ABB Relion 670 Series Application Manual page 47

1MRK 505 382-UEN E
Table 5: Relevant settings
Setting
IdMin
EndSection1
EndSection2
SlopeSection2
SlopeSection3
IdMinHigh
tIdMinHigh
IdUnre
I2/I1Ratio
I5/I1Ratio
CCCOpMode
VTOnLineGrp1
VTOnLineGrp2
C0
C1
NoOfLineEnds
NoOfCTSetsGrp1
NoOfCTSetsGrp2
IBase
NoOfUsedCTs
TapTransformer
DiffMode
Communication set-up, 670/650 series
Application Guide
Value Remark
0.20 20 % of IBase = 1000 A
Must be set above the maximum possible charging current (in this
example set to approximately 2 x of that value).
1.00 100 % of IBase = 1000 A
3.00 300 % of IBase = 1000 A
0.50 Slope = 50 %
1.00 Slope = 100 %
1.00 100 % of IBase = 1000 A
1000 Interval of initial decreased sensitivity in ms.
3.00 300 % of IBase = 1000 A
Maximum through fault current calculated based on:
IECEQUATION15178 V1 EN-US
IECEQUATION15179 V1 EN-US
0.10 Ratio = 10 %
The value can be set this low because the 2
ignored if an internal fault is detected.
0.10 Ratio = 10 %
The value can be set this low because the 5
ignored if an internal fault is detected and no tap transformer
exists in the protected zone.
1 The exact method with currents and voltages is used. Line
capacitances must be specified.
0 VT is placed on the bus.
0 VT is placed on the bus.
7.751e-9 x 200 Total zero sequence capacitance of 220kV on a 200 km power line.
12.74e-9 x 200 Total positive sequence capacitance of 220kV on a 200 km power
line.
2 Number of physical line ends in the protected zone (setting used
by charging current compensation).
1 Number of three-phase CT groups at first line end, the currents of
which are connected to input group 1 (setting used by charging
current compensation).
1 Number of three-phase CT groups at second line end, the currents
of which are connected to input group 2 (setting used by charging
current compensation).
1000 Nominal current of the protected power line.
2 Total number of CT groups in the protected zone.
0 Tap transformer not included in the protected zone (and its current
therefore not directly measured).
Master Differential function activated.
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Analog and binary signal transfer for line differential protection
220
 
I 2.45
Through
 
3 (4.84 58.64)
 
1.2 I 1.2 2.45 kA
Through
 
I
dUnre
I 1 kA
Base
Section 4
kA

2.94 kA
nd
harmonic block is
th
harmonic block is
41