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Transformer Design And Protection Presentation Transcript
1.Transformer Design & protection
2.Transformer protection Philosophy
Transformer Faults:
Some discussion on the types of faults and their characteristic is useful in appreciating the protection principle and its limitations / capabilities.
Following types of faults may occur in the transformer:
Ground faults
Phase to phase faults
Inter turn faults
Core faults
3.Externally applied faults
Overload
External short circuit
Over-voltages
Magnetizing inrush
Ferro-resonance
Three characteristic generally provide means for detecting transformer internal faults:
An increase in phase currents
An increase in differential current
Gas formation caused by fault arc.
Transformer Faults:
Some discussion on the types of faults and their characteristic is useful in appreciating the protection principle and its limitations / capabilities.
Following types of faults may occur in the transformer:
Ground faults
Phase to phase faults
Inter turn faults
Core faults
3.Externally applied faults
Overload
External short circuit
Over-voltages
Magnetizing inrush
Ferro-resonance
Three characteristic generally provide means for detecting transformer internal faults:
An increase in phase currents
An increase in differential current
Gas formation caused by fault arc.
4. Fault on a transformer winding is controlled in magnitude by the following factors:
Source impedance
Neutral earthing impedance
Transformer leakage reactance
Fault voltage
Winding connections
5.All type of liquid insulated transformers are more or less amenable to same or similar type of protection scheme. The choice of protection scheme is based on factors like capacity, voltage class, criticality of application etc.
The transformer protection logic fall into the following two major categories, based on fault sensing method
Mechanical protections.
Electrical protection
Source impedance
Neutral earthing impedance
Transformer leakage reactance
Fault voltage
Winding connections
5.All type of liquid insulated transformers are more or less amenable to same or similar type of protection scheme. The choice of protection scheme is based on factors like capacity, voltage class, criticality of application etc.
The transformer protection logic fall into the following two major categories, based on fault sensing method
Mechanical protections.
Electrical protection
6.Liquid insulation transformers offer many option of gas/pressure operated mechanical protections against electrical faults.
The insulating oil when subjected to high temperatures, associated with arcing , decomposes to generate a number of organic gases and hydrogen.
The cellulose material if involved, results in production of oxides of carbon.
Depending upon the type, rating and volume of liquid insulation of the transformer , this basic fact can be utilized in different devices to achieve very fast and useful protection.
Protection against excessive temperature of the transformer winding also need to be incorporated as a protection against overloads and hot spots inside the transformer.
The insulating oil when subjected to high temperatures, associated with arcing , decomposes to generate a number of organic gases and hydrogen.
The cellulose material if involved, results in production of oxides of carbon.
Depending upon the type, rating and volume of liquid insulation of the transformer , this basic fact can be utilized in different devices to achieve very fast and useful protection.
Protection against excessive temperature of the transformer winding also need to be incorporated as a protection against overloads and hot spots inside the transformer.
7.Buchholz protection:
This is essentially a gas operated protection with capability of detecting and warning early about an incipient fault. The relay has two elements 1st stage and 2nd stage. The 1st stage for alarm and the 2nd stage for trip.
The 1st stage work on the accumulation of sufficient gas in the relay chamber and the 2nd stage work on the high velocity of oil caused due to evolution of gases as a result of high energy faults.
The setting of 1st stage is done at collected gas volume of 300 to 500ml.
The setting of 2nd stage is done at oil flow velocity of 100cm/s .
This is essentially a gas operated protection with capability of detecting and warning early about an incipient fault. The relay has two elements 1st stage and 2nd stage. The 1st stage for alarm and the 2nd stage for trip.
The 1st stage work on the accumulation of sufficient gas in the relay chamber and the 2nd stage work on the high velocity of oil caused due to evolution of gases as a result of high energy faults.
The setting of 1st stage is done at collected gas volume of 300 to 500ml.
The setting of 2nd stage is done at oil flow velocity of 100cm/s .
8.Buchholz relay mounting
9.Transformer protection: Mechanical
3. Pressure relief protection:
This is used to evacuate any over pressure inside the transformer to avoid explosion of the transformer tank. It operates instantaneously and trip the transformer if the pressure inside the tank reaches the set value ( 0.5-0.8 kg/ sqcm ). The no of devices and the diameter depends on the size of the transformer.
4. Temperature protection:
The thermal inertia of transformer results in slow reflection of thermal over loadings in oil temperature (OTI). Hence the temperature protection is normally provided on winding temperature (WTI). The winding hot spot temperature is measured indirectly using replica resistance and the CT secondary currents.
3. Pressure relief protection:
This is used to evacuate any over pressure inside the transformer to avoid explosion of the transformer tank. It operates instantaneously and trip the transformer if the pressure inside the tank reaches the set value ( 0.5-0.8 kg/ sqcm ). The no of devices and the diameter depends on the size of the transformer.
4. Temperature protection:
The thermal inertia of transformer results in slow reflection of thermal over loadings in oil temperature (OTI). Hence the temperature protection is normally provided on winding temperature (WTI). The winding hot spot temperature is measured indirectly using replica resistance and the CT secondary currents.
10.The temperature switch , employing mercury contacts, are susceptible to un-wanted operation during jerks on transformer like earthquakes or vibration due to severe faults. Therefore, a time delay of 5 sec is introduced in the trip.
The temperature protection is adequate against over loading. However electrical protection matching thermal characteristics of transformer can be introduced through numerical relay.
The temperature protection is adequate against over loading. However electrical protection matching thermal characteristics of transformer can be introduced through numerical relay.
11.The Electrical protections is further classified as:
Unit protection
Which are operated only for , fault in the protected
transformer.
Non-Unit protection
Which are operated for a fault outside the
transformer also and are known as back up protection
Unit protection
Which are operated only for , fault in the protected
transformer.
Non-Unit protection
Which are operated for a fault outside the
transformer also and are known as back up protection
12.Protection system applied has a very onerous duty of being inactive for the entire life of the protected equipment while being in readiness for operation, when demanded, in a time span of a few milli-seconds.
The application of the protection scheme, power supply, protection logics and the associated isolating devices are all required to play a vital role in the successful performance of this duty.
This aspect is vital in deciding the choice and application of the protection scheme in the first place since it is also vital to ensure that the system does not cause any unwanted interruptions either.
The application of the protection scheme, power supply, protection logics and the associated isolating devices are all required to play a vital role in the successful performance of this duty.
This aspect is vital in deciding the choice and application of the protection scheme in the first place since it is also vital to ensure that the system does not cause any unwanted interruptions either.
13.Biased ( percentage) differential protection:
A normal circulating current differential protection can not be applied to a transformer due to the factors like ratio, tap position and magnetizing inrush etc.
Hence, it is necessary to incorporate the percentage bias in the differential circuit.
The protection becomes sensitive to the most commonly expected , inter turn fault but to a limited extent. Sufficiently , a large no of turns have to be shorted for the protection to actuate.
A normal circulating current differential protection can not be applied to a transformer due to the factors like ratio, tap position and magnetizing inrush etc.
Hence, it is necessary to incorporate the percentage bias in the differential circuit.
The protection becomes sensitive to the most commonly expected , inter turn fault but to a limited extent. Sufficiently , a large no of turns have to be shorted for the protection to actuate.
14. There are two additional necessary feature for this protection applied to the transformer.
Stability during switching in (magnetic inrush)
Stability during abnormal voltage/frequency conditions ( over fluxing)
A biased differential relay operates for a differential current more than preset bias percentage of average through current. This value is considerably small in comparison to the through fault current and the relay become quite sensitive.
Two versions of biased differential relays are normally employed.
Stability during switching in (magnetic inrush)
Stability during abnormal voltage/frequency conditions ( over fluxing)
A biased differential relay operates for a differential current more than preset bias percentage of average through current. This value is considerably small in comparison to the through fault current and the relay become quite sensitive.
Two versions of biased differential relays are normally employed.
15.The relay has minimum operating current setting fixed at 15% of rated current and bias setting in variable steps from 10% to 60%.
The relay has a fixed non linear bias , which itself changes upward with the through current magnitude. Such relay offers a variable minimum operating current setting.
Both alternatives are generally considered equivalent from application point of view.
The magnetizing in rush current contains a large no of 2nd harmonics which is filtered out and used as a restraint to prevent the relay from operating during energization.
The relay has a fixed non linear bias , which itself changes upward with the through current magnitude. Such relay offers a variable minimum operating current setting.
Both alternatives are generally considered equivalent from application point of view.
The magnetizing in rush current contains a large no of 2nd harmonics which is filtered out and used as a restraint to prevent the relay from operating during energization.
16.Under conditions of transformer saturation a high 5th harmonic content is present which can be used as restraint to prevent mal-operation.
Some relays simply filtered out 5th harmonic from operating current, therefore, tend to operate for heavy saturation conditions.
However, the harmonic restraint feature can delay the tripping considerably for high current internal faults, due to possible CT saturation and consequent harmonics.
Hence, it is necessary to incorporate a high set tripping feature ; set at over 10 times of rated current.
Some relays simply filtered out 5th harmonic from operating current, therefore, tend to operate for heavy saturation conditions.
However, the harmonic restraint feature can delay the tripping considerably for high current internal faults, due to possible CT saturation and consequent harmonics.
Hence, it is necessary to incorporate a high set tripping feature ; set at over 10 times of rated current.
17. Some new generation relays do not incorporate harmonic restraint features. They recognize magnetic in rush and over-fluxing by technique of current wave shape identification.
Now-a-days, the trend is to use numerical relays . The basic principle more or less remain same with added advantage of versatility, man/machine interface, event logging and remote communication capability.
Now-a-days, the trend is to use numerical relays . The basic principle more or less remain same with added advantage of versatility, man/machine interface, event logging and remote communication capability.
18.SETTING CALCULATION
SUPPORTIVE CALCULATION TO VERIFY BIAS SETTINGS
Id> 0.2 Iref
Id>> 10 Iref ( should me 10% more than max inrush current)
Id>>>15 Iref
m1 0.2
m2 0.8
Effect of CTs inside delta:
In LV – 21kV side, we have connected 2CTs inside delta and the CTs are connected in such a way to sum the currents during normal operation. As CTs are connected inside the delta, the effective current will be the phase current and not the delta
current. Considering both the factors,
Effective CT ratio will be 12500/2 * 1.732 =10825A.
19.There is no vector correction required as CTs are connected inside the delta.
At normal condition current in HV bias circuit:
Primary current = 600MVA / (1.732 * 765 kV)= 452.83 A
Current in CT Secondary = 452.83 / 500 A= 0.906
Required Ratio compensation = 1 / 0.754= 1.104
At normal condition current in LV bias circuit :
Primary current = 600 MVA / (1.732 * 21kV)= 16,496.2 A
Current in CT Secondary = 16496 / 10825= 1.524 In
Required Ratio compensation = 1 / 1.524= 0.656
SUPPORTIVE CALCULATION TO VERIFY BIAS SETTINGS
Id> 0.2 Iref
Id>> 10 Iref ( should me 10% more than max inrush current)
Id>>>15 Iref
m1 0.2
m2 0.8
Effect of CTs inside delta:
In LV – 21kV side, we have connected 2CTs inside delta and the CTs are connected in such a way to sum the currents during normal operation. As CTs are connected inside the delta, the effective current will be the phase current and not the delta
current. Considering both the factors,
Effective CT ratio will be 12500/2 * 1.732 =10825A.
19.There is no vector correction required as CTs are connected inside the delta.
At normal condition current in HV bias circuit:
Primary current = 600MVA / (1.732 * 765 kV)= 452.83 A
Current in CT Secondary = 452.83 / 500 A= 0.906
Required Ratio compensation = 1 / 0.754= 1.104
At normal condition current in LV bias circuit :
Primary current = 600 MVA / (1.732 * 21kV)= 16,496.2 A
Current in CT Secondary = 16496 / 10825= 1.524 In
Required Ratio compensation = 1 / 1.524= 0.656
20.At - 5 % tap condition current in HV bias circuit:
HV Side current = 600 MVA / (1.732 * 726.75 kV)= 476.67A
Current in CT Secondary = 476.67x 1.104 / 500
With ratio compensation = 1.052
At + 5 % tap condition current in HV bias circuit:
HV Side current = 600 MVA / (1.732 * 803.25 kV)= 431.27 A
Current in CT Secondary = 431.27 x 1.104 / 500
With ratio compensation = 0.952
Differential Current at Tap Extremities:
At -5% Tap Idiff1 = 1.052-1= 0.052
At +5% Tap Idiff2 = 1-0.952= 0.048
HV Side current = 600 MVA / (1.732 * 726.75 kV)= 476.67A
Current in CT Secondary = 476.67x 1.104 / 500
With ratio compensation = 1.052
At + 5 % tap condition current in HV bias circuit:
HV Side current = 600 MVA / (1.732 * 803.25 kV)= 431.27 A
Current in CT Secondary = 431.27 x 1.104 / 500
With ratio compensation = 0.952
Differential Current at Tap Extremities:
At -5% Tap Idiff1 = 1.052-1= 0.052
At +5% Tap Idiff2 = 1-0.952= 0.048
21. 2. Restricted Earth fault protection:
This protection is applied to single winding of the transformer and quite sensitive and straight forward. The relay is high impedance differential relay and remains stable for all out of zone faults. The protection is insensitive to the inter-turn faults.
The gain in protection performance is obtained by:
1.Low instantaneous setting
2.The whole fault current is measured
Therefore, although the prospective current level decreases as the fault position progress nearer to the neutral end of the winding, the square law which controls the primary current is not applicable.
This protection is applied to single winding of the transformer and quite sensitive and straight forward. The relay is high impedance differential relay and remains stable for all out of zone faults. The protection is insensitive to the inter-turn faults.
The gain in protection performance is obtained by:
1.Low instantaneous setting
2.The whole fault current is measured
Therefore, although the prospective current level decreases as the fault position progress nearer to the neutral end of the winding, the square law which controls the primary current is not applicable.
22. WHY REF?
Simple Over current and Differential Protection for a star connected HV winding, as the transformed current and not the actual current is measured on the LV side.
Because of the square law faults in the lower third of the winding produce very little current.
Simple Over current and Differential Protection for a star connected HV winding, as the transformed current and not the actual current is measured on the LV side.
Because of the square law faults in the lower third of the winding produce very little current.
23.SETTING CALCULATION (Low impedance)
OVER HEAD LINE DIFFERENTIAL PROTECTION
CTR HV: 500/1A
CTR LV: 500/1A Relay type : System A - P632
Relay Designation - 87HV
Transformer Data :
Power: 600 MVA
HV voltage: 765 KV
LV1 Voltage: 765 KV
Recommended settings:
Id> 0.1 Iref ( can be sensitive, as CTs are of same ratio & class PS)
Id>>10 Iref
Id>>>15 Iref
m1 0.2
m2 0.8
OVER HEAD LINE DIFFERENTIAL PROTECTION
CTR HV: 500/1A
CTR LV: 500/1A Relay type : System A - P632
Relay Designation - 87HV
Transformer Data :
Power: 600 MVA
HV voltage: 765 KV
LV1 Voltage: 765 KV
Recommended settings:
Id> 0.1 Iref ( can be sensitive, as CTs are of same ratio & class PS)
Id>>10 Iref
Id>>>15 Iref
m1 0.2
m2 0.8
24. Transformer protection : Electrical
3. Over-fluxing protection:
Over-fluxing withstand characteristic of the transformer is invariably inverse time. The protection should match this characteristic. The protection against over-fluxing is provided either by definite time or by IDMT characteristic relay which senses V/f threshold . Separate alarm and trip elements are provided. The alarm function is a definite time delayed and the trip function is an IDMT characteristic.
Transformer voltage equation is given by V/f = køT
Application of the protection from HV side voltage signal results in over/under protection as the factor of no of turns is ignored in the protection.
3. Over-fluxing protection:
Over-fluxing withstand characteristic of the transformer is invariably inverse time. The protection should match this characteristic. The protection against over-fluxing is provided either by definite time or by IDMT characteristic relay which senses V/f threshold . Separate alarm and trip elements are provided. The alarm function is a definite time delayed and the trip function is an IDMT characteristic.
Transformer voltage equation is given by V/f = køT
Application of the protection from HV side voltage signal results in over/under protection as the factor of no of turns is ignored in the protection.
25. IDMT CHARACTERISTIC OF OVER-FLUXING RELAY
26. SETTING CALCULATION
VT Ratio: 765kV/110 volt
Relay type: System A - P632
Relay Designation - 99
Over Fluxing protection:
Continuous over flux withstand capability : 110%
Withstand capability at 120% : 1 minute
Withstand capability at 130% : 30 secs
Withstand capability at 140% : 5 secs
Recommended settings are as below:
Alarms:
Alarms will be generated if V/f value is 1.12 the nominal value after a time delay of 10 secs.
Tripping characteristic:
Over-fluxing tripping IDMT characteristics has to be made as per the transformer withstand specifications .
VT Ratio: 765kV/110 volt
Relay type: System A - P632
Relay Designation - 99
Over Fluxing protection:
Continuous over flux withstand capability : 110%
Withstand capability at 120% : 1 minute
Withstand capability at 130% : 30 secs
Withstand capability at 140% : 5 secs
Recommended settings are as below:
Alarms:
Alarms will be generated if V/f value is 1.12 the nominal value after a time delay of 10 secs.
Tripping characteristic:
Over-fluxing tripping IDMT characteristics has to be made as per the transformer withstand specifications .
27. 4. Back up Earth fault protection:
The back up earth fault protection (51N) take current signal from the neutral CT of the Transformer. This is the last back up protection for un-cleared ground faults.
The back up earth fault protection (51N) take current signal from the neutral CT of the Transformer. This is the last back up protection for un-cleared ground faults.
28.SETTING CALCULATION
CTR HV: 500/1
BACK UP E/F SETTING:
Threshold can be more sensitive to take care of faults near to star point. Normal recommended value is 30% of the rated Full load current.
Pick up setting = Full load current x 30 %
= 452.83 / 500 *0.3= 0.27 A
Time setting fixed to more than zone 3 time of distance relays to provide back up protection for the line protections.
Recommended DT of 2Sec.
Operating time setting of the relay should be more than the operating time of distance zones in line protection relay.
CTR HV: 500/1
BACK UP E/F SETTING:
Threshold can be more sensitive to take care of faults near to star point. Normal recommended value is 30% of the rated Full load current.
Pick up setting = Full load current x 30 %
= 452.83 / 500 *0.3= 0.27 A
Time setting fixed to more than zone 3 time of distance relays to provide back up protection for the line protections.
Recommended DT of 2Sec.
Operating time setting of the relay should be more than the operating time of distance zones in line protection relay.
29. 6. Inter-turn fault and protection:
Statistically, approximately 70-80% of all transformer faults originate as inter-turn faults and finally develop into earth fault and/or phase faults. Short circuit of a few turns of a winding will cause a significantly heavy current in the short circuited portion of the winding, while the terminal currents will be very small because of large turns ratio between the main winding and the short circuited turns.
Most probable reasons for inter-turn faults are :
1. Mechanical forces on the winding due to external short circuits
2. Excessive moisture in the paper insulation of the winding
3. Structural failure of paper insulation due to aging.
Statistically, approximately 70-80% of all transformer faults originate as inter-turn faults and finally develop into earth fault and/or phase faults. Short circuit of a few turns of a winding will cause a significantly heavy current in the short circuited portion of the winding, while the terminal currents will be very small because of large turns ratio between the main winding and the short circuited turns.
Most probable reasons for inter-turn faults are :
1. Mechanical forces on the winding due to external short circuits
2. Excessive moisture in the paper insulation of the winding
3. Structural failure of paper insulation due to aging.
30.The transformers may be subjected to steep fronted impulse voltage originated form lightning and switching having very high equivalent frequency and tend to concentrate on the end windings. This has led to reinforced design of end winding insulation.
However, the reinforced end winding insulation is not comparable to the insulation to the ground and hence a higher probability of part winding flash over exists as against that for flashover to ground.
Inter-turn faults involving very few turns are not detectable. Inter-turn faults involving fairly large number of turns either may be cleared by transformer differential or rate of gas pressure rise in transformer liquid insulation protections.
However, the reinforced end winding insulation is not comparable to the insulation to the ground and hence a higher probability of part winding flash over exists as against that for flashover to ground.
Inter-turn faults involving very few turns are not detectable. Inter-turn faults involving fairly large number of turns either may be cleared by transformer differential or rate of gas pressure rise in transformer liquid insulation protections.
31.Transformer protection Philosophy
The percentage-differential principle, which was immediately applied to transformer protection, provided excellent results in improving the security of differential protection for external faults with CT saturation.
Differential relays are prone to misoperation in the presence of transformer inrush currents resulting from transients in transformer magnetic flux. Three solution emerged to overcome this problem:
To introduce an internal time delay in the relay
Desensitize the relay for a given time to override inrush condition
To add a voltage signal to restrain or supervise the relay.
The percentage-differential principle, which was immediately applied to transformer protection, provided excellent results in improving the security of differential protection for external faults with CT saturation.
Differential relays are prone to misoperation in the presence of transformer inrush currents resulting from transients in transformer magnetic flux. Three solution emerged to overcome this problem:
To introduce an internal time delay in the relay
Desensitize the relay for a given time to override inrush condition
To add a voltage signal to restrain or supervise the relay.
32. Researchers quickly recognized that the harmonic contents of the differential current provided information that helped differentiate faults from inrush condition and led to development of differential relays with percentage-differential harmonic restraint for transformer protection.
The early relays used all of the harmonics for restraint. Later relays with blocking only second harmonic developed and led to development of philosophy of harmonic blocking instead of restraining. Many modern transformer differential relays use either harmonic restrain or blocking method. These methods ensure relay securities for a very high percentage of inrush and over excitation cases. However these methods do not work in cases with very low harmonic contents in the operating current.
Common harmonic restraint or blocking increases relay security for inrush, but it could delay operation for internal faults combined with inrush in non-faulted phases.
Transformer over excitation is another possible cause of differential relay misoperation.
The early relays used all of the harmonics for restraint. Later relays with blocking only second harmonic developed and led to development of philosophy of harmonic blocking instead of restraining. Many modern transformer differential relays use either harmonic restrain or blocking method. These methods ensure relay securities for a very high percentage of inrush and over excitation cases. However these methods do not work in cases with very low harmonic contents in the operating current.
Common harmonic restraint or blocking increases relay security for inrush, but it could delay operation for internal faults combined with inrush in non-faulted phases.
Transformer over excitation is another possible cause of differential relay misoperation.
33.Such misoperation is prevented by an additional fifth harmonic restraint or by methods based on wave shape recognition to distinguish fault from inrush in transformer differential protection relays. However these techniques do not identify transformer over excitation conditions.
The improved approach uses current-only inputs for transformer differential protection. The approach ensures security for external faults, inrush and over excitation conditions and provides dependability for internal faults. It combines harmonic restraints and blocking methods with wave shape recognition technique. The improve method uses even harmonics for restraint and dc component and fifth harmonic to block operation.
The improved approach uses current-only inputs for transformer differential protection. The approach ensures security for external faults, inrush and over excitation conditions and provides dependability for internal faults. It combines harmonic restraints and blocking methods with wave shape recognition technique. The improve method uses even harmonics for restraint and dc component and fifth harmonic to block operation.
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