbps ethernet interface inc IEC 61850 D E F G H M 5 P Analog Outputs amp firmware E None standard firmware F 4 pcs standard firmware Ingress protection rating I P30 default IP54 option NOTE 1 DI activation voltage selection applies to DI 7 DI20 only 368 2015 Schneider Electric All rights reserve
174. e average of three phase currents Table 12 11 Thermal overload stage T 49 Maximum continuous current 0 1 2 40 x step 0 01 Alarm setting range 60 99 step 196 Time constant Tau 2 180 min step 1 Cooling time coefficient 1 0 10 0 x Tau step 0 1 Max overload at 40 70 120 lmor step 1 Max overload at 70 C 50 100 lmor step 1 Ambient temperature 55 125 C step 1 Resetting ratio 0 95 Accuracy operating time 5 or 15 2015 Schneider Electric All rights reserved 63230 218 205 Section 12 Technical data Protection functions Table 12 12 Current unbalance stage l gt 46 in motor mode Setting range 2 70 step 196 Definite time characteristic operating time 1 0 600 0s s step 0 1 Inverse time characteristic 1 characteristic curve time multiplier Inv 1 505 step 1 upper limit for inverse time 1000 s Start time Typically 300 ms Reset time 450 ms Reset ratio 0 95 Inaccuracy Starting 1 unit Operate time 5 or 200 ms NOTE Stage is operational when all secondary currents are above 250 mA Table 12 13 Incorrect phase sequence gt gt 47 Setting Operating time Reset time 80 fixed lt 120 ms 105 ms NOTE Stage is blocked when motor has b
175. e before fault 1 s average value SetGrp Active setting group during fault 63230 218 204 2014 Schneider Electric All rights reserved 121 Directional power protection P 32 oection 5 Protection functions Directional power protection P P 32 Directional power function can be used for example to disconnect a motor in case the supply voltage is lost and thus helps prevent power generation by the motor It can also be used to detect loss of load of a motor Directional power function is sensitive to active power For reverse power function the pick up value is negative For underpower function a positive pick up value is used Whenever the active power goes under the pick up value the stage picks up and issues a start signal If the fault situation stays on longer than the delay setting a trip signal is issued The pick up setting range is from 200 96 to 200 96 of the nominal apparent power Sy The nominal apparent power is determined by the configured voltage and current transformer values Equation 5 3 5 V Rated Pr imary CT rated Pr imary There are two identical stages available with independent setting parameters Table 5 31 Setting parameters of P and P stages Parameter Value Unit Default Description P P 200 0 4200 0 oon 4 0 P P P pick up setting 20 0 P t lt
176. e benefit of this mode is the speed and easy access to the data in the Profibus master The drawback is the maximum buffer size of 128 bytes which limits the number of data items transferred to the master Some PLCs have their own limitation for the Profibus buffer size which may further limit the number of transferred data items Device profile Request mode Using the request mode it is possible to read all the available data from the VAMP device and still use only a very short buffer for Profibus data transfer The drawback is the slower overall speed of the data transfer and the need of increased data processing at the Profibus master as every data item must be separately requested by the master NOTE In request mode it is not possible to continuously read only one single data item At least two different data items must be read in turn to get updated data from the device There is a separate manual for VPA 3CG VVPA3CG EN M xxxx for the continuous mode and request mode The manual is available to download from our website Available data VAMPSET will show the list of all available data items for both modes A separate document Profibus parameters pdf is also available The Profibus DP communication is activated usually for remote port via a menu selection with parameter Protocol See the section Communication ports 268 2015 Schneider Electric All rights reserved 63230 218 205 Section 9 Communication Communica
177. e current L2 S1 Phase current L3 S1 Residual current 101 51 Residual current lo2 S1 See the section Voltage measurement modes See the section Voltage measurement modes See the section Voltage measurement modes Description Phase current L1 S2 Phase current L2 S2 Phase current L3 S2 Residual current lo1 52 Residual current lo2 52 See the section Voltage measurement modes See the section Voltage measurement modes See the section Voltage measurement modes L1 L2 and L3 are IEC phase names For NEMA the phases are as follows L1 A L2 B and L3 C 63230 218 205 2015 Schneider Electric All rights reserved 30 7 Rear panel Terminal X2 3 6 6 308 ao N O A 0 O 12 13 14 15 16 17 18 5 5 A4 A4 A3 COM A3 NC NO A2 COM A2 NC A2 NO SF COM SF NC SF NO 2015 Schneider Electric All rights reserved Section 11 Connections Description Alarm relay 5 Alarm relay 5 Alarm relay 4 Alarm relay 4 Alarm relay 3 common connector Alarm relay 3 normal closed connector Alarm relay 3 normal open connector Alarm relay 2 common connector Alarm relay 2 normal closed connector Alarm relay 2 normal open connector Detected internal fault relay common connector Detected internal fault relay normal closed connector Detected internal fault relay normal ope
178. e currents The gt stage can be configured for definite operation time or inverse time operation characteristic For a weak voltage supply the inverse characteristics are useful allowing more start time when a voltage drop decreases the start current and increases the start time Equation 5 2 defines the inverse operation time Figure 5 13 shows an example of the inverse characteristics T Inverse operation time Equation 5 2 _ Rated start current of the motor Nom motor start current START 7 IMOTST The default setting is 6 00xlyo1 Measured current I T MEAS T start start Maximum allowed start time Inv time coefficient k for T TSTART the motor at rated voltage The pick up setting Motor start detection current lar is the start detection level of the start current While the current has been less than 1096 of Imot and then within 200 milliseconds exceeds the setting lar the stall protection stage starts to count the operation time T START When current drops below 120 x lyor the stall protection stage releases Stall protection is active only during the starting of the motor Istlohko Figure 5 12 Block diagram of the stall protection stage Is 80 2015 Schneider Electric All rights reserved 63230 218 205 Section 5 Protection functions Stall protection lsr 48 Istart 6 pu rated start current Tstart 15 s maximum allowed start time Figure 5 13 Example of an
179. e final trip signal will stay active for 0 5 seconds and then resets automatically 63230 218 205 2015 Schneider Electric All rights reserved 249 Auto reclose function 79 DI to block AR setting Section 8 Control functions This setting is useful with an external synchro check device This setting only affects re closing the CB Re closing can be blocked with a digital input virtual input or virtual output When the blocking input is active CB won t be closed until the blocking input becomes inactive again When blocking becomes inactive the CB will be controlled close immediately AR info for mimic display setting When AR info is enabled the local panel mimic display shows small info box during AR sequence Table 8 5 Setting parameters of AH function Parameter Value Unit Default Description ARena ARon ARoff ARon Enabling disabling the autoreclose ExtSync None The digital input for blocking CB close This can be used for Synchrocheck any digital input virtual input or virtual output AR DI None The digital input for toggling the ARena parameter any digital input virtual input or virtual output AR2grp ARon ARoff ARon Enabling disabling the autoreclose for group 2 ReclT 0 02 300 00 S 10 00 Reclaim time setting This is common for all the shots CB Obj1
180. e multiplier k DT IEC IEEE RI Prg El NI LTI MI depends on the family 0 05 20 0 except 0 50 20 0 for RXIDG IEEE and IEEE2 Start time Typically 30 ms Reset time lt 95 ms Retardation time lt 50 ms Reset ratio 0 97 Transient over reach any T lt 10 Inaccuracy Starting Operating time at definite time function Operating time at IDMT function 3 of the set value or 5 mA secondary 1 or 25ms 5 or at least 25 ms 2015 Schneider Electric All rights reserved 63230 218 205 Section 12 Technical data 63230 218 205 Protection functions Table 12 8 Overcurrent stage I 50 51 Pick up current 1 10 20 00 x In Definite time function Operating time DI 0 04 1800 00 s step 0 01 s Start time Typically 30 ms Heset time 95 ms Hetardation time lt 50 ms Heset ratio 0 97 Transient over reach any T 10 96 Inaccuracy Starting Operation time 3 of the set value or 5 mA secondary 1 or 25 ms Table 12 9 Overcurrent stage I 50 51 Pick up current 0 10 40 00 x Ix gt gt gt Definite time function Operating time DI 0 03 300 00 s step 0 01 s Instant operation time lwlsET ratio 1 5 lwsET ratio 1 03 1 5 lt 30 ms lt 50 ms Start time Typically 20 ms Reset time
181. e of the transformer and short circuiting transformer secondary circuits first Replace all devices doors and covers before turning on power to this unit Failure to follow these instructions will result in death or serious injury A WARNING WORKING ON ENERGIZED EQUIPMENT Do not choose lower Personal Protection Equipment while working on energized equipment Failure to follow these instructions can result in death or serious injury 63230 218 205 2015 Schneider Electric All rights reserved 9 Related documents Section 1 General Password protection Password protection Use IED s password protection feature in order to protect untrained person interacting this device 10 2015 Schneider Electric All rights reserved 63230 218 205 Section 1 General Abbreviations Relay features The comprehensive protection functions of the relay make it ideal for utility industrial marine and off shore power distribution applications The relay features the following protection functions Table 1 1 List of protection functions IEEE ANSI code IEC symbol Function name Thermal overload protection 50 51 5O0ARC 50NARC SOBF 50NC 51NC I gt I gt gt gt Arcl gt Arclo Arclos gt CBFP locap gt Overcurrent protection Optional arc fault detection Circuit breaker failure protection Capacitor bank unbalance protection ee Overvoltage protection Up gt gt Uo gt gt gt zero se
182. e setting group for the appropriate over current stage with inrush detect signal It is also possible to use the detection signal to block any set of protection stages for a given time Inrush detection is based on FFT calculation which requires a full cycle of data for analyzing the harmonic content Therefore when using inrush blocking function the cold load pick up starting conditions are used for activating the inrush blocking when the current rise is noticed If in the signal is found second harmonic component after 2015 Schneider Electric All rights reserved 173 Voltage sags and swells oection 6 Supporting functions 1st cycle the blocking is continued otherwise 2nd harmonic based blocking signal is released Inrush blocking is recommended to be used into time delayed overcurrent stages while non blocked instant overcurrent stage is set to 20 higher than expected inrush current By this scheme fast reaction time in short circuit faults during the energization can be achieved while time delayed stages are blocked by inrush function 1 No activation because the current has not been under the set Ij p current 2 Current dropped under the lp current level but now it stays between the lp current and the pick up current for over 80ms 3 No activation because the phase two lasted longer than 80ms Now we have a cold load activation which lasts as long as the operation time was set or as long as the current stays ab
183. ected communication error counter Errors e Detected communication time out error counter Tout e Same information as in the previous menu 2015 Schneider Electric All rights reserved 63230 218 205 Section 2 Local panel user interface 63230 218 205 Configuration and parameter setting Extension port pins 7 8 and 5 Communication protocol for extension port X4 Protocol Message counter Msg This can be used to verify that the device is receiving messages Detected communication error counter Errors Detected communication time out error counter Tout Information of bit rate data bits parity stop bits This value is not directly editable Editing is done in the appropriate protocol setting menus Ethernet port These parameters are used by the ethernet interface module For changing the nnn nnn nnn nnn style parameter values VAMPSET is recommended Ethernet port protocol IP Port for protocol Port IP address lpAddr Net mask NetMsk Gateway Gatew Name server NameSw Network time protocol NTP server NTPSvr TCP Keep alive interval KeepAlive MAC address MAC IP Port for VAMPSET VS Port Message counter Msg Detected error counter Errors Timeout counter Tout Modbus Modbus address for this slave device Addr This address has to be unique within the system Modbus bit rate bit s Default is 9600 Parity Parity Default is Even For det
184. ected to supervise any of the following inputs and signals e Input l for all networks other than solidly grounded e Input 102 for all networks other than solidly grounded e Calculated signal loca for solidly and low impedance grounded networks loca la lg lc Slo Intermittent ground fault detection Short ground faults make the protection to start to pick up but will not cause a trip Here a short fault means one cycle or more For shorter than 1 ms transient type of intermittent ground faults in compensated networks there is a dedicated stage lojyr 67NI When starting happens often enough such intermittent faults can be cleared using the intermittent time setting When a new start happens within the set intermittent time the operation delay counter is not cleared between adjacent faults and finally the stage will trip Two independent stages There are two separately adjustable stages loy and gt gt Both the stages can be configured for definite time delay DT or inverse time delay operation time Inverse operation time Inverse delay means that the operation time depends on the amount the measured current exceeds the pick up setting The bigger the fault current is the faster will be the operation Accomplished inverse delays are available for both stages lo and lo gt gt The inverse delay types are described in the section Inverse time operation The device will show a scaleable graph of the co
185. ection 5 Protection functions Hecorded values of the latest eight faults There is detailed information available for the eight latest faults Time stamp fault type fault current load current before the fault elapsed delay and setting group Table 5 3 Recorded values of the overcurrent stages 8 latest faults I gt gt gt gt gt gt 50 51 Parameter Value Unit Description yyyy mm dd Time stamp of the recording date hh mm ss ms Time stamp time of day Type Fault type 1 N Ground fault 2 N Ground fault 3 N Ground fault 1 2 Two phase fault 2 3 Two phase fault 3 1 Two phase fault 1 2 3 Three phase fault xlmode Maximum fault current xlmode 1 s average phase currents before the fault Elapsed time of the operating time setting 100 trip SetGrp 1 Active setting group during fault 2 66 2015 Schneider Electric All rights reserved 63230 218 205 Section 5 Protection functions Directional phase overcurrent lo gt 67 Remote controlled overcurrent scaling Please note This function is typically used for a maintenance mode application If communications are lost it may be set via the front display or via local connection with the software Pick up setting of the three over current stages can also be controlled remotely In this case only two scaling coefficients are possible 100 the scaling is inactive and any configured value between 1096 200 the scaling is active Whe
186. ectional ground fault protection and fast arc detection At the incoming feeder the instantaneous stage gt gt gt of the VAMP feeder devices is blocked with the start signal of the overcurrent stage This helps prevent the trip signal if the fault occurs on the outgoing feeder For the directional function of ground fault function the status information on off of the Petersen coil is routed to one of the digital inputs of the feeder device so that either loging or function is obtained The function losing is used in isolated networks and the function locoso IS used in resistance or resonant grounded networks 63230 218 205 2015 Schneider Electric All rights reserved 279 Parallel line protection Section 10 Application Industrial feeder protection Figure 10 2 VAMP feeder and motor devices used in cable protection of an industry plant network Directional ground fault protection and three phase overcurrent protection is required in a cable feeder Furthermore the thermal stage can be used to protect the cable against overloading This example also includes fast arc detection 280 2015 Schneider Electric All rights reserved 63230 218 205 Section 10 Application Industrial feeder protection Parallel line protection 63230 218 205 LOAD 67 R3 LOAD SUPPLY LOAD 2151 LOAD SPARE SUPPLY LOAD R5 67 Figure 10 3 Feeder and motor device used
187. ed when the control signal is releasing Releasing of latched devices is done with a separate action LED B LED C Liquid crystal display Light emitting diode IED front panel with display and pushbuttons Network time protocol for LAN and WWW Active power Unit W IEC 101 IEC 103 m UO uu UJ Z IEEE gt m Latching Im UO Local HMI UO U 2015 Schneider Electric All rights reserved 63230 218 205 13 Periodic testing Section 1 General Power factor The absolute value is equal to cosq but the sign is for inductive i e lagging current and for capacitive i e leading current t Nominal power of the prime mover Used by reverse under power protection Py Eo o P example for overcurrent setting 1 1 Q ReaepowerUnt va aceIEC oo O RMS Roomeansqare S O oO SF T T T IED status inoperative PF pu RMS S SF Trip circuit supervision Total harmonic distortion VA Vc VN VT WWW Apparent power Unit 2 VA SNTP Simple Network Time Protocol for LAN and WWW Trip indication Voltage at input Vc at zero ohm ground fault Used in voltage measurement mode 2LL Uo Va Voltage input for V12 or Va depending of the voltage measurement mode Ves Voltage input for V23 or Ve depending of the voltage measurement mode Ve Voltage input for Vsi Vo depending
188. een running for 2 seconds Stage is operational only when least one of the currents is above 0 2 x IMOT Table 12 14 Undercurrent protection stage I lt 37 Current setting range 20 70 step 196 Definite time characteristic operating time 0 3 300 0s s step 0 1 Block limit 15 96 fixed Start time Typically 200 ms Reset time 450 ms Reset ratio 1 05 Accuracy starting 2 of set value or 0 5 of the rated value operating time 1 or 150 ms NOTE Stage Blocking is functional when all phase currents are below the block limit 63230 218 205 2015 Schneider Electric All rights reserved 349 Protection functions Section 12 Technical data Table 12 15 Current unbalance stage l 46 in feeder mode Settings Setting range 1 lj 2 70 96 Definite time function Operating time 1 0 600 0 s step 0 1 s Start time Typically 300 ms Reset time 450 ms Reset ratio 0 95 Inaccuracy Starting 1 unit Operate time 5 or 200 ms Table 12 16 Ground fault stage lg bON 51N Input signal lor input X1 7 8 loo input X1 9 1 0 locale 11 lio 3 Setting range lo 0 005 8 00 pu when lo or lo2 0 05 20 0 pu when locat Definite time function DT Operating time 0 04 300 00 s step 0 02 s IDMT function Delay curve family DT IEC
189. elected by changing the value of the parameter SetGrp group AV b I gt STATUS Status SCntr TCntr SetGrp SGrpDI Force Figure 2 7 Example of protection submenu with setting group parameters The changing of the setting parameters can be done easily When the desired submenu has been found with the arrow keys press 19 io select the submenu Now the selected setting group is indicated in the down left corner of the display See Figure 2 8 Set1 is setting group one and Set2 is setting group two When the needed changes to the selected setting group have been done press Or to select another group E is used when the active setting group is 2 and is used when the active setting group is 1 eroup2 SET I gt 51 Setting for stage I gt IL max 400A Status I 600A Figure 2 8 Example of I setting submenu 2015 Schneider Electric All rights reserved 63230 218 205 section 2 Local panel user interface Local panel operations Fault logs 63230 218 205 All the protection functions include fault logs The fault log of a function can register up to eight different faults with time stamp information fault values etc The fault logs are stored in non volatile memory Each function has its own logs The fault logs are not cleared when power is switched off The user is able to clear all logs using VAMPSET Each function has its own logs Figure 2 9 log gt log buffer Log buffer 1 2003
190. ement modes e When the voltage measurement mode is 3LN the zero sequence voltage is calculated from the phase voltages and therefore a separate zero sequence voltage transformer is not needed The setting values are relative to the configured voltage transformer VT voltage 43 e When the voltage measurement mode contains Vo The zero sequence voltage is measured with voltage transformer s for example using an open delta connection The setting values are relative to the VTg secondary voltage defined in configuration NOTE The Ug signal must be connected according the connection diagram Figure 11 17 in order to get a correct polarization Please note that actually the negative Vo Vo is to be connected to the device Two independent stages There are two separately adjustable stages Vy and Vo gt gt Both stages can be configured for definite time DT operation characteristic The zero sequence voltage function comprises two separately adjustable zero sequence voltage stages stage Vo and gt gt 2014 Schneider Electric All rights reserved 63230 218 205 oection 5 Protection functions Zero sequence voltage protection Ug 59N Setting groups There are two settings groups available for both stages Switching between setting groups can be controlled by digital inputs virtual inputs communication logic and manually Blocking Figure 5 30 Block diagram of the zero sequence voltage stages V
191. ength If there are several wire types on the same line an average line reactance value can be used to get an approximate distance value to the fault The fault locator is normally used in the incoming bay of the substation Therefore the fault location is obtained for the whole network with just one device This is very cost effective upgrade of an existing system The algorithm functions in the following order 1 Ihe needed measurements phase currents and voltages are continuously available 2 The fault distance calculation can be triggered in two ways by opening a feeder circuit breaker due to a fault and sudden increase in phase currents Enable Xfault calc1 Triggering digital input Other option is to use only the sudden increase in the phase currents Enable Xfault calc1 3 Phase currents and voltages are registered in three stages before the fault during the fault and after the detected faulty feeder circuit breaker was opened The fault distance quantities are calculated Two phases with the biggest fault current are selected The load currents are compensated Du up Or IPS The detected faulty line length reactance is calculated 204 2015 Schneider Electric All rights reserved 63230 218 205 oection 6 Supporting functions Parameter Incomer short circuit fault locator Table 6 20 Setting parameters of short circuit fault locator Default Description Triggering digital input woe
192. ent temperature correction of the overload stage gt 2014 Schneider Electric All rights reserved 63230 218 205 oection 5 Protection functions Overvoltage protection U gt 59 Example of a behavior of the thermal model Figure 5 31 shows an example of the thermal model behavior In this example T 30 minutes 1 06 and 1 and the current has been zero for a long time and thus the initial temperature rise is 0 At time 50 minutes the current changes to 0 85 x Imone and the temperature rise starts to approach value 0 85 1 06 64 96 according the time constant At time 300 min the temperature is about stable and the current increases to 5 96 over the maximum defined by the rated current and the service factor k The temperature rise starts to approach value 110 96 At about 340 minutes the temperature rise is 100 and a trip follows Initial temperature rise after restart When the device is switched on an initial temperature rise of 70 is used Depending of the actual current the calculated temperature rise then starts to approach the final value Alarm function The thermal overload stage is provided with a separately settable alarm function When the alarm limit is reached the stage activates its start signal Temperature rise Moverload 100 max alarm 80 Op 60 Settings T 30 minutes k 1 06 Oalarm 90 Time 100 min 200 min 300 min 400 min S00 min Figur
193. epends on the family 0 05 20 0 except 0 50 20 0 for RXIDG IEEE and IEEE2 Start time Typically 30 ms Reset time lt 95 ms Retardation time 50 ms Reset ratio 0 95 Reset ratio angle 29 Transient over reach any 10 96 Voltage memory 1 5 seconds Inaccuracy Starting rated value ly2 1 5A 3 of the set value or 0 5 of the rated value Angle 2 U gt 5 V 30 U 0 1 5 0 V Operate time at definite time function 1 or 25 ms Operate time at IDMT function 5 or at least 30 ms 2015 Schneider Electric All rights reserved 63230 218 205 Section 12 Technical data 63230 218 205 Protection functions Table 12 20 Directional overcurrent stages p gt gt gt l 67 Pick up current 0 10 20 0 x IMODE Mode Directional Directional BackUp Minimum voltage for the direction solving 2 VsECONDARY Base angle setting range 180 4179 Operation angle 88 Definite time function Operating time DI 0 04 300 00 s step 0 02 s Start time Typically 30 ms Heset time 95 ms Retardation time lt 50 ms Heset ratio 0 95 Reset ratio angle 29 Transient over reach any T Inaccuracy Starting rated value In 1 5A 3 of the set value or 0 5 of the rated value Angle 2
194. erised to the condition monitoring function with maximum eight current cycles points See Table 6 13 If less than eight points needed the unused points are set to lgic 1 where Igic is more than the maximum breaking capacity If the CB wearing characteristics or part of it is a straight line on a log log graph the two end points are needed to define that part of the characteristics This is because the relay is using logarithmic interpolation for any current values falling in between the given current points 2 8 The points 4 8 are not needed for the CB in Figure 6 4 Thus they are set to 100 kA and one operation in the table to be discarded by the algorithm 2015 Schneider Electric All rights reserved 181 Circuit breaker condition monitoring oection 6 Supporting functions Number of permitted operations 100 200 500 1000 10000 100000 Breaked current A CBWEARC haracteristics Figure 6 4 An example of a circuit breaker wearing characteristic graph Table 6 13 An example of circuit breaker wearing characteristics in a table format The values are taken from the figure above The table is edited with VAMPSET under menu BREAKER CURVE Point Interrupted current Number of permitted operations 1 0 mechanical age 10000 2 1 25 rated current 10000 3 31 0 maximum breaking current 80 4 100 1 5 100 1 6 100 1 7 100 1 8 100 1 182 2015 Schneider
195. ernet interface with IEC 61850 and Serial interface for external converters only REMOTE port D9S and RJ 45 D connector 1 reserved 2 TX out TTL 3 RX in TTL 4 RTS out TTL 7 GND 9 8V out RJ 45 connector 1 Transmit 2 Transmit 3 Receive 4 Reserved 5 Reserved 6 Receive 7 Reserved 8 Reserved 63230 218 205 2015 Schneider Electric All rights reserved 313 Serial communication connection Section 11 Connections Order Communication interface Connector type Pin usage Code 100 Mbps Ethernet fiber interface with IEC D9S and LC D connector 61850 and Serial interface for external converters only REMOTE port 1 reserved 2 out TTL in TTL S 4 RTS out TTL 7 GND R 9 8V out Fiber connector TX Upper LC connector RX Lower LC connector P 100Mbps Ethernet interface with IEC 61850 and D9S and RJ 45 D connector Serial interface for external converters only REMOTE port 1 reserved 2 TX out TTL in TTL 4 RTS out TTL 7 GND 9 8V out RJ 45 connector 1 Transmit 2 Transmit 3 Receive 4 Reserved 5 Reserved 6 Receive 7 Reserved 8 Reserved R 100 Mbps Ethernet fiber interface with IEC 2xLC L C connector from top 61850 Port 2 Tx Port 2 Rx Port 1 Tx Port 1 Rx 314 2015 Schneider Electric All rights reserved 63230 218 205 Section 11 Connec
196. erruling the local port in the rear panel Hemote port e Communication protocol for remote port X5 Protocol e Message counter Msg z This can be used to verify that the device is receiving messages e Detected communication error counter Errors e Detected communication time out error counter Tout e Information of bit rate data bits parity stop bits This value is not directly editable Editing is done in the appropriate protocol setting menus The counters are useful when testing the communication Local port X4 This port is disabled if a cable is connected to the front panel connector e Communication protocol for the local port X4 Protocol For VAMPSET use None or SPABUS e Message counter Msg This can be used to verify that the device is receiving messages e Detected communication error counter Errors e Detected communication time out error counter Tout e Information of bit rate data bits parity stop bits This value is not directly editable Editing is done in the appropriate protocol setting menus For VAMPSET and protocol None the setting is done in menu CONF DEVICE SETUP The counters are useful when testing the communication PC Local SPA bus This is a second menu for local port X4 The VAMPSET communication status is showed e Bytes size of the transmitter buffer Tx e Message counter Msg This can be used to verify that the device is receiving messages e Det
197. errupted a fault condition determine and clear the causes of the fault Check the condition of the circuit breaker before putting it back into service Failure to follow these instructions will result in death serious injury or equipment damage When CB is closed manually with the local panel remote bus digital inputs etc the reclaim state is activated Within the reclaim time all AR requests are ignored It is up to protection stages to take care of tripping Trip signals of protection stages must be connected to a trip relay in the output matrix Manual opening Manual CB open command during AR sequence will stop the sequence and leaves the CB open Reclaim time setting e Use shot specific reclaim time No Reclaim time setting defines reclaim time between different shots during sequence and also reclaim time after manual closing e Use shot specific reclaim time Yes Reclaim time setting defines reclaim time only for manual control Reclaim time between different shots is defined by shot specific reclaim time settings 63230 218 205 2015 Schneider Electric All rights reserved 247 Auto reclose function 79 248 NOTE Section 8 Control functions Support for 2 circuit breakers AR function can be configured to handle 2 controllable objects Object 1 6 can be configured to CB1 and any other controllable object can be used as CB2 The object selection for CB2 is made with Breaker 2 object setting Switchi
198. ers can be set Opening Default password is 2 Setting state ng Push Closing The level is automatically closed after 10 minutes idle time Giving the password 9999 can also close the level Please note Schneider Electric recommends changing the default password and saving for future use 2015 Schneider Electric All rights reserved 63230 218 205 section 2 Local panel user interface Local panel operations Opening access 1 Push on the front panel ENTER PASSWORD A 0 v Figure 2 11 Opening the access level 2 Enter the password needed for the desired level the password can contain four digits The digits are supplied one by one by first moving to the position of the digit using and then setting the desired digit value using GN 3 Push Password handling The passwords can only be changed using VAMPSET software connected to the local RS 232 port on the relay It is possible to restore the password s in case the password is lost or forgotten In order to restore the password s a relay program is needed The virtual serial port settings are 38400 bps 8 data bits no parity and one stop bit The bit rate is configurable via the front panel Command Description Get the break code Example 6569403 get pwd break get serno Get the serial number of the relay Example 12345 send both the numbers to your nearest Schneider Electric
199. eter setting Section 2 Local panel user interface Parameter setting Move to the setting state of the desired menu for example CONF CURRENT SCALING by pushing KS The Pick text appears in the upper left part of the display Enter the password associated with the configuration level by pushing and then using the arrow keys default value is 0002 For more information about the access levels please refer to the section Fault logs scroll through the parameters using the and BB A parameter can be set if the background color of the line is black If the parameter cannot be set the parameter is framed select the desired parameter for example Inom with C3 Use the and keys to change a parameter value If the value contains more than one digit use the and keys to shift from digit to digit and the and keys to change the digits Push to accept a new value If you want to leave the parameter value unchanged exit the edit state by pushing VAMP 200 series changing parameters AY4 CURRENT SCALING PICK CURRENT SCALING Inom Isec lonom OJ Edit VALUE CHANGE Figure 2 16 Changing parameters 40 2015 Schneider Electric All rights reserved 63230 218 205 oection 2 Local panel user interface Configuration and parameter setting oetting range limits If the given parameter setting values are out of range values a message noting the out of range condition will be shown when the set
200. ether with external converters or converting cables Built in options for RS 485 fiber optic plastic plastic plastic glass glass plastic or glass glass Profibus and Ethernet are available 2015 Schneider Electric All rights reserved 63230 218 205 oection 9 Communication Communication ports Local port X4 The local port has two connectors e On the front panel e 4 the rear panel 095 pins 2 and 5 Only one can be used at a time NOTE The extension port is located in the same X4 connector When the VX003 cable is inserted to the front panel connector it activates the front panel port and disables the rear panel local port by connecting the DTR pin 6 and DSR pin 4 together See Figure 9 1 Protocol for the local port The front panel port is always using the command line protocol for VAMPSET regaraless of the selected protocol for the rear panel local port If other than None protocol is selected for the rear panel local port the front panel connector when activated is still using the plain command line interface with the original speed parity etc For example if the rear panel local port is used for remote VAMPSET communication using SPA bus default 9600 7E1 it is possible to temporarily connect a PC with VAMPSET to the front panel connector with the default 38400 8N1 While the front panel connector is in use the rear panel local port is disabled The communication parameter display on the local display wil
201. etting a trip signal is issued 2015 Schneider Electric All rights reserved 63230 218 205 oection 5 Protection functions Directional ground fault protection lg 67N Polarization The negative zero sequence voltage Vo is used for polarization i e the angle reference for lg The Vo voltage is measured via energizing inputVg or it is calculated from the phase voltages internally depending on the selected voltage measurement mode see section Voltage measurement modes e LN the zero sequence voltage is calculated from the phase voltages and therefore any separate zero sequence voltage transformers are not needed The setting values are relative to the configured voltage transformer VT voltage 43 e LL Vg the zero sequence voltage is measured with voltage transformer s for example using an open delta connection The setting values are relative to the VI 9 secondary voltage defined in configuration NOTE The Vg signal must be connected according the connection diagram Figure 11 17 in order to get a correct polarization Please note that actually the negative Vo Vo is connected to the device Modes for different network types The available modes are e ResCap This mode consists of two sub modes Res and Cap A digital signal can be used to dynamically switch between these two sub modes This feature can be used with compensated networks when the Petersen coil is temporarily switched off Res The stage is
202. etting delay type to Parameters and then editing the delay function parameters A E See the section Free parameterization using IEC IEEE and IEEE2 equations e Fully programmable inverse delay characteristics Building the characteristics by setting 16 current time points The relay interpolates the values between given points with 2nd degree polynomials This mode is activated by setting curve family to PrgN There are maximum three different programmable curves available at the same time Each programmed curve can be used by any number of protection stages See the section Programmable inverse time curves Local panel graph The device will show a graph of the currently used inverse delay on the local panel display Up and down keys can be used for zooming Also the delays at 20xlagy 4xlagr and 2xlagz are shown 148 2015 Schneider Electric All rights reserved 63230 218 205 oection 5 Protection functions Inverse time operation Inverse time setting detected error signal If there are any detected errors in the inverse delay configuration the values will be rejected and the appropriate protection stage will use definite time delay There is a signal Setting Error available in output matrix which indicates three different situations 1 Settings are currently changed with VAMPSET or local panel and there is temporarily an illegal combination of curve delay points For example if previous settings were IEC NI
203. ff Off Indicates if this AR signal starts this shot AR3 On Off Off Indicates if this AR signal starts this shot AR4 On Off Off Indicates if this AR signal starts this shot Start1 0 02 300 00 S 0 02 AR1 Start delay setting for this shot otart2 0 02 300 00 S 0 02 AR2 Start delay setting for this shot Start3 0 02 300 00 S 0 02 AR3 Start delay setting for this shot Start4 0 02 300 00 S 0 02 ARA Start delay setting for this shot Discr1 0 02 300 00 S 0 02 AR1 Discrimination time setting for this shot Discr2 0 02 300 00 S 0 02 AR2 Discrimination time setting for this shot Discr3 0 02 300 00 0 02 ARS Discrimination time setting for this shot Discr4 0 02 300 00 S 0 02 AR4 Discrimination time setting for this shot 63230 218 205 2015 Schneider Electric All rights reserved 251 Auto reclose function 79 Parameter Value Section 8 Control functions Table 8 6 Measured and recorded values of AH function Unit Description Measured or recor ded values There are 5 counters available for each one of the two AR signals 252 Obj1 UNDEFINED OPEN CLOSE OPEN_REQUEST CLOSE REQUEST READY NOT READY INFO NOT AVAILABLE FAIL Object 1 state Status INIT RECLAIM TIME READY WAIT CB OPEN WAIT CB CLOSE DISCRIMINATION TIME LOCKED FINAL TRIP CB FAIL INHIBIT AR function state Shot 1 5 The currently running shot
204. for protection of parallel lines Figure 10 3 shows two parallel lines A and B protected with 51 overcurrent relays R1 R2 R3 and R4 The relays R3 and R4 are directional 67 If there is a fault in one of the lines only the detected faulty line will be switched off because of the direction functions of the relays R3 and R4 A detailed schematic of e g the relay R3 is shown in Figure 10 4 2015 Schneider Electric All rights reserved 281 Ring network protection Section 10 Application A DANGER HAZARD OF ELECTRIC SHOCK EXPLOSION OR ARC FLASH Apply appropriate personal protective equipment PPE and follow safe electrical work practices See NFPA 70E NOM 029 STPS 2011 and CSA 2462 This equipment must be installed and serviced only by qualified electrical personnel Turn off power to the busway and equipment before installing removing or working on this equipment The successful operation of this equipment depends upon proper handling installation operation and maintenance Failure to follow these instructions can result in death or serious injury Figure 10 4 Example connection using VAMP 230 same connection applies for VAMP 255 Both short circuits and ground faults will be detected The outgoing line is one of several parallel lines or the line is feeding a ring network 202 2015 Schneider Electric All rights reserved 63230 218 205 Section 10 Application Parallel line protection
205. g value Ambient temperature factor Permitted current due to tamb IMODE The rated current In or om Relay cooling time constant Setting value 2015 Schneider Electric All rights reserved 111 Thermal overload protection gt 49 oection 5 Protection functions 112 Time constant for cooling situation If the motor s fan is stopped the cooling will be slower than with an C active fan Therefore there is a coefficient for thermal constant available to be used as cooling time constant when current is less than 0 3xlyor Heat capacitance service factor and ambient temperature The trip level is determined by the maximum allowed continuous current Imax corresponding to the 100 96 temperature rise I e the heat capacitance of the motor or cable ljj4 depends of the given service factor k and ambient temperature Oayp and settings IMAx40 and lyaAxzo according the following equation k kg The value of ambient temperature compensation factor depends on the ambient temperature Oayp and settings 1 and IMax70 oee Figure 5 31 Ambient temperature is not in use when kO 1 This is true when IMAX40 is 1 0 e Samb is n a no ambient temperature sensor e TAMB is 40 k AmbientTemperatureCompensation e 1 2 1 0 0 8 0 6 10 20 30 40 50 60 70 80 C Figure 5 31 Ambi
206. he Profibus ASIC The actual Profibus bit rate is automatically set by the Profibus master and can be up to 12 Mbit s e Event numbering style Emode e Size of the Profibus Tx buffer InBuf e Size of the Profibus Rx buffer OutBuf When configuring the Profibus master system the length of these buffers are needed The size of the both buffers is set indirectly when configuring the data items for Profibus e Address for this slave device Addr This address has to be unique within the system e Profibus converter type Conv If the shown type is a dash either Profibus protocol has not been selected or the device has not restarted after protocol change or there is a communication problem between the main CPU and the Profibus ASIC For details see Profibus DP DNP3 Only one instance of this protocol is possible e Bitrate bit s Default is 9600 e Parity e Address for this device SlvAddr This address has to be unique within the system e Master s address MstrAdar For details see DNP 3 0 IEC 60870 5 101 Bitrate bit s Default is 9600 e Parity e Link layer address for this device LLAddr e ASDU address ALAddr For details see IEC 60870 5 101 2015 Schneider Electric All rights reserved 49 Configuration and parameter setting Section 2 Local panel user interface oingle line diagram editing The single line diagram is drawn with the VAMPSET software For more i
207. he sag swell 4 Time Time stamp of the sag swell Type Voltage inputs that had the sag swell Time S Duration of the sag swell Min1 Un Minimum voltage value during the sag swell in the input 1 Min2 Un Minimum voltage value during the sag swell in the input 2 Min3 Un Minimum voltage value during the sag swell in the input 3 Ave1 Un Average voltage value during the sag swell in the input 1 Ave2 Un Average voltage value during the sag swell in the input 2 Ave3 Un Average voltage value during the sag swell in the input 3 Max1 Un Maximum voltage value during the sag swell in the input 1 Max2 Un Maximum voltage value during the sag swell in the input 2 Max3 Un Maximum voltage value during the sag swell in the input 3 For details of setting ranges see the section Supporting functions 176 2015 Schneider Electric All rights reserved 63230 218 205 Section 6 Supporting functions Current transformer supervision Voltage interruptions The device includes a simple function to detect voltage interruptions The function calculates the number of voltage interruptions and the total time of the voltage off time within a given calendar period The period is based on the real time clock of the device The available periods are e 8 hours 00 00 08 00 08 00 16 00 16 00 24 00 e one day 00 00 24 00 e one week Monday 00 00 Sunday 24 00 e one month the first day 00 00 the last day
208. he trip contacts and start contact are opened unless latching is configured The precise reset time depends on the intensity of the fault the more intense the fault is the slower the reset time will be The reset time also depends on the specific protection stage 2015 Schneider Electric All rights reserved 59 General features of protection stages oection 5 Protection functions The maximum reset time for each stage is specified in section Protection functions For most stages it is less than 95 ms ReleaseTime SET CB t 4 TRIP CONTACTS Figure 5 2 Reset time is the time it takes the trip or start relay contacts to open after the fault has been cleared 60 2015 Schneider Electric All rights reserved 63230 218 205 J aa Section 5 Protection functions Overcurrent protection I gt 50 51 Hysteresis or dead band When comparing a measured value against a pick up value some amount of hysteresis is needed to avoid oscillation near equilibrium situation With zero hysteresis any noise in the measured signal or any noise in the measurement itself would cause unwanted oscillation between fault on and fault off situations Hysteresis GT hysteresis PICK UP LEVEL gt PICK UP Figure 5 3 Behavior of a greater than comparator For example in overvoltage stages the hysteresis dead band acts according this figure Hysteresis_LT hysteresis PICK UP LEVEL l
209. hen force flag is on For details of setting ranges see section Protection functions L1 L2 and L3 are IEC phase names For NEMA the phases are as follows L1 A L2 B and L3 C 63230 218 205 Hecorded values of the latest eight faults There is detailed information available of the eight latest faults Time stamp fault type fault current load current before the fault elapsed delay and setting group 2015 Schneider Electric All rights reserved 13 Current unbalance stage l2 46 in motor mode Section 5 Protection functions Table 5 6 Recorded values of the directional overcurrent stages 8 latest faults gt gt gt gt gt gt gt gt gt gt 67 Parameter Value Description yyyy mm dd Time stamp of the recording date hh mm ss ms Time stamp time of day Type Fault type 1 N Ground fault 2 N Ground fault 3 N Ground fault 1 2 Two phase fault 2 3 Two phase fault 3 1 Two phase fault 1 2 3 Three phase fault 1 2 N Two phase fault with ground contact 2 3 N Two phase fault with ground contact 3 1 N Two phase fault with ground contact 1 2 3 N Three phase fault with ground contact Fit xIn Maximum fault current Load xIn 1 s average phase currents before the fault EDly Elapsed time of the operating time setting 100 trip Angle Fault angle in degrees U1 xUn Positive sequence voltage during fault SetGrp 1 2 Active setting group during fault Direction mode Dir
210. here is a Force flag parameter which when activated allows forcing the status of any protection stage to be start or trip for a half second By using this forcing feature any current or voltage injection to the device is not necessary to check the output matrix configuration to check the wiring from the output relays to the circuit breaker and also to check that communication protocols are correctly transferring event information to a SCADA system After testing the force flag will automatically reset 5 minutes after the last local panel push button activity The force flag also enables forcing of the output relays and forcing the optional mA outputs Force flag can be found in relays menu RELAYS RELAYS Trip relay 1 Trip relay 2 Trip relay 3 Trip relay 4 Signal relay 1 Service status output otart and trip signals Every protection stage has two internal binary output signals start and trip The start signal is issued when a fault has been detected The trip signal is issued after the configured operation delay unless the fault disappears before the end of the delay time Output matrix Using the output matrix the user connects the internal start and trip signals to the output relays and indicators For more details see 2015 Schneider Electric All rights reserved 57 General features of protection stages oection 5 Protection functions Output matrix Blocking Any protection funct
211. hneider Electric All rights reserved 147 Inverse time operation Section 6 Supporting functions Inverse time operation The inverse time operation i e inverse delay minimum time IDMT type of operation is available for several protection functions The common principle formulae and graphic representations of the available inverse delay types are described in this section Inverse delay means that the operation time depends on the measured real time process values during a fault For example with an overcurrent stage using inverse delay a bigger a fault current gives faster operation The alternative to inverse delay is definite delay With definite delay a preset time is used and the operation time does not depend on the size of a fault otage specific inverse delay some protection functions have their own specific type of inverse delay Details of these dedicated inverse delays are described with the appropriate protection function Operation modes There are three operation modes to use the inverse time characteristics Standard delays Using standard delay characteristics by selecting a curve family IEC IEEE IEEE2 RI and a delay type Normal inverse Very inverse etc See the section Standard inverse delays IEC IEEE IEEE2 RI e Standard delay formulae with free parameters selecting a curve family IEC IEEE IEEE2 and defining one s own parameters for the selected delay formula This mode is activated by s
212. ied frequency range is 45 Hz 65 Hz Table 7 8 THD and harmonics Inaccuracy 1 U gt 0 1 PU 2 96 units Update rate Once a second The specified frequency range is 45 Hz 65 Hz Table 7 9 Transducer mA outputs Inaccuracy 20pA the error of the linked value Response time dead time 250 ms time constant r 2 50 ms The transducer outputs are optional See Section 14 Order information 2015 Schneider Electric All rights reserved 63230 218 205 Section 7 Measurement functions RMS values RMS values RMS currents The device calculates the RMS value of each phase current The minimum and the maximum of RMS values are recorded and stored see section Minimum and maximum values 2 2 2 RMS voltages The device calculates the RMS value of each voltage input The minimum and the maximum of RMS values are recorded and stored see section Minimum and maximum values For NEMA U V 2 2 Harmonics Total Harmonic Distortion HD THD 63230 218 205 The device calculates the T HDs as percentage of the base frequency for currents and voltages The device calculates the harmonics from the 2nd to the 15th of phase currents and voltages The 17th harmonic component will also be shown partly in the value of the 15th harmonic component This is due to the nature of digital sampling The harmonic distortion is calculated using equation
213. ights reserved 63230 218 205 Section 5 Protection functions Parameter Undervoltage protection U 27 Table 5 28 Recorded values of the overvoltage stages 8 latest faults V V V gt gt gt Value Description yyyy mm dd Time stamp of the recording date hh mm ss ms Time stamp time of day Maximum fault voltage Elapsed time of the operating time setting 100 trip Active setting group during fault Undervoltage protection V lt 27 63230 218 205 This is a basic undervoltage protection The function measures the three line to line voltages and whenever the smallest of them drops below the user s pick up setting of a particular stage this stage picks up and a start signal is issued If the fault situation remains on longer than the user s operation time delay setting a trip signal is issued Blocking during VT fuse while open As all the protection stages the undervoltage function can be blocked with any internal or external signal using the block matrix For example if the secondary voltage of one of the measuring transformers disappears because of a fuse opening See VT supervision function in the section Voltage transformer supervision The blocking signal can also be a signal from the user s logic see the section Logic functions oelf blocking at very low voltage The stages can be blocked with a separate low limit setting With this setting the particular
214. imeout lo1 peak pu The detected Ip value according the parameter In put below 102 2015 Schneider Electric All rights reserved 63230 218 205 Section 5 Protection functions Intermittent transient ground fault protection gt 67NI Parameter Value Unit Description Note Uo 96 The measured value Uon 100 Direction mode Forward Setting between direction towards line or bus Set Reverse Uo Uo pick up level Uon 100 96 Set gt 0 04 300 S Operation delay setting Set Min peaks 1 20 Minimum number of peaks required Set Reset 0 06 300 S Reset delay setting Set Intrmt S Intermittent time When the next fault occurs within Set this time the delay counting continues from the previous value Set An editable parameter password needed C Can be cleared to zero F Editable when force flag is on For details of setting ranges see section Protection functions Recorded values of the latest eight faults There is detailed information available of the eight latest detected faults Time stamp Vo voltage elapsed delay and setting group Table 5 21 Recorded values of the directional intermittent transient ground fault stage 8 latest faults lojyr 67NI Parameter Value Unit Description yyyy mm dd Time stamp of the recording date hh mm ss ms Time stamp time of day
215. imer is started Each shot from 1 to 5 has its own discrimination time setting If a critical signal is activated during the discrimination time the AR function makes a final trip The CB will then open and the AR sequence is locked Closing the CB manually clears the locked State After the discrimination time has elapsed the reclaim time timer starts If any AR signal is activated during the reclaim time or the discrimination time the AR function moves to the next shot The reclaim time setting is common for every shot lf the reclaim time runs out the auto reclose sequence is successfully executed and the AR function moves to ready state and waits fora new AR request in shot 1 246 2015 Schneider Electric All rights reserved 63230 218 205 Section 8 Control functions Auto reclose function 79 A trip signal from the protection stage can be used as a backup Configure the start signal of the protection stage to initiate the AR function If something does not work to specification in the AR function the trip signal of the protection stage will open the CB The delay setting for the protection stage should be longer than the start delay and discrimination time If a critical signal is used to interrupt an AR sequence the discrimination time setting should be long enough for the critical stage usually at least 100 ms Manual closing A DANGER HAZARD OF ELECTRIC SHOCK EXPLOSION OR ARC FLASH If the relay int
216. imit 0 5 V or 1 03 3 96 Inaccuracy 0 5 V or 3 of the set value Activation Activation block limit Operating time at definite time function 5 of the set value 1 or 30 ms If one of the phase voltages is below sag limit and above block limit but another phase voltage drops below block limit blocking is disabled Table 12 45 Voltage interruptions Voltage low limit U41 10 120 Un Definite time function DT Operating time 60 ms Fixed Reset time 60 ms Reset ratio 1 03 Inaccuracy 3 of the set value Activation 63230 218 205 2015 Schneider Electric All rights reserved 365 Section 13 Construction Section 13 Construction PANEL MOUNTING VAMP 200 SERIES mm PROJECTION MOUNTING VAMP 200 SERIES VYX076 40mm 1 57 169 mm 6 65 Standard for 200 series 20 gt VYX077 60 mm 2 36 149 5 87 Standard for 200 series 0 79 VYX233 100 mm 3 94 109 mm 4 29 2x VYX199 needed Projection mounting B A Panel mounting 2015 Schneider Electric All rights reserved 366 63230 218 205 Section 13 Construction VAMP 200 SERIES WALL ASSEMBLY FRAME TYPE V2OOW AF V200WAF E CN 27 in tb ee ew Nm 63230 218 205 2015 Schneider Electric All rights reserved 36 Section 14 Order Information Section 14 Order information When ordering please state e designation e Quantity
217. ince the device has Clr restarted or since last clearing Tout 0 216 1 Detected timeout errors since the device has Clr restarted or since last clearing Set An editable parameter password needed Clr Clearing to zero is possible 1 The communication parameters are set in the protocol specific menus For the local port command line interface the parameters are set in configuration menu 260 2015 Schneider Electric All rights reserved 63230 218 205 oection 9 Communication Communication ports Hemote port X5 Physical interface The physical interface of this port depends of the communication letter in the order code See Figure 9 1 the section Rear panel connector X5 REMOTE and the table below The TTL interface is for external converters and converter cables only It is not suitable for direct connection to distances more than one meter Physical interface and connector types of remote port X5 with various options TTL A is the default B Plastic fiber interface X HFBRO0500 C Notavailable 4 4 23 d O D QJQhRS485 soate o 1 A screwcnmp O 63230 218 205 2015 Schneider Electric All rights reserved 261 Communication ports Section 9 Communication Table 9 2 Parameters Parameter Value Unit Description Protocol Protocol selection for remote port Set None SPA Command line interface for VAMPSET bus SP
218. ine Scaled minimum 0 V Scaled maximum 15000 V Analog output minimum value 4 mA Analog output maximum value 20 mA Analog mAscaling 2 output Urine 15000 V Figure 7 7 The average of the line to line voltages At 0 V the transducer ouput is 4 mA at 15000 V the output is 20 mA Example of mA scaling for bi directional power Coupling Q Scaled minimum 2000 kVar Scaled maximum 6000 kVar Analog output minimum value 4 mA Analog output maximum value 20 mA Analog mAScaling_3 output mA 2000 6000 kVar Figure 7 8 At 2000 kVar the transducer output is 4 mA at 0 kVar it is 8 mA and at 6000 kVar the output is 20 mA 2015 Schneider Electric All rights reserved 63230 218 205 Section 8 Control functions Output relays Section 8 Control functions Output relays The output relays are also called digital outputs Any internal signal can be connected to the output relays using output matrix An output relay can be configured as latched or non latched See the section Output matrix for more details NOTE If the device has the mA option it is equipped with only three alarm relays from A1 to A3 The difference between trip contacts and alarm contacts is the DC breaking capacity See the section Trip contacts and the section oignal contacts for details The contacts are SPST normal open type except alarm relays A1 A5 which have change over contacts SPD
219. ine voltages One per unit 1 pu 1xUy 100 96 where Uy rated voltage of the VT Line to line voltage scaling Voltage measurement mode 2LL U 1LL U o LLy 2LL LLy LL LLy LLz Voltage measurement mode 3LN secondary per unit VT PRI pe A Lere VE PU PU Visxc Un Uy per unit secondary 7 U sre U py Vl sec Uus 2 230 2015 Schneider Electric All rights reserved 63230 218 205 oection 7 Measurement functions Analog output option Examples Note For NEMA UzV 1 Secondary to per unit Voltage measurement mode is aLL4 Ug VT 12000 110 Voltage connected to the device s input or Up is 110 V Per unit voltage is Upy 110 110 1 00 pu 1 00 x Uy 100 2 Secondary to per unit Voltage measurement mode is 3LN VT 12000 110 Three symmetric phase to neutral voltages connected to the device s inputs Ua Ug and are 63 5 V Per unit voltage is Upy 43 63 5 110 x 12000 11000 1 00 pu 1 00 x Uy 100 Per unit to secondary Voltage measurement mode is 2 0 VT 12000 110 Uy 11000 V The relay displays 1 00 pu 100 secondary voltage is Usec 1 00 x 110 x 11000 12000 100 8 V 4 Perunitto secondary Voltage measurement mode is 3LN VT 12000 110 Uy 11000 V The relay displays 1 00 pu 100 Three symmetric phase to neutral voltages c
220. ing DNP 3 0 protocol The following DNP 3 0 data types are supported e binary input e binary input change e double bit input e binary output e analog input e counters Additional information can be obtained from the DNP 3 0 Device Profile Document and DNP 3 0 Parameters pdf DNP 3 0 communication is activated via menu selection RS 485 interface is often used but also RS 232 and fiber optic interfaces are possible Table 9 12 Parameters Parameter Value Unit Description Set bit s 4800 bps Communication speed Set 9600 default 19200 38400 Parity None default Parity Set Even Odd SlvAddr 1 65519 An unique address for the device within the Set system MstrAddr 1 65519 Address of master Set 255 default LL Tout 0 65535 ms Link layer confirmation timeout Set 63230 218 205 2015 Schneider Electric All rights reserved 973 Communication protocols Section 9 Communication LLRetry 1 255 Link layer retry count 1 default APLTout 0 65535 ms Application layer confirmation timeout Set 5000 z default CnfMode EvOnly default Application layer confirmation mode Set All DBISup No default Double bit input support Set Yes SyncMode 0 65535 S Clock synchronization request interval Set 0 only at boot Set An editable parameter password needed IEC 60870 5 101 The IEC 60870 5 101 standard is derived from the IEC 60870 5 protocol standard
221. ing the natural unbalance current dlo A Compensated unbalance current Display lo gt gt gt lo gt gt gt gt A Setting value Recorded values SCntr Cumulative start counter TCntr Cumulative trip counter Fit pu The max fault value EDly Elapsed time as compared to the set operating time 100 tripping Isaved Recorded natural unbalance current SavedA deg Recorded phase angle of natural unbalance current Faults lo gt gt gt gt only Allowed number of detected detected issues Total lo gt gt gt gt only Actual of detected detected issues in bank Clear lo gt gt gt gt only Clear Clear the element counters L1 B1 lo gt gt gt gt only Number of detected detected issues in phase L1 in brach 1 left side L1 B2 lo gt gt gt gt only Number of detected detected issues in phase L1 in brach 2 right side L2 B1 lo gt gt gt gt only Number of detected detected issues in phase L2 in brach 1 left side L2 B2 lo gt gt gt gt only Number of detected detected issues in phase L2 in brach 2 right side L3 B1 lo gt gt gt gt only Number of detected detected issues in phase L3 in brach 1 left side L3 B2 lo gt gt gt gt only Number of detected detected issues in phase L3 in brach 2 right side Locat lo gt gt gt gt only Changed unbalance current after automatic compensation LocAng lo gt gt gt gt only
222. ion Adapting auto adjust During tens of hours of synchronizing the device will learn its average deviation and starts to make small corrections by itself The target is that when the next synchronizing message is received the deviation is already near zero Parameters AAIntv and AvDrft will show the adapted correction time interval of this 1 ms auto adjust function Time drift correction without external sync If any external synchronizing source is not available and the system clock has a known steady drift it is possible to roughly correct the clock deviation by editing the parameters and AvDrft The following equation can be used if the previous AAIntv value has been zero 604 8 AAlntv DriftInOneWeek If the auto adjust interval AAIntv has not been zero but further trimming is still needed the following equation can be used to calculate a new auto adjust interval 1 AAInt __ MEV NEW DriftInOneWeek AAT 604 8 2015 Schneider Electric All rights reserved 63230 218 205 Section 6 Supporting functions System clock and synchronization 63230 218 205 The term DriftinOneWeek 604 8 may be replaced with the relative drift multiplied by 1000 if some other period than one week has been used For example if the drift has been 37 seconds in 14 days the relative drift is 37 1000 14 24 3600 0 0306 ms s Example 1 If there has been n
223. ion except arc detection can be blocked with internal and external signals using the block matrix the section Blocking matrix Internal signals are for example logic outputs and start and trip signals from other stages and external signals are for example digital and virtual inputs some protection stages also have built in blocking functions For example under frequency protection has built in under voltage blocking to avoid tripping when the voltage is off When a protection stage is blocked it won t pick up in case a fault condition is detected If blocking is activated during the operation delay the delay counting is frozen until the blocking goes off or the pick up reason i e the fault condition disappears If the stage is already tripping the blocking has no effect Retardation time Retardation time is the time a protection relay needs to detect that a fault has been cleared during the operation time delay This parameter is important when calculating the operation time delay settings between relays RetardationTime DELAY SETTING gt trer EP TRIP CONTACTS m aa n BH n Figure 5 1 Definition for retardation time If the delay setting would be slightly shorter an unselective trip might occur the dash line pulse 56 2015 Schneider Electric All rights reserved 63230 218 205 oection 5 Protection functions General features
224. is 45 65 Hz Low voltage blocking is checking the maximum of line to line voltages Definite time function operating time 0 10 300 0 s step 0 02 s Start time 100 ms Heset time 120 ms Reset ratio f gt and f gt gt 0 998 Reset ratio f lt and f lt lt 1 002 Reset ratio LV block Instant no hysteresis Inaccuracy Starting starting LV block operating time 20 mHz 3 of the set value or 0 5 V 1 or 30 ms NOTE If device restarts for some reason there will be no trip even if the frequency is below the set limit during the start up Start and trip is blocked To cancel this block frequency has to rise above the set limit 2015 Schneider Electric All rights reserved 63230 218 205 Section 12 Technical data Protection functions Table 12 35 Underfrequency stages f f 81L Frequency measuring area 16 0 75 0 Hz Current and voltage meas range 45 0 65 0 Hz Frequency stage setting range 40 1 64 0 Hz Low voltage blocking 10 100 Un Suitable frequency area for low voltage blocking is 45 65 Hz Low voltage blocking is checking the maximum of line to line voltages Definite time function operating time 0 10 300 0 s step 0 02 s Undervoltage blocking 2 100 96 otart time 100 ms Reset time 120 ms Reset ratio 1 002 Reset ratio LV block Instant no hysteresis
225. is function cannot be used simultaneously with normal group change Directional phase overcurrent lI 67 Directional overcurrent protection can be used for directional short circuit protection Typical applications are e Short circuit protection of two parallel cables or overhead lines in a radial network e Short circuit protection of a looped network with single feeding point e Short circuit protection of a two way feeder which usually supplies loads but is used in special cases as an incoming feeder e Directional overcurrent protection in low impedance grounded networks Please note that in this case the device has to be connected to line to neutral voltages instead of line to line voltages In other words the voltage measurement mode has to be 3LN See section Voltage measurement modes The stages are sensitive to the amplitude of the highest fundamental frequency current of the three measured phase currents In phase to phase and in three phase faults the fault angle is determinded by using angles between positive sequence of currents and voltages In phase to ground faults the fault angle is determinded by using fault phase current and the healthy line to line voltage For details of power direction see section Direction of power and Current A typical characteristic is shown in Figure 5 8 The base angle setting is 30 The stage will pick up if the tip of the three phase current phasor gets into the grey area
226. isturbance record and select Open A 2 Select the comtrade file from you hard disc or equivalent VAMPSET is now ready to read the recording he virtual measurement has to be enabled B in order to send record data to the relay C 4 Sending the file to the device s memory takes a few seconds Initiate playback of the file by pressing the Go button D The Change to control mode button takes you back to the virtual measurement Ij Ernie ciiin omaes dr dw js NOTE The sample rate of the comtrade file has to be 32 cycle 625 micro seconds when 50 Hz is used The channel names have to correspond to the channel names in Vamp relays 1 lj lj 103 loo Uy Uos Ui 4 Ui Ui 5 and Uo NEMA L1 A L2 B L3 C U V 172 2015 Schneider Electric All rights reserved 63230 218 205 Section 6 Supporting functions Cold load pick up and inrush current detection Cold load pick up and inrush current detection 63230 218 205 NOTE Cold load pick up A situation is regarded as cold load when all the three phase currents have been less than a given idle value and then at least one of the currents exceeds a given pick up level within 80 ms In such case the cold load detection signal is activated for a given time This signal is available for output matrix and blocking matrix Using virtual outputs of the output matrix setting group control is possible Application for cold load detection
227. it pu values for pick up setting are based on the current transformer values Arcl 1 pu 1xly rated phase current CT value Arclg4 1 pu 1xlg4N rated residual current CT value for input 101 02 gt 1 1xlooy rated residual current CT value for input Table 5 49 Parameters of arc detection stages Arcl Arclo gt Arclge 50ARC 50NARC Parameter Value Unit Description Note Status Current status of the stage Start Light detected according Arcly F Trip Light and overcurrent detected LCntr Cumulative light indication counter S1 S2 or BI C SCntr Cumulative light indication counter for the selected in C puts according parameter Arcly TCntr Cumulative trip counter C Force Off Force flag for status forcing for test purposes This is a Set common flag for all stages and output relays On Automatically reset by a 5 minute timeout Value of the supervised signal ILmax Stage Arcl gt lo1 Stage Arclo lo2 Stage Arcloo gt 146 2015 Schneider Electric All rights reserved 63230 218 205 Section 5 Protection functions Arc fault protection 50ARC 50NARC optional Parameter Value Unit Description Note Arcl gt p Pick up setting Set u Pick up setting xlo4w 5 Pick up setting xloow Arclin Light indication source selection Set No sensor selected S1 Sensor 1 at terminals X6
228. ive exported power is 1900 kW Peak active exported power is 50 MW Pulse size is 10 kWh The average pulse frequency will be 1900 10 2 190 pulses h The peak pulse frequency will be 50000 10 5000 pulses h Set pulse length to 3600 5000 0 2 0 5 sor less The lifetime of the mechanical output relay will be 50x106 190 h 30 years 2015 Schneider Electric All rights reserved 189 Energy pulse outputs VAMP relays Active exported energy pulses E Reactive exported energy pulses 4 Active imported _ energy pulses Reactive imported _ energy pulses Eq oection 6 Supporting functions PLC Pulse counter input 1 Pulse counter input 2 Pulse counter input 3 Pulse counter input 4 Figure 6 6 Application example of wiring the energy pulse outputs to a PLC having common plus and using an external wetting voltage VAMP relays Active exported energy pulses Reactive exported energy pulses Fy Active imported p energy pulses Reactive imported F energy pulses PLC Pulse counter input 1 Pulse counter input 2 Pulse counter input 3 Pulse counter input 4 Figure 6 7 Application example of wiring the energy pulse outputs to a PLC having common minus and using an external wetting voltage VAMP relays Active exported energy pulses Reactive exported p energy pulses Activeimported energ
229. l show the active parameter values for the local port Physical interface The physical interface of this port is RS 232 63230 218 205 2015 Schneider Electric All rights reserved 259 Communication ports Table 9 1 Parameters Section 9 Communication Parameter Value Unit Description Note Protocol Protocol selection for the rear panel local port Set None Command line interface for VAMPSET SpaBus SPA bus slave ProfibusDP Profibus DB slave ModbusSla Modbus RTU slave ModbusTCPs IEC Modbus TCP slave 103 IEC 60870 5 103 slave ExternallO Modbus RTU master for external I O modules DNP3 DNP 3 0 Msg 0 232 1 Message counter since the device has restarted Clr or since last clearing Errors 0 216 1 Detected protocol errors since the device has Clr restarted or since last clearing Tout 0 216 1 Detected timeout errors since the device has Clr restarted or since last clearing Display of actual communication parameters 1 speed DPS Speed bit s Default 38400 8N1 for VAMPSET D number of data bits P parity none even odd S number of stop bits VAMPSET communication Direct or SPA bus embedded command line interface TX bytes size Unsent bytes in transmitter buffer size of the buffer Msg 0 232 1 Message counter since the device has restarted Clr or since last clearing Errors 0 216 1 Detected errors s
230. lay setting a trip signal is issued Blocking during VT fuse opening As all the protection stages the undervoltage function can be blocked with any internal or external signal using the block matrix For example if the secondary voltage of one of the measuring transformers disappears because of a fuse opening See VT supervision function in the section Voltage transformer supervision The blocking signal can also be a signal from the user s logic see the section Logic functions oelf blocking at very low voltage The stages can be blocked with a separate low limit setting With this setting the particular stage will be blocked when the biggest of the three line to line voltages drops below the given limit The idea is to avoid purposeless tripping when voltage is switched off If the operating time is less than 0 08 s the blocking level setting should not be less than 1596 for the blocking action to be fast enough The self blocking can be disabled by setting the low voltage block limit equal to zero Figure 5 34 shows an example of low voltage self blocking V 535 Va UunderSelfBlocking dead band V setting block limit time Figure 5 34 Under voltage state and block limit 63230 218 204 2014 Schneider Electric All rights reserved 119 Undervoltage protection U 27 The maximum of the three line to line voltages Vi max is below the block limit
231. le t2 when U gt 1V and lo 5 of lon or gt 50 mA else 20 Operate time at definite time function 1 or 30 ms Operate time at IDMT function 5 or at least 30 ms L1 L2 and L3 are IEC phase names L2 B and L3 C 2015 Schneider Electric All rights reserved For NEMA the phases are as follows L1 A 63230 218 205 Section 12 Technical data Protection functions Frequent start protection Table 12 22 Frequent start protection N 66 Settings Max motor starts 1 20 Min time between motor starts 1 1 100 min step 0 1 min Operation time 250 ms Inaccuracy Min time between motor starts 5 of the set value Voltage protection Table 12 23 Overvoltage stage U 59 Overvoltage setting range 50 150 Un The measurement range is up to 160 V This limit is the maximum usable setting when rated VT secondary is more than 100 V Definite time characteristic operating time 0 08 300 00 s step 0 02 Hysteresis 0 99 0 800 0 1 20 0 95 step 0 1 96 Start time Typically 60 ms Release delay 0 06 300 00 s step 0 02 Reset time lt 95 ms Retardation time 50 ms Inaccuracy starting 3 of the set value operate time 1 or 30 ms Table 12 24 Overvoltage stage U 59 Overvoltage setting range 50 150 Un The measurement range is up to 160 V This li
232. le 5 1 Parameters of the overcurrent stage I gt 50 51 Parameter Value Unit Description Note Status Current status of the stage Blocked otart F Trip F TripTime S Estimated time to trip SCnir Cumulative start counter Clr TCntr Cumulative trip counter Clr SetGrp Tore Active setting group Set SGrpDI Digital signal to select the active setting group et Dix Digital input VIx Virtual input LEDx LED indicator signal VOx Virtual output Force flag for status forcing for test purposes This is a common flag for all stages and output relays This flag is automatically On reset 5 minutes after the last front panel push button pressing ILmax A The supervised value Max of IA IB and IC A Pick up value scaled to primary value gt xlmode Pick up setting Set Curve Delay curve family Set DT Definite time IEC IEEE Inverse time See Inverse time operation IEEE2 RI PrgN Type Delay type Set DT Definite time NI VI El LTI Inverse time See Inverse time operation Parameters gt Definite operation time for definite time only Set k gt Inverse delay multiplier for inverse time only Set Dly20x S Delay at 20xImode Dly4x S Delay at 4xlmode Dly2x S Delay at 2xlmode Dly1x S Delay at 1xlmode User s constants for standard equations Type Parameters Section Inverse time operation Set An editable parameter password needed C Can be
233. led burning time or discrimination time A high speed shot means that the dead time is less than 1 s The time delayed shot means longer dead times up to 2 3 minutes 2015 Schneider Electric All rights reserved 244 63230 218 205 oection 8 Control functions Controllable objects There are four AR lines A line means an initialization signal for AR Normally start or trip signals of protection functions are used to initiate an AR sequence Each AR line has a priority AR1 has the highest and AR4 has the lowest one This means that if two lines are initiated at the same time AR will follow only the highest priority line A very typical configuration of the lines is that the instantaneous overcurrent stage will initiate the AR1 line time delayed overcurrent stage the AR2 line and ground fault protection will use lines ARS and ARA For more information about auto reclosing please refer to our application note Auto reclosing function in VAMP protection relays The auto reclose AR matrix in the following Figure 8 4 describes the start and trip signals forwarded to the auto reclose function 63230 218 205 2015 Schneider Electric All rights reserved 245 Auto reclose function 79 Section 8 Control functions AR matriix j Headgy GS uead ume viscrimiation ume e v g Waitfor oc 6 22 time 6 O p Ur SOUS c
234. led Trip on event Enabled Disabled Enabled Trip off event Table 5 8 Measured and recorded values of of the current unbalanced stagel gt 46 in feeder mode Parameter Value Unit Description Measured value 12 11 Relative negative sequence component Recorded values SCntr Cumulative start counter TCntr Cumulative start counter Flt Maximum 12 1 fault component EDly Elapsed time as compared to the set oper ating time 100 tripping 63230 218 205 2015 Schneider Electric All rights reserved 15 Current unbalance stage I2 gt 46 in motor mode Section 5 Protection functions Current unbalance stage l2 46 in motor mode 76 Equation 5 1 Current unbalance in a motor causes double frequency currents in the rotor This warms up the surface of the rotor and the available thermal capacity of the rotor is much less than the thermal capacity of the whole motor Thus an rms current based overload protection see section Thermal overload protection gt 49 is not capable to protect a motor against current unbalance The current unbalance protection is based on the negative sequence of the base frequency phase currents Both definite time and inverse time characteristics are available Inverse delay The inverse delay is based on the following equation T Operation time Delay multiplier l5 Measured and calculated negative sequence ph
235. led manually or using any of the digital inputs virtual inputs virtual outputs or LED indicator signals By using virtual I O the active setting group can be controlled using the local panel display any communication protocol or using the built in programmable logic functions Forcing start or trip condition for testing The status of a protection stage can be one of the followings Ok ss The stage is idle and is measuring the analog quantity for the protection No fault detected e Blocked The stage is detecting a fault but blocked by some reason e Start The stage is counting the operation delay e Trip The stage has tripped and the fault is still on The blocking reason may be an active signal via the block matrix from other stages the programmable logic or any digital input Some stages also have built in blocking logic For more details about block matrix see Blocking matrix 2015 Schneider Electric All rights reserved 63230 218 205 Section 5 Protection functions General features of protection stages 63230 218 205 A DANGER HAZARD OF ELECTRIC SHOCK EXPLOSION OR ARC FLASH Forcing a contact should only be used while testing and not in real time All interlocking and blockings are bypassed when the forced control is used This should only be done with full awareness of the consequences of the action Failure to follow these instructions will result in death serious injury or equipment damage T
236. load stage 49 4 20 2015 Schneider Electric All rights reserved 63230 218 205 section 2 Local panel user interface Local panel operations Main menu Number of menus Description ANSI code Note Uc 4 Capacitor O V stage 59C 4 lo 5 1st ground fault stage 50N 51N 4 lo gt gt 3 2nd ground fault stage 50N 51N 4 lo gt gt gt 3 3rd ground fault stage 50N 51N 4 lo gt gt gt gt 3 4th ground fault stage SON 51N 4 gt 6 1st directional ground fault stage 67N 4 lop gt gt 6 2nd directional ground fault stage 67N 4 loint gt 4 Transient intermittent E F 67NI 4 U 4 1st overvoltage stagea 59 4 U gt gt 3 2nd overvoltage staged 59 4 U gt gt gt 3 3rd overvoltage stagen 59 4 U lt 4 1st undervoltage stagen 27 4 U lt lt 3 2nd undervoltage stagea 27 4 U lt lt lt 3 3rd undervoltage stagen 27 4 U1 4 1st positive sequence undervoltage 27P 4 U1 4 2nd positive sequence undervoltage stagea 27P 4 Uo 3 1st residual overvoltage staged 59N 4 Uo gt gt 3 2nd residual overvoltage stagea 59 4 lt 3 1st reverse and underpower stage 32 4 P 3 2nd reverse and underpower stage 32 4 gt lt 4 1st over under frequency stage 81 4 gt gt lt lt 4 2nd over under frequency stage 81 4 f lt 4 1st underfrequency stage 81L 4 lt lt 4 2nd underfrequency stage 81L 4 dfdt 3 Rate of change of frequenc
237. lock limit 0 5 V or 1 03 3 96 Heset ratio 1 3 depends on the hysteresis setting Inaccuracy starting blocking operate time 3 of the set value 3 of set value or 0 5 V 1 or 25 ms 2015 Schneider Electric All rights reserved 35 Protection functions Section 12 Technical data Table 12 29 Zero sequence voltage stage Ug 59N Zero sequence voltage setting range 1 60 Uon Definite time function Operating time 0 3 300 0 s step 0 1 s Start time Typically 200 ms Heset time 450 ms Heset ratio 0 97 Inaccuracy Starting 2 of the set value or 0 3 of the rated value Starting UoCalc 3LN mode 1 V Operate time 1 or 150 ms Table 12 30 Zero sequence voltage stage Ug 59N Zero sequence voltage setting range 1 60 Uon Definite time function Operating time 0 08 300 0 s step 0 02 s Start time Typically 60 ms Heset time 95 ms Heset ratio 0 97 Inaccuracy Starting 2 of the set value or 0 3 of the rated value Starting Uocaic BLN mode 1 V Operate time 1 or 30 ms Circuit breaker failure protection CBFP 50BF Table 12 31 Circuit breaker failure protection CBFP 50BF Relay to be supervised T1 Tn depending the order code Definite time function Operating time 0 1 10 0 s step 0 1 s
238. lowing table Description IL1 IL2 IL3 Phase current fundamental frequency value lo1 lo2 Residual current Apparent power Active power Reactive power L1 L2 and L3 are IEC phase names For NEMA the phases are as follows L1 A L2 B and L3 C The value can be a one cycle value or an average based on the Timebase parameter Table 7 12 Parameters of the day and month registers Parameter Value Description Set Timebase Parameter to select the type of the registered values Set 20ms Collect min amp max of one cycle values 200 ms_ Collect min amp max of 200 ms average values 1s Collect min amp max of 1 s average values 1min Collect min amp max of 1 minute average values demand Collect min amp max of demand values see section Demand values ResetDays Reset the 31 day registers Set ResetMon Reset the 12 month registers Set 63230 218 205 This is the fundamental frequency rms value of one cycle updated every 20 ms 2015 Schneider Electric All rights reserved 215 Voltage measurement nodes Section 7 Measurement functions Voltage measurement modes Depending on the application and available voltage transformers the relay can be connected either to line to line voltages or phase to ground voltages The configuration parameter Voltage measurement mode must be set according the connection used e 2LL Uo The device
239. ltage of the auxiliary relay is selected according the rated auxiliary voltage used in the trip circuit The operating voltage range of the relay should be as wide as possible to cover the tolerance of the auxiliary voltage In this application using the other wet inputs for other purposes is not limited unlike when using the dry inputs 2015 Schneider Electric All rights reserved 63230 218 205 Section 11 Connections Rear panel V 110 Vdc VAMP 2xx relay Digital input 1 6 Trip relay Alarm relay for trip trip circuit circuit failure failure alarm relay compariment circuit breaker compariment close control Relay K1 Phoenix Contact EMG 17 REL KSR 120 21 21 LC Au Coil 96 127 V 20 Width 17 5 mm Assembly EN 50022 mounting rail V ux OPEN COIL V aux CLOSE COIL TCS1Dl closed Figure 10 10 Trip circuit supervision using one of the VAMP 200 series internally wetted digital input DI1 DI6 and auxiliary relay K1 and an external resistor The circuit breaker is in the closed position The supervised circuitry in this CB position is double lined The digital input is in active state when the trip circuit is complete DIGITAL INPUTS DIGITAL INPUTS Figure 10 11 An example of digital input DI1 configuration for trip circuit supervision with one wet digital input 63230 218
240. ly activated object starts to blink select the Local Remote object the letters L or R with a square box around the letter by using arrow keys 2 Push The L R dialog opens Select REMOTE to enable remote control and disable local control Select LOCAL to enable local control and disable remote control Confirm the setting by pushing E The Local Remote state will change 2015 Schneider Electric All rights reserved 63230 218 205 oection 2 Local panel user interface Operating measures 63230 218 205 Object control 1 2 Push The previously activated object starts to blink Select the object to control by using arrow keys Please note that only controllable objects can be selected Push A control dialog opens select the Open or Close command by using the or A Confirm the operation by pushing The state of the object changes Toggling virtual inputs 1 2 4 Push The previously activated object starts to blink select the virtual input object empty or black square The dialog opens Select Vion to activate the virtual input or select Vloff to deactivate the virtual input 2015 Schneider Electric All rights reserved 31 Configuration and parameter setting oection 2 Local panel user interface Measured data The measured values can be read from the P E and U menus and their submenus Furthermore any measurement value in the following t
241. mat On ically reset by a 5 minute timeout ILmax A The supervised value Max of IA IB and IC 63230 218 205 2015 Schneider Electric All rights reserved 71 Directional phase overcurrent gt 67 Section 5 Protection functions Parameter Unit Description Ip gt gt A Pick up value scaled to primary value Ig Ip xlmode Pick up setting Delay curve family DT Definite time IEC IEEE Inverse time See the section Inverse time operation IEEE2 RI PrgN Delay type DT Definite time NI VI El LTI Inverse time See the section Inverse time operation Parameters gt Definite operation time for definite time only Set gt Inverse delay multiplier for inverse time only Set Dly20x S Delay at 20xImode Dly4x S Delay at 4xlmode Dly2x S Delay at 2xlmode Dly1x S Delay at 1xlmode Mode Dir Directional mode 67 Set Undir Undirectional 50 51 Dir back up Directional and undirectional back up Offset Angle offset in degrees Set U I angle i Measured U l angle U1 Un Measured positive sequence voltage A B C D E User s constants for standard equations Type Parameters Set See Chapter 5 30 Inverse time operation Set An editable parameter password needed C Can be cleared to zero F Editable when force flag is on For details of setting ranges see section Protection functions L1 L2 and L3 are IEC phase names For NE
242. matrix This can be done in main menu DO although the VAMPSET program is recommended for output matrix editing Configure the needed digital inputs in main menu DI Configure blocking and interlockings for protection stages using the block matrix This can be done in main menu Prot although VAMPSET is recommended for block matrix editing Some of the parameters can only be changed via the RS 232 serial port using the VAMPSET software Such parameters for example passwords blockings and mimic configuration are normally set only during commissioning 38 2015 Schneider Electric All rights reserved 63230 218 205 oection 2 Local panel user interface Configuration and parameter setting 63230 218 205 oome of the parameters require the restarting of the relay This restarting is done automatically when necessary If a parameter change requires restarting the display will show as Figure 2 15 Plck PROTOCOL Change will cause autoboot Press CANCEL Figure 2 15 Example of auto reset display Press to return to the setting view If a parameter must be changed press again The parameter can now be set When the parameter change is confirmed with C3 a RESTART text appears to the top right corner of the display This means that auto resetting is pending If no key is pressed the auto reset will be executed within few seconds 2015 Schneider Electric All rights reserved 39 Configuration and param
243. me or inverse time characteristic See section Inverse time operation for details of the available inverse delays Stages gt gt gt and gt gt gt gt have definite time DT operation delay The device will show a scaleable graph of the configured delay on the local panel display Inverse time limitation The maximum measured secondary current is 5O0xly This limits the scope of inverse curves with high pick up settings See section Inverse time operation for more information Cold load and inrush current handling oee section Cold load pick up and inrush current detection Setting groups There are two settings groups available for each stage Switching between setting groups can be controlled by digital inputs virtual inputs mimic display communication logic and manually Table 5 4 Parameters of the directional overcurrent stages lo ly 67 Parameter Value Unit Description Note Status Current status of the stage Blocked Start F Trip TripTime Estimated time to trip SCntr Cumulative start counter Clr TCntr Cumulative trip counter Clr SetGrp 1or2 Active setting group Set SGrpDI Digital signal to select the active setting group Set None DIx Digital input VIx Virtual input LEDx LED indicator signal VOx Virtual output Force Off Force flag for status forcing for test purposes This is a Set common flag for all stages and output relays Auto
244. me very inverse 28 55 0 712 Long time extremely inverse 64 07 0 250 Moderately inverse 0 0515 0 1140 Very inverse 19 61 0 491 Extremely inverse 28 2 0 1217 Short time inverse 0 16758 0 11858 Short time extremely inverse 1 281 0 005 63230 218 205 2015 Schneider Electric All rights reserved 155 Inverse time operation Section 6 Supporting functions Example for Delay type Moderately inverse MI 0 50 4 IPickuP 2 pu 0 0515 B 0 114 0 02 0 50 0 0515 4 5 a 102 The operation time in this example will be 1 9 seconds The same result can be read from Figure 5 52 600 IEEE LTI 50 IEEE LIVI 400 400 200 200 100 100 80 MT 80 60 1 60 20 k 10 20 k 20 10 _ 10 zu 2 5 2 8 10 6 wa 6 5 m 4 k 2 4 Cd 2 k 1 2 k 2 1 _ 1 0 8 k 0 5 0 8 k 1 0 6 0 6 0 4 0 4 k 0 5 0 2 0 2 0 1 0 1 0 08 0 08 0 06 0 06 1 2 3 4 5678 10 20 1 2 3 4 5678 10 20 I Iset DN I Iset Figure 5 49 ANSI IEEE long time inverse delay Figure 5 50 ANSI IEEE long ti
245. me very inverse delay 156 2015 Schneider Electric All rights reserved 63230 218 205 Section 5 Protection functions IEEE LTEI 600 400 200 100 60 40 20 k 20 k 10 k 5 delay s k 2 k 1 k 0 5 0 2 0 1 0 08 0 06 Figure 5 51 ANSI IEEE long time extremely inverse Figure 5 52 ANSI IEEE moderately inverse delay delay 3 4 56 I Iset 7 8 10 20 IEEE STI 600 400 200 100 k 20 60 40 k 10 20 k 5 k 2 k 1 delay s k 0 5 0 2 0 1 0 08 0 06 Figure 5 53 ANSI IEEE short time inverse delay 63230 218 205 3 4 5678 I Iset 10 20 TL Inverse time operation IEEE MI 600 400 200 100 k 20 k 10 k 5 k delay s k 1 0 6 k 0 5 0 4 0 2 0 1 0 08 0 06 3 4 5 6 I Iset 7 8 10 20 IEEE STEI 600 400 200 100 delay s
246. mes full Stage is released 63230 218 205 2015 Schneider Electric All rights reserved 101 Intermittent transient ground fault protection loinT gt Block Setting groups Section 5 Protection functions There are two settings groups available Switching between setting groups can be controlled by digital inputs virtual inputs mimic display communication logic and manually Setting U pick up i0TBlock I TRANSIENT ALGORITHM Setting Setting Enable Operation delay Intermittent events Peak amount time Start Trip f Redster event Figure 5 28 Block diagram of the directional intermittent transient ground fault stage loint gt Table 5 20 Parameters of the directional intermittent transient ground fault stage loint gt 67NI Parameter Value Unit Description Note Status Current status of the stage Blocke d Start F Trip SCntr Cumulative start counter Clr TCntr Cumulative trip counter Clr SetGrp 1or2 Active setting group Set SGrpDI Digital signal to select the active setting group Set None DIx Digital input VIx Virtual input LEDx LED indicator signal VOx Virtual output lo input lo1Peak lo Connectors 1 7 amp 8 Set lo2Peak lo Connectors X 1 9 amp 10 Force Off Force flag for status forcing for test purposes This Set is a common flag for all stages and output relays On Automatically reset after a five minute t
247. mes the setting However there are limitations at high setting values due to the measurement range See the section Inverse time operation for more details 164 2015 Schneider Electric All rights reserved 63230 218 205 Section 6 Supporting functions Event log oection 6 Supporting functions Event log 63230 218 205 Event log is a buffer of event codes and time stamps including date and time For example each start on start off trip on or trip off of any protection stage has a unique event number code Such a code and the corresponding time stamp is called an event The event codes are listed in a separate document Modbus Profibus Spabus_event pdf As an example of information included with a typical event a programmable stage trip event is shown in the following table EVENT Description Local panel Communication protocols Code 1E2 Channel 30 event 2 Yes Yes I gt trip on Event text Yes 2 7 x In Fault value Yes 2007 01 31 Date Yes Yes 08 35 13 413 Time Yes Yes Type U12 23 31 Fault type Yes Events are the major data for a SCADA system SCADA systems are reading events using any of the available communication protocols Event log can also be scanned using the front panel or using VAMPSET With VAMPSET the events can be stored to a file especially in case the relay is not connected to any SCADA system Only the latest event can be read when using communication prot
248. meter setting Section 2 Local panel user interface Forced control Force A DANGER HAZARD OF ELECTRIC SHOCK EXPLOSION OR ARC FLASH Forcing a contact should only be used while testing and not in real time All interlocking and blockings are bypassed when the forced control is used This should only be done with full awareness of the consequences of the action Failure to follow these instructions will result in death serious injury or equipment damage In some menus it is possible to switch a function on and off by using a force function This feature should be used for testing a certain function The force function can be activated as follows 1 Move to the setting state of the desired function for example DO see Configuration and parameter setting 2 Select the Force function the background color of the force text is black force Pick RELAY OUTPUTS 1 Fnable forcing T1 Figure 2 14 Selecting Force function Push Push the or KB to change the OFF text to ON that is to activate the Force function Push KE to return to the selection list Choose the signal to be controlled by force with the and Vv for instance the T1 signal 6 Push KB to confirm the selection oignal T1 can now be controlled by force Push the or to change the selection from 0 not alert to 1 alert or vice versa 36 2015 Schneider Electric All rights reserved 63230 218 205 oection 2 Local pa
249. mit is the maximum usable setting when rated VT secondary is more than 100 V Definite time characteristic operating time 0 06 300 00 s step 0 02 Hysteresis 0 99 0 800 0 1 20 0 96 step 0 1 96 Start time Typically 60 ms Reset time 95 ms Retardation time lt 50 ms Inaccuracy starting 3 of the set value operate time 1 or 30 ms 63230 218 205 2015 Schneider Electric All rights reserved 355 Protection functions 356 Section 12 Technical data Table 12 25 Overvoltage stage U 59 Overvoltage setting range 50 160 Un The measurement range is up to 160 V This limit is the maximum usable setting when rated VT secondary is more than 100 V Definite time characteristic operating time 0 04 300 00 s step 0 01 Hysteresis 0 99 0 800 0 1 20 0 95 step 0 1 96 Start time Typically 30 ms Reset time 95 ms Retardation time 50 ms Inaccuracy starting 3 of the set value operate time 1 or 25 ms Table 12 26 Undervoltage stage U 27 Undervoltage setting range 20 120 96UN Definite time characteristic operating time 0 08 300 00 s step 0 02 Hysteresis 1 001 1 200 0 1 20 0 96 step 0 1 96 Self blocking value of the undervoltage 0 80 Un Start time Typically 60 ms Release delay 0 06 300 00 s step 0 02 s Heset time 95 ms Retardation time
250. mittent transient ground fault stage lojyr 67NI Input selection for l peak signal loi Connectors X1 7 8 lo Connectors X1 9 10 lo peak pick up level fixed 0 1 pu 50 Hz Uo pickup level 1 60 Uon Definite operating time 0 12 300 00 s step 0 02 Intermittent time 0 00 300 00 s step 0 02 Start time lt 60 ms Reset time lt 60ms Reset ratio hysteresis for Uo 0 97 Inaccuracy starting 3 for Ug No inaccuracy defined for lo transients time 1 or 30 ms The actual operation time depends of the intermittent behavior of the fault and the intermittent time setting 63230 218 205 L1 L2 and L3 are IEC phase names For NEMA the phases are as follows L1 A L2 B and L3 C 2015 Schneider Electric All rights reserved 391 Protection functions Directional current protection 352 Section 12 Technical data Table 12 19 Directional overcurrent stages l5 gt gt 67 Pick up current 0 10 4 00 x IMODE Mode Directional Directional BackUp Minimum voltage for the direction solving 2 VsECONDARY Base angle setting range 180 4179 Operation angle 88 Definite time function Operating time 0 04 300 00 s step 0 02 s IDMT function Delay curve family Curve type Time multiplier k DT IEC IEEE RI Prg El VI NI LTI MI d
251. mode The directional intermittent transient ground fault protection is used to detect short intermittent transient faults in compensated cable networks The transient faults are self extinguished at some zero crossing of the transient part of the fault current Ira and the fault duration is typically only 0 1 ms 1 ms Such short intermittent faults can not be correctly recognized by normal directional ground fault function using only the fundamental frequency components of ly and Vo Although a single transient fault usually self extinguishes within less than one millisecond in most cases a new fault happens when the phase to ground voltage of the detected faulty phase has recovered Figure 5 24 NOTE L1 L2 and L3 are IEC phase names For NEMA the phases are as follows L1 A L2 B and L32C U V 0 50 100 150 200 Time ms Figure 5 24 Typical phase to ground voltages residual current of the detected faulty feeder and the zero sequence voltage Vo during two transient ground faults in phase A In this case the network is compensated 2015 Schneider Electric All rights reserved 63230 218 205 Section 5 Protection functions 63230 218 205 Direction algorithm The function is sensitive to the instantaneous sampled values of the residual current and zero sequence voltage The selected voltage measurement mode has to include a direct Vy measurement l pick up sensitivity The sampling time interv
252. must be measured and the number of the samples per period must be controlled accordingly so that the number of the samples per period remains constant if the frequency changes Therefore secondary testing of a brand new device should be started with voltage protection functions and voltage injection to let the relay learn the local frequency However if this is not possible then the frequency must be set on the device either to 50 or 60 Hz Apart from the FFT calculations some protection functions also require the symmetrical components to be calculated for obtaining the positive negative and zero phase sequence components of the measured quantity For example the function of the unbalanced load protection stage is based on the use of the negative phase sequence component of the current Figure 4 2 shows a principle block diagram of a numerical device The main components are the energizing inputs digital input elements output relays A D converters and the micro controller including memory circuits Further a device contains a power supply unit and a human machine interface HMI Figure 4 3 shows the heart of the numerical technology That is the main block diagram for calculated functions Figure 4 4 shows a principle diagram of a single phase overvoltage function 2015 Schneider Electric All rights reserved 63230 218 205 Section 4 Introduction Principles of numerical protection techniques K211 Display and key b
253. n or EB 2006 09 14 Date of the log 12 25 10 288 Time of the log Type 1 2 The overcurrent fault has been detected in phases A and B Fit 2 86xly The fault current has been 2 86 per unit Load 0 99xly The average load current before the fault has been 0 99 pu EDly 81 The elapsed operation delay has been 81 of the setting 0 60 s 0 49 s Any registered elapsed delay less than 100 means that the stage has not tripped because the fault duration has been shorter that the delay setting SetGrp 1 The setting group has been 1 This line can be reached by pressing and several times GZ 2015 Schneider Electric All rights reserved 25 Configuration and parameter setting Section 2 Local panel user interface Setting groups 26 Most of the protection functions of the relay have two setting groups These groups are useful for example when the network topology is changed frequently The active group can be changed by a digital input through remote communication or locally by using the local panel The active setting group of each protection function can be selected separately Figure 2 7 shows an example where the changing of the gt setting group is handled with digital input one SGrpDI If the digital input is TRUE the active setting group is group two and correspondingly the active group is group one if the digital input is FALSE If no digital input is selected SGrpDI the active group can be s
254. n connector 63230 218 205 Section 11 Connections Terminal X2 with analog output 3 6 63230 218 205 O N OO A CO 10 11 12 13 14 15 16 7 18 Symbol AQ1 AO1 2 AQ2 AQ3 AO3 4 4 2 A2 NC A2 NO SF COM SF NC SF NO Rear panel Description Analog output 1 positive connector Analog output 1 negative connector Analog output 2 positive connector Analog output 2 negative connector Analog output 3 positive connector Analog output 3 negative connector Analog output 4 positive connector Analog output 4 negative connector Alarm relay 3 common connector Alarm relay 3 normal closed connector Alarm relay 3 normal open connector Alarm relay 2 common connector Alarm relay 2 normal closed connector Alarm relay 2 normal open connector Detected internal fault relay common connector Detected internal fault relay normal closed connector Detected internal fault relay normal open connector 2015 Schneider Electric All rights reserved 309 Rear panel S 3 5 m gt lt O OAOA AA AA A O A A AO 310 No O N Oo oa A O 10 11 12 13 14 15 16 17 18 NO N Oo A C Symbol 48V DI1 DI2 DI3 014 015 DI6 A1 COM A1 NO A1 NC T2 T2 T1 T1 Uaux Uaux Symbol B
255. n out module to be configured for the Profibus master 4 Ifthe value is Profibus protocol has not been selected or the device has not restarted after protocol change or there is a communication problem between the main CPU and the Profibus ASIC 63230 218 205 2015 Schneider Electric All rights reserved 269 Communication protocols Section 9 Communication SPA bus The device has full support for the SPA bus protocol including reading and writing the setting values Also reading of multiple consecutive status data bits measurement values or setting values with one message is supported oeveral simultaneous instances of this protocol using different physical ports are possible but the events can be read by one single instance only There is a separate document Spabus parameters pdf of SPA bus data items available Table 9 9 Parameters Parameter Value Unit Description Note Addr 1 899 SPA bus address Must be unique in the Set system bit s 1200 bps Communication speed Set 2400 4800 9600 default 19200 Emode Event numbering style Set Channel Use this for new installations Limit60 The other modes are for compatibility with old systems NoLimit Set An editable parameter password needed 2 0 2015 Schneider Electric All rights reserved 63230 218 205 oection 9 Communication Communication protocols IEC 60870 5 103 The IEC standard 60870 5 103 Compani
256. n scaling is enabled all settings of group one are copied to group two but the pick up value of group two is changed according the given value 10 200 e This feature can be enabled disabled via VAMPSET or by using the local panel When using VAMPSET the scaling can be activated and adjusted in the protection stage status 2 menu When using the local panel similar settings can be found from the prot menu e Itis also possible to change the scaling factor remotely by using the modbus TCP protocol When changing the scaling factor remotely value of 196 is equal to 1 Check the correct modbus address for this application from the VAMPSET or from the communication parameter list Group 2 o c remote scaling Enable Grp 2 remote scaling 150 1 Set group DI control Group Gre Perseem _ LOL MM we o we CO 0 0mm inverse delay 9 Inverse delay 1x 141 83 s 14115 s Figure 5 7 Hemote scaling example In the Figure 5 7 can be seen the affect of remote scaling After enabling group is changed from group one to group two and all settings from group one are copied to group two The difference is that group two uses scaled pick up settings 63230 218 205 2015 Schneider Electric All rights reserved 67 Directional phase overcurrent gt 67 Section 5 Protection functions NOTE When remote scaling function is used it replaces all the settings of group 2 So th
257. n starting as long as the terms for turning into running condition are not satisfied e Motor running Motor is able to turn into a running position from both stopped and starting position Low limit for motor running is 20 of the motors nominal and the high limit for motor running is 120 of the motors nominal current MOTOR STATUS Phase current IL LU E MOTOR STATUS Stopped Motor start counter 0 Motor run counter 0 THTUS gt Elapsed time from motor start 191 8 min I Motor starts in last hour 0 h IL HA DI Status ES Event enabling D Mot start event E t 123 2min Motor stopped event Ej Hat Sirs E h Figure 5 14 Motor status via VAMPSET and local panel The status of the motor can be viewed via VAMPSET software or by looking from the local panel of the relay Mstat Statuses Starting and running can be found from the output and block matrix Therefore it is possible to use these signals for tripping or indication and for blocking purposes OUTPUT MATRIX P B UPS VA A4 AS A1 A2 connected connected and latched Z Z Z Z Z i Fa Motor start Motor runnig BLOCK MATRIX Motor start Motor runnig Figure 5 15 Motor status in outout and block matrix 2015 Schneider Electric All rights reserved 63230 218 205 Section 5 Protection functions Stall protection Isr 48 63230 218 205 Sof
258. names For NEMA the phases are as follows L1 A L2 B and L32C U V e Uo Qn TUS p S Three phase power phasor Measured voltage phasor corresponding the fundamental frequency voltage between phases L1 and L2 Complex conjugate of the measured phase L1 fundamental frequency current phasor Measured voltage phasor corresponding the fundamental frequency voltage between phases L2 and L3 I Complex conjugate of the measured phase L3 fundamental 1 frequency current phasor 2015 Schneider Electric All rights reserved 217 Power calculations Section 7 Measurement functions Apparent power active power and reactive power are calculated as follows S 1 5 imag S E S The device is connected to line to neutral voltage When the device is connected to line to neutral voltages the voltage measurement mode is set equal to 3LN The following equation is used for power calculation Note L1 L2 and L3 are IEC phase names For NEMA the phases are as follows L1 A L2 B and L3 2C S ZU d Um us uo T S Three phase power phasor Measured voltage phasor corresponding the fundamental frequency voltage of phase L1 Complex conjugate of the measured phase L1 fundamental frequency current phasor U Measured voltage phasor corresponding the fundamental frequency voltage of phase L2 T Complex conjugate of the measured phase L2 fundamental frequency
259. nary input BI on the arc option card see section Optional two channel arc detection card can be used to get the light indication from another relay to build selective arc detection systems The BI signal can also be connected to any of the output relays BO indicators etc offered by the output matrix see section Output matrix Bl is a dry input for 48 Vdc signal from binary outputs of other VAMP devices or dedicated arc detection devices by VAMP 2015 Schneider Electric All rights reserved 145 Arc fault protection 50ARC 50NARC optional Section 5 Protection functions Binary output The binary output BO on the arc option card see section Optional two channel arc detection card can be used to give the light indication signal or any other signal or signals to another relay s binary input to build selective arc detection systems Selection of the BO connected signal s is done with the output matrix see section Output matrix BO is an internally wetted 48 Vdc signal for Bl of other VAMP relays or dedicated arc detection devices by VAMP Delayed light indication signal Relay output matrix has a delayed light indication output signal Delayed Arc L available for building selective arc detection systems Any light source combination and a delay can be configured starting from 0 01 s to 0 15 s The resulting signal is available in the output matrix to be connected to BO output relays etc Pick up scaling The per un
260. nctions Primary secondary and per unit scaling Voltage scaling Primary secondary scaling of line to line voltages Line to line voltage scaling Voltage measurement mode 2LL U Voltage measurement mode SLN secondary primary U eer y 3 0 PRI SEC PRI SEC EC SEC VP primary secondary U U VTsEc U U PRI VTseC SEC PRI VTR SEC VTPR Examples Note For NEMA UzV 1 Secondary to primary Voltage measurement mode is ALL Up VT 12000 110 Voltage connected to the device s input or Ug is 100 V Primary voltage is Upp 100 12000 110 10909 V 2 Secondary to primary Voltage measurement mode is 3LN VI 2 12000 110 Three phase symmetric voltages connected to the device s inputs Up and Uc are 57 7 V Primary voltage is Upp 43 x 58 x 12000 110 10902 V 3 Primary to secondary Voltage measurement mode is ALL Ug VT 12000 110 The relay displays Upp 10910 V Secondary voltage is Usec 10910 x 110 12000 100 V 4 Primary to secondary Voltage measurement mode is VT 12000 110 The relay displays U12 Us 10910 V symmetric secondary voltages at Ua Ug and Uc are Usec 10910 43 x 110 12000 57 7 V 63230 218 205 2015 Schneider Electric All rights reserved 229 Primary secondary and per unit scaling Section 7 Measurement functions Per unit pu scaling of line to l
261. nel Option NEMA 2 IP54 front panel Standard model w x h x 208 x 155 x 225 mm 8 19 x 6 10 x 8 86 in Material 1 mm 0 039 in steel plate Weight 4 2 kg 9 272 Ib Color code RAL 7032 Casing RAL 7035 Back plate Table 12 6 Package Dimensions W x H x D 215 x 160 x 275 mm 8 46 x 6 30 x 10 83 in Weight Terminal Package 5 2 kg 11 479 Ib and Manual The following VAMP devices are UL and cUL listed Models VAMP 321 VAMP 300F VAMP 300M followed by suffixes Accessories I O Units VAM SL VAM 3LX VAM 10L VAM 1010 VAM 12L and VAM 1210 Sensor Model ARC SLm x where x represents the fiber length 63230 218 205 2015 Schneider Electric All rights reserved 345 Protection functions 346 NOTE Protection functions Section 12 Technical data Please see the section Current protection function dependencies for explanation of lyopzg El Extremely Inverse NI Normal Inverse VI Very Inverse LTI Long Time Inverse MI Moderately Inverse This is the instantaneous time i e the minimum total operational time including the fault detection time and operation time of the trip contacts Non directional current protection Table 12 7 Overcurrent stage I gt 50 51 Pick up current 1 10 5 00 x IMODE Definite time function Operating time DI 0 04 300 00 s step 0 02 s IDMT function Delay curve family Curve type Tim
262. nel user interface Operating measures 9 Push execute the forced control operation of the selected function e g making the output relay of T1 to pick up 9 Hepeat the steps 7 and 8 alternate between the on off state of the function 10 Repeat the steps 1 4 to exit the Force function 11 Push to return to the main menu 63230 218 205 2015 Schneider Electric All rights reserved 37 Configuration and parameter setting Section 2 Local panel user interface Configuration and parameter setting DANGER HAZARD OF ELECTRIC SHOCK EXPLOSION OR ARC FLASH Ensure the relay has the necessary programming and settings to adequately protect the system Failure to follow these instructions will result in death serious injury or equipment damage The minimum procedure to configure a relay is as follows 1 Open the access level Configurator The default password for configurator access level is 2 2 Setthe rated values in menu CONF including at least current transformers voltage transformers and motor ratings if applicable Also the date and time settings are in this same main menu 3 Enable the needed protection functions and disable the rest of the protection functions in main menu Prot 4 Setthe setting parameter of the enable protection stages according the application 5 Connect the output relays to the start and trip signals of the enabled protection stages using the output
263. nfigured delay on the local panel display 2015 Schneider Electric All rights reserved 63230 218 205 Section 5 Protection functions Directional ground fault protection lg 67N Inverse time limitation The maximum measured secondary residual current is 10xloy and maximum measured phase current is 50xly This limits the scope of inverse curves with high pick up settings See section Inverse time operation for more information Setting groups There are two settings groups available for each stage Switching between setting groups can be controlled by digital inputs virtual inputs communication logic and manually sinp Choice Setting setine Delas Enable events leos Res li lo gt Ising Cap Figure 5 19 Block diagram of the directional ground fault stages lo and lo loDir ResCap EZ Iyo7 Z Figure 5 20 Operation characteristic of the directional ground fault protection in Res or Cap mode Res mode can be used with compensated networks and Cap mode is used with ungrounded networks 63230 218 205 2015 Schneider Electric All rights reserved 89 Directional ground fault protection gt Section 5 Protection functions 90 Angle offset 15 55 Sector 70 TRIP AREA lyp7 TRIP AREA 88 loDir SectorAdj Figure 5 21 Two example of operation characteristics of the directional ground fault stages in sector mode The d
264. nformation please refer to the VAMPSET manual doc no 63230 218 207 if 7 0 000A Figure 2 19 Single line diagram Blocking and interlocking configuration outputs only The configuration of the blockings and interlockings is done with the VAMPSET software Any start or trip signal can be used for blocking the operation of any protection stage Furthermore the interlocking between objects can be configured in the same blocking matrix of the VAMPSET software For more information please refer to the VAMPSET manual doc no 63230 218 207 50 2015 Schneider Electric All rights reserved 63230 218 205 Section 3 VAMPSET PC software Section 3 VAMPSET PC software 63230 218 205 The PC user interface can be used for e On site parameterization of the relay e Loading relay software from a computer e Reading measured values registered values and events to a computer e Continuous monitoring of all values and events Two RS 232 serial ports are available for connecting a local PC with VAMPSET to the relay one on the front panel and one on the rear panel of the relay These two serial ports are connected in parallel However if the connection cables are connected to both ports only the port on the front panel will be active To connect a PC to a serial port use the connection cable with part no VX 003 3 The VAMPSET program can also use TCP IP LAN connection Optional h
265. ng Not active Run Waiting a triggering Trig Recording FULL Memory is full in saturated mode Trig Manual triggering Set ReadyRec n m n Available recordings m maximum number of recordings The value of m depends on sample rate number and type of the selected channels and the configured recording length 170 2015 Schneider Electric All rights reserved 63230 218 205 oection 6 Supporting functions Disturbance recorder Parameter Value Unit Description Note AddCh Add one channel Maximum simultaneous number of Set channels is 12 IL1 IL2 IL3 Phase current lo1 lo2 Measured residual current Line U12 U23 U31 to line voltage UL1 UL2 UL3 Phase to neutral voltage Uo Zero sequence voltage f Frequency 5 Active reactive apparent power P F Power factor CosFii COS loCalc Phasor sum lo IL1 IL2 IL3 3 l1 Positive sequence current 12 Negative sequence current 12 11 Relative current unbalance l2 In Current unbalance xlyor U1 Positive sequence voltage U2 Negateive sequence voltage U2 U1 Relative negative sequence voltage IL Average IL1 IL2 1L3 3 Uphase Average phase voltage Uline Average line to lines voltages DI DO Digital inputs Digital outputs TanFii tanq THDIL1 THDIL2 Total harmonic distortion of IL1 IL2 or IL3 THDIL3 THDUa
266. ng between the two objects is done with a digital input virtual input virtual output or by choosing Auto CB selection AR controls CB2 when the input defined by Input for selecting CB2 setting is active except when using auto CB selection when operated CB 1 or2 is that which was last in close state Control is changed to another object only if the current object is not close Blocking of AR shots Each AR shot can be blocked with a digital input virtual input or virtual output Blocking input is selected with Block setting When selected input is active the shot is blocked A blocked shot is treated like it doesn t exist and AR sequence will jump over it If the last shot in use is blocked any AR request during reclaiming of the previous shot will cause final tripping Starting AR sequence Each AR request has own separate starting delay counter The one which starting delay has elapsed first will be selected If more than one delay elapses at the same time an AR request of the highest priority is selected AR1 has the highest priority and AR4 has the lowest priority First shot is selected according to the AR request Next AR opens the CB and starts counting dead time Starting sequence at shot 2 5 amp skipping of AR shots Each AR request line can be enabled to any combination of the 5 shots For example making a sequence of Shot 2 and Shot 4 for AR request 1 is done by enabling AR1 only for those two shots If AR sequence is
267. ng group Set None Digital input VIx Virtual input LEDx LED indicator signal VOx Virtual output Force Off Force flag for status forcing for test purposes This is Set a common flag for all stages and output relays too On Automatically reset by a 5 minute timeout MinU V The supervised minimum of line to line voltages in primary volts U lt U lt lt U lt lt lt V Pick up value scaled to primary value U lt U lt lt U lt lt lt Un Pick up setting Set t lt t lt lt t lt lt lt S Definite operation time Set LVBIk Un Low limit for self blocking Set RisDly S Release time U stage only Set Hyster Default 3 0 96 Dead band setting Set Set An editable parameter password needed C Can be cleared to zero F Editable when force flag is on For details of setting ranges see the section Protection functions Parameter Recorded values of the latest eight faults There are detailed information available of the eight latest faults for each of the stages Time stamp fault voltage elapsed delay voltage before the fault and setting group Table 5 30 Recorded values of the undervoltage stages 8 latest faults V lt lt lt V lt lt lt Value Description yyyy mm dd Time stamp of the recording date hh mm ss ms Time stamp time of day Fit Minimum fault voltage EDly Elapsed time of the operating time setting 100 trip PreFIt Supervised valu
268. ns out the OpenCB relay output closes 7 The CB opens The dead time from shot 2 starts and the OpenCB relay output opens 8 The dead time from shot 2 runs out the CloseCB output relay closes 9 The CB closes The CloseCB output relay opens and the discrimination time from shot 2 starts The current is now under gt setting 10 Reclaim time starts After the reclaim time the AR sequence is successfully executed The AR function moves to wait for a new AR request in shot 1 63230 218 205 2015 Schneider Electric All rights reserved 253 Logic functions oection 8 Control functions Logic functions The device supports customer defined programmable logic for boolean signals The logic is designed by using the VAMPSET setting tool and downloaded to the device Functions available are AND OR e COUNTERs XOR RS amp D flip flops Logic is made with VAMPSET setting tool Consumed memory is dynamically shown on the configuration view in percentage The first value indicates amount of used inputs second amount of gates and third values shows amount of outputs consumed LOGIC 6 7 5 i gt aan 2 plum tri Logic output 1 A trip tri TON 0m 1000 ms DR e DI2 Figure 8 6 Logic can be found and modified in logic menu in VAMPSET setting tool Percentages show used memory amount Inputs Logical functions Outputs used None of these is not allowed to exceed 100 oee gui
269. nt require generating of the new EDS file e Three types of communications are supported UCMM one time request response Class 3 connection cyclic request response and Class 1 connection cyclic I O messages containing assemblies data EtherNet IP implementation on VAMP device serves as a server and is not capable of initiating communication Table 9 14 EtherNet IP main configuration parameters Parameter Range Description IP address IP protocol address identifying device in the network Multicast IP Multicast IP address used for sending I O messages Multicast TTL 1 100 Time allowed to live in the header filed of the I O messages sent to multicast address Vendor ID 1 65535 Identification of a vendor by number Device Type 0 65535 Indication of general type of product Product Code 1 65535 Identification of a particular product of an individual vendor Major Revision 1 127 Major revision of the item the Identity Object represents Minor Revision 1 255 Minor revision of the item the Identity Object represents Serial Number 0 4294967295 Serial number of device Product Name 32 chars Human readable identification Producing Instance 1 1278 Instance number of producing assembly Include Run Idle On Off Include or exclude Run Idle Header in an outgoing I O messages Header Producing Consuming Instance 1 1278 Instance number of consuming assembly Include Run Idle On Off Expect presence or absence of Run Idle Hea
270. o Vo gt gt Table 5 24 Parameters of the residual overvoltage stages Vg Vo gt gt Parameter Description otatus Current status of the stage Blocked otart F Trip SCntr Cumulative start counter C TCntr Cumulative trip counter C SetGrp 1or2 Active setting group Set SGrpDI Digital signal to select the active setting group Set None DIx Digital input VIx Virtual input LEDx LED indicator signal VOx Virtual output Force Off Force flag for status forcing for test purposes This Set is a common flag for all stages and output relays On Automatically reset by a 5 minute timeout Uo The supervised value relative to Un 4 3 Uo Uo gt gt Pick up value relative to Un A 3 Set t gt t gt gt S Definite operation time Set Set An editable parameter password needed C Can be cleared to zero F Editable when force flag is on For details of setting ranges see the section Protection functions 63230 218 205 2015 Schneider Electric All rights reserved 109 Zero sequence voltage protection Ug 59 Section 5 Protection functions Hecorded values of the latest eight faults There are detailed information available of the eight latest faults Time stamp fault voltage elapsed delay and setting group Table 5 25 Recorded values of the residual overvoltage stages Vo Vo gt gt Parameter Value Unit Descrip
271. o external sync and the relay s clock is leading sixty one seconds a week and the parameter AAlIntv has been zero the parameters are set as AvDrft Lead 604 8 AAInty 9 95 61 With these parameter values the system clock corrects itself with 1 ms every 9 9 seconds which equals 61 091 s week Example 2 If there is no external sync and the relay s clock has been lagging five seconds in nine days and the AAlntv has been 9 9 s leading then the parameters are set as 1 AAN Y yew 7 m 10 6 5000 9 24 3600 9977 AvDrft Lead 2015 Schneider Electric All rights reserved 193 System clock and synchronization oection 6 Supporting functions When the internal time is roughly correct deviation is less than four seconds any synchronizing or auto adjust will never turn the clock backwards Instead in case the clock is leading it is softly slowed down to maintain causality Table 6 16 System clock parameters Parameter Value Unit Description Note Date Current date Set Time Current time Set Style Date format Set y d m Year Month Day d m y Day Month Year m d y Month Day Year SyncDI DI not used for synchronizing A 016 Minute pulse input TZone 15 00 15 00 UTC time zone for SNTP synchronization Set Note This is a decimal number For example for state of Nepal the
272. oard Antialiasing 16 bit VD converter filter current and uP voltage inputs amp E memory Alarm 3t UU Digital inputs SPAbus Modbus Profibus DP fibre connectors Auxilary power Protection Calculation of functions symmetric components Output relay FFT calculation control Amplitude and 32 samples cycle phase shift of ise shift base freqency component 32 samples cycle Digital 6 18 inputs Settings Figure 4 3 Block diagram of signal processing and protection software VISblock2 Block Setting Delay Definite inverse Inverse time Multiplier Enable s time characteristic events Figure 4 4 Block diagram of a basic protection function 63230 218 205 2015 Schneider Electric All rights reserved DD Principles of numerical protection techniques oection 5 Protection functions Section 5 Protection functions Each protection stage can be independently enabled or disabled according to the requirements of the intended application Maximum number of protection stages in one application The device limits the maximum number of enabled stages to about 30 depending of the type of the stages For more information please see the configuration instructions in the section Configuration and parameter setting General features of protection stages 56 Setting groups Most stages have two setting groups Changing between setting groups can be control
273. ocols or VAMPSET Every reading increments the internal read pointer to the event buffer In case of detected communication the latest event can be reread any number of times using an other parameter On the local panel scanning the event buffer back and forth is possible Event enabling masking In case of an uninteresting event it can be masked which helps prevent the particular event s to be written in the event buffer As a default there is room for 200 latest events in the buffer Event buffer size can be modified from 50 to 2000 Modification can be done in Local panel conf menu Indication screen popup screen can also be enabled in this same menu when VAMPSET setting tool is used The oldest one will be overwritten when a new event does occur The shown resolution of a time stamp is one millisecond but the actual resolution depends on the particular function creating the event 2015 Schneider Electric All rights reserved 165 Inverse time operation oection 6 Supporting functions For example most protection stages create events with 5 ms 10 ms or 20 ms resolution The absolute accuracy of all time stamps depends on the time synchronizing of the relay See the section oystem clock and synchronization for system clock synchronizing Event buffer overflow The normal procedure is to poll events from the device all the time If this is not done the event buffer will eventually overflow On the local screen
274. of Uc Harmonics of voltage input Uc See Figure 2 12 Count U VOLT INTERRUPTS Voltage interrupts counter Prev U VOLT INTERRUPTS Previous interruption Total U VOLT INTERRUPTS Total duration of voltage interruptions days hours Prev U VOLT INTERRUPTS Duration of previous interruption s Status U VOLT INTERRUPTS Voltage status LOW NORMAL The depth of the window can be selected L1 L2 and L3 are IEC phase names For NEMA the phases are as follows L1 A L2 B and L3 C 34 HARMONICS of IL1 RA TUS d Figure 2 12 Example of harmonics bar display 2015 Schneider Electric All rights reserved 63230 218 205 oection 2 Local panel user interface Operating measures Heading event register The event register can be read from the Evnt submenu 1 Push once 2 The EVENT LIST appears The display contains a list of all the events that have been configured to be included in the event register event list EVENT LIST lt Av Code 71E10 CB open timeout 2002 02 15 00 17 37 530 Figure 2 13 Example of an event register 5 Scroll through the event list with the and 8 4 Exit the event list by pushing lt It is possible to set the order in which the events are sorted If the Order parameter is set to New Old then the first event in the EVENT LIST is the most recent event 63230 218 205 2015 Schneider Electric All rights reserved 35 Configuration and para
275. of active exported energy Eq 100 5000 ms Pulse length of reactive exported energy E 100 5000 ms Pulse length of active imported energy Eq 100 5000 ms Pulse length of reactive imported energy 63230 218 205 ocaling examples 1 Average active exported power is 250 MW Peak active exported power is 400 MW Pulse size is 250 kWh or 025 MWh The average pulse frequency will be 250 0 250 1000 pulses h The peak pulse frequency will be 400 0 250 1600 pulses h Set pulse length to 3600 1600 0 2 2 0 sor less The lifetime of the mechanical output relay will be 50x10 1000 h 6 years This is not a practical scaling example unless an output relay lifetime of about six years is accepted Average active exported power is 100 MW Peak active exported power is 800 MW Pulse size is 400 kWh The average pulse frequency will be 100 0 400 250 pulses h The peak pulse frequency will be 800 0 400 2000 pulses h Set pulse length to 3600 2000 0 2 1 6 sor less The lifetime of the mechanical output relay will be 50x106 250 h 23 years Average active exported power is 20 MW Peak active exported power is 70 MW Pulse size is 60 kWh The average pulse frequency will be 25 0 060 416 7 pulses h The peak pulse frequency will be 70 0 060 1166 7 pulses h Set pulse length to 3600 1167 0 2 2 8 sor less The lifetime of the mechanical output relay will be 50x106 417 h 14 years Average act
276. of protection stages 63230 218 205 For example when there is a high fault in an outgoing feeder it might pick up both the incoming and outgoing feeder relay However the fault must be cleared by the outgoing feeder relay and the incoming feeder relay must not trip Although the operating delay setting of the incoming feeder is more than at the outgoing feeder the incoming feeder might still trip if the operation time difference is not big enough The difference must be more than the retardation time of the incoming feeder relay plus the operating time of the outgoing feeder circuit breaker Figure 5 1 shows an overvoltage fault seen by the incoming feeder when the outgoing feeder does clear the fault If the operation delay setting would be slightly shorter or if the fault duration would be slightly longer than in the figure a nuisance trip might happen the dashed 40 ms pulse in the figure In VAMP devices the retardation time is less than 50 ms Heset time release time Figure 5 2 shows an example of reset time i e release time when the relay is clearing an overcurrent fault When the relay s trip contacts are closed the circuit breaker CB starts to open After the CB contacts are open the fault current will still flow through an arc between the opened contacts The current is finally stopped when the arc extinguishes at the next zero crossing of the current This is the start moment of the reset delay After the reset delay t
277. of the voltage measurement mode Nn Nominal voltage Rating of VT primary or secondary lt VT Voltage transformer i e potential transformer PT O Z o www Word wide web internet http configuration interface Periodic testing The protection IED cabling and arc sensors must periodically be tested according to the end user s safety instructions national safety instructions or law Manufacturer recommends functional testing being carried minimum every five 5 years Environmental conditions may cause the need to clear the light sensors frequently lt is proposed that the periodic testing is conducted with a secondary injection principle for those protection stages which are used in the IED 2015 Schneider Electric All rights reserved 14 63230 218 205 Section 2 Local panel user interface Local panel operations oection 2 Local panel user interface Relay front panel 63230 218 205 Vamp 200 series The figure below shows as example the front panel of the device and the location of the user interface elements used for local control a cC 9e 1 Navigation push buttons e 2 LED indicators 3 LCD 2 4 RS 232 serial i communication port for Amr PC Navigation push button function CANCEL push button for returning to the previous menu To return to the first menu item in the main menu press the button for at least three se
278. oltage Yes Yes U31 Line to line voltage UL1 UL2 Phase to neutral voltage Yes UL3 Uo Zero sequence voltage Yes Yes Frequency 2 Q S Active reactive apparent power z PF Power factor CosFii E loCalc Phasor sum lo IL1 IL2 IL3 3 1 Positive sequence current l2 Negative sequence current 12 11 Relative current unbalance Il2 Imode Current unbalance xlmode U1 Positive sequence voltage 2 U2 Negative sequence voltage U2 U1 Relative voltage unbalance IL Average IL1 IL2 IL3 3 Uphase Average UL1 UL2 UL3 3 3 Uline Average U12 U23 U31 3 gt E DO Digital outputs Yes Yes Yes Yes Yes DI Digital inputs Yes Yes Yes Yes Yes TanFii tanq i THDIL1 Total harmonic distortion of IL1 THDIL2 Total harmonic distortion of IL2 THDIL3 Total harmonic distortion of IL3 i THDUa Total harmonic distortion of Ua THDUb Total harmonic distortion of Ub THDUc Total harmonic distortion of Uc E DI 2 Digital inputs 21 32 Yes Yes Yes Yes Yes Prms Active power rms value Qrms Reactive power rms value Srms Apparent power rms value fy Frequency behind circuit breaker 168 2015 Schneider Electric All rights reserved 63230 218 205 Section 6 Su
279. on standard for the informative interface of protection equipment provides standardized communication interface to a primary system master system The unbalanced transmission mode of the protocol is used and the device functions as a secondary station slave in the communication Data is transferred to the primary system using data acquisition by polling principle The IEC functionality includes application functions e station initialization e general interrogation e clock synchronization and e command transmission It is not possible to transfer parameter data or disturbance recordings via the IEC 103 protocol interface The following ASDU Application Service Data Unit types will be used in communication from the device e ASDU 1 time tagged message e ASDU 3 Measurands e ASDU 5 Identification message e ASDU 6 Time synchronization and e ASDU 8 Termination of general interrogation The device will accept e ASDU 6 Time synchronization e ASDU 7 Initiation of general interrogation and e ASDU 20 General command The data in a message frame is identified by e identification e function type and e information number These are fixed for data items in the compatible range of the protocol for example the trip of I function is identified by type identification 1 function type 160 and information number 90 Private range function types are used for such data items which are not define
280. onnected to the device s inputs Ua Ug and Uc are Usec 1 00 x 110 48 x 11000 12000 58 2 V 63230 218 205 2015 Schneider Electric All rights reserved 231 Analogue output option oection 7 Measurement functions Per unit pu scaling of zero sequence voltage Zero sequence voltage Uo scaling Voltage measurement mode 2LL U Voltage measurement mode SLN 4 LL U LLy secondary gt per unit U Uo 1 U F U Uz i e E 3 er unit secondar 28 gt U sre U py 0 FU IL ET VT ac SEC Examples Note For NEMA UzV 1 Secondary to per unit Voltage measurement mode is 2 0 110 V This is a configuration value corresponding to Ug at full ground fault Voltage connected to the device s input Uc is 22 V Per unit voltage is Upy 22 110 0 20 pu 20 96 2 Secondary to per unit Voltage measurement mode is 3LN VI 2 12000 110 Voltage connected to the device s input UA is 38 1 V while Ua Up 0 Per unit voltage is Upy 38 1 0 0 6 x 110 0 20 20 96 Per unit to secondary Voltage measurement mode is ALL Ug Uosec 110 V This is a configuration value corresponding to Ug at full ground fault The device displays Ug 20 secondary voltage at input Uc is Usec 0 20 x 110 22V 4 Perunitto secondary Voltage measurement mode is VT 2
281. onnections Terminal X2 with analog output 3 6 63230 218 205 O N OO A CO 10 11 12 13 14 15 16 7 18 Symbol AQ1 AO1 2 AQ2 AQ3 AO3 4 4 2 A2 NC A2 NO SF COM SF NC SF NO Rear panel Description Analog output 1 positive connector Analog output 1 negative connector Analog output 2 positive connector Analog output 2 negative connector Analog output 3 positive connector Analog output 3 negative connector Analog output 4 positive connector Analog output 4 negative connector Alarm relay 3 common connector Alarm relay 3 normal closed connector Alarm relay 3 normal open connector Alarm relay 2 common connector Alarm relay 2 normal closed connector Alarm relay 2 normal open connector Detected internal fault relay common connector Detected internal fault relay normal closed connector Detected internal fault relay normal open connector 2015 Schneider Electric All rights reserved 301 Rear panel Terminal X3 VO VP 6 302 O N O A CO 10 11 12 13 14 15 16 7 18 Symbol 48V DI1 DI2 DI3 014 015 016 1 A1 NO A1 NC T2 T2 T1 T1 Uaux Uaux Section 11 Connections Description Internal control voltage for digital inputs 1 6
282. or in case the new load exceeds the generating capacity the average frequency keeps on decreasing 2014 Schneider Electric All rights reserved 125 Rate of change of frequency ROCOF 81R FREQUENCY Hz 50 0 49 7 TRIP Section 5 Protection functions Settings df dt 0 5 Hz s 0 605 Q tMin 0 60 s i 2s amp E Us 25 5 Figure 5 35 An example of definite time df dt operation time At 0 6 s which is the delay setting the average slope exceeds the setting 0 5 Hz s and a trip signal is generated Setting groups There are two settings groups available Switching between setting groups can be controlled by digital inputs virtual inputs mimic display communication logic and manually Description of ROCOF implementation The ROCOF function is sensitive to the absolute average value of the time derivate of the measured frequency df dt Whenever the measured frequency slope df dt exceeds the setting value for 80 ms time the ROCOF stage picks up and issues a start signal after an additional 60 ms delay If the average df dt since the pick up moment still exceeds the setting when the operation delay time has elapsed a trip signal is issued In this definite time mode the second delay parameter minimum delay tmun must be equal to the operation delay parameter t If the frequency is stable for about 80 ms and the time t has already elapsed wi
283. or one of the serial ports Serial ports are configured in menu Bus 4 The menuis visible only if the stage is enabled 5 Objects are circuit breakers disconnectors etc Their position or status can be displayed and controlled in the inter active mimic display 6 There are two extra menus which are visible only if the access level operator or configurator has been opened with the corresponding password 7 Detailed protocol configuration is done with VAMPSET For NEMA U V 22 2015 Schneider Electric All rights reserved 63230 218 205 section 2 Local panel user interface Local panel operations 63230 218 205 Menu structure of protection functions The general structure of all protection function menus is similar although the details do differ from stage to stage As an example the details of the second overcurrent stage gt gt menus are shown below First menu of I gt gt 50 51 stage AV b I gt gt STATUS 50 51 ExDO Status Figure 2 4 First menu of I gt gt 50 51 stage This is the status start and trip counter and setting group menu The content is e Status The stage is not detecting any fault at the moment The stage can also be forced to pick up or trip is the operating level is Configurator and the force flag below is on Operating levels are explained in the section Operating levels e SCntr 5 The stage has picked up a fault five times since the last reset or
284. ore often than 10 ms So if the peak amount is set to 10 then the operational delay will not accept a smaller value than 100 ms Also if the operational delay is set to 40 ms then it s not possible to set a higher peak amount setting than 4 These input restrictions prohibit the entry of parameters to the relay such as operational delay and peak amount that are not physically possible 100 2015 Schneider Electric All rights reserved 63230 218 205 Section 5 Protection functions Intermittent transient ground fault protection lgiyr 67NI ntermittent time 0 2 s Operation time 0 16 s Reset delay 0 15 __ TRIP Setting for minimum number of peaks 2 0 0 1 0 2 0 3 0 4 Time Figure 5 25 Set peak amount is satisfied and operation time comes full inside intermittent time setting Stage issues a trip Uo Reset delay 0 1 s 0 0 1 0 2 0 3 0 4 Time 5 Figure 5 26 Peak amount is not satisfied when operation delay comes full but last required peak comes during intermittent time Stage issues instant trip when peak amount comes satisfied Intermittent time Operation time 0 3 s TRIP Setting for minimum number of peaks 2 Notrip 0 0 1 0 2 03 04 Time s Figure 5 27 Peak amount is satisfied but intermittent time comes full before operation time co
285. ormalized value or scaled Normalized value DbandEna NO Dead band calculation enable flag Set Yes DbandCy 100 10000 ms Dead band calculation interval Set Set An editable parameter password needed 63230 218 205 2015 Schneider Electric All rights reserved 275 Communication protocols Section 9 Communication External I O Modbus RTU master IEC 61850 2 6 External Modbus I O devices can be connected to the relay using this protocol See the section External input output module module for more information The relay supports communication using IEC 61850 protocol with native implementation IEC 61850 protocol is available with the optional built in Ethernet port The protocol can be used to read write static data from the relay or to receive events and to receive send GOOSE messages to other relays IEC 61850 server interface is capable of e Configurable data model selection of logical nodes corresponding to active application functions e Configurable pre defined data sets e Supported dynamic data sets created by clients e Supported reporting function with buffered and unbuffered Report Control Blocks e Sending analog values over GOOSE e Supported control modes direct with normal security direct with enhanced security select before operation with normal security select before operation with enhanced security e Supported horizontal communication with GOOSE
286. ous carry 5 Make and carry 0 5 s 30A Make and carry 3s 15A Breaking capacity AC 2 000 VA Breaking capacity DC L R 40ms at 48 V dc 5A at 110 V dc 3A at 220 V dc 1A Contact material AgNi 90 10 Terminal block Phoenix MVSTBW or equivalent Maximum wire dimension 2 5 mm 13 14 AWG 2015 Schneider Electric All rights reserved 63230 218 205 Section 12 Technical data Connections oignal contacts Number of contacts 3 change over contacts relays A1 A2 and A3 2 making contacts relays A4 and A5 1 change over contact SF relay Rated voltage 250 V ac dc Max make current 4s at duty cycle 15A 1096 Continuous carry 5A Breaking capacity AC 2 000 VA Breaking capacity DC L R240ms at 48 V dc 1 3 A at 110 V dc 0 4 A at 220 V dc 0 2A Contact material AgNi 90 10 Terminal block Maximum wire dimension Phoenix MVSTBW or equivalent 2 5 mm 13 14 AWG Ethernet connection Number of ports 1 Electrical connection Ethernet RJ 45 Ethernet 10 Base T Protocols VAMPSET Modbus TCP IEC 61850 Data transfer rate 10 Mb s Local serial communication port Number of ports 1 on front and 1 on rear panel Electrical connection RS 232 Data transfer rate 2 400 38 400 kb s 63230 218 205 2015 Schneider Electric All rights reserved 341 Block diagrams of option modules Hemote cont
287. ove the pick up setting Figure 6 1 Functionality of cold load inrush current feature Table 6 4 Parameters of the cold load amp inrush detection function Parameter Description ColdLd Status of cold load detection Start Cold load situation is active Trip Timeout Inrush Status of inrush detection Start Inrush is detected Trip Timeout ILmax A The supervised value Max of IL1 IL2 and IL3 Pickup A Primary scaled pick up value Idle A Primary scaled upper limit for idle current MaxTime S Set Idle xlmode Current limit setting for idle situation Set Pickup xlmode Pick up setting for minimum start current Set 80 ms Maximum transition time for start recognition Pickupf2 Pick up value for relative amount of 2 4 harmonic 1 Set Set An editable parameter password needed For details of setting ranges see the section Supporting functions 1 4 2015 Schneider Electric All rights reserved 63230 218 205 Section 6 Supporting functions Voltage sags and swells Voltage sags and swells Parameter Value The power quality of electrical networks has become increasingly important The sophisticated loads e g computers etc require uninterruptible supply of clean electricity VAMP protection platform provides many power quality functions that can be used to evaluate monitor and alarm on the basis of the quality One of the most important power quality fun
288. p SetGrp 1 Active setting group during the fault 2 18 2015 Schneider Electric All rights reserved 63230 218 205 oection 5 Protection functions Phase reversal incorrect phase sequence protection 12 gt gt 47 Phase reversal incorrect phase sequence protection lo gt gt 47 The phase sequence stage helps prevent the motor from being started in to wrong direction thus protecting the load When the ratio between negative and positive sequence current exceeds 8096 and the average of three phase currents exceeds 0 2xlyo1 in the start up situation the phase sequence stage starts and trips after 100 ms after start up Table 5 11 Parameters of the incorrect phase sequence stage lo 47 Parameter Value unit Description Measured value 12 11 Neg phase seq current pos phase seq current Recorded values SCntr Start counter Start reading TCntr Trip counter Trip reading Fit Max value of fault current EDly Elapsed time as compared to the set operate time 100 tripping 63230 218 205 2015 Schneider Electric All rights reserved 19 Stall protection gt 48 Section 5 Protection functions Stall protection ler 48 The stall protection stage protects the motor against prolonged direct on line DOL starts caused by e g a stalled rotor too high inertia of the load or too low voltage This function is sensitive to the fundamental frequency component of the phas
289. p or loo use the corresponding CT pp and CTsgc values For ground fault stages using Signals use the phase current CT values for and CTszgc Examples 1 Secondary to primary CT 2500 5 Current to the relay s input is 4 A gt Primary current is 4 x 500 5 400A 2 Primary to secondary CT 2500 5 The relay displays 400 A gt Injected current is lsgc 400x 5 500 4A 2015 Schneider Electric All rights reserved 63230 218 205 oection 7 Measurement functions Primary secondary and per unit scaling Per unit pu scaling For phase currents excluding Arcl gt stage 1 1 I MODE 100 where is the rated current according to the mode See the section Abbreviations For residual currents and Arcl gt stage 1 pu 21xCTsgc for secondary side and 1 pu 1 x CT pp for primary side Phase current scaling for motor mode Phase current scaling for feeder mode Arcl gt stage and residual current 3lo secondary per unit I SEC PRI I _ SEC PU PU I CT c ur MOT CT c per unit secondary I I CT I CT MOT SEC PU SEC SEC PU SEC CT rni Examples 1 Secondary to per unit for feeder mode and Arcl gt CT 2750 5 Current injected to the relay s inputs is 7 A Per unit current is 7 5 1 4 pu 140 2 Secondary to per unit and percent for phase currents in motor mode excluding Arcl gt CT 750 5 luor 525 A Cu
290. perating voltage Availability lt X3 1 48VDC supply for Di1 6 VAMP 230 1 X3 2 Internal 48VDC VAMP 255 2 X3 3 3 X3 4 4 X3 5 5 X3 6 6 X3 7 7 X7 1 External 18 265 VDC VAMP 255 8 X7 2 50 250 VAC 9 X7 3 10 X7 4 11 X7 5 12 X7 6 gt X7 7 Common for DI7 12 13 X7 8 External 18 265 VDC VAMP 255 14 X79 50 250 VAC 15 X7 10 16 X7 11 17 XT 12 18 XT 13 gt 7 14 Common for DI13 17 19 X6 1 2 External 18 265 VDC ARC card with 2 015 20 X6 3 4 50 250 VAC NOTE These digital inputs must not be connected parallel with inputs of an another device Label and description texts can be edited with VAMPSET according the application Labels are the short parameter names used on the local panel and descriptions are the longer names used by VAMPSET 63230 218 205 2015 Schneider Electric All rights reserved 23 Digital inputs oection 8 Control functions Table 8 3 Parameters of digital inputs Parameter Value Unit Description Note 011 Din 0 1 Status of digital input DI COUNTERS 011 Din 0 65535 Cumulative active edge counter Set DELAYS FOR DIGITAL INPUTS 011 Din 0 00 60 00 S Definite delay for both on and off transitions Set CONFIGURATION DI1 DI6 Inverted no For normal open contacts NO Active edge is Set 0 gt 1 yes For normal closed contacts
291. phase currents Display Imax gt Imin A Setting values as primary values Recorded values Date Date of CT supervision alarm Time Time of CT supervision alarm Imax A Maximum phase current Imin A Minimum phase current For details of setting ranges see the section Supporting functions Voltage transformer supervision Parameter The device supervises the VIs and VT wiring between the device terminals and the VTs If there is a fuse in the voltage transformer circuitry the open fuse prevents or distorts the voltage measurement Therefore an alarm should be issued Furthermore in some applications protection functions using voltage signals should be blocked to avoid nuisance tripping The VT supervisor function measures the three phase voltages and currents The negative sequence voltage V and the negative sequence currentls are calculated If Vo exceed the Vo setting and at the same time 12 is less than the lo lt setting the function will issue an alarm after the operation delay has elapsed Table 6 11 Setting parameters of VT supervisor VTSV Value Default U2 gt 0 0 200 0 34 6 Upper setting for VT supervisor 0 0 200 0 100 0 Lower setting for VT supervisor 0 02 600 0 0 10 Operation delay On Off On VT supervisor on event On Off On VT supervisor off even 180 2015 Schneider Electric All rights re
292. pporting functions Disturbance recorder fz Frequency behind 2nd circuit breaker U12y Voltage behind circuit breaker Yes Yes Yes 0122 Voltage behind 2nd circuit breaker IL1RMS IL1 RMS for average sampling IL2RMS IL2 RMS for average sampling IL3RMS IL3 RMS for average sampling L1 L2 and L3 are IEC phase names For NEMA the phases as follows L1 A L2 B and L3 C 2015 Schneider Electric All rights reserved 63230 218 205 169 Disturbance recorder oection 6 Supporting functions Table 6 3 Disturbance recorder parameters Parameter Value Unit Description Note Mode Behavior in memory full situation Set Saturated No more recordings are accepted Overflow The oldest recorder will be overwritten SR Sample rate Set 32 cycle Waveform 16 cycle Waveform 8 cycle Waveform 1 10ms One cycle value 1 20ms One cycle value 1 200 ms Average 1 1s Average 1 5s Average 1 10s Average 1 15s Average 1 30s Average 1 1min Average Time S Recording length Set PreTrig Amount of recording data before the trigger moment Set MaxLen S Maximum time setting This value depends on sample rate number and type of the selected channels and the configured recording length Status Status of recordi
293. protection based on fundamental frequency signals The intermittent transient ground fault protection stage loinT gt should always be used together with the normal directional ground fault protection stages log log gt gt The transient stage gt may in worst case detect the start of a steady ground fault in wrong direction but will not trip because the peak value of a steady state sine wave l signal must also exceed the corresponding base frequency component s peak value in order to make the logi to trip The operation time of the transient stage logjyr should be lower than the settings of any directional ground fault stage to avoid any unnecessary trip from the log gt log gt gt stages The start signal of the loint gt Stage can be also used to block gt log gt gt stages of all paralell feeders 2015 Schneider Electric All rights reserved 99 Intermittent transient ground fault protection gt 67NI Intermittent transient ground fault protection lor Section 5 Protection functions Auto reclosing The start signal of any lo stage initiating auto reclosing AR can be used to block the gt stage to avoid the lojyr stage with a long intermittent setting to interfere with the AR cycle in the middle of discrimination time Usually the loj r stage itself is not used to initiate any AR For transient faults the AR will not help because the fault phenomena itself already includes
294. protection I 50 51 62 Remote controlled overcurrent scaling 62 Directional phase overcurrent ly 67 68 Current unbalance stage l5 46 in feeder mode 75 Current unbalance stage l5 46 in motor mode 76 Phase reversal incorrect phase sequence protection l2 A M 79 Stall protection 48 ues eos onto rto E bot toits 80 DU 82 Frequent start protection N gt 66 84 Undercurrent protection l lt 37 86 Directional ground fault protection loo 67N 86 Ground fault protection lg bON 51N 93 Intermittent transient ground fault protection logi r 67NI 98 Capacitor bank unbalance protection 98 Zero sequence voltage protection Vo 59N 104 Thermal overload protection T 49 111 Overvoltage protection V 59 115 Undervoltage protection V lt 27 117 Directional power protection P lt 32 122 Frequency Protection f gt lt fo gt lt lt 81 123 Rate of change of frequency ROCOF 81 125 DVINCW
295. protocols Modbus TCP and Modbus RTU These Modbus protocols are often used in power plants and in industrial applications The difference between these two protocols is the media Modbus TCP uses Ethernet and Modbus RTU uses asynchronous communication RS 485 optic fiber RS 232 VAMPSET will show the list of all available data items for Modbus A separate document Modbus Parameters is also available The Modbus communication is activated usually for remote port via a menu selection with parameter Protocol See the section Communication ports For ethernet interface configuration see the section Ethernet port Table 9 7 Parameters Parameter Value Unit Description Note Addr 1 247 Modbus address for the device Set Broadcast address 0 can be used for clock synchronizing Modbus TCP uses also the TCP port settings bit s 1200 bps Communication speed for Modbus RTU Set 2400 4800 9600 19200 Parity None Parity for Modbus RTU Set Even Odd Set An editable parameter password needed 63230 218 205 2015 Schneider Electric All rights reserved 267 Communication protocols oection 9 Communication Profibus DP The Profibus DP protocol is widely used in industry A built in Profibus option card or external 3CG is required Device profile continuous mode In this mode the device is sending a configured set of data parameters continuously to the Profibus DP master Th
296. ption Note Status Current status of the stage Blocked otart F Trip SCntr Cumulative start counter C TCntr Cumulative trip counter C SetGrp 1or2 Active setting group Set SGrpDI Digital signal to select the active setting group Set None Digital input VIx Virtual input LEDx LED indicator signal VOx Virtual output Force Off Force flag for status forcing for test purposes This is a Set common flag for all stages and output relays Automatically On reset by a 5 minute timeout Link ee able 5 46 ame for the supervised signa et See Table 5 46 Value of the supervised signal Cmp Mode of comparison Set gt Over protection lt Under protection Diff Difference AbsDiff Absolute difference Pickup Pick up value scaled to primary level Pickup pu Pick up setting in pu Set t S Definite operation time Set Hyster Dead band setting Set NoCmp pu Minimum value to start under comparison Mode et Set An editable parameter password needed C Can be cleared to zero F Editable when force flag is on Parameter Hecorded values of the latest eight faults There is detailed information available of the eight latest faults Time stamp fault value and elapsed delay Table 5 48 Recorded values of the programmable stages PrgN 99 Value Description yyyy mm dd Time stamp of the recording date hh mm ss ms Time stamp time of day Fault value Elapsed time of the operating time setting 100
297. quence voltage protection Frequent start protection lo lg Ip gt gt gt lp gt gt gt gt Directional overcurrent protection 67N gt log Directional ground fault low set stage sensitive definite or inverse time can be used as non directional 67NI loINT Intermittent transient ground fault 68F2 lo protection Magnetishing inrush 68F5 lis gt Transfomer overexitation 81H 81L f gt lt f gt gt lt lt Overfrequency and underfrequency protection 81L f lt f lt lt Underfrequency protection 81R df dt Rate of change of frequency ROCOF protection 99 Prg1 8 Programmable stages Only available when application mode is motor protection For NEMA U V Further the relay includes a disturbance recorder Arc detection is optionally available The relay communicates with other systems using common protocols such as the Modbus RTU ModbusTCP Profibus DP IEC 60870 5 103 IEC 60870 5 101 IEC 61850 SPA bus Ethernet IP and DNP 3 0 63230 218 205 2015 Schneider Electric All rights reserved 11 Related documents Section 1 General User interface The relay can be controlled in three ways e Locally with the push buttons on the relay front panel e Locally using a PC connected to the serial port on the front panel or on the rear panel of the relay both cannot be used simultaneously e Via remote control over the optional remote control port on the relay rear panel
298. r Measured value lbickup User s pick up setting A B C D Constant parameter according Table 5 54 Table 5 54 Constants for IEEE2 inverse delay equation Delay type Parameter A B C D E MI Moderately inverse 0 1735 0 6791 0 8 0 08 0 1271 NI Normally inverse 0 0274 2 2614 0 3 0 1899 9 1272 VI Very inverse 0 0615 0 7989 0 34 0 284 4 0505 El Extremely inverse 0 0399 0 2294 0 5 3 0094 0 7222 158 2015 Schneider Electric All rights reserved 63230 218 205 Section 5 Protection functions Inverse time operation Example for Delay type Moderately inverse MI 0 50 4 pu 2 pu A 0 1735 B 0 6791 C 0 8 D 0 08 E 0 127 0 5 ls 0 6791 008 0 127 4 4 t 4A 120 38 08 0 8 08 2 2 2 The operation time in this example will be 0 38 seconds The same result can be read from Figure 5 55 IEEE2 MI E IEEE2 NI 400 400 200 200 100 100 80 80 60 H 60 40 40 20 20 10 10 8 8 61 nm 6 M 20 T d gt 2 S 20 k 10 D UO 2 2 k 10 k 5 1 1 0 8 0 8 ETT 0 6 0 6 0 4 22 0 4 kz2 k
299. rawn I0 phasor in both figures is inside the trip area The angle offset and half sector size are user s parameters Table 5 15 Parameters of the directional ground fault stages los gt gt 67N Parameter Description Status Current status of the stage Blocked otart F Trip TripTime S Estimated time to trip SCntr Cumulative start counter Clr TCntr Cumulative trip counter Clr SetGrp 1or2 Active setting group Set SGrpDI Digital signal to select the active setting group Set None DIx Digital input VIx Virtual input LEDx LED indicator signal VOx Virtual output Force Off Force flag for status forcing for test purposes This Set is a common flag for all stages and output relays On Automatically reset by a 5 minute timeout lo pu The supervised value according the parameter In ios put below log only loCalc loPeak lo2Peak loRes pu Resistive part of l only when InUse Res loCap pu Capacitive part of lg only when InUse Cap log A Pick up value scaled to primary value 90 2015 Schneider Electric All rights reserved 63230 218 205 Section 5 Protection functions Directional ground fault protection lg 67N Parameter Value Unit Description Note loo pu Pick up setting relative to the parameter Input and Set the corresponding CT value Uo Pick up setting for Uo Set Uo Measured Up Curve Delay
300. rcuit supervision are the optional inputs DI19 and DI20 because they don t share their terminals with any other digital inputs 2015 Schneider Electric All rights reserved 63230 218 205 Section 11 Connections Rear panel V ux 48 240 Vdc VAMP relay Trip relay Alarm relay for trip circuit failure trip circuit failure alarm relay compariment circuit breaker compartment TCS2DIclosed Figure 10 13 Trip circuit supervision with two digital inputs The CB is closed The supervised circuitry in this CB position is double lined The digital input is in active state when the trip circuit is complete This is applicable for dry inputs DI7 D20 only 63230 218 205 2015 Schneider Electric All rights reserved 293 Rear panel Section 11 Connections V 48 Vdc 240 Vdc AL Digital inputs 4 1 comm Trip relay Alarm relay for trip circuit failure VAMP relay trip Circuit failure alarm relay compariment circuit breaker compartment close control CB V aux CLOSE COIL TCS2Dlopen Figure 10 14 Trip circuit supervision with two digital inputs The CB is in the open position The two digital inputs are now in series NOTE If for example 0113 and DI7 are used as the upper and lower digital inputs in the Figure 10 14 the usage of 018 0114 is limited to the same circuitry sharing the Vay in the common terminal and the 0114 0118
301. re are 6 digital inputs available for control purposes The polarity normal open NO normal closed NC and a delay can be configured according the application The signals are available for the output matrix block matrix user s programmable logic etc The contacts connected to digital inputs DI1 DI6 must be dry potential free These inputs use the common internal 48 Vdc wetting voltage from terminal X3 1 only Other digital inputs supported by VAMP 255 need an external control voltage ac or dc The voltage nominal activation level can be selected in the ordering code see Section 14 Order information It is possible to use two different control voltages for 017 20 Selection in order code Nominal voltage 24 3 V dc 110 V ac 110 6 V dc 220 V ac 7 220 V dc When 110 or 220 V ac voltage is used to activate the digital Inputs the AC mode should be selected as shown below DIGITAL INPUTS DIGITAL INPUTS Mode AC Figure 8 1 AC mode selection in VAMPSET These inputs are ideal for transferring the status information of switching devices into the device Please note that it is possible to use two different control voltages for the inputs 2015 Schneider Electric All rights reserved 63230 218 205 Section 8 Control functions Table 8 2 Summary of digital inputs Digital inputs DI Terminal O
302. ready Ready information Max ctrl pulse length 0 02 600 s Pulse length for open and close commands Completion timeout 0 02 600 s Timeout of ready indication Object control Open Close Direct object control If changing states takes longer than the time defined by Max ctrl pulse length setting object does not complete and Object failure matrix signal is set Also undefined event is generated Completion timeout is only used for the ready indication If DI for obj ready is not set completion timeout has no meaning 242 2015 Schneider Electric All rights reserved 63230 218 205 Section 8 Control functions Setting Controllable objects Each controllable object has 2 control signals in matrix Output signal Description Object x Open Open control signal for the object Object x Close Close control signal for the object These signals send control pulse when an object is controlled by digital input remote bus auto reclose etc Each read only object has the following settings Value Description Open DI for obj open DI for obj close None any digital input virtual input or virtual information Close output information Object timeout 0 02 600 s Timeout for state changes If changing states takes longer than the time defined by Object timeout setting and Object failure matrix signal is set
303. relay functions on a working current principle This means that the SF relay is energized when the auxiliary supply is on and the arc flash protection is healthy The device runs self diagnostic tests for hardware and software in boot sequence and also performs runtime checking Permanent inoperative state or Detected Fatal Error If the device has a persistent detected fatal error the device releases SF relay contact and status LED is set on Local panel will also display a detected error message The detected fatal error state is entered when the device is not able to handle main functions Detected Runtime Errors When self diagnostic function detects a runtime error Selfdiag matrix signal is set and an event E56 is generated In case the detected runtime error was only temporary an off event is generated E57 The self diagnostic detected error can be reset via local HMI Diagnostic registers There are four 16 bit diagnostic registers which are readable through remote protocols The following table shows the meaning of each diagnostic register and their bits 2015 Schneider Electric All rights reserved 63230 218 205 Section 6 Supporting functions Diagnostics Register Description SelfDiag1 0 LSB T1 Output relay detected error 1 T2 2 T3 3 T4 4 A1 5 A2 6 7 A4 8 A5 SelfDiag3 0 LSB DAC Potential mA output detected error 1 STACK OS stack detected error 2 MemChk OS memor
304. repeating self extinguishing Operation time peak amount counter and intermittent time coordination Algorithm has three independently settable parameters operation delay required amount of peaks and intermittent time All requirements need to be satisfied before stage issues trip signal There is also settable reset delay to help ensure that stage does not release before circuit breaker has operated Setting range for required amount of peaks is 1 20 and the setting range for operational delay is 0 04 300s Reset delay setting range is 0 06 300s Intermittent time setting is 0 00 300s If in example setting for peaks is set to 2 and setting for operation delay is set to 160ms and intermittent time is set to 200 ms then function starts calculating operation delay from first peak and after second peak in 80 ms peak amount criteria is satisfied and when 160ms comes full operation time criteria is satisfied and the stage Issues trip Figure 5 25 If second peak does not come before operational delay comes full the stage is released after intermittent time has come full But if the second peak comes after operation time has come full but still inside intermittent time then trip is issued instantly Figure 5 26 If intermittent time comes full before operation delay comes full the stage is released Figure 5 27 There are a couple of limitations to avoid completely incorrect settings The algorithm assumes that peaks can t come m
305. restart This value can be cleared if the operating level is at least Operator Cntr2 The stage has tripped two times since the last reset or restart This value can be cleared if the operating level is at least Operator e SetGrp 1 The active setting group is one This value can be edited if the operating level is at least Operator Setting groups are explained in the section Setting groups e SGrpDI The setting group is not controlled by any digital input This value can be edited if the operating level is at least Configurator Force Off The status forcing and output relay forcing is disabled This force flag status can be set to On or back to Off if the operating level is at least Configurator If no front panel button is pressed within five minutes and there is no VAMPSET communication the force flag will be set to Off position The forcing is explained in the section Forced control Force 2015 Schneider Electric All rights reserved 23 Configuration and parameter setting 24 Section 2 Local panel user interface Second menu of I gt gt 50 51 stage second menu SET 50 51 Stage setting group 1 ExDI IL max 403A ExDO Jj Status 3 Prot gt gt 1013A gt gt 2 50xIn t gt gt 0 605 Figure 2 5 Second menu next on the right of 50 51 stage This is the main setting menu The content is Stage setting group 1 These are the group 1 setting values
306. result in death or serious injury Rear panel VAMP 255 Note L1 L2 and L3 are IEC phase names For NEMA the phases are as follows L1 A L2 B and L3 2C 296 2015 Schneider Electric All rights reserved 63230 218 205 Section 11 Connections Rear panel VAMP255BACK Figure 11 1 Connections on the rear panel of the VAMP 255 63230 218 205 2015 Schneider Electric All rights reserved 297 Section 11 Connections Rear panel VW 32V 9552 dWWVA 6l Ellon SI l an LL en gt i jin el PX cov D gt EA o TOT 25 e f x ts STI 28 21 re I8 TS TTI Figure 11 2 2 Connections on the rear panel of the VAMP 255 with mA option 63230 218 205 2015 Schneider Electric All rights reserved 298 Section 11 Terminal X1 left side 13 15 17 Terminal X1 right side 19 O OQ 10 14 18 Connections Rear panel The feeder and motor manager VAMP 255 with and without the optional analog outputs is connected to the protected object through the following measuring and control connections A 12 16 20 Symbol Description 1 IL1 S1 Phase current L1 S1 3 IL2 S1 Phase current L2 S1 5 IL3 S1 Phase current L3 S1 T lo1 1A S1 Residual current 101 51 9 lo2 5A S1 Residual current 102 51 11 Ua See the section Voltage measurement modes 13 Ub See the section
307. ric All rights reserved 303 oection 11 Connections Terminal X6 with 0119 0120 option No Symbol Description Digital input DI19 19 2 DI19 Digital input 19 3 DI20 Digital input 20 4 DI20 Digital input 20 5 _ _ 6 S1 gt Arc sensor 1 positive connector Arc sensor S1 gt 1 negative connector Arc sensor itself is polarity free 2015 Schneider Electric All rights reserved 304 63230 218 205 Section 11 Connections Rear panel 81 3 oo 77 59 1v201 Figure 11 3 Connections on the rear panel of the VAMP 230 63230 218 205 2015 Schneider Electric All rights reserved 305 Section 11 Connections V230BACK MA LLL Figure 11 4 Connections on the rear panel of the VAMP 230 with mA option 306 2015 Schneider Electric All rights reserved 63230 218 205 Section 11 Connections Terminal X1 left side Terminal X1 right side N C 13 15 17 19 10 12 14 16 18 20 Symbol IL1 S1 IL2 S1 IL3 S1 lo1 1A S1 lo2 5A S1 Ua Ub Uc Symbol IL1 S2 IL2 S2 IL3 S2 lo1 1A S2 lo2 5A S2 Ua Ub Uc Rear panel The feeder and motor manager VAMP 230 with and without the optional analog outputs is connected to the protected object through the following measuring and control connections Description Phase current L1 S1 Phas
308. rol connection option Section 12 Technical data Number of ports Electrical connection 1 on rear panel TTL standard HS 485 option HS 232 option Plastic fiber connection option Glass fiber connection option Ethernet 10 Base T option external module 100M Ethernet fiber 100M Ethernet copper RJ 45 Data transfer rate 1 200 19 200 kb s Protocols Modbus RTU master Modbus RTU slave SPA bus slave IEC 60870 5 103 Profibus DP option Modbus TCP internal external optional module IEC 60870 5 101 IEC 60870 5 101 TCP Arc detection interface option NOTE Three arc binary inputs can be connected to one arc binary output without an external amplifier 342 DNP 3 0 DNP 3 0 TCP IEC 61850 Number of arc sensor inputs 2 Sensor type to be connected VA 1 DA Operating voltage level 12 V dc Current draw when active gt 11 9 mA Current draw range 1 3 31 mA Note If the draw is outside the range either sensor or the wiring is defected Number of binary inputs Operating voltage level 1 optically isolated 48 V dc Number of binary outputs Operating voltage level 1 transistor controlled 48 V dc 2015 Schneider Electric All rights reserved 63230 218 205 Section 12 Technical data Connections Analog output connection option Number of analog mA output 4 channels Maximum output current 1
309. rops below 5 of rated Synchrocheck function Table 12 38 Synchrocheck function Sync mode Off Async Sync Voltage check mode DD DL LD DD DL DD LD DL LD DD DL LD CB closing time 0 04 0 6s Upeaplimit setting 10 120 YUN Ui ivelimit setting 10 120 Un Frequency difference 0 01 1 00 Hz Voltage difference 1 60 Un Phase angle difference 2 90 Request timeout 0 1 600 0 s Stage operation range 46 0 64 0 Hz Reset ratio U Inaccuracy voltage 3 UN frequency 20 mHz phase angle 2 when Af lt 0 2 Hz else 5 operating time 1 or 30 ms NOTE When sync mode is used Af should be less lt 0 2 Hz 362 2015 Schneider Electric All rights reserved 63230 218 205 Section 12 Technical data Protection functions Arc fault detection option The operation of the arc detection depends on the setting value of the Arcl gt Arclo gt and Arclos gt current limits The arc current limits cannot be set unless the relay is provided with the optional arc protection card Table 12 39 Arc detection stage Arcl gt 50ARC Arclg gt SONARC Arclos gt 63230 218 205 50NARC Setting range 0 5 10 0 x IN Arc sensor connection 51 S2 51 52 BI 51 52 51 52 Operating time Light only 13 ms Operating time 4 x Iser light 17 ms Operating time BIN 1
310. round fault location algorithm The algorithm can locate an ground fault accurately in radically operated compensated grounded networks The function can locate a fault only if the fault resistance is low say less than 50 ohms The fault location is given in reactance value This value can then be exported for example with event to a DMS Distribution Management System The system can then localize the fault and display it on a map The fault location must be used in the incoming bay of the substation Therefore the fault location is obtained for the whole network with just one device This is very cost effective upgrade of an existing system Please note also that the ground fault location function requires a change during an ground fault This change is done by switching the secondary resistor of the compensation coil on or off The fault should be allowed to be on at least 200 ms of which 100 ms without the resistor The resistor change can be done by using the logic functionality of the device 2015 Schneider Electric All rights reserved 209 Ground fault locator 3 X S Parameter Section 6 Supporting functions The reactance value is converted to distance in the DMS The following formula is used Xo X X X Xo X Xo distance in km reactance calculated by the device zero sequence reactance per kilometre of the line positive sequence reactance per kilometre of the line negative sequence re
311. rrent injected to the relay s inputs is 7 A gt Per unit current is 7 x 750 5 x 525 2 00 pu 2 00 X IMOT 200 3 Per unit to secondary for feeder mode and Arcl gt CT 750 5 The device setting is 2 pu 200 secondary current is legc 2 2x 5 10A 63230 218 205 2015 Schneider Electric All rights reserved 227 Primary secondary and per unit scaling oection 7 Measurement functions 4 Perunit and percent to secondary for phase currents in motor mode excluding Arcl gt CT 2750 5 luor 525 A The device setting is 2 x 2 pu 200 96 Secondary current is lsgc 2 5 x 525 750 7 5 Secondary to per unit for residual current Input is Ip or Igo CTgo 2 50 1 Current injected to the relay s input is 30 mA Per unit current is Ipy 0 03 1 0 03 pu 3 6 Perunit to secondary for residual current Input is Ip Igo CTo 2 50 1 The relay setting is 0 03 pu 3 96 Secondary current is lsgc 0 03 x 1 30 mA Secondary to per unit for residual current Input Is loca CT 2750 5 Currents injected to the relay s l4 input is 0 5 A lg lc 0 Per unit current is 0 5 5 0 1 pu 10 8 Per unit to secondary for residual current Input is loCalc CT 750 5 The relay setting is 0 1 pu 10 If Ig lc 0 then secondary current Ip is lagc 0 1x5 0 5A 228 2015 Schneider Electric All rights reserved 63230 218 205 oection 7 Measurement fu
312. rs and output relays A DANGER HAZARD OF ELECTRIC SHOCK EXPLOSION OR ARC FLASH Remove the cause of the event that resulted in the latched output relay Failure to follow these instructions will result in death serious injury or equipment damage All the indicators and output relays can be given a latching function in the configuration There are several ways to reset latched indicators and relays e From the alarm list move back to the initial display by pushing for approx 3s Then reset the latched indicators and output relays by pushing e Acknowledge each event in the alarm list one by one by pushing equivalent times Then in the initial display reset the latched indicators and output relays by pushing The latched indicators and relays can also be reset via a remote communication bus or via a digital input configured for that purpose The relay is provided with a backlighted 128 x 64 LCD dot matrix display The display can accommodate up to 21 characters horizontally and eight rows vertically at one time The display has two different purposes one is to show the single line diagram of the relay with the object status measurement values identification etc Figure 2 1 The other purpose is to show the configuration and parameterization values of the relay Figure 2 2 Tho 18 3 a4 oo 240 kW Q3 60 kvar 50 02 Hz Q9 Figure 2 1 Sections of the LCD dot matrix display 1
313. rse delay of type Rl 63230 218 205 Figure 5 60 Inverse delay of type RXIDG 2015 Schneider Electric All rights reserved 161 Inverse time operation Section 6 Supporting functions Free parameterization using IEC IEEE and IEEE2 equations This mode is activated by setting delay type to Parameters and then editing the delay function constants i e the parameters A E The idea is to use the standard equations with one s own constants instead of the standardized constants shown in the previous section Example for GE IAC51 delay type inverse 0 50 4 2 pu A 0 2078 B 0 8630 C 0 8000 D 0 4180 E 0 1947 5 102078 0 5630 a 0 4180 0 1947 037 5 08 g os 2 9 The operation time in this example will be 0 37 seconds The resulting time current characteristic of this example matches quite well with the characteristic of the old electromechanical IAC51 induction disc relay Inverse time setting detected error signal The inverse time setting detected error signal will become active if interpolation with the given parameters is not possible See the section Inverse time operation for more details Limitations The minimum definite time delay start latest when the measured value is twenty times the setting However there are limitations at high setting values due to the measurement range See the section Inverse time operation for more details 162 201
314. rt 1st INST and TCP port 2 d INST Two different protocols can be used simultaneously on one physical interface both protocols use the same IP address and MAC address but different IP port Protocol configuration menu contains address and other related information for the ethernet port TCP port 1st and 2nd instance include selection for the protocol IP port settings and message detected error timeout counters More information about the protocol configuration menu on table below Table 9 4 Main configuration parameters local display built in Ethernet port Parameter Value Unit Description Protocol Protocol selection for the extension port Set None Command line interface for VAMPSET ModbusTCPs Modbus TCP slave IEC 101 IEC 101 IEC 61850 IEC 61850 protocol EtherNet IP Ethernet IP protocol DNP3 DNP TCP Port nnn Ip port for protocol default 102 Set IpAddr n n n n Internet protocol address set with Set VAMPSET NetMsk n n n n Net mask set with VAMPSET Set Gatew default 0 0 0 0 Gateway IP address set with VAMPSET Set NTPSvr n n n n Network time protocol server set with Set VAMPSET 0 0 0 0 SNTP KeepAlive nn TCP keepalive interval set FTP server on off Enable FTP server Set FTP speed 4 Kb s default Maximum transmission speed for FTP Set FTP passwor
315. russian language packets 10 65 100 Mbps option card support 10 67 Default font sizes changed 0 gt gt minimum delay setting changed 0 05s with 0 01s step Popup window added for language packet init EF items EFDX EFDFph EFctr and EFDFItDist added to IEC103 10 74 I gt and lo lo stages with faster operation time 10 85 Virtual output events added 10 97 Autoreclose when two CB s are used and both closed AR is blocked start counter is not increased after manual CB close 5th harmonic blocking stage added 10 106 GOOSE supervision signals added Automatic LED latch release added Disturbance recorder full event added Motor load current in per cent 10 108 Use of recorder memory in percents added Various additions to IEC 61850 10 116 IP and other TCP parameters are able to change without reboot Logic output numbering is not changed when changes are made in the logic NOTE Minimum VAMPSet version of 2 2 97 required 10 118 Enable sending of analog data in GOOSE message Day light saving DST rules added for system clock HMI changes e Order of the first displays changed 1 measurement 2 mimic 3 title e timeout does not apply if the first 3 displays are active 63230 218 205 2015 Schneider Electric All rights reserved 3 1 3 2 Section 15 Revision history 10 135 Fast lt 30ms total operation time for I gt gt gt stage Ad
316. rved 63230 218 205 Section 6 Supporting functions System clock and synchronization 63230 218 205 synchronisation with DI Clock can be synchronized by reading minute pulses from digital inputs virtual inputs or virtual outputs Sync source is selected with syncDI setting When rising edge is detected from the selected input system clock is adjusted to the nearest minute Length of digital input pulse should be at least 50 ms Delay of the selected digital input should be set to zero oynchronisation correction If the sync source has a known offset delay it can be compensated with SyOS setting This is useful for compensating hardware delays or transfer delays of communication protocols A positive value will compensate a lagging external sync and communication delays A negative value will compensate any leading offset of the external synch source oync source When the device receives new sync message the sync source display is updated If no new sync messages are received within next 1 5 minutes the device will change to internal sync mode sync source IRIG B003 IRIG B003 synchronization is supported with a dedicated communication option with either a two pole or two pins in a D9 rear connector See Section 14 Order information IRIG BO003 input clock signal voltage level is TLL The input clock signal originated in the GPS receiver must be taken to multiple relays trough an IRIG B distribution module This module
317. s Table 5 22 Setting parameters of capacitor bank unbalance protection Ip gt gt gt lo gt gt gt gt 5ON 51N Parameter Value Unit Default Description Input lo1 lo2 loCalc lo2 Current measurement Input NOTE Do not use the calculated value which is only for ground fault protection purposes lo gt gt gt 0 01 20 00 pu 0 10 Setting value lo gt gt gt gt 0 01 20 00 pu 0 20 Setting value gt 0 08 300 00 S 0 50 lo gt gt gt Definite operating time 1 00 lo gt gt gt gt CMode Off On lo gt gt gt Off Compensation selection Off Normal Location lo gt gt gt gt SaveBa Get Trigger the phasor recording SetBal 0 010 3 000 pu 0 050 Compensation level S On On Off On Start on event S Off On Off On Start off event T On On Off On Trip on event T Off On Off On Trip off event DloSav On Off Off Recording trigged event DloSav On Off Off Recording ended event 106 2014 Schneider Electric All rights reserved 63230 218 205 Section 5 Protection functions Capacitor bank unbalance protection Table 5 23 Measured and recorded values of capacitor bank unbalance protection gt gt gt gt gt gt gt bON 51N Parameter Value Unit Description Measured values lo pu unbalance current includ
318. s V The choices are V volt or kV kilovolt e Scaling for active reactive and apparent power Power The choices are k for KW kvar and kVA or M for MW Mvar and MVA Device info e Relay type Type VAMP 2xx e Serial number SerN e Software version PrgVer e Bootcode version BootVer Date time setup e Day month and year Date e Time of day Time e Date format Style The choices are yyyy mm dd dd nn yyyy and mm dd yyyy Clock synchronisation e Digital input for minute sync pulse SyncDl If any digital input is not used for synchronization select e Daylight saving time for NTP synchronization DST e Detected source of synchronization SyScr e Synchronization message counter MsgCnt e Latest synchronization deviation Dev The following parameters are visible only when the access level is higher than User e Offset i e constant error of the synchronization source SyOS e Auto adjust interval AAlIntv Average drift direction AvDrft Lead or lag e Average synchronization deviation FilDev Protocol menu Bus There are three optional communication ports in the rear panel The availability depends on the communication options see Section 12 Order information 63230 218 205 2015 Schneider Electric All rights reserved 45 Configuration and parameter setting oection 2 Local panel user interface 46 In addition there is a connector in the front panel ov
319. s follows L1 A L2 B and L3 C Energy pulse outputs The device can be configured to send a pulse whenever certain amount of energy has been imported or exported The principle is presented in Figure 6 5 Each time the energy level reaches the pulse size an output relay is activated and the relay will be active as long as defined by a pulse duration setting Configurable 100 ms 5 000 ms Configurable 10 10 000 kWh kvarh Figure 6 5 Principle of energy pulses The relay has four energy pulse outputs The output channels are e Active exported energy e Reactive exported energy e Active imported energy e Reactive imported energy Each channel can be connected to any combination of the output relays using output matrix The parameters for the energy pulses can be found in the E menu under the submenus E PULSE SIZES and E PULSE DURATION 188 2015 Schneider Electric All rights reserved 63230 218 205 oection 6 Supporting functions 6 7 Voltage transformer supervision Table 6 15 Energy pulse output parameters Parameter Value Unit Description E PULSE SIZES E 10 10 000 kWh Pulse size of active exported energy Eq 10 10 000 kvarh Pulse size of reactive exported energy E 10 10 000 kWh Pulse size of active imported energy Eq 10 10 000 kvarh Pulse size of reactive imported energy E PULSE DURATION E 100 5000 ms Pulse length
320. scription Detected communication read errors 1 16 Bit number of Modbus register value Modbus register type CoilS InputS InputR or HoldingR 1 9999 Modbus register for the measurement 1 247 Modbus address of the I O device 0 1 Active state On Off Enabling for measurement 63230 218 205 2015 Schneider Electric All rights reserved 321 External option modules Section 11 Connections External digital outputs configuration VAMPSET only Description Detected communication errors Modbus register for the measurement Modbus address of the I O device Output state a 1 9999 E CL mme c 1 247 oma eT at ce LLJ LLJ 0 1 On Off Enabling for measurement 322 2015 Schneider Electric All rights reserved 63230 218 205 Section 11 Connections External option modules External analog outputs configuration VAMPSET only Range Description HoldingR HoldingR HoldingR EXTERNAL ANALOG OUTPUTS Detected communication errors 32768 32767 0 65535 Modbus value corresponding Linked Val Max Modbus value corresponding Linked Val Min InputR or HoldingR Modbus register type 1 9999 Modbus register for the output 1 247 Modbus address of the I O device Maximum limit for lined value corresponding to Modbus Max 0 42
321. secondary circuits first Replace all devices doors and covers before turning on power to this unit Failure to follow these instructions will result in death or serious injury Communication ports The device has three communication ports as standard A fourth port Ethernet is available as option See Figure 9 1 There are three communication ports in the rear panel The Ethernet port is optional The X4 connector includes two ports local port and extension port The front panel RS 232 port will shut off the local port on the rear panel when a VX003 cable is inserted 63230 218 205 2015 Schneider Electric All rights reserved 257 Communication ports Section 9 Communication CommunicationPorts LOCAL PORT COMMUNICATION PORTS EXTENSION REMOTE PORT DATA BUS PORT Front panel in use Default TTL for external adapters only Options E RS 485 isolated Fiber optic Profibus Ethernet and TTL CkS RS 485 Notisolated XS REM O TE TTL is for external adapters only 5 Optional ETHERNET E bow converter es em Mum ee l FRONTPANEL 258 Figure 9 1 Communication ports and connectors By default the X5 is a 095 type connector with TTL interface The DSH signal from the front panel port selects the active connector for the RS232 local port By default the remote port has a TTL interface It can only be used tog
322. sensitive to the resistive component of the selected l signal This mode is used with compensated networks resonant grounding and networks grounded with a high resistance Compensation is usually done with a Petersen coil between the neutral point of the main transformer and ground In this context high resistance means that the fault current is limited to be less than the rated phase current The trip area is a half plane as drawn in Figure 5 20 The base angle is usually set to zero degrees Cap The stage is sensitive to the capacitive component of the selected ly signal This mode is used with ungrounded networks The trip area is a half plane as drawn in Figure 5 20 The base angle is usually set to zero degrees 63230 218 205 2015 Schneider Electric All rights reserved 87 Directional ground fault protection lg oection 5 Protection functions 88 e Sector This mode is used with networks grounded with a small resistance In this context small means that a fault current may be more than the rated phase currents The trip area has a shape of a sector as drawn in Figure 5 21 The base angle is usually set to zero degrees or slightly on the lagging inductive side i e negative angle e Undir This mode makes the stage equal to the undirectional stage lo The phase angle and Vg amplitude setting are discarded Only the amplitude of the selected lg input is supervised Input signal selection Each stage can be conn
323. served 63230 218 205 Section 6 Supporting functions 6 7 Voltage transformer supervision Table 6 12 Measured and recorded values of VT supervisor VTSV Parameter Value Uni Description Measured value U2 Measured negative sequence voltage l2 Measured negative sequence current Recorded Date E Date of VT supervision alarm Values Time Time of VT supervision alarm U2 Recorded negative sequence voltage 12 Recorded negative sequence current For details of setting ranges see the section Supporting functions 63230 218 205 Circuit breaker condition monitoring The relay has a condition monitoring function that supervises the wearing of the circuit breaker The condition monitoring can give an alarm for the need of CB maintenance The CB wear function measures the breaking current of each CB pole separately and then estimates the condition of the CB accordingly the permissible cycle diagram The breaking current is registered when the trip relay supervised by the circuit breaker failure protection CBFP is activated See the section Circuit breaker failure protection CBFP 50BF for CBFP and the setting parameter CBrelay Breaker curve and its approximation The permissible cycle diagram is usually available in the documentation of the CB manufacturer Figure 6 4 The diagram specifies the permissible number of cycles for every level of the breaking current This diagram is paramet
324. sing device to confirm that the power is off e Avoid open current transformer connections Replace all devices doors and covers before turning on power to this unit Failure to follow these instructions will result in death or serious injury The VAMP relay is capable of detecting faults originating from the current transformers CTs or the wiring from the CTs to the relay terminals Furthermore the function can detect an open secondary of a CT and an open secondary of a CT can cause hazardous voltages and equipment damage The CT supervisor function measures phase currents If one of the three phase currents drops below lyiy setting while another phase current is exceeding the lyjAx setting the function will issue an alarm after the operation delay has elapsed Table 6 9 Setting parameters of CT supervisor CTSV Parameter Value Default Description Imax gt 0 0 10 0 2 0 Upper setting for CT supervisor Imin 0 0 10 0 0 2 Lower setting for CT supervisor gt 0 02 600 0 Operation delay CT on On Off CT supervisor on event CT off On Off CT supervisor off even 63230 218 205 2015 Schneider Electric All rights reserved 179 Voltage transformer supervision oection 6 Supporting functions Table 6 10 Measured and recorded values of CT supervisor CTSV Parameter Value Unit Measured value ILmax A Maximum of phase currents ILmin A Minimum of
325. stage will be blocked when the biggest of the three line to line voltages drops below the given limit The idea is to avoid purposeless tripping when voltage is switched off If the operating time is less than 0 08 s the blocking level setting should not be less than 1596 for the blocking action to be fast enough The self blocking can be disabled by setting the low voltage block limit equal to zero Figure 5 34 shows an example of low voltage self blocking 2015 Schneider Electric All rights reserved 117 5 20 Undervoltage protection U 27 5 Protection functions Table 5 28 Recorded values of the overvoltage stages 8 latest faults V V V gt gt gt Parameter Value Unit Description yyyy mm dd Time stamp of the recording date hh mm ss ms Time stamp time of day Fit Un Maximum fault voltage EDly Elapsed time of the operating time setting 100 trip SetGrp 1 Active setting group during fault 2 118 2014 Schneider Electric All rights reserved 63230 218 204 oection 5 Protection functions Undervoltage protection U 27 Undervoltage protection V 27 This is a basic undervoltage protection The function measures the three line to line voltages and whenever the smallest of them drops below the user s pick up setting of a particular stage this stage picks up and a start signal is issued If the fault situation remains on longer than the user s operation time de
326. started at shot 2 5 the starting delay is taken from the discrimination time setting of the previous shot For example if Shot 3 is the first shot for AR2 the starting delay for this sequence is defined by Discrimination time of Shot 2 for AR2 Critical AR request Critical AR request stops the AR sequence and causes final tripping Critical request is ignored when sequence is not running and also when AR is reclaiming Critical request is accepted during dead time and discrimination time 2015 Schneider Electric All rights reserved 63230 218 205 Section 8 Control functions Auto reclose function 79 Shot active matrix signals When starting delay has elapsed active signal of the first shot is set If successful reclosing is executed at the end of the shot the active signal will be reset after reclaim time If reclosing was not successful or new fault appears during reclaim time the active of the current shot is reset and active signal of the next shot is set if there are any shots left before final trip AR running matrix signal This signal indicates dead time The signal is set after controlling CB open When dead time ends the signal is reset and CB is controlled close Final trip matrix signals There are 5 final trip signals in the matrix one for each AR request 1 4 and critical When final trip is generated one of these signals is set according to the AR request which caused the final tripping Th
327. sue This can be easily calculated However the setting must have some margin possibly 10 less than the calculated value since there are some tolerances in the primary equipment as well as in the relay measurement circuit Then the time setting of l gt gt gt gt is not used for tripping purposes The time setting specifies how long the device must wait until it is certain that it detects an issue in the bank After this time has elapsed the stage Ip gt gt gt gt gt makes a new compensation automatically and the measured unbalance current for this stage is now zero Note the automatic compensation does not effect on the measured unbalance current of stage Ip gt gt gt If it detects an issue in the bank the algorithm checks the phase angle of the unbalance current related to the phase angle of the phase current l4 Based on this angle the algorithm can increase the corresponding detected issue counter there are six counters The user can set for the stage Ip gt gt gt gt the allowed number of detected issues e g if set to three elements the fourth detected issue will issue the trip signal The detected issue location function is used with internal fused capacitor and filter banks There is no need to use it with fuseless or external fused capacitor and filter banks nor with the reactor banks 2015 Schneider Electric All rights reserved 105 Capacitor bank unbalance protection Section 5 Protection function
328. t PICK UP Figure 5 4 Behavior of a less than comparator For example in under voltage and under frequency stages the hysteresis dead band acts according this figure Application modes 63230 218 205 The application modes available are the feeder protection mode and the motor protection mode In the feeder protection mode all current dependent protection functions are relative to nominal current In derived by CT ratios The motor protection functions are unavailable in the feeder protection mode In the motor protection mode all current dependent protection functions are relative to motor s nominal current Imot The motor protection mode enables motor protection functions All functions which are available in the feeder protection mode are also available in the motor protection mode Default value of the application mode is the feeder protection mode 2015 Schneider Electric All rights reserved 61 Overcurrent protection I gt 50 51 oection 5 Protection functions The application mode can be changed with VAMPSET software or from CONF menu of the device Changing the application mode requires configurator password Current protection function dependencies The current based protection functions are relative to ljyopg which is dependent of the application mode In the motor protection mode all of the current based functions are relative to Ivor and in the feeder protection mode to ly with the following exceptions lo
329. t n Set 1 4 Set An editable parameter password needed The six virtual outputs do act like output relays but there are no physical contacts Virtual outputs are shown in the output matrix and the block matrix Virtual outputs can be used with the user s programmable logic and to change the active setting group etc 63230 218 205 2015 Schneider Electric All rights reserved 239 Output matrix Output matrix 240 Section 8 Control functions By means of the output matrix the output signals of the various protection stages digital inputs logic outputs and other internal signals can be connected to the output relays front panel indicators virtual outputs etc There are two LED indicators named Alarm and Trip on the front panel Furthermore there are three general purpose LED indicators B and C available for customer specific indications In addition the triggering of the disturbance recorder DR and virtual outputs are configurable in the output matrix an example in Figure 8 2 An output relay or indicator LED can be configured as latched or non latched A non latched relay follows the controlling signal A latched relay remains activated although the controlling signal releases There is a common release latched signal to release all the latched relays This release signal resets all the latched output relays and indicators The reset signal can be given via a digi
330. tal harmonic distortion of input Uc f Frequency behind circuit breaker fz Frequency behind 2 circuit breaker U12 Voltage behind circuit breaker U12z Voltage behind 2 circuit breaker IL1RMS IL1 RMS for average sampling IL2RMS IL2 RMS for average sampling IL3RMS IL3 RMS for average sampling ILmin ILmax Minimum and maximum of phase currents ULLmin ULLmax Minimum and maximum of line voltages ULNmin ULNmax Minimum and maximum of phase voltages VAI VAI2 VAIS VAI4 VAI5 Virtual analog inputs 1 2 3 4 5 GOOSE 2015 Schneider Electric All rights reserved 63230 218 205 oection 5 Protection functions Programmable stages 99 63230 218 205 Eight independent stages The device has eight independent programmable stages Each programmable stage can be enabled or disabled to fit the intended application Setting groups There are two settings groups available Switching between setting groups can be controlled by digital inputs virtual inputs mimic display communication logic and manually There are two identical stages available with independent setting parameters 2015 Schneider Electric All rights reserved 143 Programmable stages 99 Section 5 Protection functions Table 5 47 Parameters of the programmable stages PrgN 99 Parameter Value Unit Descri
331. tal input via a keypad or through communication Any digital input can be used for resetting The selection of the input is done with the VAMPSET software under the menu Release output matrix latches Under the same menu the Release latches parameter can be used for resetting OUTPUT MATRIX cted paler and latched a Fa d D 1 gt gt start I gt gt trip gt gt gt gt start gt gt gt trip IDir start IDir gt trip VAMP 200 series output matrix Figure 8 2 Outout matrix 2015 Schneider Electric All rights reserved 63230 218 205 oection 8 Control functions Virtual inputs and outputs Blocking matrix By means of a blocking matrix the operation of any protection stage can be blocked The blocking signal can originate from the digital inputs DI1 to DI6 20 or it can be a start or trip signal from a protection stage or an output signal from the user s programmable logic In the block matrix Figure 8 3 an active blocking is indicated with a black dot in the crossing point of a blocking signal and the signal to be blocked In VAMP 230 the display shows 20 DI but only 6 of them are available Digital input 19 amp 20 are only available with DI19 DI20 option Output relays Operation LJCJCJCJCJCJCJLJ indicators 88 6 Stage 1 mm v mE Start Trip fd Q LESE Block d Relay Reset al latches Figure
332. te style Time zone Enable DST Event enabling Status of DST Status of DST ACTIVE Next DST changes Next DSTbegin date 2015 03 29 DSTbegin hour 03 00 Next DSTend date 2014 10 26 DSTend hour DST 0400 DST Daylight time standards vary widely throughout the world Traditional daylight summer time is configured as one 1 hour positive bias The new US Canada DST standard adopted in the spring of 2007 is one 1 hour positive bias starting at 2 00am on the second sunday in March and ending at 2 00am on the first Sunday in November In the European Union daylight change times are defined relative to the Coordinated Universal Time UTC time of day instead of local time of day as in U S European customers please carefully find out local country rules for DST 2015 Schneider Electric All rights reserved 191 System clock and synchronization oection 6 Supporting functions 192 The daylight saving rules for Finland are the IED defaults 24 hour clock Daylight saving time start Last Sunday of March at 03 00 Daylight saving time end Last Sunday of October at 04 00 DSTbegin rule DSTbegin month Ordinal of day of week Day of week DS5Tbegin hour D5Tend rule DSTend month Ordinal of day of week Day of week DSTend hour DST To help ensure proper hands free year around operation automatic daylight time adjustments must be configured using the Enable DST and not with the time zone offset opt
333. the trip command If this time is longer than the operating time of the CBFP stage the CBFP stage activates another output relay which will remain activated until the primary trip relay resets The CBFP stage is supervising all the protection stages using the same selected trip relay since it supervises the control signal of this device See the section Output matrix Table 5 44 Parameters of the circuit breaker failure stage CBFP 50BF Parameter Value Unit Description Note Status Current status of the stage Blocked Start F Trip SCntr Cumulative start counter C TCntr Cumulative trip counter C Force Off Force flag for status forcing for test purposes This Set is a common flag for all stages and output relays On Automatically reset by a 5 minute timeout Cbrelay The supervised output relay Set 1 N Relay T1 T2 VAMP 230 Relay T1 T4 VAMP 255 gt Definite operation time Set This setting is used by the circuit breaker condition monitoring See the section Circuit breaker condition monitoring Set An editable parameter password needed C Can be cleared to zero F Editable when force flag is on For details of setting ranges see the section Protection functions 140 Hecorded values of the latest eight faults There is detailed information available for the eight latest faults Time stamp and elapsed delay 2015 Schneider Electric All
334. thout a trip the stage will release ROCOF and frequency over and under stages One difference between over under frequency and df dt function is the speed In many cases a df dt function can predict an overfrequency or underfrequency situation and is thus faster than a simple overfrequency or under frequency function However in most cases a standard overfrequency and underfrequency stages must be used together with ROCOF to help ensure tripping also in case the frequency drift is slower than the slope setting of ROCOF 126 2014 Schneider Electric All rights reserved 63230 218 204 oection 5 Protection functions Rate of change of frequency ROCOF 81R 63230 218 204 Definite operation time characteristics Figure 5 35 shows an example where the df dt pick up value is 0 5 Hz s and the delay settings are t 0 60 s and tmn 0 60 s Equal times t tmy Will give a definite time delay characteristics Although the frequency slope fluctuates the stage will not release but continues to calculate the average slope since the initial pick up At the defined operation time t 0 6 s the average slope is 0 75 Hz s This exceeds the setting and the stage will trip At slope settings less than 0 7 Hz s the fastest possible operation time is limited according the Figure 5 36 0 6 s 0 5 g 0 4 0 3 Fastest possible operation time settin 0 1 0 2 0 3 0 4 0 5 0 6 0
335. ting is confirmed with Adjust the setting to be within the allowed range illegal Edlt VALUE CHANGE Illegal value Lim 0 10 5 00 Press CANCEL Figure 2 17 Example of an out of range message The allowed setting range is shown in the display in the setting mode To view the range push Push return the setting mode infoset I Info SET I Setting for stage l gt Type i32 dd Range 0 10 5 00 ENTER password CANCEL back to menu Figure 2 18 Allowed setting ranges show in the display Disturbance recorder menu DR 63230 218 205 Via the submenus of the disturbance recorder menu the following functions and features can be read and set Disturbance recorder Recording mode Mode sample rate Rate Recording time Time Pre trig time Pre Trig Manual trigger MnlTrig oS SY xm Count of ready records ReadyRe 2015 Schneider Electric All rights reserved 41 Configuration and parameter setting 42 Section 2 Local panel user interface Hec coupling 1 2 Add a link to the recorder AddLink Clear all links ClrLnks Available links BI J9 13 14 15 16 17 18 19 20 0 1 IL I2 In 12 11 12 11 loCalc f IL3 IL2 IL1 For NEMA phases are as follows L1 A L2 B L3 C THDIL1 THDIL2 THDIL3 IL1RMS IL2RMS IL3RMS Uo For NEMA UzV Uline Uphase U2 U1 U2 U1 For NEMA U
336. tion yyyy mm dd Time stamp of the recording date hh mm ss ms Time stamp time of day Fit Fault voltage relative to Un 4 3 EDly Elapsed time of the operating time setting 100 trip SetGrp 1 Active setting group during fault 2 110 2014 Schneider Electric All rights reserved 63230 218 205 section 5 Protection functions Zero sequence voltage protection Ug 59N Thermal overload protection T 49 63230 218 205 The thermal overload function protects the motor in the motor mode or cables in the feeder mode against excessive heating Thermal model The temperature is calculated using rms values of phase currents and a thermal model according IEC 60255 8 The rms values are calculated using harmonic components up to the 15th 2 2 Trip time T 1 1 In l a Alarm alarm 60 0 6 Trip k Ke Lyopg Release time a Trip release a 240 95 xk x Ione Start release a 240 95 xk x I yop x Valarm Alarm 60 0 6 Operation time Thermal time constant tau Setting value In Natural logarithm function Measured rms phase current the max value of three phase currents Preload current VO x kx If temperature rise is 120 0 1 2 This parameter is the memory of the algorithm and corresponds to the actual temperature rise k Overload factor Maximum continuous current i e service factor Settin
337. tion protocols Table 9 8 Parameters Parameter Value Unit Description Note Mode Profile selection Set Cont Continuous Reqs mode bit s 2400 bps Communication speed from the main CPU to the Profibus converter The actual Profibus bit rate is automatically set by the Profibus master and can be up to 12 Mbit s Emode Event numbering style Set Channel Use this for new installations Limit60 The other modes are for compatibility with old systems NoLimit InBuf bytes Size of Profibus master s Rx buffer data to the master 1 8 OutBuf bytes Size of Profibus master s Tx buffer data from the master 2 9 Addr 1 247 This address has to be unique within the Profibus network Set system Conv Converter type 4 No converter recognized VE Converter type VE is recognized Set An editable parameter password needed Clr 2 Clearing to zero is possible 1 continuous mode the size depends of the biggest configured data offset of a data item to be send to the master In request mode the size is 8 bytes 2 n continuous mode the size depends of the biggest configured data offset of a data to be read from the master In request mode the size is 8 bytes 3 When configuring the Profibus master system the lengths of these buffers are needed The device calculates the lengths according the Profibus data and profile configuration and the values define the i
338. tion techniques Protection mode for f gt lt and f gt gt lt lt stages These two stages can be configured either for overfrequency or for underfrequency Under voltage self blocking of underfrequency stages The underfrequency stages are blocked when biggest of the three line to line voltages is below the low voltage block limit setting With this common setting LVBIk all stages in underfrequency mode are blocked when the voltage drops below the given limit The idea is to avoid purposeless alarms when the voltage is off Initial self blocking of underfrequency stages When the biggest of the three line to line voltages has been below the block limit the under frequency stages will be blocked until the pick up setting has been reached Four independent frequency stages There are four separately adjustable frequency stages f gt lt f gt gt lt lt f lt f lt lt The two first stages can be configured for either overfrequency or underfrequency usage So four underfrequency stages total can be in use simultaneously Using the programmable stages even more can be implemented section Programmable stages 99 All the stages have definite operation time delay DT Setting groups There are two settings groups available for each stage Switching between setting groups can be controlled by digital inputs virtual inputs mimic display communication logic and manually 2014 Schneider Electric All rights reserved
339. tions Serial communication connection Order Code Communication interface Connector type Pin usage 100Mbps Ethernet interface with IEC 61850 2 X RJ 45 1 Transmit 2 Transmit 3 Receive 4 Reserved 5 Reserved 6 Receive 7 Reserved 8 Reserved NOTE In VAMP device RS485 interfaces a positive voltage from to Tx or Rx to Rx does correspond to the bit value 1 In X5 connector the optional RS485 is galvanically isolated In 2 wire mode the receiver and transmitter are internally connected in parallel See a table below REMOTE X5 TTL LOCAL RS 232 X4 X45 Figure 11 6 Pin numbering of the rear communication ports REMOTE TTL 63230 218 205 2015 Schneider Electric All rights reserved 11 2 Q ile 5 G RS485 Lu tc RS485 Figure 11 7 Pin numbering of the rear communication ports REMOTE HS 485 315 Serial communication connection Section 11 Connections Fiber RX A C 5 lt u uf 5 W A Fiber TX EET C ON Ow ProfibusDP Remote fiber Figure 11 8 Picture of rear communication port RE Figure 11 9 Pin numbering of the rear communication MOTE FIBER ports Profibus DP Dip switch number Switch position Function Function RS 485 Fiber optics 1 Left 2 wire connection Echo off Right
340. tstart Frequency converter drives and soft starter applications will not initiate the motor start signal due to the low current while starting the motor Motor will change directly from stopped to running position when the current increases into a certain level Figure 5 16 The terms of soft start Normal starting sequence As a default for the motor start detection relay uses value of 6 times motor nominal This value is editable Figure 5 17 The terms of normal starting sequence 2015 Schneider Electric All rights reserved 83 Frequent start protection gt 66 Section 5 Protection functions Frequent start protection N 66 84 The simplest way to start an asynchronous motor is just to switch the stator windings to the supply voltages However every such start will heat up the motor considerably because the initial currents are significantly above the rated current If the motor manufacturer has defined the maximum number of starts within an hour or and the minimum time between two consecutive starts this stage is easy to apply to help prevent starting too frequently When current has been less than 10 of the motor nominal current and then exceeds the value Motor start detection current of gt Stall protection stage situation is recognized as a motor start After the recognition of the motor start if current drops to a less than 1096 of the motor nominal current stage considers motor to be stoppe
341. ues are registered with time stamps since the latest manual clearing or since the device has been restarted The available registered min amp max values are listed in the following table Min amp Max measurement Description IL1 IL2 IL3 Phase current fundamental frequency value IL1RMS IL2RMS IL3RMS Phase current rms value lor lo2 Residual current U12 U23 U31 Line to line voltage Uo Zero sequence voltage f Frequency P Q S Active reactive apparent power IL1da IL2da IL3da Demand values of phase currents IL1da IL2da IL3da rms value Demand values of phase currents rms values PFda Power factor demand value The clearing parameter ClrMax is common for all these values L1 L2 and L3 are IEC phase names For NEMA the phases are as follows L1 A L2 B and L3 C 214 2015 Schneider Electric All rights reserved 63230 218 205 Section 7 Measurement functions Parameter Table 7 11 Parameters Value Description Set Maximum values of the last 31 days and twelve months ClrMax Clear Reset all minimum and maximum values Set Maximum values of the last 31 days and twelve months Measurement some maximum and minimum values of the last 31 days and the last twelve months are stored in the non volatile memory of the relay Corresponding time stamps are stored for the last 31 days The registered values are listed in the fol
342. values I lt xlmode Setting value as per times Imot t lt S Operation time s Recorded values SCntr Start counter Start reading TCntr Trip counter Trip reading Type 1 N 2 N Fault type single phase fault e g 1 N fault on phase L1 1 2 2 3 Fault type two phase fault 1 3 e g 2 3 fault between L2 and L3 1 2 3 Fault type three phase fault Fit Min value of fault current as per times Imot Load 7o 1s mean value of pre fault currents IL1 IL3 EDly Elapsed time as compared to the set operate time 100 tripping 11 12 and L3 are IEC phase names For NEMA the phases are as follows L1 A L2 B and L3 C Directional ground fault protection gt 67N 86 The directional ground fault protection is used for ground faults in networks or motors where a selective and sensitive ground fault protection is needed and in applications with varying network structure and length The device consists of versatile protection functions for ground fault protection in various network types The function is sensitive to the fundamental frequency component of the residual current and zero sequence voltage and the phase angle between them The attenuation of the third harmonic is more than 60 dB Whenever the size of ly and Vg and the phase angle between lg and Vj fulfils the pick up criteria the stage picks up and a start signal is issued If the fault situation remains on longer than the user s operation time delay s
343. vent enabling for AlrL 1 3 Set On Events are enabled Off Events are disabled OCAlarm Event enabling for combined o c starts Set On Events are enabled Off Events are disabled OCAlarmOff Off Event enabling for combined o c starts Set On Events are enabled Off Events are disabled IncFItEvnt Disabling several start and trip events of the same fault Set On Several events are enabled Off Several events of an increasing fault is disabled ClrDly 0 65535 S Duration for active alarm status AlrL1 Alr2 AlrL3 Set and OCs LINE FAULT FItL1 Fault trip status for each phase FItL2 0 O No fault since fault ClrDly FItL3 1 1 Fault is on OCt Combined overcurrent trip status 0 FItL1 FItL2 FItL3 0 1 FItL1 1 orFItL221 or FItL3 1 200 2015 Schneider Electric All rights reserved 63230 218 205 oection 6 Supporting functions Combined overcurrent status Parameter Value Unit Description Note LxTrip On Event enabling for FItL1 Set On Events are enabled Off Events are disabled LxTripOff Off Event enabling for FltL1 Set On Events are enabled Off Events are disabled OCTrip On Event enabling for combined o c trips Set On Events are enabled Off Events are disabled OCTripOff Off Event enabling for combined o c starts Set On Events are enabled Off Events are disabled IncFltEvnt Disabling several events of the same fault Set On Several events are enabled Off
344. vice 52 2015 Schneider Electric All rights reserved 63230 218 205 Section 4 Introduction Main features 63230 218 205 Principles of numerical protection techniques Fully digital signal handling with a powerful 16 bit microprocessor and high measuring accuracy on all the setting ranges due to an accurate 16 bit A D conversion technique Wide setting ranges for the protection functions e g the ground fault protection can reach a sensitivity of 0 596 Integrated fault location for short circuit faults The device can be matched to the requirements of the application by disabling the functions that are not needed Flexible control and blocking possibilities due to digital signal control inputs DI and outputs DO Easy adaptability of the device to various substations and alarm systems due to flexible signal grouping matrix in the device Possibility to control six objects e g circuit breakers disconnectors otatus of eight objects e g circuit breakers disconnectors switches Freely configurable display with six measurement values Freely configurable interlocking schemes with basic logic functions Recording of events and fault values into an event register from which the data can be read via a keypad and a local HMI or by means of a PC based VAMPSET user interface Latest events and indications are in non volatile memory Easy configuration parameterisation and reading of information via local
345. x108 21x108 421x108 Minimum limit for lined value corresponding to Modbus Min Link selection 21x107 21x107 Minimum amp maximum output values Active value On Off Enabling for measurement 63230 218 205 2015 Schneider Electric All rights reserved 323 Block optional diagrams Block optional diagrams VAMP 255 324 XT 9 DI14 X7 10 DI15 X7 11 DI16 X7 12 D17 X7 13 DI18 X7 14 COMM dINVA Option Block Figure 11 11 Block diagram of VAMP 255 2015 Schneider Electric All rights reserved Section 11 Connections 2 ct N N 20 b o rt 11 21 2 21 LZ 14 Z 63230 218 205 Section 11 Connections X3 1 X3 2 D X3 3 X3 4 X3 5 X3 6 X3 7 7 1 7 2 X7 3 X7 4 X7 5 XT 6 7 7 7 8 7 9 DI13 0114 7 10 0115 7 11 0116 7 12 0117 7 13 0118 X7 14 COMM 63230 218 205 Block optional diagrams uA X4 N i gt d O Tl X3 14 7 Ic X3 15 mo m E X3 12 lo1 D QI T X3 13 5A C X7 17 lo2 laren 7 18 X7 15 V12 7 16 1 X3 9 V23 t EZ X eer A2 X3 10 X2 13 Ir Z X2 14 X2 15 Option Block 3 X2 10 7 X2 11 X2 12 A4 X2 7 X2 8 eee ee a a A5 X2 5 BI X2 6 SF X2 16 NE
346. y ROCOF stage 81R 4 Prg1 3 1st programmable stage 4 Prg2 3 2nd programmable stage 4 Prg3 3 3rd programmable stage 4 Prg4 3 4th programmable stage 4 Prg5 3 5th programmable stage 4 Prg6 3 6th programmable stage 4 Prg7 3 7th programmable stage 4 Prg8 3 8th programmable stage 4 If2 gt 9 Second harmonic O C stage 68F2 4 If5 gt 3 Fifth harmonic O C stage 68F5 4 CBFP 3 Circuit breaker failure protection 50BF 4 CBWE 4 Circuit breaker wearing supervision 4 AR 15 Auto reclose 79 CTSV 1 CT supervisor 4 CT SV 1 CT supervisor 4 VTSV 1 VT supervisor 63230 218 205 2015 Schneider Electric All rights reserved 21 Configuration and parameter setting Section 2 Local panel user interface Main menu Number of menus Description ANSI code Note Arcl gt 4 Optional arc detection stage for phase to phase 50ARC 4 faults and delayed light signal Arclo1 gt 3 Optional arc detection stage for ground faults 50NARC 4 Current input 101 Arclo2 gt 3 Optional arc detection stage for ground faults 5ONARC 4 Current input 102 OBJ 11 Object definitions 5 Lgic 2 Status and counters of user s logic 1 10 2 Device setup scaling etc 6 Bus 13 Serial port and protocol configuration 7 Diag 6 Device self diagnosis Notes 1 Configuration is done with VAMPSET 2 Recording files are read with VAMPSET menu is visible only if protocol ExternallO is selected f
347. y by trained and qualified personnel No responsibility is assumed by Schneider Electric for any consequences arising out of the use of this material A qualified person is one who has skills and knowledge related to the construction installation and operation of electrical equipment and has received safety training to recognize and avoid the hazards involved Table of Contents Table of Contents Eme Genea N EAE 9 Fac WOO 10 PACA TO ERIT 11 Bisriailtirziarciel MN NR TEE 12 Related NET 12 PODICVIGUONS E 13 FPenodicalteSliNO ROREM 14 Section 2 Local panel user interface 20 0 ssena Eaa nemen 15 Relay front 15 Brera 17 Adjusting display contrast 18 Local panel operations 19 Menu structure of protection functions 23 Setting groups esseeee nn 26 Fault 0 0 se 27 Operating levels 28 Operating 30 Control functions 30 Measured data 31 Reading event register 35 Forced control Force
348. y detected error 3 BGTask OS background task timeout 4 DI Digital input detected error Remove 011 012 5 6 Arc Arc card detected error 7 SecPulse Hardware detected error 8 RangeChk DB Setting outside range 9 CPULoad OS overload 10 24V Internal voltage detected error 11 15V 12 ITemp Internal temperature too high 13 ADChk1 A D converter detected error 14 ADChk2 A D converter detected error 15 MSB E2prom E2prom detected error SelfDiag4 0 LSB 12V Internal voltage detected error 1 ComBuff BUS buffer detected error The code is displayed in self diagnostic events and on the diagnostic menu on local panel and VAMPSET 63230 218 205 2015 Schneider Electric All rights reserved 203 Incomer short circuit fault locator oection 6 Supporting functions Short circuit fault locator The device includes a stand alone fault locator algorithm The algorithm can locate a short circuit in radial operated networks The fault location is given in reactance ohms and kilometers or miles Fault value can then be exported for example with event to a DMS Distribution Management System The system can then localize the fault If a DMS is not available the distance to the fault is displayed as kilometers as well as a reactance value However the distance value is valid only if the line reactance is set correctly Furthermore the line should be homogenous that is the wire type of the line should be the same for the whole l
349. y pulses Reactiveimported amp energy pulses Pulse counter input 1 Pulse counter input Pulse counter input 3 Pulse counter input Z Figure 6 8 Application example of wiring the energy pulse outputs to a PLC having common minus and an internal wetting voltage 190 2015 Schneider Electric All rights reserved 63230 218 205 Section 6 Supporting functions System clock and synchronization oystem clock and synchronization 63230 218 205 The internal clock of the relay is used to time stamp events and disturbance recordings The system clock should be externally synchronised to get comparable event time stamps for all the relays in the system The synchronizing is based on the difference of the internal time and the synchronising message or pulse This deviation is filtered and the internal time is corrected softly towards a zero deviation Time zone offsets Time zone offset or bias can be provided to adjust the local time for IED The Offset can be set as a Positive or Negative value within a range of 15 00 to 415 00 hours and a resolution of 0 01 h Basically quarter hour resolution is enough Daylight saving time DST IED provides automatic daylight saving adjustments when configured A daylight savings time summer time adjustment can be configured separately and in addition to a time zone offset SYSTEM CLOCK Date Day of week Time of day Da
350. y1 Un Measured voltage comparison side Recorded values ReqCntr Request counter SyncCntr Synchronising counter FailCntr Unsuccesful sync 1 2 Recorded frequency reference side fy1 Hz Recorded frequency comparison side 0121 Un Recorded voltage reference side U12y Un Recorded voltage comparison side dAng Deg Recorded phase angle difference when close command is given from the function dAngC Deg Recorded phase angle difference when the circuit breaker actually closes EDly The elapsed time compared to the set re quest timeout setting 10096 timeout 1 Please note that the labels parameter names change according to the voltage selection 132 The following signals of the stage are available in the output matrix and the logic Request OK and The request signal is active when a request has received but the breaker is not yet closed The OK signal is active when the synchronising conditions are met or the voltage check criterion is met The fail signal is activated if the function does not close the breaker within the request timeout setting See the figure below 2014 Schneider Electric rights reserved 63230 218 204 oection 5 Protection functions Synchrocheck 25 2 UJ 1 Sync request 2 Sync OK 3 Object close command 5 l l i A v
351. zV UL8 UL2 UL 1 12 U31 U23 U12 For NEMA UzV CosFii FE Oy Q P lo2 lo1 Prms Qrms Srms Tanfii THDUa THDUb THDUc IL min ILmax ULLmin ULLmax ULNmin ULNmax fy fz U12y 1122 Configuring digital inputs DI The following functions can be read and set via the submenus of the digital inputs menu 1 2 4 The status of digital inputs DIGITAL INPUTS 1 6 18 Operation counters DI COUNTERS Operation delay DELAYs for Digln The polarity of the input signal INPUT POLARIT Y Either normally open NO or normally closed NC circuit Event enabling EVENT MASK1 2015 Schneider Electric All rights reserved 63230 218 205 oection 2 Local panel user interface Configuration and parameter setting Configuring digital outputs DO The following functions can be read and set via the submenus of the digital outputs menu e status of the output relays RELAY OUTPUTS1 and 2 e The forcing of the output relays RELAY OUTPUTS and 2 only if Force 2 ON Forced control 0 or 1 of the Trip relays Forced control 0 or 1 of the Alarm relays Forced control 0 or 1 of the SF relay e he configuration of the output signals to the output relays The configuration of the operation indicators LED Alarm and Trip and application specific alarm LEDs A B and C that is the output relay matrix NOTE The amount of Trip and Alarm relays depends on the relay type and optional hardware

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