05 SEP-602B RED670 1p1 Current Functions

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Substation Automation and Protection Training

RED670 Line Differential Protection IED

©

ABB AB, 2007

Current functions

2008-01-30

Substation Automation and Protection Training

1

RED 670; Current functions Instantaneous phase overcurrent, IOC max 2 instances

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Four step phase overcurrent, TOC, 1 instance

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Instantaneous residual current, IEF, 1 instance

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Four step residual overcurrent, TEF, max 1 instance

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ABB AB, 2007

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Substation Automation and Protection Training

RED 670; Current functions

Breaker failure protection, BFP, max 2 instances

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Stub protection, STB, max 2 instances

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Thermal overload protection, THL, max 2 instances

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Pole Discordance, PD, max 2 instances

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ABB AB, 2007

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2008-01-30

Substation Automation and Protection Training

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RED 670; Current functions IOC, TOC, THL, BFP and PD are standard in the preconfigured variants: „

A31 3ph 1 CB

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A32 1ph 1 CB

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B31 3ph 2 CB

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B32 1PH 2 CB

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ABB AB, 2007

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Substation Automation and Protection Training

Instantaneous Phase Overcurrent function (PIOC, 51) „

Set as instantaneous protection where the fault current is limited to defined maximum values e.g. from a long power line or a transformer reactance.

„

Low transient overreach to allow setting close to the maximum through fault current level

„

High speed to give fast fault clearance at heavy fault currents

„

Can give phase information and be used with Distance protection as fast optional function also giving single phase tripping

„

Current can be summated from two (or more) current input sets.

IF

Σ

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ABB AB, 2007

3I>>

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Instantaneous Phase Overcurrent function (PIOC, 51)

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ABB AB, 2007

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

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Substation Automation and Protection Training

PIOC,51; Calculation of settings

Select IP>> = max(IfB,IfA)

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ABB AB, 2007

Consider also eventual transient overreach due to possible dc component of the fault current 2008-01-30

Substation Automation and Protection Training

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PIOC,51; Calculation of settings

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ABB AB, 2007

Consider also the effect of parallel line when applicable

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Substation Automation and Protection Training

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ABB AB, 2007

PIOC, 51; Function block

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Phase Overcurrent function (TOC, 51_67) „

Four stage Phase overcurrent.

„

Each stage can be set Directional or Non directional

„

Each stage can be Definite- or Inverse time delayed.

IF

Σ

3I> Æ

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ABB AB, 2007

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Substation Automation and Protection Training

„

19 IEC/ANSI curves

„

Logaritmic invers

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Taylor made curve is available

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Each stage can be blocked from second harmonic inrush currents.

„

With directional memory

„

Current can be summated from two (or more) current input sets.

Phase Overcurrent function (PTOC, 51_67)

faultState

Direction Element

I3P

4 step over current element One element for each step

dirPhAFlt dirPhBFlt

faultState PICKUP

dirPhCFlt

V3P

TRIP

I3P

Harmonic Restraint Element

harmRestrBlock

enableDir Mode Selection

enableStep1-4 DirectionalMode1-4

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ABB AB, 2007

en05000740_ansi.vsd

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ABB AB, 2007

Phase Overcurrent function (PTOC, 51_67)

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Substation Automation and Protection Training

„

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

Phase Overcurrent function (PTOC, 51_67), - Application

IF

67/51

G

3I> Æ

G

4

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ABB AB, 2007

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2008-01-30

Back-up selectivity with direction and different time grading in both directions

Substation Automation and Protection Training

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PTOC, 51_67; Direction „

The direction is determined by checking the angle of U and I

„

Voltage is the angle reference

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Lagging current is plus angle

„

With directional memory

„

Direction can be set

Reverse

Uref RCA

ROA

ROA

Forward Idir

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ABB AB, 2007

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Substation Automation and Protection Training

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Off/Non-directional

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Forward/Reverse

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RCA ~ 10-40°

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ROA ~ 100-150°

TOC, 51_67; Reset possibilities Curve name

Curve Index no.

1

IEC Reset (constant time)

2

ANSI Reset (Inverse time)

3

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ABB AB, 2007

Instantaneous

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4-step Phase overcurrent protection (TOC) „

The direction is determined by checking the angle of U and I

„

Voltage is the angle reference

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Lagging current is plus angle

„

With directional memory

jX

Forward operation Forward operation 110-150

θ

Reverse operation

10-40

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ABB AB, 2007

Reverse operation

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θ

Substation Automation and Protection Training

R

TOC, 51_67; Polarizing voltages „

UrefL2 L3 = UL2 - UL3

IdirL2 L3 = IL2 - IL3

UrefL3 L1 = UL3 - UL1

IdirL3 L1 = IL3 - IL1

Polarizing voltages at phase to earth fault UrefL1 = UL1

IdirL1 = IL1

UrefL2 = UL2

IdirL2 = IL2

UrefL3 = UL3

IdirL3 = IL3

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ABB AB, 2007

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Polarizing voltages at phase to phase fault IdirL1L2 = IL1 - IL2 UrefL1L2 = UL1 - UL2

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TOC, 51_67; Function block inputs

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ABB AB, 2007

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

TOC1OC4PTOC_51_67 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 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

VisioDocument 2008-01-30 18

Substation Automation and Protection Training

TOC, 51_67; Function block outputs TOC1OC4PTOC_51_67

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ABB AB, 2007

I3P U3P BLOCK BLKTR BLKST1 BLKST2 BLKST3 BLKST4 ENMULT1 ENMULT2 ENMULT3 ENMULT4

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Substation Automation and Protection Training

TRIP TR1 TR2 TR3 TR4 TRL1 TRL2 TRL3 TR1L1 TR1L2 TR1L3 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

General TRIP TRIP step1, step2, step3 and step4 TRIP phase L1, L2, and L3 TRIP step1 phase L1, L2, L3 TRIP step2 phase L1, L2, L3 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 block Direction phase L1, L2 and L3

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TOC, 51_67; Setting calculation For directional underreaching step1 „ „

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Select the max(IfB) Consider also eventual transient overreach due to possible dc component of the fault current The set value for the high set underreaching step can be derived as:

I1 > = 1.31 • IfB The value 1.31 includes a security margin of 10% for transient overreach and 20 % general security margin

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ABB AB, 2007

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Substation Automation and Protection Training

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ABB AB, 2007

TOC, 51_67; Setting parameters

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TOC, 51_67; Setting parameters General setting parameters Basic settings

Advanced settings StartPhSel = Number of phases needed for operation (1, 2 or 3 of 3)

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ABB AB, 2007

IminOpPhSel = Minimum current in % of Ibase for directionality Should be set lower than setting of the lowest step

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Substation Automation and Protection Training

TOC, 51_67; Setting parameters Basic setting parameters for step1

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ABB AB, 2007

K1 = Time multiplier for inverse time characteristic t1Min = Minimum operate time for inverse time characteristic I1Mult = Current multiplication factor for step1, activates if input ENMULT1 is high

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Substation Automation and Protection Training

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TOC, 51_67; Setting parameters Advanced setting parameters for step1

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ABB AB, 2007

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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Substation Automation and Protection Training

PTOC, 51_67; Setting parameters „

IBase: Base current in primary A. „

„

UBase: Base voltage in primary kV „

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Normally set to the primary voltage of the VT (PT). Range 0.05-2000

AngleRCA: Protection characteristic angle set in degrees. „

„

Normally set to the primary current of the CT. Range 1-99999

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

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ABB AB, 2007

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PTOC, 51_67; Setting parameters „

IminOpPhSel: Minimum current for phase selection set in % of Ibase „

„

StartPhSel: Number of phases, with high current, required for operation: 1 of 3, 2 of 3 or 3 of 3. „

„

Default set to Non-Directional

2ndHarmStab: Operate level of 2nd harmonic current restrain set in % of the fundamental current, range is 5-100% I steps of 1%. „

Default setting is 20%.

HarmRestrain: Off/On, enables blocking from harmonic restrain.

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ABB AB, 2007

„

Default setting is 1 of 3.

DirMode1: Directional mode „

„

should be less than the lowest step setting. Default setting is 7%.

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Substation Automation and Protection Training

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ABB AB, 2007

PTOC, 51_67; Setting parameters

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Instantaneous Earth Overcurrent function (IEF)

IF

Σ

„

Set as instantaneous protection where the fault current is limited to defined maximum values e.g. from a long power line or a transformer reactance.

„

Low transient overreach to allow setting close to the maximum through fault current level

„

High speed to give fast fault clearance at heavy fault currents

„

Can give phase information and be used with Distance protection as fast optional function also giving single phase tripping

„

Current can be summated from two (or more) current input sets.

„

Residual connection or separate inputs can be used.

Irsd or 3I0

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ABB AB, 2007

IN>>

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Substation Automation and Protection Training

4-step Earth fault protection (TEF, 51N_67N) Application Earth fault protection of feeders in effectively earthed distribution and sub transmission systems

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Back-up earth fault protection of transmission lines

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Sensitive earth fault protection of transmission lines

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Back-up earth fault protection of power transformers

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Earth fault protection of different kinds of equipment connected to the power system

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such as shunt capacitor banks, shunt reactors and others

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ABB AB, 2007

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4-step Earth fault protection (TEF)

IF

UL1+UL2+UL3

IN> Æ

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ABB AB, 2007

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Substation Automation and Protection Training

„

Four stage Earth overcurrent.

„

Each stage can be set Off, Nondirectional, Forward or Reverse

„

Each stage can be Definite- or Inverse time delayed.

„

Taylor made curve is available

„

Each stage can be blocked from second harmonic inrush currents.

„

Directional polarizing from calculated UL1+UL2+UL3 or by external Open delta to a separate Analogue input.

4-step Earth fault protection (TEF, 51N_67N) Directional element with communication and WEI

Reverse operation

3Io

„

Operation based on I*cosΦ

„

Polarising -3U0 > 1.0 %

„

CVT filter against 3rd harm

„

Characteristic angle “AngleRCA” = -180--180° o (default -65 )

„

Current can be summated from two current sets and the measurement can be from separate IN input or internally calculated: 3I0 = IL1+IL2+IL3

3Io(rev) = 0,6 x 3Io (forward)

AngleRCA

3Io

-Upol

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ABB AB, 2007

Forward operation

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Substation Automation and Protection Training

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TEF, 51N_67N; Polarizing alternatives „

Voltages polarization (-3U0)

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Current polarization (IN*ZN)

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Dual polarization Both voltage and current is allowed to polarize

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ABB AB, 2007

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Substation Automation and Protection Training

Earth Overcurrent function (TEF) - Application

IF

G

67N/51N

IN> Æ

G

4

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ABB AB, 2007

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2008-01-30

Back-up selectivity with two directions and different time grading in both directions

Substation Automation and Protection Training

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PEFM, 51N_67N; Functional overview Directional Check Element

3U0

Direction Element

4 step over current element One element for each step

operatingCurrent earthFaultDirection

3I0

signal to communication scheme

TRIP

angleValid

enableDir

3I0

Harmonic Restraint Element

harmRestrBlock

1

start step 2, 3 and 4 Blocking at parallel transformers SwitchOnToFault

Mode Selection

CB pos or cmd

enableStep1-4 DirectionalMode1-4

ABB AB, 2007

©

enableDir

TRIP

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Substation Automation and Protection Training

TEF, 51N_67N; Analogue inputs „

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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).

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ABB AB, 2007

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The function are connected to pre-processing block by the following signals

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4-step earth fault protection (TEF) Set to match the distance protection reach

t

„

„

1sec



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ABB AB, 2007



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Substation Automation and Protection Training



„

Directional or Non- directional

„

Definitive time

„

Second harmonic restrained

Step 4:

min

20 ms

2008-01-30

Step 1-3:



„

Directional or Non- directional

„

Normal inverse

„

Very Inverse

„

Extremely inverse

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Logarithmic inverse

„

Definitive time

„

Second harmonic restrained 

-

4-step earth fault protection (TEF) t

„

Directional

„

Non-directional

„

Independent or dependent time delay

Logarithmic inverse

„

Second harmonic restrained

Normal inverse

„

Settable minimum operate current and time delay

Independent

t min I min

Very inverse

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ABB AB, 2007

Extremely inverse

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4-step earth fault protection (TEF)

10

10

„

19 different IEC/ANSI Current dependent characteristic curves (New)

„

Communication logic

t1 i t2 i t3 i t4 i

1

t5 i

„

Blocking

„

Permissive overreach (POR)

„

Fault current reversal

„

Weak-end infeed echo and trip

t6 i

1 .10

1 .10

3

4

Sti

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ABB AB, 2007

0.1 0.1 100 100

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Substation Automation and Protection Training

1 .10 100000

5

Inverse characteristic for time-current back-up „ „

Required for Back-up functions TOC, TEF Diagram or characteristic showing the operating times and corresponding actuating quantities or fault positions for the selective protection relays in the network

Purpose „ Coordinate the relay settings so that „ Faulty equipment is tripped as fast as possible „ The least possible damage is obtained for the healthy equipment „ A Back-up protection is obtained if the primary protection fails to trip

Directional

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ABB AB, 2007

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Earth fault protection (TEF)– Application problem „

Energizing a transformer will always mean inrush currents.

„

Inrush has a high neutral content in directly earthed systems

„

„

2nd harmonic will be in phase opposition and the total content will after a while be reduced to small values. BlkParTrans set to “ON” and IN over a set level (1-4) can be used to maintain the blocking even if the harmonic contents is reduced and gives an advantage at parallel transformers.

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ABB AB, 2007

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A parallel transformer in service will also see the inrush. The inrush will increase successively

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Substation Automation and Protection Training

51N

51N

IN>

IN> 51N

IN>

Close 51N

IN>

ABB AB, 2007

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2008-01-30

Substation Automation and Protection Training

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STUB protection (STB)

Line discon.

open

&

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ABB AB, 2007 42

Instantaneous overcurrent protection of busbar connection (STUB) when a line disconnector is open

„

Required in Multi-breaker arrangements with CVT (VT) on line side of DS

„

Z< (21) function cannot measure when line disconnector is open and must be blocked.

t

I STUB >

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Substation Automation and Protection Training

Trip

Pole discordance protection (PD)

+



&

t

Trip

„

Pole discordance can occur at breaker closing or opening when single pole operating devices are used. - Higher than 300 kV - Single phase trip breakers

„

Contact based supervision of the poles

„

I2 criteria to verify can be added as additional criteria to increase security

„

Can be blocked during 1-ph AR to allow shorter trip times.

„

Note! Only remote b-u trip if local attempt does not remove asymmetry. Bus trip will mean a big disadvantage for service.

t

1Ph AR in progr

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ABB AB, 2007

Trip rem end

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Breaker failure protection (BFP)

G

Failing breaker

G

„

BFP is the Local back-up for breaker failures. The failures can be due to trip coil, breaker drive or breaking components failure.

„

At an breaker failure the surrounding breakers are used to clear the fault.

„

Due to the big impact a breaker failure trip will have on the power system service, the BFR function has very high requirements on security against unnecessary tripping.

„

The BFR function is started at CB tripping and if current still flows within, about 150 ms the surrounding breakers are tripped.

G

G

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ABB AB, 2007

Back-up breakers

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Substation Automation and Protection Training

Breaker failure protection (BFP) Some setting parameters

BFP I>

t1

Current level Retrip of actual breaker

Iset 0,1 – 2 * Ibase -No retrip -With current check -Without current check

Current check mode Retrip delay, one per phase Back up trip delay, one timer per phase Back-up trip 2 Trip pulse

1 out of 3 or 2 out of 4 t1 0.000 – 60.000 s t2 0.000 – 60.000 s t3 0.000 – 60.000 s tp 150 ms (settable)

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ABB AB, 2007

t2

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Breaker failure protection (BFP)

„

Adaptive current detection ASD

„

No false operation in case of saturated CT

„

Maximum reset time approx 1/2 cycle to allow short back-up tripping times.

Pre-filter Post-filter 0.5 * Stab zone

ASD output

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ABB AB, 2007

RMS output

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Substation Automation and Protection Training

Breaker failure protection (BFP)

Fault occurs Normal clearing time Current detector dropout Protection time

Breaker interrupting time

- 30 ms

Margin

- 60 ms Back-up breaker Start

BFP timer t2

BFP

Breaker time

BFP Trip

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ABB AB, 2007

Breaker failure total clearing time

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Breaker failure protection (BFP) Note! Multiple functions CB1

Start L1 Start L2 Start L3

Trip Busbar Trip CB3 Intertrip 1

3I>BF Σ

Z<

CB3 Start L1 Start L2 Start L3

3I>BF

Trip CB1 Trip CB2 Intertrip1 Intertrip2

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ABB AB, 2007

CB2

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Substation Automation and Protection Training

Start from all protection relays tripping the Breaker. Also Bus and Breaker failure protection. Not manual opening of breaker!

3I>

Energizing Check (SYN) UA

UB

A

B

ILoad Inductive and Capacitive charging of dead line

Uhigh 27 SC/VC

„

The dead line and Live bus conditions are checked.

„

Uhigh and Ulow are verified

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ABB AB, 2007

Ulow

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Synchronism Check (SYN) UA

UB

A

UAL

25

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ABB AB, 2007

SC/VC

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Substation Automation and Protection Training

B

ILoad

Icap

dφ dU

„

Paralleling (synchronism conditions are checked

„

Δφ, Δf, ΔU and Uhigh are within set values

Synchrocheck function (SYN) U-Bus

U-Line

ΔU Δφ

SYNC

Line reference voltage

Accuracy of frequency measurement about 0,5 mHz!

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ABB AB, 2007

BLOCK

U> 50-120% of Ub U< 10- 80% of Ub 80 ms (typical)

Paralleling (Synchronism) Check Frequency difference Δf < 3-1000mHz Voltage difference ΔU < 2 - 50 % of Ub Phase difference Δφ < 5 - 90o Operate time 80 ms (typical)

U-Bus

Fuse fail

Energizing check High voltage Low voltage Operate time

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Synchrocheck (SYN)– Function block Block inputs

Conditions for AR Conditions for Man close

DS Bus 1 at DB arrangement

Test conditions fulfilled

DS Bus 2 at DB arrangement DS Line at 1 1/2 arrangement

Fuse fail on sel fuse

DS alt Line at 1 1/2 arrangement

Information that the voltage is included in the synchrocheck

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

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ABB AB, 2007

Test mode inputs

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Substation Automation and Protection Training

Information that the conditions for voltage, diff voltage phase angle diff etc are fulfilled

Synchrocheck (SYN) – Voltage selection 1U

B1Q

B2Q

1U UB1

UB2

SYN1 ULN1

3U

DB Volt sel

1U

1U

IED

UB2

UB1

SYN1

SYN2

ULN1 LN1Q

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ABB AB, 2007

3U

No Volt sel 2008-01-30

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Synchrocheck (SYN) – Voltage selection

IED 1

3U UB2

1U

SYN1

IED

ULN1

SYN1

B1Q

3U

1U UB1

LN1Q

1U

IED 2

SYN1

SYN2

1U 1U

1U

IED 3

LN2Q

SYN1

B2Q

3U

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ABB AB, 2007

No Volt sel 2008-01-30 54

Substation Automation and Protection Training

1U

1 U ULN2 UB2 1U

1 ½ CB Volt sel

Synchrocheck (SYN) – Voltage selection

REC670

SYN1

1U 3U

SYN2

SYN3

3U 1U

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ABB AB, 2007

No Volt sel 2008-01-30

Substation Automation and Protection Training

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Auto Reclosing (AR) Single-/ Two-/ Three-phase reclosing programs Program

1st attempt

2nd attempt

3rd and 4st attempt

1

3 phase

3 phase

3 phase

3 phase

2

1/2/3 phase

3

1/2 phase (No 3 phase) 1/2 phase (No 3 phase)

1 phase 2 phase 3 phase 1 phase 2 phase 1 phase 2 phase

3 phase 3 phase 3 phase 3 phase 3 phase 3 phase ----

3 phase 3 phase 3 phase 3 phase 3 phase 3 phase ----

1 phase 2 phase 3 phase 1 phase 2 phase 3 phase

3 phase 3 phase ---3 phase -------

3 phase 3 phase ---3 phase -------

4

1/2/3 phase

6

1/2/3 phase

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ABB AB, 2007

5

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Substation Automation and Protection Training

Auto-Reclosing (AR)– new in REx670 Start Quick AR without synchrocheck Skip a step and continue with next (at multiple shots)

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ABB AB, 2007

Put AR on hold e.g. waiting for Thermal relays to reset to have less sag before reclosing 2008-01-30

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ABB AB, 2007

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

„ 2008-01-30 58

Frequency protection Substation Automation and Protection Training

TOF/TUF/RVF(df/dt) – Frequency Protection-Functionality „

Detection of over- or underfrequency

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Six stages of each function

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Measures Ph-Ph or Positive sequence voltage

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Undervoltage (Dead) blocking level

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Trip signal – each step fully individually: „

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High accuracy, short measuring time

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Df/dt with positive or negative setting

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Accuracy 2 mHz for three phase

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Accuracy 50 mHz for single phase

Voltage dependent tripping time!

ABB AB, 2007

©

Settable frequency and settable time delay

2008-01-30

Substation Automation and Protection Training

59

TOF/TUF – Frequency Protection - Application Load shedding system

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System restoration system

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Generation shedding

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Remedial Action schemes

©

ABB AB, 2007

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2008-01-30 60

Substation Automation and Protection Training

Trip Circuit Supervision– Application with 670 series +

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3s



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Trip Circuit supervision can be arranged using Binary inputs or mA inputs.

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mA inputs shall be used if supervision is required from both sides i.e. at Lock-out tripping

ABB AB, 2007

©

2008-01-30 61

Trip Circuit fail

Substation Automation and Protection Training

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