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VAMP 210 manual - Schneider Electric België

1. stages IL1 IL2 IL3 Phase currents lo1 Residual current input lo lo2 Residual current input Ios U12 U23 U31 Line to line voltages UL1 UL2 UL3 Phase to ground voltages Uo Zero sequence voltage f Frequency P Active power Q Reactive power S Apparent power loCalc Phasor sum I Io I3 l1 Positive sequence current 12 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 Relative negative sequence voltage IL Average l4 lL2 13 3 Uphase Uun Average Ui1 Ute Ur3 3 Uline ULL Average U12 U23 U31 3 TanFii Tangent tan arccos Prms Active power rms value Qrms Reactive power rms value Srms Apparnet power rms value THDIL1 Total harmonic distortion of THDIL2 Total harmonic distortion of I 2 THDIL3 Total harmonic distortion of l3 THDUa Total harmonic distortion of input Ua THDUc Total harmonic distortion of input Up THDUb Total harmonic distortion of input U IL1RMS IL1 RMS for average sampling IL2RMS IL2 RMS for average sampling IL8RMS IL3 RMS for average sampling Eight independent stages The relay has eight independent programmable stages Each programmable stage can be enabled or disabled to fit the intended application 135 5 27 Programmable stages 99 5 Protection functions Technical description
2. vamp210appl3 Figure 4 1 Typical application of the VAMP 210 generator protection relay 45 4 1 Main features 4 Introduction Technical description 4 1 Main features The main features of VAMP 210 are 46 Comprehensive set of protection functions The protection stages not needed in a particular application can be disabled Versatile measuring functions including currents voltages frequency power energy symmetric components average values etc Control functions and status display for circuit breakers disconnectors etc Arc protection is available as option 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 and up to 20 bit dynamic range Easy adaptability of the relay to the power plant automation system or SCADA systems using the wide range of available communication protocols Easy adaptation to traditional alarm systems using the available signal relay outputs and the flexible signal grouping matrix of the relay Flexible control and blocking possibilities due to digital signal control inputs DI and outputs DO Freely configurable mimic display with busbar CB etc symbols and six selectable measurement values Five freely configurable double character size measurement displays Freely programmable interlocking schemes w
3. RATED INPUT Maximum secondary scaled setting enabling inverse delay times up to 20x setting Order code IL lox loo l1 l2 IL3 amp lo loo locaic VAMP 210 1_ 1 2 5A VAMP 210 5 __ 5 12 5A VAMP 210 _A 5 5 1 25A 1 25A VAMP 210 _B 5 1 1 25A 0 25A VAMP 210 _C 1 5 0 25 A 1 25 A VAMP 210 _D 1 1 0 25 A 0 25 A 5 29 1 Standard inverse delays IEC IEEE IEEE2 RI 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 error signal The inverse time setting error signal will be activated if the delay category is changed and the old delay type doesn t exist in the new category See chapter 5 29 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 chapter 5 29 for more details Table 5 29 1 1 Available standard delay families and the available delay types within each family Curve family KE O W D Delay type Oo i m u DT Definite time X NI1 Normal inverse X X VI Very inverse X X X El Extremely inverse X X X LTI Long time inverse X X LTEI Long time extremely inverse X LTVI Long time very in
4. 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 Fit xlgn Maximum fault current Load xlgn_ 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 Active setting group during fault 2 Voltage restrained controlled overcurrent function ly gt 51V The voltage restrained overcurrent stage ly gt is used for generator short circuit protection in applications where the static excitation system of the generator is fed only from the generator terminals In these applications the operation of the high set overcurrent function must be secured using a voltage restrained overcurrent function At close by short circuits the fault current rapidly decreases thus jeopardizing the operation of the high set short circuit protection The operation characteristic of a voltage restrained overcurrent function is shown in Figure 5 6 1 The under impedance protection see chapter 5 20 can be used for the same purpose 63 5 6 Voltage restrained controll overcurrent function IV gt 51V ed 5 Protection functions Technical description gt Usaa
5. For details of setting ranges see chapter 12 3 Set An editable parameter password needed C Can be cleared to zero F Editable when force flag is on Recorded 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 Recorded values of the 100 stator earth fault stage Uots lt 64F3 Parameter Value Unit Description yyyy mm dd Time stamp of the recording date hh mm ss ms Time stamp time of day Fit 3 harmonic value relative to Un V3 during fault EDly Elapsed time of the operating time setting 100 trip SetGrp 1 Active setting group during fault 2 108 V210 EN M A011 Technical description 5 Protection functions 5 18 Overfrequency and underfrequency protection f gt f lt 81H 81L 5 18 V210 EN M A011 Overfrequency and underfrequency protection f gt f lt 81H 81L 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 o
6. f gt lt f gt gt lt lt 32 P lt P lt lt Ne CBFP 21 40 SONARC I lt x lt ArCh gt X lt lt AtCl gt N N j 67NT 9 50ARC Prg1 8 Arc 5 Blocking and output matrix N vamp210appL2 Figure 10 2 1 Generator connected directly to the distribution busbar Unearthed generator neutral The neutral point of the generator winding is unearthed The busbar system is earthed via a separate earthing transformer In this case the earth fault protection principle is straight forward It is simply based on the measurement of the earth fault current Io1 between the generator and the distribution busbar 236 V210 EN M A011 Technical description 10 Applications 10 3 Generator transformer unit a 10 3 Generator transformer unit L1 L2 L3 Lif L2 L3 L1 X6 L2 2 Protection function 4
7. is used instead of the correct name 3l Example 1 single phase injection Ucn 100V Voltage measurement mode is 2LL Uo V210 EN M A011 Technical description 7 Measurement functions 7 9 Symmetric components V210 EN M A011 Injection Up U23 0 a i alae P 5 U 3 1 a o0 3 100Z0 33 U 33 U gt 33 U2 U 100 When using a single phase test device the relative unbalance U2 U will always be 100 Example 2 two phase injection with adjustable phase angle Ucn 100V Voltage measurement mode is 2LL Uo Injection Ua U2 100 V 40 Ub Uz 100 V3 V Z 150 57 7 V 2 150 U _1f1 a 10020 _100f120 1 434 90 _ U 3 1 a 100 432 150 3 120 1 432 30 _ 100 2 432 30 _ 38 5 30 3 1 32Z 30 19 22 30 Ui 38 5 U gt 19 2 Us U 50 Figure 7 9 1 shows a geometric solution The input values have been scaled with V3 100 to make the calculation easier 199 7 9 Symmetric components 7 Measurement functions Technical description 200 FortescueEx2 Positive sequence Figure 7 9 1 Example of symmetric component calculation using line to line voltages Unscaling the geometric results gives U4 100 V3 x 2 3 38 5 Us 100 48 x 1 3 19 2 U2 U 1 3 2 3 50 Example 3 two phase injection with adjustable phase angle Ucn 100V Voltage measurement mode is 3LN Injection
8. ms Pulse length of reactive imported energy 175 6 9 Energy pulse outputs 6 Supporting functions Technical description 176 Scaling examples Example 1 Average active exported power is 250 MW Peak active exported power is 400 MW Pulse size is 250 kWh 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 s or less The lifetime of the mechanical output relay will be 50x10 1000 h 6 a This is not a practical scaling example unless an output relay lifetime of about six years is accepted Example 2 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 s or less The lifetime of the mechanical output relay will be 50x10 250 h 23 a Example 3 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 s or less The lifetime of the mechanical output relay will be 50x10 417 h 14a Example 4 Average active exported power is 1900 kW Peak active
9. 100 80 10 10 8 84 oe Ss E k 5 S 2 S 2 ket 08 08 kos 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 3 4 5678 10 20 1 2 3 4 5678 10 20 T Iset inverseDelayRI T Iset inverseDelayRXIDG Figure 5 29 1 15 Inverse delay of type Figure 5 29 1 16 Inverse delay of type RI RXIDG 151 5 29 Inverse time operation 5 Protection functions Technical description 5 29 2 152 Free parametrisation 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 as in the previous chapter Example for GE IAC51 delay type inverse k 0 50 l 4pu lpickup 2 pu A 0 2078 B 0 8630 C 0 8000 D 0 4180 E 0 1947 1 0 5 0 2078 0 8630 i 0 4180 n 0 1947 0 37 ay fo Tee 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 error signal The inverse time setting error signal will become active if interpolation with the given parameters is not possible See
10. CTS out Internally connected to pin 7 o No connected 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 253 11 4 Serial communication connectors 11 Connections Technical description 11 4 2 Rear panel connector X5 REMOTE The X5 remote port communication connector options are shown in Figure 11 4 2 1 The connector types are listed in Table 11 4 2 1 Without any internal options X5 is a TTL 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 chapter 15 Internal options for fibre optic Figure 11 4 2 3 2 amp 4 wire galvanically isolated RS 485 Figure 11 4 2 2 and Profibus Figure 11 4 2 4 are available See ordering code in chapter 15 Table 11 4 2 1 Physical interface and connector types of remote port X5 with various options Serial interface A is the default Order Communication interface Connector Pin usage Code type A Serial interface for external D9S 1 reserved converters only REMOTE 2 TX_out TTL port 3 RX_in TTL 4 RTS out TTL 7 GND 9 8V out B Plastic fibre interface HFBR 0500 REMOTE port C Profibus interface D9S 3 RXD TXD
11. 12 11 Relative current unbalance I2 Ign Current unbalance xlen U1 Positive sequence voltage U2 Negative sequence voltage U2 U1 Relative voltage unbalance IL Average IL1 IL2 IL3 3 Uphase Average UL1 UL2 UL3 3 Uline Average U12 U23 U31 3 DO Digital outputs Yes Yes DI Digital inputs Yes Yes TanFii tano Prms Active power rms value Qrms Reactive power rms value Srms Apparent power rms value THDIL1 Total harmonic distortion of IL1 THDIL2 Total harmonic distortion of IL2 THDIL3 Total harmonic distortion of IL3 THDUa Total harmonic distortion of input Ua THDUb Total harmonic distortion of input Ub THDUc Total harmonic distortion of input Uc IL1RMS IL1 RMS for average sampling IL2RMS IL2 RMS for average sampling IL3RMS IL3 RMS for average sampling 157 6 2 Disturbance recorder 6 Supporting functions Technical description Disturbance recorder parameters Parameter Value Unit Description Note Mode Behaviour in memory full Set situation Saturated No more recordings are Overflow accepted 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 200ms Average 1 1s Average 1 5s Average 1 10s Average 1 15s Average 1 30s Average 1 1min Average Time s Rec
12. 136 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 Parameters of the programmable stages PrgN 99 Parameter Value Unit Description Note Status Current status of the stage Blocked Start F Trip F SCnir Cumulative start counter C TCntr Cumulative trip counter C SetGrp 1 or2 Active setting group Set SGrpDI Digital signal to select the active Set setting group S None Dix Digital input Vix Virtual input LEDx LED indicator signal VOx Virtual output Force Off Force flag for status forcing for Set On test purposes This is a common flag for all stages and output relays too Automatically reset by a 5 minute timeout Link See Name for the supervised signal Set table above See table Value of the supervised signal above Cmp Mode of comparison Set gt Over protection lt Under protection 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 Set comparison Mode lt Set An editable parameter password needed C Can be cleared to zero F Editable when force flag is on Recorded values of the
13. Objects are circuit breakers disconnectors etc Their position or status can be displayed and controlled in the interactive mimic display There are two extra menus which are visible only if the access level operator or configurator has been opened with the corresponding password Detailed protocol configuration is done with VAMPSET 19 2 2 Local panel operations 2 Local panel user interface Operation and configuration instructions 2 2 2 20 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 I gt gt menus are shown below First menu of I gt gt 50 51 stage first menu AV gt gt gt STATUS 50 51 ExDO Status SCntr TCntr SetGrp SGrpDI Force Figure 2 2 2 1 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 if the operating level is Configurator and the force flag below is on Operating levels are explained in chapter 2 2 5 e SCntr5 The stage has picked up a fault five times since the last reset of restart This value can be cleared if the operating level is at least Operator e TCnir 1 The stage has tripped two times since the last res
14. 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 input Harmonics of voltage input Ua Ua see Figure 2 3 2 1 Diagram U HARMONICS of input Harmonics of voltage input Ub Ub see Figure 2 3 2 1 Diagram U HARMONICS of input Harmonics of voltage input Uc Uc see Figure 2 3 2 1 Count U VOLT INTERRUPTS Voltage interrupt 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 Status U VOLT INTERRUPTS Voltage status LOW NORMAL harm HARMONICS of IL1 3579 11 13 15 Figure 2 3 2 1 Example of harmonics bar display 30 V210 EN M A011 Operation and configuration 2 Local panel user interface 2 3 Operating measures 2 3 3 V210 EN M A011 Reading 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 44v Code 71E10 CB open timeout 2002 02 15 00 17 37 530 Figure 2 3 3 1 Example of an event register 3 Scroll through the event list with and v 4 Exit the event list by pushing lt It is possible to se
15. The relay has three communication ports as standard A fourth port Ethernet is available as option See Figure 9 1 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 COMMUNICATION PORTS LOCAL EXTENSION REMOTE PORT PORT DATA BUS PORT Default TTL for external adapters only l Options RS 485 isolated Fibre optic Profibus Ethernet and TTL X5 TTL is for external adapters only panel in use Not isolated S X4 LOCAL FRONT PANEL Figure 9 1 1 Communication ports and connectors By default the X5 is a D9S type connector with TTL interface The DSR 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 together with external converters or converting cables Inbuilt options for RS 485 fibre optic plastic plastic plastic glass glass plastic or glass glass Profibus and Ethernet are available V210 EN M A011 Technical description 9 Communication 9 1 Communication ports 9 1 1 Local port X4 The local port has two connectors e On the front panel e X4 the rear panel D9S pins 2 3 and 5 Only one can be used at a time NOTE The extension port is locatin
16. d q A5 WY vamp210lohko Figure 11 8 1 Block diagram of the generator protection relay VAMP 210 267 11 9 Block diagrams of option modules 11 Connections Technical description 11 9 11 9 1 11 9 2 268 Block diagrams of option modules Optional arc protection X6 1 BI BI O X6 2 BO 4 X6 3 comm X6 4 L1 X6 5 L1 X6 6 L2 X6 7 L2 EE NE E A E NT ARC_option_block_diagram Figure 11 9 1 1 Block diagram of optional arc protection module Optional DI19 DI20 Options X61 DI149 DI X6 2 DI19 X6 3 DI 20 E X6 4 DI 20 X6 5 NC 3 X6 6 L gt X6 7 L a EEE O EE EE DI19D120_option_block_diagram Figure 11 9 2 1 Block diagram of optional DI19 DI20 module with one arc channel V210 EN M A011 Technical description 11 Connections 11 10 Connection examples 11 10 Connection examples 1O mM x X Qors gpg e Yo on eF ry ereees EET o Q E g o G 2 a 5 2 i 2 5 Q S R s OG N a DE K2 3 a 25 8 a Teo 7 s o
17. 10000 Hysteresis for alarm limits 21x107 er 214x107 Limit setting A A E S lt x Alarm Active state w z 21x107 ME z 241x107 Limit setting T A z E E S z lt a Alarm Active state x lt 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 V210 EN M A011 263 11 7 External I O extension modules 11 Connections Technical description External digital inputs configuration VAMPSET only Range Description Communication read errors 1 16 Bit number of Modbus register value CoilS InputS InputR or HoldingR Modbus register type 3 2 a E 1 9999 Modbus register for the measurement z 1 247 Modbus address of the I O device 0 1 Active state On Off Enabling for measurement 264 V210 EN M A011 Technical description 11 Connections 11 7 External I O extension modules V210 EN M A011 EXTERNAL DIGITAL OUTPUTS External digital outputs configuration VAMPSET only Range Description Communication errors ll 1 9999 Modbus register for the measurement om 1 247 Modbus address of the I O device 0 1 Output state On Off Enabling for measurement 265 11 7 External I O extension modules 11 Connections
18. Application layer Set 5000 default confirmation timeout CnfMode Application layer Set EvOnly default confirmation mode All DBISup Double bit input support Set No default Yes SyncMode 0 65535 S Clock synchronization Set request interval 0 only at boot Set An editable parameter password needed External I O Modbus RTU master External Modbus I O devices can be connected to the relay using this protocol See chapter 11 7 2 External input output module for more information 229 9 2 Communication protocols 9 Communication Technical description 9 2 9 IEC 61850 The relay supports communication using IEC 61850 protocol with native implementation IEC 61850 protocol is available with the optional inbuilt 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 serve 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 Supported control model direct with normal security e Supported horizontal communication with GOOSE configurable GOOSE publisher data sets configurable filters for GOOSE subscriber inputs GOOSE inputs available in the application lo
19. 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 O Pickup e a a e e e ce c ccc ccc cr ccc Cold l load Cold load and inrush No activation because the current has not been under the set lae Current Current dropped under the laie current level but now it stays between the lae current and the pick up current for over 80ms 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 above the pick up setting Figure 6 3 1 Functionality of cold load inrush current feature V210 EN M A011 Technical description 6 Supporting functions 6 3 Cold load pick up and inrush current detection V210 EN M A011 Parameters of the cold load amp inrush detection function Parameter Value Unit Description Note 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
20. PF_L1 P POWER PHASE 2 Power factor of phase 1 PF_L2 P POWER PHASE 2 Power factor of phase 2 PF_L3 P POWER PHASE 2 Power factor of phase 3 cos P COS amp TAN Cosine phi tan P COS amp TAN Tangent phi cosL1 P COS amp TAN Cosine phi of phase L1 cosL2 P COS amp TAN Cosine phi of phase L2 cosL3 P COS amp TAN Cosine phi of phase L3 Iseq P PHASE Actual current phase sequency OK SEQUENCIES Reverse Useq P PHASE Actual voltage phase sequency OK SEQUENCIES Reverse log P PHASE lo Uo angle SEQUENCIES lo2 P PHASE lo2 Uo angle SEQUENCIES fAdop P PHASE Adapted network frequency Hz SEQUENCIES E E ENERGY Exported energy MWh Eq E ENERGY Exported reactive energy Mvar E E ENERGY Imported energy MWh Eq E ENERGY Imported reactive energy Mvar E nn E DECIMAL COUNT Decimals of exported energy V210 EN M A011 Operation and configuration 2 Local panel user interface 2 3 Operating measures V210 EN M A011 Value Menu Submenu Description Eq nn E DECIMAL COUNT Decimals of reactive energy E nn E DECIMAL COUNT Decimals of imported energy Ewrap E DECIMAL COUNT Maximum energy counter value E E E PULSE SIZES Pulse size of exported energy kWh Eq 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 Puls
21. The following equation can be used if the previous AAlIntv value has been zero 604 8 AAIntv DriftInOneWeek If the auto adjust interval AAlntv has not been zero but further trimming is still needed the following equation can be used to calculate a new auto adjust interval 1 1 3 DriftInOneWeek AAINWV previous 604 8 AAINtV yew The term DriftInOne Week 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 V210 EN M A011 Technical description 6 Supporting functions 6 10 System clock and synchronization Example 1 If there has been no external sync and the relay s clock is leading sixty one seconds a week and the parameter AAlntv has been zero the parameters are set as AvDrft Lead AAIntv 004 8 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 AAlIntv has been 9 9 s leading then the parameters are set as 1 AAY yew or oe 99 9 24 3600 AvDrft Lead NOTE When the internal time is roughly correct deviation is less than four seconds any synchronizing or auto adjust will never turn the clock backwards Ins
22. k Overload factor Maximum continuous current i e service factor Setting value k Ambient temperature factor Permitted current due to tamb Figure 5 8 1 lan The rated current In or Imor C Cooling time coefficient cooling time constant C X T V210 EN M A011 Technical description 5 Protection functions 5 8 Thermal overload protection T gt 49 Time constant for cooling situation If the generator s fan is stopped the cooling will be slower than with an active fan Therefore there is a coefficient ct for thermal constant available to be used as cooling time constant when current is less than 0 3xlen Heat capacitance service factor and ambient temperature The trip level is determined by the maximum allowed continuous current Imax corresponding to the 100 temperature rise Orr i e the heat capacitance of the generator Imax depends of the given service factor k and ambient temperature ame and settings Imaxao and Imax70 according the following equation Imax k ke lon The value of ambient temperature compensation factor kO depends on the ambient temperature Oame and settings Imaxao and Imax7o See Error Reference source not found Ambient temperature is not in use when kO 1 This is true when MAX40 is 1 0 e Samb is n a no ambient temperature sensor e TAMB is 40 C k AmbientTemperatureCompensation 10 20 30 40 50 60 70 80 O
23. 0 BASE ANGLE 180 Ipr gt TRIP AREA cap ind 90 Idir_modeBiDir 15 Figure 5 5 3 Bi directional application with two stages Idir gt and Idir 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 Four independent stages There are four separately adjustable stages available lgir gt lair gt gt lgir gt gt gt and Igir gt gt gt gt 59 5 5 Directional overcurrent protection Idir gt 67 5 Protection functions Technical description 60 Inverse operation time Stages lair gt and Igi gt gt can be configured for definite time or inverse time characteristic See chapter 5 29 for details of the available inverse delays Stages Igi gt gt gt and lair gt gt gt gt have definite time DT operation delay The relay will show a scaleable graph of the configured delay on the local panel display Inverse time limitation The maximum measured secondary current is 50xlyn This limits the scope of inverse curves with high pick up settings See chapter 5 29 for more information Cold load and inrush current handling See chapter 6 3 Setting groups There are two settings groups available for each stage Switching between setting grou
24. 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 252 V210 EN M A011 Technical description 11 Connections 11 2 Auxiliary voltage 11 2 11 3 11 4 11 4 1 V210 EN M A011 Auxiliary voltage The external auxiliary voltage Uaux 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 Output relays The terminal is equipped with nine configurable output relays and a separate output relay for the self supervision system e Trip relays T1 and T2 terminals X3 12 13 and 14 15 e Alarm relays A1 A5 terminals X3 9 11 X2 5 6 7 8 10 12 13 15 e Self supervision system output relay IF terminals X2 16 18 Serial communication connectors The pin assignments of communication connectors including internal communication converters are presented in the following figures and tables Front panel connector Figure 11 4 1 1 Pin numbering of the front panel D9S connector Pin 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 COIN MD Ory RH OP
25. Auxiliary voltage Type A Type B Voltage range Uaux 40 265 V ac dc 18 36 Vdc Note Polarity X3 17 negative X3 18 positive Start up peak DC 110V Type A 15A with time constant of 1ms 220V Type A 25A with time constant of ims Power consumption lt 7 W normal conditions lt 15 W output relays activated Max permitted interruption time lt 50 ms 110 V dc Terminal block Maximum wire dimension Phoenix MVSTBW or equivalent 2 5 mm 13 14 AWG 270 V210 EN M A011 Technical description 12 Technical data 12 1 Connections 12 1 3 12 1 4 12 1 5 12 1 6 V210 EN M A011 Digital inputs Internal operating voltage Number of inputs 6 Internal operating voltage 48 Vdc Current drain when active max approx 20 mA Current drain average value lt 1mA Terminal block Phoenix MVSTBW or equivalent Maximum wire dimension 2 5 mm 13 14 AWG Trip contacts Number of contacts 2 making contacts relays T1 and T2 Rated voltage 250 Vac dc Continuous carry 5A Make and carry 0 5 s 30 A Make and carry 3s 15A DC breaking capacity L R 40ms at 48 VDC 5A at 110 VDC 3A at 220 VDC 1A Contact material AgNi 90 10 Terminal block Phoenix MVSTBW or equivalent Maximum wire dimension 2 5 mm 13 14 AWG Alarm contacts Number of contacts 3 change over contacts relays
26. L3 8 7 50 51 67 X4 _ x3 a Z 17 3p gt 3P gt 18 3P gt gt pe X5 50N 51N 3l gt gt gt gt X1 1 49 X3 9 He 11 3 10 12 4 T 5 13 gt gt gt 14 6 81H 81L 7 gt lt df at 15 8 f gt gt lt lt 40 a X2 E T P lt 50BF 5 10 a CBFP 6 11 50NARC 7 ACh gt 12 a AIChy gt 8 10 13 SOARC Arcl gt n LN 13 L t7 a Blocking and 14 i 18 output matrix 15 f D 16 17 48 V oo L K 18 Digital J DI inputs 5j 6l 7 vamp210appl_3 Figure 10 3 1 Generator transformer unit Besides the typical generator protection functions the device includes the transformer earth fault protection Whatever phase difference and voltage ratio of the transformer can be compensated in the relay in case VTs and CTs are on different sides of the unit transformer The earth fault protection of the transformer is based on an OR function between the current inputs lo and loz The stator earth fault protection reach 95 is based on measuring the fundamental frequency component of the zero sequence voltage Up with the overvoltage stage 59GN Via the digital inputs of the relay various signals can be transferred into the relay such as information about the operation of a MCB in the measuring circuit or circuit breaker status information V210 EN M A011 237 10 4 Trip circuit supervision 10 Applications Technical description 10 4 10 4 1 238 Trip circuit Supervision Trip circuit supervision is
27. Load 0 95 xin EDly 13 Figure 2 2 4 2 Example of selected fault log 24 V210 EN M A011 Operation and configuration 2 Local panel user interface 2 2 Local panel operations 2 2 5 V210 EN M A011 Operating levels The relay has three operating levels User level Operator level and Configurator level The purpose of the access levels is to 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 protection stages Opening Default password is 1 Setting state Push Os Closing 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 transformers can be set Opening Default password is 2 Setting state Push Os Closing The level is automatically closed after 10 minutes idle time Giving the password 9999 can also close the level 25 2 2 Local panel operations 2 Local panel user interface Operation and configuration instructions 26 Opening access 1 Push and on the
28. On the other hand faults near the neutral point are rare because the voltage stress is low Uof3_ANSI64F3_b 11 Operation area for Uo gt and Io gt Operation area for Uof3 lt Figure 5 17 1 The overlapping coverage of winding earth fault protection of basic protection stages and the third harmonic undervoltage protection stage V210 EN M A011 105 5 17 100 stator earth fault protection U0f3 lt 64F3 5 Protection functions Technical description 106 100 coverage of the windings The one hundred per cent in the title is slightly misleading Actually the 100 coverage is achieved only when this stage is used together with conventional earth fault protection The operation range of fundamental frequency earth fault functions 59N and 51N covers about 95 of the stator windings starting from the HV end but never 100 of the windings The coverage of the Uois lt stage is about 10 30 of the windings but starting from the LV end i e the neutral point Thus the ranges do overlap as in Figure 5 17 1 and 59N or 51N together with this 64F3 does cover 100 of the stator windings Natural 3 harmonic at the neutral point The voltage a generator is not ideal pure sine wave There will exist some small amount of harmonics as well At the neutral point there will exists some amount of 3 6 9 12 i e 3n harmonics The base frequency and other than 3n harmonics in phase voltages do cancel each other
29. Or loo CT 50 1 Current injected to the relay s input is 30 mA Per unit current is Ipy 0 03 1 0 03 pu 3 Example 6 Per unit to secondary for residual current Input is lo1 Or loo CT 50 1 The relay setting is 0 03 pu 3 Secondary current is Isec 0 03x1 30 mA Example 7 Secondary to per unit for residual current Input is locaic CT 750 5 Currents injected to the relay s IL input is 0 5 A l2 IL3 0 Per unit current is Ipu 0 5 5 0 1 pu 10 Example 8 Per unit to secondary for residual current Input is locaic CT 750 5 The relay setting is 0 1 pu 10 gt If IL2 ILtg 0 then secondary current to l4 is Isec 0 1x5 0 5A V210 EN M A011 Technical description 7 Measurement functions 7 10 Primary secondary and per unit scaling 7 10 2 V210 EN M A011 Voltage scaling Primary secondary scaling of line to line voltages Line to line voltage scaling Voltage measurement mode Voltage measurement mode 2LL Uo BLN U U VD rrr ine VT ret secondary gt primary PRI SEC PRI SEC Wsec VWI sec VW snc U pri VWI sec primary gt secondary U sic U pp U snc VT pri V3 VT pri Example 1 Secondary to primary Voltage measurement mode is 2LL Uo VT 12000 110 Voltage connected to the relay s input Ua or Up is 100 V Primary voltage is Upri 100x12000 110 10909 V Example 2 Secondary to prima
30. P REMOTE port 4 RTS 5 GND 6 5V 8 RXD TXD N D RS 485 isolated REMOTE screw terminal 1 Signal ground port 2 Reciever 3 Reciever 4 Transmitter 5 Transmitter E Glass fibre interface ST 62 5 125 um REMOTE port F Plastic glass 62 5 125 HFBR 0500 ST Plastic Rx um fibre interface Glass Tx REMOTE port G Glass 62 5 125 um ST HFBR 0500 Glass Rx plastic fibre interface Plastic Tx REMOTE port 254 V210 EN M A011 Technical description 11 Connections 11 4 Serial communication connectors V210 EN M A011 Order Code Connector type Communication interface Pin usage Ethernet interface 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 10Mbps Ethernet 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 100 Mbps Ethernet fibre interface with IEC 61850 and Serial interface for external converters only REMOTE port D9S and L
31. Parameter Value Unit Description Note LINE FAULT FItL1 FItL2 FItL3 Fault trip status for each phase O No fault since fault ClrDly 1 Fault is on OCt Combined overcurrent trip status FitL1 FItL2 FItL3 0 FitL1 1 orFltL2 1 or FItL3 1 LxTrip On Event enabling for FItL1 3 Events are enabled Events are disabled Set LxTripOff Off Event enabling for FItL1 3 Events are enabled Events are disabled Set OCTrip On Off On Event enabling for combined o c trips Events are enabled Events are disabled Set OCTripOff Off Event enabling for combined o c starts Events are enabled Events are disabled Set IncFltEvnt Disabling several events of the same fault Several events are enabled Several events of an increasing fault is disabled Set ClrDly 0 65535 Duration for active alarm status FitL1 Flt2 FltL3 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 too 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 V210 EN M A011 185 6 14 Self supervision 6 Supportin
32. Switching between setting groups can be controlled by digital inputs virtual inputs mimic display communication logic and manually Figure 5 12 1 shows the functional block diagram of the overvoltage function stages U gt U gt gt and U gt gt gt Setting Hysteresis Release Delay Enable U gt s delay events Figure 5 12 1 Block diagram of the three phase overvoltage stages U gt U gt gt and U gt gt gt 91 5 12 Overvoltage protection U gt 59 5 Protection functions Technical description Parameters of the overvoltage stages U gt U gt gt U gt gt gt 59 Parameter Value Unit Description Note Status Current status of the stage Blocked Start F Trip F SCnir Cumulative start counter C TCntr Cumulative trip counter C SetGrp 1 or2 Active setting group Set SGrpDI Digital signal to select the active Set setting group s None Dix Digital input Vix Virtual input LEDx LED indicator signal VOx Virtual output Force Off Force flag for status forcing for Set On test purposes This is a common flag for all stages and output relays too Automatically reset by a 5 minute timeout Umax V The supervised value Max of U12 U23 and U31 U gt U gt gt V Pick up value scaled to primary U gt gt gt value U gt U gt gt Un Pick up setting relative to Uen Set U gt gt gt t gt t gt gt t gt gt gt s Definite operation time Set RIsDly s Release d
33. The operation time in this example will be 5 seconds The same result can be read from Figure 5 29 1 1 500 IEC NI Bon IEC EI 400 400 200 200 100 100 80 80 60 60 40 40 20 20 10 10 m 8 8 Z 6 Z 6 gt 4 gt 4 a 2 2 0 8 0 8 0 6 0 6 04 04 k 2 k 1 0 2 0 2 0 1 RAI k o5 0 08 A S 9 1s ka 006 0 06 0 05 k 0 1 k 0 2 1 2 3 45678 10 20 1 2 3 45678 10 20 TIset inverseDelayIEC_NI T Iset inverseDelayIEC_EI Figure 5 29 1 1 IEC normal inverse Figure 5 29 1 2 IEC extremely inverse delay delay sa IEC VI ae IEC LTI 400 400 200 200 k 20 100 100 80 80 k 10 60 60 40 40 k 5 20 20 k 3 3 2 8 2 k 0 2 4 1 0 8 0 8 k1 0 6 0 6 0 4 0 4 k 0 05 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 T Iset inverseDelayIEC_VI V Iset inverseDelayIEC_LTI Figure 5 29 1 3 IEC very inverse delay Figure 5 29 1 4 IEC long time inverse delay 144 V210 EN M A011 Technical description 5 Protection functions 5 29 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 29 1 3 The IEEE standard defines inverse delay for both trip and release operations However in the device only the trip time is inverse according
34. This can be used to verify that the device is receiving messages e Communication error counter Errors e Communication time out error counter Tout e Same information as in the previous menu V210 EN M A011 Operation and configuration 2 Local panel user interface 2 4 Configuration and parameter setting V210 EN M A011 EXTENSION PORT X4 pins 7 8 and 5 e Communication protocol for extension port X4 Protocol e Message counter Msg This can be used to verify that the device is receiving messages e Communication error counter Errors e 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 Ethernet port These parameters are used by the ethernet interface For changing the nnn nnn nnn nnn style parameter values VAMPSET is recommended Ethernet port protocol Protoc IP Port for protocol Port IP address IpAdadr 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 Error counter Errors Timeout counter Tout MODBUS e Modbus addres for this slave device Addr This address has to be unique within the system e Modbus bit rate bit s Default is 9600 e Parity Parity Default is Eve
35. VIX Virtual input LEDx LED indicator signal VOx Virtual output Force Off Force flag for status forcing for Set On test purposes This is a common flag for all stages and output relays too Automatically reset by a 5 minute timeout lo pu The supervised value according lo2 the parameter Input below loCalc lo gt gt A Pick up value scaled to primary lo gt gt gt value lo gt gt gt gt lo gt gt pu Pick up setting relative to the Set lo gt gt gt parameter Input and the ass corresponding CT value t gt s Definite operation time for Set definite time only Input lo1 X1 7 amp 8 See chapter 11 lo2 X1 9 amp 10 loCalc IL1 IL2 IL3 Set For details of setting ranges see chapter 12 3 Set An editable parameter password needed C Can be cleared to zero F Editable when force flag is on Recorded values of the latest eight faults There is detailed information available of the eight latest earth faults Time stamp fault current elapsed delay and setting group 78 V210 EN M A011 Technical description 5 Protection functions 5 10 Directional earth fault protection l0 gt 67N Recorded values of the undirectional earth fault stages 8 latest faults lo gt lo gt gt lo 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 earth fault curren
36. Weight Terminal Package and Manual 5 2 kg 12 3 Protection functions For setting values the step size is mentioned if it differs from the given resolution 12 3 1 Current protection Overcurrent stage I gt 50 51 Pick up current 0 10 5 00 x len Definite time function DT Operating time 0 08 300 00 s step 0 02 s IDMT function Delay curve family DT IEC IEEE RI Prg Curve type EI 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 60 ms Reset time lt 95 ms Retardation time lt 50 ms Reset ratio 0 97 Transient over reach any t lt 10 Inaccuracy Starting 3 of the set value or 5 mA secondary Operating time at definite time function 1 or 30 ms Operating time at IDMT function 5 or at least 30 ms El Extremely Inverse NI Normal Inverse VI Very Inverse LTI Long Time Inverse Ml Moderately Inverse The measuring range may limit the scope of inverse delays See chapter 5 29 for details Overcurrent stages I gt gt and I gt gt gt 50 51 Pick up current 0 10 20 00 x Ian I gt gt 0 10 40 00 x lan I gt gt gt Definite time function Operating time DT I gt gt 0 04 1800 00 s step 0 01 s I gt gt gt 0 04 300 00 s step 0 01 s Start time Typically 60 ms Reset time lt 95 ms Retardation time l
37. for example passwords blockings and mimic configuration are normally set only during commissioning Some 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 4 1 autoboot Pick PROTOCOL Change will cause autoboot Press CANCEL Figure 2 4 1 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 ox 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 33 2 4 Configuration and parameter 2 Local panel user interface Operation and configuration setting instructions 2 4 1 34 Parameter setting 1 Move to the setting state of the desired menu for example CONF CURRENT SCALING by pushing ox The Pick text appears in the upper left part of the display 2 Enter the password associated with the configuration level by pushing and then using the arrow keys and a default value is 0002 For more information about the access levels please refer to Chapter 2 2 5 3 Scroll through the parameters using and v A parameter can be set if the background color of the line is black If the parameter cannot be set the parameter
38. gt lp gt gt A Pick up value scaled to primary value lp gt lo gt gt xIgn Pick up setting Set Curve Delay curve family DT Definite time IEC Inverse time See chapter 5 29 IEEE Set IEEE2 RI PrgN Type Delay type DT Definite time NI Inverse time See chapter 5 29 VI Set El LTI Paramet ers t gt s Definite operation time for Set definite time only k gt Inverse delay multiplier for Set inverse time only Dly20x s Delay at 20xlset Dly4x s Delay at 4xlset Dly2x s Delay at 2xlset Dly1x S Delay at 1xlset Mode Dir Directional mode 67 Set Undir Undirectional 50 51 Offset 2 Angle offset in degrees Set 9 Measured power angle U1 Un Measured positive sequence voltage A B C D User s constants for standard Set E equations Type Parameters See chapter 5 29 For details of setting ranges see chapter 12 3 Set An editable parameter password needed C Can be cleared to zero F Editable when force flag is on 61 5 5 Directional overcurrent protection Idir gt 67 5 Protection functions Technical description Parameters of the directional overcurrent stages lgir gt gt gt lgir gt gt gt gt 67 Parameter Value Unit Description Note Status Current status of the stage Blocked Start F Trip F SCnir Cumulative start counter C TCntr Cumulative trip counter C SetGrp 1 or2 Active setting group Set SGrpDI Digital signal to select
39. i amp a a f2 f1 w te a cae poss eg ee 50 8 El INES F 2 SSheapanen E 0 Zsuauavauasuraratararar 7 7 0 E fo 1 Nn 1 0 05 O10 O15 020 025 030 Time s InrushCurrentLoad0 Figure 7 1 Example of various current values of a transformer inrush current V210 EN M A011 187 7 1 Measurement accuracy 7 Measurement functions Technical description 7 1 188 Measurement accuracy The specified frequency range for all measurements except frequency is 45 Hz 65 Hz Phase current inputs Ic IL2 Ins Measuring range 25mA 250 A 5A 5mA 50 A 1A Inaccuracy 1 lt 7 5A 0 5 of value or 0 3 of In I gt 7 5A 3 of value Squelch level 0 001 x In The rated input In is 5 Aor 1 A It is specified in the order code of the relay Voltage inputs Ua Up Uc The usage of voltage inputs depends on the configuration parameter voltage measurement mode chapter 7 6 For example U is the input for zero sequence voltage Uo if the mode 2LL Uo is selected but in mode 3LN the same input is used for phase to neutral voltage U s Measuring range 0 160 V Inaccuracy 0 5 or 0 3 V Squelch level 0 1 V Residual current inputs lo1 loz Measuring range 0 5 xlon Inaccuracy lt 1 5 xXlon 0 5 of value or 0 3 of lon I gt 1 5 Xlon 3 of value Squelch level 0 0002 x lon The rated input lon is 5A 1 Aor 0 2 A
40. the right direction for earth faults too For networks having the maximum possible earth fault current less than the over current setting use 67N the directional earth fault stages Im 90 2 ind cap res BASE ANGLE 30 Teaver cap ind 90 Idir_angle2 Figure 5 5 1 Example of protection area of the directional overcurrent function V210 EN M A011 Technical description 5 5 Directional overcurrent protection Idir gt 67 5 Protection functions V210 EN M A011 Two modes are available directional and non directional Figure 5 5 2 In the non directional mode the stage is acting just like an ordinary overcurrent 50 51 stage 90 90 ind cap ind cap 2 _ aaa i DIRECTIONAL NON DIRECTIONAL SET SET VALUE o VALUE o gt gt res ee ses zres BASE ANGLE 0 TRIP AREA TRIP AREA cap tind cap tind 90 90 Idir_modeA 15 Figure 5 5 2 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 5 3 The right side stage in this example is the stage Idir gt and the left side is Idir gt gt The base angle setting of the Idir gt is 0 and the base angle of Idir gt gt is set to 180 nN 90 ind cap pfe Iyp gt gt TRIP AREA SET SET 3 VALUE VALUE 0 res tres BASE ANGLE
41. transient reactance for the synchronous machine x x a a The settings for loss of excitation stages can be derived from these machine parameters but there are many practices to do it Here is one Radius of the circle Resistive offset Ros 0 14 X q X4 2 Reactive offset Xos X g Xq 2 All the settings are in per unit X lt X 2 123 5 22 Under reactance and loss of 5 Protection functions Technical description excitation protection X lt 40 124 X w E where Zy Xpu Reactance or resistance per unit X Reactance or resistance in ohms Zn Nominal impedance of the machine 2 fe ag where Sy Zn Nominal impedance of the machine Un Nominal voltage of the machine Sn Nominal power of the machine Characteristic on power plane In Figure 5 22 2 the same characteristics as in the previous figure is drawn on a PQ power plane assuming a constant voltage of 1 PU The transformation is S U Z where U is the voltage and Z is the complex conjugate of impedance Z I UnderReactancePQplane J 15 NORMAL OPERATION AREA OF THE Cca p ind v a m fo lt H P 4 r a ASI ind SFA Figure 5 22 2 The loss of excitation characteristics drawn on a power plane Two independent under reactance stages There are two separately adjustable stages available X lt and X lt lt V210 EN M A011 Technical description 5 Protection functions 5 22 U
42. 20 1 V210 EN M A011 Technical description 5 Protection functions 5 20 Under impedance protection Z lt 21 V210 EN M A011 Whenever the positive sequence impedance goes inside the circle the stage will pick up The radius Z lt of the circle and the definite delay time are the setting parameters Yj NORMAL OPERATION AREA OF THE YAMOd ASYAAaY YAMOd GYVMYOs 7 ind PELLEN Figure 5 20 2 Underimpedance characteristics drawn in power plane assuming that voltage is constant The trip area is now outside of the circle having radius U Z lt where Z lt is the pick up setting Undercurrent blocking When for some reason voltage collapses but currents remain at normal load levels the calculated impedance may fall into the trip area Inverted start signal from the most sensitive overcurrent stage can be used to block the under impedance stages during abnormal voltages not caused be short circuit faults Characteristic on a PQ power plane In Figure 5 20 2 the same characteristics as in the previous figure is drawn on a PQ power plane assuming a constant voltage of 1 PU The transformation is S U Z where U is the voltage and Z is the complex conjugate of impedance Z The borderline of under impedance trip area in the power plane is still a circle in origin but now the trip area is the outside of the circle The shape of the normal operation area is totally different For example the maximum a
43. 3 220 Extension port X4 This is a non isolated RS 485 port for external I O devices The port is located in the same rear panel D9S 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 1 Parameters Parameter Value Unit Description Note Protocol Protocol selection for the Set extension port None Command line interface for VAMPSET SPA bus SPA bus slave ProfibusDP Profibus DB slave ModbusSla Modbus RTU slave ModbusTCPs Modbus TCP slave IEC 103 IEC 60870 5 103 slave ExternallO Modbus RTU master for external I O modules DNP3 DNP 3 0 Msg 0 2 1 Message counter since the Clr device has restarted or since last clearing Errors 0 2 541 Protocol errors since the Clr device has restarted or since last clearing Tout 0 2 61 Timeout errors since the Clr device has restarted or since last clearing Display of actual 1 communication parameters speed bit s speed DPS D number of data bits P parity none even odd Default S number of stop bits 38400 8N1 for VAMPSET 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 V210 EN M A011 Technical description 9 Communication 9 1 C
44. 3 Block diagram of the directional intermittent transient earth fault stage lomT gt Parameters of the directional intermittent transient earth fault stage loint gt 67NI Parameter Value Unit Description Note Status Current status of the stage Blocked Start F Trip F SCnir Cumulative start counter Clr TCntr Cumulative trip counter Clr SetGrp 1or2 Active setting group Set SGrpDI Digital signal to select the active setting group None Dix Digital input Set Vix Virtual input LEDx LED indicator signal VOx Virtual output Force Off Force flag for status forcing for Set On test purposes This is a common flag for all stages and output relays too Automatically reset after a five minute timeout lot pu The detected Ip value according lo2 the parameter Input below Uo A The measured U value Uon 100 Uo gt Uo pick up level Uon 100 Set t gt s Operation time Actually the Set number of cycles including faults x 20 ms When the time between faults exceeds 20 ms the actual operation time will be longer lo input lo1Peak lox Connectors X1 7 amp 8 Set lo2Peak loo Connectors X1 9 amp 10 Intrmt s Intermittent time When the next Set fault occurs within this time the delay counting continues from the previous value For details of setting ranges see chapter 12 3 Set An editable parameter password needed 89 5 12 Overvoltage protect
45. 4l 5 0 NEDI X4 2 Ow oO oY X4 RS485 Figure 11 4 2 1 Pin numbering of the Figure 11 4 2 2 Pin numbering of the rear communication ports REMOTE rear communication ports REMOTE TTL RS 485 Fibre RX ee a A Q N LU J k a 2 Oop O a LL X Fibre TX JA LN QN On JY ProfibusDP Remote fibre Figure 11 4 2 3 Picture of rear Figure 11 4 2 4 Pin numbering of the communication port REMOTE FIBRE rear communication ports Profibus DP 257 11 4 Serial communication 11 Connections Technical description connectors E N E Col Figure 11 4 2 5 Dip switches in RS 485 and optic fibre options Dip switch Switch Function Function number position RS 485 Fibre optics 1 Left 2 wire connection Echo off 1 Right 4 wire connection Echo on 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 258 V210 EN M A011 Technical description 11 Connections 11 5 Optional two channel arc protection card 11 4 3 X4 rear panel connector local RS232 and extension RS485 ports Rear panel port Pin Signal LOCAL X4 1 No connection X4 2 Rx in RS232 local X4 3 Tx out RS23
46. 60 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 Operate time 1 or 30 ms This is the instantaneous time i e the minimum total operational time including the fault detection time and operation time of the trip contacts Directional intermittent transient earth fault stage lont gt 67NI Input selection for l peak signal lo Connectors X1 7 amp 8 loo Connectors X1 9 amp 10 lo peak pick up level fixed 0 1 x lon 50 Hz Uo pickup level 10 100 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 60 ms Reset ratio hysteresis for Uo 0 97 Inaccuracy starting 3 for Up No inaccuracy defined for l transients time 1 or 30 ms The actual operation time depends of the intermittent behaviour of the fault and the intermittent time setting 276 V210 EN M A011 Technical description 12 Technical data 12 3 Protection functions V210 EN M A011 Directional earth fault stages lo gt Ibp gt gt 67N Pick up current 0 005 8 00 x lon 0 05 20 0 When locaic Start voltage 1 50 Uon Input signal lo input X1 7 amp 8 lo2 input X1 9 amp 10 locate IitlLo lis Mode Non directional Sec
47. 9 1 shows a functional block diagram of the Ip gt earth overcurrent stage with definite time and inverse time operation time Figure 5 9 2 shows a functional block diagram of the lo gt gt lo gt gt gt and lo gt gt gt gt earth fault stages with definite time operation delay V210 EN M A011 Technical description 5 Protection functions 5 9 Earth fault protection 10 gt 50N 51N V210 EN M A011 Input signal selection Each stage can be connected to supervise any of the following inputs and signals e Input Io for all networks other than rigidly earthed e Input loz for all networks other than rigidly earthed e Calculated signal locaic for rigidly and low impedance earthed networks locale l1 lL2 IL3 Additionally the stage lo gt have two more input signal alternatives to measure current peaks to detect a restriking intermittent earth fault e lo1Peak to Measure the peak value of input lo1 e lo2Peak to Measure the peak value of input loz Intermittent earth fault detection Short earth 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 earth faults in compensated networks there is a dedicated stage lot gt 67NT 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 t
48. A Primary scaled upper limit for idle current MaxTime s Set Idle xXIGN Current limit setting for idle Set situation Pickup xIGN Pick up setting for minimum Set start current 80 ms Maximum transition time for start recognition Pickupf2 Pick up value for relative Set amount of 2 harmonic liz l Set An editable parameter password needed For details of setting ranges see chapter 12 4 163 6 4 Voltage sags and swells 6 Supporting functions Technical description 6 4 164 Voltage sags and swells 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 functions 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 U lt or exceeds the swell limit U 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
49. CT supervisor CTSV Parameter Value Unit Description Measured ILmax A Maximum of phase currents value ILmin A Minimum of phase currents Display Imax gt A Setting values as primary Imin lt values Recorded Date Date of CT supervision values alarm Time Time of CT supervision alarm Imax A Maximum phase current Imin A Minimum phase current For details of setting ranges see chapter 12 4 V210 EN M A011 Technical description 6 Supporting functions 6 7 Voltage transformer supervision 6 7 V210 EN M A011 Voltage transformer supervision The device supervises the VTs and VT wiring between the relay terminals and the VTs If there is a fuse in the voltage transformer circuitry the blown 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 false tripping The VT supervisor function measures the three phase voltages and currents The negative sequence voltage U2 and the negative sequence currentls are calculated If U2 exceed the Us gt setting and at the same time l2 is less than the lo lt setting the function will issue an alarm after the operation delay has elapsed Setting parameters of VT supervisor VTSV Parameter Value Unit Default Description U2 gt 0 0 200 0 Un 34 6 Upper setting
50. Curve Delay curve family DT Definite time IEC Inverse time See chapter 5 29 IEEE Set IEEE2 RI PrgN Type Delay type DT Definite time NI Inverse time See chapter 5 29 VI Set El LTI Paramet ers t gt s Definite operation time for Set definite time only k gt Inverse delay multiplier for Set inverse time only Input lot X1 7 amp 8 See chapter 11 lo2 X1 9 amp 10 loCalc IL1 IL2 IL3 Set lo1 Peak X1 7 amp 8 peak mode lo2Peak X1 9 amp 10 peak mode Intrmt s Intermittent time Set Dly20x s Delay at 20xlset Dly4x s Delay at 4xlset Dly2x S Delay at 2xlset Dly1x S Delay at 1xlset A B C D User s constants for standard Set E equations Type Parameters See chapter 5 29 For details of setting ranges see chapter 12 3 Set An editable parameter password needed C Can be cleared to zero F Editable when force flag is on 77 5 9 Earth fault protection 10 gt 50N 51N 5 Protection functions Technical description Parameters of the undirectional earth fault stages lo gt gt lo gt gt gt lo gt gt gt gt 50N 51N Parameter Value Unit Description Note Status Current status of the stage Blocked Start F Trip F 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 s None Dix Digital input Set
51. DI1 DI6 must be dry potential free These inputs use the common internal 48 Vdc wetting voltage from terminal X3 1 only 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 Parameters of digital inputs Parameter Value Unit Description Set DI1 DIG 0 Status of digital input 1 DI COUNTERS DI1 DIG 0 65535 Cumulative active edge Set counter DELAYS FOR DIGITAL INPUTS DI1 DIG 0 00 60 00 s Definite delay for both on Set and off transitions CONFIGURATION DI1 DI6 Inverted no For normal open contacts Set NO Active edge is 0 gt 1 yes For normal closed contacts NC Active edge is 1 gt 0 Alarm display no No pop up display Set yes Alarm pop up 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 Set Off enabled Inactive edge event disabled V210 EN M A011 209 8 3 Virtual inputs and outputs 8 Control functions Technical description 8 3 210 Parameter Value Unit Description Set NAMES for DIGITAL INPUTS editable with VAMPSET only Label String of max Short name for Dis on t
52. 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 213 8 6 Controllable objects 8 Control functions Technical description 214 These signals send control pulse when an object is controlled by digital input remote bus auto reclose etc Settings for read only objects Each read only object has the following settings Setting Value Description DI for obj open None any digital Open information input virtual input or virtual output DI for obj close Close information Timeout for state changes If changing states takes longer than the time defined by Object timeout setting object fails and Object failure matrix signal is set Also undefined event is generated Object timeout 0 02 600s Controlling with DI firmware version gt 5 53 Objects can be controlled with digital input virtual input or virtual output There are four settings for each controllable object Seiting Active DI for remote open control DI for remote close control DI for local open control DI for local close control In remote state 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 se
53. It is specified in the order code of the relay Frequency Measuring range 16 Hz 75 Hz Inaccuracy 10 mHz The frequency is measured from voltage inputs Ua and or Up Power measurements P Q S Inaccuracy PF gt 0 5 1 of value or 3 VAsec Power factor cos tano Inaccuracy PF gt 0 5 2 or 0 02 Energy counters E Eq E Eq Inaccuracy PF gt 0 5 1 of value or 3 Whsecondary 1 h THD and harmonics Inaccuracy I U gt 0 1 PU 2 units Update rate At least once a second V210 EN M A011 Technical description 7 Measurement functions 7 2 Harmonics and Total Harmonic Distortion THD 7 2 V210 EN M A011 Harmonics and Total Harmonic Distortion THD The device calculates the THDs as percentage of the base frequency for currents and voltages The device calculates the harmonics from the 2 to the 15 of phase currents and voltages The 17 harmonic component will also be shown partly in the value of the 15 harmonic component This is due to the nature of digital sampling The harmonic distortion is calculated using equation 15 yn THD a where 1 hy Fundamental value h gt 15 Harmonics Example hy 100A hs 10A h7 3A h 8A rup 3 8 _ 13 0 100 For reference the RMS value is RMS V100 102 3 8 100 9A Another way to calculate THD is to use the RMS value as reference
54. Negative sequence current I Figure 5 7 1 Inverse operation delay of current unbalance stage l gt The 100 longest delay is limited to 1000 seconds 16min 40s Parameters of the current unbalance stage l2 gt 46 Parameter Value Unit Description Note Status Current status of the stage Blocked Start F Trip F SCnir Cumulative start counter C TCntr Cumulative trip counter C SetGrp 1 or2 Active setting group Set SGrpDI Digital signal to select the active Set setting group None Dix Digital input Vix Virtual input LEDx LED indicator signal VOx Virtual output Force Off Force flag for status forcing for Set On test purposes This is a common flag for all stages and output relays too Automatically reset by a 5 minute timeout I2 Ign lgn The supervised value 12 gt lgn Pick up setting Set t gt s Definite operation time Set Type DT Type DT Definite time Set INV Inverse time Equation 5 7 1 K1 s Delay multiplier Type INV Set For details of setting ranges see chapter 12 3 Set An editable parameter password needed C Can be cleared to zero F Editable when force flag is on Recorded 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 V210 EN M A011 Technical description 5 Protection functions 5 7 Current unbalance
55. Protection functions 5 19 Rate of change of frequency ROCOF protection df dt 81R V210 EN M A011 0 6 ROCOFS_v3 0 5 0 4 0 3 0 2 0 14 Fastest possible operation time setting s 0 1 0 1 0 2 0 3 0 4 0 5 0 6 0 7 0 8 Slope setting df dt Hz s 0 714 Figure 5 19 2 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 tmin smaller than the operational delay t an inverse type of operation time characteristics is achieved Figure 5 19 3 shows three examples where the frequency behaviour is the same as in the first example but the tmin setting is 0 15 s instead of being equal with t The operation time depends of the measured average slope according the following equation t np w where trrip Resulting operation time seconds SsET df dt i e slope setting hertz seconds tser 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 19 3 shows the inverse characteristics with the same settings as in Figure 5 19 4 113 5 19 Rate of change of frequency 5 Protection functions Te
56. Un v3 EDly Elapsed time of the operating time setting 100 trip SetGrp 1 Active setting group during fault 2 104 V210 EN M A011 Technical description 5 Protection functions 5 17 100 stator earth fault protection U0f3 lt 64F3 5 17 100 stator earth fault protection Uof3 lt 64F3 NOTE This protection stage is available only in voltage measurement mode 2LL Uo see chapter 7 6 NOTE For this function the zero sequence voltage must be measured from the generator s neutral point and the earth NOTE A unit transformer is usually needed between the generator and the busbar for selective operation of this function The third harmonic undervoltage stage can be used to detect earth faults near a high impedance earthed generator s neutral point or even at the neutral point These kind of faults are rare but if a second earth fault would occur in one of the phases the consequences would be severe because the first earth fault had made the network solidly earthed By using the Uor3 lt stage such situation can be avoided Neutral point is a blind point for conventional earth fault function In case there is an earth fault near the neutral point or even at the neutral point the residual current and zero sequence voltage caused by such fault are negligible or even zero Thus a conventional earth fault protection based on fundamental frequency l and or Up measurement is not able to detect such faults
57. and U31 f Hz The supervised frequency value U f Calculated Umax f Uf gt Pick up setting Set t gt s Definite operation time Set For details of setting ranges see chapter 12 3 Set An editable parameter password needed C Can be cleared to zero F Editable when force flag is on V210 EN M A011 Technical description 5 Protection functions 5 13 Volts hertz over excitation protection Uf gt 24 V210 EN M A011 Recorded values of the latest eight faults There are detailed information available of the eight latest faults Time stamp fault voltage fault frequency elapsed delay and setting group Recorded values of the volts hertz over excitation stage U gt 8 latest faults U gt 24 Parameter Value Unit Description yyyy mm dd Time stamp of the recording date hh mm ss ms Time stamp time of day Fit Fault value V Hz U Un Fault voltage f Hz Fault frequency EDly Elapsed time of the operating time setting 100 trip SetGrp 1 Active setting group during fault 2 95 5 14 Undervoltage protection U1 lt 5 Protection functions Technical description 27P 14 96 Undervoltage protection U lt 27P This a special undervoltage protection for generator applications where the voltage is measured at the generator side of the generator circuit breaker There are special self blocking features for starting up and shutting do
58. communication delays A negative value will compensate any leading offset of the external synch source AAlntv 10000 s Adapted auto adjust interval for 1 Set ms correction AvDrft Lead Adapted average clock drift sign Set Lag FilDev 125 ms Filtered synchronisation deviation Set An editable parameter password needed Astronomically a range 11 12 h would be enough but for political and geographical reasons a larger range is needed If external synchoronization 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 V210 EN M A011 Technical description 6 Supporting functions 6 11 Running hour counter 6 11 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 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 0 3599 s Total active time seconds Set Starts 0 65535 Activation counter Set Status Stop Current status of the selected Run digital signal DI Select the supervised signal Set None DI1 DI6 Physical inputs VI1 V14 Virtual inputs LedAl Output matrix out signal Al LedTr Output
59. data format normalized value or scaled value DbandEna No Dead band calculation Set Yes enable flag DbandCy 100 10000 ms Dead band calculation Set interval Set An editable parameter password needed 226 V210 EN M A011 Technical description 9 Communication 9 2 Communication protocols 9 2 6 V210 EN M A011 IEC 60870 5 103 The IEC standard 60870 5 103 Companion 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 the following 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 ASDU 1 time tagged message ASDU 3 Measurands ASDU 5 Identification message ASDU 6 Time synchronization and 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
60. definite time delay start latest wnen the measured value is twenty times the setting However there are limitations at high setting values due to the measurement range See chapter 5 29 for more details 153 6 1 Event log 6 Supporting functions Technical description 6 6 1 154 Supporting functions Event log 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 an overvoltage trip event of the first 59 stage U gt is shown in the following table EVENT Description Local Communication panel protocols Code 30E2 Channel 30 Yes Yes event 2 U gt trip on Event text Yes No 112 0 Ugn Fault value Yes No 2007 01 31 Date Yes Yes 08 35 13 413 Time Yes Yes Type U12 23 31 Fault type Yes No Events are the major data fora 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 VAMSET 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 us
61. firmware See Chapter 16 Firmware revision history c None version 6 firmware D 4pcs version 6 firmware E None standard firmware F 4pcs standard firmware Ingress protection rating IP30 default l IP54 option 289 15 Order information Operation and configuration instructions Accessories Order Code VEA3CGi VPA3CG VSE001PP VSE002 VSE003 VSE009 VIO 12 AB VIO 12 AC VIO 12 AD VX003 3 VX004 M3 VX007 F3 VA 1 DA 6 VAM 16D VYX076 VYX077 VYX233 V200WAF VM690 230 290 Explanation External ethernet interface module Profibus interface module Fiber optic Interface Module plastic plastic RS485 Interface Module RS485 Interface Module Ext I O interface External DeviceNet interface module 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 Vac dc RS232 programming cable Vampset VEA 3CGi TTL RS232 converter cable PLC VEA 3CGi TTL RS232 converter cable VPA 3CG Arc Sensor External LED module Raising Frame for 200 serie Raising Frame for 200 serie Raising Frame for 200 serie V200 wall aseembly frame 3 Phase Nominal Voltage Matching Transformer Note Cable length 3m Cable length 3m Cable length 3m Cable length 6m
62. for VT supervisor I2 lt 0 0 200 0 ln 100 0 Lower setting for VT supervisor t gt 0 02 600 0 s 0 10 Operation delay VT on On Off On VT supervisor on event VT off On Off On VT supervisor off event Measured and recorded values of VT supervisor VTSV Parameter Value Unit Description Measured U2 Un Measured negative value sequence voltage 12 ln Measured negative sequence current Recorded Date Date of VT supervision values alarm Time Time of VT supervision alarm U2 Un Recorded negative sequence voltage 12 ln Recorded negative sequence current For details of setting ranges see chapter 12 4 169 6 8 Circuit breaker condition monitoring 6 Supporting functions Technical description 6 8 170 Circuit breaker condition monitoring The relay has a condition monitoring function that supervises the wearing of the circuit breaker The condition monitoring can give alarm for the need of CB maintenance well before the CB condition is critical The CB wear function measures the breaking current of each CB pole separately and then estimates the wearing 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 chapter 5 25 for CBFP and the setting parameter CBrelay Breaker curve and its approximation The permissible cycle diagram is usually available
63. front panel ENTER PASSWORD a kk0 v Figure 2 2 5 1 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 A 3 Push Oa 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 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 pwd_break Get the break code Example 6569403 get serno Get the serial number of the relay Example 12345 Send both the numbers to your nearest Schneider Electric Customer Care Centre 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 Command Description set pwd_break 4435876 Restore the factory default passwords 4435876 is just an example The actual code should be asked from your nearest Schneider Electric Customer Care Centre Now the passwords are restored to the default values See chapter 2 2 5 V210 EN M A011 Operation and configuration 2
64. functions sesssssssereereeseserrrrrnrreeeee 49 5 3 General features of protection stages ccceeeeee 50 5 4 Overcurrent protection l gt 50 51 eeeeeeeeeeeeeeeeeeeeeeeeee 53 5 5 Directional overcurrent protection lair gt 67 cccceeeeeeeees 58 V210 EN M A011 Table of Contents 5 6 Voltage restrained controlled overcurrent function ly gt 51V 63 5 7 Current unbalance protection l2 gt 46 cceeeeeeeeeees 67 5 8 Thermal overload protection T gt 49 ceeeeeeeeeeeeees 70 5 9 Earth fault protection lo gt 5ON 51N ceeeeeeeeeeeeeeeeeee 74 5 10 Directional earth fault protection log gt 67N eeeeeeee 79 5 11 Intermittent transient earth fault protection lont gt 67NI 85 5 12 Overvoltage protection U gt 59 eeeeeeteeeeeeeeeeeeeee 90 5 13 Volts hertz over excitation protection U 24 s e 93 5 14 Undervoltage protection U4 lt 27P 0 2 eeeeeeeeeeeeeeeeeeeeeeeeeee 96 5 15 Undervoltage protection U lt 27 ceeeecieeeeteeeeeeeeeeteeee 99 5 16 Zero sequence voltage protection Uo gt 59N 2 102 5 17 100 stator earth fault protection Upis lt 64F3 105 5 18 Overfrequency and underfrequency protection f gt f lt COVEN OL ccdohiseainanschen tenia Adenia RAA 109 5 19 Rate of change of frequency ROCOF protection df dt 81R 111 5 20 Under impedance protection Z lt 21 e
65. indicators 4 RS 232 serial communication port for PC 10 V210 EN M A011 Operation and configuration 2 Local panel user interface 2 1 Relay front panel 2 1 1 V210 EN M A011 Display The relay is provided with a backlightedt 128x64 LCD dot matrix display The display enables showing 21 characters in one row and eight rows at the same 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 1 1 The other purpose is to show the configuration and parameterization values of the relay Figure 2 1 1 2 Figure 2 1 1 1 Sections of the LCD dot matrix display Freely configurable single line diagram Five controllable objects Six object statuses Bay identification Local Remote selection Auto reclose on off selection if applicable Freely selectable measurement values max six values SO OU ee N ked2 Et 5 aM I hen d TA PAN I Est Barth E E E raki i EAT ah R L H MENG Figure 2 1 1 2 Sections of the LCD dot matrix display 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 DOr ee 11 2 1 Relay front panel 2 Local panel user interface Operation and configuration instructions Backlight control Display backlight can be sw
66. instead of the fundamental frequency value In the example above the result would then be 13 0 189 7 3 Demand values 7 Measurement functions Technical description 7 3 190 Demand values The relay calculates average i e demand values of phase currents IL1 IL2 ILg and power values S P and Q The demand time is configurable from 10 minutes to 30 minutes with parameter Demand time Demand value parameters Parameter Value Description Set Time 10 30 Unit min Demand time averaging time Set Fundamental frequency values ILida A Demand of phase current IL1 IL2da A Demand of phase current IL2 IL3da A Demand of phase current IL3 Pda kW Demand of active power P PFda Demand of power factor PF Qda kvar Demand of reactive power Q Sda kVA Demand of apparent power S RMS values ILida A Demand of phase current IL1 IL2da A Demand of phase current IL2 IL3da A Demand of phase current IL3 V210 EN M A011 Technical description 7 Measurement functions 7 4 Minimum and maximum values 7 4 V210 EN M A011 Minimum and maximum values Minimum and maximum values 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 Description measurement I
67. is less than 40 ms a trip signal is issued when the operation time is full When the time between successive faults is more than 40 ms the stage will release between the faults and the delay counting is restarted from zero for every single fault and no trip will be issued For such cases the intermittent setting can be used Figure 5 11 2 shows an example of how the intermittent setting works The upper start and trip signals are a case with zero intermittent setting The lower signals are another case with intermittent setting 0 12 s The operation time setting is 0 14 s in both cases corresponding to seven 20 ms time slots with faults 87 5 11 Intermittent transient earth fault 5 Protection functions Technical description protection IOINT gt 67NI The time between the second and the third fault exceeds the release time intermittent time Thus the operation delay counter is cleared in both cases with zero intermittent time and with 0 12 s intermittent time The fourth and the next faults do occur after release time but within release time intermittent time Thus the operation delay counter is advanced at every fault in the case the intermittent time setting is more than 100 ms the lower status lines in the figure and finally a trip signal is issued at t 0 87 s When faults do occur more than 20 ms apart each other every single fault will increment the operation delay counter by 20 ms In this example the actual operation ti
68. is used for sampling rate synchronization when no voltage is present The local network frequency can also be manually given for the relay 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 1 shows a hardware block diagram of the relay The main components are the current and voltage inputs digital input elements output relays A D converters and the microcomputer and a power supply unit Figure 4 2 2 shows the inputs and outputs of a general protection function The FFT block is calculating the fundamental frequency phasors and also harmonics used by some protection functions The block matrix is used for simple interlocking More complex interlocking is done with the user s programmable logic The output matrix is used to connect the pick up and trip signals from protection blocks to the output relays and indicators Figure 4 2 3 shows a block diagram of a basic overcurrent or overvoltage function with definite and inverse operation time V210 EN M A011 47 4 2 Principles of numerical 4 Introduction Technical description protection techniques Display and keyboard Antialiasing 16 bit filter A D converter Trip
69. k 2 0 06 k 0 5 k 1 1 2 3 4 5678 10 20 T Iset inverse DelayIEEE2_EI Figure 5 29 1 14 IEEE2 extremely inverse delay RI and RXIDG type inverse time operation These two inverse delay types have their origin in old ASEA nowadays ABB earth fault relays The operation delay of types RI and RXIDG depends on the measured value and other parameters according Equation 5 29 1 4 and Equation 5 29 1 5 Actually these equations can only be used to draw graphs or when the measured value is constant during the fault Modified versions are implemented in the relay for real time usage Equation 5 29 1 4 RI k 0 236 T pickup Equation 5 29 1 5 RXIDG 0 339 ri temg 5 8 1 35In pickup t Operation delay in seconds k Users multiplier Measured value lnickup User s pick up setting V210 EN M A011 Technical description 5 Protection functions 5 29 Inverse time operation V210 EN M A011 Example for Delay type RI 4 The operation time in this example will be 2 3 seconds The same result can be read from Figure 5 29 1 15 Example for Delay type RXIDG k 0 50 4pu lhickup 2 PU k 0 50 4pu lbickup 2 PU 0 5 tee gt a 2 3 0 339 0 236 tang 5 8 1 35In 5239 The operation time in this example will be 3 9 seconds The same result can be read from Figure 5 29 1 16 eG RI ant RXIDG 400 400 200 200 100 80
70. matrix configuration for trip circuit supervision with one wet digital input V210 EN M A011 243 10 4 Trip circuit supervision 10 Applications Technical description 244 Example of dimensioning the external resistor R Uaux 110Vdc 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 Ux 120 Vac dc 20 10 Coil voltage of the auxiliary relay K1 lk 6mA Nominal coil current of the auxiliary relay K1 Pcpcol SOW Rated power of the open coil of the circuit breaker Umin Uaux 5 104 5 V Umax Uaux 10 121V Uximin Uk 10 96 V Rk1coil Uxi Ik4 20 kQ IkiMIN Ukimin Rxtcoi 4 8 MA K1MAX Uk max Rk1Coil 6 1 mA Rcscoil U aux P 242 Q The external resistance value is calculated using Equation 10 4 1 4 Equation 10 4 1 4 U U kimin R MIN I kimin R 104 5 96 0 0048 242 1529 Q By selecting the next smaller standard size we get 1 5 KQ R Coil The power rating for the external resistor is calculated using Equation 10 4 1 5 This equation includes a 100 safety margin to limit the maximum temperature of the resistor because modern resistors are extremely hot at their rated maximum power Equation 10 4 1 5 P i a R P 2 0 0061 2x1500 0 11 W Select the next bigger
71. 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 V210 EN M A011 181 6 12 Timers 6 Supporting functions Technical description 6 12 182 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 the setting parameters for details The timer outputs are available for logic functions and for the block and output matrix not in use Day sh en ty dl Mody Tuesday U Wednesday a E Ln aaa Thusdy aaa a a U S Fiddy S U aaa Saturday aaa a a a a Sudy aaa aaa a a a a a Mints a G ake Le G Ss MIWES Lf L ee ia SatSun U U Figure 6 12 1 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 forcin
72. menu selection with parameter Protocol See chapter 9 1 V210 EN M A011 223 9 2 Communication protocols 9 Communication Technical description Parameters Parameter Value Unit Description Note Mode Profile selection Set Cont Continuous mode Reqst Request 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 NoLimit compatibility with old systems InBuf bytes Size of Profibus master s 1 3 Rx buffer data to the master OutBuf bytes Size of Profibus master s 2 3 Tx buffer data from the master Addr 1 247 This address has to be Set unique within the Profibus network system Conv Converter type No converter recognized 4 VE Converter type VE is recognized Set An editable parameter password needed Clr Clearing to zero is possible 1 In 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 In 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 length of these buffers are needed The device calculates the lengths acc
73. min demand Parameter to select the type of the S registered values Collect min amp max of one cycle values Collect min amp max of 200 ms average values Collect min amp max of 1 s average values Collect min amp max of 1 minute average values Collect min amp max of demand values see chapter 7 3 ResetDays Reset the 31 day registers 5 ResetMon Reset the 12 month registers S This is the fundamental frequency rms value of one cycle updated every 20 ms 192 V210 EN M A011 Technical description 7 Measurement functions 7 6 Voltage measurement mode 7 6 V210 EN M A011 Voltage measurement mode 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 used connection The available modes are e 2LL Uo The device is connected to line to line voltages U12 and U23 and to zero sequence voltage Up The phase to ground voltages are calculated See Figure 7 6 1 and Figure 7 6 2 The network must use only three wires Any neutral wire must not exist e 3LN The device is connected to phase to ground voltages U_1 U2 and U 3 The zero sequence voltage is calculated See Figure 7 6 3 There may exist a neutral wire The overvoltage protection is always based on the line to line voltage r
74. mo oa e N oo 1 O TIIT g euowoon 2 THON Q A gt o Fi N a g a 4 Figure 11 10 1 Connection example of VAMP 210 V210 EN M A011 269 12 1 Connections 12 Technical data Technical description 12 Technical data 12 1 Connections 12 1 1 Measuring circuitry Rated phase current 5 A configurable for CT secondaries 1 10 A Current measuring range 0 250 A Thermal withstand 20 A continuously 100 A for 10 s 500 A for 1 s Burden lt 0 2VA Rated phase current optional 1 A configurable for CT secondaries 1 10 A Current measuring range 0 50 A Thermal withstand 20 A continuously 100 A for 10 s 500 A for 1 s Burden lt 0 1 VA Rated residual current optional 5 A configurable for CT secondaries 1 10 A Current measuring range 0 25 A Thermal withstand 4A continuously 20 A for 10 s 100 A for 1 s Burden lt 0 2VA Rated residual current 1 A configurable for CT secondaries 0 1 10 0 A Current measuring range 0 5A Thermal withstand 4 A continuously 20 A for 10 s 100 A for 1 s Burden lt 0 1 VA Rated voltage Un 100 V configurable for VT secondaries 50 120 V Voltage measuring range 0 160 V 100 V 110 V Continuous voltage withstand 250 V Burden lt 0 5VA Rated frequency fn 45 65 Hz Terminal block Maximum wire dimension Solid or stranded wire 4 mm 10 12 AWG 12 1 2
75. ms Time stamp time of day Fit Ug Minimum fault voltage n EDly Elapsed time of the operating time setting 100 trip PreFlt Ug Supervised value before fault 1 s n average value SetGrp 1 Active setting group during fault 2 Zero sequence voltage protection Up gt 59N The zero sequence voltage protection is used as unselective backup for earth faults and also for selective earth fault protections for generators having a unit transformer between the generator 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 earth also when there is no earth 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 broken delta connection one voltage transformer between the generator s neutral point and earth or calculated from the measured phase to earth voltages according to the selected voltage measurement mode see chapter 7 6 e Phase the zero sequence voltage is calculated from the phase voltages and therefo
76. panel user interface Operation and configuration 18 instructions Main Number Description ANSI Note menu of code menus lop gt 6 1st directional earth fault stage 67N 4 lop gt gt 6 2nd directional earth fault stage 67N 4 loint gt 4 Transient intermittent E F 67NI 4 U gt 4 1st overvoltage stage 59 4 U gt gt 3 2nd overvoltage stage 59 4 U gt gt gt 3 3rd overvoltage stage 59 4 Uf gt 3 Overexcitation stage volt hertz 24 4 U lt 4 1st undervoltage stage 27 4 U lt lt 3 2nd undervoltage stage 27 4 U lt lt lt 3 3rd undervoltage stage 27 4 U1 lt 4 1st positive sequence undervoltage stage 27P 4 U1 lt lt 4 2nd positive sequence undervoltage stage 27P 4 Uo gt 3 1st residual overvoltage stage 59N 4 Uo gt gt 3 2nd residual overvoltage stage 59N 4 Uof3 lt 3 100 stator earth fault stage 64F3 4 P lt 3 1st reverse and underpower stage 32 4 P lt lt 3 2nd reverse and underpower stage 32 4 Q lt 5 Under excitation stage 40 4 Z lt 3 1st underimpedance stage 21 4 Z lt lt 3 2nd underimpedance stage 21 4 X lt 3 1st loss of excitation stage 40 21 4 X lt lt 3 2nd loss of excitation stage 40 21 4 f gt lt 4 1st over under frequency stage 81 4 f gt gt lt lt 4 2nd over under frequency stage 81 4 f lt 4 1st underfrequency stage 81L 4 f lt lt 4 2nd underfrequency stage 81L 4 dfdt 3 Rate of cha
77. possible by the following ways o through the local HMI o through a remote communication o 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 65 close output There is also an output signal Object failed which is activated if the control of an object fails Object states Each object has the following states Setting Value Description Undefined 00 Object state bel Actual state of the object Close Undefined 11 Basic settings for controllable objects Each controllable object has the following settings Setting Value Description DI for obj open None any digital Open information DI for obj close input virtual input or Close information DI for obj ready virtual output Ready information Max ctrl pulse length 0 02 600 5 Pulse length for open and ca close commands Completion timeout Timeout of ready 0 02 600 s indication Object control Open Close Direct object control If changing states takes longer than the time defined by Max ctrl pulse length setting object fails 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 Output signals of controllable objects
78. power quality functions are located under the submenu U Setting parameters of sags and swells monitoring Parameter Value Unit Default Description U gt 20 150 110 Setting value of swell limit U lt 10 120 90 Setting value of sag limit Delay 0 04 1 00 s 0 06 Delay for sag and swell detection SagOn On Off On Sag on event SagOff On Off On Sag off event SwelOn On Off On Swell on event SwelOf On Off On Swell off event V210 EN M A011 Technical description 6 Supporting functions 6 4 Voltage sags and swells V210 EN M A011 Recorded values of sags and swells monitoring Parameter Value Unit Description Recorded Count Cumulative sag counter values Total Cumulative sag time counter Count Cumulative swell counter Total Cumulative swell time counter Sag swell Date Date of the sag swell logs 1 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 Avet 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 i
79. relays current and voltage inputs hese relays SPAbus Modbus Profibus DP fibre connectors X Protection Calculation of functions Block matrix Output matrix symmetric components Output relay FFT calculation control Amplitude and phase shift of base freqency component 32 samples cycle Digital 6 18 inputs Settings Figure 4 2 2 Block diagram of signal processing and protection software 1VISblock2 Start Register event Setting Delay Definite inverse Inverse time Multiplier Enable Ps time characteristic events Figure 4 2 3 Block diagram of a basic protection function 48 V210 EN M A011 Technical description 5 Protection functions 5 1 Maximum number of protection stages in one application 5 Deli Protection functions Each protection stage can independently be enabled or disabled according to the requirements of the intended application Maximum number of protection stages in one application 2 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 chapter 2 4 List of protection functions IEEE IEC symbol Function name ANSI code 50 51 3I gt 3l gt gt 3l gt gt gt Overcurrent protection 67 lair gt s lair gt gt lar gt gt gt lair gt gt gt gt Direct
80. self blocking can not be disabled Initial self blocking When the voltage U has been below the block limit the stages will be blocked until the pick up setting has been reached V210 EN M A011 Technical description 5 Protection functions 5 14 Undervoltage protection U1 lt 27P V210 EN M A011 Figure 5 14 1 shows an example of low voltage self blocking A _ The positive sequence voltage U is below the block limit This is not regarded as an under voltage situation B The positive sequence voltage U is above the block limit but below the pick up level However this is not regarded as an under voltage situation because the voltage has never been above the pick up level since being below the block limit C Voltage is OK because it is above the pick up limit D This is an under voltage situation E Voltage is OK F This is an under voltage situation G Voltage is under block limit and this is not regarded as an under voltage situation H SameasB Voltage is OK J SameasG K Voltage is OK U UlunderSelfBlocking A E I K dead band a ERE EPE AE AOT Ee ES U lt setting block limit time U lt under voltage state Figure 5 14 1 Positive sequence under voltage state and block limit Temporary self blocking at very low currents Further the pick up can be delayed by using setting I lt BIk When the maximum of the three measured phase currents is less than 1 of
81. stages Up gt and Up gt gt 59N Zero sequence voltage setting range 1 60 Uon Definite time function Operating time 0 3 300 0 s step 0 1 s Starting UoCalc 83LN mode Operate time Start time Typically 200 ms Reset time lt 450 ms Reset ratio 0 97 Inaccuracy Starting 2 of the set value or 0 3 of the rated value 1 V 1 or 150 ms 100 stator earth fault protection Upis lt 64F3 Pick up setting range 1 50 Definite time function Operating time 0 5 30 0 minutes Start time Reset time Reset ratio lt 2s lt 4s 1 05 Fundamental low voltage block limit U12 and U23 Blocked when U42 and Uz lt 65 of nominal Inaccuracy Starting Operating time at definite time function 1 units 1 or 2 s When pick up setting is below 5 reset value is less than set value 0 5 unit stage is used NOTE The voltage measurement mode must be 2LL U when this protection 279 12 3 Protection functions 12 Technical data Technical description 12 3 3 Frequency protection Overfrequency and underfrequency protection stages f gt lt and f gt gt lt lt Frequency measuring area 16 0 75 0 Hz Current and voltage meas range 45 0 65 0 Hz Frequency stage setting range 40 0 70 0 Hz Low voltage blocking 10 100 Un Definite time function operating time 0 10 300 0 s step 0 02 s S
82. stages have two setting groups Changing between setting groups can be controlled 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 mimic display any communication protocol or using the inbuilt programmable logic functions Forcing start or trip condition for testing The status of a protection stage can be one of the followings e Ok The stage is not detecting any fault 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 inbuilt blocking logic For example an under frequency stage is blocked if voltage is too low For more details about block matrix see chapter 8 5 Forcing start or trip condition for testing purposes There 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 relay 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
83. 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 4 1 3 for this short time P 121 2 1500 9 8 W V210 EN M A011 Technical description 10 Applications 10 4 Trip circuit supervision 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 10 4 2 Trip circuit supervision with DI19 and DI20 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 input because when the CB is in open position the two digital inputs are in series e The first digital input is connected parallel with the auxiliary contact of the open coil of the circuit breaker e 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 e The second digital input is connected in parallel with the trip contacts e Both inputs are configured as normal closed NC e The user s programmable logic is used to combine the digit
84. the alarm limit current 6 kA For such currents the decrement is one A 1 V210 EN M A011 173 6 8 Circuit breaker condition 6 Supporting functions Technical description monitoring Local panel parameters of CBWEAR function Parameter Value Unit Description Set CBWEAR STATUS Operations left for Al1L1 Alarm 1 phase L1 Al1L2 Alarm 1 phase L2 AliL3 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 time operation IL1 A Broken current of phase L1 IL2 A Broken current of phase L2 IL3 A Broken current of phase L3 CBWEAR SET Alarm1 Current 0 00 100 00 kA Alarmi current level Set Cycles 100000 1 Alarm1 limit for operations Set left Alarm2 Current 0 00 100 00 kA Alarm2 current level Set Cycles 100000 1 Alarm2 limit for operations Set left CBWEAR SET2 Al1On On Alarm1 on event enabling Set Off Al1 Off On Alarm1 off event enabling Set Off Al2On On Alarm2 on event enabling Set Off Al2Off On Alarm2 off event enabling Set Off Clear a Clearing of cycle counters Set Clear Set An editable parameter password needed The breaker curve table is edited with VAMPSET 174 V210 EN M A011 Technical description 6 Supporting functions 6 9 Energy pulse outputs 6 9 V210 EN M A011 Energy puls
85. the fault detection time and operation time of the trip contacts Under excitation stage Q lt 40 Settings Q P0 Reactive power limit at P 0 100 0 xSen Q P80 Reactive power limit at P 80 100 0 xSen Definite time function Operating time 0 08 300 00 s step 0 02 s Start time Typically 60 ms Reset time 0 06 300 00 s step 0 02 s Retardation time lt 50 ms Reset ratio 0 98 x Sen Inaccuracy Starting 3 of set value or 0 5 of Sen Operating time 1 or 30 ms This is the instantaneous time i e the minimum total operational time including the fault detection time and operation time of the trip contacts V210 EN M A011 281 12 3 Protection functions 12 Technical data Technical description Under reactance and loss of excitation stages X lt X lt lt 40 Trip area radius setting range 0 05 2 00 xZn Resistive offset Ros 2 00 2 00 xZn Reactive offset Xos 2 00 2 00 xZn Definite time function Operating time 0 08 300 00 s step 0 02 s Start time lt 80 ms Reset time 0 08 300 00 s step 0 02 s Reset ratio 1 05 Inaccuracy Starting 4 of set value or 0 01 x Zn Operating time at definite time function 1 or 30 ms This is the instantaneous time i e the minimum total operational time including the fault detection time and operation time of the trip contacts Reverse pow
86. the standard but the release time is constant The operation delay depends on the measured value and other parameters according Equation 5 29 1 2 Actually this equation can only be used to draw graphs or when the measured value is constant during the fault A modified version is implemented in the relay for real time usage Equation 5 29 1 2 t k 4 __ 3 I C ese t Operation delay in seconds k Users multiplier Measured value pickup Users pick up setting A B C Constant parameter according Table 5 29 1 3 Table 5 29 1 3 Constants for IEEE ANSI inverse delay equation Dalay wos Parameter LTI Long time inverse 0 086 0 185 0 02 LTVI Long time very inverse 28 55 0 712 2 Long time extremely LTEI inverse 64 07 0 250 2 MI Moderately inverse 0 0515 0 1140 0 02 VI Very inverse 19 61 0 491 2 El Extremely inverse 28 2 0 1217 2 STI Short time inverse 0 16758 0 11858 0 02 Short time extremely STEI Pverse 1 281 0 005 2 V210 EN M A011 145 5 29 Inverse time operation 5 Protection functions Technical description Example for Delay type Moderately inverse Ml k 0 50 4pu lpickup 2 pu A 0 0515 B 0 114 C 0 02 t 0 50 E Hos 1 9 4y 1 2 The operation time in this example will be 1 9 seconds The same result can be read from Figure 5 29 1 8 aaa IEEELTI gu IEEE LTVI 400 400 200 100 80 60 40 20 delay s delay s 0 2 0 2 0 1 0
87. timeout Set Fault Fault identifier number for IEC 103 Starts trips of all stages TagPos Position of read pointer Chn Active channel ChnPos Channel read position Fault numbering Faults Total number of faults GridFlts Fault burst identifier number Grid Time window to classify Set faults together to the same burst Set An editable parameter password needed V210 EN M A011 Technical description 9 Communication 9 2 Communication protocols 9 2 7 9 2 8 V210 EN M A011 DNP 3 0 The relay supports communication using DNP 3 0 protocol The following DNP 3 0 data types are supported binary input binary input change double bit input binary output analog input e counters Additional information can be obtained from the DNP 3 0 Device Profile Document for VAMP 2xx DNP 3 0 communication is activated via menu selection RS 485 interface is often used but also RS 232 and fibre optic interfaces are possible Parameters Parameter Value Unit Description Set bit s bps Communication speed Set 4800 9600 default 19200 38400 Parity Parity Set None default Even Odd SlvAddr 1 65519 An unique address for the Set device within the system MstrAddr 1 65519 Address of master Set 255 default LLTout 0 65535 ms Link layer confirmation Set timeout LLRetry 1 255 Link layer retry count Set 1 default APLTout 0 65535 ms
88. to activate the virtual input or select Vloff to deactivate the virtual input 27 2 3 Operating measures 2 Local panel user interface Operation and configuration instructions 2 3 2 28 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 table 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 1 kW PL2 P POWER PHASE 1 Active power of phase 2 kW PL3 P POWER PHASE 1 Active power of phase 3 kW QL1 P POWER PHASE 1 Reactive power of phase 1 kvar QL2 P POWER PHASE 1 Reactive power of phase 2 kvar QL3 P POWER PHASE 1 Reactive power of phase 3 kvar SL1 P POWER PHASE 2 Apparent power of phase 1 kVA SL2 P POWER PHASE 2 Apparent power of phase 2 kVA SL3 P POWER PHASE 2 Apparent power of phase 3 kVA
89. to exit the Force function 11 Push to return to the main menu NOTE All the interlockings and blockings are bypassed when the force control 32 is used V210 EN M A011 Operation and configuration 2 Local panel user interface 2 4 Configuration and parameter setting 2 4 V210 EN M A011 Configuration and parameter setting The minimum procedure to configure a relay is 1 Open the access level Configurator The default password for configurator access level is 2 2 Set the rated values in menu CONF including at least current transformers voltage transformers and generator ratings 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 Set the 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 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 7 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 D Some of the parameters can only be changed via the RS 232 serial port using the VAMPSET software Such parameters
90. up value scaled to primary value I gt xIgn Pick up setting Set Curve Delay curve family DT Definite time IEC Inverse time See chapter 5 29 IEEE Set IEEE2 Pre 1996 RI PrgN Type Delay type DT Definite time NI Inverse time See chapter 5 29 Vi Set El LTI Paramet ers t gt s Definite operation time for Set definite time only k gt Inverse delay multiplier for Set inverse time only Dly20x s Delay at 20xlset Dly4x s Delay at 4xlset Dly2x s Delay at 2xlset Dly1x s Delay at 1xlset A B C D User s constants for standard Set E equations Type Parameters See chapter 5 29 For details of setting ranges see chapter 12 3 Set An editable parameter password needed C Can be cleared to zero F Editable when force flag is on 55 5 4 Overcurrent protection I gt 50 51 5 Protection functions Technical description 56 Parameters of the overcurrent stages I gt gt I gt gt gt 50 51 Parameter Value Unit Description Note Status Current status of the stage Blocked Start F Trip F SCnir Cumulative start counter C TCntr Cumulative trip counter C SetGrp 1or2 Active setting group Set SGrpDI Digital signal to select the active Set setting group i None Dix Digital input Vix Virtual input LEDx LED indicator signal vox Virtual output Force Off Force flag for status forcing for Set On test purposes This is a common flag for all stages an
91. value 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 Voltage interruptions Voltage low limit U1 10 120 Definite time function DT Operating time lt 60 ms Fixed Reset time lt 60 ms Reset ratio 1 03 Inaccuracy Activation 3 of the set value 285 13 Abbreviations and symbols Operation and configuration instructions 13 286 ANSI CB CBFP cos CT CTperi CTsec Dead band DI DO DSR DST DTR FFT Hysteresis lseT loset loin loon IEEE IEC 103 LAN Abbreviations and symbols American National Standards Institute A standardization organisation Circuit breaker Circuit breaker failure protection Active power divided by apparent power P S See power factor PF Negative sign 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 Data set ready An RS232 signal Input in front panel port of VAMP relays to disable rear panel local port Daylight saving time Adjusting the official local time forward by one hour for summer time Data terminal ready An RS232 signal Output and alway
92. voltage blocking is checking the maximum of line to line voltages This is the instantaneous time i e the minimum total operational time including the fault detection time and operation time of the trip contacts 280 V210 EN M A011 Technical description 12 Technical data 12 3 Protection functions Rate of change of frequency ROCOF stage df dt gt 81R Setting range 0 2 10 0 Hz s Definite time function operating time 0 14 10 00 s Minimum delay for inverse time delay 0 14 10 00 s Start time Typically 140 ms Reset time lt operating time 150 ms Retardation time lt 90 ms Reset ratio 1 Inaccuracy starting 0 05 Hz s operating time 1 or 30 ms The fastest operation time is more than specified if the setting is less than 0 7 Hz s This is the instantaneous time i e the minimum total operational time including the fault detection time and operation time of the trip contacts 12 3 4 Impedance and power protection Under impedance stages Z lt Z lt lt 21 Pick up setting range 0 05 2 00 xZn Definite time function Operating time 0 08 300 00 s step 0 02 s Start time Typically 60 ms Reset time lt 95 ms Retardation time lt 50 ms Reset ratio 1 05 Inaccuracy Starting 4 of set value or 0 01 x Zn Operating time at definite time function 1 or 30 ms This is the instantaneous time i e the minimum total operational time including
93. when the operation delay time has elapsed a trip signal is issued In this definite time mode the second delay parameter minimum delay tmin 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 without a trip the stage will release ROCOF and over under frequency 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 underfrequency function However in most cases a standard overfrequency and underfrequency stages must be used together with ROCOF to ensure tripping also in case the frequency drift is slower than the slope setting of ROCOF Definite operation time characteristics Figure 5 19 1 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 tyin 0 60 s Equal times t tmin 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 19 2 112 V210 EN M A011 Technical description 5
94. 0 08 300 00 s step 0 02 s Start time Typically 60 ms Reset time lt 95 ms Retardation time lt 50 ms Reset ratio 0 97 Transient over reach any t lt 10 Inaccuracy Starting Operate time 3 of set value 1 or 30 ms This is the instantaneous time i e the minimum total operational time including the fault detection time and operation time of the trip contacts Current unbalance stage I2 gt 46 Setting range Definite time characteristic operating time Inverse time characteristic 1 characteristic curve time multiplier K upper limit for inverse time Start time Reset time Reset ratio Inaccuracy Starting Operate time 2 70 step 1 1 0 600 0s s step 0 1 Inv 1 50 s step 1 1000s Typically 200 ms lt 450 ms 0 95 1 unit 5 or 200 ms Stage is operational when all secondary currents are above 250 mA Thermal overload stage T gt 49 Overload factor Alarm setting range Time constant Tau Cooling time coefficient Max overload at 40 C Max overload at 70 C Ambient temperature Resetting ratio Start amp trip Inaccuracy operating time 0 1 2 40 x len Step 0 01 60 99 step 1 2 180 min step 1 1 0 10 0 xTau step 0 1 70 120 len Step 1 50 100 len step 1 55 125 C step 1 0 95 5 or 15 275 12 3 Protection functions 12 T
95. 08 0 06 0 1 0 08 0 06 1 2 3 4 5678 10 20 1 2 3 4 5678 10 20 T Iset inverseDelayIEEE1_LTI V Iset inverseDelayIEEE1_LTVI Figure 5 29 1 5 ANSI IEEE long time Figure 5 29 1 6 ANSI IEEE long time inverse delay very inverse delay 146 V210 EN M A011 Technical description 5 Protection functions 5 29 Inverse time operation V210 EN M A011 600 400 200 100 80 60 40 20 Doo delay s 0 8 0 6 0 4 0 2 0 1 0 08 0 06 1 2 3 4 5678 10 20 T Iset inverseDelayIEEE1_LTEI Figure 5 29 1 7 ANSIJEEE long time extremely inverse delay 600 400 200 100 60 40 20 delay s 0 2 0 1 0 08 0 06 1 2 3 4 5678 10 20 T Iset inverseDelayIEEE1_STI Figure 5 29 1 9 ANSI IEEE short time inverse delay IEEE LTEI IEEE STI a IEEE MI 400 200 100 20 k 20 k 10 k 5 delay s 2 k 2 k 0 5 0 2 0 1 0 08 0 06 1 2 3 4 5678 10 20 T Iset inverseDelayIEEE1_MI Figure 5 29 1 8 ANSI IEEE moderately inverse delay IEEE STEI 600 400 100 delay s 0 2 k 20 0 1 k 10 0 08 SRD RET ke 0 06 k 0 5 k 1 _ k 2 k 5 1 2 3 4 5678 10 20 TIs
96. 2 Dielectric test voltages ccccceeeeeeeeeeeeeeeeeeeeeees 272 12 2 3 Mechanical tests xa r aie as wes 272 12 2 4 Environmental COnditionS cceeeceeeeeeeeeeeeeeees 272 T 22S CASING eoit eea ra a re EE 272 27 6 PACK AGG nein a a ONA 273 12 3 Protection fUNCTIONS cccceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeees 273 12 3 1 Current DrOtS COM cecca cansg3cuee casdueestavGegecces eerste 273 12 3 2 Voltage protection ccccceeeeeeeeeeeeeeeeeeeeeeeees 278 12 3 3 Frequency protection ccccceeeeeeesseeeeeeeeeeeeees 280 12 3 4 lmpedance and power protection eeeeeee 281 12 3 5 Second harmonic function eee eeeeeeteeeeeeeeees 282 12 3 6 Fifth harmonic fUNCTION cceeeeeeeeeeeeeeetteeeeeeeees 282 12 3 7 Circuit breaker failure protection ceeeee 283 12 3 8 Arc fault protection stages Option ceeee 283 12 4 Supporting functions site eh cieceticteteteininie ictal etigteledtsase 284 12 4 1 Disturbance recorder DR cccceeeeeeeeteeeeeeeees 284 12 4 2 Inrush current detection 68 eeeeeeeeeseeeeeeeeees 284 12 4 3 Transformer supervision cceeeeeeeeeeeeeeeeeeeeees 284 6 V210 EN M A011 Table of Contents V210 EN M A011 12 4 4 Voltage sags amp swells ccccceeeeeeeeeeeeeeeeeeeeeeees 285 12 4 5 Voltage interruptions ccccceeeeeeeeeeeeeeeeeeeeeeeees 285 13 Abbrev
97. 2 local X4 4 DTR out 8 V X4 5 GND X4 6 No connection X4 7 B RS485 extension port X4 8 A RS485 extension port X4 9 No connection NOTE In the VAMP relays a positive RS485 voltage from A to B corresponds to bit value 1 In X4 connector the RS485 extension port is not galvanically isolated 11 5 Optional two channel arc protection card NOTE When this option card is installed the parameter Arc card type has value 2Arc Bl O Please check the ordering code in chapter 15 NOTE If the slot X6 is already occupied with the DI19 DI20 digital input card this option is not available but there is still one arc sensor channel available See chapter 11 6 The optional arc protection 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 relay or manager V210 EN M A011 259 11 6 Optional digital I O card 11 Connections Technical description DI19 D120 11 6 260 Optional digital I O card DI19 D
98. 29in 2x VYX199 needed 21 0 83 Semi flush B 7S Panel mounting 288 V210 EN M A011 Technical description 15 Order information 12 4 Supporting functions 15 Order information When ordering please state the ordering code VAMP 210 ORDERING CODE V 210 CILITICILIC I Note Optional hardware A H available Optional hardware A G available V210 EN M A011 Nominal current A 1 1A 5 5A Nominal earth fault currents loi amp lo2 A A 5A amp 5A B 5A amp 1A C 1A amp 5A D 1A amp 1A Frequency Hz 7 Standard relay Supply voltage V 40 265Vac de 18 36Vdc 40 265Vac dce ARC Protection 36Vdc ARC Protection 40 265Vac dc DI19 DI20 Optional 18 36Vdc DI19 DI20 Optional moov 1 Optional hardware A None B Plastic Plastic serial fibre interface C Profibus interface D _ RS 485 interface 4 wire E Glass Glass serial fibre interface F _ Rx Plastic Tx Glass serial fibre interface G Rx Glass Tx Plastic serial fibre interface H _ RJ 45 10Mbps ethernet interface M RJ 45 10Mbps ethernet inc IEC 61850 O LC 100 Mbps ethernet fibre interface inc IEC 61850 RJ 45 100Mbps ethernet interface inc IEC 61850 2xLC 100 Mbps ethernet fibre interface inc IEC 61850 2x RJ 45 100 Mbps ethernet interface inc IEC 61850 P R S Analog Outputs amp firmware A Nore version 3
99. 4 1 5 The rated coil voltage 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 V210 EN M A011 Technical description 10 Applications 10 4 Trip circuit supervision V x 110 Vdc Alarm relay for trip circuit failure Trip Circuit failure alarm relay compartment circuit breaker compartment close control Relay K1 Phoenix Contact EMG 17 REL KSR 120 21 21 LC Au Coil 96 127 V 20 kQ Width 17 5 mm Assembly EN 50022 mounting rail V aux CLOSE COIL TCS1Dl closed Figure 10 4 1 5 Trip circuit supervision using one of the VAMP 200 series internally wetted digital input DI1 DI6 and auxiliary relay K1 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 DIGITAL INPUTS DIGITAL INPUTS 1 0 HC 0 5 s off off On 0 Figure 10 4 1 6 An example of digital input DI1 configuration for trip circuit supervision with one wet digital input OUTPUT MATRIX connected connected and latched T1 T2 T3 T4 A1 A2 D Figure 10 4 1 7 An example of output
100. 5 POlts c cnssscebecteeedsesdpneessacthentennsseetesdeesdseeteeeteeenneets 259 11 5 Optional two channel arc protection Card eee 259 11 6 Optional digital I O card DI19 DI20 eeeeeee 260 11 7 External I O extension modules eeeeeeeeeeeeeeees 261 11 7 1 External LED module VAM 16D eeeeeee 261 11 7 2 External input output module ceeeeeeeees 261 11 8 Block diagrams 1 5 detectois paste doe tenesdeheeanedadabededeneenssbde 267 11 9 Block diagrams of option modules ceeeeeeeeee 268 11 9 1 Optional arc protection ccccceeeeeeeeeeeeeteeeeeeeees 268 11 9 2 Optional DI19 DI20 eeeeeccceeeeeeeeeeseseeeeeeeeeeeees 268 11 10 Connection examples cccccceeeeeeeeeeeeeeeeeeeeeeeees 269 12 Technical data wiicciissscncecivenininnicnnaeericinieinennnienwevucinanewenss 270 12 COMMOGU GINS nsin e aaa 270 12 1 1 Measuring circuitry ce cco coca cect eines ener Cocesvetieiicuctimecendss 270 12 1 2 Auxiliary VOItAQC ceeeeeeeeeeeceeeeeeeeeeeeeeeeeeeeeeeees 270 2 PSS Digital INPUTS manene perenne ener 271 Te TA Enp contact Sann ETA 271 12 1 5 Alarm COMaCe cnc eines edi eeaiie eh ededalds 271 12 1 6 Arc protection interface Option ceeeeee 271 12 2 Tests and environmental ConditionS ccccceeee 272 12 2 1 Disturbance tests cccccseccceeeeeeeeeeeeeeeeeeeeeeeeees 272 12 2
101. 99xlgn The average load current before the fault has been 0 99 pu e 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 than the delay setting e SetGrp 1 The setting group has been 1 This line can be reached by K pressing Mid and several times V210 EN M A011 Operation and configuration 2 Local panel user interface 2 2 Local panel operations 2 2 3 V210 EN M A011 Setting groups 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 2 3 1 shows an example where the changing of the I 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 selected by changing the value of the parameter SetGrp group AV P I gt STATUS Status SCntr TCntr SetGrp SGrpDI Force Figure 2 2 3 1 Example of protection submenu with setting grou
102. A1 A2 and A3 2 making contacts relays A4 and A5 1 change over contact IF relay Rated voltage 250 V ac dc Continuous carry 5A DC breaking capacity L R 40ms at 48 VDC 1 3 A at 110 VDC 0 4 A at 220 VDC 0 2 A Contact material AgNi 0 15 gold plated Terminal block Phoenix MVSTBW or equivalent Maximum wire dimension 2 5 mm 13 14 AWG Arc protection interfac e option Number of arc sensor inputs Sensor type to be connected Operating voltage level Current drain when active Current drain range 2 VA1DA 12 Vdc gt 11 9mA 1 3 31 mA NOTE If the drain is outside the range either sensor or the wiring is defected Number of binary inputs 1 optically isolated Operating voltage level 48 Vdc Number of binary outputs 1 open collector Operating voltage level 48 Vdc output without an external amplifier NOTE Maximally three arc binary inputs can be connected to one arc binary 271 12 2 Tests and environmental 12 Technical data Technical description conditions 12 2 Tests and environmental conditions 12 2 1 Disturbance tests Emission EN 50081 1 Conducted EN 55022B 0 15 30 MHz Emitted CISPR 11 30 1 000 MHz Immunity EN 50082 2 Static discharge ESD EN 61000 4 2 class III 6 kV contact discharge 8 kV air discharge Fast transients EFT EN 61000 4 4 class III 2 kV 5 50 ns 5 kHz Surge E
103. C D connector 1 reserved 2 TX_out TTL 3 RX_in TTL 4 RTS out TTL 7 GND 9 8V out Fiber connector TX Upper LC connector RX Lower LC connector 255 11 4 Serial communication connectors 11 Connections Technical description 256 Order Code Communication interface Connector type Pin usage 100Mbps Ethernet 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 100 Mbps Ethernet fibre interface with IEC 61850 LC connector from top Port 2 Tx Port 2 Rx Port 1 Tx Port 1 Rx 100Mbps Ethernet interface with IEC 61850 1 Transmit 2 Transmit 3 Receive 4 Reserved 5 Reserved 6 Receive 7 Reserved 8 Reserved NOTE In the VAMP relays RS485 interfaces a positive voltage from Tx to Tx or Rx to Rx does correspond to the bit value 1 In X5 connector the optional RS485 is galvanically isolated NOTE In 2 wire mode the receiver and transmitter are internally connected in parallel See a table below V210 EN M A011 Technical description 11 Connections 11 4 Serial communication connectors V210 EN M A011 111 on 211 X
104. COM _ Internal fault relay common connector 17 a 17 IFNC Internal fault relay normal closed connector ig O 18 IFNO Internal fault relay normal open connector NXS 251 11 1 Rear panel view 11 Connections Technical description Terminal X3 No Symbol Description 1 1 48V Internal wetting voltage for digital inputs 1 6 2 2 DIt Digital input 1 3 3 DI2 Digital input 2 4 4 DIS Digital input 3 5 5 DI4 Digital input 4 6 6 DI5 Digital input 5 7 7 DI6 Digital input 6 8 aie 9 9 A1 COM Alarm relay 1 common connector 40 10 A1NO Alarm relay 1 normal open connector 11 A1NC Alarm relay 1 normal closed connector m 12 T2 Trip relay 2 14 13 T2 Trip relay 2 3 14 iTi Trip relay 1 14 15 T1 Trip relay 1 15 16 16 17 Uaux Auxiliary voltage 17 18 Uaux Auxiliary voltage 18 Symbol Description Bl External arc light input BO Arc output COM Common for BI and BO S1 gt Arc sensor 1 positive connector S1 gt Arc sensor 1 negative connector S2 gt Arc sensor 2 positive connector S2 gt Arc sensor 2 negative connector Arc sensor itself is polarity free Terminal X6 with DI19 DI20 option No Symbol Description 1 DI19 Digital input 19 2 DI19 Digital input 19 3 DI20 Digital input 20
105. D2 Be SEA DUS iis eeo Sa Magica e a 225 9 2 5 IEC 60870 5 101 is csscccsnpastednnptatetodvasieaetyeabeianaanebers 226 9 2 6 IEC 60870 5 103 di cosscustnotavsicesintigtiamiecnastiniantis 227 927 DNP 3 Oir E E E 229 9 2 8 External I O Modbus RTU master 0 00 229 PoE Ol OOO ree aneti ieii pei aaeain 230 AOA EEN E e ce tad EE 232 TO AD PliGatlO nS iisisiccctiiscsieducncidnad stuisatianwecad stcevadeaanasadictcdanteates 234 10 1 Directly connected generator eeeeeeeeeeeeeeeeeeeeeeeeee 235 10 2 Directly connected generator with unearthed generator MEU alas enaar E A A ied ANAA 236 10 3 Generator transformer unit sssssseeessesseserrrrrrreeseerrree 237 10 4 Trip circuit supervision csseseeeieteae are Oeste 238 10 4 1 Trip circuit supervision with one digital input 238 10 4 2 Trip circuit supervision with DI19 and DI20 245 Table of Contents 11 CONC CIOS vais sian tvawecandetwecenteavereududeenauccdseievindnanendudceteuiiansuat 249 11 1 Rear panel view tiene cote owiehe a cane eee oe 249 11 2 Auxiliary voltage 0 e cece eeeeeenee teeter ee eeeeeeeeeeeeeeeeeeeeeeees 253 DIS POUIDULTSlAY Sy nnise a 253 11 4 Serial communication Connectors ceeeeeeeeeeeeeees 253 11 4 1 Front panel CONNECHOTM ccceeeeeeeeeeeeeeeeeeeeeees 253 11 4 2 Rear panel connector X5 REMOTE e 254 11 4 3 X4 rear panel connector local RS232 and extension RS48
106. DST rules added for system clock HMI changes Order of the first displays changed 1 measurement 2 mimic 3 title timeout does not apply if the first 3 displays are active 293 16 Revision history Operation and configuration instructions 294 V210 EN M A011 Customers Care Center http www schneider electric com ccc Schneider Electric 35 rue Joseph Monier 92506 Rueil Malmaison FRANCE Phone 33 0 1 41 29 70 00 Fax 33 0 1 41 29 71 00 www schneider electric com Publication version V210 EN M A011 Publishing Schneider Electric 12 2012 2012 Schneider Electric All rights reserved
107. Disables rear local communication Height 40mm Height 60mm Height 100mm 690V gt 230V 400V gt 110V V210 EN M A011 Technical description 16 Revision history 12 4 Supporting functions 16 V210 EN M A011 Revision history Manual revision history Manual version Description V210 EN M A011 The first version Firmware revision history Firmware version Description 3 66 Non volatile value storage E PROM updated 3 68 Info display v spontaneous alarm display conflict updated 6 13 A major update Older versions of VAMPSET parameter files are not compatible and must NOT be used Numerous new features has been added e several new protection stages e two setting groups for protection stages e temperature measurement and supervising using external Modbus modules e digital I O extension using external Modbus modules e user s programmable logic e user configurable interactive mimic display e language support Latin alphabet e EC 60870 5 103 DNP 3 0 communication protocols e Supported for internal Ethernet adaptor See Communication interface H in Chapter 15 Order information 6 21 lO gt sector mode characteristics improved IEC 60870 5 101 added 6 62 Uof8 lt correction Unit transformer correction Transient Intermittent 67NI protection function added RMS mode to I gt added Programmable curve Operation delay
108. FANG 2 VOWAGS scaling nann teehee een 205 8 Control TUncCion cicccccciciccccceciecccccctescscceescscccceicscccecccsccceeces 208 8 1 Output HOLA Sesh ecisat Posie blicesdiceadeited detested atuted deeMeted Mercedes 208 6 2 Digita MPU S lt intictecstaceisisicie a tical ete el cee et tere al tues 209 8 3 Virtual inputs and CUTOUTS icsccc sees coce ccerceen dace cen ccencevndeeten 210 8 4 COUTTS etc set wa cae cari ne aviv ania a darie aecesic ee 211 8 9 Blocking Malik nc2sceseteic eesti eae cscs eie cael ase 212 8 6 Controllable ODjCCtS ic cesccc cc ccceceeecccendeannecocecnceseeinacties 213 8 6 1 Local Remote Selection cceceeeeeeeeeeeeeeeeteees 215 6 7 gt LOGIC TUMCHONS Siicict tticcecetttatee E saete olteate 215 9 Communication cicecccecieccicecteccicectececceedecedcaedececenetecedenedencecees 216 9 1 Communication ports cccceeeeeeeeeeeeeeeeeeeeeeeeeeeeeteeee 216 9 1 1 Local port X4 sssssesesssennnnnessesssrrrrrnrnssserrrrennnnneeee 217 9 1 2 Remote port X5 sssssssssssenrressserrrrrrnrnnnsserrrrrnnrrnnset 219 9 1 3 Extension port X4 ccccccceeeeeeeeeceeeceeeeeeeeeeeeeeseeees 220 9 1 4 Ethernet port cccccccceeeeeeesssseseeeceeeeeeeeeeeeseeeeeees 221 9 2 Communication PFOLOCOISicx cee eessceee cout cetera ceendae 222 9 2 1 PC communication iss acsssa cincinnati sia ri itn 222 9 2 2 Modbus TCP and Modbus RTU eeeeee 222 Fee PrOD S DIP a E Raat cette eae 223
109. FtransientFig3 WAV ao AAV VAVAVAVA Seta UL 0 50 100 150 200 Time ms Figure 5 11 1 Typical phase to earth voltages residual current of the faulty feeder and the zero sequence voltage Up during two transient earth faults in phase L1 In this case the network is compensated 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 Uo measurement lo pick up sensitivity The sampling time interval of the relay is 625 us at 50 Hz 32 samples cycle The l 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 is 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 lo transient than sensitive to the absolute amplitude of the transient Thus a fixed value is used as a pick up level for the lo Co ordination with Up gt back up protection Especially in a fully compensated situation the zero sequen
110. I20 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 chapter 15 NOTE If the slot X6 is already occupied with the two channel arc sensor card chapter 11 5 this option is not available The DI19 DI20 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 X6 1 DI19 X6 2 DI19 X6 3 DI20 X6 4 DI20 X6 5 NC X6 6 L X6 7 L V210 EN M A011 Technical description 11 Connections 11 7 External I O extension modules 11 7 External I O extension modules 11 7 1 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 relays front panel Please refer the User manual VAM 16 D VM16D ENxxx for details 11 7 2 External input output module The relay supports an optional external input output modules used to extend the number of digital inputs and outputs Also modules for analogue 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 EXTENSI
111. L1 IL2 IL3 Phase current fundamental frequency value IL1RMS IL2RMS Phase current rms value IL3RMS lo1 lo2 Residual current U12 U23 U31 Line to line voltage Uo Zero sequence voltage f Frequency P Q S Active reactive apparent power ILida IL2da IL8da Demand values of phase currents ILida IL2da IL8da Demand values of phase currents rms values rms value PFda Power factor demand value The clearing parameter ClrMax is common for all these values Parameters Parameter Value Description Set ClrMax Reset all minimum and maximum values S Clear 191 7 5 Maximum values of the last 31 days and twelve months 7 Measurement functions Technical description 7 5 Maximum values of the last 31 days and twelve months 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 following table Measurement Max Min Description IL1 IL2 IL3 X Phase current fundamental frequency value lo1 lo2 X Residual current S xX Apparent power P X X Active power Q X X Reactive power The value can be a one cycle value or an average according parameter Timebase Parameters of the day and month registers Parameter Value Description Set Timebase 20 ms 200 ms 1s 1
112. Leki 27 2 3 2 Measured Calas xascic cazcucscsavceaseeet canes taceeesesesceeekaseass 28 2 3 3 Reading event register cccccceeeeeeeseseeeeeeeeeees 31 2 3 4 Forced control Force cccceeeeeeeesseeeeeeeeeeeees 32 2 4 Configuration and parameter setting ccceeeeeeee 33 2 4 1 Parameter Sein ese sacs ceceewel cock eves swesewatcediavadameenetins 34 2 4 2 Setting range limits ceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeees 35 2 4 3 Disturbance recorder menu DR eeeeeeeeeeees 35 2 4 4 Configuring digital inputs DI eeeeeeeeeeees 36 2 4 5 Configuring digital outputs DO eeeeeeeeees 36 2 4 6 Protection Menu Prot c ccccceeeeeeeeeeeeseeeeeeeeeees 37 2 4 7 Configuration menu CONF ssssssssssssssssesssssssrrnnneeseee 37 2 4 8 Protocol menu BUS eeceeeeecceeeeeeeeeeeeeeeeeeeeeeeeees 40 2 4 9 Single line diagram editing ccceeeeeeeeeeeeeees 43 2 4 10 Blocking and interlocking configuration 43 3 VAMPSET PC software cccccccsssseseeeeeeeeeeeeeeeeeeeseeeeeeeeeees 44 4 INMFOAUCUON ssn eaa a aaia raias 45 4 1 Main IGQLUING Siete scans anya rei sits alot neath ot 46 4 2 Principles of numerical protection techniques 47 5 Protection functions ss civiciscscsiscdescesadassdiniunssatiedleitieasanrazarcaaess 49 5 1 Maximum number of protection stages in one application49 5 2 List of protection
113. Local panel user interface 2 3 Operating measures 2 3 2 3 1 V210 EN M A011 Operating measures Control functions 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 analogue measurement values Please note that the operator password must be active in order to be able to control the objects Please refer to page 26 Opening access Toggling Local Remote control 1 Push ox The previously activated object starts to blink 2 Select the Local Remote object L or R squared by using the arrow keys 3 Push ox 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 4 Confirm the setting by pushing ox The Local Remote state will change Object control 1 Push ox The previously activated object starts to blink 2 Select the object to control by using the arrow keys Please note that only controllable objects can be selected 3 Push ox A control dialog opens 4 Select the Open or Close command by using and v 5 Confirm the operation by pushing ox The state of the object changes Toggling virtual inputs 1 Push ox The previously activated object starts to blink 2 Select the virtual input object empty or black square 3 The dialog opens 4 Select Vlon
114. N 61000 4 5 class III 2 KV 1 2 50 us common mode 1 kV 1 2 50 us differential mode Conducted HF field EN 61000 4 6 0 15 80 MHz 10 V Emitted HF field EN 61000 4 3 80 1000 MHz 10 V m GSM test ENV 50204 900 MHz 10 V m pulse modulated 12 2 2 Dielectric test voltages Insulation test voltage IEC 60255 5 2 kV 50 Hz 1 min Class III Surge voltage IEC 60255 5 5 kV 1 2 50 us 0 5 J Class III 12 2 3 Mechanical tests Vibration IEC 60255 21 1 10 60 Hz amplitude 0 035 mm Class 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 half sine acceleration 5 g duration 11 ms Class 3 shocks in X Y and Z axis direction 12 2 4 Environmental conditions Operating temperature 10 to 55 C Transport and storage temperature 40 to 70 C Relative humidity lt 75 1 year average value lt 90 30 days per year no condensation permitted 12 2 5 Casing Degree of protection IEC 60529 IP20 Dimensions W x H x D 208 x 155 x 225 mm 8 19 x 6 10 x 8 86 inches Material 1 mm steel plate Weight 4 2 kg Colour code RAL 7032 Casing RAL 7035 Back plate 2 2 V210 EN M A011 Technical description 12 Technical data 12 3 Protection functions 12 2 6 Package Dimensions W x H x D 215 x 160 x 275 mm 8 46 x 6 30 x 10 82 inches
115. Ni eE aI O T eE ri rin N va xe i l le ll I loz U U U LL SLOWS F 1919199 S12 sFe1 od OV AG9C OV NTO SLO Oo No elie feieliei elie lnjol mlolnlaja Si Figure 11 1 1 Connections on the rear panel of the VAMP 210 The generator protection relay is connected to the protected object through the following measuring and control connections Phase currents IL1 IL2 and IL3 terminals X1 1 6 Residual currents 101 and 102 terminals X1 7 10 Phase to phase voltages U12 and U23 terminals X1 11 14 Zero sequence voltage UO terminals X1 17 18 V210 EN M A011 249 11 1 Rear panel view 11 Connections Technical description Terminal X1 left side No Symbol Description 1 IL1 S1 Phase current L1 S1 1 3 IL2 S1 Phase current L2 S1 3 5 5 IL3 S1 Phase current L3 S1 5 G 7 lo1 S1 Residual curr
116. ON port is primarily designed for IO modules This port is found in the LOCAL connector of the relay backplane and IO devices should be connected to the port with VSE003 adapter NOTE If ExternallO protocol is not selected to any communication port VAMPSET doesn t display the menus required for configuring the IO devices After changing EXTENSION port protocol to ExternallO restart the relay and read all settings with VAMPSET V210 EN M A011 261 11 7 External I O extension modules 11 Connections Technical description 262 an a oO lt z lt a UJ a x lt External analog inputs configuration VAMPSET only HoldingR HoldingR Range Description Communication read errors X 32000 32000 Y2 Scaled value Y 1000 1000 Point 2 X2 Modbus value Y1 Scaled value Point 1 D X1 Modbus value on 32000 32000 E Subtracted from Modbus 2 value before running XY Off scaling set InputR or HoldingR Modbus register type 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 V210 EN M A011 Technical description 11 Connections 11 7 External I O extension modules Alarms for external analog inputs Range Description 0
117. PDT Parameters of output relays Parameter Value Unit Description Note T1 T2 0 Status of trip output relay Al A5 1 0 1 Status of alarm output relay IF Status of the internal fault indication relay Force On Off Force flag for output relay forcing for test purposes This is a common flag for all output relays and protection stage status too Any forced relay s and this flag are automatically reset by a 5 minute timeout Set REMOTE PULSES Al A5 0 00 99 98 or 99 99 Pulse length for direct output relay control via communications protocols 99 99 s Infinite Release by writing 0 to the direct control parameter Set NAMES for OUTPUT RELAYS edita ble with VAMPSET only Description String of max 32 characters Names for DO on VAMPSET screens Default is Trip relay n n 1 2 or Alarm relay n n 1 5 Set Set An editable parameter password needed F Editable when force flag is on V210 EN M A011 Technical description 8 Control functions 8 2 Digital inputs 8 2 Digital inputs There 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
118. Pick up setting Xloin Arclo2 gt pu Pick up setting Xloon Arclin Light indication source selection Set No sensor selected S1 Sensor 1 at terminals X6 4 5 S2 Sensor 2 at terminals X6 6 7 1 S2 Bl Terminals X6 1 3 1 Bl S2 Bl 1 S2 Bl Delayed light signal output Ldly s Delay for delayed light output Set signal LdlyCn Light indication source selection Set No sensor selected S1 Sensor 1 at terminals X6 4 5 S2 Sensor 2 at terminals X6 6 7 1 S2 Bl Terminals X6 1 3 1 Bl S 2 Bl 1 S2 Bl For details of setting ranges see chapter 12 3 Set An editable parameter password needed C Can be cleared to zero F Editable when force flag is on Recorded values of the latest eight faults There are detailed information available of the eight latest faults Time stamp fault type fault value load current before the fault and elapsed delay 139 5 29 Inverse time operation 5 Protection functions Technical description 5 29 140 Recorded values of the arc protection stages Arcl gt ArcloiA Arclo2 gt 50ARC 50NARC Parameter Value Unit Description yyyy mm dd Time stamp of the recording date hh mm ss ms Time stamp time of day Type pu Fault type value Only for Arcl gt stage Fit pu Fault value Load pu Pre fault current Only for Arcl gt stage EDly Elapsed time of the operating time setting 100 trip Inverse time operation The inverse time operation i e inve
119. Pulse counter input 1 Pulse counter input 2 Pulse counter input 3 Pulse counter input 4 e pulseconf2 Pulse counter input 1 Pulse counter input 2 Pulse counter input 3 Pulse counter input 4 e pulsecont3 having common minus and an internal wetting voltage V210 EN M A011 6 10 System clock and synchronization 6 Supporting functions Technical description 6 10 178 System clock and synchronization 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 Adapting auto adjust During tens of hours of synchronizing the device will learn its average error 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 AvDrit 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 error by editing the parameters AAlntv and AvDrit
120. Secondary to per unit Voltage measurement mode is BLN VT 12000 110 Uan 11000 V Three symmetric phase to neutral voltages connected to the relay s inputs Uz Up and Us are 58 2 V Per unit voltage is Upu V3x58 2 110x12000 11000 1 00 pu 1 00xUen 100 Example 3 Per unit to secondary Voltage measurement mode is 2LL Uo VT 12000 110 Uan 11000 V The relay displays 1 00 pu 100 Secondary voltage is Usec 1 00x110x11000 12000 100 8 V Example 4 Per unit to secondary Voltage measurement mode is 3LN VT 12000 110 Uan 11000 V The relay displays 1 00 pu 100 Three symmetric phase to neutral voltages connected to the relay s inputs Ua Ub and U are Usec 1 00x110 V3x11000 12000 58 2 V V210 EN M A011 Technical description 7 Measurement functions 7 10 Primary secondary and per unit scaling V210 EN M A011 Per unit pu scaling of zero sequence voltage Zero sequence voltage Uo scaling Voltage measurement mode Voltage measurement mode 3LN 2LL Uo 1LL Uo LLy U secondary gt a i 1 UatUy tue ac per unit iste pu VT grc V3 per unit gt U U U ae _ secondary ae al wen UatUo Ue SEC V3 U py Wc Example 1 Secondary to per unit Voltage measurement mode is 2LL Uo Uosec 110 V This is a configuration value corresponding to Up at full earth fault Voltage connected to the device s input U
121. Set An editable parameter password needed C Can be cleared to zero F Editable when force flag is on Recorded values of the latest eight faults There are detailed information available of the eight latest faults Time stamp fault type fault current load current before the fault elapsed delay and setting group 65 5 6 Voltage restrained controlled overcurrent function IV gt 51V 5 Protection functions Technical description 66 Recorded values of the voltage restrained controlled overcurrent stages 8 latest faults iv gt 51V 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 Flt xlgn_ Maximum fault current Load xlgn_ 1s average phase currents before the fault EDly Elapsed time of the operating time setting 100 trip SetGrp Active setting group during the fault V210 EN M A011 Technical description 5 Protection functions 5 7 Current unbalance protection 12 gt 46 5 7 V210 EN M A011 Current unbalance protection l2 gt 46 Current unbalance in a generator 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 ther
122. SetGrp 1 or2 Active setting group Set SGrpDI Digital signal to select the active Set setting group None Dix Digital input VIX Virtual input LEDx LED indicator signal VOx Virtual output Force Off Force flag for status forcing for Set On test purposes This is a common flag for all stages and output relays too Automatically reset by a 5 minute timeout f Hz Measured frequency df dt Hz s The supervised value df dt gt Hz s Pick up value Set t gt s Definite operation time Set tMin gt S Minimum operating time for inverse delay For definite time Set set tMin t LVbIk Un Low limit for self blocking This is acommon setting for all four Set stages and with the undervoltage stages For details of setting ranges see chapter 12 3 Set An editable parameter password needed C Can be cleared to zero F Editable when force flag is on Recorded values of the latest eight faults There are detailed information available of the eight latest faults Time stamp frequency drift elapsed delay and setting group V210 EN M A011 115 5 20 Under impedance protection Z lt 5 Protection functions Technical description 21 5 20 116 Recorded values of the rate of change of frequency stage 8 latest faults df dt gt 81R Parameter Value Unit Description yyyy mm dd Time stamp of the recording date hh mm ss ms Time stamp time of day Fit Hz s Faulty frequency drift EDly Elap
123. T program The recording is in COMTRADE format This means that also other programs can be used to view and analyse the recordings made by the relay For more details please see a separate VAMPSET manual Number of channels At the maximum there can be 12 recordings and the maximum selection of channels in one recording is also 12 limited in waveform recording The 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 analogue waveforms V210 EN M A011 Technical description 6 Supporting functions 6 2 Disturbance recorder V210 EN M A011 Available channels The following channels i e signals can be linked to a disturbance recorder Available for waveform ae Voltage measurement Channel Description mode 2LL Uo 3LN IL1 IL2 IL3 Phase current Yes Yes lo1 lo2 Measured residual current Yes Yes U12 U23 Line to line voltage Yes U31 Line to line voltage UL1 UL2 UL3 Phase to neutral voltage Yes Uo Zero sequence voltage Yes f Frequency P Q S Active reactive apparent power P F Power factor CosFii coso loCalc Phasor sum lo IL1 IL2 IL3 3 l1 Positive sequence current 12 Negative sequence current
124. Tamb Set ExtAl1 External Analogue input 1 16 16 For details of setting ranges see chapter 12 3 Set An editable parameter password needed C Can be cleared to zero F Editable when force flag is on 73 5 9 Earth fault protection 10 gt 50N 51N 5 Protection functions Technical description 5 9 74 Earth fault protection lo gt 50N 51N Undirectional earth fault protection is used for generator s stator earth faults in low impedance earthed networks In high impedance earthed networks compensated networks and isolated networks undirectional earth fault can be used as back up protection The undirectional earth fault function is sensitive to the fundamental frequency component of the residual current 3lo 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 i0s1 Setting Io gt s Delay Definite inverse Inverse time Multiplier Enable events time characteristics Figure 5 9 1 Block diagram of the earth fault stage l gt 0ssblock Start Register event Register event Setting Io gt gt s Delay Enable events Figure 5 9 2 Block diagram of the earth fault stages Ip gt gt l gt gt gt and Ip gt gt gt gt Figure 5
125. Technical description 266 EXTERNAL ANALOG OUTPUTS External analog outputs configuration VAMPSET only c4 S 2 HoldingR Range Description 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 42x108 21 21x108 Minimum limit for lined value corresponding to Modbus Min Link selection 21x107 oo 4214x107 Minimum amp maximum output values Active value On Off Enabling for measurement V210 EN M A011 Technical description 11 Connections 11 8 Block diagrams 11 8 V210 EN M A011 Block diagrams 10 11 12 13 14 17 18 X3 NoJAUON Protection function 50 51 3 gt 3l gt gt 3l gt gt gt 5ON 51N 59 u gt U gt gt U gt gt gt 81H 81L f gt lt f gt gt lt lt 32 P lt SOBF CBFP SONARC ACh gt Arcly gt 99 50ARC Prg1 8 Arcl gt BEEBE BSS Blocking and output matrix
126. The data in a message frame is identified by e type 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 gt 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 defined by the standard e g the status of the digital inputs and the control of the objects 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 227 9 2 Communication protocols 9 Communication Technical description 228 Parameters Parameter Value Unit Description Note Addr 1 254 An unique address within Set the system bit s bps Communication speed Set 9600 19200 Measlint 200 10000 ms Minimum measurement Set response interval SyncRe ASDU6 response time Set Sync mode Sync Proc Msg Msg Proc Set An editable parameter password needed Parameters for disturbance record reading Parameter Value Unit Description Note ASDU23 On Enable record info Set Off message Smpls msg 1 25 Record samples in one Set message Timeout 10 10000 S Record reading
127. Ua U 100 V3 V 20 57 7V 20 Up U 100 V3 V 2 120 57 7 V 2 120 Us U 0V This is actually identical case with example 2 because the resulting line to line voltages U12 UL Utz 100 V 730 and Uz Ute Uls Ure 100 V3 V7 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 100 70 U 1 1 1 ane 100 20 1002 120 U a a T ET 100 20 100 20 U la a gt 0 373 10940 1002 120 1002 60 19 22 60 20020 38 5 20 33 100 60 19 27 60 V210 EN M A011 Technical description 7 Measurement functions 7 9 Symmetric components Uo 19 2 U 38 5 U2 19 2 V210 EN M A011 U2 U 50 Figure 7 9 2 shows a graphical solution The input values have been scaled with V3 100 to make the calculation easier Positive sequence FortescueEx3 U 2 3 2 2 aU U aU Injected line to neutral voltages U 0 cee l Un Un egative sequence x UL UL U 1 3 Figure 7 9 2 Example of symmetric component calculation using line to neutral voltages Unscaling the geometric results gives U 100 V3 x 2 3 38 5 U gt 100V3x1 3 19 2 U gt U 1 3 2 3 50 201 7 10 Primary secondary and per unit 7 Measurement functions Technical description scaling 7 10 Primary secondary and per uni
128. VAMP 210 Generator protection relay Publication version V210 EN M A011 User manual Schneider V210 EN M A011 Table of Contents Table of Contents Nis GSN SF Al sais cascntantahiaasahaaoeutienraasilakanantuavaned tananantienssemnTenneiaatanael 8 1 1 Relay features fxs tc eee i essaiatd Nate beaaked taint ead tat aah 8 k2 SWSEN WG ACC otic ecccster teed eatea aa Aa Aa AEEA EAA AANS 9 1 3 Operating Safety coed fei asians el A heehee aes eee bla ede 9 2 Local panel user interface cccccceseeeseeeeeeeeeeeeeeeeeeeeneeees 10 2ko Relay front panels seei ai 10 DAT ADISplay eee a e e A 11 2 1 2 Menu navigation and pointers eeeeeeeeeeeeeeeeeees 12 2l Keypads ics ob aeaea a a E actors aain 12 2 1 4 Operation INndicators ccceeccceeeeeeeeeeseeeeeeeeeeeeees 13 2 1 5 Adjusting display Contrast cccceeeeceeeeeeeeeeeeees 14 2 2 Local panel operations 2 cves ces cots ctat cocececcvocesecdcecceuectoeseesdee 15 2 2 1 Navigating in Menus cccceeeeeeeeeeeeeeeeeeeeeeees 15 2 2 2 Menu structure of protection functions 20 PAPAE ARSI QUOUDS sievics ives adc coeliecssueatars ieee tacdevedancceneepaciee 23 224 AUN IOOS tcc inen a a aa a aads 24 2 2 5 Operating levels ceeeeccsecceeeeeeeeeeeseeneeeeeeeeees 25 2 3 Operating MEASUIOS soi cece seek coccetud coneseniseceseudeiencaneedonnseedion 27 2 3 1 Control fUNCtIONS 4 2cc2 occ cet ietet esi eesree ete
129. adband calculation 10 51 SC fault distance added to IEC 103 map 10 56 Uo setting grange of loDir stages changed from 1 20 to 1 50 10 58 New features in IEC 61850 added Outputs vef files with suomi amp russian language packets 10 65 100 Mbps option card support 10 67 Default font sizes changed lo gt gt minimum delay setting changed to 0 05s with 0 01s step Popup window added for language packet init EF items EFDX EFDFph EFctr and EFDFItDist added to IEC103 10 68 Ethernet IP and DeviceNet identity info changes 10 74 Lower 3 harmonic limit for Upf3 lt I gt and I gt lo gt gt gt gt stages with faster operation time 10 85 Virtual output events added 10 106 GOOSE supervision signals added Automatic LED latch release added Disturbance recorder full event added 10 108 Use of recorder memory in percents added Various additions to IEC 61850 10 113 U12y voltage measurement to IEC 60870 5 101 protocol NOTE Vampset version 2 2 59 required V210 EN M A011 Technical description 16 Revision history 12 4 Supporting functions V210 EN M A011 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 Vampset version 2 2 97 required 10 118 Enable sending of analog data in GOOSE message Day light saving
130. after the event code Setting parameters for events Parameter Value Description Note Count Number of events ClrEn Clear event buffer Set Clear Order Order of the event buffer for local display Set Old New New Old FVSca Scaling of event fault value Set PU Per unit scaling Pri Primary scaling Display On Alarm pop up display is enabled Set Alarms Off No alarm 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 chapter 6 10 hh mm ss nnn Time V210 EN M A011 155 6 2 Disturbance recorder 6 Supporting functions Technical description 6 2 156 Disturbance recorder The disturbance recorder can be used to record all the measured signals that is currents voltages and the status information of digital inputs DI and digital outputs DO The digital inputs include also the arc protection signals S1 S2 BI and BO if the optional arc protection 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 All recordings are time stamped Reading recordings The recordings can be uploaded viewed and analysed with the VAMPSE
131. age by means of the par meters Q1 and Q2 The shaded area is the area of operation In this example the operation depends on both P and Q because the operating line has an 8 slope Q1 Q2 14 P P Q circle2 Figure 5 21 2 Setting of the under excitation stage by means of the parameters Q1 and Q2 The shaded area constitutes the area of operation In the above example the operation solely depends on the reactive power because the operating line is vertical Q1 Q2 0 V210 EN M A011 Technical description 5 Protection functions 5 21 Under excitation protection Q lt 4 0 V210 EN M A011 Power swing A release time setting is available against prolonged power swings In a power swing situation the power phasor is swinging back and forth between capacitive and inductive power With a long enough release time setting the stage accumulates the total fault time and will eventually trip 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 Parameters of the under excitation stage Q lt 40 Parameter Value Unit Description Note Status Current status of the stage Blocked Start F Trip F TripTime s Estimated time to trip SCntr Cumulative start counter Clr TCntr Cumulative trip counter Clr SetGrp 1 or2 Active setting group Set SGrpDI Digital sign
132. ages Operating time Start time Typically 60 ms Reset time lt 95 ms Retardation time lt 50 ms Reset ratio 1 03 Inaccuracy Starting 3 of set value 1 or 30 ms This is the total operational time including the fault detection time and operation time of the trip contacts NOTE To make the relay trip after low voltage blocking the positive sequence voltage has to go above the pick up setting V210 EN M A011 Technical description 12 Technical data 12 3 Protection functions V210 EN M A011 Undervoltage stage U lt U lt lt U lt lt lt 27 Setting range 20 120 xUn Definite time function Operating time U lt Operating time U lt lt and U lt lt lt 0 08 300 00 s step 0 02 s 0 06 300 00 s step 0 02 s Undervoltage blocking 0 80 x Un Start time Typically 60 ms Reset time for U lt Reset time for U lt lt and U lt lt lt Retardation time Reset ratio hysteresis Reset ratio Block limit 0 06 300 00 s step 0 02 s lt 95 ms lt 50 ms 1 001 1 200 0 1 20 0 step 0 1 0 5 V or 1 03 3 Inaccuracy starting blocking time 3 of set value 3 of set value or 0 5 V 1 or 30 ms This is the instantaneous time i e the minimum total operational time including the fault detection time and operation time of the trip contacts Zero sequence voltage
133. al 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 e The output from the logic 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 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 4 2 1 is not possible in most applications Using the other digital inputs in the same group as the lower DI in the Figure 10 4 2 1 is limited because the whole group will be tied to the auxiliary voltage Vaux Note In many applications the optimum digital inputs for trip circuit supervision are the optional inputs DI19 and DI20 because they don t share their terminals with any other digital inputs V210 EN M A011 245 10 4 Trip circuit supervision 10 Applications Technical description V x 48 Vdc 240 Vdc VAMP relay Alarm relay for trip circuit failure trip circuit failure alarm relay compartment circuit breaker compartment Vaux CLOSE COIL TCS2Diclosed Figure 10 4 2 1 Trip circuit supervision with two dry digital input The CB is closed The supervised circuitry in this CB position is dou
134. al to select the active Set setting group None Dix Digital input Vix Virtual input LEDx LED indicator signal VOx Virtual output Force Off Force flag for status forcing for Set On test purposes This is a common flag for all stages and output relays too Automatically reset by a 5 minute timeout P Sgn The supervised active power value Q Sgn_ The supervised reactive power value Q P0 Sgn Setting 1 See Figure 5 21 1 Set kvar Q P80 Sgn Setting 2 See Figure 5 21 2 Set kvar t lt s Definite operation time Set RIsDly s Release delay for power swing Set For details of setting ranges see chapter 12 3 Set An editable value password needed C Can be cleared to zero F Editable when force flag is on Recorded values of the latest eight faults There are detailed information available of the eight latest earth faults Time stamp fault power P and Q elapsed delay and setting group 121 5 22 Under reactance and loss of 5 Protection functions Technical description excitation protection X lt 40 22 122 Recorded values of the under excitation stage Q lt 40 Parameter Value Unit Description yyyy mm dd Time stamp of the recording date hh mm ss ms Time stamp time of day P Sgn Active fault power Q Sgn Reactive fault power EDly Elapsed time of the operating time setting 100 trip SetGrp 1 Active setting group
135. and flexible protection functions are provided for the generator earth fault protection These features are needed when for instance several generators are connected in parallel to the same busbar but their earthing principles differ The other energizing connections except for the ones for the earth fault protection are independent of the generator size and type For large generator a higher accuracy of the protection functions is needed Being based on numerical signal processing and high resolution A D conversion the device fulfils also these requirements The three generator protection applications on the following pages illustrate how the flexibility of the device can be utilized 234 V210 EN M A011 Technical description 10 Applications 10 1 Directly connected generator 10 1 Directly connected generator L1 L2 L3 50 51 X3 3 gt 3b gt 3P gt gt gt 50N 51N 3Pp gt gt gt W gt 49 T gt 37 U gt gt gt 81H 81L f gt lt f gt gt lt lt 32 P lt P lt lt 21 40 X lt X lt lt 9 b Prg1 8 Arce Blocking and 18 0 output matrix K4 X3 MBV n Digital input
136. and the Equation 6 8 2 and Equation 6 8 3 the relay calculates 10000 In 80 _ 37000 1 5038 In 1250 a 10000 1250 8 454 10 V210 EN M A011 Technical description 6 Supporting functions 6 8 Circuit breaker condition monitoring Using Equation 6 8 1 the relay gets the number of permitted operations for current 6 kA 6 C 454 10 600015038 Thus the maximum number of current breaking at 6 kA is 945 This can be verified with the original breaker curve in Figure 6 8 1 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 Example of operation 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 much are Alarm2 counters decremented Using Equation 6 8 1 and values n and a from the previous example the relay gets the number of permitted operation at 10 kA 454 10 10kA 12500 8 z 313 At alarm level 2 6 kA the corresponding number of operations is calculated according Equation 6 8 4 A ONTA C 945 An A 313 o Thus Alarm2 counters for phases L1 and L2 are decremented by 3 In phase L1 the currents is less than
137. 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 relay See chapter 8 4 for details about the output matrix and the trip relays 132 V210 EN M A011 Technical description 5 Protection functions 5 26 Circuit breaker failure protection CBFP 50BF V210 EN M A011 Parameters of the circuit breaker failure stage CBFP 50BF Parameter Value Unit Description Note Status Current status of the stage Blocked Start F Trip F SCnir Cumulative start counter C TCntr Cumulative trip counter C Force Off Force flag for status forcing for Set On test purposes This is a common flag for all stages and output relays too Automatically reset by a 5 minute timeout CBrelay 1 2 The supervised output relay Set Relay T1 T2 depending the ordering code t gt s Definite operation time Set For details of setting ranges see chapter 12 3 Set An editable parameter password needed C Can be cleared to zero F Editable when force flag is on This setting is used by the circuit breaker condition monitoring too See chapter 6 8 Recorded values of the latest eight faults There are detailed information available of the eight latest faults Time stamp and elapsed delay Recorded values of the circuit breaker fa
138. arameter 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 wearing The operations left can be read from the counters AliLn Alarm 1 and Al2Ln Alarm2 There are three values for both alarms one for each phase The smallest of three is supervised by the two alarm functions V210 EN M A011 171 6 8 Circuit breaker condition monitoring 6 Supporting functions Technical description 172 Logarithmic interpolation The permitted number of operations for currents in between the defined points are logarithmically interpolated using equation Equation 6 8 1 a C where n C permitted operations interrupted current a constant according Equation 6 8 2 n constant according Equation 6 8 3 Equation 6 8 2 Equation 6 8 3 a C I In natural logarithm function Ck permitted operations k row 2 7 in Table 6 8 1 Ik Corresponding current k row 2 7 in Table 6 8 1 Ck permitted operations k row 2 7 in Table 6 8 1 lk 1 corresponding current k row 2 7 in Table 6 8 1 Example of the logarithmic interpolation Alarm 2 current is set to 6 kA What is the maximum number of operations according Table 6 8 1 The current 6 kA lies between points 2 and 3 in the table That gives value for the index k Using k 2 Ck 10000 Cyi1 80 ket 31kKA Ik 1 25kA
139. art of the manual PROFIBUS Only one instance of this protocol is possible e Mode e Bit rate bit s Use 2400 bps This parameter is the bit rate between the main CPU and the 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 InBufl 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 the technical description part of the manual V210 EN M A011 Operation and configuration 2 Local panel user interface 2 4 Configuration and parameter setting 2 4 9 2 4 10 V210 EN M A011 DNP3 Only one instance of this protocol is possible e Bit rate bit s Default is 9600 e Parity e Addres for this device SlvAddr This address has to be unique within the system e Master s addres MstrAddr For further details see the technical description part of the manual S
140. at the neutral point Figure 5 17 2 and Figure 5 17 3 The third harmonic residual undervoltage stage Uois lt is supervising the level of the 3 harmonic at the neutral point If there is an earth fault near the neutral point this 150 Hz or 180 Hz voltage drops below setting and the stage will pick up Uof3_HARM3 20 Uo Uti Ur2 UL3 3 Figure 5 17 2 When symmetric phase to ground voltages containing third harmonic are summed together the result is not zero Uof3_HARM5 ULI UL2 UL3 20 Uo U11 Ur2 UL3 3 0 Figure 5 17 3 When the phase to ground voltages do contain fifth harmonic they cancel each other when summed and the resulting zero sequence voltage Up will be zero V210 EN M A011 Technical description 5 Protection functions 5 17 100 stator earth fault protection U0f3 lt 64F3 Finding out the correct pick up setting A problem with this third harmonic undervoltage stage is to find a proper pick up setting In practice an empirical value is used because the natural 3 harmonic at the neutral point is dependent on Construction of the generator Loading and the power factor Amount of excitation Earthing circuitry Transformers connected The relay itself can be used to measure the actual level of 3 Uo harmonic during various situations Typically the generator is producing its minimum amount of 3 harmonic when the load is small and the excitation is low The pick up s
141. ated power of the open coil of the circuit breaker If this value is not known 0 Q can be used for the Rooi Umin Uaux 20 88 V Umax Uaux 10 121V Rcoi U7aux P 242 Q The external resistance value is calculated using Equation 10 4 1 1 Equation 10 4 1 1 U un U l R Ip Coil R R 88 18 0 003 242 0 003 23 1 KQ In practice the coil resistance has no effect By selecting the next smaller standard size we get 22 KQ The power rating for the external resistor is estimated using Equation 10 4 1 2 and Equation 10 4 1 3 The Equation 10 4 1 2 is for the CB open situation including a 100 safety margin to limit the maximum temperature of the resistor Equation 10 4 1 2 P 2 I R P 2 0 003 2x22000 0 40 W 241 10 4 Trip circuit supervision 10 Applications Technical description 242 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 4 1 3 for this short time Equation 10 4 1 3 P Cae R P 12142 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 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
142. ation Technical description 9 2 5 IEC 60870 5 101 The IEC 60870 5 101 standard is derived from the IEC 60870 5 protocol standard 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 Supported 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 document Parameters Parameter Value Unit Description Note bit s 1200 bps Bitrate used for serial Set 2400 communication 4800 9600 Parity None Parity used for serial Set Even communication 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 Set size 8 octet 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 Set Full time tag format 3 octet time tag or 7 octet time tag MeasFormat Scaled The parameter determines Set Normalized measurement
143. ay 3 common connector Fs S 11 A3 NC Alarm relay 3 normal closed connector 49 ea 12 A3NO Alarm relay 3 normal open connector 13 A2 COM Alarm relay 2 common connector 13 14 A2NC Alarm relay 2 normal closed connector 14 15 A2 NO Alarm relay 2 normal open connector 15 16 IF COM _ Internal fault relay common connector 16 17 IFNC Internal fault relay normal closed connector 17 18 IFNO Internal fault relay normal open connector 18 Terminal X2 with the analogue output V210 EN M A011 No Symbol Description 1I 1 AQ1 Analogue output 1 common positive connector 2 2 AO1 Analogue output 1 negative connector 3 3 AQ2 Analogue output 2 common positive connector 4 4 AQ2 Analogue output 2 negative connector 5 5 AO3 Analogue output 3 common positive connector 6l 6 AO3 Analogue output 3 negative connector 71 7 AO4 Analogue output 4 common positive connector 8l 8 AO4 Analogue output 4 negative connector o S 2 i 10 10 A3 COM Alarm relay 3 common connector 11 11 A3 NC Alarm relay 3 normal closed connector 12 12 A3NO Alarm relay 3 normal open connector 13 13 A2COM Alarm relay 2 common connector 14 14 A2NC Alarm relay 2 normal closed connector 15 15 A2 NO Alarm relay 2 normal open connector 16 16 IF
144. 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 chapter 5 27 Three independent stages There are three separately adjustable stages U gt U gt gt and U gt gt gt All the stages can be configured for definite time DT operation characteristic Configurable release delay The U gt stage has a settable release delay 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 delay has elapsed If the fault appears again before the release delay 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 V210 EN M A011 Technical description 5 Protection functions 5 12 Overvoltage protection U gt 59 V210 EN M A011 Configurable hysteresis The dead band is 3 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 Otherwise the stage will not release after fault Setting groups There are two settings groups available for each stage
145. bined overcurrent status 6 Supporting functions Technical description 6 13 184 Line fault parameters Combined overcurrent status This function is collecting faults fault types and registered fault currents of all enabled overcurrent stages Parameter Value Unit Description Note IFitLas Xlen Current of the latest overcurrent fault Set LINE ALARM AlrL1 AlrL2 AlrL3 Start alarm status for each phase O No start since alarm ClrDly 1 Start is on OCs Combined overcurrent start status AlrL1 AlrL2 AlrL3 0 AlrL1 1 orAlrL2 1 or AlrL3 1 LxAlarm On Event enabling for AlrL1 3 Events are enabled Events are disabled Set LxAlarm Off Off Event enabling for AlrL1 3 Events are enabled Events are disabled Set OCAlarm Off On Event enabling for combined o c starts Events are enabled Events are disabled Set OCAlarmOff On Off Off Event enabling for combined o c starts Events are enabled Events are disabled Set IncFltEvnt Off Disabling several start and trip events of the same fault Several events are enabled Several events of an increasing fault is disabled Set ClrDly 0 65535 Duration for active alarm status AlrL1 Alr2 AlrL3 and OCs Set V210 EN M A011 Technical description 6 Supporting functions 6 14 Self supervision
146. ble lined The digital input is in active state when the trip circuit is complete This is applicable for dry inputs DI7 D20 only 246 V210 EN M A011 Technical description 10 Applications 10 4 Trip circuit supervision V ux 48 Vdc 240 Vdc VAMP relay Trip Circuit Failure alarm Alarm relay for trip circuit failure TCS2Dlopen Figure 10 4 2 2 Trip circuit supervision with two dry digital inputs The CB is in the open position The two digital inputs are now in series Note If for example DI13 and DI7 are used as the upper and lower digital inputs in the Figure 10 4 2 2 the usage of DI8 DI14 is limited to the same circuitry sharing the Vaux in the common terminal and the DI14 DI18 cannot be used because they share the same common terminal with DI13 V210 EN M A011 247 10 4 Trip circuit supervision 10 Applications Technical description 248 Figure 10 4 2 3 An example of digital input configuration for trip circuit supervision with two dry digital inputs DIZ and DI13 Figure 10 4 2 4 An example of logic configuration for trip circuit supervision with two dry digital inputs DIZ and DI13 Figure 10 4 2 5 An example of output matrix configuration for trip circuit supervision with two dry digital inputs V210 EN M A011 Technical description 11 Connections 11 1 Rear panel view 11 Connections 11 1 Rear panel view VO90XAA Soe NS oY peo BoD gt fe nl tl olaol Si
147. c is 22 V Per unit voltage is Upu 22 110 0 20 pu 20 Example 2 Secondary to per unit Voltage measurement mode is BLN VT 12000 110 Voltage connected to the device s input Ua is 38 1 V while Ua Up 0 Per unit voltage is Uru 38 1 0 0 V3x110 0 20 pu 20 Example 3 Per unit to secondary Voltage measurement mode is 2LL Uo Uosec 110 V This is a configuration value corresponding to Uo at full earth fault The device displays Up 20 gt Secondary voltage at input Uc is Usec 0 20x110 22 V Example 4 Per unit to secondary Voltage measurement mode is BLN VT 12000 110 The device displays Uo 20 gt If Up Ue 0 then secondary voltages at U is Usec V3x0 2x110 38 1 V 207 8 1 Output relays 8 Control functions Technical description 8 8 1 208 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 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 chapters 12 1 4 and 12 1 5 for details The contacts are SPST normal open type NO except alarm relays A1 A2 and A3 which have change over contacts S
148. ce voltage back up protection stage Uo gt for the bus may not release between consecutive faults and the Uo gt might finally do an unselective trip if the intermittent transient stage Ioint gt doesn t operate fast enough The actual operation time of the loint gt stage is very dependent on the behaviour of the fault and the intermittent time setting To make the co ordination between Uo gt and loint gt more simple the start signal of the transient stage loint gt in an outgoing feeder can be used to block the Up gt backup protection V210 EN M A011 Technical description 5 Protection functions 5 11 Intermittent transient earth fault protection IOINT gt 67NI V210 EN M A011 Co ordination with the normal directional earth fault protection based on fundamental frequency signals The intermittent transient earth fault protection stage loint gt should always be used together with the normal directional earth fault protection stages l gt lp gt gt The transient stage loint gt may in worst case detect the start of a steady earth 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 Igint gt to trip The operation time and Uo setting of the transient stage loint gt should be higher than the settings of any l gt stage to avoid any unnecessary and possible incorrect start signa
149. chapter 5 29 for more details Limitations The minimum definite time delay start latest wnen the measured value is twenty times the setting However there are limitations at high setting values due to the measurement range See chapter 5 29 for more details V210 EN M A011 Technical description 5 Protection functions 5 29 Inverse time operation 5 29 3 V210 EN M A011 Programmable inverse time curves Only with VAMPSET requires rebooting The current time curve points are programmed using VAMPSET PC program There are some rules for defining the curve points e configuration must begin from the topmost row e row 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 rows on the bottom should be filled with 1 00 0 00s Here is an example configuration of curve points Point Current I lpick up Operation delay 1 1 00 10 00s 2 2 00 6 50 s 3 5 00 4 00s 4 10 00 3 00s 5 20 00 2 00s 6 40 00 1 00s 7 1 00 0 00 s 8 1 00 0 00 s 9 1 00 0 00 s 10 1 00 0 00 s 11 1 00 0 00 s 12 1 00 0 00 s 13 1 00 0 00 s 14 1 00 0 00 s 15 1 00 0 00 s 16 1 00 0 00 s Inverse time setting error signal The inverse time setting error signal will be activated if interpolation with the given points fails See chapter 5 29 for more details Limitations The minimum
150. chnical description ROCOF protection df dt 81R Slope and delay settings 0 5 Hz s 1Hz s 1 5 Hz s 0 6 0 6 s 05s 04s ROCOF6_y3 0 8 0 5 0 7 a gt w Operation time s o gt b 0 2 Setting for minimum delay tyin 0 15 s 0 1 2 3 4 Measured slope df dt Hz s Figure 5 19 3 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 FREQUENCY ROCOF3_v3 Hz 50 0 Settings ARO df dt 0 5 Hz s Vz t 0 60s A Ly tun 0 158 N EN a SS Se i SE JME 0 00 0 15 START TRIP Figure 5 19 4 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 114 V210 EN M A011 Technical description 5 Protection functions 5 19 Rate of change of frequency ROCOF protection df dt 81R Parameters of the rate of change of frequency stage df dt gt 81R Parameter Value Unit Description Note Status Current status of the stage Blocked Start F Trip F SCnir Cumulative start counter C TCntr Cumulative trip counter C
151. 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 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 1 A This is specified in the order code of the device e Rated value of 10 CT primary current lonom e Rated value of 10 CT secondary current losec e Rated 101 input of the relay loinp 5 A or 1 A This is specified in the order code of the device e Rated value of 102 CT primary current lo2nom e Rated value of 102 CT secondary current lo2sec e Rated 102 input of the relay lo2inp 5A 1 Aor 0 2 A This is specified in the order code of the device 37 2 4 Configuration and parameter 2 Local panel user interface Operation and configuration setting instructions 38 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 earthed 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 measur
152. counter Clr TCntr Cumulative trip counter Clr SetGrp 1or2 Active setting group Set SGrpDI Digital signal to select the active setting group z None Dix Digital input Set VIX Virtual input LEDx LED indicator signal VOx Virtual output Force Off Force flag for status forcing for Set On test purposes This is a common flag for all stages and output relays too Automatically reset by a 5 minute timeout lo pu The supervised value according lo2 the parameter Input below loCalc lop gt only loPeak Iop gt only lo2Peak loRes pu Resistive part of l only when InUse Res loCap pu Capacitive part of Ip only when InUse Cap loo gt A Pick up value scaled to primary value log gt pu Pick up setting relative to the Set parameter Input and the corresponding CT value Uo gt Pick up setting for Uo Set Uo Measured Uo Curve Delay curve family DT Definite time IEC Inverse time See chapter 5 29 IEEE Set IEEE2 RI PrgN Type Delay type DT Definite time NI Inverse time See chapter 5 29 Vi Set El LTI Paramet ers 83 5 10 Directional earth fault protection l0 gt 67N 5 Protection functions Technical description 84 Parameter Value Unit Description Note t gt s Definite operation time for Set definite time only k gt Inverse delay multiplier for Set inverse time only Mode ResCap High impedance earthed nets Sector Low impedance earthed nets S
153. cted 10 signal This mode is used with unearthed networks The trip area is a half plane as drawn in Figure 5 10 2 The base angle is usually set to zero degrees e Sector This mode is used with networks earthed 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 10 3 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 gt The phase angle and Uo amplitude setting are discarded Only the amplitude of the selected lo input is supervised Input signal selection Each stage can be connected to supervise any of the following inputs and signals e Input lo for all networks other than rigidly earthed e Input loz for all networks other than rigidly earthed e Calculated signal locar for rigidly and low impedance earthed networks locale Iu ILo IL3 3lo Additionally the stage lop gt have two more input signal alternatives to measure current peaks to detect short restriking intermittent earth faults e lo1Peak to Measure the peak value of input lo1 e lo2Peak to Measure the peak value of input loz 80 V210 EN M A011 Technical description 5 Protection functions 5 10 Directional earth fault protection l0 gt 67N V210 EN M A011 Intermittent earth fault detection Sh
154. ctive power prime mover limit is just a vertical line while in impedance plane Figure 5 20 1 it is a circle touching the jX axis 117 5 20 Under impedance protection Z lt 5 Protection functions Technical description 21 When current is zero the impedance calculation gives infinite as result Thus the stage will not pick up in a machine stand still situation Two independent under impedance stages There are two separately adjustable stages available Z lt and Z lt lt 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 Parameters of the under impedance stages Z lt Z lt lt 21 Parameter Value Unit Description Note Status Current status of the stage Blocked Start F Trip F TripTime Ss Estimated time to trip SCnir Cumulative start counter Clr TCntr Cumulative trip counter Clr SetGrp 1 or2 Active setting group Set SGrpDI Digital signal to select the active setting group L None Dix Digital input Set Vix Virtual input LEDx LED indicator signal VOx Virtual output Force Off Force flag for status forcing for Set On test purposes This is a common flag for all stages and output relays too Automatically reset by a 5 minute timeout Z ohm The supervised value scaled to primary value Inf infinite Z xZn The supervis
155. d output relays too Automatically reset by a 5 minute timeout ILmax A The supervised value Max of IL1 IL2 and IL3 I gt gt gt gt gt A Pick up value scaled to primary value I gt gt I gt gt gt xIgn Pick up setting Set t gt gt t gt gt gt s Definite operation time Set For details of setting ranges see chapter 12 3 Set An editable parameter password needed C Can be cleared to zero F Editable when force flag is on Recorded values of the latest eight faults There are detailed information available of the eight latest faults Time stamp fault type fault current load current before the fault elapsed delay and setting group V210 EN M A011 Technical description 5 Protection functions 5 4 Overcurrent protection I gt 50 51 Recorded values of the overcurrent stages 8 latest faults I gt I gt gt I 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 Fit xlgn Maximum fault current Load xlgn_ 1 s average phase currents before the fault EDly Elapsed time of the operating time setting 100 trip SetGrp 1 Active setting group during fault 2 V210 EN M A011 57 5 5 Directional overcurrent protection Idi
156. dress used for sending IO messages Multicast TTL 1 100 Time to live of the IO 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 1 127 Major revision of the item the Revision Identity Object represents Minor 1 255 Minor revision of the item the Revision Identity Object represents Serial 0 4294967295 Serial number of device Number Product 32 chars Human readable identification Name Producing 1 1278 Instance number of producing Instance assembly Include On Off Include or exlude Run Idle Run Idle Header in an outgoing IO Header messages Producing Consuming 1 1278 Instance number of consuming Instance assembly Include On Off Expect presence or absence of Run Idle Run Idle Header in an incoming Header IO messages Consuming 233 9 2 Communication protocols 10 Applications Technical description 10 Applications The device comprises all the essential protection functions needed for a generator except the differential protection function Thanks to the comprehensive range of protection functions the generator protection relay can be used as the main protection for a variety of generators from small diesel power plants to large hydro power plants in the power range from 1 to 100 MW Especially versatile
157. during fault 2 Under reactance and loss of excitation protection X lt 40 Synchronous machines need some minimum level of excitation to remain stable throughout their load range If excitation is lost or is too low the machine may drop out of synchronism The loss of excitation stages X lt and X lt lt are used to supervise that the synchronous machine is working in the stable area The protection is based on positive sequence impedance as viewed from the machine terminals This impedance is calculated using the measured three phase voltages and phase currents according the following equation Ui I Z positive sequence impedance U positive sequence voltage phasor l positive sequence current phasor Z where If this impedance goes under the steady state stability limit the synchronous machine may loose its stability and drop out of synchronism Detecting power swinging A release time setting is available against prolonged power swings In a power swing situation the power phasor is swinging back and forth between capacitive and inductive power With a long enough release time setting the stage accumulates the total fault time and will eventually trip Undercurrent blocking When for some reason voltage collapses but currents remain at normal load levels the calculated impedance may fall into the trip area Inverted start signal from the most sensitive overcurrent stage can be used to block t
158. e of inverse curves with high pick up settings See chapter 5 29 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 mimic display communication logic and manually Parameters of the undirectional earth fault stage lo gt 50N 51N Parameter Value Unit Description Note Status Current status of the stage Blocked Start F Trip F TripTime s Estimated time to trip SCntr Cumulative start counter Clr TCntr Cumulative trip counter Clr SetGrp 1 or2 Active setting group Set SGrpDI Digital signal to select the active setting group k None Dix Digital input Set VIX Virtual input LEDx LED indicator signal VOx Virtual output Force Off Force flag for status forcing for Set On test purposes This is a common flag for all stages and output relays too Automatically reset by a 5 minute timeout lo pu The supervised value according lo2 the parameter Input below loCalc loPeak lo2Peak lo gt A Pick up value scaled to primary value lo gt pu Pick up setting relative to the Set parameter Input and the corresponding CT value V210 EN M A011 Technical description 5 Protection functions 5 9 Earth fault protection 10 gt V210 EN M A011 50N 51N Parameter Value Unit Description Note
159. e 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 E E E pulse TEST Test the exported energy pulse Eq E E pulse TEST Test the exported reactive energy pulse E E E pulse TEST Test the imported energy pulse Eq E E pulse TEST Test the imported reactive energy pulse IL1 I PHASE CURRENTS Phase current IL1 A IL2 I PHASE CURRENTS Phase current IL2 A IL3 I PHASE CURRENTS Phase current IL3 A ILida I PHASE CURRENTS 15 min average for IL1 A IL2da I PHASE CURRENTS 15 min average for IL2 A IL8da I PHASE CURRENTS 15 min average for IL3 A lo I SYMMETRIC Primary value of zerosequence residual CURRENTS current lo A lo2 SYMMETRIC Primary value of zero CURRENTS sequence residual current lo2 A loC I SYMMETRIC Calculated lo A CURRENTS l1 I SYMMETRIC Positive sequence current A CURRENTS 12 I SYMMETRIC Negative sequence current A CURRENTS 12 11 I SYMMETRIC Negative sequence current related to CURRENTS positive sequence current for unbalance protection THDIL I HARM DISTORTION Total harmonic distortion of the mean value of phase currents THDIL1 I HARM DISTORTION Total harmonic distortion of phase current IL1 THDIL2 I HARM DISTORTION Total harmonic distor
160. e in frequency A load drop will increase the frequency and increasing load will decrease the frequency at least for a while The frequency may oscillate after the initial change After a while the control system of the generator s will drive the frequency back to the original value However in case of a heavy short circuit fault or in case the new load exceeds the generating capacity the average frequency keeps on decreasing FREQUENCY ROCOF1_v3 Hz 50 0 Settings df dt 0 5 Hz s t 0 60s tMin 0 60 s 49 7 TRIP M Figure 5 19 1 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 V210 EN M A011 111 5 19 Rate of change of frequency 5 Protection functions Technical description ROCOF protection df dt 81R 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
161. e is OK because it is above the pick up limit This is an under voltage situation Voltage is OK This is an under voltage situation The voltage Uttmin 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 W onmo Ao TT Un max max U U Uz UunderSelfBlocking dead band ea ea sl ag PEREIRAS A fea PERR U lt setting block limit time U lt under voltage state Figure 5 15 1 Under voltage state and block limit Three independent stages There are three separately adjustable stages U lt U lt lt and U 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 100 V210 EN M A011 Technical description 5 Protection functions 5 15 Undervoltage protection U lt 27 Parameters of the under voltage stages U lt U lt lt U lt lt lt 27 Parameter Value Unit Description Note Status Current status of the stage Blocked Start F Trip F SCnir Cumulative start counter C TCntr Cumulative trip counter C SetGrp 1 or2 Active setting group Set Digital sig
162. e 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 9 1 Each time the energy level reaches the pulse size an output relay is activated and it will stay active as long as defined by a pulse duration setting Configurable 100 ms 5 000 ms lt M Configurable 10 10 000 kWh kvarh Figure 6 9 1 Principle of energy pulses The device has four energy pulse outputs The channels are Active exported energy Reactive exported energy Active imported energy 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 Energy pulse output parameters Parameter Value Unit Description E PULSE SIZES 10 10 000 kWh Pulse size of active exported energy 10 10 000 kvarh Pulse size of reactive exported energy 10 10 000 kWh Pulse size of active imported energy 10 10 000 kvarh Pulse size of reactive imported energy E PULSE DURATION 100 5000 ms Pulse length of active exported energy 100 5000 ms Pulse length of reactive exported energy 100 5000 ms Pulse length of active imported energy Eq 100 5000
163. e restrained or voltage controlled overcurrent function 46 l gt Current unbalance protection 49 T gt Thermal overload protection 50N 51N l gt lo gt gt lo gt gt gt Ip gt gt gt gt Earth fault protection 67N Iog gt s Tog gt gt Directional earth fault protection 67NT lor Intermittent transient earth fault protection 59 U gt U gt gt U gt gt gt Overvoltage protection 27 U lt U lt lt U lt lt lt Undervoltage protection 24 U f gt Volts hertz overexcitation protection 27P Ui lt Ui lt lt Positive sequence undervoltage protection 59N Uo gt Uo gt gt Residual voltage protection 64F3 Uot3 lt 100 stator earth fault protection 81H 81L f gt lt f gt gt lt lt Overfrequency and underfrequency protection 81L f lt f lt lt Under frequency protection 81R df dt gt Rate of change of frequency ROCOF protection 21 Z lt Z lt lt Underimpedance protection 40 Q lt Underexcitation protection 21 40 X lt X lt lt Underreactance protection Loss of excitation 32 P lt P lt lt Reverse and underpower protection 51F2 l gt Second harmonic O C stage 51F5 lis gt Fifth harmonic O C stage 50BF CBFP Circuit breaker failure protection 99 Prg1 8 Programmable stages V210 EN M A011 Operation and configuration 1 General 1 2 User interface IEEE IEC symbol Function name ANSI code 50ARC Arcl gt Optional arc fault protection 50NARC Arclo gt Arclos gt Further the rela
164. e voltage 5 Protection functions Technical description protection U0 gt 59N Parameters of the residual overvoltage stages Uo gt Uo gt gt 59N 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 SGrpDI Digital signal to select the active Set setting group None Dix Digital input VIX Virtual input LEDx LED indicator signal VOx Virtual output Force Off Force flag for status forcing for Set On test purposes This is a common flag for all stages and output relays too Automatically reset by a 5 minute timeout Uo The supervised value relative to Un V3 Uo gt Uo gt gt Pick up value relative to Un V3 Set t gt t gt gt s Definite operation time Set For details of setting ranges see chapter 12 3 Set An editable parameter password needed C Can be cleared to zero F Editable when force flag is on Recorded 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 Recorded values of the residual overvoltage stages Uo gt Uo gt gt 59N Parameter Value Unit Description yyyy mm dd Time stamp of the recording date hh mm ss ms Time stamp time of day Fit Fault voltage relative to
165. each stage Switching between setting groups can be controlled by digital inputs virtual inputs mimic display communication logic and manually l0fiisblock Setting Tcosp Res Ip gt s Ising Cap Figure 5 10 1 Block diagram of the directional earth fault stages lo gt and Iyp gt gt 81 5 10 Directional earth fault 5 Protection functions Technical description protection l0 gt 67N loDir_ResCap Figure 5 10 2 Operation characteristic of the directional earth fault protection in Res or Cap mode Res mode can be used with compensated networks and Cap mode is used with ungrounded networks 90 90 Angle offset 15 55 Angle offset 32 Sector 70 Sector 120 TRIP AREA E gt TRIP AREA 88 loDir_SectorAdj Figure 5 10 3 Two examples of operation characteristics of the directional earth fault stages in sector mode The drawn Ip phasor in both figures is inside the trip area The angle offset and half sector size are user s parameters 82 V210 EN M A011 Technical description 5 Protection functions 5 10 Directional earth fault protection l0 gt 67N V210 EN M A011 Parameters of the directional earth fault stages lop gt lop gt gt 67N Parameter Value Unit Description Note Status Current status of the stage Blocked Start F Trip F TripTime s Estimated time to trip SCntr Cumulative start
166. echnical data Technical description Earth fault stage Ip gt 50N 51N Input signal lo input X1 7 amp 8 loz input X1 9 amp 10 locaic ILitlLotlis Setting range lo gt 0 005 8 00 When loor lo2 0 05 20 0 When locaic Definite time function DT Operating time 0 08 300 00 s step 0 02 s IDMT function Delay curve family DT IEC IEEE RI Prg Curve type EI 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 60 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 30 ms Operating time at IDMT function 5 or at least 30 ms El Extremely Inverse NI Normal Inverse VI Very Inverse LTI Long Time Inverse Ml Moderately Inverse The measuring range may limit the scope of inverse delays See chapter 5 29 for details Earth fault stages Io gt gt lo2 gt lo2 gt gt 50N 51N Input signal lo input X1 7 amp 8 lo2 input X1 9 amp 10 locatc ILitlLo lis Setting range lo gt gt 0 01 8 00 When Ip or loo 0 05 20 0 When locaic Definite time function Operating time 0 08 300 00 s step 0 02 s Start time Typically
167. ed value scaled to per unit pu 1 pu 1xZ Ugn V3xlgn Inf infinite Z lt ohm Pick up value scaled to primary Z lt lt value Z lt xZn Pick up setting in per unit pu Set Z lt lt 1 pu 1XZ_ Ugn V3Xlgn t lt s Definite operation time Set U1 V Measured value of positive sequence voltage U4 l1 A Measured value of positive sequence current For details of setting ranges see chapter 12 3 Set An editable value password needed C Can be cleared to zero F Editable when force flag is on 118 V210 EN M A011 Technical description 5 Protection functions 5 21 Under excitation protection Q lt 4 0 21 V210 EN M A011 Recorded values of the latest eight faults There are detailed information available of the eight latest earth faults Time stamp fault impedance elapsed delay and setting group Recorded values of the under impedance stages Z lt Z lt lt 21 Parameter Value Unit Description yyyy mm dd Time stamp of the recording date hh mm ss ms Time stamp time of day Flt Zn Minimum fault impedance EDly Elapsed time of the operating time setting 100 trip SetGrp 1 Active setting group during fault 2 Under excitation protection Q lt 40 Synchronous machines need some minimum level of excitation to remain stable throughout their load range If excitation is too low the machine may drop out of
168. eeeeeeeeeeeeees 116 5 21 Under excitation protection Q lt 40 eeeeeeeeeeeeeee 119 5 22 Under reactance and loss of excitation protection X lt 40 122 5 23 Reverse power and under power protection P lt 32 126 5 24 Second harmonic O C stage je gt 51F 2 n se 130 5 25 Fifth harmonic O C stage lis gt 51F5 ceeeeeeeeteeeeees 131 5 26 Circuit breaker failure protection CBFP 50BPF 132 5 27 Programmable stages 99 cccceeceeeeessseeeeeeeeeeeeeeeeee 134 5 28 Arc fault protection 50ARC 50NARC optional 137 5 29 Inverse time Operation ccccceeeeeeeeeseeeeeeeeeeeeeeeeeees 140 5 29 1 Standard inverse delays IEC IEEE IEEE2 RI 142 5 29 2 Free parametrisation using IEC IEEE and IEEE2 COAL OINS vies vcs ireid anan ied edd anda teed aeaaaee inc aeeu le ined in ied ined 152 5 29 3 Programmable inverse time CurveS 000 153 6 Supporting functions iiiiiiciisiiisciiecuscdcincrcntnarewenccdsndincanateatve 154 Galle Event NOG as capes cds ara i a Omticenstecncnide 154 6 2 Disturbance reCordet cccceeeeeeeeeeeeeeeeeeeeeeeeeeeeeees 156 6 3 Cold load pick up and inrush current detection 161 6 4 Voltage sags and SWellS cccceeeeeeeseeeeeeeeeeeeeeeeeeees 164 6 5 Voltage interruptions ccceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee 166 6 6 Current transformer SUperVISION eeeeeeeeeee
169. eeeeeees 168 6 7 Voltage transformer supervision cceeeeeeeeeeeeees 169 6 8 Circuit breaker condition mMonitoring cccceeeeeee 170 6 9 Energy pulse outputs cccceeeeeeeeeeeeeeeeeeeeeeeeeeeeeees 175 6 10 System clock and synchronization ccceeeeeeeeeees 178 6 11 Running hour COUNTEL cceeeeeeeeeeeeeeeeteeeeeeeeeeeeteees 181 G T2 METS aea r eee 182 6 13 Combined overcurrent Status eeeeeeeeeeeeeeeeeeeeeeeeeees 184 6 14 Self SUPEIVISION 00 eeeeeeeeeeeeeeeeeeeee eee eeeeeeeeeeeeeeeeeeeeeeeeees 186 V210 EN M A011 Table of Contents V210 EN M A011 7 Measurement functions ccceceeeeeeeeeeeeeeeeeeeeeeeeeeeeeneeeeeees 187 7 1 Measurement accuracy ccccceeeeeeeeeeeeteeeeeeeeeeeteeeeeaeees 188 7 2 Harmonics and Total Harmonic Distortion THD 189 7 3 Demand vale Serinin 190 7 4 Minimum and maximum Values cccccccccccceeeeeeeeeeees 191 7 5 Maximum values of the last 31 days and twelve months192 7 6 Voltage measurement Mode ccceeeeeeeeeeeeeeeeeees 193 7 7 Power calculation aire ce ernncesnencee atl eneee 195 7 8 Direction of power and CUITeNnt ccccccccceeeeeeeeeeeeeeees 197 7 9 Symmetric COMPONEINS tce a ctrecteistecetsoeteteliueteiettntes 198 7 10 Primary secondary and per unit scaling 0000 202 ZOO GUN CNESCANING 22 2 Mec hs areca rtdechusdiven tena 202
170. egardless of the measurement mode NOTE When the 100 stator earth fault stage U0f3 lt is to be used the mode 2LL Uo must be used and the zero sequence voltage must be measured from the generator s neutral point as in Error Reference source not found L1 L2 L3 2Line Uo 2Line_Uo_1 15 Figure 7 6 1 The device is connected to line to line voltages from V connected open delta voltage transformers The zero sequence voltage is measured with a voltage transformer between neutral point and ground Voltage measurement mode is set to 2LL U 193 7 6 Voltage measurement mode 7 Measurement functions Technical description L1 L2 L3 2Line Uo 2Line_Uo_2 15 Figure 7 6 2 The device is connected to line to line voltages from three Y connected voltage transformers The zero sequence voltage is measured with VT tertiaries in a broken delta connection Voltage measurement mode is set to 2LL Up LI L2 L3 3Phase VAMP 210 3Phase 15 Figure 7 6 3 The device is connected to phase to ground voltages from three Y connected voltage transformers The zero sequence is calculated internally Voltage measurement mode is set to 3LN 194 V210 EN M A011 Technical description 7 Measurement functions 7 7 Power calculation 7 7 Power calculation The power calculation in VAMP relays are dependent on the voltage measurement mode see chapter 7 6 The equations used for power calculations are described in this c
171. elay U gt stage only Set Hyster 3 Dead band size i e hysteresis Set default For details of setting ranges see chapter 12 3 Set An editable parameter password needed C Can be cleared to zero F Editable when force flag is on Recorded 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 Recorded values of the overvoltage stages 8 latest faults U gt U gt gt U gt gt gt 59 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 92 V210 EN M A011 Technical description 5 Protection functions 5 13 Volts hertz over excitation protection Uf gt 24 5 13 Volts hertz over excitation protection Ur 24 The saturation of any inductive network components like transformers inductors motors and generators depend on the voltage and frequency The lower the frequency the lower is the voltage at which the saturation begins The volts hertz over excitation protection stage is sensitive to the voltage frequency ratio instead of voltage only Figure 5 13 1 shows the difference between volts hertz and a standard overvoltage function The maximum of the t
172. elay tybe Parameter y YP 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 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 148 V210 EN M A011 Technical description 5 Protection functions 5 29 Inverse time operation Example for Delay type Moderately inverse Ml k 0 50 4pu Ipickup 2pu A 0 1735 B 0 6791 C 0 8 D 0 08 E 0 127 0 6791 0 08 0 127 4 4 2 4 3 6 08 0 8 0 8 2 2 2 The operation time in this example will be 0 38 seconds The same result can be read from Figure 5 29 1 11 M IEEE2 MI 400 t 0 5 0 1735 0 38 ei IEEE2 NI 400 200 200 100 80 60 40 100 80 20 delay s delay s 0 2 0 1 0 08 0 08 k 0 5 0 06 0 06 T 2 3 4 5678 10 20 1 2 3 4 5678 10 20 TIset inverse DelayIEEE2_MI Tset inverse DelayIEEE2_NI Figure 5 29 1 11 IEEE2 moderately Figure 5 29 1 12 IEEE2 normal inverse inverse delay delay V210 EN M A011 149 5 29 Inverse time operation 5 Protection functions Technical description 150 ie IEEE2 VI 400 100 60 40 N 3 0 8 Ta 2 6 4 2 g 2 k 20 1 k 10 0 8 0 6 k 5 0 4 0 2 2 0 1 0 08 0 06 k 0 5 1 2 3 4 5678 10 20 set inverse DelayIEEE2_VI Figure 5 29 1 13 IEEE2 very inverse delay a IEEE2 EI 400 200 100 delay s k 20 06 k 10 k 5
173. ement accuracy The rated CT secondary may also be less than the rated input but the measurement accuracy near zero current will decrease VOLTAGE SCALING Rated VT primary voltage Uprim Rated VT secondary voltage Usec Rated UO VT secondary voltage Uosec Voltage measuring mode Umode GENERATOR SETTING Rated voltage of the generator or motor Ugn e Rated power of the generator or motor Sgn e Rated shaft power of the prime mover Pm If this value is not known set it equal to Sgn The reverse power and underpower stages do use this value as reference for 1 00 per unit e Rated current of the generator calculated by the device Ign e Rated impedance of the generator or motor calculated by the device Zgn e Existence of any unit transformer between VTs and CTs Trafo In case the VTs are on the bus side of the transformer and CTs are on the generator side this parameter is set equal to On The generator may have a unit transformer but if the VTs and CTs are on the same side of this transformer this parameter is set equal to Off e Connection group of the unit transformer if any IEC marking with capital letters Y and D for bus side and small case letters y and d for generator side combined with the dial hour is used For example Yd11 means a wye delta transformer where the delta side phase to ground voltages are leading 30 the wye side phase to ground voltages e Rated busbar side voltage of the unit transfo
174. ends of the communication letter in the order code See Figure 9 1 1 chapter 11 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 Parameters Parameter Value Unit Description Note Protocol Protocol selection for Set remote port None SPA bus SPA bus slave ProfibusDP Profibus DB slave ModbusSla Modbus RTU slave ModbusTCPs Modbus TCP slave IEC 103 IEC 60870 5 103 slave ExternallO Modbus RTU master for external I O modules DNP3 DNP 3 0 Msg 0 29 1 Message counter since the Clr device has restarted or since last clearing Errors 0 2 81 Protocol errors since the Cir device has restarted or since last clearing Tout 0 2 81 Timeout errors since the Cir device has restarted or since last clearing Display of current 1 communication parameters speed bit s speed DPS 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 219 9 1 Communication ports 9 Communication Technical description 9 1
175. ent Nominal power of the prime mover Used by reverse under power protection See VT Per unit Depending of the context the per unit refers to any nominal value For example for overcurrent setting 1 pu 1Xlen Reactive power Unit var acc IEC Root mean square Apparent power Unit VA Nominal power of the protected device Simple Network Time Protocol for LAN and WWW Trip circuit supervision Total harmonic distortion Voltage at input U at zero ohm earth fault Used in voltage measurement mode 2LL Uo Voltage input for U42 or U_ depending of the voltage measurement mode Voltage input for U23 or UL2 depending of the voltage measurement mode Voltage input for Us or Uo depending of the voltage measurement mode Nominal voltage of the protected device Nominal voltage Rating of VT primary or secondary Coordinated Universal Time used to be called GMT Greenwich Mean Time Voltage transformer i e potential transformer PT Nominal primary value of voltage transformer Nominal secondary value of voltage transformer World wide web internet 287 14 Construction Operation and configuration instructions 14 Construction PANEL MOUNTING VAMP 200 SERIES 190 7 48 mm SEMI FLUSH VAMP 200 SERIES _Raising trame A Ta o Fixngbracket VYX076 40mm 1 57in 69mm 6 65in Standard for 200 series 5 20 VYX077 60mm 2 36in 149mm 5 87In Standard for 200 serles 0 79 VYX233 100 mm 3 94in 109mm 4
176. ent lo1 S1 7 EY 9 lo2 S1 Residual current lo2 S1 9 g 11 Ua a Line to line voltage U12 a or phase to neutral voltage UL1 a 11 13 Ub a Line to line voltage U23 a or phase to neutral voltage UL2 a ii ey ite t 35 g 17 Uc dn n Zero sequence voltage Uo dn or phase to neutral voltage UL3 b 19 17 B 19 amp o Terminal X1 right side No Symbol Description 2 IL1 S2 Phase current L1 S2 G 2 f4 IL2 S2 Phase current L2 S2 E 41 6 IL3 S2 Phase current L3 S2 S 6 8 lo1 S2 Residual current lo1 S2 E 8 10 lo2 S2 Residual current lo2 S2 10112 Ua b n Line to line voltage U12 b or phase to neutral voltage UL1 n 42 14 Ub b n Line to line voltage U23 b or phase to neutral voltage UL2 n Q Ilr te t Q i 18 Uc da a Zero sequence voltage Uo da or phase to neutral voltage UL3 a f 20 RI 18 A 20 250 V210 EN M A011 Technical description 11 Connections 11 1 Rear panel view Terminal X2 without the analogue output No Symbol Description 1l S J ics i all 2l a ail ees 2 4l 4 I E 5 5 A5 Alarm relay 5 6 6 A5 Alarm relay 5 7 S 7 A4 Alarm relay 4 8 8 A4 Alarm relay 4 all ee ale a 10 Ze 10 A3 COM Alarm rel
177. er and under power stages P lt P lt lt 32 Pick up setting range 200 0 200 0 Pm Definite time function Operating time 0 3 300 0 s Start time Typically 200 ms Reset time lt 500 ms Reset ratio 1 05 Inaccuracy Starting 3 of set value or 0 5 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 drops below 5 of rated 12 3 5 Second harmonic function 2 Harmonic stage 51F2 Settings Setting range 2 Harmonic 10 100 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 2 of the nominal of CT If the moninal current is 5 A the 100 Hz component needs to exceed 100 mA 12 3 6 Fifth harmonic function 5 Harmonic stage Ij5 gt 51F5 Settings Setting range 2 Harmonic 10 100 Operating time 0 05 300 00 s step 0 01 s Inaccuracy Starting 2 unit NOTE The amplitude of second harmonic content has to be at least 2 of the nominal of CT If the moninal current is 5 A the 250 Hz component needs to exceed 100 mA 282 V210 EN M A011 Technical description 12 Technical data 12 3 Protection functions 12 3 7 12 3 8 V210 EN M A011 Circuit breaker failure protection Circuit breaker
178. et Undir Undirectional mode Offset o Angle offset for RecCap and Set Sector modes ChCtrl Res Cap control in mode ResCap Res Fixed to Resistive characteristic Set Cap Fixed to Capacitive DI1 6 characteristic VIH 4 Controlled by digital input Controlled by virtual input InUse Selected submode in mode ResCap 2 Mode is not ResCap Res Submode resistive Cap Submode capacitive Input lot X1 7 amp 8 See chapter 11 lo2 X1 9 amp 10 loCalc IL1 IL2 IL3 Set lo1 Peak X1 7 amp 8 peak mode log gt only lo2Peak X1 9 amp 10 peak mode Ig gt only Intrmt s Intermittent time Set Dly20x s Delay at 20xlset Dly4x S Delay at 4xlset Dly2x s Delay at 2xlset Dly1x s Delay at 1xlset A B C D User s constants for standard Set E equations Type Parameters See chapter 5 29 For details of setting ranges see chapter 12 3 Set An editable parameter password needed C Can be cleared to zero F Editable when force flag is on Recorded values of the latest eight faults There is detailed information available of the eight latest earth faults Time stamp fault current elapsed delay and setting group V210 EN M A011 Technical description 5 Protection functions 5 11 Intermittent transient earth fault protection IOINT gt 67NI 5 11 V210 EN M A011 Recorded values of the directional earth fault stages 8 latest faults lo gt lop gt gt 67N Parameter Value Unit Descrip
179. et inverseDelayIEEE1_STEI Figure 5 29 1 10 ANSI IEEE short time extremely inverse delay 147 5 29 Inverse time operation 5 Protection functions Technical description IEEE2 inverse time operation Before the year 1996 and ANSI standard C37 112 microprocessor relays were using equations approximating the behaviour of various induction disc type relays A quite popular approximation is Equation 5 29 1 3 which in the device 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 29 1 4 The old electromechanical induction disc relays have inverse delay for both trip and release operations However in the device 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 29 1 3 Actually this equation can only be used to draw graphs or when the measured value is constant during the fault A modified version is implemented in the relay for real time usage Equation 5 29 1 3 B D E t k A z i I I I Aa c C C pickup Tiii Tiii A t Operation delay in seconds k Users multiplier Measured value lpickup User s pick up setting A B C D Constant parameter according Table 5 29 1 4 Table 5 29 1 4 Constants for IEEE2 inverse delay equation D
180. et of 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 chapter 2 2 3 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 e 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 V210 EN M A011 Operation and configuration 2 Local panel user interface 2 2 Local panel operations V210 EN M A011 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 chapter 2 3 4 Second menu of I gt gt 50 51 stage second menu AV lt gt gt gt SET 50 51 Stage setting group 1 ExDI ILmax 403A ExDO Status Prot I gt gt 1013A gt gt 2 50xlgn t gt gt 0 60s Figure 2 2 2 2 Second menu next on the right of l gt gt 50 51 stage This is the main setting menu The content is e Stage setting group 1 These are the group 1 setting values The other setting group can be seen by pressing push and then or lt Setting groups are explained in chapter 2 2 3 e ILmax 403A The maximum of the three measured phase curre
181. etting must be below this minimum value A typical operation delay is one minute Blocking the protection The squelch of voltage measurement will block the stage when the generator is stopped Using the block matrix blocking by under voltage under power CB position and other blocking schemes are possible 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 V210 EN M A011 107 5 17 100 stator earth fault 5 Protection functions Technical description protection U0f3 lt 64F3 Parameters of the 100 stator earth fault stage Upois lt 64F3 Parameter Value Unit Description Note Status Current status of the stage Blocked Start F Trip F SCnir Cumulative start counter C TCntr Cumulative trip counter C SetGrp 1or2 Active setting group Set SGrpDI Digital signal to select the active Set setting group i None Dix Digital input Vix Virtual input LEDx LED indicator signal vox Virtual output Force Off Force flag for status forcing for Set On test purposes This is a common flag for all stages and output relays too Automatically reset by a 5 minute timeout Uof8 The supervised value relative to Uon For Uon see chapter 7 2 Uof8 lt Pick up value relative to Uon Set For Uon see chapter 7 2 t lt min Definite operation time in Set minutes
182. exported power is 50 MW Pulse size is 10 kWh The average pulse frequency will be 1900 10 190 pulses h The peak pulse frequency will be 50000 10 5000 pulses h Set pulse length to 3600 5000 0 2 0 5 s or less The lifetime of the mechanical output relay will be 50x10 190 h 30 a V210 EN M A011 Technical description 6 Supporting functions 6 9 Energy pulse outputs VAMP 210 Active exported 4 energy pulses Reactive exported energy pulses Active imported _ energy pulses Reactive imported _ energy pulses Figure 6 9 2 Application example of wiring the energy pulse outputs to a PLC q q PLC Pulse counter input 1 Pulse counter input 2 Pulse counter input 3 Pulse counter input 4 e pulseconfl having common plus and using an external wetting voltage VAMP 210 Active exported 4 energy pulses Reactive exported 4 energy pulses Active imported p energy pulses Reactive imported _ energy pulses Figure 6 9 3 Application example of wiring the energy pulse outputs to a PLC having common minus and using an external wetting voltage VAMP 210 Active exported energy pulses Reactive exported energy pulses Active imported _ energy pulses Reactive imported E energy pulses Figure 6 9 4 Application example of wiring the energy pulse outputs to a PLC q q q q
183. face 2 2 Local panel operations 2 2 2 2 1 V210 EN M A011 Local panel operations 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 one of the local communication ports Some parameters are factory set Navigating in menus All the menu functions are based on the main menu submenu structure 1 Use the arrow keys and to move up and down in the main menu 2 To move to a submenu repeatedly push until the required submenu is shown Correspondingly push to return to the main menu 3 Push to confirm the selected submenu If there are more than six items in the selected submenu a black line appears to the right side of the display Figure 2 2 1 1 It is then possible to scroll down in the submenu 4 Push to cancel a selection 5 Pushing the or key in any position of a sub menu when it is not selected brings you directly one step up or down in the main menu The active main menu selection is indicated with black back ground color The possible navigating directions in the menu are shown in the upper left corner by means of black triangular symbols scroll ENABLED STAGES 3 U gt On U gt gt On U gt gt gt On U lt Off U lt lt Off U lt lt lt Off Figure 2 2 1 1 Example of scroll indication 15 2 2 Local pa
184. failure protection CBFP 50BF Relay to be supervised T1 or T2 Definite time function Operating time 0 1 10 0 s step 0 1 s Reset time lt 95 ms Inaccuracy Operating time 20 ms This setting is used by CB condition monitoring function too Arc fault protection stages option Arc protection stage Arcl gt 50ARC option Setting range Arc sensor connection Operating time Light only Operating time 4xlset light Operating time BIN Operating time Delayed Arc L gt BO operating time Reset time Reset time Delayed ARC L Reset time BO Reset ratio Inaccuracy Starting Operating time Delayed ARC light 0 5 10 0 x In 1 S2 S1 S2 BI S1 Bl S2 Bl S1 S2 BI 13 ms 17ms 10 ms 0 01 0 15s lt 3 ms lt 95 ms lt 120 ms lt 85 ms 0 90 10 of the set value 5 ms 10 ms Arc protection stage Arclo gt 50NARC option Setting range Arc sensor connection Operating time Light only Operating time 4xlset light Operating time BIN Operating time Delayed Arc L gt BO operating time Reset time Reset time Delayed ARC L Reset time BO Reset ratio Inaccuracy Starting Operating time Delayed ARC light 0 5 10 0 x In 1 S2 S1 S2 BI S1 Bl S2 Bl S 1 S2 BI 13 ms 17ms 10 ms 0 01 0 15s lt 3 ms lt 95 ms lt 120 ms lt 85 ms 0 90 10 of the set value 5
185. g 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 chapter 5 29 3 V210 EN M A011 Technical description 5 Protection functions 5 29 Inverse time operation V210 EN M A011 Local panel graph The relay 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 20xlser 4xlse7 and 2xlser are shown Inverse time setting error signal If there are any errors in the inverse delay configuration 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 and then curve family is changed to IEEE the setting error will active 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 errors in formula parameters A E and the device is not able to build the delay curve 3 T
186. g a digit in a numerical lt A gt oN value 5 Additional information key O NOTE The term which is used for the buttons in this manual is inside the brackets V210 EN M A011 Operation and configuration 2 Local panel user interface 2 1 Relay front panel 2 1 4 V210 EN M A011 Operation Indicators The relay is provided with eight LED indicators CO Power C Error Com Alarm Trip OA B DE Figure 2 1 4 1 Operation indicators of the relay LED indicator Meaning Measure Remarks Power LED lit The auxiliary power has Normal operation state been switched on Error LED lit Internal fault operates in The relay attempts to parallel with the self reboot REBOOT If the supervision output relay error LED remains lit call for maintenance Com LED lit or The serial bus is in use and Normal operation state flashing transferring information Alarm LED lit One or several signals of The LED is switched off the output relay matrix have when the signal that been assigned to output LA caused output Al to and the output has been activate e g the START activated by one of the signal is reset The signals For more resetting depends on the information about output type of configuration matrix please see chapter connected or latched 2 4 5 Trip LED lit One or several signals of The LED is switched off the output relay matrix have when t
187. g 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 V210 EN M A011 Technical description 6 Supporting functions 6 12 Timers V210 EN M A011 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 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 183 6 13 Com
188. g functions Technical description 6 14 186 Self supervision The functions of the micro controller 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 a fault situation If the restarting fails the watchdog issues a self supervision alarm indicating a permanent internal fault When the watchdog circuit detects a permanent fault 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 relay disappear an alarm is automatically given because the internal fault IF output relay functions on a working current principle This means that the IF relay is energized when the auxiliary supply is on and no internal fault is detected V210 EN M A011 Technical description 7 Measurement functions 6 14 Self supervision 7 Measurement functions All the direct measurements are based on fundamental frequency values The exceptions are frequency and instantaneous current for arc protection The figure shows a current waveform and the corresponding fundamental frequency component second harmonic and rms value in a special case when the current deviates significantly from a pure sine wave es L oad 0 100 i i i
189. g in the same X4 connector NOTE 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 1 Protocol for the local port The front panel port is always using the command line protocol for VAMPSET regardless 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 will show the active parameter values for the local port Physical interface The physical interface of this port is RS 232 V210 EN M A011 217 9 1 Communication ports 9 Communication Technical description Parameters Parameter Value Unit Description Note Protocol Protocol selection for the Set rear panel local port None Command line interface for VAMPSET SpaBus SPA bus slave ProfibusDP Profibus DB slave ModbusSla M
190. ge transformer VT voltage V3 e LL Uo The zero sequence voltage is measured with voltage transformer s for example using a broken delta connection The setting values are relative to the VTo secondary voltage defined in configuration NOTE The Up signal must be connected according the connection diagram Figure 10 2 1 in order to get a correct polarization Please note that actually the negative Uo Up is connected to the relay V210 EN M A011 79 5 10 Directional earth fault 5 Protection functions Technical description protection l0 gt 67N 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 o Res The stage is sensitive to the resistive component of the selected lo signal This mode is used with compensated networks resonant grounding and networks earthed with a high resistance Compensation is usually done with a Petersen coil between the neutral point of the main transformer and earth 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 10 2 The base angle is usually set to zero degrees o Cap The stage is sensitive to the capacitive component of the sele
191. gic 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 on our website 230 V210 EN M A011 Technical description 9 Communication 9 2 Communication protocols V210 EN M A011 IEC 61850 main config parameters Parameter Value Unit Description Set Port 0 64000 IP protocol port Set Check Yes No If the checkbox Check Set upper upper addresses is addresses checked the below parameters are also checked and used for addressing when the client is communicating to the device by default this is disabled The below parameters are ACSE association parameters described in the standard part 61850 8 1 AP ID nnn nnn nann nnn ACSE AP title value Set AE 0 64000 ACSE AE qualifier Qualifier P Selector 0 4200000000 Presentation selector S Selector 0 64000 Session selector T Selector 0 64000 Transport selector IED Name String Identifcation of the device Each device must have unique name Delete command Send command to clear dynamic all dynamic datasets datasets 231 9 2 Communication protocols 9 Communication Technical description 9 2 10 232 EtherNet IP The relay supports communication using EtherNet IP protocol which is a part of CIP Common Industrial Protocol family EtherNet IP pr
192. gt U gt gt gt Definite time characteristic operating time U gt U gt gt operating time U gt gt gt Starting time Resetting time U gt Resetting time U gt gt U gt gt gt Retardation time Reset ratio Inaccuracy starting operate time 50 150 Un 50 160 Un 0 08 300 00 s step 0 02 0 06 300 00 s step 0 02 Typically 60 ms 0 06 300 00 s step 0 02 lt 95 ms lt 50 ms 0 99 0 800 0 1 20 0 step 0 1 3 of the set value 1 or 30 ms 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 measurement range is up to 175 V This limits the maximum usable setting when rated VT secondary is more than 100 V Volts hertz over excitation protection U gt 24 Operating time at definite time function Pick up setting range 100 200 Operating time 0 3 300 0 s Start time Typically 200 ms Reset time lt 450 ms Reset ratio 0 995 Inaccuracy Starting U lt 0 5 unit f lt 0 05 Hz 1 or 150 ms Positive sequence undervoltage stages U lt U lt lt 27P Setting range 20 120 x Uan Definite time function Operating time 0 08 300 00 s Undervoltage blocking Blocking time when I lt 1 x Ign 2 100 x Uen common for both stages 0 30s common for both st
193. hapter The relay is connected to line to line voltages When the relay is connected to line to line voltages the voltage measurement mode is set to equal to 2LL Uo The following Aron equation is used for power calculation S U Thy U33 Ty where Three phase power phasor Measured voltage phasor corresponding the fundamental frequency voltage between phases L1 and L2 I Complex conjugate of the measured phase L1 fundamental frequency current phasor U Measured voltage phasor corresponding the fundamental frequency voltage between phases L2 and L3 I Complex conjugate of the measured phase L3 fundamental frequency current phasor Q l Apparent power active power and reactive power are calculated as follows s s P real S Q imag S COs oe f S V210 EN M A011 195 7 7 Power calculation 7 Measurement functions Technical description 196 The relay is connected to line to neutral voltage When the relay is connected to line to neutral voltages the voltage measurement mode is set to equal to 3LN The following equation is used for power calculation S U nla U lia U Iis where 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 Measured voltage phasor corresponding the fundamental frequency voltage of phase L2 Complex conj
194. he Set 10 characters local display Default is DIn n 1 6 Description String of max Long name for Dls Default Set 32 characters is Digital input n n 1 6 Set An editable parameter password needed 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 Parameters of virtual inputs Parameter Value Unit Description Set Vit VI4 0 Status of virtual input 1 Events On Event enabling Set Off NAMES for VIRTUAL INPUTS editable with VAMPSET only Label String of max Short name for VIs on the Set 10 characters local display Default is VIn n 1 4 Description String of max Long name for Vis Default Set 32 characters is Virtual input n n 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 V210 EN M A011 Technical description 8 Control functions 8 4 Output matrix 8 4 V210 EN M A011 Output matrix By means of the output matrix the output signa
195. he VAMPSET program can communicate using the local RS 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 interface configuration see chapter 9 1 4 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 fibre RS 232 VAMPSET will show the list of all available data items for Modbus A separate document Modbus parameters pdf is also available The Modbus communication is activated usually for remote port via a menu selection with parameter Protocol See chapter 9 1 For ethernet interface configuration see chapter 9 1 4 Parameters Parameter Value Unit Description Note Addr 1 247 Modbus address for the Set device Broadcast address 0 can be used for clock synchronizing Modbus TCP uses also the TCP port settings bit s 1200 bps Communication speed for Set 2400 Modbus RTU 4800 9600 19200 Parity None Parity for Modbus RTU Set Even Odd Set An editable parameter password needed V210 EN M A011 Technical description 9 Communication 9 2 Communication protocols 9 2 3 Profibus DP The Profibus DP protocol is widely used in ind
196. he operation delay counter is not cleared between adjacent faults and finally the stage will trip Four or six independent undirectional earth fault overcurrent stages There are four separately adjustable earth fault stages lo gt lo gt gt Ip gt gt gt and lo gt gt gt gt The first stage lo gt 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 earth fault stages chapter 5 10 in undirectional mode two more stages with inverse operation time delay are available for undirectional earth fault protection 75 5 9 Earth fault protection 10 gt 50N 51N 5 Protection functions Technical description 76 Inverse operation time Ip 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 will be the operation Accomplished inverse delays are available for the Io gt stage The inverse delay types are described in chapter 5 29 The relay will show a scaleable graph of the configured delay on the local panel display Inverse time limitation The maximum measured secondary residual current is 10xloy and maximum measured phase current is 50xIn This limits the scop
197. he signal that been assigned to output Tr caused output Tr to and the output has been activate e g the TRIP activated by one of the signal is reset The signals For more resetting depends on the information about output type of configuration relay configuration please connected or latched see chapter 2 4 5 A C LED lit Application related status Configurable indicators 13 2 1 Relay front panel 2 Local panel user interface Operation and configuration instructions Resetting latched indicators and output relays 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 a for approx 3 s Then reset the latched indicators and output relays by pushing ox 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 SK The latched indicators and relays can also be reset via a remote communication bus or via a digital input configured for that purpose 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 see chapter 3 V210 EN M A011 Operation and configuration 2 Local panel user inter
198. he under reactance stages during abnormal voltages not caused be short circuit faults Characteristic on an impedance plane The characteristics on an impedance plane is a circle covering the unstable area of the synchronous machine Figure 5 22 1 The V210 EN M A011 Technical description 5 Protection functions 5 22 Under reactance and loss of excitation protection X lt 40 V210 EN M A011 radius X lt and centre point Roffset Xoffset of the circle are editable Whenever the positive sequence impedance goes inside this circle the stage will pick up If the fault stays on longer than the definite time delay setting the stage will issue a trip signal UnderReactanceZplane jX A cap Z Va sho k 40 NORMAL 9 D a n 4N OPERATION 265 mig AREA OF THE m S O GENERATOR 4 a gt Roffset lt R m o zw a otg gt E 1s 7 be m D cap AN A 3S Figure 5 22 1 The trip region of loss of excitation stage is a circle is covering the unstable area of the generator The radius X lt Roffset and Xoffset are the setting parameters Whenever the positive sequence impedance falls inside the X lt circle the stage picks up Calculating setting values The machine manufacturer specifies synchronous unsaturated reactance and the
199. here are errors in the programmable curve configuration and the device is not able to interpolate values between the given points Limitation The maximum measured phase current is 50xln and the maximum directly measured earth fault current is 5xlon This limits the scope of inverse curves when the setting is more than 2 5xly overcurrent stages and earth fault stages using localc input or 0 25xloin earth fault stages using Io input or Io2 input The In and loin and Ipon depend on the order code See chapter 15 The table below gives the limit values in secondary amperes Example of limitation CT 750 5 lan 5 77A CT 100 1 a cable CT for lo Secondary scaled Ignsec iS NOW 3 85 A For 5 A CT secondaries and 1 A residual current inputs VAMP relay VAMP 210 5D7AAA is used It has 5 A phase current inputs and 1 A residual inputs For overcurrent stage I gt the table below gives 12 5 A Thus the maximum setting for l gt stage giving full inverse delay range is 12 5 A 3 85 A 3 25 xlen For earth fault stage Io gt and input Io the table below gives 0 25 A Thus the maximum setting for l gt stage giving full inverse delay range is 0 25 A 1 A 0 25 pu This equals a 25 A primary earth fault current 141 5 29 Inverse time operation 5 Protection functions Technical description When using input signal locaic the corresponding setting is 12 5 A 1 A 12 5 pu This equals a 9375 A of primary earth fault current
200. hree line to line voltage is used regardless of the voltage measurement mode chapter 7 6 By using line to line voltages any phase to ground over voltages during earth faults have no effect The earth fault protection functions will take care of earth faults The used net frequency is automatically adopted according the local network frequency Overexcitation protection is needed for generators which are excitated even during start up and shut down If such a generator is connected to a unit transformer also the unit transformer needs volts hertz over excitation protection Another application is sensitive overvoltage protection of modern transformers with no flux density margin in networks with unstable frequency 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 Measured voltage PU V210 EN M A011 ole Uf gt setting Us setting gt 2 0 5 18 5 A 16 amp o op 14 a af 5 S w 10 o 3 08 wm 06 a z 0 4 one 0 2 30 35 40 45 50 55 60 65 30 35 40 45 50 55 60 65 30 36 42 48 54 60 66 72 30 36 42 48 54 60 66 72 Frequency Hz OverVoltreqChar Frequency Hz VoltPerHorz Figure 5 13 1 This figure shows the difference between volts hert
201. iations and SYMbOIS ccccceeeseeseeeeeeeeeeeeeeeeeees 286 14 Construction mreresrrerererer errr rier rr rererererer eres rer rererererrrrrerrr terry 288 TS Order information vicsessscisieciscccesssnseriweiencewersennnerocrecenscnes 289 16 REVISION RISTOMY siciescccii cece cscicesseantscaceenscesseerdsancncetsincadnanenane 291 1 General Operation and configuration instructions 1 1 Relay features T General This first part Operation and configuration of the publication contains general descriptions of the functions of the generator protection relay as well as operation instructions It also includes instructions for parameterization and configuration of the relay and instructions for changing settings The second part Technical description of the publication includes detailed protection function descriptions as well as application examples and technical data sheets 1 1 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 List of protection functions IEEE IEC symbol Function name ANSI code 50 51 3l gt 3l gt gt 3l gt gt gt Overcurrent protection 67 lgir gt s lair gt gt lgir gt gt gt lair gt gt gt Directional overcurrent protection 51V Iv gt Voltag
202. ill not work e Si Light sensor S1 e S2 Light sensor S2 e S1 S2 Either one of the light sensors S1 or S2 e BI Binary input of the arc card 48 Vdc e S1 Bl Light sensor S1 or the binary input e S2 Bl Light sensor S2 or the binary input e S1 S2 Bl Light sensor S1 or S2 or the binary input 137 5 28 Arc fault protection 50ARC 50NARC optional 5 Protection functions Technical description 138 Binary input The binary input BI on the arc option card see chapter 11 5 can be used to get the light indication from another relay to build selective arc protection systems The BI signal can also be connected to any of the output relays BO indicators etc offered by the output matrix See chapter 8 4 BI is a dry input for 48 Vdc signal from binary outputs of other VAMP relays or dedicated arc protection devices by VAMP Binary output The binary output BO on the arc option card see chapters 11 5 and 11 6 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 protection systems Selection of the BO connected signal s is done with the output matrix See chapter 8 4 BO is an internally wetted 48 Vdc signal for BI of other VAMP relays or dedicated arc protection devices by VAMP Delayed light indication signal Relay output matrix has a delayed light indication output signal Delayed Arc L gt available for building selective arc protec
203. ilure stage 8 latest faults CBFP 50BF Parameter Value Unit Description yyyy mm dd Time stamp of the recording date hh mm ss ms Time stamp time of day EDly setting 100 trip Elapsed time of the operating time 133 5 27 Programmable stages 99 5 Protection functions Technical description 27 134 Programmable stages 99 For special applications the user can built his own protection stages by selecting the supervised signal and the comparison mode The following parameters are available e Priority If operation times less than 60 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 Link The name of the supervised signal see table below e Cmp Compare mode gt for over or lt for under comparison e Pick up Limit of the stage The available setting range and the unit depend on the selected signal e t Definite time operation delay e Hyster Dead band hysteresis e NoCmp Only used with compare mode under lt This is the limit to start the comparison Signal values under NoCmp are not regarded as fault V210 EN M A011 Technical description 5 Protection functions 5 27 Programmable stages 99 V210 EN M A011 Available signals to be supervised by the programmable
204. in the documentation of the CB manufacturer Figure 6 8 1 The diagram specifies the permissible number of cycles for every level of the breaking current This diagram is parameterised to the condition monitoring function with maximum eight current cycles points See Table 6 8 1 If less than eight points needed the unused points are set to Ipic 1 where Isic is more than the maximum breaking capacity If the CB wearing characteristics or part of it is a straight line ona log log graph the two end points are enough 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 8 1 Thus they are set to 100 kA and one operation in the table to be discarded by the algorithm 100000 T a eel eee Dest od l l l l 2 I S Rees shes oS ase eo ge Poe ee eee i i 10000 ila Ses errr ie ee ro T L D i i Suis ere es lle Fa l l 1000 r r F 1 1 O FESE priest a EA 4 l l 9 l i S fe te fe we a 1 1 E 100 i 1 I 1 I es aa areal i f i i i 20 F LISAR EF e T l l 1 10 100 200 500 1000 10000 100000 Breaked current A CBWEARcharacteristics Figure 6 8 1 An example of a circuit breaker wearing characteristic graph Table 6 8 1 An example of circuit breaker wearing characteristics in a table format The value are taken f
205. ing communication protocols or VAMPSET Every reading increments the internal read pointer to the event buffer In case of communication error 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 prevents 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 in all v 10 xx softwares Modification can be done in Local panel conf menu Alarm 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 of the particular function creating the event For example most protection stages create events with 10 ms or 20 ms resolution The absolute accuracy of all time stamps depends on V210 EN M A011 Technical description 6 Supporting functions 6 1 Event log the time synchronizing of the relay See chapter 6 10 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 this is indicated with string OVF
206. ingle line diagram editing The single line diagram is drawn with the VAMPSET software For more information please refer to the VAMPSET manual VVAMPSET EN M xxxx single line diagram 1 Bay OA 0 000A OkW OKvar IR Figure 2 4 9 1 Single line diagram Blocking and interlocking configuration 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 VVAMPSET EN M xxxx 43 2 4 Configuration and parameter 3 VAMPSET PC software Technical description setting 3 44 VAMPSET PC software 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 a connection cable of type VX 003 3 The VAMPSET
207. inputs virtual inputs mimic display communication logic and manually There are two identical stages available with independent setting parameters 128 V210 EN M A011 Technical description 5 Protection functions 5 23 Reverse power and under power protection P lt 32 V210 EN M A011 Parameters of the reverse under power stages P lt P lt lt 32 Parameter Value Unit Description Note Status Current status of the stage Blocked Start F Trip F SCnir Cumulative start counter C TCntr Cumulative trip counter C SetGrp 1 or2 Active setting group Set SGrpDI Digital signal to select the active Set setting group s None Dix Digital input Vix Virtual input LEDx LED indicator signal VOx Virtual output Force Off Force flag for status forcing for Set On test purposes This is a common flag for all stages and output relays too Automatically reset by a 5 minute timeout P kW The supervised value P lt P lt lt kW Pick up value scaled to primary value P lt P lt lt Pm Pick up value scaled to pu Set t lt t lt lt s Definite operation time Set For details of setting ranges see chapter 12 3 Set An editable parameter password needed C Can be cleared to zero F Editable when force flag is on Recorded values of the latest eight faults There are detailed information available of the eight latest faults Time stamp fault power elapsed delay and
208. ion U gt 59 5 Protection functions Technical description 12 90 C Can be cleared to zero F Editable when force flag is on Recorded values of the latest eight faults There is detailed information available of the eight latest detected faults Time stamp Uo voltage elapsed delay and setting group Recorded values of the directional intermittent transient earth fault stage 8 latest faults lont gt 67NI 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 detected earth 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 Overvoltage protection U gt 59 The overvoltage function measures the fundamental frequency component of the line to line voltages regardless of the voltage measurement mode chapter 7 6 By using line to line voltages any phase to ground over voltages during earth faults have no effect The earth fault protection functions will take care of earth 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 rigidly earthed 4 wire networks with loads
209. ional overcurrent protection 51V Iv gt Voltage restrained or voltage controlled overcurrent function 46 l2 gt Current unbalance protection 49 T gt Thermal overload protection 50N 51N l gt lo gt gt lo gt gt gt Ip gt gt gt gt Earth fault protection 67N Iog gt Log gt gt Directional earth fault protection 67NT Ior Intermittent transient earth fault protection 59 U gt U gt gt U gt gt gt Overvoltage protection 27 U lt U lt lt U lt lt lt Undervoltage protection 24 U f gt Volts hertz overexcitation protection 27P Ui lt Ui lt lt Positive sequence undervoltage protection 59N Uo gt Up gt gt Residual voltage protection 64F3 Uors lt 100 stator earth fault protection 81H 81L f gt lt f gt gt lt lt Overfrequency and underfrequency protection 81L f lt f lt lt Under frequency protection 81R df dt gt Rate of change of frequency ROCOF protection 21 Z lt Z lt lt Underimpedance protection 40 Q lt Underexcitation protection 21 40 X lt X lt lt Underreactance protection Loss of excitation 32 P lt P lt lt Reverse and underpower protection 51F2 l gt Second harmonic O C stage 51F5 lis gt Fifth harmonic O C stage 50BF CBFP Circuit breaker failure protection 99 Prg1 8 Programmable stages V210 EN M A011 49 5 3 General features of protection 5 Protection functions Technical description stages 5 3 50 General features of protection stages Setting groups Most
210. irtual inputs mimic display communication logic and manually 109 5 18 Overfrequency and 5 Protection functions Technical description underfrequency protection f gt f lt 81H 81L Parameters of the over amp under frequency stages f gt lt f gt lt gt lt f lt f lt lt 81H 81L Parameter Value Unit Description Note Status Current status of the stage Blocked Start F Trip F SCnir Cumulative start counter C TCntr Cumulative trip counter C SetGrp 1 or2 Active setting group Set SGrpDI Digital signal to select the active Set setting group None Dix Digital input Vix Virtual input LEDx LED indicator signal vox Virtual output Force Off Force flag for status forcing for Set On test purposes This is a common flag for all stages and output relays too Automatically reset by a 5 minute timeout f Hz The supervised value Hz Pick up value fX Over under stage f gt lt See fXX Mode Set f lt Over under stage f gt lt gt lt f lt lt Under stage f lt Under stage f lt lt s Definite operation time tX f gt lt stage tXX f gt lt gt lt stage Set t lt f lt stage t lt lt f lt lt stage Mode Operation mode only for f gt lt and f gt lt gt lt Set gt Overfrequency mode 2 Underfrequency mode LVbIck Un Low limit for self blocking This is acommon setting for all four Set stages For details of setting ranges see chapte
211. 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 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 V210 EN M A011 Technical description 10 Applications 10 4 Trip circuit supervision Using optional DI19 DI20 Note In the device only the optional digital inputs DI19 and DI20 are dry see the ordering code for this option V aux 24 Vdc 240 Vdc VAMP relay Trip relay by Pala Alarm relay ted for trip a circuit failure rip circul Failure alarm relay compartment circuit breaker compartment SS SS Se eS TCS1Diclosed Figure 10 4 1 1 Trip circuit supervision using a single dry 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 digi
212. is framed 4 Select the desired parameter for example Inom with l 5 Use the and to change a parameter value If the value contains more than one digit use and to shift from digit to digit and the and to change the digits 6 Push to accept a new value If you want to leave the parameter value unchanged exit the edit state by pushing a VAMP 200 series changing parameters CURRENT SCALING PICK CURRENT SCALING CT prima inom Isec Isec lonom lonom losec d losec loinp loinp lo2nom lo2nom OK OJ Edit VALUE CHANGE E enter CT pary CANCEL ok PES j Figure 2 4 1 1 Changing parameters V210 EN M A011 Operation and configuration 2 Local panel user interface 2 4 Configuration and parameter setting 2 4 2 2 4 3 V210 EN M A011 Setting range limits If the given parameter setting values are out of range values a fault message will be shown when the setting is confirmed with mi Adjust the setting to be within the allowed range illegal Edit VALUE CHANGE Illegal value Lim 0 10 5 00 Press CANCEL Figure 2 4 2 1 Example of a fault message The allowed setting range is shown in the display in the setting mode To view the range push 0 Push to return to the setting mode infoset_I Info SET I gt Setting for stage I gt Type i32 dd Range 0 10 5 00 ENTER password CANCEL back to menu Figure 2 4 2 2 Allowed setting ranges show in the display Disturba
213. isplay communication logic and manually Start Register event Trip Register event Setting I gt s Delay Definite inverse Inverse time Multiplier Enable events i characteristics Figure 5 4 1 Block diagram of the three phase overcurrent stage l gt 3visblock 3vIssblock Register event Register event Setting I gt gt s Delay Enable events Figure 5 4 2 Block diagram of the three phase overcurrent stage I gt gt and I gt gt gt Parameters of the overcurrent stage I gt 50 51 Parameter Value Unit Description Note Status Current status of the stage Blocked Start F Trip F TripTime s Estimated time to trip SCntr Cumulative start counter Clr TCntr Cumulative trip counter Clr SetGrp 1 or2 Active setting group Set SGrpDI Digital signal to select the active setting group None Dix Digital input Set Vix Virtual input LEDx LED indicator signal VOx Virtual output V210 EN M A011 Technical description 5 Protection functions 5 4 Overcurrent protection I gt 50 51 V210 EN M A011 Parameter Value Unit Description Note Force Off Force flag for status forcing for Set On test purposes This is a common flag for all stages and output relays too This flag is automatically reset 5 minutes after the last front panel push button pressing ILmax A The supervised value Max of IL1 IL2 and IL3 I gt A Pick
214. itched 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 Menu navigation and pointers 1 Use and A to move up and down in the main menu that is on the left hand side of the display The active main menu option is indicated with a cursor The options in the main menu items are abbreviations e g Evnt events 2 After any selection the arrow symbols in the upper left corner of the display show the possible navigating directions applicable navigation keys in the menu 3 The name of the active submenu and a possible ANSI code of the selected function are shown in the upper part of the display e g CURRENTS 4 Further each display holds the measured values and units of one or more quantities or parameters e g ILmax 300A Keypad You can navigate in the menu and set the required parameter values using the keypad and the guidance given in the display Furthermore the keypad is used to control objects and switches on the single line diagram display The keypad is composed of four arrow keys one cancel key one enter key and one info key o Figure 2 1 3 1 Keys on the keypad 1 Enter and confirmation key amp Home Cancel key E Up Down Increase Decrease arrow keys amp Vj Keys for selecting submenus selectin
215. ith basic logic functions and timers Recording of time stamped events and fault values Built in disturbance recorder for evaluating all the analogue and digital signals Disturbance recorder for evaluating all the analogue and digital signals Easy configuration parameterisation and reading of information via the local human man interface HMI or with the free of charge VAMPSET PC program Built in self regulating AC DC converter for auxiliary power supply from any source within the range from 40 to 265 VDC or VAC The alternative power supply is for 18 to 36 VDC V210 EN M A011 Technical description 4 Introduction 4 2 Principles of numerical protection techniques 4 2 Principles of numerical protection techniques The manager is 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 manager is primarily based on an adapted Fast Fourier Transformation FFT algorithm Synchronized sampling of the measured voltage and current signals is used The sample rate is 32 samples cycle within the frequency range 45 Hz 65 Hz The frequency is measured from the voltage signals and used to synchronize the sampling rate 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 The learned frequency
216. latest eight faults There are detailed information available of the eight latest faults Time stamp fault value and elapsed delay V210 EN M A011 Technical description 5 Protection functions 5 28 Arc fault protection 50ARC 50NARC optional 5 28 V210 EN M A011 Recorded values of the programmable stages PrgN 99 Parameter Value Unit Description yyyy mm dd Time stamp of the recording date hh mm ss ms Time stamp time of day Fit pu Fault value EDly Elapsed time of the operating time setting 100 trip SetGrp 1 Active setting group during fault 2 Arc fault protection 50ARC 50NARC optional NOTE This protection function needs optional hardware in slot X6 More details of the hardware can be found in chapters 11 5 and 12 1 6 Arc protection is used for fast arc protection 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 gt for phase to phase arc faults Current inputs IL1 IL2 IL3 are used e Arcloi gt for phase to earth arc faults Current input lo is used e Arclos gt for phase to earth arc faults Current input loz 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 w
217. lected input Length of digital input pulse should be at least 60 ms V210 EN M A011 Technical description 8 Control functions 8 7 Logic functions 8 6 1 8 7 V210 EN M A011 Local Remote selection 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 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 Logic functions The relay supports customer defined programmable logic for boolean signals The logic is designed by using the VAMPSET setting tool and downloaded to the relay Functions available are AND OR XOR NOT COUNTERs RS amp D flip flops Maximum number of outputs is 20 Maximum number of input gates is 31 An input gate can include any number of inputs For detailed information please refer to the VAMPSET manual VVAMPSET EN M xxxx 215 9 1 Communication ports 9 Communication Technical description 9 7 1 216 Communication Communication ports
218. ls from the loint gt stage Auto reclosing The start signal of any I gt stage initiating auto reclosing AR can be used to block the Ioint gt stage to avoid the loint gt stage with a long intermittent setting to interfere with the AR cycle in the middle of discrimination time Usually the Ioint gt stage itself is not used to initiate any AR For transient faults the AR will not help because the fault phenomena itself already includes repeating self extinguishing Intermittent time Single transient faults make the protection to pick up but will not cause trip if the stage has time to release between to successive faults When starting happens often enough such intermittent faults can be cleared using the intermittent time setting When a new fault happens within the set intermittent time the operation delay counter is not cleared between adjacent faults and finally the stage will trip A single transient fault is enough to start the stage and increase the delay counter by 20 ms For example if the operating time is 140 ms and the time between two peaks does not exceed the intermittent time setting then the seventh peak will cause a trip Figure 5 11 3 Operation time setting and the actual operation time When the algorithm detects the direction of the fault outwards from the bus the stage picks up and the operation delay counter is incremented with 20 ms and a start signal is issued If the time between successive faults
219. ls 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 A 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 See an example in Figure 8 4 1 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 digital 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 T1 T2 A A2 A3 A4 A5 Alarm Trip A B C DR vOo1 e connected connected and latched Z Z Z Z Z T Z b gt start I gt trip gt gt start gt gt trip lo gt start lo gt trip lo gt gt start lo gt gt trip OutputMatri
220. ly longer than in the figure an unselective trip might happen the dashed 40 ms pulse in the figure In VAMP relays the retardation time is less than 50 ms 51 5 3 General features of protection 5 Protection functions Technical description stages 52 Reset time release time Figure 5 3 2 shows an example of reset time i e release delay 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 cut off 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 the trip contacts and start contact are opened unless latching is configured The reset time varies from fault to fault depending on the fault size After a big fault the time is longer The reset time also depends on the specific protection stage The maximum reset time for each stage is specified in chapter 12 3 For most stages it is less than 95 ms ReleaseTime treser TRIP CONTACTS Figure 5 3 2 Reset time is the time it takes the trip or start relay contacts to open after the fault has been cleared 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 hy
221. mal capacity of the whole generator Thus an rms current based overload protection see chapter 5 8 is not capable to protect a generator 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 Equation 5 7 1 t where i gn t Operation time K Delay multiplier l gt Measured and calculated negative sequence phase current of fundamental frequency ln Rated current of the generator K Pick up setting l2 gt in pu The maximum allowed degree of unbalance Example Ki 15s lo 22 9 0 229 Xlgn Ko 5 0 05 XIgn t 13 300 4 2 0 05 1 The operation time in this example will be five minutes More stages definite time delay only If more than one definite time delay stages are needed for current unbalance protection the freely programmable stages can be used chapter 5 27 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 67 5 7 Current unbalance protection 12 gt 46 5 Protection functions Technical description 68 CurrentUnbalanceChar 2000 1000 Operation time s 20 60
222. me starting from the third fault will be 617 ms although the setting was 140 ms In case the intermittent setting would have been 0 2 s or more the two first faults had been included and a trip would have issued at t 0 64 s EFtransientFig7 1 Intermittent time 0 s i Start T2 Lo H ppi CES pp SCEE payg BCH paa BA p ALe Trip i 0 12 s Intermittent time 0 12 s 0 0 0 2 0 4 0 6 0 8 1 0 Time s Figure 5 11 2 Effect of the intermittent time parameter The operation delay setting is 0 14 s 7x20 ms The upper start and trip status lines are for a case with the intermittent time set to zero No trip will happen The lower start and trip status lines show another case with intermittent time setting 0 12 s In this case a trip signal will be issued at t 0 87 s 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 88 V210 EN M A011 Technical description 5 Protection functions 5 11 Intermittent transient earth fault protection IOINT gt 67NI V210 EN M A011 idtBlock I samples I I peak TRANSIENT ALGORITHM I fundamental freq amplitude U samples o U fundamental E i freq amplitude Setting Setting Setting Enable U pick up Delay Intermittent events n delay 20 ms time Figure 5 11
223. ms 10 ms 283 12 4 Supporting functions 12 Technical data Technical description 12 4 12 4 1 12 4 2 12 4 3 284 Arc protection stage Arclo2 gt 50NARC option Setting range Arc sensor connection Operating time Light only Operating time 4xlset light Operating time BIN Operating time Delayed Arc L gt BO operating time Reset time Reset time Delayed ARC L Reset time BO Reset ratio Inaccuracy Starting Operating time Delayed ARC light 0 5 10 0 x In 1 S2 S1 S2 BI S1 Bl S2 Bl S1 S2 BI 13 ms 17ms 10 ms 0 01 0 15s lt 3 ms lt 95 ms lt 120 ms lt 85 ms 0 90 10 of the set value 5 ms 10 ms Supporting functions Disturbance recorder DR 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 Disturbance recorder DR Mode of recording Sample rate Waveform recording Trend curve recording Recording time one record Pre trigger rate Number of selected channels Saturated Overflow 32 cycle 16 cycle 8 cycle 10 20 200 ms 1 5 10 15 30s 1 min 0 1 s 12 000 min must be shorter than MAX time 0 100 0 12 Inrush current detection 68 Settings Setting range 2 Harmonic Operating time 10 100 0 05 300 00 s s
224. mum total operational time including the fault detection time and operation time of the trip contacts The measuring range may limit the scope of inverse delays See chapter 5 29 for details Directional overcurrent stages lair gt gt gt and lair gt gt gt gt 67 Pick up current 0 10 20 0 x len Mode Directional non directional Minimum voltage for the direction solving 0 1 V secondary Base angle setting range 180 to 179 Operation angle 88 Definite time function Operating time DT 0 06 300 00 s step 0 02 s Start time Typically 60 ms Reset time lt 95 ms Retardation time lt 50 ms Reset ratio 0 95 Reset ratio angle 2 Transient over reach any t lt 10 Inaccuracy Starting rated value IN 1 5A Angle Operate time at definite time function 3 of the set value or 0 5 of the rated value 2 U gt 5 V 30 U gt 0 1 V 1 or 30 ms This is the instantaneous time i e the minimum total operational time including the fault detection time and operation time of the trip contacts 274 V210 EN M A011 Technical description 12 Technical data 12 3 Protection functions V210 EN M A011 Voltage restrained controlled overcurrent stage ly gt 51V Settings lyv gt Ux Ux2 Z Iv Ivo 0 50 4 00 x len 0 150 0 200 ly gt Definite time function Operating time
225. n For details see the technical description part of the manual EXTERNAL I O protocol This is a Modbus master protocol to communicate with the extension I O 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 the technical description part of the manual 41 2 4 Configuration and parameter 2 Local panel user interface Operation and configuration setting instructions 42 SPA BUS Several instances of this protocol are possible e SPABUS addres for this device Addr This address has to be unique within the system e Bit rate bit s Default is 9600 e Event numbering style Emode Default is Channel For details see the technical description part of the manual IEC 60870 5 101 e Bit rate bit s Default is 9600 e Parity e Link layer address for this device LLAddr e ASDU address ALAdadr For details see the technical description part of the manual 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 Bit rate bit s Default is 9600 e Minimum measurement response interval Measint e ASDU6 response time mode SyncRe For details see the technical description part of the manual IEC 103 DISTURBANCE RECORDINGS For details see the technical description p
226. n 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 notice that a fault has been cleared during the operation time delay This parameter is important when grading the operation time delay settings between relays trauu jer lt 50 my DELAY SETTING gt tmur trer ey TRIPCONTACTS TE Figure 5 3 1 Definition for retardation time If the delay setting would be slightly shorter an unselective trip might occur the dash line pulse For example when there is a big fault in an outgoing feeder it might start i e 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 3 1 shows an overcurrent 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 slight
227. nabled Start on event Disabled S_Off Enabled Enabled Start off event Disabled T_On Enabled Enabled Trip on event Disabled T_Off Enabled Enabled Trip off event Disabled V210 EN M A011 Technical description 5 Protection functions 5 25 Fifth harmonic O C stage 1f5 gt 51F5 25 V210 EN M A011 Measured and recorded values of second harmonic blocking 2 Ha 51F2 Parameter Value Unit Description Measured IL1H2 2 harmonic of IL1 values proportional to the fundamental value of IL1 IL2H2 2 harmonic of IL2 IL3H2 2 harmonic of IL3 Recorded Flt A The max fault value values EDly Elapsed time as compared to the set operating time 100 tripping Fifth harmonic O C stage Ijs5 gt 51F5 Overexiting for example a transformer creates odd harmonics This 5 harmonic overcurrent stage can be used detect overexcitation This stage can also be used to block some other stages The ratio between the fifth 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 trip delay of the stages to be blocked must be more than 60 ms to ensure a proper blocking Setting parameters of second harmonic blocking 5 Ha 51F5 Parameter Value U
228. nal to select the active Set SGrpDI setting group s None Dix Digital input Vix Virtual input LEDx LED indicator signal VOx Virtual output Force Off Force flag for status forcing for Set On test purposes This is a common flag for all stages and output relays too 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 V Pick up value scaled to primary U lt lt lt value U lt U lt lt Ugn Pick up setting Set U lt lt lt t lt t lt lt t lt lt lt s Definite operation time Set LVBIk Ugn Low limit for self blocking Set RlsDly s Release delay U lt stage only Set Hyster Default Dead band setting Set 3 0 For details of setting ranges see chapter 12 3 Set An editable parameter password needed C Can be cleared to zero F Editable when force flag is on 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 V210 EN M A011 101 5 16 Zero sequence voltage protection U0 gt 59N 5 Protection functions Technical description 5 16 102 Recorded values of the undervoltage stages 8 latest faults U lt U lt lt U lt lt lt 27 Parameter Value Unit Description yyyy mm dd Time stamp of the recording date hh mm ss
229. nce recorder menu DR 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 PreTrig Manual trigger MnITrig Count of ready records ReadyRe REC COUPLING e Add a link to the recorder AddLink e Clear all links ClrLnks 35 2 4 Configuration and parameter 2 Local panel user interface Operation and configuration setting instructions Available links DO DI Uline Uphase IL U2 U1 U2 U1 I2 In 12 11 12 11 loCalc CosFii PF S Q P f Uo UL3 UL2 UL1 U31 U23 U12 l02 lo IL3 IL2 IL1 Prms Qrms Srms Tanfii THDIL1 THDIL2 THDIL3 THDUa THDUb THDUc fy fz U12y U12z 2 4 4 Configuring digital inputs DI The following functions can be read and set via the submenus of the digital inputs menu 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 POLARITY Either normally open NO or normally closed NC circuit e Event enabling EVENT MASK1 2 4 5 Configuring digital outputs DO The following functions can be read and set via the submenus of the digital outputs menu e The status of the output relays RELAY OUTPUTS1 and 2 e The forcing of the output relays RELAY OUTPUTS1 and 2 only if Force ON o Forced cont
230. nce voltage of Un V3 U1 lt U1 lt lt V Pick up value scaled to primary value U1 lt U1 lt lt Pick up setting of Un V3 Set t lt t lt lt s Definite operation time Set LVBIk Un Low limit for self blocking This Set is acommon setting for both stages I lt Blk s Pick up delay when current is Set less than 1 len For details of setting ranges see chapter 12 3 Set An editable parameter password needed C Can be cleared to zero F Editable when force flag is on Recorded 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 V210 EN M A011 Technical description 5 Protection functions 5 15 Undervoltage protection U lt 27 Recorded values of the undervoltage stages 8 latest faults Ui lt U1 lt lt 27P Parameter Value Unit Description yyyy mm dd Time stamp of the recording date hh mm ss ms Time stamp time of day Fit Un Minimum fault voltage EDly Elapsed time of the operating time setting 100 trip SetGrp 1 Active setting group during fault 2 5 15 Undervoltage protection U lt 27 This 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 faul
231. nder reactance and loss of excitation protection X lt 40 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 Parameters of the under reactance stages X lt X lt lt 40 Parameter Value Unit Description Note Status Current status of the stage Blocked Start F Trip F 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 3 None Dix Digital input Set Vix Virtual input LEDx LED indicator signal VOx Virtual output Force Off Force flag for status forcing for Set On test purposes This is acommon flag for all stages and output relays too Automatically reset by a 5 minute timeout Z ohm The supervised value scaled to primary value Inf infinite Z xZn The supervised value scaled to per unit pu 1 pu 1xXZy Ugn V3xl gn Inf infinite Zo 3 Angle of the supervised impedance X lt ohm Pick up value scaled to primary X lt lt value X lt xZn Pick up setting in per unit pu Set X lt lt 1 pu 1xZn Ugn V3XI gn t lt s Definite operation time Set RIsDly s Release delay Set Ros xZn Resistive offset for trip area origin Set in pu Xos xZn Reactive off
232. nel operations 2 Local panel user interface Operation and configuration 16 instructions Main menu Submenus I I I I z I V a Prot k protection enabling a a I I i ok I i y I I a I i l l pick up setting za I a y iene l Yy I i moving in the menus_relay Figure 2 2 1 2 Principles of the menu structure and navigation in the menus 6 Push O to obtain additional information about any menu item 7 Push to revert to the normal display Main menu The general menu structure is shown in Figure 2 2 1 2 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 V210 EN M A011 Operation and configuration 2 Local panel user interface 2 2 Local panel operations A list of the local main menu Main Number Description ANSI Note menu of code menus 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 measurements Dema 15 Demand values Umax 5 Time stamped min amp max of voltages Imax 9 Time stam
233. ng For phase currents excluding Arcl gt stage 1 pu 1xlen 100 where Ign is the rated current of the generator For residual currents and Arcl gt stage 1 pu 1xCTsec for secondary side and 1 pu 1xCTpr for primary side Phase current scaling Residual current 3lo excluding Arcl gt stage scaling and phase current scaling for Arcl gt stage f _ I SEC CT ori I SEC secondary gt per unit Lpy Ip CT sxc gi GN CT sxc nan Ion amp per unit gt secondary I snc I py CT sp 1 sec py CT suc CT prr Example 1 Secondary to per unit for phase currents excluding Arcl gt CT 750 5 lan 525A Current injected to the relay s inputs is 7 A Per unit current is Ipu 7X750 5x525 2 00 pu 2 00 xlen 200 Example 2 Secondary to per unit for Arcl gt CT 750 5 Current injected to the relay s inputs is 7 A Per unit current is Ipu 7 5 1 4 pu 140 Example 3 Per unit to secondary for phase currents excluding Arcl gt CT 750 5 lan 525A The relay setting is 2xlgn 2 pu 200 Secondary current is Isec 2x5x525 750 7A Example 4 Per unit to secondary for Arcl gt CT 750 5 The relay setting is 2 pu 200 Secondary current is Isec 2x5 10A 203 7 10 Primary secondary and per unit 7 Measurement functions Technical description scaling 204 Example 5 Secondary to per unit for residual current Input is lo
234. nge of frequency 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 3 Second harmonic O C stage 51F2 4 CBFP 3 Circuit breaker failure protection 50BF 4 CBWE 4 Circuit breaker wearing supervision 4 CTSV 1 CT supervisor 4 VTSV 1 VT supervisor 4 Arcl gt 4 Optional arc protection stage for phase to phase 50ARC 4 faults and delayed light signal Arclo gt 3 Optional arc protection stage for earth faults Current 50NARC_ 4 input 101 Arclo2 gt 3 Optional arc protection stage for earth faults Current 50NARC_ 4 input 102 OBJ 11 Object definitions 5 V210 EN M A011 Operation and configuration 2 Local panel user interface 2 2 Local panel operations Main Number Description ANSI Note menu of code menus Lgic 2 Status and counters of user s logic 1 CONF 10 2 Device setup scaling etc 6 Bus 13 Serial port and protocol configuration 7 Diag 6 Device selfdiagnosis Notes V210 EN M A011 1 2 3 Configuration is done with VAMPSET Recording files are read with VAMPSET The menu is visible only if protocol ExternallO is selected for one of the serial ports Serial ports are configured in menu Bus The menu is visible only if the stage is enabled
235. nit Default Description If5 gt 10 100 10 Setting value If2 lfund t_f5 0 05 300 0 s 0 05 Definite operating time S_On Enabled Enabled Start on event Disabled S_Off Enabled Enabled Start off event Disabled T_On Enabled Enabled Trip on event Disabled T_Off Enabled Enabled Trip off event Disabled 131 5 26 Circuit breaker failure 5 Protection functions Technical description protection CBFP 50BF Measured and recorded values of fifth harmonic blocking 5 Ha 51F5 Parameter Value Unit Description Measured IL1H5 5 harmonic of IL1 values proportional to the fundamental value of IL1 IL2H5 A 5 harmonic of IL2 IL3H5 5 harmonic of IL3 Recorded Fit The max fault value values EDly Elapsed time as compared to the set operating time 100 tripping 5 26 Circuit breaker failure protection CBFP 50BF 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 relay 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 the trip command If this time is longer than the operating time of the CBFP stage the CBFP stage activates
236. nput 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 chapter 12 4 165 6 5 Voltage interruptions 6 Supporting functions Technical description 6 5 166 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 8 hours 00 00 08 00 08 00 16 00 16 00 24 00 one day 00 00 24 00 one week Monday 00 00 Sunday 24 00 one month the first day 00 00 the last day 24 00 one 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 U and a user given limit value Whenever the measured U goes below the limit the interruption counter is increased and the total time counter starts increasing Shortest recognized interru
237. nt Number of voltage sags during the current observation period Prev Number of voltage sags during the previous observation period Total Total summed time of voltage sags during the current observation period Prev Total summed time of voltage sags during the previous observation period For details of setting ranges see chapter 12 4 167 6 6 Current transformer supervision 6 Supporting functions Technical description 6 6 168 Current transformer supervision The relay supervise the external wiring between the relay terminals and current transformers CT and the CT them selves Furthermore this is a safety function as well since an open secondary of a CT causes dangerous voltages The CT supervisor function measures phase currents If one of the three phase currents drops below Imin lt setting while another phase current is exceeding the Imax gt setting the function will issue an alarm after the operation delay has elapsed Setting parameters of CT supervisor CTSV Parameter Value Unit Default Description Imax gt 0 0 10 0 xIgn 2 0 Upper setting for CT supervisor Imin lt 0 0 10 0 xIgn 0 2 Lower setting for CT supervisor t gt 0 02 600 0 s 0 10 Operation delay CT on On Off On CT supervisor on event CT off On Off On CT supervisor off event Measured and recorded values of
238. nts is at the moment 403 A This is the value the stage is supervising e Status Status of the stage This is just a copy of the status value in the first menu e I gt gt 1013A The pick up limit is 1013 A in primary value e gt gt 2 50xlgn 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 chapter 2 2 5 e t gt gt 0 60s The total operation delay is set to 600 ms This value can be edited if the operating level is at least Operator 21 2 2 Local panel operations 2 Local panel user interface Operation and configuration instructions 22 Third menu of I gt gt 50 51 stage third menu AV lt I gt gt LOG FAULT LOG 1 ExDI 2006 09 14 ExDO 12 25 10 288 Type 1 2 Fit 2 86xlgn CBWE Load 0 99xlgn EDly 81 Figure 2 2 2 3 Third and last menu next on the right of l gt gt 50 51 stage This is the menu for registered values by the I gt gt stage Fault logs are explained in chapter 2 2 4 e FAULT LOG 1 This is the latest of the eight available logs You may move between the logs by pressing push and then or lt e 2006 09 14 Date of the log e 12 25 10 288 Time of the log e Type 1 2 The overcurrent fault has been detected in phases L1 and L2 A amp B red amp yellow R amp S u amp v e Fit 2 86xlgn The fault current has been 2 86 per unit e Load 0
239. odbus RTU slave ModbusT CPs Modbus TCP slave IEC 103 IEC 60870 5 103 slave ExternallO Modbus RTU master for external I O modules DNP3 DNP 3 0 Msg Oa 2 Message counter since the Clr device has restarted or since last clearing Errors o 2 61 Protocol errors since the Clr device has restarted or since last clearing Tout o 2 61 Timeout errors since the Cir device has restarted or since last clearing Display of actual 1 communication parameters speed bit s speed DPS D number of data bits P parity none even odd Default S number of stop bits 38400 8N1 for VAMPSET VAMPSET communication Direct or SPA bus embedded command line interface TX bytes size Unsent bytes in transmitter buffer size of the buffer Msg 0 29 1 Message counter since the Clr device has restarted or since last clearing Errors Oy 4 Errors since the device has Clr restarted or since last clearing Tout o 2 61 Timeout errors since the Cir device has 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 V210 EN M A011 Technical description 9 Communication 9 1 Communication ports 9 1 2 V210 EN M A011 Remote port X5 Physical interface The physical interface of this port dep
240. olled overcurrent function IV gt 51V V210 EN M A011 Cold load and inrush current handling See chapter 6 3 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 Parameters of the voltage restrained and voltage controlled overcurrent stage ly gt 51V Parameter Value Unit Description Note Status Current status of the stage Blocked Start F Trip F SCnir Cumulative start counter C TCntr Cumulative trip counter C SetGrp 1 or2 Active setting group Set SGrpDI Digital signal to select the active Set setting group s None Dix Digital input VIX Virtual input LEDx LED indicator signal VOx Virtual output Force Off Force flag for status forcing for Set On test purposes This is a common flag for all stages and output relays too Automatically reset by a 5 minute timeout ILmax A The supervised value Max of IL1 IL2 and IL3 Iv gt A Pick up value scaled to primary value Iv gt xIgn Pick up setting Set t gt s Definite operation time Set X1 U1 Voltage for the 1st knee point Set X2 U1 Voltage for the 2 knee point Set Y1 lv gt Multiplier for pick up setting at Set the 1st knee point Y2 lv gt Multiplier for pick up setting at Set the 2 knee point For details of setting ranges see chapter 12 3
241. ommunication ports 9 1 4 V210 EN M A011 Ethernet port IEC61850 and Modbus TCP use ethernet communication Also VAMPSET SPA bus and DNP 3 0 communication can be directed via TCP IP Parameters Parameter Value Unit Description Set Protoc Protocol selection for the Set extension port None Command line interface for VAMPSET ModbusTCPs Modbus TCP slave IEC 61850 IEC 61850 protocol Ethernet IP Ethernet IP protocol Port nnn lp port for protocol Set default 102 pAddr n n n n Internet protocol address Set set with VAMPSET NetMsk n n n n Net mask set with Set VAMPSET Gatew default 0 0 0 0 Gateway IP address set Set with VAMPSET NTPSvr n n n n Network time protocol Set server set with VAMPSET 0 0 0 0 no SNTP VS Port nn IP port for Vampset Set KeepAlive nn TCP keepalive interval Set MAC nnnnannnnnnnn MAC address Msg nnn Message counter Errors nnn Error counter Tout nnn Timeout counter Set An editable parameter password needed 221 9 2 Communication protocols 9 Communication Technical description 9 2 9 2 1 9 2 2 222 Communication protocols This 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 PC communication is using a VAMP specified command line interface T
242. onic ratio to fundamental frequency lt2 li1 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 Pickupf2 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 coarse 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 161 6 3 Cold load pick up and inrush 6 Supporting functions Technical description current detection 162 NOTE Inrush detection is based on FFT calculation which recuires 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 1 st cycle the blocking is continued otherwise 2 nd harmonic based blocking signal is released
243. or definite time DT or inverse time operation characteristic IDMT The stages I gt gt and I 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 4 1 shows a functional block diagram of the I gt overcurrent stage with definite time and inverse time operation time Figure 5 4 2 shows a functional block diagram of the I gt gt and l gt gt gt overcurrent stages with definite time operation delay 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 the I gt stage The inverse delay types are described in chapter 5 29 The relay will show the currently used inverse delay curve graph on the local panel display Inverse time limitation The maximum measured secondary current is 50xly This limits the scope of inverse curves with high pick up settings See chapter 5 29 for more information 53 5 4 Overcurrent protection I gt 50 51 5 Protection functions Technical description 54 Cold load and inrush current handling See chapter 6 3 Setting groups There are two settings groups available for each stage Switching between setting groups can be controlled by digital inputs virtual inputs mimic d
244. ording length Set PreTrig Amount of recording data Set before the trig moment 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 recording 3 Not active Run Waiting a triggering Trig Recording FULL Memory is full in saturated mode ManTrig Manual triggering Set Trig 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 158 V210 EN M A011 Technical description 6 Supporting functions 6 2 Disturbance recorder Parameter Value Unit Description Note AddCh IL1 IL2 IL3 lo1 lo2 U12 U23 U31 UL1 UL2 UL3 Uo f P Q S P F CosFii loCalc 11 12 12 11 I2 Ign U1 U2 U2 U1 IL Uphase Uline DO DI TanFii THDIL1 THDIL2 THDIL3 THDUa THDUb THDUc IL1 RMS IL2RMS IL8RMS Add one channel Maximum simultaneous number of channels is 12 Set ClrCh Clear Remove all channels Set Ch List of selected channels For details of setting ranges see chapter 12 4 Set An editable parameter password needed 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 eve
245. ording the Profibus data and profile configuration and the values define the in out module to be configured for the Profibus master 4 If the value is i0 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 224 V210 EN M A011 Technical description 9 Communication 9 2 Communication protocols 9 2 4 V210 EN M A011 SPA bus The manager 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 Several 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 Parameters Parameter Value Unit Description Note Addr 1 899 SPA bus address Must be Set unique in the system bit s bps Communication speed Set 1200 2400 4800 9600 default 19200 Emode Event numbering style Set Channel Use this for new installations Limit60 The other modes are for NoLimit compatibility with old systems Set An editable parameter password needed 225 9 2 Communication protocols 9 Communic
246. ort earth 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 earth faults in compensated networks there is a dedicated stage lot gt 67NT 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 lo gt and l 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 gt and lp gt gt The inverse delay types are described in chapter 5 29 The relay will show a scaleable graph of the configured delay on the local panel display Inverse time limitation The maximum measured secondary residual current is 10xlon and maximum measured phase current is 50xly This limits the scope of inverse curves with high pick up settings See chapter 5 29 for more information Setting groups There are two settings groups available for
247. otocol is available with the optional inbuilt Ethernet port The protocol can be used to read write data from the relay using request response communication or via cyclic messages transporting data assigned to assemblies sets of data EtherNet IP main features Static data model 2 standard objects Overload and Control Supervisor 2 private objects one for digital data and one for analog data and 4 configuration objects for protection functions configuration 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 below or to assemblies content require generating of the new EDS file Three types of communications are supported UCMM one time request response Class 3 connection cyclic request response and Class 1 connection cyclic IO messages containing assemblies data EtherNet IP implementation on VAMP relay serves as a server and is not capable of initiating communication V210 EN M A011 Technical description 9 Communication 9 2 Communication protocols V210 EN M A011 EtherNet IP main configuration parameters Parameter Range Description IP address IP protocol address identifing device in the network Multicast IP Multicast IP ad
248. ower coso Power factor quadrant related to direction PF voltage inductive Lagging Forward capacitive Leading Forward _ inductive Leading Reverse capacitive Lagging Reverse Z 197 7 9 Symmetric components 7 Measurement functions Technical description 7 9 198 Symmetric components In a three phase system the voltage or current phasors may be divided in symmetric components according C L Fortescue 1918 The symmetric components are e Positive sequence 1 e Negative sequence 2 e Zero sequence 0 Symmetric components are calculated according the following equations So 1 1 1fU S gt l a a V where S la aw So zero sequence component S positive sequence component negative sequence component TR N 1 vad a 12120 aa i a phasor rotating constant 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 Uo i e two line to line voltage are measured the following equation is used instead re s iosa en where U 3 1 Ta U z Ui2 Voltage between phases L1 and L2 U23 Voltage between phases L2 and L3 When using line to line voltages any zero sequence voltage can not be calculated NOTE The zero sequence or residual measurement signals connected to the relay are Uo and 3l However usually the name l
249. p parameters The changing of the setting parameters can be done easily When the desired submenu has been found with the arrow keys press to select the submenu Now the selected setting group is indicated in the down left corner of the display See Figure 2 2 3 2 Seti 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 amp is used when the active setting group is 2 and is used when the active setting group is 1 group2 SET I gt Setting for stage I gt ILmax Status I gt Figure 2 2 3 2 Example of I gt setting submenu 23 2 2 Local panel operations 2 Local panel user interface Operation and configuration instructions 2 2 4 Fault logs 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 Each function has its own logs See Figure 2 2 4 1 log AV lt p I gt log buffer Log buffer 1 2003 04 28 11 11 52 251 Figure 2 2 4 1 Example of fault log To see the values of for example log two press to select the current log log one The current log number is then indicated in the down left corner of the display See Figure 2 2 4 2 Log2 log two The log two is selected by pressing once log2 I gt log buffer Date 03 08 21 342 Type 1 2 Log2 jFit 1 69 xin I gt
250. ped min amp max of currents Pmax 5 Time stamped min 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 DI 5 Digital inputs including virtual inputs DO 4 Digital outputs relays and output matrix ExtAl 3 External analogue 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 I gt 5 1st overcurrent stage 50 51 4 I gt gt 3 2nd overcurrent stage 50 51 4 gt gt gt 3 3rd overcurrent stage 50 51 4 Iv gt 4 Voltage restrained controlled overcurrent stage 51V 4 l gt 6 1st directional overcurrent stage 67 4 lo gt gt 6 2nd directional overcurrent stage 67 4 lo gt gt gt 4 3rd directional overcurrent stage 67 4 lp 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 overload stage 49 4 lo gt 5 1st earth fault stage 5ON 51N 4 lo gt gt 3 2nd earth fault stage 50N 51N 4 lo gt gt gt 3 3rd earth fault stage 5ON 51N 4 lo gt gt gt gt 3 4th earth fault stage 5ON 51N 4 V210 EN M A011 17 2 2 Local panel operations 2 Local
251. peration delay setting a trip signal is issued For situations where no voltage is present an adapted frequency is used See chapter 4 2 Protection mode for f gt lt and f gt lt gt 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 generator is not running 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 lt gt lt f lt f lt lt The two first stages can be configured for either overfrequency or underfrequency usage So totally four underfrequency stages can be in use simultaneously Using the programmable stages even more can be implemented chapter 5 27 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 v
252. program can also use TCP IP LAN connection Optional hardware 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 our web page www vamp fi For more information about the VAMPSET software please refer to the user s manual with the code VVAMPSET EN M xxxx Also the VAMPSET user s manual is available at our web site V210 EN M A011 Technical description 4 Introduction 2 4 Configuration and parameter setting 4 V210 EN M A011 Introduction The numerical device includes all the essential protection functions needed to protect generators in power plants industry offshore applications and embedded power generation L1 L2 L3 Lif ef e A aml B a L F A ce 2 Lt Al Protection function 4 B b 50 51 67 SIV p 3p Ea le 3p gt 3P gt gt SON SIN a 49 p gt 37 u gt gt 2 if gt gt gt ge x 5 a I i l a j lt u gt lt lt lt lt u gt gt gt 81H 81L t gt lt 99 Prgl 8 Blocking and output matrix
253. protection 12 gt 46 V210 EN M A011 Recorded values of the current unbalance stage 8 latest faults l2 gt 46 Parameter Value Unit Description yyyy mm dd Time stamp of the recording date hh mm ss ms Time stamp time of day Fit lgn Maximum unbalance current EDly Elapsed time of the operating time setting 100 trip SetGrp 1 Active setting group during the fault 69 5 8 Thermal overload protection T gt 5 Protection functions Technical description 49 5 8 70 Thermal overload protection T gt 49 The thermal overload function protects the generator stator windings against excessive temperatures Thermal model The temperature is calculated using rms values of phase currents and a thermal model according IEC 60255 8 The rms values is calculated using harmonic components up to the 15 rar Trip time Gore Alarm a k ko loy valarm Alarm 60 0 6 Trip a k ko lon I Release time t T C In a I Trip release a V0 95 x ko x Igy Start release a V0 95 x ko x Igy xvalarm Alarm 60 0 6 T Operation time T Thermal time constant tau Setting value In Natural logarithm function Measured rms phase current the max value of three phase currents Ip Preload current 1 VOxk Icy If temperature rise is 120 gt 1 2 This parameter is the memory of the algorithm and corresponds to the actual temperature rise
254. ps can be controlled by digital inputs virtual inputs mimic display communication logic and manually Figure 5 5 4 shows the functional block of the Idir gt stage Start Register event Trip Register event Figure 5 5 4 Block diagram of the three phase overcurrent stage lair gt 3vidirsblock Dir Base angle Setting Idir gt s Delay Definite inverse Inverse time Multiplier Enable events Not dir time characteristics Parameters of the directional overcurrent stages lair gt lair gt gt 67 Parameter Value Unit Description Note Status Current status of the stage Blocked Start F Trip F 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 2 None Dix Digital input Set VIX Virtual input LEDx LED indicator signal VOx Virtual output Parameter Value Unit Description Note V210 EN M A011 Technical description 5 Protection functions 5 5 Directional overcurrent protection Idir gt 67 V210 EN M A011 Force Off Force flag for status forcing for Set On test purposes This is a common flag for all stages and output relays too Automatically reset by a 5 minute timeout ILmax A The supervised value Max of IL1 IL2 and IL3 l
255. ption 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 5 1 Voltage U1 t 10 20 30 40 50 60 70 80 90 ms gt Time Figure 6 5 1 A short voltage interruption which is probably not recognized On the other hand if the limit U lt 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 5 2 V210 EN M A011 Technical description 6 Supporting functions 6 5 Voltage interruptions V210 EN M A011 Voltage U1 A U lt gt Time 10 20 30 40 50 60 70 80 90 ms Figure 6 5 2 A short voltage interrupt that will be recognized Setting parameters of the voltage sag measurement function Parameter Value Unit Default Description U1 lt 10 0 120 0 64 Setting value Period 8h Month Length of the observation Day period Week Month Date Date Time z Time Measured and recorded values of voltage sag measurement function Parameter Value Unit Description Measured value Voltage LOW OK Current voltage status U1 Measured positive sequence voltage Recorded values Cou
256. r 12 3 Set An editable parameter password needed C Can be cleared to zero F Editable when force flag is on Recorded values of the latest eight faults There are detailed information available of the eight latest faults Time stamp frequency during fault elapsed delay and setting group Recorded values of the over amp under frequency stages 8 latest faults f gt lt f gt lt gt lt f lt f lt lt 81H 81L Parameter Value Unit Description 110 V210 EN M A011 Technical description 5 Protection functions 5 19 Rate of change of frequency ROCOF protection df dt 81R yyyy mm dd Time stamp of the recording date hh mm ss ms Time stamp time of day Fit Hz Faulty frequency EDly Elapsed time of the operating time setting 100 trip SetGrp 1 Active setting group during fault 2 5 19 Rate of change of frequency ROCOF protection df dt 81R 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 A special application for ROCOF is to detect loss of grid loss of mains islanding The more the remaining load of the local generator differs from the load before the loss of grid the better the ROCOF function detects the situation Frequency behaviour during load switching Load switching and fault situations may generate chang
257. r gt 67 5 Protection functions Technical description 5 5 Directional overcurrent protection la ir gt 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 earthed networks Please note that in this case the device has to connected to line to neutral voltages instead of line to line voltages In other words the voltage measurement mode has to be 3LN See chapter 7 6 The stages are sensitive to the amplitude of the highest fundamental frequency current of the three measured phase currents The phase angle is based on the phase angle of the three phase power phasor For details of power direction see chapter 7 8 A typical characteristic is shown in Figure 5 5 1 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 NOTE If the maximum possible earth fault current is greater than the most 58 sensitive directional over current setting the device has to connected to the line to neutral voltages instead of line to line voltages in order to get
258. re CC Figure 5 8 1 Ambient temperature correction of the overload stage T gt V210 EN M A011 71 5 8 Thermal overload protection T gt 5 Protection functions Technical description 49 72 Example of a behaviour of the thermal model Figure 5 8 2 shows an example of the thermal model behaviour In this example t 30 minutes k 1 06 and kO 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 85xlgn and the temperature rise starts to approach value 0 85 1 06 64 according the time constant At time 300 min the temperature is about stable and the current increases to 5 over the maximum defined by the rated current and the service factor k The temperature rise starts to approach value 110 At about 340 minutes the temperature rise is 100 and a trip follows Initial temperature rise after restart When the relay 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 thermbeh overload 100 Omax alarm 80 _ LY Reset ratio 95 Op 60 Settings T 30 minutes k 1 06 alarm 90 bax k Iy To
259. re a separate zero sequence voltage transformer is not needed The setting values are relative to the configured voltage transformer VT voltage V3 e Line Up The zero sequence voltage is measured with voltage transformer s for example using a broken delta connection The setting values are relative to the VTo secondary voltage defined in configuration NOTE The U signal must be connected according the connection diagram Figure 10 2 1 in order to get a correct polarization Please note that actually the negative Uo Up is to be connected to the relay V210 EN M A011 Technical description 5 Protection functions 5 16 Zero sequence voltage protection U0 gt 59N Two independent stages There are two separately adjustable stages Up gt and Up gt gt Both stages can be configured for definite time DT operation characteristic The zero sequence voltage function comprises two separately adjust table zero sequence voltage stages stage Uo gt and Uo gt gt Setting groups There are two settings groups available for both stages Switching between setting groups can be controlled by digital inputs virtual inputs mimic display communication logic and manually U0sblock Start Event register Trip Event register Blocking Setting Release Delay Enable Uo gt s delay events Figure 5 16 1 Block diagram of the zero sequence voltage stages U gt and Up gt gt V210 EN M A011 103 5 16 Zero sequenc
260. rmer if any UnBB e Rated generator side voltage of the unit transformer if any UnGS UNITS FOR MIMIC DISPLAY e Unit for voltages 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 V210 EN M A011 Operation and configuration 2 Local panel user interface 2 4 Configuration and parameter setting V210 EN M A011 DEVICE INFO Relay type Type VAMP 210 Serial number SerN Software version PrgVer 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 da dd nn yyyy and mm dd yyyy CLOCK SYNCHRONISATION e Digital input for minute sync pulse SyncDI If any digital input is not used for synchronization select Daylight saving time for NTP synchronization DST Detected source of synchronization SyScr Synchronization message counter MsgCnt 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 e Average drift direction AvDrft Lead or lag e Average synchronization deviation FilDev 39 2 4 Configuration and parameter 2 Local panel user interface Operation and configuration instructions set
261. rol 0 or 1 of the Trip relays o Forced control 0 or 1 of the Alarm relays o Forced control 0 or 1 of the IF relay e The 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 36 V210 EN M A011 Operation and configuration 2 Local panel user interface 2 4 Configuration and parameter setting 2 4 6 2 4 7 V210 EN M A011 Protection menu Prot The following functions can be read and set via the submenus of the Prot menu e Reset all the counters PROTECTION SET CIAII e Read the status of all the protection functions PROTECT STATUS 1 x e Enable and disable protection functions ENABLED STAGES 1 x e Define the interlockings between signals 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 The following functions and features can be read and set via the submenus of the configuration menu DEVICE SETUP e Bit rate for the
262. rom the V210 EN M A011 Technical description 6 Supporting functions 6 8 Circuit breaker condition monitoring figure above The table is edited with VAMPSET under menu BREAKER CURVE Point Interrupted current Number of permitted kA 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 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 e Operations left alarm limit An alarm is activated when there are less operation 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 p
263. rse 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 chapter 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 Stage 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 1 Standard delays Using standard delay characteristics by selecting a curve family IEC IEEE IEEE2 Rl and a delay type Normal inverse Very inverse etc See chapter 5 29 1 2 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 setting delay type to Parameters and then editing the delay function parameters A E See chapter 5 29 2 3 Fully programmable inverse delay characteristics Building the characteristics by settin
264. ry Voltage measurement mode is 3LN VT 12000 110 Three phase symmetric voltages connected to the relay s inputs Ua Ub and Uc are 57 7 V gt Primary voltage is Upri V3x58x12000 110 10902 V Example 3 Primary to secondary Voltage measurement mode is 2LL Uo VT 12000 110 The relay displays Upri 10910 V gt Secondary voltage is Usec 10910x110 12000 100 V Example 4 Primary to secondary Voltage measurement mode is 3LN VT 12000 110 The relay displays U12 U23 Us 10910 V Symmetric secondary voltages at Ua Up and U are Usec 10910 V3x110 12000 57 7 V 205 7 10 Primary secondary and per unit 7 Measurement functions Technical description scaling 206 Per unit pu scaling of line to line voltages One per unit 1 pu 1xUgn 100 where Uan rated voltage of the generator Line to line voltage scaling Voltage measurement mode Voltage measurement mode 3LN 2LL Uo secondary gt per oe U sec VT pri U J3 U sec i VT prr anit Ye U Vi ess U SEC GN SEC GN per unit gt U U VT U on U i ee WP ssc i U on secondar SEC PU SEC SEC PU y VT err V3 VT pri Example 1 Secondary to per unit Voltage measurement mode is 2LL Uo VT 12000 110 Ucn 11000 V Voltage connected to the relay s input Ua or Up is 100 8 V Per unit voltage is Upu 100 8 110x12000 11000 1 00 pu 1 00xUen 100 Example 2
265. ry 20 ms V210 EN M A011 159 6 2 Disturbance recorder 6 Supporting functions Technical description Running virtual comtrade files with VAMP relays Virtual comtrade files can be run with VAMP relays with the v 10 74 software or a later version Relay behaviour can be analysed by playing the recorder data over and over again in the relay memory Steps of opening the VAMPSET setting tool 1 Go to Disturbance record and select Open A 2 Select the comtrade file from you hard disc or equivalent VAMPSET is now ready to read the recording 3 The virtual measurement has to be enabled B in order to send record data to the relay C 4 Sending the file to the relay 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 Blelo c P Bev itual measurement Be EE ee JEMTDC_Simulation 1 Show AVG z an RMS Reading record file Show MIN m tor STITT T Sending record data to device 078 1515457 mem C47F26 FD F4 FE O4 FE 12 FE OC FE 1A FE 16 FE 00 FEOS TD a Enable vitual measurement a C Protected target VAMP 52 Frequency 50 000 Hz Repeats 7 Note The sample rate of the comtrade file has to be 32 cycle 625 os when 50 Hz is used The channel names have to correspond to the channel names in Vamp rela
266. s vamp210appl_1 Figure 10 1 1 Generator connected directly to the distribution busbar Earthed generator neutral The device is suitable for use in directly earthed high low resistance earthed and isolated systems The differential and directional earth fault protection provides a sensitive and selective protection solution in high resistance earthed and isolated systems In directly earthed or low resistance earthed systems the non directional earth fault stage constitutes a sufficiently selective earth fault protection when energized from two current transformers forming a differential current connection The rotor earth fault protection can be realized with the non directional earth fault stage using the energizing current input lo2 in combination with a simple current injection device for example type VEO MSV V210 EN M A011 235 10 2 Directly connected generator 10 Applications Technical description with unearthed generator neutral 10 2 Directly connected generator with unearthed generator neutral Protection function 50 51 67 51V 3 gt 3 gt gt gt 3p gt 3b gt 46 ap gt gt ia 3b gt gt 50N 51N gt 3P gt gt gt 49 T gt 37 u gt gt gt gt gt 81H 81L
267. s true 8 Vdc in front panel port of VAMP relays Fast Fourier transform Algorithm to convert time domain signals to frequency domain or to phasors l e dead band Used to avoid oscillation when comparing two near by values Another name for pick up setting value I gt Another name for pick up setting value Ip gt Nominal current of the Io input of the relay Nominal current of the loz input of the relay Nominal current of lo input in general Nominal current of the protected device Nominal current Rating of CT primary or secondary International Electrotechnical Commission An international standardization organisation Institute of Electrical and Electronics Engineers Abbreviation for communication protocol defined in standard IEC 60870 5 103 Local area network Ethernet based network for computers and relays V210 EN M A011 Technical description 13 Abbreviations and symbols 12 4 Supporting functions Latching NTP PF Pu PT pu Un Us Uc Uan Un UTC VT VTPRI VTsec WWW V210 EN M A011 Output relays and indication LEDs can be latched which means that they are not released when the control signal is releasing Releasing of lathed devices is done with a separate action Network time protocol for LAN and WWW Active power Unit W Power factor The absolute value is equal to cos but the sign is for inductive i e lagging current and for capacitive i e leading curr
268. sed time of the operating time setting 100 trip SetGrp 1 Active setting group during fault 2 Under impedance protection Z lt 21 Under impedance protection can be used to detect near short circuit faults even when excitation of the generator collapse thus limiting the available short circuit current It is an alternative for the voltage restrained overcurrent protection chapter 5 6 When the generator s short circuit current capacity is limited any high set overcurrent stage might not pick up but an under impedance stage will still detect the fault The stage is sensitive to positive sequence impedance Z4 which is calculated using the equation U Z where L Z absolute value of positive sequence impedance U positive sequence voltage l positive sequence current UnderlmpedanceZplane cap R A ind jx MINI PA 0UMUy 0 w Loy ba ZO KN er j WAE PRY s NORMAL OPERATION AREA OF THE GENERATOR R ind cap Figure 5 20 1 The trip region of under impedance stage is a circle in origin The radius Z lt is the setting value The bigger circle stator limit represents the rated power of the generator The impedance relay is insensitive to the phase angle between current and voltage Its characteristics in an impedance plane is a circle in origin where the horizontal axis represents resistance R and the vertical axis represents reactance jX Figure 5
269. set for trip area origin Set in pu Ros ohm Resistive offset for trip area origin in primary ohms Xos xZn Reactive offset for trip area origin in primary ohms For details of setting ranges see chapter 12 3 Set An editable parameter password needed C Can be cleared to zero F Editable when force flag is on V210 EN M A011 125 5 23 Reverse power and under 5 Protection functions Technical description power protection P lt 32 23 126 Recorded values of the latest eight faults There are detailed information available of the eight latest earth faults Time stamp fault impedance fault angle elapsed delay and setting group Recorded values of the under reactance stages X lt X lt lt 40 Parameter Value Unit Description yyyy mm dd Time stamp of the recording date hh mm ss ms Time stamp time of day Fit Zn Fault impedance Angle R Fault angle EDly Elapsed time of the operating time setting 100 trip SetGrp 1 Active setting group during fault 2 Reverse power and under power protection P lt 32 Reverse power function can be used for generators against motoring to protect the prime mover against over speeding or to disconnect a motor in case the supply voltage is lost and thus prevent any power generation by the motor Under power function can be used to detect loss of the mechanical load of a motor Reverse and under power function is sensi
270. setting extended Data points added to DNP3 0 and IEC 60870 5 101 protocols Protocol menus visible in Vampset only if protocol is selected into use to a port Corrections and additions to IEC 60870 5 101 DNP 3 0 Profibus and Modbus slave and TCP protocols DeviceNET protocol support added DCF 77 time syncronisation support added 291 16 Revision history Operation and configuration instructions 292 6 71 Phase voltage and power measurement corrections Synchrocheck correction in voltage mode 2LL Ly Second harmonics stage added Data points added to DNP3 0 IEC 60870 5 101 and Modbus slave and TCP protocols RMS mode added and Operation delay setting extended for I gt gt Transient Intermittent 67NI protection function improvements Operation delay min setting reduced 10 38 First release with new CPU Older versions of VAMPSET parameter files are not compatible with 10 x firmware Native IEC61850 support including GOOSE added DeviceNET protocol support added UTF 8 support for local HMI panel Russian added RTD Inputs Quick Setup support added for VIO 12Ax EthernetIP added Improvements added to DNP3 0 IEC 60870 5 101 protocols 10 45 NVRAM event buffer size is user parameter 10 48 Support for HMS Profibus solution IRIG BOO3 10 49 Polarity added for relays Read write MAC address to from EEPROM with new chip IEC61850 DI counters are reported via de
271. setting group Recorded values of the reverse under power stages 8 latest faults P lt P lt lt 32 Parameter Value Unit Description yyyy mm dd Time stamp of the recording date hh mm ss ms Time stamp time of day Flt xPm Minimum power EDly Elapsed time of the operating time setting 100 trip SetGrp 1 Active setting group during fault 2 129 5 24 Second harmonic O C stage 5 Protection functions Technical description If2 gt 51F2 5 24 130 Second harmonic O C stage I2 gt 51F2 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 ensure a proper blocking Setting Delay Enable events 2 Harm Figure 5 24 1 Block diagram of the second harmonic stage Setting parameters of second harmonic blocking 2 Ha 51F2 Parameter Value Unit Default Description If2 gt 10 100 10 Setting value If2 lfund t_f2 0 05 300 0 s 0 05 Definite operating time S_On Enabled E
272. steresis 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 l Figure 5 3 3 Behaviour of a greater than comparator For example in overcurrent and overvoltage stages the hysteresis dead band acts according this figure V210 EN M A011 Technical description 5 Protection functions 5 4 Overcurrent protection I gt 50 51 5 4 V210 EN M A011 Hysteresis_LT hysteresis l K PICK UP LEVEL lt PICK UP l Figure 5 3 4 Behaviour of a less than comparator For example in under voltage and under frequency stages the hysteresis dead band acts according this figure Overcurrent protection l gt 50 51 Overcurrent protection is used against short circuit faults and heavy 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 Three independent stages There are three separately adjustable overcurrent stages I gt I gt gt and I gt gt gt The first stage l gt can be configured f
273. synchronism The under excitation protection protects the generator against the risk of lost of synchronism When the generator produces capacitive power that is when the reactive component of the power phasor is negative the excitation current can be so low that the synchronism is lost This stage supervises the amount of capacitive power and in case it exceeds the setting a start signal is issued If the fault continues longer than user s operation delay time setting a trip signal is issued The measurement of the degree of excitation is based ona complex three phase power vector which is calculated from the fundamental components of the phase currents and line to line voltages Trip area on a PQ plane The tripping area of the under excitation stage on a PQ plane is defined with two parameters Q1 and Q2 see Figure 5 21 1 and Figure 5 21 2 When the tip of the power phasor lies on the left side of the left side of a straight line drawn through Q1 and Q2 and on the negative side of P axis the stage picks up The P coordinate of the setting point Q1 has a fixed value equal to zero and the Q coordinate is adjustable The P coordinate of the setting point Q2 has a fixed value of 80 of the rated power of the generator and the Q coordinate is adjustable 119 5 21 Under excitation protection Q lt 5 Protection functions Technical description 40 120 P P Q Circlel Figure 5 21 1 Setting of the under excitation st
274. t EDly Elapsed time of the operating time setting 100 trip SetGrp 1 Active setting group during fault 2 5 10 Directional earth fault protection log gt 67N The directional earth fault protection is used for generator s stator earth faults in networks where a selective and sensitive earth fault protection is needed and in applications with varying network structure and length The relay consists of versatile protection functions for earth 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 l and Uo and the phase angle between Ip and Uo 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 setting a trip signal is issued Polarization The negative zero sequence voltage Uo is used for polarization i e the angle reference for Io This Uo voltage is measured via energizing input Uo or it is calculated from the phase voltages internally depending on the selected voltage measurement mode see chapter 7 6 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 volta
275. t 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 and generator name plate values The following scaling equations are useful when doing secondary testing 7 10 1 Current scaling NOTE The rated value of the relay s current input 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 See chapter 12 1 1 for details Primary and secondary scaling Current scaling CT prr secondary primary ppp Isc CT sc ve CT src primary secondary J op 1 pp CT pri For residual currents to inputs lo1 or lo2 use the corresponding CTpri and CTgec values For earth fault stages using locaic Signals use the phase current CT values for CTpri and CTsec Example 1 Secondary to primary CT 500 5 Current to the relay s input is 4 A Primary current is Iprpi 4x500 5 400 A Example 2 Primary to secondary CT 500 5 The relay displays lpr 400 A gt Injected current is Isec 400x5 500 4 A 202 V210 EN M A011 Technical description 7 Measurement functions 7 10 Primary secondary and per V210 EN M A011 unit scaling Per unit pu scali
276. t 50 ms Reset ratio 0 97 Transient over reach any t lt 10 Inaccuracy Starting 3 of the set value or 5 mA secondary Operation time 1 or 25 ms This is the instantaneous time i e the minimum total operational time including the fault detection time and operation time of the trip contacts V210 EN M A011 273 12 3 Protection functions 12 Technical data Technical description Directional overcurrent stages lair gt and lair gt gt 67 Pick up current 0 10 4 00 x len Mode Directional non directional Minimum voltage for the direction solving 0 1 V secondary Base angle setting range 180 to 179 Operation angle 88 Definite time function Operating time DT 0 06 300 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 RXIDG IEEE and IEEE2 Start time Typically 60 ms Reset time lt 95 ms Retardation time lt 50 ms Reset ratio 0 95 Reset ratio angle 2 Transient over reach any t lt 10 Inaccuracy Starting Angle Operate time at definite time function Operate time at IDMT function 3 of the set value or 0 5 of the rated value 2 U gt 5 V 30 U gt 0 1 V 1 or 30 ms 5 or at least 30 ms This is the instantaneous time i e the mini
277. t situation remains on longer than the user s operation time delay setting a trip signal is issued Blocking during VT fuse failure 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 failure See VT supervision function in chapter 6 7 The blocking signal can also be a signal from the user s logic see chapter 8 7 Self 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 15 to the blocking action to be enough fast The self blocking can be disabled by setting the low voltage block limit equal to zero V210 EN M A011 99 5 15 Undervoltage protection U lt 27 5 Protection functions Technical description Figure 5 15 1 shows an example of low voltage self blocking A The maximum of the three line to line voltages ULLmax iS below the block limit This is not regarded as an under voltage situation The voltage Uttmin is above the block limit but below the pick up level This is an undervoltage situation Voltag
278. t 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 31 2 3 Operating measures 2 Local panel user interface Operation and configuration instructions 2 3 4 Forced control Force In some menus it is possible to switch a signal on and off by using a force function This feature can be used for instance 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 Chapter 2 4 on page 33 2 Select the Force function the background color of the force text is black VAMP 210 force Pick RELAY OUTPUTS 1 Enable forcing T1 0 0 0 0 0 0 0 F Figure 2 3 4 1 Selecting Force function 3 Push Oa 4 Push or to change the OFF text to ON that is to activate the Force function 5 Push to return to the selection list Choose the signal to be controlled by force with and v for instance the T1 signal 6 Push to confirm the selection Signal T1 can now be controlled by force 7 Push or to change the selection from 0 not alert to 1 alert or vice versa 8 Push to execute the forced control operation of the selected function e g making the output relay of T1 to pick up 9 Repeat the steps 7 and 8 to alternate between the on and off state of the function 10 Repeat the steps 1 4
279. t_ylivirtaporras ly 100xly gt ly 0 20x1 gt pf 4 U 0 2 Uy 0 8 1 Figure 5 6 1 Characteristics of a voltage restrained overcurrent function ly gt When the generator pole voltage falls below the set voltage level the start current level of the overcurrent stage ly gt also starts falling linearly controlled by the voltage according to the characteristic curve in Figure 5 6 1 When the setting parameters are selected according to Figure 5 6 2 the function is said to be voltage controlled NOTE The overcurrent function can be used as a normal high set overcurrent 64 stage I gt gt gt if IY1 and IY2 are set to 100 r Uohj_ylivirtaporras K gt Iy 1 00 x I gt Iy 0 20 x I gt Ux Ux 0 4 Un Figure 5 6 2 Voltage controlled overcurrent characteristics The voltage setting parameters Ux and Ux2 are proportional to the rated voltage of the generator They define the voltage limits within which the start current of the overcurrent unit is restrained The multipliers ly and ly2 are used for setting the area of change of the start level of the overcurrent function in proportion to the Ux and Ux settings The voltage restrained controlled overcurrent stage operates with definite time characteristic The start current ly gt and the operating time t gt can be set by the user V210 EN M A011 Technical description 5 Protection functions 5 6 Voltage restrained contr
280. tal input is in active state when the trip circuit is complete This is applicable for dry inputs DI7 DI20 V210 EN M A011 239 10 4 Trip circuit supervision 10 Applications Technical description V ux 24 Vdc 240 Vdc VAMP relay ss a as eve F Alarm relay for trip circuit failure Trip Circuit failure alarm relay compartment circuit breaker compartment close control ee eee ee ee TCS1Dlopen Figure 10 4 1 2 Trip circuit supervision using a single dry digital inout when the circuit breaker is in open position Note If for example DI7 is used for trip circuit supervision the usage of DI8 DI14 is limited to the same circuitry sharing the V aux in the common terminal DIGITAL INPUTS DIGITAL INPUTS Figure 10 4 1 3 An example of digital input DI7 configuration for trip circuit supervision with one dry digital input 240 V210 EN M A011 Technical description 10 Applications 10 4 Trip circuit supervision OUTPUT MATRIX T4 T2 T3 T4 Af A2 connected connected and latched A DI V210 EN M A011 Figure 10 4 1 4 An example of output matrix configuration for trip circuit supervision with one dry digital input Example of dimensioning the external resistor R Uaux 110 Vdc 20 10 Auxiliary voltage with tolerance Up 18 Vdc Threshold voltage of the digital input lpi 3 mA Typical current needed to activate the digital input including a 1 mA safety margin Poot SOW R
281. tarting time lt 100 ms Reset time lt 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 20 mHz starting LV block 3 of the set value or 0 5 V operating time 1 or 30 ms Suitable frequency area for low voltage blocking is 45 65 Hz Low voltage blocking is checking the maximum of line to line voltages This is the instantaneous time i e the minimum total operational time including the fault detection time and operation time of the trip contacts NOTE f lt 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 visit above the set limit Underfrequency stages f lt and f lt lt Frequency measuring area 16 0 75 0 Hz Current and voltage meas range 45 0 65 0 Hz Frequency stage setting range 40 0 64 0 Hz Low voltage blocking 10 100 Uen Definite time function operating time 0 10 300 0 s step 0 02 s Undervoltage blocking 2 100 Starting time lt 100 ms Reset time lt 120 ms Reset ratio 1 002 Reset ratio LV block Instant no hysteresis Inaccuracy starting 20 mHz starting LV block 3 of the set value or 0 5 V operating time 1 or 30 ms Suitable frequency area for low voltage blocking is 45 65 Hz Low
282. tead in case the clock is leading it is softly slowed down to maintain causality 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 The digital input used for clock ne synchronisation DI not used for synchronizing DI1 DIG Minute pulse input TZone 12 00 UTC time zone for SNTP Set 14 00 synchronization Note This is a decimal number For example for state of Nepal the time zone 5 45 is given as 5 75 DST No Daylight saving time for SNTP Set Yes Parameter Value Unit Description Note V210 EN M A011 179 6 10 System clock and synchronization 6 Supporting functions Technical description 180 SySrc Clock synchronisation source Internal No sync recognized since 200 s DI Digital input SNTP Protocol sync SpaBus Protocol sync ModBus Protocol sync ProfibusDP Protocol sync IEC 103 Protocol sync DNP3 Protocol sync MsgCnt 0 65535 The number of received 0 etc synchronisation messages or pulses Dev 32767 ms Latest time deviation between the system clock and the received synchronization SyOS 10000 000 s Synchronisation correction for Set any constant error in the synchronizing source A positive value will compensate a lagging external sync and
283. tep 0 01 s This is the instantaneous time i e the minimum total operational time including the fault detection time and operation time of the trip contacts Transformer supervision Current transformer supervision Pick up current 0 00 10 00 x In Definite time function DT Operating time 0 06 600 00 s step 0 02 s Reset time lt 60 ms Reset ratio Imax gt 0 97 Reset ratio Imin lt 1 03 Inaccuracy Activation 3 of the set value Operating time at definite time function 1 or 30 ms V210 EN M A011 Technical description 12 Technical data 12 4 Supporting functions 12 4 4 12 4 5 V210 EN M A011 Voltage transformer supervision Pick up setting U2 gt 0 0 200 0 Pick up setting 12 lt 0 0 200 0 Definite time function DT Operating time 0 06 600 00 s step 0 02 s Reset time lt 60 ms Reset ratio 3 of the pick up value Inaccuracy Activation U2 gt Activation l2 lt Operating time at definite time function 1 unit 1 unit 1 or 30 ms Voltage sags amp swells Voltage sag limit 10 120 Voltage swell limit 20 150 Definite time function DT Operating time 0 08 1 00 s step 0 02 s Low voltage blocking 0 50 Reset time lt 60 ms Reset ration Sag 1 03 Swell 0 97 Block limit 0 5 V or 1 03 3 Inaccuracy Activation 0 5 V or 3 of the set
284. the active Set setting group S None Dix Digital input Vix Virtual input LEDx LED indicator signal vox Virtual output Force Off Force flag for status forcing for Set On test purposes This is a common flag for all stages and output relays too Automatically reset by a 5 minute timeout ILmax A The supervised value Max of IL1 IL2 and IL3 lp gt gt gt gt A Pick up value scaled to primary lp gt gt gt gt gt value lp gt gt gt gt xIgn Pick up setting Set lp gt gt gt gt gt t gt gt gt s Definite operation time for Set t gt gt gt gt definite time only Mode Dir Directional 67 Set Undir Undirectional 50 51 Offset 2 Angle offset in degrees Set S Measured power angle U1 Un Measured positive sequence voltage For details of setting ranges see chapter 12 3 Set An editable parameter password needed C Can be cleared to zero F Editable when force flag is on Recorded values of the latest eight faults There are detailed information available of the eight latest faults Time stamp fault type fault current load current before the fault elapsed delay and setting group 62 V210 EN M A011 Technical description 5 Protection functions 5 6 Voltage restrained controlled overcurrent function IV gt 51V 5 6 V210 EN M A011 Recorded values of the directional overcurrent stages 8 latest faults lair gt lair gt gt lair gt gt gt lair gt gt gt gt 67
285. the rated generator current this delay is enabled The idea is to avoid purposeless alarms when the generator circuit breaker is open and the excitation is switched off By setting the delay equal to zero this feature is disabled Two independent stages There are two separately adjustable stages U lt and U lt lt Both stages can be configured for definite time DT operation characteristic 97 5 14 Undervoltage protection U1 lt 27P 5 Protection functions Technical description 98 Setting groups There are two settings groups available for both stages Switching between setting groups can be controlled by digital inputs virtual inputs mimic display communication logic and manually Parameters of the under voltage stages U lt U lt lt 27P Parameter Value Unit Description Note Status Current status of the stage Blocked Start F Trip F SCnir Cumulative start counter C TCntr Cumulative trip counter C SetGrp 1 or2 Active setting group Set SGrpDI Digital signal to select the active Set setting group z None Dix Digital input Vix Virtual input LEDx LED indicator signal VOx Virtual output Force Off Force flag for status forcing for Set On test purposes This is a common flag for all stages and output relays too Automatically reset by a 5 minute timeout U1 V The supervised positive sequence voltage in primary volts U1 The supervised positive seque
286. ting 2 4 8 40 Protocol menu Bus There are three communication ports in the rear panel In addition there is a connector in the front panel overruling the local port in the rear panel REMOTE PORT X5 e Communication protocol for remote port X5 Protocol e Message counter Msg This can be used to verify that the device is receiving messages e Communication error counter Errors e 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 pins 2 3 and 5 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 Communication error counter Errors e 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 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
287. tion 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 unit pu values for pick up setting are based on the current transformer values Arcl gt 1 pu 1xly rated phase current CT value Arclo1 gt 1 pu 1Xlo1n rated residual current CT value for input lot Arcloz gt 1 pu 1Xlo2n rated residual current CT value for input loo V210 EN M A011 Technical description 5 Protection functions 5 28 Arc fault protection 50ARC 50NARC optional V210 EN M A011 Parameters of arc protection stages Arcl gt ArcloiA Arclo2 gt 50 ARC 50NARC Parameter Value Unit Description Note Status Current status of the stage Start Light detected according Arclin F Trip Light and overcurrent detected F LCntr Cumulative light indication C counter S1 S2 or BI SCntr Cumulative light indication C counter for the selected inputs according parameter Arclin TCntr Cumulative trip counter C Force Off Force flag for status forcing for Set On test purposes This is a common flag for all stages and output relays too Automatically reset by a 5 minute timeout Value of the supervised signal ILmax Stage Arcl gt lo1 Stage Arclo gt lo2 Stage Arclos gt Arcl gt pu Pick up setting xin Set Arclo1 gt pu
288. tion yyyy mm dd Time stamp of the recording date hh mm ss ms Time stamp time of day Fit pu Maximum earth fault current EDly Elapsed time of the operating time setting 100 trip Angle 2 Fault angle of Ip Up 0 Uo Max Up voltage during the fault SetGrp 1 Active setting group during fault 2 Intermittent transient earth fault protection loint gt 67NI NOTE This function is available only in voltage measurement modes which include direct U measurement like for example 2U Up but not for example in mode 3U y The directional intermittent transient earth 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 lFaut and the fault duration is typically only 0 1 ms 1 ms Such short intermittent faults can not be correctly recognized by normal directional earth fault function using only the fundamental frequency components of lo and Up Although a single transient fault usually self extinguishes within less than one millisecond in most cases a new fault happens when the phase to earth voltage of the faulty phase has recovered Figure 5 11 1 1 The voltage measurement modes are described in a separate chapter 85 5 11 Intermittent transient earth fault 5 Protection functions Technical description protection IOINT gt 67NI 86 E
289. tion of phase current IL2 THDIL3 I HARM DISTORTION Total harmonic distortion of phase current IL3 Diagram I HARMONICS of IL1 Harmonics of phase current IL1 see Figure 2 3 2 1 Diagram I HARMONICS of IL2 Harmonics of phase current IL2 see Figure 2 3 2 1 29 2 3 Operating measures 2 Local panel user interface Operation and configuration instructions Value Menu Submenu Description Diagram I HARMONICS of IL3 Harmonics of phase current IL3 see Figure 2 3 2 1 Uline U LINE VOLTAGES Average value for the three line voltages V U12 U LINE VOLTAGES Phase to phase voltage U12 V U23 U LINE VOLTAGES Phase to phase voltage U23 V U31 U LINE VOLTAGES Phase to phase voltage U31 V UL U PHASE VOLTAGES Average for the three phase voltages V UL1 U PHASE VOLTAGES Phase to earth voltage UL1 V UL2 U PHASE VOLTAGES Phase to earth voltage UL2 V UL3 U PHASE VOLTAGES Phase to earth voltage UL3 V Uo U SYMMETRIC Residual voltage Uo VOLTAGES U1 U SYMMETRIC Positive sequence voltage VOLTAGES U2 U SYMMETRIC Negative sequence voltage VOLTAGES U2 U1 U SYMMETRIC Negative sequence voltage related to VOLTAGES positive sequence voltage THDU U HARM DISTORTION Total harmonic distortion of the mean value of voltages THDUa_ U HARM DISTORTION Total harmonic distortion of the voltage input a
290. tive to active power 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 Scaling of pick up setting The pick up setting is proportional to the nominal power of the prime mover parameter Pm which is part of the basic configuration V210 EN M A011 Technical description 5 Protection functions 5 23 Reverse power and under power protection P lt 32 ReversePowerPQplane NORMAL ie OPERATION AREA OF THE end GENERATO 1m I u a m 5 m o lt lt J u JE 2 p ZZ on Lo m g JE i s O ml g STABILITY LIMIT i I i I ind i cap P A 7 Figure 5 23 1 Characteristics of reverse power function Reverse power For reverse power protection a negative pick up value is used Figure 5 23 1 V210 EN M A011 127 5 23 Reverse power and under 5 Protection functions Technical description power protection P lt 32 UnderPowerPQplane NORMAL 15 OPERATION Z ind ER ANA Figure 5 23 2 Characteristics of under power function cap Under power When the pick up value is positive the function is called under power Figure 5 23 2 Two independent stages There are two separately adjustable stages available P lt and P lt lt Setting groups There are two settings groups available Switching between setting groups can be controlled by digital
291. tor ResCap Base angle setting range 180 to 179 Operation angle 88 10 170 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 EI VI NI LTI MI depends on the family 0 05 20 0 except 0 50 20 0 for RXIDG IEEE and IEEE2 Start time Reset time Reset ratio Reset ratio angle Typically 60 ms lt 95 ms 0 95 20 Inaccuracy Starting Uo amp lo rated value In 1 5A Starting Uo amp lo Peak Mode when rated value lon 1 10A Starting Up amp lo locaic Angle Operate time at definite time function Operate time at IDMT function 3 of the set value or 0 3 of the rated value 5 of the set value or 2 of the rated value Sine wave lt 65 Hz 3 of the set value or 0 5 of the rated value 2 when U gt 1V and lo gt 5 of lon else 20 1 or 30 ms 5 or at least 30 ms El Extremely Inverse NI Normal Inverse VI Very Inverse LTI Long Time Inverse Ml Moderately Inverse The measuring range may limit the scope of inverse delays See chapter 5 29 for details 277 12 3 Protection functions 12 Technical data Technical description Voltage protection Overvoltage stages U gt U gt gt and U gt gt gt 59 Overvoltage setting range U gt U gt
292. transferring event information to a SCADA system After testing the force flag will automatically reset 5 minute after the last local panel push button activity The force flag also enables forcing of the output relays and forcing the optional mA outputs Start 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 chapter 8 4 V210 EN M A011 Technical description 5 Protection functions 5 3 General features of protection stages V210 EN M A011 Blocking Any protection function except arc protection can be blocked with internal and external signals using the block matrix chapter 8 5 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 have also inbuilt blocking functions For example under frequency protection has inbuilt under voltage blocking to avoid tripping when the voltage is off When a protection stage is blocked it won t pick up in case of a fault condition is detected If blocking is activated during the operatio
293. ugate of the measured phase L2 fundamental frequency current phasor Measured voltage phasor corresponding the fundamental frequency voltage of phase L3 Complex conjugate of the measured phase L3 fundamental frequency current phasor Apparent power active power and reactive power are calculated similarly as with line to line voltages s s P real S Q imag S P cosp V210 EN M A011 Technical description 7 Measurement functions 7 8 Direction of power and current 7 8 V210 EN M A011 Direction of power and current Figure 7 8 1 shows the concept of three phase current direction and sign of cos and power factor PF Figure 7 8 2 shows the same concepts but on a PQ power plane 90 ind cap Reverse inductive power Forward capacitive power current is leading current is leading cos cosp PF PF cap ind Reverse capacitive power Forward inductive power current is lagging current is lagging COS cos PF PF Figure 7 8 1 Quadrants of voltage current phasor plane Q 90 lt cap ind Reverse capacitive power Forward inductive power current is lagging current is lagging cosm cos PF PF s pP o ind cap Reverse inductive power Forward capacitive power current is leading current is leading coso cos PF PF Figure 7 8 2 Quadrants of power plane Table of power quadrants Power Current P
294. used to ensure that the wiring from the protective device to a circuit breaker is in order This circuit is unused most of the time but when a protection device detects a fault in the network it is too late to notice that the circuit breaker cannot be tripped because of a broken 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 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 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 4 1 1 e The digital input is configured as Normal Closed NC e The digital input delay
295. ustry An external VPA 3CG or an internal Profibus module see the order code in chapter 15 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 The 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 more it is not possible to read continuously only one single data item At least two data items must be read in turn to get updated data from the device There is a separate manual for VPA 3CG available for the continuous mode and request mode 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
296. verse X MI Moderately inverse X X STI Short time inverse X STEI Short time extremely inverse X RI Old ASEA type X RXIDG Old ASEA type X 142 V210 EN M A011 Technical description 5 Protection functions 5 29 Inverse time operation V210 EN M A011 IEC inverse time operation The operation time depends on the measured value and other parameters according Equation 5 29 1 1 Actually this equation can only be used to draw graphs or when the measured value is constant during the fault A modified version is implemented in the relay for real time usage Equation 5 29 1 1 t Operation delay in seconds k Users multiplier Measured value Ipickup User s pick up setting A B Constants parameters according Table 5 29 1 2 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 29 1 2 Constants for IEC inverse delay equation p lav i Parameter elay type A B NI Normal inverse 0 14 0 02 El Extremely inverse 80 2 VI Very inverse 13 5 1 LTI Long time inverse 120 1 Example for Delay type Normal inverse NI k 0 50 4 pu constant current pickup 2pu A 0 14 B 0 02 ee 0 50 0 14 50 0 02 G 2 143 5 29 Inverse time operation 5 Protection functions Technical description
297. vertoap 1 05 Imax I 1 l 45 min Ip 0 85 Iy i l l Time 100 min 200 min 300 min 400 min 500 min Figure 5 8 2 Example of the thermal model behaviour V210 EN M A011 Technical description 5 Protection functions 5 8 Thermal overload protection T gt V210 EN M A011 49 Parameters of the thermal overload stage T gt 49 Parameter Value Unit Description Note Status Current status of the stage Blocked Start F Trip F Time hh mm s Estimated time to trip s SCntr Cumulative start counter C TCntr Cumulative trip counter C Force Off Force flag for status forcing for Set On test purposes This is a common flag for all stages and output relays too Automatically reset by a 5 minute timeout T Calculated temperature rise F Trip limit is 100 MaxRMS Arms Measured current Highest of the three phases Imax A kxIgn Current corresponding to the 100 temperature rise k gt xIgn Allowed overload service Set factor Alarm Alarm level Set tau min Thermal time constant Set ctau xtau Coefficient for cooling time Set constant Default 1 0 kTamb xIgn Ambient temperature corrected max allowed continuous current Imax40 lgn Allowed load at Tamb 40 C Set Default 100 Imax70 lgn Allowed load at Tamb 70 C Set Tamb C Ambient temperature Editable Set Samb n a Default 40 C Samb Sensor for ambient temperature n a No sensor in use for
298. wn a generator This undervoltage function measures the positive sequence of fundamental frequency component U4 of the measured voltages for calculation of U see chapter 7 9 By using positive sequence all the three phases are supervised with one value and in case the generator looses connection to the network loss of mains the undervoltage situation is detected faster than by using just the minimum of the three line to line voltages Whenever the positive sequence voltage U 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 failure 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 failure See VT supervision function in chapter6 7 The blocking signal can also be a signal from the user s logic see chapter 8 7 Self blocking at very low voltage The stages will be blocked when the voltage is below a separate low voltage blocking setting With this setting LVBlk both stages are blocked when the voltage U drops below the given limit The idea is to avoid purposeless alarms when the generator is not running The LVBIk setting is common for both stages The
299. x Figure 8 4 1 Output matrix 211 8 5 Blocking matrix 8 Control functions Technical description 8 5 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 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 5 1 an active blocking is indicated with a black dot in the crossing point of a blocking signal and the signal to be blocked NOTE The display show 20 Dis even only 6 of them are available Digital input 19 amp 20 are only available with DI19 DI20 option Output_mattx Output relays Operation LdbJbIbILILILIL indicators HHHHHHHH 8 amp 88 Block matrix S Relay matrix Reset all latches Figure 8 5 1 Blocking matrix and output matrix Digital Inputs 212 V210 EN M A011 Technical description 8 Control functions 8 6 Controllable objects 8 6 V210 EN M A011 Controllable objects The relay allows controlling of six objects that is circuit breakers disconnectors and earthing switches Controlling can be done by select execute or direct control principle The logic functions can be used to configure interlocking for a safe controlling 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
300. y includes a disturbance recorder Arc protection is optionally available The relay communicates with other systems using common protocols such as the Modbus RTU ModbusTCP Profibus DP IEC 60870 5 101 IEC 60870 5 103 IEC 61850 SPA bus Ethernet IP and DNP 3 0 1 2 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 remote control port on the relay rear panel 1 3 Operating Safety A WARNING HAZARD OF ELECTRIC SHOCK EXPLOSION OR ARC FLASH 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 Failure to follow these instructions can result in death serious injury or equipment damage V210 EN M A011 2 1 Relay front panel 2 Local panel user interface Operation and configuration instructions 2 Local panel user interface 2 1 Relay front panel The figure below shows as an example the front panel of the relay VAMP 210 and the location of the user interface elements used for local control VAMP 210 Scheider Figure 2 1 1 The front panel of VAMP 210 1 LCD dot matrix display 2 Keypad 3 LED
301. ys IL1 IL2 IL3 lo1 lo2 U12 U23 UL1 UL2 UL3 and Uo 160 V210 EN M A011 Technical description 6 Supporting functions 6 3 Cold load pick up and inrush current detection 6 3 V210 EN M A011 Cold load pick up and inrush current detection 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 Right 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 2 harm
302. z and normal overvoltage protection The volts hertz characteristics on the left depend on the frequency while the standard overvoltage function on the right is insensitive to frequency The network frequency 50 Hz or 60 Hz is automatically adopted by the relay 93 5 13 Volts hertz over excitation protection Uf gt 24 5 Protection functions Technical description 94 The setting for a certain V Hz value K can be calculated using the following formala U ser K where fy SEC 100 Uiser setting in per cent K secondary volts per hertz sensitivity fn rated network frequency VTsec rated secondary of the voltage transformer Example K 2 56 Vsec Hz fn 50 Hz VTsec 110 V U 2 56 gt 100 116 SEF imo 50 Parameters of the volts hertz over excitation stage U gt 24 Parameter Value Unit Description Note Status Current status of the stage Blocked Start F Trip F SCnir Cumulative start counter C TCntr Cumulative trip counter C SetGrp 1or2 Active setting group Set SGrpDI Digital signal to select the active Set setting group None Dix Digital input VIX Virtual input LEDx LED indicator signal VOx Virtual output Force Off Force flag for status forcing for Set On test purposes This is a common flag for all stages and output relays too Automatically reset by a 5 minute timeout Umax V The supervised value Max of U12 U23

VAMP 210 manual - Schneider Electric België

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VAMP 210 manual - Schneider Electric Belgi&euml;

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VAMP 210 manual - Schneider Electric België