11 Ret521 PDF
11 Ret521 PDF
11 Ret521 PDF
Numerical Transformer
and
Terminal
Protection Training
RET 521
C
E
BUU:PTUA-R Training
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Slide No - 1
RET 521 - application
E
transformers
shunt reactors
groups with generators and step-up
transformers
special transformers
etc.
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Slide No - 2
RET 521 - design
¾ of 19” RET521
AIM
ABB Relays
7I+3U
8I+2U
C
IOM
E 8BI + 12BO
MIM
6 of mA channels
all AIM, BIM, BOM, IOM, MIM modules are optional
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Slide No - 3
Ordering Hardware - General
SETTABLE
SETTABLE
X
X
Select IO modules
in accordance with
X
requirements.
X
please note that there
X
are no binary inputs &
X
outputs on PSM module
X
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Slide No - 6
Ordering Hardware – Communication
Indications
Event logging and presentation
Service values from analogue
Ready Start input modules and protection
Ready Start Trip
Trip functions, (i.e. differential
RET
RET521
521 Ver.2.3
Ver 2.0
E= Enter menu currents, etc.)
E = Enter menu
C=
C =Reset
ResetLED
LED Settings: reading, changing
Partial configuration
C Self-monitoring information
Port with optic interface to RS
232 for local PC
E
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Slide No - 8
Human Machine Interface, (HMI) functions
Any input channel can be set as a reference for the phase angle
measurement
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Slide No - 15
RET 521 - some important facts (2)
Note:
It is extremely important to properly set all the values under the power transformer data
HMI: Selection from table no 1- 288 SMS: Direct selection of coupling group
(Coupling group shown in LCD window) (288 variants)
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Slide No - 18
CT & VT Setup
Note:
It is extremely important to properly set all the values below for RET 521 input
analog channels
{
Used input tap for CT on AIM card in A InputCTTap Input1A, Input5A 0-1 1 0
Rated CT primary current in A CTprim A 1-99999 1 1000
CT
Rated CT secondary current in A CTsec A 1-5 1 1
Current transf. earthing, CTearth ToObject, FromObject 0-1 1 0
Towards power transf./Towards bus
VT
{ Rated VT primary voltage in kV
Rated VT secondary voltage in V
VTprim
VTsec
kV
V
0.1-999.9 0.1
1-999 1
100.0
100
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Slide No - 19
CT & VT Setup
Sec Neutral CT
Reference Directions
for Current
Transformers Sec Phase CT
Second.
Primary
Pri Phase CT
Tertiary
Ter Neutral CT
Pri Neutral CT
Ter Phase CT
Current Transformer
Definition:
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CT Reference Current Direction = Current has a positive value when flows in the same direction with associated arrow
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Slide No - 20
CT Setup Example
S1 P1
S1 P1
300/5
100/1
ToObject
S2 S2 P2
HV Neutral CT LV Neutral CT
P2
Param. name Settings Param. name Settings
InputCTTap Input1A InputCTTap Input5A
CTprim 100 N 5A 1A N 5A 1A N 5A 1A N 5A 1A N 5A 1A N 5A 1A N 5A 1A N 5A 1A CTprim 300
CTsec 1 CTsec 5
RET 521
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Ip + Is + It = 0 (?)
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Slide No - 23
RET 521 – DIFP function for 2-Winding Transformer
BR 6
iL 4
t
iI
t
it
2
H
− 0.3 2
0 t
• Initial Inrush
• Recovery Inrush
• Sympathetic Inrush
parallel always
Slide No - 30
Typical Inrush Currents for 3-Phase Transformer
Waveblock criteria detects current gaps during inrush
8
65MVA
Typical Current Gap
150/6.6kV 6
Yd11
300/1 4
2
Current [pu]
Phase L1
rec
Phase L2
0
Inrush recorded at Gaurain, Phase L3
Belgium in 1992 -2
1
iL
t
iI
t 0 20 40 60 80 100 120 140
it
H 1
− 2.3 3
0 t
• With known Tap position, Differential function can be supplied with regular
updated information of the tap, helps in adapting to the actual turns ratio
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Differential current Id
Id = I1 - I2 in pu
6
150A/1A
5 unrestrained limit
Ir1 = 120A Iunre: 5 - 25 5
4
30MVA 4
operate area
Idiff in pu
slope 2
3
3
2
zone 2
2
zone 1
1
11kV
C:\Janez\VISIOFIG\
Vfj_0098.vsd
Idiff & Ibias Calculations for DIFP
iA1
CT1 CT3
Yyo
300/1 500/1
Y y
iA ia
iA2
CT2 m = NLV / NHV = ULV / UHV ; m is transformer turns ratio
200/1
m = func(Tap Position); => Tap Position Compensation
Idiffa[Amps]= Abs {( IA1 + IA2) - m* Ia}; (HV side as a reference; Idiffb & Idiffc respectively)
Ibias [pu]= Max { k1*IA1; k2*IA2; k3*IA; k4*Ia;currents from other two phases }
1 1 1 1
k1 = CT1 Rated Primary Current k2 = CT2 Rated Primary Current k3 = Ir1 k4 = Ir2
Cross-block
3I0 reduction
(yes / no)
Wave block
150A/1A >1
group of a transformer
instantaneous
Ir1 Send
2nd h block & cross block
30MVA (yes / no) (yes / no)
pre-filtering
Cross-block
Idiff
after DFF TRRES
&
START
1800A/1A
Ibias Unrestraint
>1 TRIP
after DFF level
Ir2
TRUNR
11kV
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C:\Janez\VISIOFIG\
Slide No - 36
Vfj_0099.vsd
RET 521 - tap position reading
Basic Setting Parameter description Param. name Unit Range Step Default
Operation Transformer Differential Protection, Off/On Operation Off, On Off
Stabilizing characteristic number CharactNo 1-5 1 3
Maximum sensitivity in % of Ir Idmin % of Ir1 10 - 50 1 30
Unrestrained limit in % of Ir Idunre % of Ir1 500 - 2500 1 1000
Second harmonic blocking, Conditionally/Always StabByOption Conditionally, Always Conditionally
Second to first harmonic ratio in % I2/I1ratio % 10 - 25 1 15
Fifth to first harmonic ratio in % I5/I1ratio % 10 - 50 1 25
Automatic Subtraction of Zero Sequence Current ZSCSub Off, On On
Cross Blocking Between Phases CrossBlock Off, On On
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Slide No - 41
Tap Changer Settings for DIFP
Tap-Changer Setting Parameter description Param. name Unit Range Step Default
Number of taps NoOfTaps 1 - 64 1 20
Rated tap RatedTap 1 - 64 1 10
Voltage for minimum (tap1) tap in kV MinTapVoltage kV 0.1 - 999.9 0.1 100.0
Voltage for maximum tap in kV MaxTapVoltage kV 0.1 - 999.9 0.1 100.0
Above service values are related to the winding 1 when Sr1 = Smax
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Slide No - 43
Ordering DIFP function
145kV
AI module Main processing module BO module
Used in direct and low
impedance earthed
A/D converter, scalling with CT and VT ratio
systems
REF1-
3I0d
DFF in primary values
Operates instantaneously
pre-filtering
TRIP block
REF2-
BO
Unaffected by inrush
3I0d
currents and external
faults
11kV
Up to three instances are
C:\Janez\VISIOFIG\
Vfj_0100.vsd
available
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Slide No - 46
RET 521 - REFn operate characteristic
diff current in pu 5
4 operate area
2
zone 1 zone 2 second slope=100%
1 restrain area
minimum base sensitivity 50 %
default base sensitivity 30 % first slope=70%
maximum base sensitivity 5 %
Step : 1 % transformer rated current
0 1 2 3 4 5 6
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iA1
CT1 5/1 = n CT3
300/1 500/1
Y y
iA ia
iA2
CT2 iN
200/1 CTN
250/1
Ibias [pu]= MAX { k1*IA1; k2*IA2; k3*IA; currents from other two phases; k3*In }
1 1 1
k1 = CT1 Rated Primary Current k2 = CT2 Rated Primary Current k3 = Ir1
Ibias [Amps]= Relevant Power Transformer Winding Rated Current * Ibias [pu]
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Slide No - 48
REF directional measurement, internal fault
Current distribution for Internal Earth Fault
power system
contribution to
fault current zone of protection
IL1
A (L1) Ia = 0 a (L1)
IL2
B (L2) Ib = 0 b (L2)
IL3
C (L3) Ic = 0 c (L2)
MTA
-IN
ROA reference is
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IL1
A (L1) Ia = 0 a (L1)
IL2
B (L2) Ib = 0 b (L2)
IL3
C (L3) Ic = 0 c (L2)
MTA
-IN
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ROA reference is
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>1
Directional
pre-filtering
check
& TRIP
3I0diff
after DFF
START
Ibias
after DFF
11kV
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C:\Janez\VISIOFIG\
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Vfj_0101.vsd
Slide No - 51
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Slide No - 52
CAP 531 Function Block for REF1
Settings for REF
Above service values are always related to the power transformer winding to
which REF instance is connected
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Slide No - 53
Ordering REF functions
X
X
= Rated Current of the Power Transformer Winding to which relevant TOC instance is connected in CAP tool
*
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Slide No - 58
Additional settings for directional TOC
Parameter description Param. name Unit Range Step Default
Direction for trip, lowset, NonDir, Forward,
DirectionLow NonDir
NonDir/Forward/Reverse Reverse
Direction for trip, highset, NonDir, Forward,
DirectionHigh NonDir
NonDir/Forward/Reverse Reverse
Relay Characteristic Angle in deg. rca deg 20 - 50 1 30
Relay Operate Angle in deg. roa deg 60 - 90 1 75
Action low pol. voltage, lowset , NonDir/Block UActionLow NonDir, Block NonDir
Action low pol. voltage, highset , NonDir/Block UActionHigh NonDir, Block NonDir
Rated voltage for user defined side, in kV UrUserDef kV 1.0 - 999.9 0.1 100.0
X
X
= Rated Current of the Power Transformer Winding to which relevant TEF instance is connected in CAP tool
*
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Slide No - 64
Additional settings for directional TEF
Parameter description Param. name Unit Range Step Default
Direction for trip, lowset, NonDir, Forward,
DirectionLow NonDir
NonDir/Forward/Reverse Reverse
Direction for trip, highset, NonDir, Forward,
DirectionHigh NonDir
NonDir/Forward/Reverse Reverse
Relay Characteristic Angle in deg. rca deg 0 - 90 1 70
Relay Operate Angle in deg. roa deg 60 - 90 1 75
Rated voltage for user defined side, in kV UrUserDef kV 1.0 - 999.9 0.1 100.0
X
X
X
Three-phase or one-phase
measurement
and TUVn-
very inverse IDMT delay at TOVn
Functions are configurable to all
windings
U< Trip One-phase or three-phase voltage
inputs are available
TUV
Different tripping options
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Slide No - 69
Residual time O/V protection function
U Trip
TOV
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Slide No - 70
All Settings for TOV
Parameter description Param. name Unit Range Step Default
Operation Time Overvoltage Protection, Off/On Operation Off, On Off
Start voltage, lowset in % of Ur UsetLow % of Ur* 5.0 - 200.0 0.1 120.0
Start voltage, highset in % of Ur UsetHigh % of Ur* 5.0 - 200.0 0.1 150.0
Time characteristic for TOV1, DEF/VI CurveType DEF, VI DEF
Definite delay lowset in sec. tDefLow s 0.03 - 120.00 0.01 10.00
Minimum operating time in sec. tMin s 0.05 - 1.00 0.01 0.50
Definite delay highset in sec. tDefHigh s 0.03 - 60.00 0.01 2.00
Time multiplier for inverse time function k 0.05 - 1.10 0.01 0.30
Block lowset, Off/On BlockLow Off, On Off
Block highset, Off/On BlockHigh Off, On Off
= Rated Voltage of the Power Transformer Winding to which relevant TOV instance is connected in CAP tool
*
Service Values for TOV
Parameter description Param. name Range
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= Rated Voltage of the Power Transformer Winding to which relevant TUV instance is connected in CAP tool
*
X
X
ResetLockOut % of Itr^2 10 - 95 1 50
Lockout reset level in % of heat content trip level
= Rated Current of the Power Transformer Winding to which relevant THOL function is connected in CAP tool
*
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Slide No - 77
Service Values for THOL
Parameter description Param. name Unit Range
Measured current in % of thermal overload base
Imeasured % of Ibx 0 - 250
current
Thermal status in % of heat content trip level ThermalStatus % of Itr^2 0 - 999
NotActive,
Time to trip calc. >1.3*Time
TimeToTrCalc
NotActive/>1.3*TimeConst/Active Const,
Active
Time to trip thermal overload, in min. TimeToTrip min 1 - 650
NotActive,
Time to reset lockout calc. >1.3*Time
TimeToRstCalc
NotActive/>1.3*TimeConst/Active Const,
Active
Time to reset lockout function, in min. TimeToReset min 1 - 650
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Slide No - 78
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Slide No - 79
CAP 531 Function Block for THOL
Ordering THOL function
11kV
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Slide No - 82
Over-Excitation protection with IEEE Curve
• ALARM signal can be delayed from 0 to 120sec
• Relative OverExitation for IEEE curve is calculated as M= (E / f)/(Emaxcont / frated)
• For IEEE Curve top=0,18*k/(M-1)2; k is settable from 1 to 60
• Integration method is used to calculate trip time (i.e. accumulated heat content)
• Exponential reset of accumulated heat content with settable time constant
• Settable Emax limit (it defines Mmax= (Emax / f)/(Emaxcont / frated))
overexcitation
top
tmax
Tailor Curve
underexcitation
}
(Mmax-1)/5
Overexcitation [pu]
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Slide No - 83
OverExcitation protection with “Tailor Made” Curve
overexcitation
top
tmax
Tailor Curve
underexcitation
}
(Mmax-1)/5
tmin
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Overexcitation [pu] M
All Settings for OVEX
Parameter description Param. name Unit Range Step Default
Operation Overexcitation Protection (V/Hz), Off/On Operation 0 = Off, 1 = On Off, On Off
Emax continous no-load, in p.u. Emaxcont p.u. 1.00 - 1.50 0.01 1.10
Excitation with tMin delay, in p.u. Emax p.u. 1.20 - 1.80 0.01 1.40
Minimum operating time in sec. tMin s 0.50 - 30.00 0.01 1.00
Maximum time delay for overexcitation, in min. tMax min 10 - 120 1 30
Time multiplier for inverse time function k 1 - 60 1 1
Transformer core cooling time constant, in min. Tcool min 1 - 120 1 20
Time delay for alarm, in sec. tAlarm s 0 - 120 1 0
Time value in sec. for Time 1 t1 s 0 - 7200 1 7200
Time value in sec. for Time 2 t2 s 0 - 7200 1 3600
Time value in sec. for Time 3 t3 s 0 - 7200 1 1800
Time value in sec. for Time 4 t4 s 0 - 7200 1 900
Time value in sec. for Time 5 t5 s 0 - 7200 1 450
Time value in sec. for Time 6 t6 s 0 - 7200 1 225
IEEE,
Time characteristic for OVEX , IEEE/Tailor made CurveType IEEE
Tailor made
Winding reactance in p.u. Sr base Xleak p.u. Sr base 0.000 - 0.250 0.001 0.000
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Slide No - 85
Service Values for OVEX
Control for:
single transformer with LDC
reverse reactance principle
Master-Follower by CAP configuration
Up to four parallel operating
transformers based on minimised
circulating current method
Exchange of information via LON
communication
Extensive monitoring of tap changer
Load
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Slide No - 92
RET 521 - VCTR for one transformer
block VCTR
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Slide No - 93
RET 521 - blocking conditions for VCTR
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Slide No - 96
Ordering VCTR & DR functions
Summary of function
-All general function protection modules are executed in RET521 fastest internal
execution cycle (i.e. five times in each fundamental power system cycle).
-The GF-function is always connected to 3-Ph current and 3-Ph voltage input in
the configuration tool, but it will always measure current and quantity, selected by
the end user in the setting tool
-Its also possible to configure any number of modules to the same side of the
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power transformer.
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Slide No - 98
New Protection Functions in RET521 Library
Multipurpose General Protection Function (GF)
Each General Function module has following protection elements (feature) built in:
Over/under frequency protection can be used for several power system protection
and control applications. for examples
In RET 521 up to three FRF modules can be ordered. Each module has
Note: Frequency can be measured either with single phase or three phase voltage.
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Slide No - 100
Event Recorder
Recorded signals
0 to 10 analogue signals
0 to 48 digital signals,
both binary inputs and
internal logical signals
All signals are selectable
Triggering on
Level of U and I signals
Binary signals
Manual
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Slide No - 102
Communication
LON
•Local Operating Network (LON) based on
LonTalk Protocol from Echelon Corporation
•Defacto standard in industry segment
•Follows OSI-model
• Extension for IEC 870-5-101
• Multi-master peer-to-peer protocol
•Control and protection communication
•Fibre connection glass / plastic
SPA
•Open ASCII-based protocol
•Defacto standard in relay and control
•Master-slave principle
•Control and protection communication
•Fibre connection glass / plastic
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Slide No - 103
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Slide No - 104
Substation Automation Configuration/Setting
Example/Testing
and
Protection Training RET 521
C
E
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Slide No - 105
RET 521 - Flexible Functional Structure (CAP531 configurable)
145kV
AI module Main processing module BO module
DIFP-
TOCn- TRIP
pre-filtering
30MVA 150A/1A ALARM
REFn-
TRIP block
BO
TEFn-
110V
3
11kV
3
1800A/1A TOVn-
Ir2 = 1575A
BI module
>1
11kV BI
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Slide No - 106
C:\Janez\VISIOFIG\
VFJ_0097.vsd
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Slide No - 107
CAP 531 Function Block for Analogue Input Module
CAP 531 Function Block for Digital Fourier Filters
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Slide No - 108
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Slide No - 109
CAP 531 Function Block for Disturbance Recorder
Main Principles for RET 521 Configuration
Analogue Filtering & Protection Trip Blocks, Binary Outputs
Inputs Disturbance and Control Other Logic & (i.e. Trip, Raise,
Event Recording
Recording Functions Lower etc.)
{
{ AIM1
Differential (DIFP)
3Ph DFF
{
Transformer
(C3P1)
TRIP
{
BOM
TRIP
BLOCK
Red Colour
Indicates 3Ph DFF Subsidiary
(C3P2)
Settings Configuration
Input-Output Hardware
mA & Binary Fixed Signals
Internal Signals
Inputs Time Synchronization
Active Setting Group
3Ph DFF TOC AND
Test Mode
Tap Position as mA Input
Oil Temperature as mA Input { mim
(C3P3)
Inputs and Settings
are always located on
MIM 1Ph DFF
Left-hand side of
(V1P1) OR function block
Outputs are always
{
Oil Temp trip via Binary Input located on Right-hand
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EVENT
Slide No - 110
Settings Example
Transformer Data:
132/69/11kV
ONAN: 30/30/4MVA
ONAF: 40/40/4MVA
250/1
To Set:
1200/5 Transformer Data
CT Data
DIFP
HV OC
HV EF
500/1 VCTR Single
66000/110V
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Slide No - 111
Settings Example
Step N. 1: SET POWER TRANSFORMER DATA
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Slide No - 112
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Slide No - 113
Settings Example
Step N. 2: SET TAP CHANGER DATA
Settings Example
Step N. 3: SET CT data (AIM1)
CT1:
CT2:
CT3:
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Slide No - 114
Settings Example
Step N. 3: SET CT data (AIM1)
CT4:
CT5:
CT6:
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Slide No - 115
Settings Example
Step N. 3: SET CT data (AIM1)
CT7:
CT8:
CT9:
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Slide No - 116
Settings Example
Step N. 3: SET DIFP
winding earthed
(by zig-zag) zero sequence current should be
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Slide No - 117
taken away.
Testing Example
Connect the terminal to the test equipment (DOBLE/OMICRON).
You need a test equipment with 6 current generators.
Careful with MV side quantities, they might be shown with 180 degrees
displacement because positive reference is always toward the power
transformer.
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Slide No - 118
Testing Example
Calculate stable through load condition at 40 MVA at HV and MV side:
1.43 DIFP
250/1
0.7 A 1A
175 A
DIFFERENTIAL
Algorithm
1200/5
Set: 0.3
0.113
0A
0A
1.493
500/1
0.67 A 1A
335 A
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ISX IDX
ratio = IDX / ISX
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Slide No - 119
Testing Example
Through load condition at 40 MVA at HV side:
175 A
IL1SECONDARY = = 0.7 A 0o
250
175 A
IL 2 SECONDARY = = 0.7 A 240o
250 Inject through load
condition at HV and
175 A MV side.
IL3SECONDARY = = 0.7 A 120o
250
Through load condition at 40 MVA at MV side:
Observe no trip.
335 A
IL1SECONDARY = = 0.67 A 0o
500
335 A
IL 2 SECONDARY = = 0.67 A 240o
500
335 A
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500
Slide No - 120
Testing Example
Invert the phase of MV currents and inject again the 6 quantities:
IL1SECONDARY = 0.7 A 0o
IL 2 SECONDARY = 0.7 A 240o HV
IL3SECONDARY = 0.7 A 120o
1.43 DIFP
250/1
0.21 A 0.3A
52.5 A
DIFFERENTIAL
Algorithm
1200/5
Set: 0.3
0A 0.113
0A
1.493
500/1
0A 0A
0A
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Slide No - 122
Testing Example
CHECK PICK-UP DIFFERENTIAL CURRENT
(3-PHASE FAULT FROM HV SIDE):
IL1SECONDARY = 0.21 A 0o
IL 2 SECONDARY = 0.21 A 240o HV
IL3SECONDARY = 0.21 A 120o
IL1SECONDARY = 0 A
IL 2 SECONDARY = 0 A MV
IL3SECONDARY = 0 A
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0.36 A 0.3A
90.8 A (1Ph)
DIFFERENTIAL
Algorithm
1200/5
Set: 0.3
0A 0.113
0A
1.493
500/1
0A 0A
0A
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Slide No - 124
Testing Example
CHECK PICK-UP DIFFERENTIAL CURRENT
(1-PHASE FAULT FROM HV SIDE):
IL1SECONDARY = 0.363 A 0o
IL 2 SECONDARY = 0 A 240o HV
IL3SECONDARY = 0 A 120o
IL1SECONDARY = 0 A
IL 2 SECONDARY = 0 A MV
IL3SECONDARY = 0 A
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1.43 DIFP
250/1
0 A 0A
0A
DIFFERENTIAL
Algorithm
1200/5
Set: 0.3
0A 0.113
0A
1.493
500/1
0.201 A 0.3 A
100.5 A
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Slide No - 126
Testing Example
CHECK PICK-UP DIFFERENTIAL CURRENT
(3-PHASE FAULT FROM MV SIDE):
IL1SECONDARY = 0 A 0o
IL 2 SECONDARY = 0 A 240o HV
IL3SECONDARY = 0 A 120o
IL1SECONDARY = 0.201 A 0o
IL 2 SECONDARY = 0.201 A 240o MV
IL3SECONDARY = 0.201 A 120o
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1.43 DIFP
250/1
0 A 0A
0A
DIFFERENTIAL
Algorithm
1200/5
Set: 0.3
0A 0.113
0A
1.493 / 1.732
500/1
0.348 A 0.3 A
174 A (1Ph)
BUU:PTUA-R Training
© ABB Bangalore.
Slide No - 128
Testing Example
CHECK PICK-UP DIFFERENTIAL CURRENT
(1-PHASE FAULT FROM MV SIDE):
IL1SECONDARY = 0 A 0o
IL 2 SECONDARY = 0 A 240o HV
IL3SECONDARY = 0 A 120o
IL1SECONDARY = 0.348 A 0o
IL 2 SECONDARY = 0 MV
IL3SECONDARY = 0
BUU:PTUA-R Training
1.43 DIFP
250/1
0A 0A
0A
DIFFERENTIAL
Algorithm
1200/5
Set: 0.3
635 A 0.113
2.649 A 0.3 A
1.493
500/1
0A 0A
0A
BUU:PTUA-R Training
© ABB Bangalore.
Slide No - 130
Testing Example
CHECK PICK-UP DIFFERENTIAL CURRENT
(3-PHASE FAULT FROM LV SIDE):
IL1SECONDARY = 0 A 0o
IL 2 SECONDARY = 0 A 240o HV
IL3SECONDARY = 0 A 120o
IL1SECONDARY = 2.649 A 0o
IL 2 SECONDARY = 2.649 A 240o LV
IL3SECONDARY = 2.649 A 120o
1.43 DIFP
250/1
0A 0A
0A
DIFFERENTIAL
Algorithm
1200/5
Set: 0.3
635 A 0.113
(1Ph)
2.649 A 0.3 A
1.493
500/1
0A 0A
0A
BUU:PTUA-R Training
© ABB Bangalore.
Slide No - 132
Testing Example
CHECK PICK-UP DIFFERENTIAL CURRENT
(1-PHASE FAULT FROM LV SIDE):
IL1SECONDARY = 0 A 0o
IL 2 SECONDARY = 0 A 240o HV
IL3SECONDARY = 0 A 120o
IL1SECONDARY = 2.649 A 0o
IL 2 SECONDARY = 0 A 240o LV
IL3SECONDARY = 0 A 120o
BUU:PTUA-R Training