Transmission Protection Overview - Aventri · Communication-Based Protection Rationale Distance...
Transcript of Transmission Protection Overview - Aventri · Communication-Based Protection Rationale Distance...
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Transmission ProtectionOverview
2013 Hands-On Relay SchoolSteven Chase
Schweitzer Engineering Laboratories
Pullman, WA
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Transmission Line Protection Objective
General knowledge and familiarity with transmission protection schemes
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Transmission Line Protection Topics
Primary/backup protection
Coordination
Communication-based schemes
Breaker failure protection
Out-of-step relaying
Synchronism checking
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Primary Protection Function
Trip for abnormal system conditions that may Endanger human life
Damage system equipment
Cause system instability
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Protection Zones
Primary protection first line of defense
Backup protection operates when primary fails
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How Can A Protection System Fail?
Current or voltage signal supply
Tripping voltage supply
Power supply to the relay
Protective relay
Tripping circuit
Circuit breaker
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Two Types of Backup
Remote backup Located at different station
No common elements
Local backup Located at same station
Few common elements– Separate relays
– Independent tripping supply and circuit
– Different current and voltage inputs
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Remote vs Local Backup
Speed Remote is slower
Selectivity Remote disconnects larger part of the
system
Price Local requires additional equipment
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Primary and Backup Coordination
Best selectivity with minimum operating time
Backup achieved through settings Pick up values
Time delays
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Coordination Types Considered
Time-Overcurrent
Time-Stepped Distance
Communication-Aided Schemes
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Time-Overcurrent Relays
Definite-Time Overcurrent Operate in a settable time delay when
the current exceeds the pickup value
Instantaneous operation – no intentional time delay
Inverse-Time Overcurrent Operating curve chosen as a function
of the damage curve of the primary equipment
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Time-Overcurrent CoordinationInverse-Time Overcurrent
Pickup of relay A set low enough to see the fault shown and backup relay C
Pickup should be above emergency load conditions (phase relays)
Time delay of relay A should allow relay C to clear the fault first
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Time-Overcurrent Coordination
S - Selectivity time delay (aka CTI): Breaker operating time
Overtravel (impulse) time (E/M relays)
Safety margin
0.2s ≤ CTI ≤ 0.4s
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Time-Overcurrent CoordinationLooped Systems
Directionality required for most relays
1-2-3-4-5
a-b-c-d-e
Relays at ‘5’ and ‘e’ can be nondirectional
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Instantaneous Overcurrent Protection
Inverse-Time O/C coordination may result in long time delays
Instantaneous O/C relays set to trip for faults for ~80% of the line section Significantly reduced tripping times for many faults
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Time-Stepped Distance Protection
Coordination similar to that of inverse-time O/C
Relay at A set to trip instantaneous for faults in its Zone 1 (reaching ~80% of the line section)
Relay at A backs up relay at C after Zone 2 timer times out
Faults at the end of the line also cleared in Zone 2 time
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Communication-Based ProtectionRationale
Distance protection can clear faults instantaneously for 60% to 80% of the line length
Protection speed may be critical to maintain system stability
High-speed autoreclosing application
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Communication-Based ProtectionCommunication Mediums
Power Line Carrier
Microwave
Fiber-Optics
Pilot Channels (Private and Leased)
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Communication-Based ProtectionScheme Types
Permissive Overreaching Transfer Trip (POTT)
Permissive Underreaching Transfer Trip (PUTT)
Directional Comparison Blocking (DCB)
Directional Comparison Unblocking (DCUB)
Direct Underreaching Transfer Trip (DUTT)
Direct Transfer Trip (DTT)
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Permissive Overreaching TTProtective Zones
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Permissive Overreaching TT
Permissive signal must be detected from the remote end for the communication-aided trip
Absence of communication channel disables the accelerated tripping
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Permissive Overreaching TTComplications and Concerns
Desensitization due to infeed Dependability issue – failure to trip high
speed
Current reversal Occurs in parallel lines with sequential
tripping
Security issue – coupled with long channel reset times may cause trip of the healthy parallel line
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Current ReversalAll Sources In
Z2 at Breaker 1 picks up and sends permissive signal to Breaker 2
Z2 at Breakers 3 and 4 send permissive signals to each other
Z1 at Breaker 4 trips instantaneously
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Current ReversalSystem After Breaker 4 Opens
Current reverses through the healthy line
Z2 at Breaker 2 picks up
If the permissive signal has not reset, Breaker 2 trips on POTT
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Current ReversalPossible Solution
Timer with instantaneous pickup and time delayed dropout, initiated on reverse Z3
Delay trip with POTT until the timer drops out
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Permissive Underreaching TT
Similar to POTT but permissive signal sent by underreaching Z1 elements
At the receiving end, Z2 elements qualify the permissive signal
No problems with current reversal since Z1 doesn’t overreach
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Directional Comparison BlockingProtective Zones
Zone 2 elements cover the entire line
Reverse Zone 3 elements must reach further than the opposite Zone 2 overreach
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Directional Comparison BlockingBasic Logic
In-section faults will not key transmitter and both ends trip high-speed
Out-of-section fault will key the transmitter at the nearest end to block the trip at the opposite end
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Directional Comparison BlockingComplications and Concerns
Coordinating time at fault inception Z3 faster than Z2, but channel delay time reduces
the margin
Z2 must be slowed down
External fault clearing Z3 and Z2 race to drop out, if Z3 drops out first Z2
overtrips
Z3 operates faster and drops slower
Channel reset time helps
Slower transmitter key dropout time helps
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Directional Comparison BlockingComplications and Concerns
External fault clearing failure Local backup provided by time-delayed Z3 or
external BF relay clears the near bus
Remote backup provided by Z2 clears the line
Stop preference over start
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Directional Comparison BlockingComplications and Concerns
Current reversal
Reach Margin Z3 reaches farther back than remote Z2 by at least
50% of Z2 overreach
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Directional Comparison Unblocking
Essentially the same as POTT
Requires FSK
In-section fault may impede communication
In case of channel loss, a 150 ms window is open when permissive signal is bypassed and Z2 allowed to trip high speed
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Direct Underreaching TT
Underreaching Z1 elements send direct transfer trip
Noisy channel can cause false trip
Very secure channel required
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Pilotless Accelerated Trip Schemes
Communication equipment not justifiable in lower voltage transmission applications
In-section faults may be uniquely determined by system conditions
Detecting these conditions is all that is needed for high speed tripping
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Pilotless Accelerated Trip SchemesFaulted System with Breakers Closed
After Breaker 2 opens the only current that can flow is the fault current
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Pilotless Accelerated Trip SchemesFaulted System with Breaker 2 Open
Tripping conditions:
Three-phase load was present before the fault
Three-phase current was lost
Current above the threshold detected in at least one phase
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Breaker Failure Relaying
Minimize the damage when a breaker fails to clear a fault
Trips all sources locally within the critical clearing time to maintain system stability
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Breaker Failure RelayingCommon Causes of Breaker Failure
Main breaker poles failed to clear the fault due to inadequate insulating medium
Open trip coil or trip coil circuit
Loss of tripping dc
Mechanical failure of the breaker trip mechanism
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Breaker Failure RelayingOperating Philosophy
Activated only when a trip signal is issued from protective relay
If current is above threshold after a pre-set time period, breaker failure condition is declared
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Breaker Failure RelayingConsiderations
Timer settings must take into account the clearing time of the slowest breaker and the reset time of the fault detector
The effect of CT subsidence current on the apparent current dropout time
Substation bus configuration must be taken into account to trip minimum number of breakers
In multi-breaker schemes, possible transfer trip to the remote end
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Out-of-Step Detection and BlockingCauses of Out-of-Step
Power swings result from faults, switching, or big changes in load or generation
Magnitude of the swing depends on the system impedance change during such conditions
Swings can be stable or unstable
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Power Transfer Equation
,
sin
where:power transferred from the sending to the receiving endsending end voltagereceiving end voltage
angle by which leads total reactance between the sending and rece
S RS R
S
R
S R
V VP P PX
PVV
V VX
iving end
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Power Transfer Curves
,
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Electrical Quantities During SwingApparent Impedance Trajectories
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Electrical Quantities During SwingApparent Impedance Trajectories
Apparent impedance during power swings can enter into the reach of distance relays
If the apparent impedance stays longer than the time delay in a given zone, that distance element will trip as for a fault
To prevent such tripping, out-of-step blocking schemes are employed
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Out-of-Step Blocking Distance Elements
If the timer expires between the two zones,out-of-step condition is declared and selected distance elements are blocked
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Synchronism Checking
After clearing a fault, one end of the line will reclose to “test” the line
If the test is good, the other end can be closed but only if voltages are close enough and there is a small phase angle difference
If the conditions are not right, the system will undergo a mechanical and electrical shock with a possible unstable swing
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Synchronism CheckingMonitored Quantities
Voltage magnitudes
Phase angle difference
Slip frequency
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Synchronism CheckingSynchronizer Window
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Synchronism CheckingConditions
Both voltage phasors are above 59V setting
Phase angle difference is small
The above conditions are maintained for at least a short time, ensuring that the slip frequency is small enough and measurements are valid
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Synchronism Checking Relay
Phasor difference setting
Timer setting
The measured phasor difference should be below the setting for the given time
Different than a synchronizing relay
25DV 59V sin
225T360 f
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Questions?