GE C60, Instruction Manual

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GE Multilin C60 Breaker Protection System 5-71
5 SETTINGS 5.2 PRODUCT SETUP
5
• Firmware revision of the relay.
• Date and time of trigger.
• Name of trigger (specific operand).
• Line or feeder ID via the name of a configured signal source.
• Active setting group at the time of trigger.
• Pre-fault current and voltage phasors (two cycles before either a 50DD disturbance associated with fault report source
or the trigger operate). Once a disturbance is detected, pre-fault phasors hold for 3 seconds waiting for the fault report
trigger. If trigger does not occur within this time, the values are cleared to prepare for the next disturbance.
• Fault current and voltage phasors (one cycle after the trigger).
• Elements operated at the time of triggering.
• Events: 9 before trigger and 7 after trigger (only available via the relay webpage).
• Fault duration times for each breaker (created by the breaker arcing current feature).
The captured data also includes the fault type and the distance to the fault location, as well as the reclose shot number
(when applicable) To include fault duration times in the fault report, the user must enable and configure breaker arcing cur-
rent feature for each of the breakers. Fault duration is reported on a per-phase basis.
The relay allows locating faults, including ground faults, from delta-connected VTs. In this case, the missing zero-sequence
voltage is substituted either by the externally provided neutral voltage (broken delta VT) connected to the auxiliary voltage
channel of a VT bank, or by the zero-sequence voltage approximated as a voltage drop developed by the zero-sequence
current, and user-provided zero-sequence equivalent impedance of the system behind the relay.
The trigger can be any FlexLogic operand, but in most applications it is expected to be the same operand, usually a virtual
output, that is used to drive an output relay to trip a breaker. To prevent the overwriting of fault events, the disturbance
detector should not be used to trigger a fault report. A
FAULT RPT TRIG
event is automatically created when the report is
triggered.
If a number of protection elements are ORed to create a fault report trigger, the first operation of any element causing the
OR gate output to become high triggers a fault report. However, If other elements operate during the fault and the first oper-
ated element has not been reset (the OR gate output is still high), the fault report is not triggered again. Considering the
reset time of protection elements, there is very little chance that fault report can be triggered twice in this manner. As the
fault report must capture a usable amount of pre and post-fault data, it can not be triggered faster than every 20 ms.
Each fault report is stored as a file; the relay capacity is fifteen (15) files. An sixteenth (16th) trigger overwrites the oldest
file.
The EnerVista UR Setup software is required to view all captured data. The relay faceplate display can be used to view the
date and time of trigger, the fault type, the distance location of the fault, and the reclose shot number.
The
FAULT REPORT 1 SOURCE
setting selects the source for input currents and voltages and disturbance detection.
The
FAULT 1 REPORT TRIG
setting assigns the FlexLogic operand representing the protection element/elements requiring
operational fault location calculations. The distance to fault calculations are initiated by this signal. The
FAULT REPORT 1 Z1
MAG
and
FAULT REPORT 1 Z0 MAG
impedances are entered in secondary ohms.
The
FAULT REPORT 1 VT SUBSTITUTION
setting shall be set to “None” if the relay is fed from wye-connected VTs. If delta-con-
nected VTs are used, and the relay is supplied with the neutral (3V0) voltage, this setting shall be set to “V0”. The method is
still exact, as the fault locator would combine the line-to-line voltage measurements with the neutral voltage measurement
to re-create the line-to-ground voltages. See the
ACTUAL VALUES

RECORDS

FAULT REPORTS
menu for additional
details. It required to configure the delta and neutral voltages under the source indicated as input for the fault report. Also,
the relay will check if the auxiliary signal configured is marked as “Vn” by the user (under VT setup), and inhibit the fault
location if the auxiliary signal is labeled differently.
If the broken-delta neutral voltage is not available to the relay, an approximation is possible by assuming the missing zero-
sequence voltage to be an inverted voltage drop produced by the zero-sequence current and the user-specified equivalent
zero-sequence system impedance behind the relay: V0 = –Z0
×
I0. In order to enable this mode of operation, the
FAULT
REPORT 1 VT SUBSTITUTION
setting shall be set to “I0”.
The
FAULT REP 1 SYSTEM Z0 MAG
and
FAULT REP 1 SYSTEM Z0 ANGLE
settings are used only when the
VT SUBSTITUTION
set-
ting value is “I0”. The magnitude is to be entered in secondary ohms. This impedance is an average system equivalent
behind the relay. It can be calculated as zero-sequence Thevenin impedance at the local bus with the protected line/feeder