2. Objective
Understand why transformer inrush
occurs
Understand the characteristics of an
inrush waveform
Understand the impact transformer
inrush can have on differential relays
Discuss various methods to reliably
restrain differential relay operation
3. Basics of Differential Relays
Very Simple –
Sum of All
currents should
be zero.
Must Compensate
for Phase Shift and
Magnitude
Difference
6. What is Inrush Current
All transformers must establish flux in the transformer core
This flux causes a current to flow known as the
magnetizing current
Magnetizing current appears as differential current
7. Steady State Magnetization
Current
Non-Linearity of the core results in a non-linear
magnetizing current waveform
Notice flux lags excitation voltage by 90 degrees
Steady State Magnetizing current is in the range of 1-3% of
XFMR FLA
8. Magnetizing Current Under
Non-Steady State Conditions
When an abrupt change in excitation voltage occurs, a
large magnetizing current can flow.
The Magnetizing Inrush Current is dependant on several
factors, which will be discussed on the following slides
9. Impact of Switching Point
Highest magnitude inrush occurs when excitation voltage is
applied at zero crossing.
Lowest magnitude inrush occurs when excitation voltage is
applied at –90 degrees.
Time
e
ϕ
Start of event
Time
e ϕ
Start of event
10. Impact of Remnant Flux
Remnant Flux can be positive or negative
This can lead to increased or decreased magnetizing
inrush current
11. Impact of Power System
Impedance
The peak magnitude of the inrush current is
dictated by the strength of the power system
source
The duration of an inrush event is dictated by the
resistive losses in the circuit
12. Impact of Transformer Design
Electrical steel has remained fairly
constant over the years
Laminated core designs lead to lower
reluctance cores
Lower reluctance cores are more
efficient leading to lower magnetizing
current
17. When Does Inrush Occur?
During Transformer Energization:
Typically the most severe case, because excitation voltage is going
from zero to maximum value
During Post Fault Voltage Recovery:
During a fault the system voltage is depressed, and then returns to
full value
Not typically as sever as Energization because Flux won’t be fully
offset from excitation voltage
Sympathetic Inrush:
18. Inrush Restraint Methods
As shown earlier, high levels of inrush
current can cause differential relay
misoperation
We need to identify this condition and stop
the differential relay from operating while
inrush condition is present
Many methods exist, all rely on the
characteristics of the inrush waveform
19. Percentage of Total Harmonic
This method utilizes the fact the inrush
waveform is rich in harmonics.
EM relays applied this per phase.
Problems
More efficient core designs produce less harmonic
content
CT Saturation essentially creates a setting “floor”
22. Typical 2nd Harmonic Ratios
Typical values of 2nd
harmonic to
fundamental ratios in
the range of 10%-
60%
Can be much lower as
shown
Microprocessor relays
have introduced
methods to deal with
this problem
23. Percentage of 2nd Harmonic
This method utilizes the fact the inrush
waveform has a dominant second
harmonic component.
EM relays applied this per phase.
CT Saturation still a problem
24. Percentage of 4th Harmonic
This method utilizes the fact the inrush
waveform is not symmetric, leading to even
harmonics
Used in some microprocessor relays
CT Saturation still a problem
No significant benefit over 2nd harmonic
methods
25. Waveshape Based Method
Relies on flat spots
near zero value
CT saturation can
compromise
security and
dependability
Were used widely
in solid-state
relays
26. Adaptive 2nd Harmonic Method
Method utilizes 2nd
Harmonic
Magnitude and
Angle
Dynamically
restrains over a
maximum of 6
cycles
May slow
operation by a few
cycles if 2nd
harmonic current
is present
27. How to Apply Various
Methods?
EM relays typically used either % total
harmonic or % 2nd harmonic methods
EM relays applied them on a per-phase
basis
Microprocessor relays can apply many
methods on a per-phase, 1 out of 3
(cross blocking), 2 out of 3, or average
basis
Pros and Cons to each
28. Considerations When Applying
Harmonic Restraint
Reliability – Ability for the differential
relay to operate on all internal faults
Security – Ability for the differential relay
to restrain for all transformer inrush
events
Speed – How quickly internal faults are
cleared
No method is best, depends on user
requirements
29. Considerations When Applying
Harmonic Restraint
1 out of 3 (Cross Blocking)– Very secure,
but can reduce reliability or speed:
Consider fault during energization
Per Phase – Less secure, very reliable:
Consider low 2nd harmonic inrush
2 out of 3 – More secure then Per Phase,
potentially less reliable
Averaging Method – More secure then
Per Phase or 2 out of 3, no compromise
on reliability
30. Transformer Inrush Impact on
Generator Differential
High DC component of Inrush may saturate
Gen CT’s.
Using harmonic restraint is not a good
solution, adds too much delay
87G
31. Transformer Inrush Impact on
Generator Differential
Flux balanced CT configuration can be used on
smaller Generators
32. Transformer Inrush Impact on
Generator Differential
For problem installations, transformer CB close
can be used to delay 87G
87G
Transformer Close CB Command
Delays 87G Relay
33. Importance of Good
Waveform Capture
Depending on specific system conditions and transformer
design, varying levels of 2nd harmonic content may be
present
It is in the users best interest to capture inrush
waveforms whenever possible
If a fairly complete library of actual waveform data is
available, this can be used to fine tune settings and
evaluate new methods
34. Conclusion
Transformer Inrush will occur anytime a change to
the transformer excitation voltage occurs
Transformer Inrush appears as differential current to
the transformer differential relay
2nd harmonic based methods should not be set lower
then 15% otherwise dependability is put at risk
Many blocking methods exist, however, they pose
various compromises to security, reliability, and
speed.
The right choice of blocking method depends on the
individual user
Generator Differential relays can also be impacted by
transformer inrush