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Setting summary for RET670Station:Data:
Station CVoltage 415length km
ParameterGeneral settingsStation Name:Frequency
Beskrivning
Station No:Object Name:Object No:Unit Name:Unit No:
VoltageLength
System voltage
X1R1X0R0
Primary Line Positive Sequence ReactancePrimary Line Positive Sequence ResistancePrimary Line Zero Sequence ReactancePrimary Line Zero Sequence Resistance
VTPrimUphasesUrCTPrimIphasesIr
Voltage Transformer Primary VoltageVoltage Transformer Secondary VoltageCurrent Transformer Primary CurrentCurrent Transformer Secondary Current
CT EarthPhase SelectionX1
Direction of CT earthing
Phase selection Reactive reach
R+=R0=
Setting of Transformer protection terminal type RET670 v1.1Transformer: =T1 =T2 respectivelyFrequency:Rated data:
50 HzRated Power 500 MVA / 500 MVA /Voltage ratioTap changer +Wind 1 - Ir1Wind 2 - Ir2
415 kV9
//-
696 A 1255 A
230.0 kV9
/*
20 MVA20.0 kV
1.67 %
Connection Coolingp.u. Impedance
CT ratio Wind 1CT ratio Wind 2
at Base1000 /2000 /
YNyn0d1ONAF0.120
500 MVA1 A 1 A
VT ratio Wind 1VT ratio Wind 2
415230
//
0.110 kV0.110 kV
Transformer impedance R1 +R0 +
CT ratio
CVT ratio
1000 /
415 /
jX1 =jX0 =
1.316 +1.185 +
1 A
0.110 kV
Maximum load on line: 696 A ==> 344 ohm/ph
41.3 ohmj37.201 ohm
primary Export
1. Terminal identification
StationName: Station CStationNumber:ObjectName:Object Number:UnitName:
1Transformer=T1RET 670
UnitNumber:Relay serial NoFrequencyAux voltage
1A123450 Hz110.000 V
Project
Station C 400/230 kV S/S for ABB RET 670 CustomerApproved Resp. dept. Title Rev ind
Max DegerfaltPrepared
EngineerABB PTSX
TPADate
Setting of Transformer protection relay RET670
2005-11-11 500MVA 400/230 kV TransformerDocument No.
CSheet
1Cont
1MRK 504 083-WEN 33
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A
BB
PTS
XP
rinto
ut 2
007-
05-2
8
CBA
Rev No
Adjusted for RET 670 1.1 releaseAdjusted
MDMD
First issueDescription
MDAppd
2007-05-282006-07-052005-11-11Date
Project
Station C 400/230 kV S/S for ABB RET 670 CustomerApproved Resp. dept. Title Rev ind
Max DegerfaltPrepared
EngineerABB PTSX
TPADate
Setting of Transformer protection relay RET670
2005-11-11 500MVA 400/230 kV TransformerDocument No.
CSheet
2Cont
1MRK 504 083-WEN 33
Set analogue voltage channels.
Name: =Ch I7IN_400
Ch I8IN_230
Ch I9NotUsed
Ch U1UL1-W2
VTprimnVTsecn
==
1000.0001.0 A
2000.0001.0 A
1000.0001.0 A
230.0000.110 V
Ch U2UL2-W2
Ch U3UL3-W2
230.0000.110 V
230.0000.110 V
2. Setting of analogue and digital channels.Configure analogue inputs for TRM1:Set analogue current channels
Name:CTprimCTsec
===
Ch I1IL1-CB1
Ch I2IL2-CB1
1000.0001.0 A
1000.0001.0 A
Ch I3IL3-CB1
Ch I4IL1-CB2
1000.0001.0 A
2000.0001.0 A
Ch I5IL2-CB2
Ch I6IL3-CB2
2000.0001.0 A
2000.0001.0 A
CTStarPoint = Out Indicates the earthing towards object (Out) or towards busbar (In).
Set Digital IO boards
I/O Module 1 =OperationOn
OscBlock40
OscRelease30 Pos Slot3
I/O Module 2I/O Module 3I/O Module 4I/O Module 5
====
OnOn
4040
OnOn
4040
3030
Pos Slot3Pos Slot3
3030
Pos Slot3Pos Slot3
Note: OscBlock and OcscRel defines the filtering time at activation
3. Setting of the analogue preprocessing function blocks SMAI (General settings/Power system)Set ref for DFT filter adjustment:Set the measured minimum value:
DFTRefGrpnMeaMinValGrpn
==
Grp7AdDFTRef5%
set voltage L1 as ref
Set the connection typeSet negation of the function blockSet the base voltageFor first function block in each task time also
ConTypeGrpnNegGrpn
UBaseGrpn
==
Ph-NOff
= REF!
SYNCH output reference DFTRefExtOut
Note! Same settings are valid for all groups.
= Grp7AdDFTRef set voltage L1 as ref
Set analogue voltage channels.
Name: =Ch U1UL2_Bus1
Ch U2UL2-Bus2
Ch U3UL2 400B1
Ch U4UL2-400B2
VTprimnVTsecn
==
230.0000.110 V
230.0000.110 V
415.0000.110 V
415.0000.110 V
Ch U5UL2-L2
Ch U6Not used
415.0000.110 V
230.0000.110 V
Configure analogue inputs for TRM2:Set analogue current channels
Ch I1 Ch I2 Ch I3 Ch I4Name:CTprimCTsec
===
IL1_2302000.000
IL2-2302000.000
1.0 A 1.0 A
IL3-2302000.000
Not Used2000.000
1.0 A 1.0 A
Ch I5 Ch I6Not Used
2000.000Not Used
2000.0001.0 A 1.0 A
CTStarPoint = Out Indicates the earthing towards object (Out) or towards busbar (In).
Prin
tout
200
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-28
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PTS
X
Project
Station C 400/230 kV S/S for ABB RET 670 CustomerApproved Resp. dept. Title Rev ind
Max DegerfaltPrepared
EngineerABB PTSX
TPADate
Setting of Transformer protection relay RET670
2005-11-11 500MVA 400/230 kV TransformerDocument No.
CSheet
3Cont
1MRK 504 083-WEN 33
4b. Differential Protection Setting (T2D1) under Setting group:
Setting of minimum differential operating currentOperation = On
Setting of cross-over point between slope 1 and slope 2
Setting of slope 2 stabilisation, Slope 1 has fixed stabilization
IdMin =
EndSection1 =
0.25 *Ibase
1.25 Ibase
Setting of cross-over point between slope 2 and slope 3
Setting of slope 2 stabilisation
SlopeSection2 =
EndSection2 =
Setting of minimum differential operating current for unrestraint step
Set the operation of Cross Blocking logic On-Off
SlopeSection3 =
Idunre =
40% *Ibias
3.00 Ibase
80% *Ibias
10.00 *Ibase
Set the second and fifth harmonic stabilizing level when transformers are inside the zoneOpCrossBlock =
I2/I1RatioI5/I1Ratio
==
Set the operation of Negative sequence differential protection!
Setting of minimum negative sequence differential current levelOpNegSeqDiff =
IMinNegSeq =
On
15 %25 %
Yes
0.04 *IbaseSetting of the Relay operating angles.
NegSeqROA = 60
4a. Setting of the Differential function data under General settings.Winding 1 (W1)Connection type Y
Winding 2 (W2)Connection type Y
Rated Current W1TconfigForW1CT1ratingW1TraAWind1Volt
696 A Yes
1000 A 415.0 kV
Rated Current W2TconfigForW2
1255 A No
CT1ratingW2TraBWind1Volt
2000 A 230.0 kV
ZSCurrSubtrW3 On ZSCurrSubtrW2ClockNumTransfB
On12 relative W1, hour notation
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X
5a. Setting of Restricted Earth Fault function REF1Activation of the Short Circui function
Operation = OnSetting of the base current for the REF1 function
Set the minimum sensitivityIbase =
Idmin =
696 A
10 %Setting of the Characteristic angles for operation.
Set the factor for CT primary 1 rated current compared to the neutral CT.roa =
CtFactorPri1 =Set the factor for CT primary 2 rated current compared to the neutral CT.
Set the factor for CTsecond winding input 1 rated current compared to the neutral CT.CtFactorPri2 =
CtFactorSec1 =
60
1.0
1.0
1.0Set the factor for CTsecond winding input 2 rated current compared to the neutral CT.
CtFactorSec2 = 1.0
5b. Setting of Restricted Earth Fault function REF2Activation of the Short Circui function
Operation = OnSetting of the base current for the REF2 function
Set the minimum sensitivityIbase =
Idmin =
1255 A
10 %Setting of the Characteristic angles for operation.
Set the factor for CT primary 1 rated current compared to the neutral CT.roa =
CtFactorPri1 =Set the factor for CT primary 2 rated current compared to the neutral CT.
Set the factor for CTsecond winding input 1 rated current compared to the neutral CT.CtFactorPri2 =
CtFactorSec1 =
60
1.0
1.0
1.0Set the factor for CTsecond winding input 2 rated current compared to the neutral CT.
CtFactorSec2 = 1.0
Project
Station C 400/230 kV S/S for ABB RET 670 CustomerApproved Resp. dept. Title Rev ind
Max DegerfaltPrepared
EngineerABB PTSX
TPADate
Setting of Transformer protection relay RET670
2005-11-11 500MVA 400/230 kV TransformerDocument No.
CSheet
4Cont
1MRK 504 083-WEN 33Print
out 2
007-
05-2
8
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Setting of the tripping logic (TR01)Operation = On
Set the trip pulse length
Set the latching of the trip signal
Program =
tTripMin =
3ph
0.150 s
Set the internal activation of Lock-out output, else only activation of Lock-out input will create Lock-outTripLockout =
AutoLock =
Off
Off
Setting of the tripping logic (TR02)Operation = On
Set the trip pulse length
Set the latching of the trip signal
Program =
tTripMin =
3ph
0.150 s
Set the internal activation of Lock-out output, else only activation of Lock-out input will create Lock-outTripLockout =
AutoLock =
Off
Off
Setting of the tripping logic (TR03)Operation = On
Set the trip pulse length
Set the latching of the trip signal
Program =
tTripMin =
3ph
0.150 s
Set the internal activation of Lock-out output, else only activation of Lock-out input will create Lock-outTripLockout =
AutoLock =
Off
Off
Setting of the tripping logic (TR04)Operation = On
Set the trip pulse length
Set the latching of the trip signal
Program =
tTripMin =
3ph
0.150 s
Set the internal activation of Lock-out output, else only activation of Lock-out input will create Lock-outTripLockout =
AutoLock =
Off
Off
Setting of the tripping logic (TR05)Operation = On
Set the trip pulse length
Set the latching of the trip signal
Program =
tTripMin =
3ph
0.150 s
Set the internal activation of Lock-out output, else only activation of Lock-out input will create Lock-outTripLockout =
AutoLock =
Off
Off
Project
Station C 400/230 kV S/S for ABB RET 670 CustomerApproved Resp. dept. Title Rev ind
Max DegerfaltPrepared
EngineerABB PTSX
TPADate
Setting of Transformer protection relay RET670
2005-11-11 500MVA 400/230 kV TransformerDocument No.
CSheet
5Cont
1MRK 504 083-WEN 33Prin
tout
200
7-05
-28
Setting of the tripping matrix (TR01) used for the HV Bus CBOperation = On
Set the pulse length
Set th on delayPulseTime1 =
OnDelayTime1 =
0.150 s
0.000 s
PulseTime2
OnDelayTime2
= 0.150 s
= 0.000 s
PulseTime2 =
OnDelayTime2 =
0.150 s
0.000 sSet the off delay
OffDelayTime1 = 0.000 s OffDelayTime2 = 0.000 s OffDelayTime2 = 0.000 s
Setting of the tripping matrix (TR02) used for the HV Tie CBOperation = On
Set the pulse length
Set th on delayPulseTime1 =
OnDelayTime1 =
0.150 s
0.000 s
PulseTime2
OnDelayTime2
= 0.150 s
= 0.000 s
PulseTime2 =
OnDelayTime2 =
0.150 s
0.000 sSet the off delay
OffDelayTime1 = 0.000 s OffDelayTime2 = 0.000 s OffDelayTime2 = 0.000 s
Setting of the tripping matrix (TR03) used for the LV side CBOperation = On
Set the pulse length
Set th on delayPulseTime1 =
OnDelayTime1 =
0.150 s
0.000 s
PulseTime2
OnDelayTime2
= 0.150 s
= 0.000 s
PulseTime2 =
OnDelayTime2 =
0.150 s
0.000 sSet the off delay
OffDelayTime1 = 0.000 s OffDelayTime2 = 0.000 s OffDelayTime2 = 0.000 s
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Station C 400/230 kV S/S for ABB RET 670 CustomerApproved Resp. dept. Title Rev ind
Max DegerfaltPrepared
EngineerABB PTSX
TPADate
Setting of Transformer protection relay RET670
2005-11-11 500MVA 400/230 kV TransformerDocument No.
CSheet
6Cont
1MRK 504 083-WEN 33
Instantaneous overcurrent protection (IOC1) on 400 kV side phasesThe function is used with a reach less than 80% of the transformer at minimum source impedance.Setting of operation
Set the Base current for the function on which the current levels are basedOperation =
Ibase =
On
696 A Setting of operation mode
Operating level of the instantaneous O/C protectionOpMode =
IP>> =Set a multiplier at inrush used when the binary input is activated
StValMult =
1 out of 3
840% *Ibase
2.00
Instantaneous overcurrent protection (IEF1) on 400 kV side phasesThe function is used with a reach less than 80% of the transformer at minimum source impedance.Setting of operation
Set the Base current for the function on which the current levels are basedOperation =
Ibase =
On
696 A Operating level of the instantaneous O/C protection
Set a multiplier at inrush used when the binary input is activatedIN>> =
StValMult =
1200% *Ibase
2.00
Instantaneous overcurrent protection (IOC2) on 230 kV side phasesThe function is used with a reach less than 80% of the transformer at minimum source impedance.Setting of operation
Set the Base current for the function on which the current levels are basedOperation =
Ibase =
On
696 A Setting of operation mode
Operating level of the instantaneous O/C protectionOpMode =
IP>> =Set a multiplier at inrush used when the binary input is activated
StValMult =
1 out of 3
840% *Ibase
2.00
Instantaneous overcurrent protection (IEF2) on 230 kV side phasesThe function is used with a reach less than 80% of the transformer at minimum source impedance.Setting of operation
Set the Base current for the function on which the current levels are basedOperation =
Ibase =
On
696 A Operating level of the instantaneous O/C protection
Set a multiplier at inrush used when the binary input is activatedIN>> =
StValMult =
1200% *Ibase
2.00
Prin
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-28
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PTS
X
Project
Station C 400/230 kV S/S for ABB RET 670 CustomerApproved Resp. dept. Title Rev ind
Max DegerfaltPrepared
EngineerABB PTSX
TPADate
Setting of Transformer protection relay RET670
2005-11-11 500MVA 400/230 kV TransformerDocument No.
CSheet
7Cont
1MRK 504 083-WEN 33
Setting of Fuse Failure supervision function based on U0-I0, U2-I2 and dU-dI (FSD) for 230 VT fusesSetting of the operation for the Fuse failure supervision
Setting of the operating mode for the Fuse failure supervisionOperation =
OpMode =
On
OnSetting of the Base voltage level on which the voltage setting is based
Set the Base current for the function on which the current levels are basedUBase =
Ibase =Setting of the 3U0 (UZs) voltage required to give operation
Setting of the 3I0 (IZs) current which will block the fuse failure function3U0> =
3I0< =
230.0 kV
2000 A
20% *UBase
10% *IbaseSetting of the U2 (UNs) voltage required to give operation
Setting of the I2 (INs) current which will block the fuse failure function3U2> =
3I2< =Setting of the operation for the DU> and DI< measuring function
Setting of the DU> voltage required to give operationOperation DUDI =
DU> =
20% *UBase
10% *Ibase
Off
20% *UBaseSetting of the DI< current which will block the fuse failure function
Setting of the operate voltage for phase voltagesIPH> =
UPH> =Setting of the operate value for phase currents
Setting of the seal-in function On-Off giving seal-in of alarm until voltages are symmetrical and highDI< =
SEALIN =
10% *Ibase
70% *UBase
10% *Ibase
OnSet the voltage level for the seal-in of the function
Note! At operation symmetrical voltages (reset of DLD) is required to reset the FUSE function.Setting of the U< voltage
USealIn< =
Setting of under currentUDLD< =
IDLD< =
60% *UBase
60% *UBase
20% *Ibase
Prin
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PTS
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Station C 400/230 kV S/S for ABB RET 670 CustomerApproved Resp. dept. Title Rev ind
Max DegerfaltPrepared
EngineerABB PTSX
TPADate
Setting of Transformer protection relay RET670
2005-11-11 500MVA 400/230 kV TransformerDocument No.
CSheet
8Cont
1MRK 504 083-WEN 33
Setting of four step Earth fault overcurrent function (TEF1) on 400 kV side neutral
Activation of the earth fault function
Set the Base current for the function on which the current levels are based
Setting of the Base voltage level on which the directional polarizing voltage is based
Operation =
Ibase =
On
696 A
Setting of parameters for first stageSetting of the operating direction for the stage
UBase= =
DirMode1 =Setting of the operating characteristic
Setting of the operating current level in primary valuesCharacteristic1 =
IN1>' =
415.0 kV
NonDir
IEC NI
70 A
Set the current multiplier for IN1 valid at activation of input ENMULT
Set the definite time delay, when definite time characteristic has been selected
IN1> =
IN1Mult =
Set the back-up trip time delay multiplier for inverse characteristic
Set the Minimum operating time for inverse characteristic
t1 =
k1 =
10% *Ibase
2.00
0.30 s
0.20
Select the reset curve type for the inverse delay
Set the Reset time delay for definite time delayed function
t1Min =
ResetTypeCrv1 =
Set the release of Harmonic restraint blocking for the stage
Setting of parameters for second stage
tReset1 =
HarmRestrain1 =
0.30 s
Instantaneous
0.02 s
On
Setting of the operating direction for the stage
Setting of the operating characteristicDirMode2 =
Characteristic2 =Setting of the operating current level in primary values
Set the current multiplier for IN2 valid at activation of input ENMULT
IN2>' =IN2> =
Off
IEC NI
600 A 86% *Ibase
Set the definite time delay, when definite time characteristic has been selected
Set the back-up trip time delay multiplier for inverse characteristic
IN2Mult =
t2 =
Set the Minimum operating time for inverse characteristic
Select the reset curve type for the inverse delay
k2 =
t2Min =
2.00
0.30 s
0.20
0.30 s
Set the Reset time delay for definite time delayed function
Set the release of Harmonic restraint blocking for the stage
ResetTypeCrv2 =
tReset2 =
HarmRestrain2 =
Instantaneous
0.02 s
On
Prin
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Station C 400/230 kV S/S for ABB RET 670 CustomerApproved Resp. dept. Title Rev ind
Max DegerfaltPrepared
EngineerABB PTSX
TPADate
Setting of Transformer protection relay RET670
2005-11-11 500MVA 400/230 kV TransformerDocument No.
CSheet
9Cont
1MRK 504 083-WEN 33
Setting of parameters for third stageSetting of the operating direction for the stage
DirMode3 = OffSetting of the operating characteristic
Setting of the operating current level in primary valuesCharacteristic3 =
IN3> =
IEC NI
1200 A
Set the current multiplier for IN3 valid at activation of input ENMULT
Set the definite time delay, when definite time characteristic has been selected
IN3> =
IN3Mult =
Set the back-up trip time delay multiplier for inverse characteristic
Set the Minimum operating time for inverse characteristic
t3 =
k3 =
173% *Ibase
2.00
0.30 s
0.20
Select the reset curve type for the inverse delay
Set the Reset time delay for definite time delayed function
t3Min =
ResetTypeCrv3 =
Set the release of Harmonic restraint blocking for the stage
Setting of parameters for fourth stage
tReset3 =
HarmRestrain3 =
0.30 s
Instantaneous
0.02 s
On
Setting of the operating direction for the stage
Setting of the operating characteristicDirMode4 =
Characteristic4 =Setting of the operating current level in primary values
Set the current multiplier for IN4 valid at activation of input ENMULT
IN4> =IN4> =
Off
IEC NI
2000 A 288% *Ibase
Set the definite time delay, when definite time characteristic has been selected
Set the back-up trip time delay multiplier for inverse characteristic
IN4Mult =
t4 =
Set the Minimum operating time for inverse characteristic
Select the reset curve type for the inverse delay
k4 =
t4Min =
2.00
0.30 s
0.20
0.30 s
Set the Reset time delay for definite time delayed function
Set the release of Harmonic restraint blocking for the stage
ResetTypeCrv4 =
tReset4 =
Set of Direction, Harmonic blocking and SOTF functionalitySetting of the minimum neutral point polarizing voltage level for the directional funtion
HarmRestrain4 =
3U0>Dir =
Instantaneous
0.02 s
On
1.00 %*UbaseSet the relay characteristic angle, i.e. the angle between the neutral point voltage and current
Setting of the operating current level for the directional release. Note! Sensitivity at RCAAngleRCA =
IN>DirCmp =
-65 deg Normal zero sequence source angle at direct earthing
3% *Ibase
Prin
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-28
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Station C 400/230 kV S/S for ABB RET 670 CustomerApproved Resp. dept. Title Rev ind
Max DegerfaltPrepared
EngineerABB PTSX
TPADate
Setting of Transformer protection relay RET670
2005-11-11 500MVA 400/230 kV TransformerDocument No.
CSheet
10Cont
1MRK 504 083-WEN 33
Set the method of directional polarizing to be used
Setting of the minimum enutral current required for direction polarizingPolMethod = Voltage
Setting of the zero sequence source resistance generating the polarizing current in primary ohm
Setting of the zero sequence source resistance generating the polarizing current in primary ohm
IPolMin =
RNPol =
5.00 %*IBase
5.00 ohm
Enable the harmonic restraint measuring function
Setting of the harmonic content in IN current blocking level
XNPol =
HarmRestrain =
Set the harmonic seal-in blocking at parallel transformers on if problems are expected due to sympatetic inrush.
Set the current level to be blocked to seal-in the Harmonic blocking on this level if sympatetic inrush is expected.
2ndHarmStab =
BlockParTransf =
40.00 ohm
On
25% of I
Off
Set the SOTF function operating mode
Select the input signal which shall activate the SOTF function
UseStartVal =
SOTF =
Select the input signal which shall activate the undertime function
Select the step to be uset in SOTF mode
ActivationSOTF =
ActUndertime =
IN1>
Off
CloseCommand
CloseCommand
Set the time after closing or position change during which the SOTF function is active
Set the time delay for the SOTF trip
UseStartVal =
t4U =
Set the time delay for the undertime trip i.e acclerated trip from the selected stage at closing
Enable Harmonic restraint function in SOTF
tSOTF =
tUndertime =
IN2>
1.00 s
0.30 s
0.30 s
HarmResSOTF = Off
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TPADate
Setting of Transformer protection relay RET670
2005-11-11 500MVA 400/230 kV TransformerDocument No.
CSheet
11Cont
1MRK 504 083-WEN 33
Setting of four step Earth fault overcurrent function (TEF) on 230 kV side neutral
Activation of the earth fault function
Set the Base current for the function on which the current levels are based
Setting of the Base voltage level on which the directional polarizing voltage is based
Operation =
Ibase =
On
1255 A
Setting of parameters for first stageSetting of the operating direction for the stage
UBase= =
DirMode1 =Setting of the operating characteristic
Setting of the operating current level in primary valuesCharacteristic1 =
IN1>' =
230.0 kV
NonDir
IEC NI
126 A
Set the current multiplier for IN1 valid at activation of input ENMULT
Set the definite time delay, when definite time characteristic has been selected
IN1> =
IN1Mult =
Set the back-up trip time delay multiplier for inverse characteristic
Set the Minimum operating time for inverse characteristic
t1 =
k1 =
18% *Ibase
2.00
0.30 s
0.20
Select the reset curve type for the inverse delay
Set the Reset time delay for definite time delayed function
t1Min =
ResetTypeCrv1 =
Set the release of Harmonic restraint blocking for the stage
Setting of parameters for second stage
tReset1 =
HarmRestrain1 =
0.30 s
Instantaneous
0.02 s
On
Setting of the operating direction for the stage
Setting of the operating characteristicDirMode2 =
Characteristic2 =Setting of the operating current level in primary values
Set the current multiplier for IN2 valid at activation of input ENMULT
IN2>' =IN2> =
Off
IEC NI
600 A 86% *Ibase
Set the definite time delay, when definite time characteristic has been selected
Set the back-up trip time delay multiplier for inverse characteristic
IN2Mult =
t2 =
Set the Minimum operating time for inverse characteristic
Select the reset curve type for the inverse delay
k2 =
t2Min =
2.00
0.30 s
0.20
0.30 s
Set the Reset time delay for definite time delayed function
Set the release of Harmonic restraint blocking for the stage
ResetTypeCrv2 =
tReset2 =
HarmRestrain2 =
Instantaneous
0.02 s
On
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Setting of Transformer protection relay RET670
2005-11-11 500MVA 400/230 kV TransformerDocument No.
CSheet
12Cont
1MRK 504 083-WEN 33
Setting of parameters for third stageSetting of the operating direction for the stage
DirMode3 = OffSetting of the operating characteristic
Setting of the operating current level in primary valuesCharacteristic3 =
IN3> =
IEC NI
1200 A
Set the current multiplier for IN3 valid at activation of input ENMULT
Set the definite time delay, when definite time characteristic has be
IN3> =
IN3Mult =
Set the back-up trip time delay multiplier for inverse characteristic
Set the Minimum operating time for inverse characteristic
t3 =
k3 =
173% *Ibase
2.00
0.30 s
0.20
Select the reset curve type for the inverse delay
Set the Reset time delay for definite time delayed function
t3Min =
ResetTypeCrv3 =
Set the release of Harmonic restraint blocking for the stage
Setting of parameters for fourth stage
tReset3 =
HarmRestrain3 =
0.30 s
Instantaneous
0.02 s
On
Setting of the operating direction for the stage
Setting of the operating characteristicDirMode4 =
Characteristic4 =Setting of the operating current level in primary values
Set the current multiplier for IN4 valid at activation of input ENMULT
IN4> =IN4> =
Off
IEC NI
6000 A 863% *Ibase
Set the definite time delay, when definite time characteristic has be
Set the back-up trip time delay multiplier for inverse characteristic
IN4Mult =
t4 =
Set the Minimum operating time for inverse characteristic
Select the reset curve type for the inverse delay
k4 =
t4Min =
2.00
0.30 s
0.20
0.30 s
Set the Reset time delay for definite time delayed function
Set the release of Harmonic restraint blocking for the stage
ResetTypeCrv4 =
tReset4 =
Set of Direction, Harmonic blocking and SOTF functionalitySetting of the minimum neutral point polarizing voltage level for the directional funtion
HarmRestrain4 =
3U0>Dir =
Instantaneous
0.02 s
On
1.00 %*UbaseSet the relay characteristic angle, i.e. the angle between the neutral point voltage and current
Setting of the operating current level for the directional release. Note! Sensitivity at RCAAngleRCA =
IN>DirCmp =Set the definite time delay for the directional comparison function
tDirCmp =
-65 deg Normal zero sequence source angle at direct earthing
3% *Ibase
0.05 s
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Setting of Transformer protection relay RET670
2005-11-11 500MVA 400/230 kV TransformerDocument No.
CSheet
13Cont
1MRK 504 083-WEN 33
Set the method of directional polarizing to be used
Setting of the minimum enutral current required for direction polarizingPolMethod = Voltage
Setting of the zero sequence source resistance generating the polarizing current in primary ohm
Setting of the zero sequence source resistance generating the polarizing current in primary ohm
IPolMin =
RNPol =
5.00 %*IBase
5.00 ohm
Enable the harmonic restraint measuring function
Setting of the harmonic content in IN current blocking level
XNPol =
HarmRestrain =
Set the harmonic seal-in blocking at parallel transformers on if problems are expected due to sympatetic inrush.
Set the current level to be blocked to seal-in the Harmonic blocking on this level if sympatetic inrush is expected.
2ndHarmStab =
BlockParTransf =
40.00 ohm
On
25% of I
Off
Set the SOTF function operating mode
Select the input signal which shall activate the SOTF function
UseStartVal =
SOTF =
Select the input signal which shall activate the undertime function
Select the step to be uset in SOTF mode
ActivationSOTF =
ActUndertime =
IN1>
Off
CloseCommand
CloseCommand
Set the time after closing or position change during which the SOTF function is active
Set the time delay for the SOTF trip
UseStartVal =
t4U =
Set the time delay for the undertime trip i.e acclerated trip from the selected stage at closing
Enable Harmonic restraint function in SOTF
tSOTF =
tUndertime =
IN2>
1.00 s
0.30 s
0.30 s
HarmResSOTF = Off
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Setting of Transformer protection relay RET670
2005-11-11 500MVA 400/230 kV TransformerDocument No.
CSheet
14Cont
1MRK 504 083-WEN 33
Setting of four stage Phase overcurrent function (TOC1) on 400 kV side phasesActivation of the phase overcurrent function
Operation =Set the Base current for the function on which the current levels are based
Setting of the Base voltage level on which the directional polarizing voltage is basedIbase =
UBase= =
On
696 A
415.0 kVSet the Directional angle Directional overcurrent protection
Set the angles from the RCA angle Max and Min limiting the operating areaAngleRCA =
MaxFwdAng =Setting of the operating current level for phase selection in primary values
Set the number of phases required to get the Phase selection (phase start) outputs
IPh> = gives IMinOpPhSel =
-65 deg
50 deg MinFwdAng
765 A 110% *Ibase
= 80 deg
Enable the harmonic restraint measuring function
Setting of the harmonic content in I current blocking level
StartPhSel =
HarmRestrain =
Setting of parameters for first stageSetting of the operating direction for the stage
2ndHarmStab =
DirMode1 =
1 out of 3
Off
20% of I
NonDirSetting of the operating characteristic
Setting of the operating current level in primary valuesCharacteristic1 =
I1> =
Set the multiplier for start value which is activated when the multiplier input is activated, normally at CB closing.
Set the definite time delay, when definite time characteristic has been selected
gives I1> =
I1Mult =
IEC NI
904 A 130% *Ibase
1.00
Set the back-up trip time delay multiplier for inverse characteristic
Set the Minimum operating time for inverse characteristic
t1 =
k1 =
Select the reset curve type for the inverse delay
Set the Reset time delay for definite time delayed function
t1Min =
ResetTypeCrv =
0.30 s
0.20
0.30 s
Instantaneous
Set the release of Harmonic restraint blocking for the stage
Setting of parameters for second stage
tReset1 =
HarmRestraint1 =
Setting of the operating direction for the stage
Setting of the operating characteristicDirMode2 =
Characteristic2 =
0.02 s
Disabled
Off
IEC NISetting of the operating current level in primary values
Set the multiplier for start value which is activated when the multiplier input is activated, normally at CB closing
I2> =I2> =
Set the definite time delay, when definite time characteristic has been selectedI2Mult =
t2 =
3617 A 520% *Ibase
1.00
0.30 s
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Setting of Transformer protection relay RET670
2005-11-11 500MVA 400/230 kV TransformerDocument No.
CSheet
15Cont
1MRK 504 083-WEN 33
Set the back-up trip time delay multiplier for inverse characteristic
Set the Minimum operating time for inverse characteristick2 = 0.20
Select the reset curve type for the inverse delay
Set the Reset time delay for definite time delayed function
t2Min =
ResetTypeCrv2 =
0.30 s
Instantaneous
Set the release of Harmonic restraint blocking for the stage
Setting of parameters for third stage
tReset2 =
HarmRestraint2 =
Setting of the operating direction for the stage
Setting of the operating characteristicDirMode3 =
Characteristic3 =
0.02 s
Disabled
Off
IEC NISetting of the operating current level in primary values
Set the multiplier for start value which is activated when the multiplier input is activated, normally at CB closing
I3'> =I3> =
Set the definite time delay, when definite time characteristic has been selected
Set the back-up trip time delay multiplier for inverse characteristic
I3Mult =
t3 =
12521 A 1800% *Ibase
1.00
0.30 s
Set the Minimum operating time for inverse characteristic
Select the reset curve type for the inverse delay
k3 =
t3Min =
Set the Reset time delay for definite time delayed function
Set the release of Harmonic restraint blocking for the stage
ResetTypeCrv3 =
tReset3 =
0.20
0.30 s
Instantaneous
0.02 s
Setting of parameters for fourth stageSetting of the operating direction for the stage
HarmRestraint3 =
DirMode4 =Setting of the operating characteristic
Setting of the operating current level in primary valuesCharacteristic4 =
I4>' =
Disabled
Off
IEC NI
8347 A
Set the multiplier for start value which is activated when the multiplier input is activated, normally at CB closing
Set the definite time delay, when definite time characteristic has been selected
I4> =
I4Mult =
Set the back-up trip time delay multiplier for inverse characteristic
Set the Minimum operating time for inverse characteristic
t4 =
k4 =
1200% *Ibase
1.00
0.30 s
0.20
Select the reset curve type for the inverse delay
Set the Reset time delay for definite time delayed function
t4Min =
ResetTypeCrv4 =
Set the release of Harmonic restraint blocking for the stagetReset4 =
HarmRestraint4 =
0.30 s
Instantaneous
0.02 s
Disabled
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Setting of Transformer protection relay RET670
2005-11-11 500MVA 400/230 kV TransformerDocument No.
CSheet
16Cont
1MRK 504 083-WEN 33
Setting of four stage Phase overcurrent function (TOC2) on 230 kV side phasesActivation of the phase overcurrent function
Operation =Set the Base current for the function on which the current levels are based
Setting of the Base voltage level on which the directional polarizing voltage is basedIbase =
UBase= =
On
1255 A
230.0 kVSet the Directional angle Directional overcurrent protection
Set the angles from the RCA angle Max and Min limiting the operating areaAngleRCA =
MaxFwdAng =Setting of the operating current level for phase selection in primary values
Set the number of phases required to get the Phase selection (phase start) outputs
IPh> = gives IMinOpPhSel =
-65 deg
50 deg MinFwdAng
1381 A 110% *Ibase
= 80 deg
Enable the harmonic restraint measuring function
Setting of the harmonic content in I current blocking level
StartPhSel =
HarmRestrain =
Setting of parameters for first stageSetting of the operating direction for the stage
2ndHarmStab =
DirMode1 =
1 out of 3
Off
20% of I
ForwardSetting of the operating characteristic
Setting of the operating current level in primary valuesCharacteristic1 =
I1> =
Set the multiplier for start value which is activated when the multiplier input is activated, normally at CB closing.
Set the definite time delay, when definite time characteristic has been selected
gives I1> =
I1Mult =
IEC NI
1632 A 130% *Ibase
1.00
Set the back-up trip time delay multiplier for inverse characteristic
Set the Minimum operating time for inverse characteristic
t1 =
k1 =
Select the reset curve type for the inverse delay
Set the Reset time delay for definite time delayed function
t1Min =
ResetTypeCrv =
0.30 s
0.20
0.30 s
Instantaneous
Set the release of Harmonic restraint blocking for the stage
Setting of parameters for second stage
tReset1 =
HarmRestraint1 =
Setting of the operating direction for the stage
Setting of the operating characteristicDirMode2 =
Characteristic2 =
0.02 s
Disabled
Off
IEC NISetting of the operating current level in primary values
Set the multiplier for start value which is activated when the multiplier input is activated, normally at CB closing
I2> =I2> =
Set the definite time delay, when definite time characteristic has been selectedI2Mult =
t2 =
5021 A 400% *Ibase
1.00
0.30 s
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Setting of Transformer protection relay RET670
2005-11-11 500MVA 400/230 kV TransformerDocument No.
CSheet
17Cont
1MRK 504 083-WEN 33
Set the back-up trip time delay multiplier for inverse characteristic
Set the Minimum operating time for inverse characteristick2 = 0.20
Select the reset curve type for the inverse delay
Set the Reset time delay for definite time delayed function
t2Min =
ResetTypeCrv2 =
0.30 s
Instantaneous
Set the release of Harmonic restraint blocking for the stage
Setting of parameters for third stage
tReset2 =
HarmRestraint2 =
Setting of the operating direction for the stage
Setting of the operating characteristicDirMode3 =
Characteristic3 =
0.02 s
Disabled
Off
IEC NISetting of the operating current level in primary values
Set the multiplier for start value which is activated when the multiplier input is activated, normally at CB closing
I3'> =I3> =
Set the definite time delay, when definite time characteristic has been selected
Set the back-up trip time delay multiplier for inverse characteristic
I3Mult =
t3 =
10041 A 800% *Ibase
1.00
0.30 s
Set the Minimum operating time for inverse characteristic
Select the reset curve type for the inverse delay
k3 =
t3Min =
Set the Reset time delay for definite time delayed function
Set the release of Harmonic restraint blocking for the stage
ResetTypeCrv3 =
tReset3 =
0.20
0.30 s
Instantaneous
0.02 s
Setting of parameters for fourth stageSetting of the operating direction for the stage
HarmRestraint3 =
DirMode4 =Setting of the operating characteristic
Setting of the operating current level in primary valuesCharacteristic4 =
I4>' =
Disabled
Off
IEC NI
15062 A
Set the multiplier for start value which is activated when the multiplier input is activated, normally at CB closing
Set the definite time delay, when definite time characteristic has been selected
I4> =
I4Mult =
Set the back-up trip time delay multiplier for inverse characteristic
Set the Minimum operating time for inverse characteristic
t4 =
k4 =
1200% *Ibase
1.00
0.30 s
0.20
Select the reset curve type for the inverse delay
Set the Reset time delay for definite time delayed function
t4Min =
ResetTypeCrv4 =
Set the release of Harmonic restraint blocking for the stagetReset4 =
HarmRestraint4 =
0.30 s
Instantaneous
0.02 s
Disabled
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Setting of Transformer protection relay RET670
2005-11-11 500MVA 400/230 kV TransformerDocument No.
CSheet
18Cont
1MRK 504 083-WEN 33
Setting of Synchrocheck function (SYN2) for 400 kV Bus CB (Note Option)Setting of the operating mode for the function
Operation = OnSetting of the input phase for Bus 1 voltage reference
Setting of the phase or line 1 voltage measurementSelPhaseBus1 =
SelPhaseLine1 =
L2
L2Setting of the input phase for bus 2 voltage reference (used in multi breaker schemes only)
Setting of the phase or line 2 voltage measurement (used in multi-breaker schemes only)SelPhaseBus2 =
SelPhaseLine2 =
L2
L2Setting of the Base voltage level on which the voltage settings are based
Setting of the phase shift for phases involved in checkingUBase= =
Phase shift =Setting of the voltage ratio between Line VT and Bus VT (Line/Bus)
Setting of the busbar arrangement for Bus VT selectionUratio =
CBConfig =
415.0 kV
0
1.00
1 1/2 Bus CBSet the values for the Energizing checkSetting of the maximum live voltage level at which energizing is allowed
Set the operating level for the Bus high voltage at Line energizingUMaxEnerg =
Setting of the operating voltage level for the low line voltage level at line energizing
Set the operating level for the Line high voltage at Bus energizing
UHighBusEnerg =
ULowLineEnerg =
115%
80% *UBase
40% *UBase
Setting of the operating voltage level for the low Bus voltage level at Bus energizing
Setting of the energizing check directions to be activated.
UHighLineEnerg =
ULowBusEnerg =
Set the time delay for the Auto Energizing
Setting of the manual Dead line/bus and Dead/Dead switching conditions to be allowed
AutoEnergi =
tAutoEnerg =
80% *UBase
40% *UBase
Off
0.10 s
Set the time delay for the Manual Energizing
ManEnergManEnergDLDB
==
tManEnerg =Set general settings for the Synchronism check functionSetting of the operating mode for the synchonism check (paralleling) function
Setting of the allowed voltage difference for Manual and Auto synchronism checkOperationSync =
DBLLOff
0.10 s
On
Set the operating level for the Bus high voltage at Line synchronism check
Set the operating level for the Line high voltage at Line synchronism check
UDiff =
UHighBusSync =
UHighLineSync =
10%
80% *UBase
80% *UBase
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Setting of Transformer protection relay RET670
2005-11-11 500MVA 400/230 kV TransformerDocument No.
CSheet
19Cont
1MRK 504 083-WEN 33
Set the values for the Manual Synchronism (paralleling) checkSetting of the frequency difference for Manual synchronism check
FreqDiffM = 0.010 HzSetting of the phase angle difference for Manual synchronism check
Setting of the time delay for Manual synchronism checkPhaseDiffM =
tSyncM =
45
0.10 s
Set the values for the Auto Synchronism (paralleling) checkSetting of the frequency difference for Auto synchronism check
FreqDiffA =Setting of the phase angle difference for Auto synchronism check
Setting of the time delay for Auto synchronism checkPhaseDiffA =
tSyncA =
0.010 Hz
45
0.10 s
Setting of the operating mode for the Synchronising function.
Setting of the min frequency difference required to perform synchronising.Operation =
Shall be set same as Synchrocheck value FreqDiffA/M.
Setting of the frequency difference required to perform synchronisingFreqDiffMin =
FreqDiffMax =
Off
0.010 Hz
0.220 HzSet the operating level for the Bus high voltage at Line synchronism check
Set the operating level for the Line high voltage at Line synchronism checkUHighBusSynch =
UHighLineSynch =Setting of the allowed voltage difference for Manual and Auto synchronism check
Setting of the time delay for energizingUDiffSynch =
tClosePulse =
80% *UBase
80% *UBase
10%
0.300 sSetting of the breaker operating time at closing (including possible auxiliary relays)
Setting of the minimum time for Synchronizing. Before this time no pulse will be giventBreaker =
tMinSynch =Setting of the maximum time for Synchronizing. After this time the function will be reset.
tMaxSynch =
0.08 s
0.25 s
300.00 s
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Setting of Transformer protection relay RET670
2005-11-11 500MVA 400/230 kV TransformerDocument No.
CSheet
20Cont
1MRK 504 083-WEN 33
Setting of Synchrocheck function (SYN3) for 400 kV Tie CB Note! OptionSetting of the operating mode for the function
Operation = OnSetting of the input phase for Bus 1 voltage reference
Setting of the phase or line 1 voltage measurementSelPhaseBus1 =
SelPhaseLine1 =
L2
L2Setting of the input phase for bus 2 voltage reference (used in multi breaker schemes only)
Setting of the phase or line 2 voltage measurement (used in multi-breaker schemes only)SelPhaseBus2 =
SelPhaseLine2 =
L2
L2Setting of the Base voltage level on which the polarizing voltage is based
Setting of the phase shift for phases involved in checkingUBase= =
Phase shift =Setting of the voltage ratio between Line VT and Bus VT (Line/Bus)
Setting of the busbar arrangement for Bus VT selectionUratio =
CBConfig =
415.0 kV
0
1.00
Tie CBSet the values for the Energizing checkSetting of the maximum live voltage level at which energizing is allowed
Set the operating level for the Bus high voltage at Line energizingUMaxEnerg =
Setting of the operating voltage level for the low line voltage level at line energizing
Set the operating level for the Line high voltage at Bus energizing
UHighBusEnerg =
ULowLineEnerg =
115%
80% *UBase
40% *UBase
Setting of the operating voltage level for the low Bus voltage level at Bus energizing
Setting of the energizing check directions to be activated.
UHighLineEnerg =
ULowBusEnerg =
Set the time delay for the Auto Energizing
Setting of the manual Dead line/bus and Dead/Dead switching conditions to be allowed
AutoEnerg =
tAutoEnerg =
80% *UBase
40% *UBase
Off
0.10 s
Set the time delay for the Manual Energizing
ManEnergManEnergDLDB
==
tManEnerg =Set general settings for the Synchronism check functionSetting of the operating mode for the synchonism check (paralleling) function
Setting of the allowed voltage difference for Manual and Auto synchronism checkOperationSync =
DBLLOff
0.10 s
On
Set the operating level for the Bus high voltage at Line synchronism check
Set the operating level for the Line high voltage at Line synchronism check
UDiff =
UHighBusSync =
UHighLineSync =
10%
80% *UBase
80% *UBase
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Setting of Transformer protection relay RET670
2005-11-11 500MVA 400/230 kV TransformerDocument No.
CSheet
21Cont
1MRK 504 083-WEN 33
Set the values for the Manual Synchronism (paralleling) checkSetting of the frequency difference for Manual synchronism check
FreqDiffM = 0.010 HzSetting of the phase angle difference for Manual synchronism check
Setting of the time delay for Manual synchronism checkPhaseDiffM =
tSyncM =
45
0.10 s
Set the values for the Auto Synchronism (paralleling) checkSetting of the frequency difference for Auto synchronism check
FreqDiffA =Setting of the phase angle difference for Auto synchronism check
Setting of the time delay for Auto synchronism checkPhaseDiffA =
tSyncA =
0.010 Hz
45
0.10 s
Setting of the operating mode for the Synchronising function.
Setting of the min frequency difference required to perform synchronising.Operation =
Shall be set same as Synchrocheck value FreqDiffA/M.
Setting of the frequency difference required to perform synchronisingFreqDiffMin =
FreqDiffMax =
Off
0.010 Hz
0.220 HzSet the operating level for the Bus high voltage at Line synchronism check
Set the operating level for the Line high voltage at Line synchronism checkUHighBusSynch =
UHighLineSynch =Setting of the allowed voltage difference for Manual and Auto synchronism check
Setting of the time delay for energizingUDiffSynch =
tClosePulse =
80% *UBase
80% *UBase
10%
0.300 sSetting of the breaker operating time at closing (including possible auxiliary relays)
Setting of the minimum time for Synchronizing. Before this time no pulse will be giventBreaker =
tMinSynch =Setting of the maximum time for Synchronizing. After this time the function will be reset.
tMaxSynch =
0.08 s
0.25 s
300.00 s
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Setting of Transformer protection relay RET670
2005-11-11 500MVA 400/230 kV TransformerDocument No.
CSheet
22Cont
1MRK 504 083-WEN 33
Setting of Synchrocheck function (SYN1) for 230 kV CBSetting of the operating mode for the function
Operation = OnSetting of the input phase for Bus 1 voltage reference
Setting of the phase or line 1 voltage measurementSelPhaseBus1 =
SelPhaseLine1 =
L2
L2Setting of the input phase for bus 2 voltage reference (used in multi breaker schemes only)
Setting of the phase or line 2 voltage measurement (used in multi-breaker schemes only)SelPhaseBus2 =
SelPhaseLine2 =
L2
L2Setting of the Base voltage level on which the polarizing voltage is based
Setting of the phase shift for phases involved in checkingUBase= =
Phase shift =Setting of the voltage ratio between Line VT and Bus VT (Line/Bus)
Setting of the busbar arrangement for Bus VT selectionUratio =
CBConfig =
230.0 kV
0
1.00
Tie CBSet the values for the Energizing checkSetting of the maximum live voltage level at which energizing is allowed
Set the operating level for the Bus high voltage at Line energizingUMaxEnerg =
Setting of the operating voltage level for the low line voltage level at line energizing
Set the operating level for the Line high voltage at Bus energizing
UHighBusEnerg =
ULowLineEnerg =
115%
80% *UBase
40% *UBase
Setting of the operating voltage level for the low Bus voltage level at Bus energizing
Setting of the energizing check directions to be activated.
UHighLineEnerg =
ULowBusEnerg =
Set the time delay for the Auto Energizing
Setting of the manual Dead line/bus and Dead/Dead switching conditions to be allowed
AutoEnerg =
tAutoEnerg =
80% *UBase
40% *UBase
Off
0.10 s
Set the time delay for the Manual Energizing
ManEnergManEnergDLDB
==
tManEnerg =Set general settings for the Synchronism check functionSetting of the operating mode for the synchonism check (paralleling) function
Setting of the allowed voltage difference for Manual and Auto synchronism checkOperationSync =
DBLLOff
0.10 s
On
Set the operating level for the Bus high voltage at Line synchronism check
Set the operating level for the Line high voltage at Line synchronism check
UDiff =
UHighBusSync =
UHighLineSync =
10%
80% *UBase
80% *UBase
Prin
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Setting of Transformer protection relay RET670
2005-11-11 500MVA 400/230 kV TransformerDocument No.
CSheet
23Cont
1MRK 504 083-WEN 33
Set the values for the Manual Synchronism (paralleling) checkSetting of the frequency difference for Manual synchronism check
FreqDiffM = 0.010 HzSetting of the phase angle difference for Manual synchronism check
Setting of the time delay for Manual synchronism checkPhaseDiffM =
tSyncM =
45
0.10 s
Set the values for the Auto Synchronism (paralleling) checkSetting of the frequency difference for Auto synchronism check
FreqDiffA =Setting of the phase angle difference for Auto synchronism check
Setting of the time delay for Auto synchronism checkPhaseDiffA =
tSyncA =
0.010 Hz
45
0.10 s
Setting of the operating mode for the Synchronising function.
Setting of the min frequency difference required to perform synchronising.Operation =
Shall be set same as Synchrocheck value FreqDiffA/M.
Setting of the frequency difference required to perform synchronisingFreqDiffMin =
FreqDiffMax =
Off
0.010 Hz
0.220 HzSet the operating level for the Bus high voltage at Line synchronism check
Set the operating level for the Line high voltage at Line synchronism checkUHighBusSynch =
UHighLineSynch =Setting of the allowed voltage difference for Manual and Auto synchronism check
Setting of the time delay for energizingUDiffSynch =
tClosePulse =
80% *UBase
80% *UBase
10%
0.300 sSetting of the breaker operating time at closing (including possible auxiliary relays)
Setting of the minimum time for Synchronizing. Before this time no pulse will be giventBreaker =
tMinSynch =Setting of the maximum time for Synchronizing. After this time the function will be reset.
tMaxSynch =
0.08 s
0.25 s
300.00 s
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Setting of Transformer protection relay RET670
2005-11-11 500MVA 400/230 kV TransformerDocument No.
CSheet
24Cont
1MRK 504 083-WEN 33
Setting of Breaker failure function (BFP1) for 400 kV Bus CBActivation of the Breaker failure function
Operation =Setting of the operating mode for retrip of own breaker
Set the used principle for current checkRetripMode =
BUTripMode =
On
Retrip Off
1 out of 3Set the used principle forback-up tripping, with or without contact resp current checks
Set the Base current for the function on which the current levels are basedFunctionMode =
Ibase =Setting of the operating current level
Setting of the operating current level for Neutral currentIP> =
IN> =
Current
696 A
10% *Ibase
10% *IbaseSet the retrip time delay
Set the back-up trip time delayt1 =
t2 =Set the back-up trip time delay for Multi-phase start
Set an additional time delay for a second back-up trip step if used. Will be added to t2 B-u trip time without checks.t2MPh =
t3 =
0.050 s
0.120 s
0.120 s
0.030 sSet the length of the trip pulse
Set the current level above which the contact base operation (if selected) is blockedtPulse =
I>BlkCont =Set the time to alarm for CB faults if input is used
tCBAlarm =
0.200 s
20% *Ibase
5.000 s
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TPADate
Setting of Transformer protection relay RET670
2005-11-11 500MVA 400/230 kV TransformerDocument No.
CSheet
25Cont
1MRK 504 083-WEN 33
Setting of Breaker failure function (BFP2) for400 kV Tie CBActivation of the Breaker failure function
Operation =Setting of the operating mode for retrip of own breaker
Set the used principle for current checkRetripMode =
BUTripMode =
On
Retrip Off
1 out of 3Set the used principle forback-up tripping, with or without contact resp current checks
Set the Base current for the function on which the current levels are basedFunctionMode =
Ibase =Setting of the operating current level
Setting of the operating current level for Neutral currentIP> =
IN> =
Current
696 A
10% *Ibase
10% *IbaseSet the retrip time delay
Set the back-up trip time delayt1 =
t2 =Set the back-up trip time delay for Multi-phase start
Set an additional time delay for a second back-up trip step if used. Will be added to t2 B-u trip time without checks.t2MPh =
t3 =
0.050 s
0.120 s
0.120 s
0.030 sSet the length of the trip pulse
Set the current level above which the contact base operation (if selected) is blockedtPulse =
I>BlkCont =Set the time to alarm for CB faults if input is used
tCBAlarm =
0.200 s
20% *Ibase
5.000 s
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Setting of Transformer protection relay RET670
2005-11-11 500MVA 400/230 kV TransformerDocument No.
CSheet
26Cont
1MRK 504 083-WEN 33
Setting of Breaker failure function (BFP3) for 230 kV Circuit breaker
Activation of the Breaker failure function
Setting of the operating mode for retrip of own breaker
Set the used principle for current check
Operation =
RetripMode =
On
Retrip Off
Set the used principle forback-up tripping, with or without contact resp current checks
Set the Base current for the function on which the current levels are based
BUTripMode =
FunctionMode =
Setting of the operating current level
Setting of the operating current level for Neutral current
Ibase =
IP> =
1 out of 3
Current
1255 A
10% *Ibase
Set the retrip time delay
Set the back-up trip time delay
IN> =
t1 =
Set the back-up trip time delay for Multi-phase start
Set an additional time delay for a second back-up trip step if used. Will be added to t2 B-u trip time without checks.
t2 =
t2MPh =
10% *Ibase
0.050 s
0.120 s
0.120 s
Set the length of the trip pulse
Set the current level above which the contact base operation (if selected) is blocked
t3 =
tPulse =
Set the time to alarm for CB faults if input is usedIP> =
tCBAlarm =
0.030 s
0.200 s
20% *Ibase
5.000 s
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Setting of Transformer protection relay RET670
2005-11-11 500MVA 400/230 kV TransformerDocument No.
CSheet
27Cont
1MRK 504 083-WEN 33
Setting of the System Overload function (TTR1)Operation =
Set the Base current for the function on which the current levels are based
Setting of the reference current level above which continuous operation gives tripIbase =
IRef =
On
1255 A
102% *IbaseSet the multiplication factor used when the multiplication input is activated.
Set the Base current for the function on which the current levels are based with non forced coolingIRefMult =
Ibase1 =Set the Base current for the function on which the current levels are based with forced cooling.
Set the time constant without coolingIbase2 =
Tau1 =
1.00
1255 A
1255 A
90 deg CSet the time constant with cooling.
Current setting for rescaling Tau1 with factor Tau1HighTau2 =
IHighTau1 =Set multiplier to constant Tau1 when current is higher than IHighTau1
Current setting for rescaling Tau1 with factor Tau1LowTau1High =
ILowTau1 =
90 deg C
100.0 %Ibase1
100 %Tau1
100.0 %Ibase1Set multiplier to constant Tau1 when current is lower than ILowTau1
Current setting for rescaling Tau2 with factor Tau2HighTau1Low =
IHighTau2 =Set multiplier to constant Tau2 when current is higher than IHighTau2
Current setting for rescaling Tau2 with factor Tau2LowTau2High =
ILowTau2 =
100 %Tau1
100.0 %Ibase2
100 %Tau2
100.0 %Ibase2Set multiplier to constant Tau2 when current is lower than ILowTau2
Set the steady state (continuous) current level giving trip (times IBase 1 or 2 depending of cooling)Tau2Low =
ITrip =Set the alarm level current for alarm 1 as a percentage of the trip level.
Set the alarm level current for alarm 2 as a percentage of the trip level.Alarm1 =
Alarm2 =
100 %Tau2
100.0 %Ibasex
90.0 %ITrip
80.0 %ITripSet the level at which the lock-out of closing is reset
Set the initial thermal content to be used at closing of the bay.ResLo =
ThetaInit =Set the time delay
Set the tripping pulse length. Note! Trip is pulsed and lock-out of closing separate!Warning =
tPulse =
60.0 %ITrip
50.0 %
30 min
0.100 s
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Setting of Transformer protection relay RET670
2005-11-11 500MVA 400/230 kV TransformerDocument No.
CSheet
28Cont
1MRK 504 083-WEN 33
Setting of Measuring values SRVSet nder General settings/Monitoring:Set for each of the measuring functions S,P, Q,PF,U,I, FrSet the deadband typeSet deaband in % resp Set the supervision limits for high and low alarm and the hystereses for the limits in VA
SdbTypeSdb
==
SHHlimit =
Note! Measures the W2 side values!
Deadband1%
1200000000
Set the maximum and minimum value for the measuring in VA
SHlimitSLlimit
==
SLLlimit =
Set active and reactive powerSet the deadband type
S maxS min
==
PdbType =
1000000000200000005000000
1500000000100000
DeadbandSet deaband in % resp Set the supervision limits for high and low alarm and the hystereses for the limits in W/Var
P db =
PHHlimitPHlimit
==
Set the maximum and minimum value for the measuring in W/Var
PLlimitPLLlimit
==
P max =
2%
12000000001000000000200000005000000
1500000000
Set the Power Factor PF valuesSet deaband in % resp
P min =
PFdb =Set the supervision limits for high and low alarm and the hystereses for the limits
PFHHlimit =PFHlimitPFLlimit
==
100000
1%
110.8
Q dbType = DeadbandQ db =
QHHlimitQHlimit
==
1%
3000000010000000
QLlimitQLLlimit
==
Q max =
2000000100000
1500000000Q min = 100000
Set the maximum and minimum value for the measuringPfLLlimit =
PF maxPF min
==
Set the Voltage and Current valuesSet the deadband typeSet deaband in % resp Set the supervision limits for high and low alarm and the hystereses for the limits in V/A
U dbType =Udb =
0.7
10
Deadband2%
UHHlimitUHlimit
==
ULlimitULLlimit
==
Set the maximum and minimum value for the measuring in V/A
Sett he frequency values
U max =U min =
450000000400000000360000000320000000
6000000001000
I dbType =Idb =
Deadband1%
IHHlimitIHlimit
==
ILlimitILLlimit
==
36003200300100
I max =I min =
60001
Set the deadband typeSet deaband in % resp Set the supervision limits for high and low alarm and the hystereses for the limits inHz
f dbTypef Fdb
==
fHHlimit =fHlimitfLlimit
==
fLLlimit =
Deadband1%
56534744
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Setting of Transformer protection relay RET670
2005-11-11 500MVA 400/230 kV TransformerDocument No.
CSheet
29Cont
1MRK 504 083-WEN 33
Set nder General settings/Monitoring:Operation
Mode==
Setting of the Base voltage level on which the voltage settings are based
Set the Base current for the function on which the current levels are basedUBase= =
Ibase =
OnL1, L2, L3
230.0 kV
1255 A Set the minimum values for which the power is calculated
Set S amplitude factor and angle compensationIMin =
Ampl =
1% *Ibase
1.000
UMin =
Angle =
1% *UBase
0.0 deg
Setting of Current Phasors values CMMXUSet nder General settings/Monitoring:
Operation =Set for phase L1 currentSet the deadband typeSet deaband in % resp secSet the deadband at zero
IL1 dbType =IL1 db
IL1 Zero db=
Note! Measures the line values!
On
Deadband1%0.2%
Set the supervision limits for high and low alarm and the hystereses for the limits in VAIL1 HHlimit =
IL1 HlimitIL1 Llimit
==
Set the maximum and minimum value for the measuring in VAIL1 LLlimit =
IL1 maxIL1 min
==
36003200300100
60001
Set for phase L3 currentSet the deadband typeSet deaband in % resp secSet the deadband at zero
IL13 dbType =IL3 db
IL3 Zero db=
Set the supervision limits for high and low alarm and the hystereses for the limits in VAIL3 HHlimit =
IL3 HlimitIL3 Llimit
==
Deadband1%0.2%
36003200300
Set the maximum and minimum value for the measuring in VAIL3 LLlimit =
IL3 maxIL3 min
==
Set for I0 currentSet the deadband typeSet deaband in % resp secSet the deadband at zero
I0 dbType =I0= db
I0 Zero db=
100
60001
Deadband1%0.2%
Set for phase L2 currentIL2 dbType =
IL2 dbIL2 Zero db
=Deadband1%0.2%
IL2 HHlimit =IL2 HlimitIL2 Llimit
==
36003200300
IL2 LLlimit =
IL2 maxIL2 min
==
100
60001
Set for neutral IN currentILN dbType =
IN dbIN Zero db
=Deadband1%0.2%
IN HHlimit =IN HlimitIN Llimit
==
36003200300
IN LLlimit =
IN maxIN min
==
100
60001
Set for negative sequence I2 currentI2 dbType =
I2 dbI2 Zero db
=Deadband1%0.2%
Set the supervision limits for high and low alarm and the hystereses for the limits in VAI0 HHlimit =
I0 HlimitI0 Llimit
==
Set the maximum and minimum value for the measuring in VAI0 LLlimit =
I0 maxI0 min
==
36003200300100
60001
Note! Connect alarm to measuring expander block to use them in Application configuration
I2 HHlimit =I2 HlimitI2 Llimit
==
36003200300
I2 LLlimit =
I2 maxI2 min
==
100
60001
Prin
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Station C 400/230 kV S/S for ABB RET 670 CustomerApproved Resp. dept. Title Rev ind
Max DegerfaltPrepared
EngineerABB PTSX
TPADate
Setting of Transformer protection relay RET670
2005-11-11 500MVA 400/230 kV TransformerDocument No.
CSheet
30Cont
1MRK 504 083-WEN 33
Setting of Voltage Phasors values VMMXUSet nder General settings/Monitoring:
Operation =Set for phase L1VoltageSet the deadband typeSet deaband in % resp secSet the deadband at zero
UL1 dbType =UL1 db
UL1 Zero db=
Note! Measures the line values!
On
Deadband1%0.2%
Set the supervision limits for high and low alarm and the hystereses for the limits in VAUL1 HHlimit =
UL1 HlimitUL1 Llimit
==
Set the maximum and minimum value for the measuring in VAUL1 LLlimit =
UL1 maxUL1 min
==
440000420000360000320000
6000001
Set for phase L3 VoltageSet the deadband typeSet deaband in % resp secSet the deadband at zero
U13 dbType =UL3 db
U3 Zero db=
Set the supervision limits for high and low alarm and the hystereses for the limits in VAU3 HHlimit =UL3 Hlimit
U3 Llimit==
Deadband1%0.2%
440000420000360000
Set the maximum and minimum value for the measuring in VAU3 LLlimit =
UL3 maxUL3