generator protection reg650 product guide · 2018-05-10 · ns2 ptoc 46 i2> oc4 ptoc 51 3i>...

Relion® 650 series

Generator protection REG650Product Guide

Contents

1. 650 series overview..............................................3

2. Application...........................................................3

3. Available functions...............................................5

4. Differential protection.........................................15

5. Impedance protection........................................16

6. Current protection..............................................17

7. Voltage protection..............................................20

8. Frequency protection.........................................22

9. Secondary system supervision..........................22

10. Control...............................................................23

11. Logic..................................................................24

12. Monitoring.........................................................25

13. Metering............................................................27

14. Human Machine interface.................................28

15. Basic IED functions...........................................28

16. Station communication.....................................29

17. Hardware description........................................30

18. Connection diagrams........................................32

19. Technical data...................................................36

20. Ordering............................................................76

Disclaimer

The information in this document is subject to change without notice and should not be construed as a commitment by ABB AB. ABB AB assumesno responsibility for any errors that may appear in this document.

© Copyright 2011 ABB AB.

All rights reserved.

Trademarks

ABB and Relion are registered trademarks of ABB Group. All other brand or product names mentioned in this document may be trademarks orregistered trademarks of their respective holders.

Generator protection REG650 1MRK 502 036-BEN -Product version: 1.1 Issued: February 2011

2 ABB

1. 650 series overview

The 650 series IEDs provide optimum 'off-the-shelf', ready-to-use solutions. It is configuredwith complete protection functionality anddefault parameters to meet the needs of awide range of applications for generationtransmission and sub-transmission grids.

The 650 series IEDs include:

• Complete ready-made solutions optimizedfor a wide range of applications forgeneration, transmission and sub-transmission grids.

• Support for user-defined names in the locallanguage for signal and functionengineering.

• Minimized parameter setting based ondefault values and ABB's new global basevalue concept. You only need to set thoseparameters specific to your ownapplication, such as the line data.

• GOOSE messaging for horizontalcommunication.

• Extended HMI functionality with 15dynamic three-color-indication LEDs perpage, on up to three pages, andconfigurable push-button shortcuts fordifferent actions.

• Programmable LED text-based labels.• Settable 1A/5A -rated current inputs.

2. Application

REG650 is used for the protection andmonitoring of generating plants. The IED isespecially suitable for applications indistributed control systems with highdemands on reliability. It is intended mainlyfor small and medium size generation stations.

REG670 may be used when more extensiveprotection systems are required or incombination with REG650 to provideredundant schemes.

A wide range of protection functions isavailable to achieve full and reliableprotection for different types of generatingplants, for example hydro power plants andthermal power plants. This enablesadaptation to the protection requirements ofmost generating plants.

Protection functions are available fordetecting and clearing internal faults, such asgenerator stator short circuits and earthfaults, generator rotor earth faults, unittransformer short circuits and earth faults andfaults in the external power system, fed fromthe generating plant.

Two packages have been defined for thefollowing applications:

• Generator protection IED includinggenerator differential protection (B01)

• Generator-transformer unit protectionIED including transformer differentialprotection (B05)

In many generating plants, the protectionsystem can be designed with a combinationof the two packages, that is, two IEDs ofeither same type or different types, will giveredundant protection for a generating unit(generator and unit transformer) dependingon the requirements for the plant design.

The packages are configured and ready foruse. Analogue inputs and binary input/outputcircuits are pre-defined.

The pre-configured IED can be changed andadapted with the graphical configuration tool.


Revision: -

ABB 3

A, B, C or D

~

59N UN>

STEF PHIZ

59THD U3d/N

REG650-B01

TR PTTR

49 Ith

LEX PDIS

40

OEX PVPH

24 U/f>

UV2 PTUV

27 3U<

OV2 PTOV

59 3U>

OC4 PTOC

51 3I>

GEN PDIF

87G 3Id/I

SA PTUF

81U f<

110kV HV Substation

VR2 PVOC

51V I>/U<ZG PDIS

21 Z<

AEG GAPC

50AE U

SA PTOF

81O f>YY

SDD RFUF

60FL

Note:

1) Input for independent non-directional OC and overload functions. It can be used for different purposes (e.g. OC protection for either Auxiliary trafo or Excitation trafo or Step-up transformer HV side)

I

U

NS2 PTOC

46 I2>

OC4 PTOC

51 3I>

CC RPLD

52PD PD

CC RBRF

50BF 3I> BF

YY

Generator CB

AuxiliaryTransformer

UnitTransformer

29MVA121/11kV

YNd5

ExcitationTransformer

HV CB

ROV2 PTOV

59N 3Uo>

TR PTTR

49 Ith

OOS PPAM

78 Ucos

SES RSYN

25 SC

1)

2)

3)

3) Input for independent directional (sensitive) EF function. It can be used for different purposes (e.g. as rotor EF with RXTTE4 or stator EF for generators operating in parallel)

Fiel

d C

B

HZ PDIF

87N IdN

2) Input for independent non-directional EF function. It can be used for different purposes (e.g. as stator EF protection or turn-to-turn protection for generators with split winding or even HV side EF protection). Alternatively it can be used for High-Impedance REF protection.

ROV2 PTOV

59N 3Uo>

CV MMXN

Meter.

GOP PDOP

32

GOP PDUP

37 P<

TRM module with 4I+1I*+5U AIM module with 6I+4U

¤)

¤) Requires dedicated CT cores, external resistor and metrosil for correct operation

V MSQI

47 U2>

EF4 PTOC

67N

SDE PSDE

67N

Rotor EF protection 64R

GOP PDOP

32Q

SA PFRC

81R df/dt

390kVA11/0.37kV

Dyn11

50/5

1600/5

1600/5

10/1

1.6MVA11/0.4kV

EF4 PTOC

51N IN>

11 0.11 0.11/ /

33 3kV

11 0.11 0.11/ /

33 3kV

11/ 0.11

3kV

200/1

100/52500/5

1000

29MVA11kV

150rpm

RX

TTE

4

D

C B

A

H J, G or H

200/5

G

Y200/1

J

C MSQI

Meter.

IEC10000299-1-en.vsd

Q

P

IN> IN> <

IEC10000299 V1 EN

Figure 1. Generator protection IED including generator differential protection (B01)


4 ABB

~

STEF PHIZ

59THD U3d/N

REG650-B05

LEX PDIS

40

GOP PDOP

32

OEX PVPH

24 U/f>

UV2 PTUV

27 3U<

OV2 PTOV

59 3U>

T3D PDIF

87T 3Id/I

SA PTUF

81U f<

110kV HV Substation

VR2 PVOC

51V I>/U<ZG PDIS

21 Z<

AEG GAPC

50AE U

SA PTOF

81O f>YY

I

U

NS2 PTOC

46 I2>

OC4 PTOC

51 3I>

CC RPLD

52PD PD

CC RBRF

50BF 3I> BF

YY

Generator CB

HV CB

ROV2 PTOV

59N 3Uo>

TR PTTR

49 Ith

OOS PPAM

78 Ucos

SES RSYN

25 SC

Note:

2) Input for independent non-directional EF function. It can be used for different purposes (e.g. as stator EF protection or turn-to-turn protection for generators with split winding or even HV side EF protection). Alternatively it can be used for High-Impedance REF protection.

1) Inputs for independent directional (sensitive) EF function. It can be used for different purposes (e.g. as rotor EF with RXTTE4 or stator EF for generators running in parallel)

1)

2)

Fiel

d C

B

TR PTTR

49 Ith

OC4 PTOC

51 3I>

HZ PDIF

87N IdN

EF4 PTOC

51N IN>

GT01

ROV2 PTOV

59N 3Uo>

59N UN>

YY

CV MMXN

Meter.

GOP PDUP

37 P<

TRM module with 4I+1I*+5U AIM module with 6I+4U

¤)

¤) Requires dedicated CT cores, external resistor and metrosil for correct operation

V MSQI

47 U2>

EF4 PTOC

67N

SDE PSDE

67N

Rotor EF protection 64R

CV MMXN

Meter.

GOP PDOP

32Q

SA PFRC

81R df/dt

3)

3) Alternatively step-up transformer HV side open delta VT can be connected here

Generator CB

AuxiliaryTransformer

UnitTransformer

29MVA121/11kV

YNd5

ExcitationTransformer

390kVA11/0.37kV

Dyn11

50/5

1600/5

29MVA11kV

150rpm

200/1

100/5

1.6MVA11/0.4kV

11 0.11 0.11/ /

33 3kV

110 0.11 0.11/ /

33 3kV

11/ 0.11

3kV

2500/5

1000

RXT

TE4

C

B

E

A

D

A or B

D or E

200/5

G

1600/5

10/1H J, G or H

Y200/1

J

SDD RFUF

60FL

C MSQI

Meter.


IN> IN>

Q

P

<

IEC10000300 V1 EN

Figure 2. Generator-transformer unit protection IED including transformer differentialprotection (B05)


ABB 5

3. Available functions

Main protection functions

IEC 61850/Functionblock name

ANSI Function description Generator

REG

650 (

B01)

Gen

dif

f

REG

650 (

B05)

Gen

+Tra

fo d

iff

Differential protection

T3WPDIF 87T Transformer differential protection, three winding 1

HZPDIF 87 1Ph High impedance differential protection 1 1

GENPDIF 87G Generator differential protection 1

Impedance protection

ZGPDIS 21G Underimpedance protection for generators andtransformers

1 1

LEXPDIS 40 Loss of excitation 1 1

OOSPPAM 78 Out-of-step protection 1 1

LEPDIS Load encroachment 1 1


6 ABB

Back-up protection functions

IEC 61850/Functionblockname


REG

650 (

B01)

Gen

dif

f

REG

650 (

B05)

Gen

+Tra

fo d

iff

Current protection

OC4PTOC 51/67 Four step directional phase overcurrent protection 2 2

EF4PTOC 51N/67N

Four step directional residual overcurrentprotection

2 2

SDEPSDE 67N Sensitive directional residual overcurrent andpower protection

1 1

TRPTTR 49 Thermal overload protection, two time constants 2 2

CCRBRF 50BF Breaker failure protection 1 1

CCRPLD 52PD Pole discordance protection 1 1

GUPPDUP 37 Directional underpower protection 1 1

GOPPDOP 32 Directional overpower protection 2 2

AEGGAPC 50AE Accidental energizing protection for synchronousgenerator

1 1

NS2PTOC 46I2 Negative-sequence time overcurrent protectionfor machines

1 1

VR2PVOC 51V Voltage-restrained time overcurrent protection 1 1

Voltage protection

UV2PTUV 27 Two step undervoltage protection 1 1

OV2PTOV 59 Two step overvoltage protection 1 1

ROV2PTOV 59N Two step residual overvoltage protection 2 2

OEXPVPH 24 Overexcitation protection 1 1

STEFPHIZ 59THD 100% Stator earth fault protection, 3rd harmonicbased

1 1

Frequency protection


ABB 7

IEC 61850/Functionblockname


REG

650 (

B01)

Gen

dif

f

REG

650 (

B05)

Gen

+Tra

fo d

iff

SAPTUF 81 Underfrequency function 4 4

SAPTOF 81 Overfrequency function 4 4

SAPFRC 81 Rate-of-change frequency protection 2 2


8 ABB

Control and monitoring functions

IEC 61850/Function blockname


REG

650 (

B01)

Gen

dif

f

REG

650 (

B05)

Gen

+Tra

fo d

iff

Control

SESRSYN 25 Synchrocheck, energizing check, andsynchronizing

1 1

QCBAY Bay control 1 1

LOCREM Handling of LR-switch positions 1 1

LOCREMCTRL LHMI control of Permitted Source To Operate(PSTO)

1 1

SLGGIO Logic Rotating Switch for function selectionand LHMI presentation

15 15

VSGGIO Selector mini switch extension 20 20

DPGGIO IEC 61850 generic communication I/Ofunctions double point

16 16

SPC8GGIO Single point generic control 8 signals 5 5

AUTOBITS AutomationBits, command function forDNP3.0

3 3

I103CMD Function commands for IEC60870-5-103 1 1

I103IEDCMD IED commands for IEC60870-5-103 1 1

I103USRCMD Function commands user defined forIEC60870-5-103

4 4

I103GENCMD Function commands generic forIEC60870-5-103

50 50

I103POSCMD IED commands with position and select forIEC60870-5-103

50 50

Secondary system supervision

SDDRFUF Fuse failure supervision 1 1

TCSSCBR Breaker close/trip circuit monitoring 3 3

Logic


ABB 9



REG

650 (

B01)

Gen

dif

f

REG

650 (

B05)

Gen

+Tra

fo d

iff

SMPPTRC 94 Tripping logic 6 6

TMAGGIO Trip matrix logic 12 12

OR Configurable logic blocks, OR gate 283 283

INVERTER Configurable logic blocks, Inverter gate 140 140

PULSETIMER Configurable logic blocks, Pulse timer 40 40

GATE Configurable logic blocks, Controllable gate 40 40

XOR Configurable logic blocks, exclusive OR gate 40 40

LOOPDELAY Configurable logic blocks, loop delay 40 40

TIMERSET Configurable logic blocks, timer function block 40 40

AND Configurable logic blocks, AND gate 280 280

SRMEMORY Configurable logic blocks, set-reset memoryflip-flop gate

40 40

RSMEMORY Configurable logic blocks, reset-set memoryflip-flop gate

40 40

FXDSIGN Fixed signal function block 1 1

B16I Boolean 16 to Integer conversion 16 16

B16IFCVI Boolean 16 to Integer conversion with logicnode representation

16 16

IB16A Integer to Boolean 16 conversion 16 16

IB16FCVB Integer to Boolean 16 conversion with logicnode representation

16 16

Monitoring

CVMMXN Measurements 6 6

CMMXU Phase current measurement 10 10

VMMXU Phase-phase voltage measurement 6 6

CMSQI Current sequence component measurement 6 6

VMSQI Voltage sequence measurement 6 6


10 ABB



REG

650 (

B01)

Gen

dif

f

REG

650 (

B05)

Gen

+Tra

fo d

iff

VNMMXU Phase-neutral voltage measurement 6 6

CNTGGIO Event counter 5 5

DRPRDRE Disturbance report 1 1

AxRADR Analog input signals 4 4

BxRBDR Binary input signals 6 6

SPGGIO IEC 61850 generic communication I/Ofunctions

64 64

SP16GGIO IEC 61850 generic communication I/Ofunctions 16 inputs

16 16

MVGGIO IEC 61850 generic communication I/Ofunctions

16 16

MVEXP Measured value expander block 66 66

SPVNZBAT Station battery supervision 1 1

SSIMG 63 Insulation gas monitoring function 2 2

SSIML 71 Insulation liquid monitoring function 2 2

SSCBR Circuit breaker condition monitoring 1 1

I103MEAS Measurands for IEC60870-5-103 1 1

I103MEASUSR Measurands user defined signals forIEC60870-5-103

3 3

I103AR Function status auto-recloser forIEC60870-5-103

1 1

I103EF Function status earth-fault for IEC60870-5-103 1 1

I103FLTPROT Function status fault protection forIEC60870-5-103

1 1

I103IED IED status for IEC60870-5-103 1 1

I103SUPERV Supervison status for IEC60870-5-103 1 1

I103USRDEF Status for user defined signals forIEC60870-5-103

20 20


ABB 11



REG

650 (

B01)

Gen

dif

f

REG

650 (

B05)

Gen

+Tra

fo d

iff

Metering

PCGGIO Pulse counter logic 16 16

ETPMMTR Function for energy calculation and demandhandling

3 3


12 ABB

Designed to communicate



REG

650 (

B01)

Gen

dif

f

REG

650 (

B05)

Gen

+Tra

fo d

iff

Station communication

IEC 61850 communication protocol, LAN1 1 1

DNP3.0 for TCP/IP communicationprotocol, LAN1

1 1

IEC61870-5-103 IEC60870-5-103 serial communication viaST

1 1

GOOSEINTLKRCV Horizontal communication via GOOSE forinterlocking

59 59

GOOSEBINRCV GOOSE binary receive 4 4

GOOSEDPRCV GOOSE function block to receive a doublepoint value

32 32

GOOSEINTRCV GOOSE function block to receive aninteger value

32 32

GOOSEMVRCV GOOSE function block to receive amesurand value

16 16

GOOSESPRCV GOOSE function block to receive a singlepoint value

64 64


ABB 13

Basic IED functions


Function description

Basic functions included in all products

INTERRSIG Self supervision with internal event list 1

SELFSUPEVLST Self supervision with internal event list 1

SNTP Time synchronization 1

TIMESYNCHGEN Time synchronization 1

DTSBEGIN,DTSEND,TIMEZONE

Time synchronization, daylight saving 1

IRIG-B Time synchronization 1

SETGRPS Setting group handling 1

ACTVGRP Parameter setting groups 1

TESTMODE Test mode functionality 1

CHNGLCK Change lock function 1

TERMINALID IED identifiers 1

PRODINF Product information 1

PRIMVAL Primary system values 1

SMAI_20_1-12 Signal matrix for analog inputs 2

3PHSUM Summation block 3 phase 12

GBASVAL Global base values for settings 6

ATHSTAT Authority status 1

ATHCHCK Authority check 1

FTPACCS FTP access with password 1

DOSFRNT Denial of service, frame rate control for front port 1

DOSLAN1 Denial of service, frame rate control for LAN1 1

DOSSCKT Denial of service, socket flow control 1


14 ABB

4. Differential protection

Transformer differential protectionT2WPDIF/T3WPDIF

The Transformer differential protection, two-winding (T2WPDIF) and Transformerdifferential protection, three-winding(T3WPDIF) are provided with internal CTratio matching and vector groupcompensation and settable, zero sequencecurrent elimination.

The function can be provided with two orthree-phase sets of current inputs. All currentinputs are provided with percentage biasrestraint features, making the IED suitable fortwo- or three-winding transformerarrangements.

Two-winding applications

xx05000048.vsd

IEC05000048 V1 EN

two-windingpowertransformer

Three-winding applications

xx05000052.vsd

IEC05000052 V1 EN

three-windingpowertransformer withall threewindingsconnected

xx05000049.vsd

IEC05000049 V1 EN

three-windingpowertransformer withunconnecteddelta tertiarywinding

Figure 3. CT group arrangement fordifferential protection andother protections

The setting facilities cover for applications ofthe differential protection to all types ofpower transformers and auto-transformerswith or without load tap changer as well asfor shunt reactors or and local feeders within

the station. An adaptive stabilizing feature isincluded for heavy through-faults.

Stabilization is included for inrush currents aswell as for overexcitation condition. Adaptivestabilization is also included for systemrecovery inrush and CT saturation forexternal faults. A high set unrestraineddifferential current protection is included fora very high speed tripping at a high internalfault currents.

An innovative sensitive differential protectionfeature, based on the theory of symmetricalcomponents, offers the best possiblecoverage for power transformer winding turn-to-turn faults.

1Ph High impedance differentialprotection HZPDIF

The 1Ph High impedance differentialprotection HZPDIF function can be usedwhen the involved CT cores have the sameturn ratio and similar magnetizingcharacteristics. It utilizes an externalsummation of the currents in theinterconnected CTs and a series resistor and avoltage dependent resistor externally to theIED.

HZPDIF can be used as high impedance REFprotection.

Generator differential protectionGENPDIF

Short circuit between the phases of the statorwindings causes normally very large faultcurrents. The short circuit gives risk ofdamages on insulation, windings and statoriron core. The large short circuit currentscause large forces, which can cause damageeven to other components in the powerplant, such as turbine and generator-turbineshaft.

The task of Generator differential protectionGENPDIF is to determine whether a fault iswithin the protected zone, or outside theprotected zone. If the fault is internal, thefaulty generator must be quickly tripped, thatis, disconnected from the network, the field


ABB 15

breaker tripped and the power to the primemover interrupted.

To limit the damage due to stator windingshort circuits, the fault clearance must be asfast as possible (instantaneous). If thegenerator block is connected to the powersystem close to other generating blocks, thefast fault clearance is essential to maintain thetransient stability of the non-faultedgenerators.

Normally, the short circuit fault current isvery large, that is, significantly larger than thegenerator rated current. There is a risk that ashort circuit can occur between phases closeto the neutral point of the generator, thuscausing a relatively small fault current. Thefault current can also be limited due to lowexcitation of the generator. Therefore, it isdesired that the detection of generator phase-to-phase short circuits shall be relativelysensitive, detecting small fault currents.

It is also of great importance that thegenerator differential protection does not tripfor external faults, with large fault currentsflowing from the generator. To combine fastfault clearance, as well as sensitivity andselectivity, the generator differentialprotection is normally the best choice forphase-to-phase generator short circuits. Anegative-sequence-current-based internal-external fault discriminator can be used todetermine whether a fault is internal orexternal. The internal-external faultdiscriminator not only positivelydiscriminates between internal and externalfaults, but can independently detect minorfaults which may not be felt (until theydevelop into more serious faults) by the"usual" differential protection based onoperate-restrain characteristic.

An open CT circuit condition createsunexpected operations for Generatordifferential protection under the normal loadconditions. It is also possible to damagesecondary equipment due to high voltageproduced from open CT circuit outputs.Therefore, it may be a requirement fromsecurity and reliability points of view to have

open CT detection function to blockGenerator differential protection function incase of open CT conditions and at the sametime produce the alarm signal to theoperational personal to make quick remedyactions to correct the open CT condition.

Generator differential protection GENPDIF isalso well suited to generate fast, sensitive andselective fault clearance, if used to protectshunt reactors or small busbars

5. Impedance protection

Underimpedance protection forgenerators and transformersZGPDIS

The underimpedance protection forgenerators and transformers ZGPDIS, has theoffset mho characteristic as a three zone back-up protection for detection of short circuits intransformers and generators. The three zoneshave independent measuring and settingsthat gives high flexibility for all types ofapplications.

Load encroachment characteristic is availablefor third zone as shown in figure 4.

en07000117.vsd

jX

Operation area Operation area

R

Operation area

No operation area No operation area

IEC07000117 V1 EN

Figure 4. Load encroachment influence onthe offset mho characteristic


16 ABB

Loss of excitation LEXPDIS

There are limits for the low excitation of asynchronous machine. A reduction of theexcitation current weakens the couplingbetween the rotor and the stator. Themachine may lose the synchronism and startto operate like an induction machine. Then,the reactive power consumption willincrease. Even if the machine does not loosesynchronism it may not be acceptable tooperate in this state for a long time.Reduction of excitation increases thegeneration of heat in the end region of thesynchronous machine. The local heating maydamage the insulation of the stator windingand the iron core.

To prevent damages to the generator itshould be tripped when excitation becomestoo low.

Out-of-step protection OOSPPAM

Out-of-step protection (OOSPPAM) functionin the IED can be used both for generatorprotection application as well as, lineprotection applications.

The main purpose of the OOSPPAM functionis to detect, evaluate, and take the requiredaction during pole slipping occurrences inthe power system.

The OOSPPAM function detects pole slipconditions and trips the generator as fast aspossible, that is after the first pole-slip if thecentre of oscillation is found to be in zone 1which normally includes the generator and itsstep-up power transformer. If the centre ofoscillation is found to be further out in thepower system, that is, in zone 2, more thanone pole-slip is usually allowed before thegenerator-transformer unit is disconnected. Ifthere are several out-of-step relays in thepower system, then one which finds thecentre of oscillation in its zone 1 shalloperate first.

Load encroachment LEPDIS

Heavy load transfer is common in manypower networks and may make fault

resistance coverage difficult to achieve. Insuch a case, Load encroachment (LEPDIS)function can be used to enlarge the resistivesetting of the underimpedance measuringzones without interfering with the load.

6. Current protection

Four step phase overcurrentprotection OC4PTOC

The four step phase overcurrent protectionfunction OC4PTOC has an inverse or definitetime delay independent for step 1 and 4separately. Step 2 and 3 are always definitetime delayed.

All IEC and ANSI time delayed characteristicsare available.

The directional function is voltage polarizedwith memory. The function can be set to bedirectional or non-directional independentlyfor each of the steps.

Four step residual overcurrentprotection EF4PTOC

The four step residual overcurrent protection(EF4PTOC) has a settable inverse or definitetime delay independent for step 1 and 4separately. Step 2 and 3 are always definitetime delayed.

All IEC and ANSI time delayed characteristicsare available.

The directional function is voltage polarized,current polarized or dual polarized.

EF4PTOC can be set directional or non-directional independently for each of the steps.

A second harmonic blocking can be setindividually for each step.

Sensitive directional residualovercurrent and power protectionSDEPSDE

In isolated networks or in networks withhigh impedance earthing, the earth faultcurrent is significantly smaller than the short


ABB 17

circuit currents. In addition to this, themagnitude of the fault current is almostindependent on the fault location in thenetwork. The protection can be selected touse either the residual current or residualpower component 3U0·3I0·cos j, for

operating quantity. There is also availableone non-directional 3I0 step and one non-

directional 3U0 overvoltage tripping step.

Thermal overload protection, twotime constant TRPTTR

If a power transformer or generator reachesvery high temperatures the equipment mightbe damaged. The insulation within thetransformer/generator will have forcedageing. As a consequence of this the risk ofinternal phase-to-phase or phase-to-earthfaults will increase. High temperature willdegrade the quality of the transformer/generator insulation.

The thermal overload protection estimatesthe internal heat content of the transformer/generator (temperature) continuously. Thisestimation is made by using a thermal modelof the transformer/generator with two timeconstants, which is based on currentmeasurement.

Two warning levels are available. Thisenables actions in the power system to bedone before dangerous temperatures arereached. If the temperature continues toincrease to the trip value, the protectioninitiates a trip of the protected transformer/generator.

Breaker failure protection CCRBRF

Breaker failure protection (CCRBRF) ensuresfast back-up tripping of surrounding breakersin case the own breaker failure to open.CCRBRF can be current based, contact based,or an adaptive combination of these twoprinciples.

A current check with extremely short resettime is used as check criterion to achieve ahigh security against unnecessary operation.

A contact check criteria can be used wherethe fault current through the breaker is small.

Breaker failure protection (CCRBRF) currentcriteria can be fulfilled by one or two phasecurrents, or one phase current plus residualcurrent. When those currents exceed the userdefined settings, the function is activated.These conditions increase the security of theback-up trip command.

CCRBRF function can be programmed to givea three-phase re-trip of the own breaker toavoid unnecessary tripping of surroundingbreakers at an incorrect initiation due tomistakes during testing.

Pole discordance protectionCCRPLD

Circuit breakers and disconnectors can endup with the poles in different positions (close-open), due to electrical or mechanicalfailures. This can cause negative and zerosequence currents which cause thermal stresson rotating machines and can causeunwanted operation of zero sequence ornegative sequence current functions.

Normally the own breaker is tripped tocorrect such a situation. If the situationpersists the surrounding breakers should betripped to clear the unsymmetrical loadsituation.

The pole discordance function operates basedon information from the circuit breaker logicwith additional criteria from unsymmetricalphase currents when required.

Directional over/underpowerprotection GOPPDOP/GUPPDUP

The directional over-/under-power protectionGOPPDOP/GUPPDUP can be used wherevera high/low active, reactive or apparent powerprotection or alarming is required. Thefunctions can alternatively be used to checkthe direction of active or reactive power flowin the power system. There are a number ofapplications where such functionality isneeded. Some of them are:


18 ABB

• detection of reversed active power flow• detection of high reactive power flow

Each function has two steps with definitetime delay. Reset times for both steps can beset as well.

Accidental energizing protectionfor synchronous generatorAEGGAPC

Inadvertent or accidental energizing of off-line generators has occurred often enoughdue to operating errors, breaker headflashovers, control circuit malfunctions, or acombination of these causes. Inadvertentlyenergized generator operates as inductionmotor drawing a large current from thesystem. The voltage supervised overcurrentprotection is used to protect the inadvertentlyenergized generator.

Accidental energizing protection forsynchronous generator (AEGGAPC) takes themaximum phase current input from thegenerator terminal side or from generatorneutral side and maximum phase to phasevoltage inputs from the terminal side.AEGGAPC is armed when the terminalvoltage drops below the specified voltagelevel for the preset time.

Negative sequence time overcurrentprotection for machines NS2PTOC

Negative-sequence time overcurrentprotection for machines NS2PTOC is intendedprimarily for the protection of generatorsagainst possible overheating of the rotorcaused by negative sequence component inthe stator current.

The negative sequence currents in agenerator may, among others, be caused by:

• Unbalanced loads• Line to line faults• Line to earth faults• Broken conductors• Malfunction of one or more poles of a

circuit breaker or a disconnector

NS2PTOC can also be used as a backupprotection, that is, to protect the generator in

the event line protections or circuit breakersfail to clear unbalanced system faults.

To provide an effective protection for thegenerator for external unbalanced conditions,NS2PTOC is able to directly measure thenegative sequence current. NS2PTOC also hasa time delay characteristic which matches theheating characteristic of the generator

22I t K= as defined in standard.

where:

I2 is negative sequence currentexpressed in per unit of the ratedgenerator current

t is operating time in seconds

K is a constant which depends of thegenerators size and design

NS2PTOC has a wide range of K settings andthe sensitivity and capability of detecting andtripping for negative sequence currents downto the continuous capability of a generator.

A separate output is available as an alarmfeature to warn the operator of a potentiallydangerous situation.

Voltage-restrained time overcurrentprotection VR2PVOC

Voltage-restrained time overcurrentprotection (VR2PVOC) function isrecommended as a backup protection forgenerators.

The overcurrent protection feature has asettable current level that can be used eitherwith definite time or inverse timecharacteristic. Additionally, it can be voltagecontrolled/restrained.

One undervoltage step with definite timecharacteristic is also available with thefunction in order to provide funcionality forovercurrent protection with undervoltage seal-in.


ABB 19

7. Voltage protection

Two step undervoltage protectionUV2PTUV

Undervoltages can occur in the power systemduring faults or abnormal conditions. Twostep undervoltage protection (UV2PTUV)function can be used to open circuit breakersto prepare for system restoration at poweroutages or as long-time delayed back-up toprimary protection.

UV2PTUV has two voltage steps, where step1 is settable as inverse or definite timedelayed. Step 2 is always definite time delayed.

Two step overvoltage protectionOV2PTOV

Overvoltages may occur in the power systemduring abnormal conditions such as suddenpower loss, tap changer regulating failures,open line ends on long lines etc.

OV2PTOV has two voltage steps, where step1 can be set as inverse or definite timedelayed. Step 2 is always definite time delayed.

OV2PTOV has an extremely high reset ratioto allow settings close to system servicevoltage.

Two step residual overvoltageprotection ROV2PTOV

Residual voltages may occur in the powersystem during earth faults.

Two step residual overvoltage protectionROV2PTOV function calculates the residualvoltage from the three-phase voltage inputtransformers or measures it from a singlevoltage input transformer fed from an opendelta or neutral point voltage transformer.

ROV2PTOV has two voltage steps, wherestep 1 can be set as inverse or definite timedelayed. Step 2 is always definite time delayed.

Overexcitation protectionOEXPVPH

When the laminated core of a powertransformer or generator is subjected to a

magnetic flux density beyond its designlimits, stray flux will flow into non-laminatedcomponents not designed to carry flux andcause eddy currents to flow. The eddycurrents can cause excessive heating andsevere damage to insulation and adjacentparts in a relatively short time. The functionhas settable inverse operating curves andindependent alarm stages.

95% and 100% Stator earth faultprotection based on 3rd harmonicSTEFPHIZ

Stator earth fault is a fault type havingrelatively high fault rate. The generatorsystems normally have high impedanceearthing, that is, earthing via a neutral pointresistor. This resistor is normallydimensioned to give an earth fault current inthe range 3 – 15 A at a solid earth-faultdirectly at the generator high voltageterminal. The relatively small earth faultcurrents give much less thermal andmechanical stress on the generator, comparedto the short circuit case, which is betweenconductors of two phases. Anyhow, the earthfaults in the generator have to be detectedand the generator has to be tripped, even iflonger fault time compared to internal shortcircuits, can be allowed.

In normal non-faulted operation of thegenerating unit the neutral point voltage isclose to zero, and there is no zero sequencecurrent flow in the generator. When a phase-to-earth fault occurs the neutral point voltagewill increase and there will be a current flowthrough the neutral point resistor.

To detect an earth fault on the windings of agenerating unit one may use a neutral pointovervoltage protection, a neutral pointovercurrent protection, a zero sequenceovervoltage protection or a residualdifferential protection. These protections aresimple and have served well during manyyears. However, at best these simple schemesprotect only 95% of the stator winding. Theyleave 5% close to the neutral endunprotected. Under unfavorable conditions


20 ABB

the blind zone may extend up to 20% fromthe neutral.

The 95% stator earth fault protectionmeasures the fundamental frequency voltagecomponent in the generator star point and itoperates when it exceeds the preset value. Byapplying this principle approximately 95% ofthe stator winding can be protected. In orderto protect the last 5% of the stator windingclose to the neutral end the 3rd harmonic

voltage measurement can be performed. In100% Stator E/F 3rd harmonic protectioneither the 3rd harmonic voltage differentialprinciple, the neutral point 3rd harmonicundervoltage principle or the terminal side3rd harmonic overvoltage principle can beapplied. However, differential principle isstrongly recommended. Combination of thesetwo measuring principles provides coveragefor entire stator winding against earth faults.

x E3

Rf

TCB 2(1-x) E3

overvoltage protection 10% – 100%

Differential0% – 30%

CB 1 may not exist

RN

NCB 1

stator winding

uTuN

x E3

Rf Transformer

TCB 2(1-x) E3

x

Neutral point fundamental frequency over-voltage protection 5% - 100%

3rd harmonic differential0% - 30%

CB 1 may not exist

1 or 100 %

RN

NNCB 1

stator winding

uTuN 1 - x1 - xSamples of the neutral voltage from which the

fundamental and 3rd harmonic voltages are filtered out

Samples of the terminal voltage from which the 3rd harmonic

voltage is filtered out


IEC10000202 V1 EN

Figure 5. Protection principles for STEFPHIZ function

Rotor earth fault protection 64R

Generator rotor winding and its associated dcsupply electric circuit is typically fullyinsulated from the earth (that is, ground).Therefore single connection of this circuit toearth will not cause flow of any substantialcurrent. However if second earth faultappears in this circuit circumstances can bequit serious. Depending on the location ofthese two faults such operating conditionmay cause:

• Partial or total generator loss of field• Large dc current flow through rotor

magnetic circuit• Rotor vibration• Rotor displacement sufficient to cause

stator mechanical damage

Therefore practically all bigger generatorshave some dedicated protection which iscapable to detect the first earth fault in therotor circuit and then, depending on the faultresistance, either just to give an alarm to theoperating personnel or actually to give stopcommand to the machine. Requires injectionunit for rotor earth fault protection (RXTTE4)and a protective resistor on plate for correctoperation.


ABB 21

8. Frequency protection

Underfrequency protection SAPTUF

Underfrequency occurs as a result of lack ofgeneration in the network.

Underfrequency protection SAPTUF is usedfor load shedding systems, remedial actionschemes, gas turbine startup and so on.

SAPTUF is provided with an undervoltageblocking.

Overfrequency protection SAPTOF

Overfrequency protection function SAPTOF isapplicable in all situations, where reliabledetection of high fundamental power systemfrequency is needed.

Overfrequency occurs at sudden load dropsor shunt faults in the power network. Closeto the generating plant, generator governorproblems can also cause over frequency.

SAPTOF is used mainly for generationshedding and remedial action schemes. It isalso used as a frequency stage initiating loadrestoring.

SAPTOF is provided with an undervoltageblocking.

Rate-of-change frequencyprotection SAPFRC

Rate-of-change frequency protection function(SAPFRC) gives an early indication of a maindisturbance in the system. SAPFRC can beused for generation shedding, load sheddingand remedial action schemes. SAPFRC candiscriminate between positive or negativechange of frequency.

SAPFRC is provided with an undervoltageblocking.

9. Secondary systemsupervision

Fuse failure supervision SDDRFUF

The aim of the fuse failure supervisionfunction (SDDRFUF) is to block voltagemeasuring functions at failures in thesecondary circuits between the voltagetransformer and the IED in order to avoidunwanted operations that otherwise mightoccur.

The fuse failure supervision function basicallyhas three different algorithms, negativesequence and zero sequence basedalgorithms and an additional delta voltageand delta current algorithm.

The negative sequence detection algorithm isrecommended for IEDs used in isolated orhigh-impedance earthed networks. It is basedon the negative-sequence measuringquantities, a high value of voltage 3U2

without the presence of the negative-sequence current 3I2.

The zero sequence detection algorithm isrecommended for IEDs used in directly orlow impedance earthed networks. It is basedon the zero sequence measuring quantities, ahigh value of voltage 3U0 without the

presence of the residual current 3I0.

A criterion based on delta current and deltavoltage measurements can be added to thefuse failure supervision function in order todetect a three phase fuse failure, which inpractice is more associated with voltagetransformer switching during stationoperations.

For better adaptation to system requirements,an operation mode setting has beenintroduced which makes it possible to selectthe operating conditions for negativesequence and zero sequence based function.The selection of different operation modes


22 ABB

makes it possible to choose differentinteraction possibilities between the negativesequence and zero sequence based algorithm.

Breaker close/trip circuitmonitoring TCSSCBR

The trip circuit supervision function TCSSCBRis designed to supervise the control circuit ofthe circuit breaker. The invalidity of a controlcircuit is detected by using a dedicatedoutput contact that contains the supervisionfunctionality.

The function operates after a predefinedoperating time and resets when the faultdisappears.

10. Control

Synchrocheck, energizing check,and synchronizing SESRSYN

The Synchronizing function allows closing ofasynchronous networks at the correctmoment including the breaker closing time,which improves the network stability.

Synchrocheck, energizing check, andsynchronizing (SESRSYN) function checksthat the voltages on both sides of the circuitbreaker are in synchronism, or with at leastone side dead to ensure that closing can bedone safely.

SESRSYN function includes a built-in voltageselection scheme for double bus arrangements.

Manual closing as well as automatic reclosingcan be checked by the function and can havedifferent settings.

For systems which are running asynchronousa synchronizing function is provided. Themain purpose of the synchronizing functionis to provide controlled closing of circuitbreakers when two asynchronous systems aregoing to be connected. It is used for slipfrequencies that are larger than those forsynchrocheck and lower than a set maximumlevel for the synchronizing function.

Bay control QCBAY

The Bay control QCBAY function is usedtogether with Local remote and local remotecontrol functions is used to handle theselection of the operator place per bay.QCBAY also provides blocking functions thatcan be distributed to different apparatuseswithin the bay.

Local remote LOCREM /Localremote control LOCREMCTRL

The signals from the local HMI or from anexternal local/remote switch are applied viathe function blocks LOCREM andLOCREMCTRL to the Bay control (QCBAY)function block. A parameter in function blockLOCREM is set to choose if the switch signalsare coming from the local HMI or from anexternal hardware switch connected viabinary inputs.

Logic rotating switch for functionselection and LHMI presentationSLGGIO

The logic rotating switch for functionselection and LHMI presentation function(SLGGIO) (or the selector switch functionblock) is used to get a selector switchfunctionality similar to the one provided by ahardware selector switch. Hardware selectorswitches are used extensively by utilities, inorder to have different functions operating onpre-set values. Hardware switches arehowever sources for maintenance issues,lower system reliability and an extendedpurchase portfolio. The logic selectorswitches eliminate all these problems.

Selector mini switch VSGGIO

The Selector mini switch VSGGIO functionblock is a multipurpose function used for avariety of applications, as a general purposeswitch.

VSGGIO can be controlled from the menu orfrom a symbol on the single line diagram(SLD) on the local HMI.


ABB 23

IEC 61850 generic communicationI/O functions DPGGIO

The IEC 61850 generic communication I/Ofunctions (DPGGIO) function block is used tosend double indications to other systems orequipment in the substation. It is especiallyused in the interlocking and reservationstation-wide logics.

Single point generic control 8signals SPC8GGIO

The Single point generic control 8 signals(SPC8GGIO) function block is a collection of8 single point commands, designed to bringin commands from REMOTE (SCADA) tothose parts of the logic configuration that donot need extensive command receivingfunctionality (for example, SCSWI). In thisway, simple commands can be sent directlyto the IED outputs, without confirmation.Confirmation (status) of the result of thecommands is supposed to be achieved byother means, such as binary inputs andSPGGIO function blocks. The commands canbe pulsed or steady.

AutomationBits AUTOBITS

The Automation bits function (AUTOBITS) isused to configure the DNP3 protocolcommand handling.

11. Logic

Tripping logic SMPPTRC

A function block for protection tripping isprovided for each circuit breaker involved inthe tripping of the fault. It provides the pulseprolongation to ensure a trip pulse ofsufficient length, as well as all functionalitynecessary for correct co-operation withautoreclosing functions.

The trip function block includes functionalityfor breaker lock-out.

Trip matrix logic TMAGGIO

Trip matrix logic TMAGGIO function is usedto route trip signals and other logical outputsignals to different output contacts on the IED.

TMAGGIO output signals and the physicaloutputs allows the user to adapt the signalsto the physical tripping outputs according tothe specific application needs.

Configurable logic blocks

A number of logic blocks and timers areavailable for the user to adapt theconfiguration to the specific application needs.

• OR function block.

• INVERTER function blocks that inverts theinput signal.

• PULSETIMER function block can be used,for example, for pulse extensions orlimiting of operation of outputs.

• GATE function block is used for whetheror not a signal should be able to pass fromthe input to the output.

• XOR function block.

• LOOPDELAY function block used to delaythe output signal one execution cycle.

• TIMERSET function has pick-up and drop-out delayed outputs related to the inputsignal. The timer has a settable time delay.

• AND function block.

• SRMEMORY function block is a flip-flopthat can set or reset an output from twoinputs respectively. Each block has twooutputs where one is inverted. The memorysetting controls if the block should be resetor return to the state before theinterruption, after a power interruption. Setinput has priority.

• RSMEMORY function block is a flip-flopthat can reset or set an output from twoinputs respectively. Each block has two


24 ABB

outputs where one is inverted. The memorysetting controls if the block should be resetor return to the state before theinterruption, after a power interruption.Reset input has priority.

Boolean 16 to Integer conversionB16I

Boolean 16 to integer conversion function(B16I) is used to transform a set of 16 binary(logical) signals into an integer.

Boolean 16 to Integer conversionwith logic node representationB16IFCVI

Boolean 16 to integer conversion with logicnode representation function (B16IFCVI) isused to transform a set of 16 binary (logical)signals into an integer.

Integer to Boolean 16 conversionIB16A

Integer to boolean 16 conversion function(IB16A) is used to transform an integer into aset of 16 binary (logical) signals.

Integer to Boolean 16 conversionwith logic node representationIB16FCVB

Integer to boolean conversion with logicnode representation function (IB16FCVB) isused to transform an integer to 16 binary(logic) signals.

IB16FCVB function can receive remote valuesover IEC61850 depending on the operatorposition input (PSTO).

12. Monitoring

Measurements CVMMXN, CMMXU,VNMMXU, VMMXU, CMSQI, VMSQI

The measurement functions are used to get on-line information from the IED. These servicevalues make it possible to display on-line

information on the local HMI and on theSubstation automation system about:

• measured voltages, currents, frequency,active, reactive and apparent power andpower factor

• primary and secondary phasors• current sequence components• voltage sequence components

Event counter CNTGGIO

Event counter (CNTGGIO) has six counterswhich are used for storing the number oftimes each counter input has been activated.

Disturbance report DRPRDRE

Complete and reliable information aboutdisturbances in the primary and/or in thesecondary system together with continuousevent-logging is accomplished by thedisturbance report functionality.

Disturbance report DRPRDRE, alwaysincluded in the IED, acquires sampled data ofall selected analog input and binary signalsconnected to the function block that is,maximum 40 analog and 96 binary signals.

The Disturbance report functionality is acommon name for several functions:

• Event list• Indications• Event recorder• Trip value recorder• Disturbance recorder

The Disturbance report function ischaracterized by great flexibility regardingconfiguration, starting conditions, recordingtimes, and large storage capacity.

A disturbance is defined as an activation ofan input to the AxRADR or BxRBDR functionblocks, which are set to trigger thedisturbance recorder. All signals from start ofpre-fault time to the end of post-fault timewill be included in the recording.

Every disturbance report recording is savedin the IED in the standard Comtrade format.The same applies to all events, which arecontinuously saved in a ring-buffer. The local


ABB 25

HMI is used to get information about therecordings. The disturbance report files maybe uploaded to PCM600 for further analysisusing the disturbance handling tool.

Event list DRPRDRE

Continuous event-logging is useful formonitoring the system from an overviewperspective and is a complement to specificdisturbance recorder functions.

The event list logs all binary input signalsconnected to the Disturbance report function.The list may contain up to 1000 time-taggedevents stored in a ring-buffer.

Indications DRPRDRE

To get fast, condensed and reliableinformation about disturbances in theprimary and/or in the secondary system it isimportant to know, for example binarysignals that have changed status during adisturbance. This information is used in theshort perspective to get information via thelocal HMI in a straightforward way.

There are three LEDs on the local HMI(green, yellow and red), which will displaystatus information about the IED and theDisturbance report function (trigged).

The Indication list function shows all selectedbinary input signals connected to theDisturbance report function that havechanged status during a disturbance.

Event recorder DRPRDRE

Quick, complete and reliable informationabout disturbances in the primary and/or inthe secondary system is vital, for example,time-tagged events logged duringdisturbances. This information is used fordifferent purposes in the short term (forexample corrective actions) and in the longterm (for example functional analysis).

The event recorder logs all selected binaryinput signals connected to the Disturbancereport function. Each recording can containup to 150 time-tagged events.

The event recorder information is availablefor the disturbances locally in the IED.

The event recording information is anintegrated part of the disturbance record(Comtrade file).

Trip value recorder DRPRDRE

Information about the pre-fault and faultvalues for currents and voltages are vital forthe disturbance evaluation.

The Trip value recorder calculates the valuesof all selected analog input signals connectedto the Disturbance report function. The resultis magnitude and phase angle before andduring the fault for each analog input signal.

The trip value recorder information isavailable for the disturbances locally in theIED.

The trip value recorder information is anintegrated part of the disturbance record(Comtrade file).

Disturbance recorder DRPRDRE

The Disturbance recorder function suppliesfast, complete and reliable information aboutdisturbances in the power system. Itfacilitates understanding system behavior andrelated primary and secondary equipmentduring and after a disturbance. Recordedinformation is used for different purposes inthe short perspective (for example correctiveactions) and long perspective (for examplefunctional analysis).

The Disturbance recorder acquires sampleddata from selected analog- and binary signalsconnected to the Disturbance report function(maximum 40 analog and 96 binary signals).The binary signals available are the same asfor the event recorder function.

The function is characterized by greatflexibility and is not dependent on theoperation of protection functions. It canrecord disturbances not detected byprotection functions.

The disturbance recorder information for thelast 100 disturbances are saved in the IED


26 ABB

and the local HMI is used to view the list ofrecordings.

Measured value expander blockMVEXP

The current and voltage measurementsfunctions (CVMMXN, CMMXU, VMMXU andVNMMXU), current and voltage sequencemeasurement functions (CMSQI and VMSQI)and IEC 61850 generic communication I/Ofunctions (MVGGIO) are provided withmeasurement supervision functionality. Allmeasured values can be supervised with foursettable limits: low-low limit, low limit, highlimit and high-high limit. The measure valueexpander block has been introduced toenable translating the integer output signalfrom the measuring functions to 5 binarysignals: below low-low limit, below low limit,normal, above high-high limit or above highlimit. The output signals can be used asconditions in the configurable logic or foralarming purpose.

Station battery supervisionSPVNZBAT

The station battery supervision functionSPVNZBAT is used for monitoring batteryterminal voltage.

SPVNZBAT activates the start and alarmoutputs when the battery terminal voltageexceeds the set upper limit or drops belowthe set lower limit. A time delay for theovervoltage and undervoltage alarms can beset according to definite time characteristics.

In the definite time (DT) mode, SPVNZBAToperates after a predefined operate time andresets when the battery undervoltage orovervoltage condition disappears.

Insulation gas monitoring functionSSIMG

Insulation gas monitoring function (SSIMG) isused for monitoring the circuit breakercondition. Binary information based on thegas pressure in the circuit breaker is used asinput signals to the function. In addition, thefunction generates alarms based on receivedinformation.

Insulation liquid monitoringfunction SSIML

Insulation liquid monitoring function (SSIML)is used for monitoring the circuit breakercondition. Binary information based on theoil level in the circuit breaker is used as inputsignals to the function. In addition, thefunction generates alarms based on receivedinformation.

Circuit breaker monitoring SSCBR

The circuit breaker condition monitoringfunction SSCBR is used to monitor differentparameters of the circuit breaker. Thebreaker requires maintenance when thenumber of operations has reached apredefined value. The energy is calculatedfrom the measured input currents as a sum of

Iyt values. Alarms are generated when thecalculated values exceed the thresholdsettings.

The function contains a blockingfunctionality. It is possible to block thefunction outputs, if desired.

13. Metering

Pulse counter logic PCGGIO

Pulse counter (PCGGIO) function countsexternally generated binary pulses, forinstance pulses coming from an externalenergy meter, for calculation of energyconsumption values. The pulses are capturedby the BIO (binary input/output) moduleand then read by the PCGGIO function. Ascaled service value is available over thestation bus.

Function for energy calculation anddemand handling ETPMMTR

Outputs from the Measurements (CVMMXN)function can be used to calculate energyconsumption. Active as well as reactivevalues are calculated in import and exportdirection. Values can be read or generated as


ABB 27

pulses. Maximum demand power values arealso calculated by the function.

14. Human Machineinterface

Local HMI

GUID-23A12958-F9A5-4BF1-A31B-F69F56A046C7 V2 EN

Figure 6. Local human-machine interface

The LHMI of the IED contains the followingelements:

• Display (LCD)• Buttons• LED indicators• Communication port

The LHMI is used for setting, monitoring andcontrolling .

The Local human machine interface, LHMIincludes a graphical monochrome LCD with aresolution of 320x240 pixels. The charactersize may vary depending on selectedlanguage. The amount of characters and rowsfitting the view depends on the character sizeand the view that is shown.

The LHMI can be detached from the mainunit. The detached LHMI can be wallmounted up to a distance of five meters from

the main unit. The units are connected withthe Ethernet cable included in the delivery.

The LHMI is simple and easy to understand.The whole front plate is divided into zones,each with a well-defined functionality:

• Status indication LEDs• Alarm indication LEDs which can

indicate three states with the colorsgreen, yellow and red, with userprintable label. All LEDs are configurablefrom the PCM600 tool

• Liquid crystal display (LCD)• Keypad with push buttons for control

and navigation purposes, switch forselection between local and remotecontrol and reset

• Five user programmable function buttons• An isolated RJ45 communication port for

PCM600

15. Basic IED functions

Self supervision with internal eventlist

The Self supervision with internal event list(INTERRSIG and SELFSUPEVLST) functionreacts to internal system events generated bythe different built-in self-supervisionelements. The internal events are saved in aninternal event list.

Time synchronization

Use time synchronization to achieve acommon time base for the IEDs in aprotection and control system. This makescomparison of events and disturbance databetween all IEDs in the system possible.

Time-tagging of internal events anddisturbances are an excellent help whenevaluating faults. Without timesynchronization, only the events within theIED can be compared to one another. Withtime synchronization, events anddisturbances within the entire station, and


28 ABB

even between line ends, can be compared atevaluation.

In the IED, the internal time can besynchronized from a number of sources:

• SNTP• IRIG-B• DNP• IEC60870-5-103

Parameter setting groups ACTVGRP

Use the four sets of settings to optimize theIED operation for different system conditions.Creating and switching between fine-tunedsetting sets, either from the local HMI orconfigurable binary inputs, results in a highlyadaptable IED that can cope with a variety ofsystem scenarios.

Test mode functionality TESTMODE

The protection and control IEDs have manyincluded functions. To make the testingprocedure easier, the IEDs include the featurethat allows individual blocking of a single-,several-, or all functions.

There are two ways of entering the test mode:

• By configuration, activating an inputsignal of the function block TESTMODE

• By setting the IED in test mode in thelocal HMI

While the IED is in test mode, all functionsare blocked.

Any function can be unblocked individuallyregarding functionality and event signaling.This enables the user to follow the operationof one or several related functions to checkfunctionality and to check parts of theconfiguration, and so on.

Change lock function CHNGLCK

Change lock function (CHNGLCK) is used toblock further changes to the IEDconfiguration and settings once thecommissioning is complete. The purpose is toblock inadvertent IED configuration changesbeyond a certain point in time.

Authority status ATHSTAT

Authority status (ATHSTAT) function is anindication function block for user log-onactivity.

Authority check ATHCHCK

To safeguard the interests of our customers,both the IED and the tools that are accessingthe IED are protected, by means ofauthorization handling. The authorizationhandling of the IED and the PCM600 isimplemented at both access points to the IED:

• local, through the local HMI• remote, through the communication ports

16. Stationcommunication

IEC 61850-8-1 communicationprotocol

The IED supports the communicationprotocols IEC 61850-8-1 and DNP3 over TCP/IP. All operational information and controlsare available through these protocols.However, some communication functionality,for example, horizontal communication(GOOSE) between the IEDs, is only enabledby the IEC 61850-8-1 communication protocol.

The IED is equipped with an optical Ethernetrear port for the substation communicationstandard IEC 61850-8-1. IEC 61850-8-1protocol allows intelligent electrical devices(IEDs) from different vendors to exchangeinformation and simplifies systemengineering. Peer-to-peer communicationaccording to GOOSE is part of the standard.Disturbance files uploading is provided.

Disturbance files are accessed using the IEC61850-8-1 protocol. Disturbance files areavailable to any Ethernet based applicationvia FTP in the standard Comtrade format.Further, the IED can send and receive binary


ABB 29

values, double point values and measuredvalues (for example from MMXU functions),together with their quality, using the IEC61850-8-1 GOOSE profile. The IED meets theGOOSE performance requirements fortripping applications in substations, asdefined by the IEC 61850 standard. The IEDinteroperates with other IEC 61850-compliantIEDs, tools, and systems and simultaneouslyreports events to five different clients on theIEC 61850 station bus.

The event system has a rate limiter to reduceCPU load. The event channel has a quota of10 events/second. If the quota is exceededthe event channel transmission is blockeduntil the event changes is below the quota,no event is lost.

All communication connectors, except for thefront port connector, are placed on integratedcommunication modules. The IED isconnected to Ethernet-based communicationsystems via the fibre-optic multimode LCconnector (100BASE-FX).

The IED supports SNTP and IRIG-B timesynchronization methods with a time-stamping resolution of 1 ms.

• Ethernet based: SNTP and DNP3• With time synchronization wiring: IRIG-B

The IED supports IEC 60870-5-103 timesynchronization methods with a timestamping resolution of 5 ms.

Table 1. Supported communicationinterface and protocol alternatives

Interfaces/Protocols

Ethernet100BASE-

FX LC

STconnector

IEC61850-8-1

DNP3

IEC60870-5-103

= Supported

Horizontal communication viaGOOSE for interlocking

GOOSE communication can be used forexchanging information between IEDs via theIEC 61850-8-1 station communication bus.This is typically used for sending apparatusposition indications for interlocking orreservation signals for 1-of-n control. GOOSEcan also be used to exchange any boolean,integer, double point and analog measuredvalues between IEDs.

DNP3 protocol

DNP3 (Distributed Network Protocol) is a setof communications protocols used tocommunicate data between components inprocess automation systems. For a detaileddescription of the DNP3 protocol, see theDNP3 Communication protocol manual.

IEC 60870-5-103 communicationprotocol

IEC 60870-5-103 is an unbalanced (master-slave) protocol for coded-bit serialcommunication exchanging information witha control system, and with a data transfer rateup to 38400 bit/s. In IEC terminology, aprimary station is a master and a secondarystation is a slave. The communication isbased on a point-to-point principle. Themaster must have software that can interpretIEC 60870-5-103 communication messages.

17. Hardware description

Layout and dimensions

Mounting alternatives

The following mounting alternatives areavailable (IP40 protection from the front):

• 19” rack mounting kit• Wall mounting kit• Flush mounting kit• 19" dual rack mounting kit


30 ABB

See ordering for details about availablemounting alternatives.

Flush mounting the IED

H

I

K

J

C

F

G

B

A

ED

IEC09000672.ai

IEC09000672 V1 EN

Figure 7. Flush mounting the IED into a panelcut-out

A 240 mm G 21.55 mm

B 21.55 mm H 220 mm

C 227 mm I 265.9 mm

D 228.9 mm J 300 mm

E 272 mm K 254 mm

F ∅6 mm

A

B

C

IEC09000673.ai

IEC09000673 V1 EN

Figure 8. Flush mounted IED

A 222 mm

B 27 mm

C 13 mm

Rack mounting the IED

A C

B

E

D

IEC09000676.ai

IEC09000676 V1 EN

Figure 9. Rack mounted IED

A 224 mm + 12 mm with ring-lug connector

B 25.5 mm

C 482.6 mm (19")

D 265.9 mm (6U)

E 13 mm

A

BC

E

D

IEC09000677.ai

IEC09000677 V1 EN

Figure 10. Two rack mounted IEDs side by side

A 224 mm + 12 mm with ring-lug connector

B 25.5 mm

C 482.6 mm (19")

D 13 mm

E 265.9 mm (6U)


ABB 31

Wall mounting the IED

C

F

G

B

A

ED

IEC09000678.ai

IEC09000678 V1 EN

Figure 11. Wall mounting the IED

A 270 mm E 190.5 mm

B 252.5 mm F 296 mm

C ∅6.8 mm G 13 mm

D 268.9 mm

GUID-5C185EAC-13D0-40BD-8511-58CA53EFF7DE V1 EN

Figure 12. Main unit and detached LHMIdisplay

A 25.5 mm E 258.6 mm

B 220 mm F 265.9 mm

C 13 mm G 224 mm

D 265.9 mm


32 ABB

18. Connection diagrams

1MRK006501-NB 2 PG 1.1 IEC V1 EN

Figure 13. Designation for 6U, 1/2x19" casingwith 1 TRM and 1 AIM

Module Slot Rear Position

COM pCOM X0, X1, X4, X9,X304

PSM pPSM X307, X309, X410

TRM p2 X101, X102

AIM p4 X103, X104

BIO p5 X331, X334

BIO p6 X336, X339


ABB 33

Connection diagrams for REG650 B01


Figure 14. Communication module (COM)


Figure 15. Power supply module (PSM)48-125V DC


Figure 16. Power supply module (PSM),110-250V DC


Figure 17. Transformer module (TRM)


34 ABB


Figure 18. Analog input module (AIM)


Figure 19. Binary input/output (BIO) option(Terminal X331, X334)

Connection diagrams for REG650 B05

1MRK006501-PB 3 PG 1.1 IEC V1 EN

Figure 20. Communication module (COM)


Figure 21. Power supply module (PSM)48-125V DC


ABB 35


Figure 22. Power supply module (PSM),110-250V DC


Figure 23. Transformer module (TRM)


Figure 24. Analog input module (AIM)


Figure 25. Binary input/output (BIO) option(Terminal X331, X334)


36 ABB

19. Technical data

General

Definitions

Referencevalue

The specified value of an influencing factor to which are referred thecharacteristics of the equipment

Nominalrange

The range of values of an influencing quantity (factor) within which, underspecified conditions, the equipment meets the specified requirements

Operativerange

The range of values of a given energizing quantity for which the equipment,under specified conditions, is able to perform its intended functionsaccording to the specified requirements

Energizing quantities, rated valuesand limits


ABB 37

Analog inputs

Table 2. Energizing inputs

Description Value

Rated frequency 50/60 Hz

Operating range Rated frequency ± 5 Hz

Current inputs Rated current, In 0.1/0.5 A1) 1/5 A2)

Thermal withstandcapability:

• Continuously 4 A 20 A

• For 1 s 100 A 500 A

• For 10 s 20 A 100 A

Dynamic currentwithstand:

• Half-wave value 250 A 1250 A

Input impedance <100 mΩ <20 mΩ

Voltage inputs Rated voltage, Un 100 V AC/ 110 V AC/ 115 V AC/ 120 V AC

Voltage withstand:

• Continuous 420 V rms

• For 10 s 450 V rms

Burden at rated voltage <0.05 VA

1) Residual current2) Phase currents or residual current


38 ABB

Auxiliary DC voltage

Table 3. Power supply

Description Type 1 Type 2

Uauxnominal 100, 110, 120, 220, 240 VAC, 50 and 60 Hz

48, 60, 110, 125 V DC

110, 125, 220, 250 V DC

Uauxvariation 85...110% of Un (85...264 V

AC)

80...120% of Un (38.4...150 V

DC)

80...120% of Un (88...300 V

DC)

Maximum load of auxiliaryvoltage supply

35 W

Ripple in the DC auxiliaryvoltage

Max 15% of the DC value (at frequency of 100 Hz)

Maximum interruption time inthe auxiliary DC voltagewithout resetting the IED

50 ms at Uaux

Binary inputs and outputs

Table 4. Binary inputs

Description Value

Operating range Maximum input voltage 300 V DC

Rated voltage 24...250 V DC

Current drain 1.6...1.8 mA

Power consumption/input <0.3 W

Threshold voltage 15...221 V DC (parametrizable in the range insteps of 1% of the rated voltage)


ABB 39

Table 5. Signal output and IRF output

IRF relay change over - type signal output relay

Description Value

Rated voltage 250 V AC/DC

Continuous contact carry 5 A

Make and carry for 3.0 s 10 A

Make and carry 0.5 s 30 A

Breaking capacity when the control-circuittime constant L/R<40 ms, at U< 48/110/220V DC

≤0.5 A/≤0.1 A/≤0.04 A

Table 6. Power output relays without TCS function

Description Value

Rated voltage 250 V AC/DC





≤1 A/≤0.3 A/≤0.1 A

Table 7. Power output relays with TCS function

Description Value

Rated voltage 250 V DC





≤1 A/≤0.3 A/≤0.1 A

Control voltage range 20...250 V DC

Current drain through the supervision circuit ~1.0 mA

Minimum voltage over the TCS contact 20 V DC


40 ABB

Table 8. Ethernet interfaces

Ethernet interface Protocol Cable Data transfer rate

LAN/HMI port (X0)1) - CAT 6 S/FTP or better 100 MBits/s

LAN1 (X1) TCP/IP protocol Fibre-optic cablewith LC connector

100 MBits/s

1) Only available for the external HMI option.

Table 9. Fibre-optic communication link

Wave length Fibre type Connector Permitted path

attenuation1)

Distance

1300 nm MM 62.5/125μm glassfibre core

LC <8 dB 2 km

1) Maximum allowed attenuation caused by connectors and cable together

Table 10. X4/IRIG-B interface

Type Protocol Cable

Screw terminal, pinrow header

IRIG-B Shielded twisted pair cableRecommended: CAT 5, Belden RS-485 (9841-9844) or Alpha Wire (Alpha 6222-6230)

Table 11. Serial rear interface

Type Counter connector

Serial port (X9) Optical serial port, type ST for IEC60870-5-103

Influencing factors

Table 12. Degree of protection of flush-mounted IED

Description Value

Front side IP 40

Rear side, connection terminals IP 20

Table 13. Degree of protection of the LHMI

Description Value

Front and side IP 42


ABB 41

Table 14. Environmental conditions

Description Value

Operating temperature range -25...+55ºC (continuous)

Short-time service temperature range -40...+70ºC (<16h)Note: Degradation in MTBF and HMIperformance outside the temperature rangeof -25...+55ºC

Relative humidity <93%, non-condensing

Atmospheric pressure 86...106 kPa

Altitude up to 2000 m

Transport and storage temperature range -40...+85ºC

Table 15. Environmental tests

Description Type test value Reference

Cold tests operation storage

96 h at -25ºC16 h at -40ºC 96 h at -40ºC

IEC 60068-2-1

Dry heat tests operation storage

16 h at +70ºC 96 h at +85ºC

IEC 60068-2-2

Damp heattests

steady state cyclic

240 h at +40ºChumidity 93% 6 cycles at +25 to +55ºChumidity 93...95%

IEC 60068-2-78 IEC 60068-2-30


42 ABB

Type tests according to standards

Table 16. Electromagnetic compatibility tests


100 kHz and 1 MHz burstdisturbance test

IEC 61000-4-18IEC 60255-22-1, level 3

• Common mode 2.5 kV

• Differential mode 1.0 kV

Electrostatic discharge test IEC 61000-4-2IEC 60255-22-2, level 4

• Contact discharge 8 kV

• Air discharge 15 kV

Radio frequency interferencetests

• Conducted, common mode 10 V (emf), f=150 kHz...80MHz

IEC 61000-4-6IEC 60255-22-6, level 3

• Radiated, amplitude-modulated

20 V/m (rms), f=80...1000MHz and f=1.4...2.7 GHz

IEC 61000-4-3IEC 60255-22-3, level 3

Fast transient disturbancetests

IEC 61000-4-4IEC 60255-22-4, class A

• Communication ports 2 kV

• Other ports 4 kV

Surge immunity test IEC 61000-4-5IEC 60255-22-5, level 3/2

• Communication 1 kV line-to-earth

• Other ports 2 kV line-to-earth, 1 kV line-to-line

Power frequency (50 Hz)magnetic field

IEC 61000-4-8, level 5

• 3 s 1000 A/m

• Continuous 100 A/m


ABB 43

Table 16. Electromagnetic compatibility tests, continued


Power frequency immunitytest

• Common mode

• Differential mode

300 V rms 150 V rms

IEC 60255-22-7, class AIEC 61000-4-16

Voltage dips and shortinterruptions

Dips:40%/200 ms70%/500 msInterruptions:0-50 ms: No restart0...∞ s : Correct behaviour atpower down

IEC 60255-11IEC 61000-4-11

Electromagnetic emissiontests

EN 55011, class AIEC 60255-25

• Conducted, RF-emission(mains terminal)

0.15...0.50 MHz < 79 dB(µV) quasi peak< 66 dB(µV) average

0.5...30 MHz < 73 dB(µV) quasi peak< 60 dB(µV) average

• Radiated RF-emission

30...230 MHz < 40 dB(µV/m) quasi peak,measured at 10 m distance

230...1000 MHz < 47 dB(µV/m) quasi peak,measured at 10 m distance


44 ABB

Table 17. Insulation tests


Dielectric tests: IEC 60255-5

• Test voltage 2 kV, 50 Hz, 1 min1 kV, 50 Hz, 1 min,communication

Impulse voltage test: IEC 60255-5

• Test voltage 5 kV, unipolar impulses,waveform 1.2/50 μs, sourceenergy 0.5 J1 kV, unipolar impulses,waveform 1.2/50 μs, sourceenergy 0.5 J, communication

Insulation resistancemeasurements

IEC 60255-5

• Isolation resistance >100 MΏ, 500 V DC

Protective bonding resistance IEC 60255-27

• Resistance <0.1 Ώ (60 s)

Table 18. Mechanical tests

Description Reference Requirement

Vibration response tests(sinusoidal)

IEC 60255-21-1 Class 2

Vibration endurance test IEC60255-21-1 Class 1

Shock response test IEC 60255-21-2 Class 1

Shock withstand test IEC 60255-21-2 Class 1

Bump test IEC 60255-21-2 Class 1

Seismic test IEC 60255-21-3 Class 2

Product safety

Table 19. Product safety

Description Reference

LV directive 2006/95/EC

Standard EN 60255-27 (2005)


ABB 45

EMC compliance

Table 20. EMC compliance

Description Reference

EMC directive 2004/108/EC

Standard EN 50263 (2000)EN 60255-26 (2007)


46 ABB

Differential protection

Table 21. Transformer differential protection T2WPDIF, T3WPDIF

Function Range or value Accuracy

Operating characteristic Adaptable ± 1.0% of Ir for I < Ir± 1.0% of Ir for I > Ir

Reset ratio >94% -

Unrestrained differential currentlimit

(1.00-50.00)xIBaseon high voltagewinding

± 1.0% of set value

Base sensitivity function (0.05 - 0.60) xIBase

± 1.0% of Ir

Minimum negative sequencecurrent

(0.02 - 0.20) xIBase

± 1.0% of Ir

Operate angle, negative sequence (30.0 - 90.0)degrees

± 1.0 degrees

Second harmonic blocking (5.0-100.0)% offundamentaldifferential current

± 2.0% of Ir

Fifth harmonic blocking (5.0-100.0)% offundamentaldifferential current

± 12.0% of Ir

Connection type for each of thewindings

Y or D -

Phase displacement between highvoltage winding, W1 and each ofthe windings, W2 and W3. Hournotation

0–11 -

Operate time, restrained function 25 ms typically at0 to 5 x Ib

-

Reset time, restrained function 25 ms typically at5 to 0 x Ib

-

Operate time, unrestrainedfunction

20 ms typically at0 to 5 x Ib

-

Reset time, unrestrained function 25 ms typically at5 to 0 x Ib

-


ABB 47

Table 22. 1Ph High impedance differential protection HZPDIF


Operate voltage (20-400) VI=U/R

± 1.0% of Ir

Reset ratio >95% -

Maximum continuous voltage U>Trip2/series resistor ≤200 W -

Operate time 15 ms typically at 0 to 10 x Ud -

Reset time 90 ms typically at 10 to 0 x Ud -

Critical impulse time 2 ms typically at 0 to 10 x Ud -

Table 23. Generator differential protection GENPDIF


Reset ratio > 90% -

Unrestrained differential currentlimit

(1-50)p.u. of IBase ± 1.0% of set value

Base sensitivity function (0.05–1.00)p.u. ofIBase

± 1.0% of Ir

Negative sequence current level (0.02–0.2)p.u. ofIBase

± 1.0% of Ir

Operate time, restrained function 40 ms typically at0 to 2 x set level

-

Reset time, restrained function 40 ms typically at2 to 0 x set level

-

Operate time, unrestrainedfunction

20 ms typically at0 to 5 x set level

-

Reset time, unrestrained function 40 ms typically at5 to 0 x set level

-

Operate time, negative sequenceunrestrained function

15 ms typically at0 to 5 x set level

-

Critical impulse time, unrestrainedfunction

2 ms typically at 0to 5 x set level

-


48 ABB

Impedance protection

Table 24. Underimpedance protection for generators and transformers ZGPDIS


Number of zones 3 -

Forward positive sequenceimpedance

(0.005-3000.000)Ω/phase

± 2.0% static accuracyConditions:

• Voltage range: (0.1-1.1) x Ur

• Current range: (0.5-30) x Ir• Angle: at 0 degrees and 85

degrees

Reverse positive sequenceimpedance

(0.005-3000.000)Ω/phase

-

Angle for positive sequenceimpedance,

(10-90) degrees -

Timers (0.000-60.000) s ± 0.5% ± 10 ms

Operate time 55 ms typically -

Reset ratio 105% typically -

Table 25. Loss of excitation LEXPDIS


X offset of Mho top point (–1000.00–1000.00)% ofZBase

± 2.0% of Ur/Ir

Diameter of Mho circle (0.00–3000.00)% of ZBase ± 2.0% of Ur/Ir

Timers (0.00–6000.00) s ± 0.5% ± 25 ms


ABB 49

Table 26. Out-of-step OOSPPAM

Function Range or value Accuracy Remark

VOLTAGE 0.1 – 2.0 UBase Better than ±1.5 % of truevalue or 1 % of rated,whichever is greater

Better than ±0.5 % at nominalvoltage

CURRENT 0.1 – 5.0 IBase Better than ±1.0 % of truevalue or 1 % of rated,whichever is greater

Better than ±0.5 % at nominalcurrent

X 0.1 – 2.0UBase, 0.1 –5.0 IBase

Better than ±3.0 % of truevalue or 3.0 % of Zbase,whichever is greater

Better than ±1 % at nominalcurrent and voltage

R 0.1 – 2.0UBase, 0.1 –5.0 IBase

Better than ±3.0 % of truevalue or 3.0 % of Zbase,whichever is greater


P 0.1 – 2.0UBase, 0.1 –5.0 IBase

Better than ±3.0 % of truevalue or ±3 % of rated S,whichever is greater


Q 0.1 – 2.0UBase, 0.1 –5.0 IBase

Better than ±3.0 % of truevalue or ±3 % of rated S,whichever is greater


ROTORANG Better than ±6 degrees Better than ±3 deg at nominalcurrent and voltage

SLIPFREQ 0.1 – 10 Hz Better than ±50 mHz Under steady-state conditionswith constant slip

UCOSPHI 0.1 – 2.0UBase, 0.1 –5.0 IBase

Better than ±3.0 % of truevalue or 3.0 % of UBase,whichever is greater

Table 27. Load enchroachment LEPDIS


Load encroachmentcriteria:Load resistance, forwardand reverseSafety load impedanceangle

(1.00–3000.00) Ω/phase(5-85) degrees

± 5.0% static accuracy± 2.0 degrees static angular accuracyConditions:Voltage range: (0.1-1.1) x Ur

Current range: (0.5-30) x IrAngle: at 0 degrees and 85 degrees

Reset ratio 105% typically -


50 ABB

Current protection

Table 28. Four step phase overcurrent protection OC4PTOC

Function Setting range Accuracy

Operate current (5-2500)% of lBase ± 1.0% of Ir at I ≤ Ir± 1.0% of I at I > Ir

Reset ratio > 95% -

Min. operating current (1-10000)% of lBase ± 1.0% of Ir at I ≤ Ir ±1.0%

of I at I > Ir

Independent time delay (0.000-60.000) s ± 0.5% ±25 ms

Minimum operate timefor inverse characteristics

(0.000-60.000) s ± 0.5% ±25ms

Inverse characteristics,see table 68, table 69 andtable 70

17 curve types See table 68, table 69 andtable 70

Operate time,nondirectional startfunction

20 ms typically at 0 to 2 x Iset -

Reset time, nondirectionalstart function


Operate time, directionalstart function


Reset time, directionalstart funciton


Critical impulse time 10 ms typically at 0 to 2 x Iset -

Impulse margin time 15 ms typically -


ABB 51

Table 29. Four step residual overcurrent protection EF4PTOC


Operate current (1-2500)% of lBase ± 1.0% of Ir at I £ Ir± 1.0% of I at I > Ir

Reset ratio > 95% -

Operate current fordirectional comparison

(1–100)% of lBase ± 1.0% of Ir

Min. operating current (1-10000)% of lBase ± 1.0% of Ir at I < Ir ±

1.0% of I at I < Ir

Minimum operate timefor inverse characteristics

(0.000-60.000) s ± 0.5% ± 25 ms

Timers (0.000-60.000) s ± 0.5% ±25 ms


17 curve types See table 68, table 69 andtable 70

Minimum polarizingvoltage

(1–100)% of UBase ± 0.5% of Ur

Minimum polarizingcurrent

(2-100)% of IBase ±1.0% of Ir

Real part of source Zused for currentpolarization

(0.50-1000.00) W/phase -

Imaginary part of sourceZ used for currentpolarization

(0.50–3000.00) W/phase -

Operate time, non-directional start function

30 ms typically at 0.5 to 2 x Iset -

Reset time, non-directional start function

30 ms typically at 2 to 0.5 x Iset -

Operate time, directionalstart function

30 ms typically at 0,5 to 2 x IN -

Reset time, directionalstart function

30 ms typically at 2 to 0,5 x IN -


52 ABB

Table 30. Sensitive directional residual overcurrent and power protection SDEPSDE


Operate level for 3I0·cosjdirectional residualovercurrent

(0.25-200.00)% of lBase At low setting:(2.5-10) mA(10-50) mA

± 1.0% of Ir at I £ Ir± 1.0% of I at I > Ir ±0.5 mA±1.0 mA

Operate level for 3I0·3U0

· cosj directional residualpower

(0.25-200.00)% of SBase At low setting:(0.25-5.00)% of SBase

± 1.0% of Sr at S £ Sr

± 1.0% of S at S > Sr

± 10% of set value

Operate level for 3I0 and

j residual overcurrent


± 1.0% of Ir at £ Ir± 1.0% of I at I > Ir ±0.5 mA±1.0 mA

Operate level for non-directional overcurrent

(1.00-400.00)% of lBase At low setting:(10-50) mA

± 1.0% of Ir at I £ Ir± 1.0% of I at I > Ir ± 1.0 mA

Operate level for non-directional residualovervoltage

(1.00-200.00)% of UBase ± 0.5% of Ur at U£Ur

± 0.5% of U at U > Ur

Residual release currentfor all directional modes


± 1.0% of Ir at I £ Ir± 1.0% of I at I > Ir ±0.5 mA± 1.0 mA

Residual release voltagefor all directional modes

(1.00 - 300.00)% of UBase ± 0.5% of Ur at U£Ur

± 0.5% of U at U > Ur

Reset ratio > 95% -

Timers (0.000-60.000) s ± 0.5% ±25 ms


17 curve types See table 68, table 69 andtable 70Class 5 + 150 ms

Relay characteristic angleRCA

(-179 to 180) degrees ± 2.0 degrees

Relay open angle ROA (0-90) degrees ± 2.0 degrees


ABB 53

Table 30. Sensitive directional residual overcurrent and power protection SDEPSDE,continued


Operate time, non-directional residual overcurrent


Reset time, non-directional residual overcurrent

90 ms typically at 1.2 to 0.5 x Iset -

Operate time, non-directional residualovervoltage

70 ms typically at 0.8 to 1.5 x Uset -

Reset time, non-directional residualovervoltage

120 ms typically at 1.2 to 0.8 x Uset -

Operate time, directionalresidual over current


Reset time, directionalresidual over current

170 ms typically at 2 to 0.5 x Iset -

Critical impulse time non-directional residual overcurrent

100 ms typically at 0 to 2 x Iset


--

Impulse margin time non-directional residual overcurrent

25 ms typically -


54 ABB

Table 31. Thermal overload protection, two time constants TRPTTR


Base current 1 and 2 (30–250)% of IBase ± 1.0% of Ir

Operate time:

2 2

2 2ln p

b

I It

I It

æ ö-ç ÷= ×ç ÷-è ø

EQUATION1356 V1 EN (Equation 1)

I = Imeasured

Ip = load current before

overload occurs

Time constant τ = (1–500)minutes

IEC 60255–8, class 5 + 200 ms

Alarm level 1 and 2 (50–99)% of heat contenttrip value

± 2.0% of heat content trip

Operate current (50–250)% of IBase ± 1.0% of Ir

Reset level temperature (10–95)% of heat contenttrip

± 2.0% of heat content trip

Table 32. Breaker failure protection CCRBRF


Operate phase current (5-200)% of lBase ± 1.0% of Ir at I £ Ir± 1.0% of I at I > Ir

Reset ratio, phase current > 95% -

Operate residual current (2-200)% of lBase ± 1.0% of Ir at I £ Ir± 1.0% of I at I > Ir

Reset ratio, residual current > 95% -

Phase current level forblocking of contact function

(5-200)% of lBase ± 1.0% of Ir at I £ Ir± 1.0% of I at I > Ir

Reset ratio > 95% -

Timers (0.000-60.000) s ± 0.5% ±10 ms

Operate time for currentdetection

35 ms typically -

Reset time for currentdetection

10 ms maximum -


ABB 55

Table 33. Pole discordance protection CCRPLD


Operate value, currentasymmetry level

(0-100) % ± 1.0% of Ir

Reset ratio >95% -

Time delay (0.000-60.000) s ± 0.5% ± 25 ms

Table 34. Directional over/underpower protection GOPPDOP, GUPPDUP


Power level (0.0–500.0)% of SBase ± 1.0% of Sr at S < Sr

± 1.0% of S at S > Sr1)

(1.0-2.0)% of SBase < ± 50% of set value 2)

(2.0-10)% of SBase < ± 20% of set value 3)

Characteristic angle (-180.0–180.0) degrees 2 degrees

Timers (0.010 - 6000.000) s ± 0.5% ± 25 ms

1) Accuracy valid for 50 Hz. At 60 Hz both accuracies are ±2.0%2) Accuracy valid for 50 Hz. At 60 Hz the accuracy is -50/+100%3) Accuracy valid for 50 Hz. At 60 Hz the accuracy is ±40%


56 ABB

Table 35. Accidental energizing protection for synchronous generator AEGGAPC


Operate value, overcurrent (2-900)% of IBase ± 1,0% of Ir at I<Ir± 1.0% of I at I>Ir

Reset ratio, overcurrent >95% -

Transient overreach,overcurrent function

<20% at τ = 100 ms -

Critical impulse time,overcurrent


Impulse margin time,overcurrent

15 ms typically -

Operate value, undervoltage (2-200)% of UBase ± 0.5% of Ur at U<Ur

± 0.5% of U at U>Ur

Critical impulse time,undervoltage

10 ms typically at 2 to 0 x Uset -

Impulse margin time,undervoltage

15 ms typically -

Operate value, overvoltage (2-200)% of UBase ± 0.5% of Ur at U<Ur

± 0.5% of U at U>Ur

Timers (0.000-60.000) s ± 0.5% ± 25 ms


ABB 57

Table 36. Negative sequence time overcurrent protection for machines NS2PTOC


Operate value, step 1 and 2,negative sequenceovercurrent

(3-500)% of IBase ± 1.0% of Ir at I < Ir± 1.0% of I at I > Ir

Reset ratio, step 1 and 2 >95% -

Operate time, start 30 ms typically at 0 to 2 x Iset


-

Reset time, start 40 ms typically at 2 to 0 x Iset -

Time characteristics Definite or Inverse -

Inverse time characteristic

step 1, 2

2I t K=

K=1.0-99.0 Class 5 + 40 ms

Reset time, inversecharacteristic step 1,

22I t K=

K=0.01-20.00 Class 10 + 40 ms

Maximum trip delay, step 1IDMT

(0.00-6000.00) s ± 0.5% ± 25 ms

Minimum trip delay, step 1IDMT

(0.000-60.000) s ± 0.5% ± 25 ms

Timers (0.00-6000.00) s ± 0.5% ± 25 ms


58 ABB

Table 37. Voltage-restrained time overcurrent protection VR2PVOC


Start overcurrent (2 - 5000)% of IBase ± 1.0% of Ir at I<Ir± 1.0% of I at I>Ir

Definite time delay (0.00 - 6000.00) s ± 0.5% ± 25 ms

Inverse characteristics, seetable 68, table 69 and table 70

17 curves type See table 68, table 69and table70

Operate time start overcurrent 30 ms typically at 0 to 2 x Iset


-

Reset time start overcurrent 40 ms typically at 2 to 0 x Iset -

Start undervoltage (2.0 - 100.0)% of UBase ± 0.5 % of Ur

Operate time startundervoltage

30 ms typically 2 to 0 x Uset -

Reset time start undervoltage 40 ms typically at 0 to 2 x Uset -

High voltage limit, voltagedependent operation

(30 - 100)% of UBase ± 1.0 % of Ur

Reset ratio, overcurrent > 95% -

Reset ratio, undervoltage < 105% -

Overcurrent:Critical impulse timeImpulse margin time


15 ms typically

-


ABB 59

Voltage protection

Table 38. Two step undervoltage protection UV2PTUV


Operate voltage, low andhigh step

(1–100)% of UBase ± 0.5% of Ur

Reset ratio <105% -

Inverse time characteristicsfor low and high step, seetable 72

- See table 72

Definite time delay, step 1 (0.00 - 6000.00) s ± 0.5% ± 25 ms

Definite time delays, step 2 (0.000-60.000) s ± 0.5% ±25 ms

Minimum operate time,inverse characteristics

(0.000–60.000) s ± 0.5% ± 25 ms

Operate time, start function 30 ms typically at 2 to 0.5 x Uset -

Reset time, start function 40 ms typically at 0.5 to 2 x Uset -

Critical impulse time 10 ms typically at 2 to 0 x Uset -


Table 39. Two step overvoltage protection OV2PTOV


Operate voltage, low andhigh step

(1-200)% of UBase ± 0.5% of Ur at U < Ur

± 0.5% of U at U > Ur

Reset ratio >95% -


- See table 71

Definite time delay, step 1 (0.00 - 6000.00) s ± 0.5% ± 25 ms

Definite time delays, step 2 (0.000-60.000) s ± 0.5% ± 25 ms

Minimum operate time,Inverse characteristics

(0.000-60.000) s ± 0.5% ± 25 ms

Operate time, start function 30 ms typically at 0 to 2 x Uset -

Reset time, start function 40 ms typically at 2 to 0 x Uset -




60 ABB

Table 40. Two step residual overvoltage protection ROV2PTOV


Operate voltage, step 1 (1-200)% of UBase ± 0.5% of Ur at U < Ur

± 0.5% of U at U > Ur

Operate voltage, step 2 (1–100)% of UBase ± 0.5% of Ur at U < Ur

± 0.5% of U at U > Ur

Reset ratio >95% -


- See table 73

Definite time setting, step 1 (0.00–6000.00) s ± 0.5% ± 25 ms

Definite time setting, step 2 (0.000–60.000) s ± 0.5% ± 25 ms

Minimum operate time forstep 1 inverse characteristic

(0.000-60.000) s ± 0.5% ± 25 ms

Operate time, start function 30 ms typically at 0 to 2 x Uset -

Reset time, start function 40 ms typically at 2 to 0 x Uset -



Table 41. Overexcitation protection OEXPVPH


Operate value, start (100–180)% of (UBase/frated) ± 0.5% of U

Operate value, alarm (50–120)% of start level ± 0.5% of Ur at U ≤ Ur

± 0.5% of U at U > Ur

Operate value, high level (100–200)% of (UBase/frated) ± 0.5% of U

Curve type IEEE

2

(0.18 ):

( 1)k

IEEE tM

×=

-

EQUATION1319 V1 EN (Equation 2)

where M = (E/f)/(Ur/fr)

Class 5 + 40 ms

Minimum time delay forinverse function

(0.000–60.000) s ± 0.5% ± 25 ms

Alarm time delay (0.000–60.000) s ± 0.5% ± 25 ms


ABB 61

Table 42. 100% Stator E/F 3rd harmonic STEFPHIZ


Fundamental frequencylevel UN (95% Stator EF)

(1.0–50.0)% of UBase ± 0.5% of Ur

Third harmonicdifferential level

(0.5–10.0)% of UBase ± 5.0% of Ur

Third harmonicdifferential block level

(0.1–10.0)% of UBase ± 5.0% of Ur

Timers (0.020–60.000) s ± 0.5% ± 25 ms

Filter characteristic:FundamentalThird harmonic

Reject third harmonic by1–40Reject fundamentalharmonic by 1–40

-

Frequency protection

Table 43. Under frequency protection SAPTUF


Operate value, start function (35.00-75.00) Hz ± 2.0 mHz

Operate value, restore frequency (45 - 65) Hz ± 2.0 mHz

Operate time, start function At 50 Hz: 200 ms typically at fset

+0.5 Hz to fset -0.5 Hz

At 60 Hz: 170 ms typically at fset

+0.5 Hz to fset -0.5 Hz

-

Reset time, start function At 50 Hz: 60 ms typically at fset -0.5

Hz to fset +0.5 Hz

At 60 Hz: 50 ms typically at fset -0.5

Hz to fset +0.5 Hz

-

Operate time delay (0.000-60.000)s <250 ms

Restore time delay (0.000-60.000)s <150 ms


62 ABB

Table 44. Overfrequency protection SAPTOF


Operate value, start function (35.00-75.00) Hz ± 2.0 mHz atsymmetricalthree-phasevoltage

Operate time, start function At 50 Hz: 200 ms typically at fset

-0.5 Hz to fset +0.5 Hz

At 60 Hz: 170 ms at fset -0.5 Hz to

fset +0.5 Hz

-

Reset time, start function At 50 and 60 Hz: 55 ms typically atfset +0.5 Hz to fset-0.5 Hz

-

Timer (0.000-60.000)s <250 ms

Table 45. Rate-of-change frequency protection SAPFRC


Operate value, start function (-10.00-10.00) Hz/s ± 10.0 mHz/s

Operate value, restore enablefrequency

(45.00 - 65.00) Hz ± 2.0 mHz

Timers (0.000 - 60.000) s <130 ms

Operate time, start function At 50 Hz: 100 ms typicallyAt 60 Hz: 80 ms typically

-


ABB 63

Secondary system supervision

Table 46. Fuse failure supervision SDDRFUF


Operate voltage, zero sequence (1-100)% of UBase ± 1.0% of Ur

Operate current, zero sequence (1–100)% of IBase ± 1.0% of Ir

Operate voltage, negativesequence

(1–100)% of UBase ± 0.5% of Ur

Operate current, negativesequence

(1–100)% of IBase ± 1.0% of Ir

Operate voltage change level (1–100)% of UBase ± 5.0% of Ur

Operate current change level (1–100)% of IBase ± 5.0% of Ir

Operate phase voltage (1-100)% of UBase ± 0.5% of Ur

Operate phase current (1-100)% of IBase ± 1.0% of Ir

Operate phase dead line voltage (1-100)% of UBase ± 0.5% of Ur

Operate phase dead line current (1-100)% of IBase ± 1.0% of Ir

Table 47. Breaker close/trip circuit monitoring TCSSCBR


Operate time delay (0.020 - 300.000) s ± 0,5% ± 110 ms


64 ABB

Control

Table 48. Synchronizing, synchrocheck and energizing check SESRSYN


Phase shift, jline - jbus (-180 to 180) degrees -

Voltage ratio, Ubus/Uline 0.2 to 5.0 -

Frequency difference limit betweenbus and line

(0.003-1.000) Hz ± 2.0 mHz

Phase angle difference limitbetween bus and line

(5.0-90.0) degrees ± 2.0 degrees

Voltage difference limit betweenbus and line

± 0.5% of Ur

Time delay output for synchrocheck (0.000-60.000) s ± 0.5% ± 25 ms

Time delay for energizing check (0.000-60.000) s ± 0.5% ± 25 ms

Closing time for the circuit breaker (0.000-60.000) s ± 0.5% ± 25 ms

Logic

Table 49. Tripping logic SMPPTRC


Trip action 3-ph -

Timers (0.000-60.000) s ± 0.5% ± 10 ms


ABB 65

Table 50. Configurable logic blocks

Logic block Quantity with cycle time Range or value Accuracy

5 ms 20 ms 100 ms

AND 60 60 160 - -

OR 60 60 160 - -

XOR 10 10 20 - -

INVERTER 30 30 80 - -

SRMEMORY 10 10 20 - -

RSMEMORY 10 10 20 - -

GATE 10 10 20 - -

PULSETIMER 10 10 20 (0.000–90000.000) s ± 0.5% ± 25 ms

TIMERSET 10 10 20 (0.000–90000.000) s ± 0.5% ± 25 ms

LOOPDELAY 10 10 20

Monitoring

Table 51. Measurements CVMMXN


Voltage (0.1-1.5) ×Ur ± 0.5% of Ur at U£Ur

± 0.5% of U at U > Ur

Connected current (0.2-4.0) × Ir ± 0.5% of Ir at I £ Ir± 0.5% of I at I > Ir

Active power, P 0.1 x Ur Sr

1)

Reactive power, Q 0.1 x Ur Sr

1)

Apparent power, S 0.1 x Ur Sr

Apparent power, S Threephase settings

cos phi = 1 ± 0.5% of S at S > Sr


Power factor, cos (φ) 0.1 x Ur < U < 1.5 x Ur

0.2 x Ir< I < 4.0 x Ir

< 0.02 2)

1) Accuracy valid for 50 Hz. At 60 Hz both accuracies are ±2.0%2) Accuracy valid for 50 Hz. At 60 Hz the accuracy is <0.04.


66 ABB

Table 52. Event counter CNTGGIO


Counter value 0-10000 -

Max. count up speed 10 pulses/s -


ABB 67

Table 53. Disturbance report DRPRDRE


Current recording - ± 1,0% of Ir at I ≤ Ir± 1,0% of I at I > Ir

Voltage recording - ± 1,0% of Ur at U ≤

Ur

± 1,0% of U at U >Ur

Pre-fault time (0.05–3.00) s -

Post-fault time (0.1–10.0) s -

Limit time (0.5–8.0) s -

Maximum number of recordings 100, first in - first out -

Time tagging resolution 1 ms See timesynchronizationtechnical data

Maximum number of analog inputs 30 + 10 (external +internally derived)

-

Maximum number of binary inputs 96 -

Maximum number of phasors in the TripValue recorder per recording

30 -

Maximum number of indications in adisturbance report

96 -

Maximum number of events in the Eventrecording per recording

150 -

Maximum number of events in the Eventlist

1000, first in - first out -

Maximum total recording time (3.4 srecording time and maximum number ofchannels, typical value)

340 seconds (100recordings) at 50 Hz, 280seconds (80 recordings)at 60 Hz

-

Sampling rate 1 kHz at 50 Hz1.2 kHz at 60 Hz

-

Recording bandwidth (5-300) Hz -


68 ABB

Table 54. Event list DRPRDRE

Function Value

Buffer capacity Maximum number of events inthe list

1000

Resolution 1 ms

Accuracy Depending on timesynchronizing

Table 55. Indications DRPRDRE

Function Value

Buffer capacity Maximum number of indications presentedfor single disturbance

96

Maximum number of recorded disturbances 100

Table 56. Event recorder DRPRDRE

Function Value

Buffer capacity Maximum number of events in disturbance report 150

Maximum number of disturbance reports 100

Resolution 1 ms

Accuracy Depending ontimesynchronizing

Table 57. Trip value recorder DRPRDRE

Function Value

Buffer capacity

Maximum number of analog inputs 30



ABB 69

Table 58. Disturbance recorder DRPRDRE

Function Value

Buffer capacity Maximum number of analog inputs 40

Maximum number of binary inputs 96


Maximum total recording time (3.4 s recording time andmaximum number of channels, typical value)

340 seconds (100 recordings)at 50 Hz280 seconds (80 recordings) at60 Hz

Table 59. Station battery supervision SPVNZBAT


Lower limit for the batteryterminal voltage

(60-140) % of Ubat ± 1.0% of set battery voltage

Reset ratio, lower limit <105 % -

Upper limit for the batteryterminal voltage

(60-140) % of Ubat ± 1.0% of set battery voltage

Reset ratio, upper limit >95 % -

Timers (0.000-60.000) s ± 0.5% ± 110 ms

Table 60. Insulation gas monitoring function SSIMG


Pressure alarm 0.00-25.00 -

Pressure lockout 0.00-25.00 -

Temperature alarm -40.00-200.00 -

Temperature lockout -40.00-200.00 -

Timers (0.000-60.000) s ± 0.5% ± 110 ms

Table 61. Insulation liquid monitoring function SSIML


Alarm, oil level 0.00-25.00 -

Oil level lockout 0.00-25.00 -

Temperature alarm -40.00-200.00 -

Temperature lockout -40.00-200.00 -

Timers (0.000-60.000) s ± 0.5% ± 110 ms


70 ABB

Table 62. Circuit breaker condition monitoring SSCBR


Alarm levels for open andclose travel time

(0-200) ms ± 0.5% ± 25 ms

Alarm levels for number ofoperations

(0 - 9999) -

Setting of alarm for springcharging time

(0.00-60.00) s ± 0.5% ± 25 ms

Time delay for gas pressurealarm

(0.00-60.00) s ± 0.5% ± 25 ms

Time delay for gas pressurelockout

(0.00-60.00) s ± 0.5% ± 25 ms

Metering

Table 63. Pulse counter PCGGIO

Function Setting range Accuracy

Cycle time for report ofcounter value

(1–3600) s -

Table 64. Function for energy calculation and demand handling ETPMMTR


Energy metering MWh Export/Import,MVArh Export/Import

Input from MMXU. No extra errorat steady load

Hardware

IED

Table 65. Degree of protection of flush-mounted IED

Description Value

Front side IP 40

Rear side, connection terminals IP 20

Table 66. Degree of protection of the LHMI

Description Value

Front and side IP 42


ABB 71

Dimensions

Table 67. Dimensions

Description Value

Width 220 mm

Height 265.9 mm (6U)

Depth 249.5 mm

Weight box <10 kg (6U)

Weight LHMI 1.3 kg (6U)

Inverse time characteristics

Table 68. ANSI Inverse time characteristics


Operating characteristic:

( )1= + ×

-

æ öç ÷ç ÷è ø

P

At B k

I

EQUATION1249-SMALL V1 EN

I = Imeasured/Iset

k = (0.05-999) in steps of 0.01unless otherwise stated

-

ANSI Extremely Inverse A=28.2, B=0.1217, P=2.0 ANSI/IEEE C37.112,class 5 + 40 ms

ANSI Very inverse A=19.61, B=0.491, P=2.0

ANSI Normal Inverse A=0.0086, B=0.0185, P=0.02, tr=0.46

ANSI Moderately Inverse A=0.0515, B=0.1140, P=0.02

ANSI Long Time ExtremelyInverse

A=64.07, B=0.250, P=2.0

ANSI Long Time Very Inverse A=28.55, B=0.712, P=2.0

ANSI Long Time Inverse k=(0.05-999) in steps of 0.01A=0.086, B=0.185, P=0.02


72 ABB

Table 69. IEC Inverse time characteristics


Operating characteristic:

( )1= ×

-

æ öç ÷ç ÷è ø

P

At k

I


I = Imeasured/Iset

k = (0.05-999) in steps of 0.01 -

IEC Normal Inverse A=0.14, P=0.02 IEC 60255-151,class 5 + 40 ms

IEC Very inverse A=13.5, P=1.0

IEC Inverse A=0.14, P=0.02

IEC Extremely inverse A=80.0, P=2.0

IEC Short time inverse A=0.05, P=0.04

IEC Long time inverse A=120, P=1.0

Table 70. RI and RD type inverse time characteristics


RI type inverse characteristic

1

0.2360.339

= ×

-

t k

I


I = Imeasured/Iset

k = (0.05-999) in steps of 0.01 IEC 60255-151,class 5 + 40 ms

RD type logarithmic inversecharacteristic

5.8 1.35= - ×æ öç ÷è ø

tI

Ink


I = Imeasured/Iset

k = (0.05-999) in steps of 0.01 IEC 60255-151,class 5 + 40 ms


ABB 73

Table 71. Inverse time characteristics for overvoltage protection


Type A curve:

=- >

>

æ öç ÷è ø

tk

U U

U


U> = Uset

U = Umeasured

k = (0.05-1.10) in steps of0.01 unless otherwise stated

Class 5 +40 ms

Type B curve:

2.0

480

32 0.5 0.035

=×

- >× - -

>

æ öç ÷è ø

tk

U U

U



Type C curve:

3.0

480

32 0.5 0.035

=×

- >× - -

>

æ öç ÷è ø

tk

U U

U




74 ABB

Table 72. Inverse time characteristics for undervoltage protection


Type A curve:

=< -

<

æ öç ÷è ø

kt

U U

U


U< = Uset

U = UVmeasured


Class 5 +40 ms

Type B curve:

2.0

4800.055

32 0.5

×= +

< -× -

<

æ öç ÷è ø

kt

U U

U


U< = Uset

U = Umeasured



ABB 75

Table 73. Inverse time characteristics for residual overvoltage protection


Type A curve:

=- >

>

æ öç ÷è ø

tk

U U

U


U> = Uset

U = Umeasured

k = (0.05-1.10) insteps of 0.01

Class 5 +40 ms

Type B curve:

2.0

480

32 0.5 0.035

=×

- >× - -

>

æ öç ÷è ø

tk

U U

U


k = (0.05-1.10) insteps of 0.01

Type C curve:

3.0

480

32 0.5 0.035

=×

- >× - -

>

æ öç ÷è ø

tk

U U

U


k = (0.05-1.10) insteps of 0.01


76 ABB

20. Ordering

GuidelinesCarefully read and follow the set of rules to ensure problem-free order management.Please refer to the available functions table for included application functions.

To obtain the complete ordering code, please combine code from the tables, as given in the example below.

Exemple code: REG650*1.1-B01X00-X00-B1A5-B-A-SA-AB1-RA3B1-AX-E. Using the code of each position #1-11specified as REG650*1-2 2-3-4 4-5-6-7 7-8 8-9 9 9-10 10 10 10-11

# 1 - 2 - 3 - 4 - 5 6 - 7 - 8 - 9 - 10 - 11

REG650* - - - - - - - - -

Posi

tion

SOFTWARE #1 Notes and Rules

Version number

Version no 1.1

Selection for position #1. 1.1

Configuration alternatives #2 Notes and Rules

Generator protection, IEC B01

Generator-Transformer protection, IEC B05

ACT configuration

ABB standard configuration X00

Selection for position #2. X00

Software options #3 Notes and Rules

No option X00

Selection for postition #3 X00

First HMI language #4 Notes and Rules

English IEC B1

Selection for position #4.

Additional HMI language #4

No second HMI language X0

Chinese A5

Selection for position #4. B1

Casing #5 Notes and Rules

Rack casing, 6 U 1/2 x 19" B

Selection for position #5. B


ABB 77

Mounting details with IP40 of protection from the front #6 Notes and Rules

No mounting kit included X

Rack mounting kit for 6 U 1/2 x 19" A

Wall mounting kit for 6U 1/2 x 19" D

Flush mounting kit for 6U 1/2 x 19" E

Wall mounting bracket 6U 1/2 x 19" G


Connection type for Power supply, Input/outputand Communication modules

#7 Notes and Rules

Compression terminals S

Ringlug terminals R

Power supply

Slot position:

pPSM

100-240V AC, 110-250V DC, 9BO A

48-125V DC, 9BO B


Human machine interface #8 Notes and Rules

Local human machine interface, OL3000, IEC6U 1/2 x 19", Basic

A

Detached LHMI

No detached mounting of LHMI X0

Detached mounting of LHMI incl. Ethernet cable, 1m B1





Selection for position #8. A

Connection type for Analog modules #9 Notes and Rules

Compression terminals S

Ringlug terminals R

Analog system

Slot position: p2

Transformer module, 4I, 1/5A+1I, 0.1/0.5A+5U,100/220V

A3

Slot position: p4

Analog input module, 6I + 4U, 1/5A, 100/220V B1

Selection for position #9. A3 B1


78 ABB

Binary input/output module #10 Notes and Rules

Slot position (rear view) p5

p6

Available slots in 1/2 case

No board in slot X X AIM in p4

Binary input/output module 9 BI, 3 NO Trip, 5 NOSignal, 1 CO Signal

A p5 basic, p6 optional

Selection for position #10. A

Communication and processing module #11 Notes and Rules

Slot position (rear view)

pCO

M

14BI, IRIG-B, Ethernet, LC, ST B

Selection for position #11. B

Accessories

Rack mounting kit for 2 x 6U 1/2 x 19" Quantity: 1KHL400240R0001

External resistor unit

High impedance resistor unit 1-ph with resistor and voltagedependent resistor for 20-100V operating voltage

Quantity: RK795101-MA

High impedance resistor unit 1-ph with resistor and voltagedependent resistor for 100-400V operating voltage

Quantity: RK795101-CB

Configuration and monitoring tools

Front connection cable between LCD-HMI and PC Quantity: 1MRK 001 665-CA

LED Label special paper A4, 1 pc Quantity: 1MRK 002 038-CA

LED Label special paper Letter, 1 pc Quantity: 1MRK 002 038-DA

External interface units for Rotor earth fault protection

Injection unit for Rotor earth fault protection (RXTTE 4) Quantity: 1MRK 002 108-BA

Protective resistor on plate Quantity: RK795102-AD


ABB 79

Manuals

Note: One (1) IED Connect CD containing user documentation (Operation manual, Technical manual,Installation manual, Commissioning manual, Application manual, Communication protocol manual,DNP, Communication protocol manual, IEC61850, Communication protocol manual, IEC60870-5-103,Type test certificate, Engineering manual and Point list manual, DNP3, Connectivity packages and LEDlabel template is always included for each IED.

Rule: Specify additional quantity of IED Connect CD requested

User documentation Quantity: 1MRK 003 500-AA

Rule: Specify the number of printed manuals requested

Operation manual IEC Quantity: 1MRK 500 093-UEN

Technical manual IEC Quantity: 1MRK 502 034-UEN

Commissioning manual IEC Quantity: 1MRK 502 035-UEN

Application manual IEC Quantity: 1MRK 502 033-UEN

Communication protocol manual, DNP3 IEC Quantity: 1MRK 511 241-UEN

Communication protocol manual, IEC 61850 IEC Quantity: 1MRK 511 242-UEN

Communication protocol manual, IEC 60870-5-103 IEC Quantity: 1MRK 511 243-UEN

Engineering manual IEC Quantity: 1MRK 511 245-UEN

Installation manual IEC Quantity: 1MRK 514 014-UEN

Point list manual, DNP3 IEC Quantity: 1MRK 511 244-UEN

Reference information

For our reference and statistics we would be pleased to be provided with the following application data:

Country: End user:

Station name: Voltage level: kV


80 ABB

Related documents

Documents related to REG650 Identity number

Application manual 1MRK 502 033-UEN

Technical manual 1MRK 502 034-UEN

Commissioning manual 1MRK 502 035-UEN

Product Guide 1MRK 502 036-BEN

Type test certificate 1MRK 502 036-TEN

Rotor Earth Fault Protection with Injection Unit RXTTE4 and REG670 1MRG001910

650 series manuals Identity number

Communication protocol manual, DNP3 1MRK 511 241-UEN

Communication protocol manual, IEC 61850 1MRK 511 242-UEN

Communication protocol manual, IEC 60870-5-103 1MRK 511 243-UEN

Point list manual, DNP3 1MRK 511 244-UEN

Engineering manual 1MRK 511 245-UEN

Operation manual 1MRK 500 093-UEN

Installation manual 1MRK 514 014-UEN


ABB 81

Contact us

ABB ABSubstation Automation ProductsSE-721 59 Västerås, SwedenPhone +46 (0) 21 32 50 00Fax +46 (0) 21 14 69 18

www.abb.com/substationautomation

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