transmission duong pardo & elmore 500kv bf protection
TRANSCRIPT
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1
500kV IPT
Breaker Failure Protection65 th Annual TAMU Protective Relay Conference
April 2 nd , 2012
Vinh Duong, P. E., PMP ABBJorge L. Pardo, P. E. Progress Energy
John Elmore Power Grid Eng.
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Road Map for the Paper
Introduction Who We Are, What We DoExisting System ConfigurationBrief Overview of Breaker Failure Protection
Need for ImprovementNew Application ConceptConclusions, Where We Go Next
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Who We Are, What We Do3
Progress Energy (March 2012)Utility company head quartered in Raleigh, NCListed in NYSE: PGNTwo operating entities: The Carolinas (PEC) and Florida (PEF)Serves 3.1 millions electric customers22,000 MW of regulated electric generating capacity
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PEF System Configuration
4700 miles of transmission lines including 69kV,115kV, 230kV and 500kVOne nuclear generating site of 860 MW in westernFlorida Additional 13,000 MW from coal, combustion, andoil plants throughout the territory
Five 500kV-230kV substation sites
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500kV Transmission Syst. Protection5
Transmission Lines: Three redundant high-speedpilot schemes Communication means including self-healing multiplexor over
fiber optic network, power line carrier and micro-wave Autotransformers and Substation Buses: Dual
redundant protection packages A dedicated breaker failure protection package
(separate from other relay & control functions) Redundant battery systems with dedicated station
DC load centers
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The Art of Line Protection
To detect transmission line faults andinitiate isolation of that fault on the linesegment with minimal impact to the rest
of the transmission system and to thecustomer.
Do it by isolating the minimum faultedsection in the quickest time.
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Typical 500kV Protection System7
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Breaker Failure Protection Scheme
Expand the clearing area for faults due to breakermis-operation (stuck breaker)Time delayed operation initiated by all trippingrelays using breaker as clearing pointTime coordinated to allow primary zone clearing but faster than other backup functions in order toavoid system instability conditions
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Typical BF Protection Logic9
BF Scheme Needs:BFI input from protection relaysFault detector setting
(*Transformer fault detector if necessary)
BF timer setting
OR AND
TIMER62-1
Breaker FailureScheme Output
50FD87T*
BFI
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Typical BF Timing10
Not a problem if the total fault clearing time is 12+cycles
The total fault clearing time shall not be longer thanthe system critical clearing time
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Line Relay Zones11
instantaneousBlocked
Blocked
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Typical Transmission Line12
t1 time zerot2 relay operate time (1/2 to 3 cycles)
t3 carrier start (immediate)t4 remote carrier received (channel time)t5 trip initiated from relayt6 breaker opens (2-4 cycle mechanical operate times)t7 breaker failure trip (20 cy from trip initiate)
t8 - Zone 2 trip (30 cy) & t9 - Zone 3 trip (90cy)
t1 t2 t3 t4 t5 t6 t7 t8 t9
strike detect
startreceive
Trip
Zone 3
Zone 2
BFoperate
breaker
opentimeline
action
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The Need
With addition of 2 nd nuclear site and expansion of500kV network, the recommended critical clearingtime would be:
5.5 cycles for multi-phase fault8.0 cycles for single-phase fault
Need faster reset times for BF schemes to avoidovertrip
Use of IPT (Independent Pole Trip) breakers
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Can the new scheme Meet the Need?
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Considerations
Relay operating time: 2 cyclesFailed breaker operating time: 2 cyclesRelay 50BF reset time: 1 cycle
BF timer safety margin: 2 cyclesLocal and remote contributing breaker operating time: 2 cyclesDTT channel time: 0.5 cyclesTotal BF times = Critical clearing: 9.5 cycles
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Latency16
Just how fast must it be?
< 6 ms
Telecom Delivers the Message
< 6 milliseconds
Relay/Protection Executes the Action
< 10 milliseconds
Total Time to React< 1 Cycle ~ 16 milliseconds
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What system or relays are available?
Line, auto, and bus differential protection relays to be sub-cycle type
Directly tripping breaker(s) and issuing BFIEliminate auxiliary/tripping relays from the circuitReplace PLC, lease line, and micro-wave with dedicate fiberoptic cable or fiber optic based multiplexor
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Breaker Failure Protection Relay18
BF protection relay to be sub-cycle typeDirectly tripping breakers and DTT
Re-sequence the BF logic to discount fault detector
reset time Allow the BF timer to time out first
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BF Timing Improvement19
Relay operating time: 1 cycles
Failed breaker operating time: 2 cycles
Relay 50BF reset time: 1 cycle
BF timer safety margin: 2 cycles
Local and remote contributing
breaker operating time: 2 cycles
DTT channel time: 0.5 cycles
Total BF times = Critical clearing: 7.5 cycles
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Issues with IPT Breakers21
Low SF6 Gas:Slow leakage to critically low => breaker opens and block closeFast leakage to critically low => breaker block operation andlock into its current position => all three poles inoperable
Loss of Spring Charge:Sudden loss of spring charge => breaker block operation andlock into its current position => all three poles inoperable
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The Solution22
Implement dual BF timer scheme with IPT breakerTypical time = 8.0 cycles for single-phase fault
One IPT pole failsShort time = 5.5 cycles for multi-phase fault
Two or three IPT pole failsBF relay armed to bypass the failed breaker and directly trips thelocal and remote contributing breakers
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Summary
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Multi-Phase Fault BF Time24
Relay operating time: 1 cycles
Failed breaker operating time: 2 cycles
BF timer safety margin: 0 cyclesLocal and remote contributing
breaker operating time: 2 cycles
DTT channel time: 0.5 cycles
Total BF times = Critical clearing: 5.5 cycles
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BF Time with Bypass Logic25
Relay operating time: 1 cycles
Failed breaker operating time: 2 cycles
BF timer safety margin: 0 cyclesLocal and remote contributing
breaker operating time: 2 cycles
DTT channel time: 0.5 cycles
Total BF times = Critical clearing: 3.5 cycles
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Where Do We Go Next26
Consider its expanded use where criticalclearing time margins are becoming morecritical
Continue to expand our fiber network toprovide communications assisted relayingand BF-DTTLook into peer to peer communication
network among IEDs in the substation to cutdown IED contact operating time and wiring
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Questions?
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