ABB REC650 Applications Manual page 51

1MRK 511 286-UUS A
Application manual
2
æ ö
22
= × =
Z j 10
ç ÷
sc ,22
è 145 ø
GUID-FA8FA533-48E3-45FA-A22A-584CD0F754BF V1 EN
The transformer impedance referred to 22 kV level is:
2
22
= × =
Z j 0.12
T ,22
60
GUID-78CEC42F-9A02-411B-B6D3-95017467242B V1 EN
The fault current can be calculated as follows:
22000
3
= ×
I
sc ph 2
+
2 j 0.23
GUID-2C4DC073-E49B-45BB-8136-96B455CC57A1 V1 EN
This fault current is recalculated to the 145 kV level:
22
= × =
I 948 144
sc ph 2 ,145
145
GUID-2E36019B-9370-4703-9B31-91870BBD7BDB V1 EN
This current is smaller than the required minimum setting to avoid an unwanted trip
when experiencing a large load current. This means that the 145 kV phase
overcurrent protection cannot serve as complete back-up protection for the outgoing
22 kV feeders.
2. Set TD1 to 0.15
The time setting must be coordinated with the feeder protections to assure
selectivity. It can be stated that there is no need for selectivity between the high
voltage side phase overcurrent protection and the low voltage side phase overcurrent
protection.
The feeder short circuit protections have the following setting:
Pickup1: 300 A which corresponds to 45 A on 145 kV level.
Pickup1: 6 000 A which corresponds to 910 A on 145 kV level.
Characterist: IEC Normal Inverse (IEC Norm. inv.) with k-factor = 0.25
The setting of the k-factor for the 145 kV phase overcurrent protection is derived
from graphical study of the inverse time curves. It is required that the smallest time
difference between the inverse time curves shall be 0.4 s. With the setting TD1 = 0.15
the time margin between the characteristics is about 0.4 s as shown in figure 7.
W
j 0.23
W
j 0.97
3
=
948 A
+ +
j 0.97 3 j 10
A
Section 3
REC650 setting examples
(Equation 3)
(Equation 4)
(Equation 5)
(Equation 6)
45