GE TRANSFORMER MANAGEMENT RELAY 745, Инструкция по эксплуатации

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5-64 745 Transformer Management Relay GE Multilin
5.6 S4 ELEMENTS 5 SETPOINTS
5
The issue of maloperation due to heavy external faults resulting in CT saturation is handled by a programmable timer. The
timer provides the necessary delay for the external fault to be cleared by the appropriate external protection with the added
benefit that if the RGF element remains picked up after the timer expires, the 745 operates and clears the fault. This
approach provides backup protection. Since the RGF element is targeted at detecting low magnitude internal winding fault
currents, the time delay for internal faults is of little consequence, since sensitivity and security are the critical parameters.
For example, consider a transformer with the following specifications:
10 MVA, 33 kV to 11 kV, 10% Impedance, Delta/Wye30
R
g
= 6.3 ohms
Phase CT Ratio = 600 / 1 A
Rated Load Current =
I
rated
= 10 MVA / (
×
11 kV) = 525 A
Maximum Phase-to-Ground Fault Current = I
gf(max)
= 11 kV / (
×
6.3) = 1000 A
For a winding fault point at 5% distance from the neutral:
(EQ 5.10)
From Figure 5–23: Fault Currents vs. Points from Neutral on page 5–63, we see that the I
p
increase due to the fault is neg-
ligible and therefore 3 I
o
= 0 (approximately). Therefore, the maximum phase current = I
max
= I
rated
= 525 A (approx.), and
(EQ 5.11)
The Winding 1 Restricted Ground Fault setpoints are described below:
• W1(3) RESTD GND FAULT PICKUP : Enter the minimum level of ground differential current (in units of Phase CT pri-
mary associated with the winding, where the RGF is set) for the Winding 1(3) Restricted Ground Fault element.
• W1(3) RESTD GND FAULT SLOPE : Enter a slope percentage (of ground differential current to maximum line current).
• W1(3) RESTD GND FAULT DELAY : Enter the time that the Winding 1(3) Restricted Ground Fault element must
remain picked up before the element operates.
Figure 5–26: RESTRICTED GROUND FAULT SCHEME LOGIC
3
3
I
fault
0.05 I
gf max
( )
×
0.05 1000 A
×
50 A
= = =
I
gd
3 I
0
I
g
–
0
I
fault
Phase CT Primary
-------------------------------------------------
–
0 50 A
600
------------
–
0.08 CT
×
Pickup Setting
= = = = =
Slope
I
gd
I
max
-----------
50 A
525 A
---------------- 9.5% (select Slope Setting = 9%)
= = =
Time Delay: dependent on downstream protection coordination (100 ms typical)
Courtesy of NationalSwitchgear.com