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8/10/2019 Protection 11
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Generator & transformer
Protection
Hui Ren
Electrical Engineering Department
North China Electric Power University
Source: Power System Protection, Edited by the Electricity Training Association
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Differential protection
overcurrent protectionEarth fault protection
Overload protection
Loss of field protection
Reverse power protection
Phaseto phase faults
interturn faults
earth faults
earth faults
Loss of excitation
overloading
Reverse power
Stator
faults
rotor
faults
overvoltage
Abnormal
conditionOvervoltage protection
Interturn fault protection
Generator faults, Abnormal
Condition and Protection
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Overall differential protection for phase-to-
phase faults
Overcurrent protection as backup
protection and protection for earth fault.
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(a) Basic differential
overcurrentrelay
(b) percentage
differential relay
Differential Relay
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Percentage-differential relaying for a wye-connected
generator.
Differential Relay
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Percentage-differential relaying for a delta-connectedgenerator.
Differential Relay
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Percentage-differential relay for
a generator and transformer unit
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Inter-turn fault protection
Inter-turn fault can not be detected by the Differentialprotection
Remaining clear of earth, no differential current except fora large current circulating the shorted turns.
Fault evolving and cleared by other protection If the faults occur in the stator slots, they quickly develop
into faults to earth, then cleared by the stator earth faultprotection.
risk If occur at the winding ends, may cause extensive damage
to the generator before the fault evolves to one detectableby other protection.
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High-resistance groundingAdvantages of High-resistance grounding
reduced thermal and mechanical stress inapparatus carrying ground fault current;
reduced shock, burn, and flash hazards topersonnel in the vicinity of a ground fault,
ability to control transient overvoltages due toarcing faults.
For these reasons, most generators usehigh-resistance grounding.
Stator Ground Protection
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drawbacks of High resistance grounding it complicates the detection of ground
faults on the stator winding, particularlywhen the fault is close to the neutral.
Due to the small fault current, thegenerator differential relay is insensitive toa ground fault.
The differential relay has troubledistinguishing the small fault current fromthe third harmonic current that also flows inthe neutral.
Stator Ground Protection
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Two methods of detecting a short circuit to ground
Overvoltagerelay
Stator Ground Protection
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100% of Stator ground protection
Stator Ground Protection
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Rotor earth-fault protection
Utilizing a high resistance connected
across the rotor circuit, the centre point of
which is connected to earth through the
coil of a sensitive relay.
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If the prime mover does not produce sufficient torque todrive the generator, the generator may operate as a motordriving the prime mover. Since this is a potentiallydangerous condition for steam turbines, gas turbines,engines, and some hydro turbines, protection is needed.
The simplest way to provide this protection is with adirectional relay that senses the real (or average) powerflow P, but is insensitive to the reactive flow Q. If the relaydetects P into the generator from the electrical system, thenthe prime mover may have insufficient input power and therelay should trip. The relay may be set to alarm and/or tripafter a time delay of a few seconds.
Reverse Power Relay
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Faults external to the generator are usually cleared quicklyby circuit protection, but failure of remote protection tooperate, or its associated circuit breaker to trip, wouldleave the faulted circuit connected to the genrator.
Phase to ground and phase to phase short circuits
unbalanced loads, and unsymmetrical (non-transposed)transmission lines are produce varying degrees of negativesequence current in the generatorso cause the rotoroverheating. Therefore, the negative sequence protection isone of the primary protection.
the negative sequence relay is a backup protection, since itprimarily protects the generator from faults external to theunit. Because of this, the relay must be coordinated withother relays in the system. Typical relay application is atime-overcurrent relay with a negative-sequence currentmeasuring network
Negative phase-sequence relay
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diagram of a negative phase sequence overcurrent relay
Negative Sequence Relay
Negative phasesequence current
measuring network
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Loss of excitation (field failure)
protection
Loss of excitation results in a generator losingsynchronism and running above synchronous speed.Operating as an induction generator, it would produceits main flux from wattless stator current drawn fromthe power system to which it was still connected.Excitation under these conditions requirescomponents of reactive current which may wellexceed the rating of the generator and so overload the
stator winding.
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Loss of field (loss of excitation) relays arerecommended for generators. If the generator
loses its excitation, then it will draw its excitation
from the electrical system by drawing reactive
power as what an induction machine would,meaning the generator is supplying real power but
absorbing reactive power.
Excitation under these conditions requires
components of reactive current which may well
exceed the rating of the generator and so overload
the stator winding.
Loss of Field Protection
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Loss of Field Protection
Although loss of field can be damaging to the
generator, it is also a system problem that causes low
voltage and resulting in low reactive-power support
of other nearby generators. In some cases, systeminstability could occur because one machine lost its
field at a time when the remaining generators were
heavily loaded with reactive power.
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Introduction
Differential protection
Percentage differential protection Magnetizing inrush current
Overcurrent relays
Pressure relays
Conclusion
Transformer Protection Topic
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Fault, abnormal condition and protection
Differential protection
Overcurrent protection
Overload protection
Overfluxing protection
Overheating protection
Phase to phase faults
interturn faults
Phase to earth faults
Core fault
overfluxing
overheating
tank fault
Introduction
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Differential protection
Similar to that of generators, but
The differential protection system comparesh.v. and l.v. current, which are in a known
relationship under healthy conditions, ratherthan the same current entering and leavingthe protected apparatus, as for generatorprotection.
So, it is capable of detecting interturn shortcircuits, since these change the effectiveoverall transformation ratio of the powertransformer.
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c.t. connection requirements
Giving a through fault balance
No zero-sequence currents;
Phase shift due to the through transformer of
positive and negative-sequence currents mustbe compensated;
Effect of tap changing equipment upon the
overall transformer ratio.
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Two basic requirements that the differential-relay connectionsmust satisfy are:
(1) the differential relay must not operate for load or
external faults;
(2) the relay must operate for severe enough internal faults.
Differential ProtectionDifferential Protection
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Unbalanced currentunbalances between CTs during external faultsarising from an accumulation of unbalances forthe following reasons:
(1) tap-changing in the power transformer;
(2) mismatch between CT currents and relay tapratings;
(3) the difference between the errors of the CTs oneither side of the power transformer;
(4) the inrush current;
Differential Protection
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the CTs on any
wye winding of a
power transformer
should beconnected in delta,
and the CTs on
any delta winding
should be
connected in wye.
Differential Protection
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Connections of Two-winding transformer with differentialrelays.
Percentage (biased) Differential
Protection
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Percentage Differential
Protection
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Problems related to differential relaying of power
transformersdisturbance measurement Side effects 1 Side effects 2 Side effects 3
inrush Accurate estimationof the 2ndand the 5thharmonics takes
around one cycle.
Due to the magneticof the core, the 2nd
and the 5thharmonic
may be jeopardizing
relay security
The harmonicsmayblock a relay during
severe internal faults
due to saturation of CT
The means ofrestraining the
relay from
tripping during
external
faults,inrush and
overexcitation
may Limit the
relay speed ofoperation
overfluxing The 5thharmonic maybe present in internal
fault currents due to
saturation of CT
External fault The measuredcurrents display
enormous rate of
change and are often
significantly distorted
The CTs saturation
during external fault
may produce an
extra differential
signal
All the means of
preventing false tripping
during external faults
reduce to the
dependability of the
relay
Internal fault The internal currentmay be as low an
few percent of the
rated value
The security demandsunder inrush,
overexcitation and
external faults may limit
relay dependability
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the magnetizing inrush may be also caused by
(a) Initial magnetizing due to switching a
transformer in.
(b) occurrence of an external fault, voltagerecovery after clearing an external fault.
(c) when a phase-to-ground fault evolves into a
phase-to-phase-to-ground fault
(d) out-of-phase synchronizing of a connected
generator.
Magnetizing Inrush Current
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When a transformer is switched-off, the
magnetizing voltage is taken away, the
magnetizing current goes to zero while
the flux follows the hysteresis loop of the
core. This results in certain residual flux
left in the core. When, afterwards, the
transformer is re-energized by analternating sinusoidal voltage, the flux
becomes also sinusoidal but biased by the
remaining flux. The residual flux may be
as high as 80-90% of the rated flux, and
therefore, it may shift the flux-currenttrajectories far above the knee-point of
the characteristic resulting in both large
peak values and heavy distortions of the
magnetizing current .
Inrush due to switching-in
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Characteristics of the inrush current
Include a large dc component.Include amounts of higher harmonics , mainly the second harmonic.
Typical Inrush Current
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0
10
20
30
40
50
60
70
2nd
3rd
4th
5th
6th
7th
Harmonic components of the
inrush current
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This is a classical way to restrain the relay from tripping during
magnetizing inrush conditions. As analyzed before, themagnetizing inrush current consists of certain amounts of higherharmonics, but the second harmonic always dominates. Generally,low levels of harmonics indicate internal fault and enabletripping, while high levels indicate inrush and restrain the relay.
For digital relays this may be written as:
Where, Id2is the amplitude of the second Harmonic in the
differential current;
Id1is the amplitude of the power frequency component in
the differential current;
Kis the restraint ratio of the second harmonic, and the
setting is about 0.15-0.2(15-20%).
Second Harmonic Restraint
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The shape, magnitude and duration of the inrushcurrent depend on several factors:
Size of a transformer
Impedance of the system from which a transformer
is energized
Magnetic properties of the core material
Remanence in the core
The moment when a transformer is switched in
How a transformer is switched in
Inrush Current
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Sample inrush currents in a three-phase wye-delta connected
transformers
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Inrush currents measured in separate phases of athree-phase transformer may differ considerably
because of the following:
The angle of the energizing voltages are
different in different phases.
When the delta-connected winding is switched-
in, magnetizing voltages are line voltages.
Depending on the core type and other conditions,only some of the core legs may get saturated.
Inrush in Three Phase
Transformer
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Due to the large and slowly decaying dc component, the inrushcurrent is likely to saturate the CTs even if the magnitude of the
current is comparatively small. When being saturated, a CT
introduces certain distortions to its secondary current. Due to
CTs saturation during inrush conditions, the amount of thesecond harmonic may drop considerably.
Saturation of current
transformers during inrush
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Overcurrent protection
High current settingmust not operate
under emergency loading conditions
Slow operationtime setting may have to
be high in order to grade with other
overcurrent relays on the system
On large transformersas backup
protection for terminal faults, or unclearedl.v. system faults.
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Various types of mechanical relays such as suddenpressure relays and gas-accumulation relays havebeen used for transformer protection.
On the occurrence of an internal transformer fault,
the pressure inside the tank suddenly rises. Thesudden pressure relay senses this, but it isinsensitive to pressure changes that normallyoccur in a transformer during operation. In many
cases, the pressure relay will operate on aninternal fault that does not produce enough currentto trip the differential relays to avoid catastrophicfailures.
Pressure Relay
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Percentage differential protectionApplication: above 6300KVA
Magnetizing inrush current
The cause of magnetizing inrush currentThe characteristics of magnetizing inrush
current
The measures of distinguish inrush current
Overcurrent protection
Application: external phase-fault protection
Conclusion
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No matter what the initial conditions are, when excitation is lost, the equivalent
generator impedance traces a path from the first quadrant into a region of the
fourth quadrant that is entered only when excitation is severely reduced or lost.By encompassing this region within the relay characteristic, the relay will
operate when the generator first starts to slip poles and will trip the field breaker
and disconnect the generator from the system before either the generator or the
system can be damaged.
the most common type of lose-of-
excitation relay is a directional-distance relay measuring the AC
current and voltage at the main
generator terminals. Figure shows
several loss-of-excitation
characteristics and the operating
characteristic of one type of loss-of
excitation relay on an R-X diagram.
Loss of Field Protection