Download - 05 SEP-602B RED670 1p1 Current Functions
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ABB
AB,
2007
2008-01-30 Substation Automation and Protection Training
RED670 Line DifferentialProtection IED
Current functions
Substation Automation andProtection Training
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2007
2008-01-30 Substation Automation and Protection Training
Instantaneous phase overcurrent, IOC max
2 instances
Four step phase overcurrent, TOC, 1
instance
Instantaneous residual current, IEF, 1instance
Four step residual overcurrent, TEF, max 1
instance
RED 670; Current functions
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2007
2008-01-30 Substation Automation and Protection Training
RED 670; Current functions
Breaker failure protection, BFP, max 2 instances
Stub protection, STB, max 2 instances
Thermal overload protection, THL, max 2 instances
Pole Discordance, PD, max 2 instances
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2007
2008-01-30 Substation Automation and Protection Training
IOC, TOC, THL, BFP and PD are standard in the pre-
configured variants:
A31 3ph 1 CB
A32 1ph 1 CB B31 3ph 2 CB
B32 1PH 2 CB
RED 670; Current functions
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2007
2008-01-30 Substation Automation and Protection Training
Instantaneous Phase Overcurrent function (PIOC, 51)
Set as instantaneous protectionwhere the fault current is limited todefined maximum values e.g. froma long power line or a transformerreactance.
Low transient overreach to allowsetting close to the maximumthrough fault current level
High speed to give fast faultclearance at heavy fault currents
Can give phase information and beused with Distance protection as
fast optional function also givingsingle phase tripping
Current can be summated from two(or more) current input sets.
IF
3I>>
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2008-01-30 Substation Automation and Protection Training
OpMode = 1out of 3 or 2 out of 3
IP>> = The setting threshold for the current function
StVaMult = A multiplication factor for increase of IP>> by
activating input ENMULT
Instantaneous Phase Overcurrent function (PIOC, 51)
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2008-01-30 Substation Automation and Protection Training
PIOC,51; Calculation of settings
Select IP>> = max(IfB,IfA)
Consider also eventual transient overreach due to
possible dc component of the fault current
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2008-01-30 Substation Automation and Protection Training
Consider also the effect of parallel line when applicable
PIOC,51; Calculation of settings
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2007
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PIOC, 51; Function block
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2007
2008-01-30 Substation Automation and Protection Training
Phase Overcurrent function (TOC, 51_67)
Four stage Phase overcurrent.
Each stage can be setDirectional or Non directional
Each stage can be Definite- orInverse time delayed.
19 IEC/ANSI curves
Logaritmic invers
Taylor made curve is available
Each stage can be blocked fromsecond harmonic inrush currents.
With directional memory
Current can be summated from two(or more) current input sets.
IF
3I>
4
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en05000740_ansi.vsd
Direction
Element
4 step over currentelement
One element for eachstep
HarmonicRestraint
Mode Selection
dirPhAFlt
dirPhBFlt
dirPhCFlt
harmRestrBlock
enableDir
enableStep1-4
DirectionalMode1-4
faultState
Element
faultState
I3P
V3P
I3P
PICKUP
TRIP
Phase Overcurrent function (PTOC, 51_67)
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2008-01-30 Substation Automation and Protection Training
Phase Overcurrent function (PTOC, 51_67)
The filtering principal can be
selected to Discrete Fourier
Filtering (DFT) or true RMS
(RMS) by the setting
parameter MeasType
DFT filer out the fundamental
component which is most
common in normal line
protection applications
RMS gives a current which
includes harmonics, which is
usefull in shunt capacitor
applications
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Phase Overcurrent function (PTOC, 51_67), - Application
Back-up selectivity with directionand different time grading in bothdirections
IF
3I>
4
G
G67/51
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PTOC, 51_67; Direction
Uref
Idir
RCAROA
Forward
ROA
en05000745.vsd
Reverse
The direction is determined by
checking the angle of U and I
Voltage is the angle reference
Lagging current is plus angle
With directional memory
Direction can be set
Off/Non-directional
Forward/Reverse
RCA ~ 10-40
ROA ~ 100-150
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TOC, 51_67; Reset possibilities
3ANSI Reset
(Inverse time)
2IEC Reset
(constant time)
1Instantaneous
Curve Index no.Curve name
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2008-01-30 Substation Automation and Protection Training
4-step Phase overcurrent protection (TOC)
110-150
10-40
jX
R
Forward operation
Reverse operation
Forward operation
Reverse operation
The direction is determined by
checking the angle of U and I
Voltage is the angle reference
Lagging current is plus angle
With directional memory
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TOC, 51_67; Polarizing voltages
Polarizing voltages at phase to phase fault
L2-L1 UU=2L1LUref
L3-L2 UU=3L2LUrefL1-L3 UU=1L3LUref
L2-L1 II=2L1LIdir
L3-L2 II=3L2LIdirL1-L3 II=1L3LIdir
Polarizing voltages at phase to earth fault
L1U=1LUref
L2U=2LUref
L3U=3LUref
L1I=1LIdir
L2I=2LIdir
L3I=3LIdir
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OC4PTOC_51_67
TOC1-
I3P
U3P
BLOCK
BLKTR
BLKST1
BLKST2
BLKST3
BLKST4
ENMULT1
ENMULT2
ENMULT3
ENMULT4
TRIP
TR1
TR2
TR3
TR4
TRL1
TRL2
TRL3
TR1L1
TR1L2
TR1L3
TR2L1
TR2L2
TR2L3
TR3L1TR3L2
TR3L3
TR4L1
TR4L2
TR4L3
START
ST1
ST2
ST3
ST4
STL1
STL2
STL3
ST1L1
ST1L2
ST1L3
ST2L1
ST2L2
ST2L3
ST3L1
ST3L2
ST3L3
ST4L1
ST4L2
ST4L3
2NDHARM
DIRL1
DIRL2
DIRL3
VisioDocument
When activated, the current multiplier InMult
(n=1 for step1 etc) is in use for step1, Step2,
step3 and step4 for increasing the operate
level
TOC, 51_67; Function block inputs
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2008-01-30 Substation Automation and Protection Training
OC4PTOC_51_67
TOC1-
I3P
U3P
BLOCK
BLKTR
BLKST1
BLKST2
BLKST3
BLKST4
ENMULT1
ENMULT2ENMULT3
ENMULT4
TRIP
TR1
TR2
TR3
TR4
TRL1
TRL2
TRL3
TR1L1
TR1L2TR1L3
TR2L1
TR2L2
TR2L3
TR3L1
TR3L2
TR3L3
TR4L1
TR4L2
TR4L3
START
ST1
ST2
ST3
ST4
STL1
STL2
STL3
ST1L1
ST1L2
ST1L3
ST2L1
ST2L2
ST2L3
ST3L1
ST3L2
ST3L3
ST4L1
ST4L2
ST4L3
2NDHARM
DIRL1
DIRL2
DIRL3
TRIP step1, step2, step3 and step4
TRIP phase L1, L2, and L3
TRIP step1 phase L1, L2, L3TRIP step2 phase L1, L2, L3
General TRIP
TRIP step3 phase L1, L2, L3
TRIP step4 phase L1, L2,L3
General start
START step1, step2, step3 and step4
START L1, L2 and L3
START step1 phase L1, L2 and L3
START step2 phase L1, L2 and L3
START step3 phase L1, L2 and L3
START step4 phase L1,L2 and L3
Second harmonic blockDirection phase L1, L2 and L3
TOC, 51_67; Function block outputs
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2008-01-30 Substation Automation and Protection Training
TOC, 51_67; Setting calculation
Select the max(IfB)
Consider also eventual transientoverreach due to possible dccomponent of the fault current
The set value for the high setunderreaching step can bederived as:
The value 1.31 includes asecurity margin of 10% fortransient overreach and 20 %general security margin
For directional underreaching step1
IfB31.11I =>
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TOC, 51_67; Setting parameters
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2008-01-30 Substation Automation and Protection Training
TOC, 51_67; Setting parameters
IminOpPhSel = Minimum current in % of Ibase for directionality
Should be set lower than setting of the lowest step
General setting parameters
Basic settings
Advanced
settings
StartPhSel = Number of phases needed for operation (1, 2 or 3 of 3)
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Basic setting parameters for step1
TOC, 51_67; Setting parameters
K1 = Time multiplier for inverse time characteristic
t1Min = Minimum operate time for inverse time characteristicI1Mult = Current multiplication factor for step1, activates
if input ENMULT1 is high
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TOC, 51_67; Setting parameters
Advanced setting parameters for step1
ResetTypeCrv1 = Reset curve type for step1
tReset1 = Reset time delay for IEC inverse curve for step1
tPCrv1, tACrv1, tBCrv1, tCCrv1, tPRCrv1, tTRCrv1, tCRCrv1 = Parameter P, A, B,C , PR, TR and CR for customer programmable inverse time curve for step1
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ABB
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2007
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IBase: Base current in primary A.
Normally set to the primary current of the
CT. Range 1-99999
UBase: Base voltage in primary kV
Normally set to the primary voltage of the
VT (PT). Range 0.05-2000
AngleRCA: Protection characteristic
angle set in degrees.
Default set to 55. Range 40-65
AngleROA: Angle to define the angle
sector of the directional function
Default set to 80. Range 40-89
PTOC, 51_67; Setting parameters
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IminOpPhSel: Minimum current for phase selection set in % ofIbase
should be less than the lowest step setting. Default setting is 7%.
StartPhSel: Number of phases, with high current, required for
operation: 1 of 3, 2 of 3 or 3 of 3. Default setting is 1 of 3.
DirMode1: Directional mode
Default set to Non-Directional
2ndHarmStab: Operate level of 2nd harmonic current restrain setin % of the fundamental current, range is 5-100% I steps of 1%.
Default setting is 20%.
HarmRestrain: Off/On, enables blocking from harmonic restrain.
PTOC, 51_67; Setting parameters
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PTOC, 51_67; Setting parameters
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Instantaneous Earth Overcurrent function (IEF)
Set as instantaneous protection wherethe fault current is limited to definedmaximum values e.g. from a longpower line or a transformer reactance.
Low transient overreach to allowsetting close to the maximum through
fault current level High speed to give fast fault clearance
at heavy fault currents
Can give phase information and beused with Distance protection as fastoptional function also giving singlephase tripping
Current can be summated from two (ormore) current input sets.
Residual connection or separate inputscan be used.
IF
IN>>
Irsd
or
3I0
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4-step Earth fault protection (TEF, 51N_67N)
Earth fault protection of feeders in effectively earthed
distribution and sub transmission systems Back-up earth fault protection of transmission lines
Sensitive earth fault protection of transmission lines
Back-up earth fault protection of power transformers
Earth fault protection of different kinds of equipmentconnected to the power system
such as shunt capacitor banks, shunt reactors andothers
Application
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Four stage Earth overcurrent.
Each stage can be set Off, Non-directional, Forward or Reverse
Each stage can be Definite- orInverse time delayed.
Taylor made curve is available
Each stage can be blocked fromsecond harmonic inrush currents.
Directional polarizing from calculatedUL1+UL2+UL3 or by external Opendelta to a separate Analogue input.
IF
IN>
4
UL1+UL2+UL3
4-step Earth fault protection (TEF)
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4-step Earth fault protection (TEF, 51N_67N)
Directional element with communication and WEI
Reverse
operation
Forward
operation
-Upol3Io
Operation based on I*cos
Polarising -3U0 > 1.0 %
CVT filter against 3rd harm
Characteristic angleAngleRCA = -180--180(default -65
o)
Current can be summatedfrom two current sets andthe measurement can befrom separate IN input orinternally calculated:3I0 = IL1+IL2+IL3
3Io3Io(rev) = 0,6 x 3Io (forward)
AngleRCA
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TEF, 51N_67N; Polarizing alternatives
Voltages polarization (-3U0)
Current polarization (IN*ZN)
Dual polarization
Both voltage and current is
allowed to polarize
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Earth Overcurrent function (TEF) - Application
Back-up selectivity with twodirections and different time gradingin both directions
IF
IN>
4
G
G 67N/51N
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PEFM, 51N_67N; Functional overview
en05000741.vsd
DirectionElement
4 step over currentelement
One element for each
step
HarmonicRestraint
ModeSelection
earthFaultDirection
harmRestrBlock
enableDir
enableStep1-4
DirectionalMode1-4
TRIP
Element
enableDir
angleValid
Directional Check
operatingCurrent
SwitchOnToFault
start step 2, 3 and4
signal tocommunication
scheme
TRIP
3U0
3I0
Blocking at paralleltransformers
1
CBpos
or cmd
Element
3I0
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The function are connected to pre-processing block by the following
signals
I3P, input for the function Operating Quantity
U3P, input for the function Voltage Polarizing Quantity
IP3P, input for the function Current Polarizing Quantity
The function uses Residual Current (i.e. 3Io) for its operating
quantity
directly measured
Internally calculated from three phase current input within IED 670
(when the fourth analog input into the pre-processing block connected
to TEF function Analog Input I3Pis not connected to a dedicated CT
input of IED 670 in SMT tool).
TEF, 51N_67N; Analogue inputs
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4-step earth fault protection (TEF)
Step 1-3:
Directional or Non- directional
Definitive time
Second harmonic restrained
Step 4:
Directional or Non- directional
Normal inverse
Very Inverse
Extremely inverse -
Logarithmic inverse
Definitive time
Second harmonic restrained
t
1sec
20 ms
min
Set to match the distance protection reach
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Directional
Non-directional
Independent or dependenttime delay
Second harmonic restrained
Settable minimum operate
current and time delay
Logarithmic inverse
t
tmin
Imin
Independent
Normal inverse
Very inverse
Extremely inverse
4-step earth fault protection (TEF)
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19 different IEC/ANSI Current
dependent characteristic curves
(New)
Communication logic
Blocking
Permissive overreach (POR)
Fault current reversal
Weak-end infeed echo and trip
100 1 .103
1 .104
1 .105
0.1
1
1010
0.1
t1 i
t2 i
t3 i
t4 i
t5 i
t6 i
100000100 Sti
4-step earth fault protection (TEF)
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Inverse characteristic for time-current back-up
Required for Back-up functions TOC, TEF
Diagram or characteristic showing the operating times and correspondingactuating quantities or fault positions for the selective protection relays in the
network
Purpose
Coordinate the relay settings so that
Faulty equipment is tripped asfast as possible
The least possible damage isobtained for the healthyequipment
A Back-up protection is obtainedif the primary protectionfails to trip
Directional
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Earth fault protection (TEF) Application problem
Energizing a transformer willalways mean inrush currents.
Inrush has a high neutral contentin directly earthed systems
A parallel transformer in service
will also see the inrush. Theinrush will increase successively
2nd harmonic will be in phaseopposition and the total contentwill after a while be reduced tosmall values.
BlkParTrans set to ON and INover a set level (1-4) can be usedto maintain the blocking even ifthe harmonic contents is reduced
and gives an advantage at paralleltransformers.
Close
IN> IN>
IN>
IN>
51N 51N
51N
51N
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STUB protection (STB)
Instantaneous overcurrentprotection of busbarconnection (STUB) when aline disconnector is open
Required in Multi-breakerarrangements with CVT(VT) on line side of DS
Z< (21) function cannotmeasure when linedisconnector is open andmust be blocked.
open
I STUB >&
t
Trip
Line discon.
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Pole discordance protection (PD)
Pole discordance can occur atbreaker closing or opening whensingle pole operating devices areused.- Higher than 300 kV
- Single phase trip breakers Contact based supervision of the
poles
I2 criteria to verify can be added asadditional criteria to increase security
Can be blocked during 1-ph AR toallow shorter trip times.
Note! Only remote b-u trip if localattempt does not remove asymmetry.
Bus trip will mean a big disadvantagefor service.Trip rem end
& t
+
1Ph AR in progr
Trip
t
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Breaker failure protection (BFP)
BFP is the Local back-up for breakerfailures. The failures can be due totrip coil, breaker drive or breakingcomponents failure.
At an breaker failure the surroundingbreakers are used to clear the fault.
Due to the big impact a breaker failuretrip will have on the power systemservice, the BFR function has veryhigh requirements on security againstunnecessary tripping.
The BFR function is started at CBtripping and if current still flows within,about 150 ms the surroundingbreakers are tripped.
G
G
G
G
Back-up breakers
Failing
breaker
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Some setting parameters
BFP
I>
t1
t2
Current level Iset 0,1 2 * IbaseRetrip of actual breaker -No retrip
-With current check-Without current check
Current check mode 1 out of 3 or 2 out of 4
Retrip delay, one per phase t1 0.000 60.000 s
Back up trip delay, one timerper phase t2 0.000 60.000 sBack-up trip 2 t3 0.000 60.000 s
Trip pulse tp 150 ms (settable)
Breaker failure protection (BFP)
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ASD output
RMS output
Pre-filter
Post-filter0.5 *
Stab zone
Adaptive currentdetection ASD
No false operation in
case of saturated CT Maximum reset time
approx 1/2 cycle toallow short back-uptripping times.
Breaker failure protection (BFP)
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- 30 ms - 60 ms
Fault occurs
Normal clearing time
Current detector
dropout
MarginBreaker
interrupting time
Protection
time
Start
BFP
BFP timer t2 BFP
Trip
Breaker time
Back-up breaker
Breaker failure total clearing time
Breaker failure protection (BFP)
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3I>BF
3I>BF
Z
Start L1
Start L2Start L3
Start L1
Start L2Start L3
Start from all protection relays
tripping the Breaker. Also Bus and
Breaker failure protection.
Not manual opening of breaker!
CB1
CB3
Trip Busbar
Trip CB3
Intertrip 1
Trip CB1
Trip CB2
Intertrip1
Intertrip2
CB2
Note! Multiple functions
Breaker failure protection (BFP)
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Energizing Check (SYN)
The dead line and Live bus
conditions are checked.
Uhigh and Ulow are verified
SC/VC
27
AB
ILoad
UA UB
Ulow
Uhigh
Inductive and Capacitive
charging of dead line
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2007
2008-01-30 Substation Automation and Protection Training
Synchronism Check (SYN)
Paralleling (synchronismconditions are checked
,f, U and Uhigh are within
set values
SC/VC
25
AB
ILoad
UA UB
UAL
d
dU
Icap
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Synchrocheck function (SYN)
BLOCK
U-LineU-Bus
SYNC
Linereferencevoltage
Fuse fail
U-Bus
Energizing check
High voltage U> 50-120% of Ub
Low voltage U< 10- 80% of Ub
Operate time 80 ms (typical)
Paralleling (Synchronism) CheckFrequency difference f < 3-1000mHz
Voltage difference U < 2 - 50 % of
UbPhase difference < 5 - 90o
Operate time 80 ms (typical)
Accuracy of frequency measurement
about 0,5 mHz!
U
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Synchrocheck (SYN) Function block
Fuse fail on sel fuse
Information that the voltage
is included in the
synchrocheck
Information that the
conditions for voltage, diff
voltage phase angle diff etc
are fulfilled
Conditions for AR
Conditions for Man close
Test conditions fulfilledDS Bus 1 at DB arrangement
DS Bus 2 at DB arrangement
DS Line at 1 1/2 arrangement
DS alt Line at 1 1/2 arrangement
Bus1 VT Fuse fail alt. OK
Bus2 VT Fuse fail alt. OK
Line 1 VT Fuse fail alt. OK
Line 2 VT Fuse fail alt. OK
Block inputs
Test mode inputs
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Synchrocheck (SYN) Voltage selection
SYN1
SYN1 SYN2
1 U
1 U1 U
IED
3 U
1 U
3 U
B2QB1Q
UB1 UB2
ULN1
ULN1
UB1 UB2
LN1Q
DB Volt sel
No Volt sel
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SYN1
IED 1
SYN1
IED 2
SYN1
IED 3
1 U
1 U3 U
3 U
SYN1
IED
SYN2
3 U
1 U
1 U
1 U
1 U
1 U
1 U
1 U
B2Q
UB1UB2
ULN1
LN1Q
LN2Q
ULN2 UB2
B1Q
No Volt sel1 CB Volt sel
Synchrocheck (SYN) Voltage selection
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AB,
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2008-01-30 Substation Automation and Protection Training
SYN1
REC670
SYN2
SYN3
3 U
3 U
1 U
1 U
No Volt sel
Synchrocheck (SYN) Voltage selection
56
ABB
AB,
2007
2008-01-30 Substation Automation and Protection Training
Auto Reclosing (AR)
Single-/ Two-/ Three-phase reclosing programs
3 phase
--------
3 phase
--------
1 phase
2 phase3 phase
1/2/3 phase6
3 phase
3 phase
----
3 phase
3 phase
----
1 phase
2 phase
3 phase
1/2/3 phase5
3 phase
----
3 phase
----
1 phase
2 phase
1/2 phase
(No 3 phase)
4
3 phase
3 phase
3 phase
3 phase
1 phase
2 phase
1/2 phase
(No 3 phase)
3
3 phase
3 phase
3 phase
3 phase
3 phase
3 phase
1 phase
2 phase
3 phase
1/2/3 phase2
3 phase3 phase3 phase3 phase1
3rd and 4st attempt2nd attempt1st attemptProgram
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ABB
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2008-01-30 Substation Automation and Protection Training
Start Quick AR without
synchrocheck
Auto-Reclosing (AR) new in REx670
Put AR on hold e.g. waiting
for Thermal relays to resetto have less sag before
reclosing
Skip a step and continue
with next (at multiple shots)
58
ABB
AB,
2007
2008-01-30 Substation Automation and Protection Training
Content
Time Overvoltage protection function
Time Undervoltage protection function
Multipurpose general protection function
Fuse failure supervision
Instantaneous phase overcurrent Time delayed phase overcurrent
Instantaneous earth overcurrent
Time delayed earth overcurrent
Stub protection
Pole Discordance protection
Breaker failure protection
Synchrocheck function Auto Reclose function
Frequency protection
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ABB
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2007
2008-01-30 Substation Automation and Protection Training
TOF/TUF/RVF(df/dt) Frequency Protection-Functionality
Detection of over- or underfrequency
Six stages of each function
Measures Ph-Ph or Positive sequence voltage Undervoltage (Dead) blocking level
Trip signal each step fully individually:
Settable frequency and settable time delay
High accuracy, short measuring time
Df/dt with positive or negative setting
Accuracy 2 mHz for three phase
Accuracy 50 mHz for single phase
Voltage dependent tripping time!
60
ABB
AB,
2007
2008-01-30 Substation Automation and Protection Training
TOF/TUF Frequency Protection - Application
Load shedding system
System restoration system
Generation shedding
Remedial Action schemes
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ABB
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2007
2008-01-30 Substation Automation and Protection Training
Trip Circuit Supervision Application with 670 series
Trip Circuit supervision can be arranged
using Binary inputs or mA inputs.
mA inputs shall be used if supervision is
required from both sides i.e. at Lock-outtripping
+ -
Trip Circuit fail3s