3.Application of Dist Prot With KD Appendix
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Transcript of 3.Application of Dist Prot With KD Appendix
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8/6/2019 3.Application of Dist Prot With KD Appendix
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Knowledge Is PowerSMApparatus Maintenance and Power Management
for Energy Delivery
Application of Distance ProtectionJay Gosalia
Vice President of Marketing
Doble Engineering Company
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Distance Protection
3 Zones of protection
Zone 1 operates with no intentional time
delay
Zone 2 provides back up protection to Zone
1 and operates with some time delayZone 3 typically has offset characteristic
and has a time delay longer then Zone 2
Zone 2 and Zone 3 are used in pilotscheme if employed
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General Application Rules
Zone 1 protects 80-85% of line length AB
Zone 2 protects line AB + 50% of line BC Zone 3 Protects AB + Line BC + 20-30% of line CD + 20-30%
of line behind terminal A
Zone 1 protects 80-85% of line length AB
Zone 2 protects line AB + 50% of line BC
Zone 3 Protects AB + Line BC + 20-30% of line CD + 20-30%
of line behind terminal A
AB DC
Time
Zone 1
Zone 2Zone 3
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Reach Setting Criteria : Zone 1
Zone 1 should never over reach for the faults on or
beyond remote terminal
Considering 5% accuracy of CTs and PTs maximum
reach of Zone 1 can be 90% of line length AB
Considering accuracy of Zone 1 protection 5% and safety
margin of 5% Zone 1 reach can be 80% of the line length. In some instances based on the previous practices Zone
1 is set to 90% of line length
It is safe to set Zone 1 reach 80% of line length in general
A BDC
Zone 1
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Zone 1: Requirements
Should cover the protected circuit and shouldprovide good fault resistance coverage Fast operation for limiting the system disturbance Directional discrimination for security and reliability
AB
DC
Zone 1
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Reach Setting Criteria : Zone 2
Zone 2 should always over reach for the faults on or
beyond remote terminal Zone 2 should always reach beyond the remote terminal andcover at least 50% of next line section
Zone 2 time delay should be larger then the operating timeof Protection + CB (at terminal C of line CD) + safety margin
Breaker fail timer co ordination is required
Zone 2 is used in the pilot aided trip scheme to provideinstantaneous protection for faults anywhere on line BC
AB C
D
Zone 2
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Zone 2 Time Delay : Criteria
Determine Zone 2 time if Breaker fail protection is employed
Breaker fail protection clears the fault by tripping back up breaker ifthe primary breaker fails to clear the fault after the protection trip
For fault on line CD, protection at breaker 5 will see the fault andissues a trip command to breaker 5 and at the same time initiatesbreaker fail protection
If breaker 5 trip it resets the breaker fail protection
The fault is seen by the protection at breaker 3, in Zone 2.
If breaker 5 fails then Breaker fail protection trip all breakers at bus C
What should be the Zone 2 time delay for protection at breaker 3?
1 2 3 4 5 6
B CA D
Zone 2
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Breaker Fail Scheme
Breaker fail scheme principle Consists of a timer, high speed pick up/drop out over
current protection and lock out protection
Some time re-trip protection is employed Needs 52a breaker input to sense breaker status
When protection operates it initiates breaker fail
scheme Timer is starts and seals in with the high speed over
current protection
Issues re trip command to second trip coil of the breaker
If breaker trips then 52a resets the timer and at the sametime over current protection.
If breaker fails to trip then timer times out and picks up lockout protection to trip the back up breakers connected to the
bus
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Breaker Fail Protection Logic
OR62X
62Y
AND50 Timer86
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Timing Diagram : Normal Operation
Operating
Time of CB: 2Cy.
Protection
Trip: 1Cy.
Drop out time
Of current prot : 1 Cy.
Margin: 5 Cy.
Breaker fail timer time delay : 7 Cy.
Breaker fail protection start
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Timing Diagram : Failed CB
Operating
Time of CB: 2Cy.
Protection
Trip: 1Cy.
Drop out time
Of current prot : 1 Cy.
Margin: 5 Cy.
Margin
7 Cy.
Operating
Time of CB: 2 Cy.Breaker fail
Protection trip : 0.5 Cy
Breaker fail timer time delay : 7 Cy.
Breaker fail protection start
Remote Zone 2 Back up protection operation time :say 20 Cy.
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Reach Criteria Zone 3
Zone 3 is a back up protection and last resort for the
isolation of the fault if everything fails
Time Delayed protection. Time delay is longer thenZone 2 delay
When a very long line is following the short line Zone
3 reach may be very long Can interfere with load on the line
Lens characteristic is a potential solution
It is used in the pilot aided protection when blocking
scheme is employed to detect the fault direction
Typically set in the offset mode to cover the reverse
fault
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Zone 3 : Load Encroachment
Load
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Zone 1 Reach : 3 Terminal Line
X
Y
ZIx
Iy
Ix + Iy
F
Fault voltage at X = VF
= Ix*ZF
+ Iy* (1-d)ZFFault current at X = Ix
Apparent Impedance at X =VF/IF= VF/Ix =ZF + Iy/Ix (1-d)ZFAdditional impedance due to in feed = Iy/Ix (1-d)ZFFault will be seen farther: Protection will not trip
Fault voltage at X = VF = Ix*ZF + Iy* (1-d)ZFFault current at X = Ix
Apparent Impedance at X =VF/IF= VF/Ix =ZF + Iy/Ix (1-d)ZFAdditional impedance due to in feed = Iy/Ix (1-d)ZFFault will be seen farther: Protection will not trip
d
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Zone 1 Reach : 3 Terminal Line
X
Y
ZIxF
Lets Set the reach considering maximum in feed so protection tripsNow say breaker at Y is out for maintenance
Now the fault in the next line section will be seen as internal
Protection will trip for the external fault
Lets Set the reach considering maximum in feed so protection trips
Now say breaker at Y is out for maintenance
Now the fault in the next line section will be seen as internal
Protection will trip for the external fault
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Rules for Zone 1 and Zone 2 Reach
Zone 1 should never overreach and Zone 2 shouldalways over reach the remote terminal
For 3 terminal line set the
Zone 1 Reach As if there is no in feed
Set the Zone 1 only up to tap point
Zone 2 Reach
Set the Zone 2 reach considering maximum in feed
General rule and good practice for Zone 1 Its better not to trip for an internal fault then to trip for the
external fault
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Phase to Phase Fault
Phase to phase fault MHO is an ideal characteristic Fault resistance is arc resistance
Fault current = V/(Zs+ZL+ Rarc)
Arc resistance inversely proportional to current and directlyproportional to line spacing
Rarc = (8750 * L)/ I1.4
For strong source: lower Zs, creates high fault current,
produces lower arc resistance For weak source : higher Zs, creates lower fault current,
produces higher arc resistance
For phase to phase fault MHO characteristic adjusts basedon the source impedance
A
B
C
GZs
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Arc Resistance
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Phase to Phase Fault: Fault Resistance
Phase-Phase faultsconsist only of arcresistance Earth faults consist ofarc and tower footingresistance
A i t C
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Arc resistance Coverage
ZR
Zs
Rarc
ZR
Zs
Rarc
Strong source, Lower Zs, smaller Rarc, lower expansion = Good Rarc coverage
Weak source, Higher Zs, larger Rarc, higher expansion = Good Rarc coverageStrong source, Lower Zs, smaller Rarc, lower expansion = Good Rarc coverage
Weak source, Higher Zs, larger Rarc, higher expansion = Good Rarc coverage
P S i
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Power Swing
Variation in power flow Sudden removal of fault
Loss of synchronism between ends of power system
Change in the direction of power flow
Protection on the system may see the impendencemoving from load condition to its operating zone.
During transient condition Protection should not trip
Only protection that requires system disconnectionat suitable point should trip
To prevent tripping some type of sensing need to
be employed to distinguish between power swingand actual fault
Requires Power Swing Blocking Protection
P S i
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Power Swing
Power Flow from A to B EA leads EB by angle
Total impedance : Z=ZSA +ZL+ZSB
Current I = (EA-EB)/Z
Voltage E at the Relay = EA-I*ZSA
Power Flow from A to B EA leads EB by angle
Total impedance : Z=ZSA +ZL+ZSB
Current I = (EA-EB)/Z
Voltage E at the Relay = EA-I*ZSA
A B
EA EB
21
ZsBZL
ZsA
E
I
P S i N l C diti
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Power Swing : Normal Condition
ZR=E / I
B
EA EB
21
ZsBZL
ZsA
E
I
EB
I I*ZSA
EA
E
EA - EB
EA - EB
P S i Ab l C diti
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Power Swing : Abnormal Condition
ZR is much smaller then ZR
E is small
EA-EB is large due large
ZR is much smaller then ZR E is small
EA-EB is large due large
I
EB
I*ZSAEA
E EA - EB
ZR=E / I
B
EA EB
21
ZsBZL
ZsA
E
I
Power Swing
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Power Swing
EB
II*ZSA
EA
E
EA - EB
EA - EBEB
I*ZSAEA
E EA - EB
Power Swing : Locus
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Power Swing : Locus
P.S. LOCUS
LOAD
R
PSB
ZSB
Z L
ZSA
O
Z
X
MHO Characteristic : Power Swing
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MHO Characteristic : Power Swing
P.S. LOCUS
LOAD
R
ZSB
Z L
ZSA
X
QUAD Characteristic : Power Swing
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QUAD Characteristic : Power Swing
P.S. LOCUS
LOAD
R
ZSB
Z L
ZSA
X
Switch ON to Fault
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Switch ON to Fault
Ensures inst. Trip under switch on to fault condition whenline is energized with earthing clamps connected tobreaker terminals
Need for SOTF
Protection against close up 3 Phase Faults when line
VTs are used When used with Bus PT pre fault memory polarization
can provide tripping through distance protection
Distance Protection: Switch ON to
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Fault
Distance Protection: VT Supervision
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Distance Protection: VT Supervision
Condition shall be Detected when;3Vo > 20% of VN (L-N) & 3Io < 20% of IN
FUSE FAILURE WILL CAUSE VOLTAGE UNBALANCEAND HENCE VO(V2) BUTNO CURRENT UNBALANCE IO(I2)UNBALANCED FAULTS CAUSE BOTH VOLTAGE/CURRENTUNBALANCE,PREVENTING VTS OPERATIONFUSE FAIL SUPERVISION IS BLOCKED FOR 150 TO 300ms FOLLOWING LINEENERGIZATION IN ORDER NOT TO OPERATE FOR UNEQUAL POLE CLOSING &ALSO DURING AUTO-RECLOSING
Distance Protection: Setting Criteria
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Distance Protection: Setting Criteria
Distance Protection: Setting Criteria
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Distance Protection: Setting Criteria
Distance Protection: Setting Criteria
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Distance Protection: Setting Criteria
Distance Protection: Setting Criteria
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Distance Protection: Setting Criteria
Distance Protection: Setting Criteria
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Distance Protection: Setting Criteria
Distance Protection: Setting Criteria
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Distance Protection: Setting Criteria
PERMISSIVE OVERREACHING SCHEMES AREADOPTED FOR SHORT LINES ( ALSO CALLEDDIRECTIONAL COMPARISON SCHEMES) ADVANTAGESARE; BETTER PERFORMANCE FOR HIGH RESISTANCEFAULTS. SUPERIOR TO PILOT WIRE AS DIGITAL DECISIONSARE EXCHANGED AND NOT ANALOGUE SUPERIOR TO PHASE COMPARISON WHICHREQUIRES FAITHFUL TRANSMISSION OF PHASEINFORMATION.
Distance Protection: Setting Criteria
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g
Communication signal is sent to remoteend when the fault is detected in the reversedirection. Tripping is achieved when thisblocking signal is not received within a timeT0 (20-40 ms) and the local relay hasdetected a fault in the forward direction.
Distance Protection: Setting Criteria
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g
Distance Protection: Setting Criteria
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g
BLOCKING SCHEMES ARE USED WHENCOMMUNICATION SIGNALS SHALL NOTBE TRANSMITTED OVER FAULTY LINEFOR RELIABILITY REASONS
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