relion 670 series line differential protection …...disturbance recording and fault locator are...

Relion® 670 series

Line differential protection RED670Pre-configuredProduct Guide

Contents

1. Application...........................................................3

2. Available functions...............................................5

4. Functionality.........................................................9

5. Hardware description.........................................28

6. Connection diagrams.........................................30

7. Technical data....................................................38

8. Ordering.............................................................89

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 2010 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.

Line differential protection RED670 1MRK 505 188-BEN CPre-configuredProduct version: 1.1 Issued: June 2010

2 ABB

1. Application

RED670 is used for the protection, controland monitoring of overhead lines and cablesin all types of networks. The IED can be usedfrom distribution up to the highest voltagelevels. It is suitable for the protection ofheavily loaded lines and multi-terminal lineswhere the requirement for tripping is one-,two-, and/or three-phase. The IED is alsosuitable for protection of cable feeders togenerator block transformers.

The phase segregated current differentialprotection provides an excellent sensitivityfor high resistive faults and gives a securephase selection. The availability of sixstabilized current inputs per phase allows useon multi-breaker arrangements in threeterminal applications or up to five terminalapplications with single breakerarrangements. The communication betweenthe IEDs involved in the differential schemeis based on the IEEE C37.94 standard and canbe duplicated for important installationswhen required for redundancy reasons.Charging current compensation allows highsensitivity also on long overhead lines andcables. A full scheme distance protection isincluded to provide independent protectionin parallel with the differential scheme incase of a communication channel failure forthe differential scheme. The distanceprotection then provide protection for theentire line including the remote end back upcapability either in case of a communicationsfailure or via use of an independentcommunication channel to provide a fullyredundant scheme of protection (that is asecond main protection scheme). Eightchannels for intertrip and other binary signalsare available in the communication betweenthe IEDs.

The auto-reclose for single-, two- and/orthree phase reclosing includes prioritycircuits for multi-breaker arrangements. It co-operates with the synchronism checkfunction with high-speed or delayed reclosing.

High set instantaneous phase and earthovercurrent, four step directional or un-directional delayed phase and earthovercurrent, thermal overload and two stepunder- and overvoltage functions areexamples of the available functions allowingthe user to fulfill any application requirement.

Disturbance recording and fault locator areavailable to allow independent post-faultanalysis after primary disturbances. TheDisturbance recorder will also show remotestation currents, as received to this IED, timecompensated with measure communicationtime.

Out of Step function is available to separatepower system sections close to electricalcentre at occurring out of step.

The advanced logic capability, where the userlogic is prepared with a graphical tool, allowsspecial applications such as automaticopening of disconnectors in multi-breakerarrangements, closing of breaker rings, loadtransfer logics etc. The graphicalconfiguration tool ensures simple and fasttesting and commissioning.

A loop testing function allows completetesting including remote end IED when localIED is set in test mode.

Serial data communication is via opticalconnections to ensure immunity againstdisturbances.

The wide application flexibility makes thisproduct an excellent choice for both newinstallations and the refurbishment of existinginstallations.

Four packages has been defined for followingapplications:

• Single-breaker (double or single bus)with three phase tripping (A31)

• Single-breaker (double or single bus)with single phase tripping (A32)

• Multi-breaker (one-and a half or ring)with three phase tripping (B31)

• Multi-breaker (one-and a half or ring)with single phase tripping (B32)

Line differential protection RED670 1MRK 505 188-BEN CPre-configuredProduct version: 1.1 Issued: June 2010Pre-configured Revision: C

ABB 3

The packages are configured and ready fordirect use. Optional functions are notconfigured but a maximum configurationwith all optional functions are available astemplate in the graphical configuration tool.Analogue and tripping IO has been pre-defined for basic use.

Add binary I/O as required for yourapplication at ordering. Other signals need tobe applied as required for each application.

For details on included basic functions referto section""

The applications are shown in figures 1 and 2for single resp. multi-breaker arrangement.

The application on a high ohmic earthedsystem is shown in figure 1.

Refer to the Application manual for pre-configured analog and binary IO.

SC/VCO->I

I->O

CLOSE

TRIP

BUS A

BUS B

87L

79 25

94/86

3Id/I>

TO REMOTE END:FIBRE OPTIC OR TO MUX

3I>

50BF

TRIP BUSBAR A or/and B

en05000302.vsd

3U>

59

3U<

27

3I>50/51

IEC05000302 V1 EN

Figure 1. The single breaker packages for single- and three phase tripping typical arrangementfor one protection sub-system is shown here. The differential function is moresensitive than any earthfault or directional earth fault function and these functionsare thus an option.


4 ABB

SC/VCO->I

I->O

CLOSE

TRIP

BUS A

87L

79 25

94/86

3I>50BF

TRIP BUSBAR&CB2

3I>50BF

S

SC/VCO->I

I->O CLO

SE

TRIP

25

94/86

79

3Id/I>

CB1

CB2

TRIPCB1/3

en05000303.vsdTO REMOTE END:FIBRE OPTIC OR TO MUX

3U>

59

3U<

27

3I>50/51

IEC05000303 V1 EN

Figure 2. The multi breaker packages for single- and three phase tripping typical arrangementfor one protection sub-system is shown here. The differential function is moresensitive than any earth fault or directional earth fault function and these functionsare thus an option. Auto-reclose, Synchrocheck and Breaker failure functions areincluded for each of the two breakers.


ABB 5

2. Available functions

ANSI Function description Single breaker, 3-phase tripping(A31)

Multi breaker, 3-phase tripping(B31)

Singel breaker, 1-phase tripping(A32)


Basic Option(Qty/optiondesign)




Differential protection(Only one alternative can be selected)

87 1 phase High impedancedifferential protection(HZPDIF)

- 3/A02 - 3/A02 - 3/A02 - 3/A02

87L Line differential protection, 3CT sets, 2-3 line ends (L3CPDIF)

1 - - - 1 - - -

87L Line differential protection, 6CT sets, 3-5 line ends (L6CPDIF)

- 1/A04 1 - - 1/A04 1 -

87LT Line differential protection 3CT sets, with in-zonetransformers, 2-3 line ends(LT3CPDIF)

- 1/A05 - - - 1/A05 - -

87LT Line differential protection 6CT sets, with in-zonetransformers, 3-5 line ends(LT6CPDIF)

- 1/A06 - 1/A06 - 1/A06 - 1/A06

Impedance protection

21 Distance protection zones,quadrilateral characteristic(ZMQPDIS/ZMQAPDIS)

- 3/B01 - 3/B01 - 1/B10,3/B01

- 3/B01

Directional impedancequadrilateral (ZDRDIR)

- 1/B01 - 1/B01 - 1/B01 - 1/B01

21 Distance measuring zone,quadrilateral characteristic forseries compensated lines(ZMCPDIS/ZMCAPDIS)

- 3/B06 - 3/B06 - 3/B06 - 3/B06

21 Directional impedancequadrilateral, including seriescompensation (ZDSRDIR)

- 1/B06 - 1/B06 - 1/B06 - 1/B06

21 Full-scheme distanceprotection, mho characteristic(ZMHPDIS)

- 3/B07 - 3/B07 - 3/B07 - 3/B07

Directional impedance elementfor mho characteristic(ZDMRDIR)

- 1/B07 - 1/B07 - 1/B07 - 1/B07

Additional distance protectiondirectional function for earthfaults (ZDARDIR)

- 1/B07 - 1/B07 - 1/B07 - 1/B07

Mho impedance supervisionlogic (ZSMGAPC)

- 1/B07 - 1/B07 - 1/B07 - 1/B07

78 Power swing detection(ZMRPSB)

- 1/B01/B06/B07

- 1/B01/B06/B07

- 1/B01/B06/B07

- 1/B01/B06/B07

Power swing logic (ZMRPSL) - 1/B03 - 1/B03 - 1/B03 - 1/B03

78 Pole slip protection (PSPPPAM) - 1/B21 - 1/B21 - 1/B21 - 1/B21

Automatic switch onto faultlogic, voltage and currentbased (ZCVPSOF)

- 1/B01/B06/B07

- 1/B01/B06/B07

- 1/B01/B06/B07

- 1/B01/B06/B07

Current protection

50 Instantaneous phaseovercurrent protection(PHPIOC)

1 - 1 - 1 - 1 -


6 ABB









51/67 Four step phase overcurrentprotection (OC4PTOC)

1 - 1 - 1 - 1 -

50N Instantaneous residualovercurrent protection(EFPIOC)

- 1/C04 - 1/C04 - 1/C04 - 1/C04

51N/67N

Four step residual overcurrentprotection (EF4PTOC)

- 1/C04 - 1/C04 - 1/C04 - 1/C04

67N Sensitive directinal residualovercurrent and powerprotection (SDEPSDE)

- 1/C16 - 1/C16 - 1/C16 - 1/C16

26 Thermal overload protection,one time constant (LPPTTR)

1 - 1 - 1 - 1 -

50BF Breaker failure protection(CCRBRF)

1 - 2 - 1 - 2 -

50STB Stub protection (STBPTOC) - 1/B01 1 1/B01 - 1/B01 1 1/B01

52PD Pole discordance protection(CCRPLD)

1 - 2 - 1 - 2 -

37 Directional underpowerprotection (GUPPDUP)

- 1/C17 - 1/C17 - 1/C17 - 1/C17

32 Directional overpowerprotection (GOPPDOP)

- 1/C17 - 1/C17 - 1/C17 - 1/C17

46 Broken conductor check(BRCPTOC)

1 - 1 - 1 - 1 -

Voltage protection

27 Two step undervoltageprotection (UV2PTUV)

1 - 1 - 1 - 1 -

59 Two step overvoltageprotection (OV2PTOV)

1 - 1 - 1 - 1 -

59N Two step residual overvoltageprotection (ROV2PTOV)

1 - 1 - 1 - 1 -

24 Overexcitation protection(OEXPVPH)

- 1/D03 - 1/D03 - 1/D03 - 1/D03

60 Voltage differential protection(VDCPTOV)

2 - 2 - 2 - 2 -

27 Loss of voltage check(LOVPTUV)

1 - 1 - 1 - 1 -

Frequency protection

81 Underfrequency protection(SAPTUF)

- 2/E02 - 2/E02 - 2/E02 - 2/E02

81 Overfrequency protection(SAPTOF)

- 2/E02 - 2/E02 - 2/E02 - 2/E02

81 Rate-of-change frequencyprotection (SAPFRC)

- 2/E02 - 2/E02 - 2/E02 - 2/E02

Multipurpose protection

General current and voltageprotection (CVGAPC)

- 4/F01 - 4/F01 - 4/F01 - 4/F01

Secondary system supervision

Current circuit supervision(CCSRDIF)

1 - 2 - 1 - 2 -

Fuse failure supervision(SDDRFUF)

3 - 3 - 3 - 3 -


ABB 7









Control

25 Synchrocheck, energizingcheck and synchronizing(SESRSYN)

1 - 2 - 1 - 2 -

79 Autorecloser (SMBRREC) 1 1/H04 2 2/H05 1 1/H04 2 2/H05

Apparatus control for singlebay, max 8 apparatuses (1CB)incl. interlocking (APC8)

- 1/H07 - - - 1/H07 - -

Apparatus control for singlebay, max 15 apparatuses(2CBs) incl. interlocking(APC15)

- - - 1/H08 - - - 1/H08

Logic rotating switch forfunction selection and LHMIpresentation (SLGGIO)

15 - 15 - 15 - 15 -

Selector mini switch (VSGGIO) 20 - 20 - 20 - 20 -

Scheme communication

85 Scheme communication logicfor distance or overcurrentprotection (ZCPSCH)

- 1/B01/B06/B07

- 1/B01/B06/B07

- 1/B01/B06/B07

- 1/B01/B06/B07

85 Phase segregated schemecommunication logic fordistance protection(ZC1PPSCH)

- - - - - 1/B05 - 1/B05

85 Current reversal and weak-endinfeed logic for distanceprotection (ZCRWPSCH)

- 1/B01/B06/B07

- 1/B01/B06/B07

- 1/B01/B06/B07

- 1/B01/B06/B07

Current reversal and weak-endinfeed logic for phasesegregated communication(ZC1WPSCH)

- - - - - 1/B05 - 1/B05

Local acceleration logic(ZCLCPLAL)

- 1/B01 - 1/B01 - 1/B01 - 1/B01

85 Scheme communication logicfor residual overcurrentprotection (ECPSCH)

- 1/C04 - 1/C04 - 1/C04 - 1/C04

85 Current reversal and weak-endinfeed logic for residualovercurrent protection(ECRWPSCH)

- 1/C04 - 1/C04 - 1/C04 - 1/C04

Logic

94 Tripping logic (SMPPTRC) 1 - 2 - 1 - 2 -

Trip matrix logic (TMAGGIO) 12 - 12 - 12 - 12 -

Monitoring

Measurements (CVMMXU) 6/10/6 - 6/10/6 - 6/10/6 - 6/10/6 -

Event counter (CNTGGIO) 5 - 5 - 5 - 5 -

Disturbance report (DRPRDRE) 1 - 1 - 1 - 1 -

IEC61850 genericcommunication I/O functions(SPGGIO)

16 - 16 - 16 - 16 -

Fault locator (LMBRFLO) 1 - 1 - 1 - 1 -


8 ABB









Measured value calculationand demand handling(RANGE_XP)

66 - 66 - 66 - 66 -

Metering

Pulse counter logic (PCGGIO) 16 - 16 - 16 - 16 -

Function for energy calculationand demand handling(ETPMMTR)

6 - 6 - 6 - 6 -

Station communication

IEC61850-8-1 Communication*)

1 - 1 - 1 - 1 -

LON communication protocol *) 1 - 1 - 1 - 1 -

SPA communication protocol *) 1 - 1 - 1 - 1 -

IEC60870-5-103communication protocol *)

1 - 1 - 1 - 1 -

DNP3.0 for TCP/IP andEiA-485 communicationprotocol

1 - 1 - 1 - 1 -

Single command, 16 signals 4 - 4 - 4 - 4 -

Multiple command and transmit 60/10 - 60/10 - 60/10 - 60/10 -

Remote communication

Binary signal transfer 6 - 6 - 6 - 6 -

*) In order to utilize it, an appropriate optional hardware port must be ordered.

4. Functionality

Differential protection

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 magnetizingcharacteristic. It utilizes an externalsummation of the phases and neutral currentand a series resistor and a voltage dependentresistor externally to the IED.

Line differential protection, 3 or 6 CT setsL3CPDIF, L6CPDIF

Line differential protection applies theKirchhoff's law and compares the currentsentering and leaving the protected multi-terminal circuit, consisting of overhead powerlines, power transformers and cables. It offersphase-segregated true current differentialprotection with high sensitivity and providesphase selection information for single-poletripping.

The three terminal version is used forconventional two-terminal lines with orwithout 1 1/2 circuit breaker arrangement inone end, as well as three terminal lines withsingle breaker arrangements at all terminals.


ABB 9

en05000039.vsd

RED670

RED670

Protected zone

Comm. Channel

IEC05000039 V1 EN

Figure 3. Example of application on a conventional two-terminal line

The six terminal versions are used forconventional two-terminal lines with 1 1/2circuit breaker arrangements in both ends, as

well as multi terminal lines with up to fiveterminals.

Protected zone

Comm. Channel

en05000040.vsd

RED670

RED670

RED670

Comm. ChannelComm. Channel

IEC05000040 V1 EN

Figure 4. Example of application on a three-terminal line with 1 1/2 breaker arrangements

The current differential algorithm provideshigh sensitivity for internal faults, at the sametime as it has excellent stability for externalfaults. Current samples from all CTs areexchanged between the IEDs in the line ends(master-master mode) or sent to one IED(master-slave mode) for evaluation.

A restrained dual biased slope evaluation ismade where the bias current is the highestphase current in any line end giving a securethrough fault stability even with heavilysaturated CTs. In addition to the restrainedevaluation, an unrestrained high differentialcurrent setting can be used for fast trippingof internal faults with very high currents.

A special feature with this function is thatapplications with small power transformers

(rated current less than 50 % of thedifferential current setting) connected as linetaps (that is, as "shunt" power transformers),without measurements of currents in the tap,can be handled. The normal load current ishere considered to be negligible, and specialmeasures need only to be taken in the eventof a short circuit on the LV side of thetransformer. In this application, the trippingof the differential protection can be timedelayed for low differential currents toachieve coordination with down stream overcurrent IEDs.

A line charging current compensationprovides increased sensitivity of Linedifferential protection.

Line differential protection 3 or 6 CT sets,with in-zone transformers LT3CPDIF,LT6CPDIF

Two two-winding power transformers, or onethree-winding power transformer, can be

included in the line differential protectionzone. Both two- and three-windingtransformers are correctly represented withvector group compensations made in the

algorithm. The function includes 2nd and 5th


10 ABB

harmonic restraint and zero-sequence currentelimination.

RED670

RED670

RED670

Protected zone

Comm. Channel

Comm. Channel

Comm. Channel

en05000042.vsdIEC05000042 V1 EN

Figure 5. Example of application on a three-terminal line with a power transformer in theprotection zone

Analog signal transfer for line differentialprotection (MDIF)

The line differential communication can bearranged as a master-master system or amaster-slave system alternatively. In theformer, current samples are exchangedbetween all terminals, and an evaluation ismade in each terminal. This means that a 64kbit/s communication channel is needed

between every IED included in the same linedifferential protection zone. In the latter,current samples are sent from all slave IEDsto one master IED where the evaluation ismade, and trip signals are sent to the remoteends when needed. In this system, a 64 kbit/scommunication channel is only neededbetween the master, and each one of theslave terminals.

Protected zone

Comm.Channels

RED670

RED670

RED670

RED670

RED670

en05000043.vsdIEC05000043 V1 EN

Figure 6. Five terminal line with master-master system


ABB 11

RED670

Protected zone

Comm.Channels

RED670

RED670

en05000044.vsd

RED670

RED670

IEC05000044 V1 EN

Figure 7. Five terminal line with master-slave system

Current samples from IEDs locatedgeographically apart from each other, mustbe time coordinated so that the currentdifferential algorithm can be executedcorrectly. In RED 670 it is possible to makethis coordination in two different ways. Theecho method of time synchronizing isnormally used whereas for applications

where transmit and receive times can differ,the optional built in GPS receivers shall beused.

The communication link is continuouslymonitored, and an automatic switchover to astandby link is possible after a preset time.


Distance measuring zone, quadrilateralcharacteristic ZMQPDIS, ZMQAPDIS

The line distance protection is athree zonefull scheme protection with three fault loopsfor phase-to-phase faults and three faultloops for phase-to-earth fault for each of theindependent zones. Individual settings foreach zone in resistive and reactive reachgives flexibility for use as back-up protectionfor transformer connected to overhead linesand cables of different types and lengths.

ZMQPDIS together with Phase selection withload encroachment FDPSPDIS hasfunctionality for load encroachment, whichincreases the possibility to detect highresistive faults on heavily loaded lines.

The independent measurement of impedancefor each fault loop together with a sensitiveand reliable built-in phase selection makesthe function suitable in applications withsingle-phase autoreclosing.

Built-in adaptive load compensationalgorithm prevents overreaching of zone 1 at

load exporting end at phase-to-earth faults onheavily loaded power lines.

The distance protection zones can operateindependently of each other in directional(forward or reverse) or non-directional mode.This makes them suitable, together withdifferent communication schemes, for theprotection of power lines and cables incomplex network configurations, such asparallel lines, multi-terminal lines, and so on.

Distance measuring zone, quadrilateralcharacteristic for series compensated linesZMCPDIS, ZMCAPDIS

The line distance protection is a three zonefull scheme protection with three fault loopsfor phase-to-phase faults and three faultloops for phase-to-earth fault for each of theindependent zones. Individual settings foreach zone resistive and reactive reach giveflexibility for use on overhead lines andcables of different types and lengths.

Quadrilateral characteristic is available.

ZMCPDIS function has functionality for loadencroachment which increases the possibility


12 ABB

to detect high resistive faults on heavilyloaded lines.

en05000034.vsd

R

X

Forwardoperation

Reverseoperation

IEC05000034 V1 EN

Figure 8. Typical quadrilateral distanceprotection zone with loadencroachment function activated

The independent measurement of impedancefor each fault loop together with a sensitiveand reliable built in phase selection makesthe function suitable in applications withsingle phase auto-reclosing.

Built-in adaptive load compensationalgorithm for the quadrilateral functionprevents overreaching of zone1 at loadexporting end at phase to earth-faults onheavily loaded power lines.

The distance protection zones can operate,independent of each other, in directional(forward or reverse) or non-directional mode.This makes them suitable, together withdifferent communication schemes, for theprotection of power lines and cables incomplex network configurations, such asparallel lines, multi-terminal lines.

Full-scheme distance measuring, Mhocharacteristic ZMHPDIS

The numerical mho line distance protection isathree zone full scheme protection for back-up detection of short circuit and earth faults.The three zones have fully independent

measuring and settings, which gives highflexibility for all types of lines.

The IED can be used up to the highestvoltage levels. It is suitable for the protectionof heavily loaded lines and multi-terminallines where the requirement for tripping isone-, two- and/or three-pole.

The independent measurement of impedancefor each fault loop together with a sensitiveand reliable built in phase selection makesthe function suitable in applications withsingle phase autoreclosing.

Built-in adaptive load compensationalgorithm prevents overreaching at phase-to-earth faults on heavily loaded power lines,see figure 9.

en07000117.vsd

jX

Operation area Operation area

R

Operation area

No operation area No operation area

IEC07000117 V1 EN

Figure 9. Load encroachment influence onthe offset mho characteristic

The distance protection zones can operate,independent of each other, in directional(forward or reverse) or non-directional mode(offset). This makes them suitable, togetherwith different communication schemes, forthe protection of power lines and cables incomplex network configurations, such asparallel lines, multi-terminal lines and so on.

The possibility to use the phase-to-earthquadrilateral impedance characteristictogether with the mho characteristic increasesthe possibility to overcome eventual lack of


ABB 13

sensitivity of the mho element due to theshaping of the curve at remote end faults.

The integrated control and monitoringfunctions offer effective solutions foroperating and monitoring all types oftransmission and sub-transmission lines.

Phase selection, quadrilateralcharacteristic with fixed angle FDPSPDIS

The operation of transmission networkstoday is in many cases close to the stabilitylimit. Due to environmental considerations,the rate of expansion and reinforcement ofthe power system is reduced, for example,difficulties to get permission to build newpower lines. The ability to accurately andreliably classify the different types of fault, sothat single pole tripping and autoreclosingcan be used plays an important role in thismatter. Phase selection, quadrilateralcharacteristic with fixed angle FDPSPDIS isdesigned to accurately select the proper faultloop in the distance function dependent onthe fault type.

The heavy load transfer that is common inmany transmission networks may make faultresistance coverage difficult to achieve.Therefore, FDPSPDIS has a built-in algorithmfor load encroachment, which gives thepossibility to enlarge the resistive setting ofboth the phase selection and the measuringzones without interfering with the load.

The extensive output signals from the phaseselection gives also important informationabout faulty phase(s), which can be used forfault analysis.

Directional impedance element for Mhocharacteristic ZDMRDIR

The phase-to-earth impedance elements canbe optionally supervised by a phaseunselective directional function (phaseunselective, because it is based onsymmetrical components).

Faulty phase identification with loadencroachment FMPSPDIS

The operation of transmission networkstoday is in many cases close to the stabilitylimit. Due to environmental considerationsthe rate of expansion and reinforcement ofthe power system is reduced, for exampledifficulties to get permission to build newpower lines. The ability to accurate andreliable classifying the different types of faultso that single phase tripping andautoreclosing can be used plays an importantroll in this matter.

The phase selection function is design toaccurate select the proper fault loop in thedistance function dependent on the fault type.

The heavy load transfer that is common inmany transmission networks may in somecases interfere with the distance protectionzone reach and cause unwanted operation.Therefore the function has a built inalgorithm for load encroachment, which givesthe possibility to enlarge the resistive settingof the measuring zones without interferingwith the load.

The output signals from the phase selectionfunction produce important informationabout faulty phase(s), which can be used forfault analysis as well.

Power swing detection ZMRPSB

Power swings may occur after disconnectionof heavy loads or trip of big generation plants.

Power swing detection function (ZMRPSB) isused to detect power swings and initiateblock of selected distance protection zones.Occurrence of earth-fault currents during apower swing can block ZMRPSB function toallow fault clearance.

Power swing logic ZMRPSL

Additional logic is available to secure trippingfor faults during power swings and preventtripping at power swings started by a fault inthe network.


14 ABB

Pole slip protection PSPPPAM

Sudden events in an electrical power systemsuch as large changes in load, faultoccurrence or fault clearance, can causepower oscillations referred to as powerswings. In a non-recoverable situation, thepower swings become so severe that thesynchronism is lost, a condition referred to aspole slipping. The main purpose of the poleslip protection (PSPPPAM) is to detect,evaluate, and take the required action forpole slipping occurrences in the powersystem. The electrical system parts swingingto each other can be separated with the line/sclosest to the centre of the power swingallowing the two systems to be stable asseparated islands.

Automatic switch onto fault logic, voltageand current based ZCVPSOF

Automatic switch onto fault logic (ZCVPSOF)is a function that gives an instantaneous tripat closing of breaker onto a fault. A dead linedetection check is provided to activate thefunction when the line is dead.

Current protection

Instantaneous phase overcurrentprotection PHPIOC

The instantaneous three phase overcurrentfunction has a low transient overreach andshort tripping time to allow use as a high setshort-circuit protection function.

Four step phase overcurrent protectionOC4PTOC

The four step phase overcurrent protectionfunction OC4PTOC has an inverse or definitetime delay independent for each stepseparately.

All IEC and ANSI time delayed characteristicsare available together with an optional userdefined time characteristic.

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

A 2nd harmonic blocking can be setindividually for each step.

Instantaneous residual overcurrentprotection EFPIOC

The Instantaneous residual overcurrentprotection EFPIOC has a low transientoverreach and short tripping times to allowthe use for instantaneous earth-faultprotection, with the reach limited to less thantypical eighty percent of the line at minimumsource impedance. EFPIOC can be configuredto measure the residual current from the three-phase current inputs or the current from aseparate current input. EFPIOC can beblocked by activating the input BLOCK.

Four step residual overcurrent protectionEF4PTOC

The four step residual overcurrent protectionEF4PTOC has an inverse or definite timedelay independent for each step separately.

All IEC and ANSI time delayed characteristicsare available together with an optional userdefined characteristic.

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.

EF4PTOC can be used as main protection forphase-to-earth faults.

EF4PTOC can also be used to provide asystem back-up for example, in the case ofthe primary protection being out of servicedue to communication or voltage transformercircuit failure.

Directional operation can be combinedtogether with corresponding communicationlogic in permissive or blocking teleprotectionscheme. Current reversal and weak-endinfeed functionality are available as well.

EF4PTOC can be configured to measure theresidual current from the three-phase current


ABB 15

inputs or the current from a separate currentinput.

Sensitive directional residual overcurrentand power protection SDEPSDE

In isolated networks or in networks withhigh impedance earthing, the earth faultcurrent is significantly smaller than the shortcircuit 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, foroperating quantity with maintained shortcircuit capacity. There is also available onenondirectional 3I0 step and one 3U0overvoltage tripping step.

Thermal overload protection, one timeconstant LPTTR

The increasing utilizing of the power systemcloser to the thermal limits has generated aneed of a thermal overload protection alsofor power lines.

A thermal overload will often not be detectedby other protection functions and theintroduction of the thermal overloadprotection can allow the protected circuit tooperate closer to the thermal limits.

The three-phase current measuring protection

has an I2t characteristic with settable timeconstant and a thermal memory.

An alarm level gives early warning to allowoperators to take action well before the lineis tripped.

Breaker failure protection CCRBRF

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

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

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

CCRBRF can be single- or three-phaseinitiated to allow use with single phasetripping applications. For the three-phaseversion of CCRBRF the current criteria can beset to operate only if two out of four forexample, two phases or one phase plus theresidual current start. This gives a highersecurity to the back-up trip command.

CCRBRF function can be programmed to givea single- or three-phase re-trip of the ownbreaker to avoid unnecessary tripping ofsurrounding breakers at an incorrectinitiation due to mistakes during testing.

Stub protection STBPTOC

When a power line is taken out of service formaintenance and the line disconnector isopened in multi-breaker arrangements thevoltage transformers will mostly be outsideon the disconnected part. The primary linedistance protection will thus not be able tooperate and must be blocked.

The stub protection STBPTOC covers thezone between the current transformers andthe open disconnector. The three-phaseinstantaneous overcurrent function isreleased from a normally open, NO (b)auxiliary contact on the line disconnector.

Pole discordance protection CCRPLD

Single pole operated circuit breakers can dueto electrical or mechanical failures end upwith the different poles in different positions(close-open). This can cause negative andzero sequence currents which gives thermalstress on 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 breaker should betripped to clear the unsymmetrical loadsituation.

The Polediscordance protection functionCCRPLD operates based on information from


16 ABB

auxiliary contacts of the circuit breaker forthe three phases with additional criteria fromunsymmetrical phase current when required.

Directional over/underpower protectionGOPPDOP/GUPPDUP

The directional over-/under-power protection(GOPPDOP/GUPPDUP) can be usedwherever a high/low active, reactive orapparent power protection or alarming isrequired. The functions can alternatively beused to check the direction of active orreactive power flow in the power system.There are number of applications where suchfunctionality is needed. Some of them are:

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

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

Broken conductor check BRCPTOC

The main purpose of the function Brokenconductor check (BRCPTOC) is the detectionof broken conductors on protected powerlines and cables (series faults). Detection canbe used to give alarm only or trip the linebreaker.

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, each withinverse or definite time delay.

Two step overvoltage protection OV2PTOV

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

Two step overvoltage protection OV2PTOVcan be used as open line end detector,normally then combined with directionalreactive over-power function or as systemvoltage supervision, normally then givingalarm only or switching in reactors or switchout capacitor banks to control the voltage.

OV2PTOV has two voltage steps, each ofthem with inverse or definite time delayed.

OV2PTOV has an extremely high reset ratioto allow setting close to system service voltage.

Two step residual overvoltage protectionROV2PTOV

Residual voltages may occur in the powersystem during earth faults.

Two step residual overvoltage protectionROV2PTOV calculates the residual voltagefrom the three-phase voltage inputtransformers or from a single-phase voltageinput transformer fed from an open delta orneutral point voltage transformer.

ROV2PTOV has two voltage steps, each withinverse or definite time delayed.

Overexcitation protection OEXPVPH

When the laminated core of a powertransformer or generator is subjected to amagnetic 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. Overexcitationprotection OEXPVPH has settable inverseoperating curve and independent alarm stage.

Voltage differential protection VDCPTOV

A voltage differential monitoring function isavailable. It compares the voltages from twothree phase sets of voltage transformers andhas one sensitive alarm step and one tripstep. It can be used to supervise the voltagefrom two fuse groups or two different voltagetransformers fuses as a fuse/MCB supervisionfunction.


ABB 17

Loss of voltage check LOVPTUV

Loss of voltage check (LOVPTUV) is suitablefor use in networks with an automatic systemrestoration function. LOVPTUV issues a three-pole trip command to the circuit breaker, ifall three phase voltages fall below the setvalue for a time longer than the set time andthe circuit breaker remains closed.


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 under voltageblocking.

The operation may be based on single-phase,phase-to-phase or positive-sequence voltagemeasurement.

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. The operation is based on single-phase, phase-to-phase or positive-sequencevoltage measurement.

Rate-of-change frequency protectionSAPFRC

Rate-of-change frequency protection function(SAPFRC) gives an early indication of a maindisturbance in the system. SAPFRC can be

used for generation shedding, load shedding,remedial action schemes. SAPFRC candiscriminate between positive or negativechange of frequency.

SAPFRC is provided with an undervoltageblocking. The operation may be based onsingle-phase, phase-to-phase or positive-sequence voltage measurement.


General current and voltage protectionCVGAPC

The General current and voltage protection(CVGAPC) can be utilized as a negativesequence current protection detectingunsymmetrical conditions such as open phaseor unsymmetrical faults.

CVGAPC can also be used to improve phaseselection for high resistive earth faults,outside the distance protection reach, for thetransmission line. Three functions are used,which measures the neutral current and eachof the three phase voltages. This will give anindependence from load currents and thisphase selection will be used in conjunctionwith the detection of the earth fault from thedirectional earth fault protection function.


Current circuit supervision CCSRDIF

Open or short circuited current transformercores can cause unwanted operation of manyprotection functions such as differential,earth-fault current and negative-sequencecurrent functions.

It must be remembered that a blocking ofprotection functions at an occurrence of openCT circuit will mean that the situation willremain and extremely high voltages willstress the secondary circuit.

Current circuit supervision (CCSRDIF)compares the residual current from a threephase set of current transformer cores withthe neutral point current on a separate inputtaken from another set of cores on thecurrent transformer.


18 ABB

A detection of a difference indicates a fault inthe circuit and is used as alarm or to blockprotection functions expected to giveunwanted tripping.

Fuse failure supervision (RFUF)

Failures in the secondary circuits of thevoltage transformer can cause unwantedoperation of distance protection,undervoltage protection, neutral point voltageprotection, energizing function (synchronismcheck) etc. The fuse failure supervisionfunction prevents such unwanted operations.

There are three methods to detect fuse failures.

The method based on detection of zerosequence voltage without any zero sequencecurrent. This is a useful principle in a directlyearthed system and can detect one or twophase fuse failures.

The method based on detection of negativesequence voltage without any negativesequence current. This is a useful principle ina non-directly earthed system and can detectone or two phase fuse failures.

The method based on detection of du/dt-di/dt where a change of the voltage is comparedto a change in the current. Only voltagechanges means a voltage transformer fault.This principle can detect one, two or threephase fuse failures.

Control

Synchronizing, synchrocheck andenergizing check SESRSYN

The Synchronizing function allows closing ofasynchronous networks at the correctmoment including the breaker closing time.The systems can thus be reconnected after anautoreclose or manual closing, whichimproves the network stability.

Synchrocheck, energizing check (SESRSYN)function checks that the voltages on bothsides of the circuit breaker are insynchronism, or with at least one side deadto ensure that closing can be done safely.

SESRSYN function includes a built-in voltageselection scheme for double bus and 1½breaker or ring busbar 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.

Autorecloser SMBRREC

The autorecloser (SMBRREC) functionprovides high-speed and/or delayed auto-reclosing for single or multi-breakerapplications.

Up to five reclosing attempts can beprogrammed. The first attempt can be single-,two and/or three phase for single phase ormulti-phase faults respectively.

Multiple autoreclosing functions are providedfor multi-breaker arrangements. A prioritycircuit allows one circuit breaker to close firstand the second will only close if the faultproved to be transient.

Each autoreclosing function can beconfigured to co-operate with a synchrocheckfunction.

Interlocking

The interlocking function blocks thepossibility to operate primary switchingdevices, for instance when a disconnector isunder load, in order to prevent materialdamage and/or accidental human injury.

Each apparatus control function hasinterlocking modules included for differentswitchyard arrangements, where eachfunction handles interlocking of one bay. Theinterlocking function is distributed to eachIED and is not dependent on any centralfunction. For the station-wide interlocking,


ABB 19

the IEDs communicate via the system-wideinterbay bus (IEC 61850-8-1) or by using hardwired binary inputs/outputs. The interlockingconditions depend on the circuitconfiguration and apparatus position status atany given time.

For easy and safe implementation of theinterlocking function, the IED is deliveredwith standardized and tested softwareinterlocking modules containing logic for theinterlocking conditions. The interlockingconditions can be altered, to meet thecustomer’s specific requirements, by addingconfigurable logic by means of the graphicalconfiguration tool.

Logic rotating switch for functionselection and LHMI presentation SLGGIO

The logic rotating switch for functionselection and LHMI presentation function(SLGGIO) (or the selector switch functionblock) is used to get a selector switchfunctionality similar with the one provided bya hardware selector switch. Hardwareselector switches are used extensively byutilities, in order to have different functionsoperating on pre-set values. Hardwareswitches are however sources formaintenance issues, lower system reliabilityand extended purchase portfolio. The virtualselector switches eliminate all these problems.

Selector mini switch VSGGIO

Selector mini switch (VSGGIO) functionblock is a multipurpose function used in theconfiguration tool in PCM600 for a variety ofapplications, as a general purpose switch.

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

Single point generic control 8 signalsSPC8GGIO

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 complicated function blocks that

have the capability to receive commands (forexample, SCSWI). In this way, simplecommands can be sent directly to the IEDoutputs, without confirmation. Confirmation(status) of the result of the commands issupposed to be achieved by other means,such as binary inputs and SPGGIO functionblocks.


Scheme communication logic for distanceor overcurrent protection ZCPSCH

To achieve instantaneous fault clearance forall line faults, a scheme communication logicis provided. All types of communicationschemes for example, permissiveunderreaching, permissive overreaching,blocking, unblocking, intertrip are available.

The built-in communication module (LDCM)can be used for scheme communicationsignaling when included.

Phase segregated scheme communicationlogic for distance protection ZC1PPSCH

Communication between line ends is used toachieve fault clearance for all faults on apower line. All possible types ofcommunication schemes for example,permissive underreach, permissive overreachand blocking schemes are available. Tomanage problems with simultaneous faultson parallel power lines phase segregatedcommunication is needed. This will thenreplace the standard Scheme communicationlogic for distance or Overcurrent protection(ZCPSCH) on important lines where threecommunication channels (in each subsystem)are available for the distance protectioncommunication.

The main purpose of the Phase segregatedscheme communication logic for distanceprotection (ZC1PPSCH) function is tosupplement the distance protection functionsuch that:

• fast clearance of faults is also achieved atthe line end for which the faults are on


20 ABB

the part of the line not covered by itsunderreaching zone.

• correct phase selection can bemaintained to support single-poletripping for faults occurring anywhere onthe entire length of a double circuit line.

To accomplish this, three separatecommunication channels, that is, one perphase, each capable of transmitting a signalin each direction is required.

ZC1PPSCH can be completed with thecurrent reversal and WEI logic for phasesegregated communication, when foundnecessary in Blocking and Permissiveoverreaching schemes.

Current reversal and weak-end infeed logicfor distance protection ZCRWPSCH

The current reversal function is used toprevent unwanted operations due to currentreversal when using permissive overreachprotection schemes in application withparallel lines when the overreach from thetwo ends overlap on the parallel line.

The weak-end infeed logic is used in caseswhere the apparent power behind theprotection can be too low to activate thedistance protection function. When activated,received carrier signal together with localunder voltage criteria and no reverse zoneoperation gives an instantaneous trip. Thereceived signal is also echoed back toaccelerate the sending end.

Three phase or phase segregated schemelogic is available.

Current reversal and weak-end infeed logicfor phase segregated communicationZC1WPSCH

Current reversal and weak-end infeed logicfor phase segregated communication(ZC1WPSCH) function is used to preventunwanted operations due to current reversalwhen using permissive overreach protectionschemes in application with parallel lineswhen the overreach from the two endsoverlaps on the parallel line.

The weak-end infeed logic is used in caseswhere the apparent power behind theprotection can be too low to activate thedistance protection function. When activated,received carrier signal together with localunder voltage criteria and no reverse zoneoperation gives an instantaneous trip. Thereceived signal is also echoed back toaccelerate the sending end.

Local acceleration logic ZCLCPLAL

To achieve fast clearing of faults on thewhole line, when no communication channelis available, local acceleration logic(ZCLCPLAL) can be used. This logic enablesfast fault clearing during certain conditions,but naturally, it can not fully replace acommunication channel.

The logic can be controlled either by theautorecloser (zone extension) or by the loss-of-load current (loss-of-load acceleration).

Scheme communication logic for residualovercurrent protection ECPSCH

To achieve fast fault clearance of earth faultson the part of the line not covered by theinstantaneous step of the residual overcurrentprotection, the directional residualovercurrent protection can be supported witha logic that uses communication channels.

In the directional scheme, information of thefault current direction must be transmitted tothe other line end. With directionalcomparison, a short operates time of theprotection including a channel transmissiontime, can be achieved. This short operatetime enables rapid autoreclosing functionafter the fault clearance.

The communication logic module fordirectional residual current protectionenables blocking as well as permissive under/overreaching schemes. The logic can also besupported by additional logic for weak-endinfeed and current reversal, included inCurrent reversal and weak-end infeed logicfor residual overcurrent protection Currentreversal and weak-end infeed logic for


ABB 21

residual overcurrent protection (ECRWPSCH)function.

Current reversal and weak-end infeed logicfor residual overcurrent protectionECRWPSCH

The Current reversal and weak-end infeedlogic for residual overcurrent protectionECRWPSCH is a supplement to Schemecommunication logic for residual overcurrentprotection ECPSCH.

To achieve fast fault clearing for all earthfaults on the line, the directional earth-faultprotection function can be supported withlogic that uses communication channels.

The 670 series IEDs have for this reasonavailable additions to scheme communicationlogic.

If parallel lines are connected to commonbusbars at both terminals, overreachingpermissive communication schemes can tripunselectively due to fault current reversal.This unwanted tripping affects the healthyline when a fault is cleared on the other line.This lack of security can result in a total lossof interconnection between the two buses. Toavoid this type of disturbance, a fault currentreversal logic (transient blocking logic) canbe used.

Permissive communication schemes forresidual overcurrent protection, can basicallyoperate only when the protection in theremote terminal can detect the fault. Thedetection requires a sufficient minimumresidual fault current, out from this terminal.The fault current can be too low due to anopened breaker or high positive and/or zerosequence source impedance behind thisterminal. To overcome these conditions,weak end infeed (WEI) echo logic is used.

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 of

sufficient length, as well as all functionalitynecessary for correct co-operation withautoreclosing functions.

The trip function block includes functionalityfor evolving faults and breaker lock-out.

Trip matrix logic TMAGGIO

Trip matrix logic (TMAGGIO) function isused to route trip signals and/or other logicaloutput signals to different output contacts onthe IED.

TMAGGIO output signals and the physicaloutputs are available in PCM600 and thisallows the user to adapt the signals to thephysical tripping outputs according to thespecific application needs.

Configurable logic blocks

A number of logic blocks and timers areavailable for user to adapt the configurationto 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 controllingif a signal should be able to pass from theinput to the output or not depending on asetting.

• 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 two


22 ABB

outputs where one is inverted. The memorysetting controls if the block after a powerinterruption should return to the statebefore the interruption, or be reset. Setinput has priority.

• RSMEMORY function block is a flip-flopthat can reset or set an output from twoinputs respectively. Each block has twooutputs where one is inverted. The memorysetting controls if the block after a powerinterruption should return to the statebefore the interruption, or be reset. Resetinput has priority.

Fixed signal function block

The Fixed signals function (FXDSIGN)generates a number of pre-set (fixed) signalsthat can be used in the configuration of anIED, either for forcing the unused inputs inother function blocks to a certain level/value,or for creating a certain logic.

Monitoring

Measurements

The service value function is used to get on-line information from the IED. These servicevalues makes it possible to display on-lineinformation on the local HMI and on theSubstation automation system about:

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

• the primary and secondary phasors• differential currents, bias currents• positive, negative and zero sequence

currents and voltages• mA, input currents• pulse counters• event counters• measured values and other information

of the different parameters for includedfunctions

• logical values of all binary in- andoutputs and

• general IED information.

Supervision of mA input signals (MVGGIO)

The main purpose of the function is tomeasure and process signals from differentmeasuring transducers. Many devices used inprocess control represent various parameterssuch as frequency, temperature and DCbattery voltage as low current values, usuallyin the range 4-20 mA or 0-20 mA.

Alarm limits can be set and used as triggers,e.g. to generate trip or alarm signals.

The function requires that the IED isequipped with the mA input module.

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.

Disturbance report functionality is a commonname for several functions:

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

Disturbance report function is characterizedby great flexibility regarding configuration,starting conditions, recording times and largestorage capacity.

A disturbance is defined as an activation ofan input in the AxRADR or BxRBDR functionblocks, which is set to trigger the disturbancerecorder. All signals from start of pre-fault


ABB 23

time to the end of post-fault time will beincluded 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 localHMI is used to get information about therecordings, but the disturbance report filesmay be uploaded to PCM600 and furtheranalysis using the disturbance handling tool.

Event list DRPRDRE

Continuous event-logging is useful formonitoring of 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 of up to 1000 time-tagged events 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 all selected analog input andbinary signals connected to the Disturbancereport function (maximum 40 analog and 96binary signals). The binary signals are thesame signals as available under the eventrecorder function.

The function is characterized by greatflexibility and is not dependent on the


24 ABB

operation of protection functions. It canrecord disturbances not detected byprotection functions.

The disturbance recorder information for thelast 100 disturbances are saved in the IEDand the local HMI is used to view the list ofrecordings.

Event function

When using a Substation Automation systemwith LON or SPA communication, time-tagged events can be sent at change orcyclically from the IED to the station level.These events are created from any availablesignal in the IED that is connected to theEvent function (EVENT). The event functionblock is used for LON and SPAcommunication.

Analog and double indication values are alsotransferred through EVENT function.

Fault locator LMBRFLO

The accurate fault locator is an essentialcomponent to minimize the outages after apersistent fault and/or to pin-point a weakspot on the line.

The fault locator is an impedance measuringfunction giving the distance to the fault inpercent, km or miles. The main advantage isthe high accuracy achieved by compensatingfor load current.

The compensation includes setting of theremote and local sources and calculation ofthe distribution of fault currents from eachside. This distribution of fault current,together with recorded load (pre-fault)currents, is used to exactly calculate the faultposition. The fault can be recalculated withnew source data at the actual fault to furtherincrease the accuracy.

Especially on heavily loaded long lines(where the fault locator is most important)where the source voltage angles can be up to35-40 degrees apart the accuracy can be stillmaintained with the advanced compensationincluded in fault locator.

Measured value expander block RANGE_XP

The current and voltage measurementsfunctions (CVMMXU, 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 that is low-low limit, low limit,high limit and high-high limit. The measurevalue expander block (RANGE_XP) has beenintroduced to be able to translate the integeroutput signal from the measuring functions to5 binary signals that is below low-low limit,below low limit, normal, above high-highlimit or above high limit. The output signalscan be used as conditions in the configurablelogic.

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 binary input module and then read bythe pulse counter function. A scaled servicevalue is available over the station bus. Thespecial Binary input module with enhancedpulse counting capabilities must be orderedto achieve this functionality.

Function for energy calculation anddemand handling ETPMMTR

Outputs from Measurements (CVMMXU)function can be used to calculate energy.Active as well as reactive values arecalculated in import and export direction.Values can be read or generated as pulses.Maximum demand power values are alsocalculated by the function.


ABB 25

Basic IED functions

Time synchronization

Use the time synchronization source selectorto select a common source of absolute timefor the IED when it is a part of a protectionsystem. This makes comparison of events anddisturbance data between all IEDs in a stationautomation system possible.

Human machine interface

The local HMI is divided into zones withdifferent functionality.

• Status indication LEDs.• Alarm indication LEDs, which consist of

15 LEDs (6 red and 9 yellow) with userprintable label. All LEDs are configurablefrom PCM600.

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

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

• Isolated RJ45 communication port.

IEC05000056-LITEN V1 EN

Figure 10. Medium graphic HMI, 15controllable objects


Overview

Each IED is provided with a communicationinterface, enabling it to connect to one ormany substation level systems or equipment,either on the Substation Automation (SA) busor Substation Monitoring (SM) bus.

Following communication protocols areavailable:

• IEC 61850-8-1 communication protocol• LON communication protocol• SPA or IEC 60870-5-103 communication

protocol• DNP3.0 communication protocol

Theoretically, several protocols can becombined in the same IED.

IEC 61850-8-1 communication protocol

The IED is equipped with single or doubleoptical Ethernet rear ports (order dependent)for the new substation communicationstandard IEC 61850-8-1 for the station bus.IEC 61850-8-1 communication is also possiblefrom the optical Ethernet front port. IEC61850-8-1 protocol allows intelligent 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.

Serial communication, LON

Existing stations with ABB station bus LONcan be extended with use of the optical LONinterface. This allows full SA functionalityincluding peer-to-peer messaging andcooperation between existing ABB IED's andthe new IED 670.

SPA communication protocol

A single glass or plastic port is provided forthe ABB SPA protocol. This allows extensionsof simple substation automation systems butthe main use is for Substation MonitoringSystems SMS.


26 ABB

IEC 60870-5-103 communication protocol

A single glass or plastic port is provided forthe IEC60870-5-103 standard. This allowsdesign of simple substation automationsystems including equipment from differentvendors. Disturbance files uploading isprovided.

DNP3.0 communication protocol

An electrical RS485 and an optical Ethernetport is available for the DNP3.0communication. DNP3.0 Level 2communication with unsolicited events, timesynchronizing and disturbance reporting isprovided for communication to RTUs,Gateways or HMI systems.

Single command, 16 signals

The IEDs can receive commands either froma substation automation system or from thelocal HMI. The command function block hasoutputs that can be used, for example, tocontrol high voltage apparatuses or for otheruser defined functionality.

Multiple command and transmit

When 670 IED's are used in SubstationAutomation systems with LON, SPA orIEC60870-5-103 communication protocols theEvent and Multiple Command function blocksare used as the communication interface forvertical communication to station HMI andgateway and as interface for horizontal peer-to-peer communication (over LON only).


Analog and binary signal transfer toremote end

Three analog and eight binary signals can beexchanged between two IEDs. This

functionality is mainly used for the linedifferential protection. However it can beused in other products as well. An IED cancommunicate with up to 4 remote IEDs.

Binary signal transfer to remote end, 192signals

If the communication channel is used fortransfer of binary signals only, up to 192binary signals can be exchanged betweentwo IEDs. For example, this functionality canbe used to send information such as status ofprimary switchgear apparatus or intertrippingsignals to the remote IED. An IED cancommunicate with up to 4 remote IEDs.

Line data communication module, short,medium and long range LDCM

The line data communication module (LDCM)is used for communication between the IEDssituated at distances <110 km or from theIED to optical to electrical converter with G.703 or G.703E1 interface located on adistances <3 km away. The LDCM modulesends and receives data, to and from anotherLDCM module. The IEEE/ANSI C37.94standard format is used.

Galvanic X.21 line data communicationmodule X.21-LDCM

A module with built-in galvanic X.21converter which e.g. can be connected tomodems for pilot wires is also available.

Galvanic interface G.703 resp G.703E1

The external galvanic data communicationconverter G.703/G.703E1 makes an optical-to-galvanic conversion for connection to amultiplexer. These units are designed for 64kbit/s resp 2Mbit/s operation. The converteris delivered with 19” rack mountingaccessories.


ABB 27

5. Hardware description

Hardware modules

Power supply module PSM

The power supply module is used to providethe correct internal voltages and full isolationbetween the terminal and the battery system.An internal fail alarm output is available.

Binary input module BIM

The binary input module has 16 opticallyisolated inputs and is available in twoversions, one standard and one withenhanced pulse counting capabilities on theinputs to be used with the pulse counterfunction. The binary inputs are freelyprogrammable and can be used for the inputof logical signals to any of the functions.They can also be included in the disturbancerecording and event-recording functions. Thisenables extensive monitoring and evaluationof operation of the IED and for all associatedelectrical circuits.

Binary output module BOM

The binary output module has 24independent output relays and is used fortrip output or any signaling purpose.

Static binary output module SOM

The static binary output module has six faststatic outputs and six change over outputrelays for use in applications with high speedrequirements.

Binary input/output module (IOM)

The binary input/output module is usedwhen only a few input and output channelsare needed. The ten standard output channelsare used for trip output or any signallingpurpose. The two high speed signal outputchannels are used for applications whereshort operating time is essential. Eightoptically isolated binary inputs cater forrequired binary input information.

mA input module MIM

The milli-ampere input module is used tointerface transducer signals in the –20 to +20mA range from for example OLTC position,temperature or pressure transducers. Themodule has six independent, galvanicallyseparated channels.

Optical ethernet module OEM

The optical fast-ethernet module is used toconnect an IED to the communication buses(like the station bus) that use the IEC61850-8-1 protocol (port A, B). The modulehas one or two optical ports with STconnectors.

Serial SPA/IEC 60870-5-103 and LONcommunication module SLM

The optical serial channel and LON channelmodule is used to connect an IED to thecommunication that use SPA, LON, orIEC60870–5–103. The module has two opticalports for plastic/plastic, plastic/glass, or glass/glass. One port is used for SPA and IEC60870-5-103 one port is used for LON.

Line data communication module LDCM

Each module has one optical port, one foreach remote end to which the IEDcommunicates.

Alternative cards for Long range (1550 nmsingle mode), Medium range (1310 nm singlemode) and Short range (850 nm multi mode)are available.

Galvanic X.21 line data communicationmodule X.21-LDCM

The galvanic X.21 line data communicationmodule is used for connection totelecommunication equipment, for exampleleased telephone lines. The module supports64 kbit/s data communication between IEDs.

Examples of applications:

• Line differential protection• Binary signal transfer


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Galvanic RS485 serial communicationmodule

The galvanic RS485 serial communicationmodule is used as an alternative for DNP3.0communication.

GPS time synchronization module GSM

This module includes the GPS receiver usedfor time synchronization. The GPS has oneSMA contact for connection to an antenna.

IRIG-B Time synchronizing module

The IRIG-B time synchronizing module isused for accurate time synchronizing of theIED from a station clock.

Electrical (BNC) and optical connection (ST)for 0XX and 12X IRIG-B support.

Transformer input module TRM

The transformer input module is used togalvanically separate and transform the

secondary currents and voltages generated bythe measuring transformers. The module hastwelve inputs in different combinations ofcurrents and voltage inputs.

Alternative connectors of Ring lug orCompression type can be ordered.

High impedance resistor unit

The high impedance resistor unit, withresistors for pick-up value setting and avoltage dependent resistor, is available in asingle phase unit and a three phase unit.Both are mounted on a 1/1 19 inch apparatusplate with compression type termnals.

Layout and dimensions

Dimensions

xx05000003.vsd

CB

E

F

A

D

IEC05000003 V1 EN

Figure 11. 1/2 x 19” case with rear cover


ABB 29

xx05000004.vsd

IEC05000004 V1 EN

Figure 12. Side-by-side mounting

Case size A B C D E F

6U, 1/2 x 19” 265.9 223.7 201.1 242.1 252.9 205.7

6U, 3/4 x 19” 265.9 336.0 201.1 242.1 252.9 318.0

6U, 1/1 x 19” 265.9 448.1 201.1 242.1 252.9 430.3

(mm)

Mounting alternatives

Following mounting alternatives (IP40protection from the front) are available:

• 19” rack mounting kit• Flush mounting kit with cut-out

dimensions:

1/2 case size (h) 254.3 mm (w) 210.1mm

3/4 case size (h) 254.3 mm (w) 322.4mm

1/1 case size (h) 254.3 mm (w) 434.7mm

• Wall mounting kit

See ordering for details about availablemounting alternatives.


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6. Connection diagrams

Table 1. Designations for 1/2 x 19” casing with 1 TRM slot

IEC08000471 BG V1 EN

Module Rear Positions

PSM X11

BIM, BOM, SOM or IOM X31 and X32 etc. to X51and X52

BIM, BOM, SOM, IOM orGSM

X51, X52

SLM X301:A, B, C, D

IRIG-B 1) X302

OEM X311:A, B, C, D

RS485 or LDCM 2) 3) X312

LDCM 2) X313

TRM X401

1) IRIG-B installation, when included in seat P30:22) LDCM installation sequence: P31:2 or P31:33) RS485 installation, when included in seat P31:2Note!1 One LDCM can be included depending of availabilityof IRIG-B respective RS485 modules.


ABB 31

Table 2. Designations for 3/4 x 19” casing with 2 TRM slot



PSM X11

BIM, BOM, SOM, IOM orMIM

X31 and X32 etc. to X71 andX72

BIM, BOM, SOM, IOM,MIM or GSM

X71, X72

SLM X301:A, B, C, D

IRIG-B or LDCM 1,2) X302

LDCM 2) X303

OEM 4) X311:A, B, C, D

RS485 or LDCM 2) 3) X312

LDCM 2) X313

LDCM 2) X322

LDCM 2) X323

TRM 1 X401

TRM 2 X411

1) IRIG-B installation, when included in seat P30:22) LDCM installation sequence: P31:2, P31:3, P32:2, P32:3,P30:2 and P30:33) RS485 installation, when included in seat P31:2, P31:3,P32:2 or P32:34) OEM X311:A, B (IEC 61850-8-1). (X311:C, D IEC61850-8-1)Note!2-4 LDCM can be included depending of availability of IRIG-B respective RS485 modules.When IRIG-B, RS485 and 4 pc of LDCM are in use, needsa second ADM.


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Table 3. Designations for 1/1 x 19” casing with 2 TRM slots



PSM X11

BIM, BOM, SOM,IOM or MIM

X31 and X32 etc. to X131and X132

BIM, BOM, SOM,IOM, MIM orGSM

X131, X132

SLM X301:A, B, C, D

IRIG-B or LDCM1,2)

X302

LDCM 2) X303

OEM 4) X311:A, B, C, D

RS485 or LDCM2) 3)

X312

LDCM 2) X313

LDCM 2) X322

LDCM 2) X323

TRM 1 X401

TRM 2 X411

1) IRIG-B installation, when included in seatP30:22) LDCM installation sequence: P31:2, P31:3,P32:2, P32:3, P30:2 and P30:33) RS485 installation, when included in seatP31:2, P31:3, P32:2 or P32:44) OEM X311:A, B (IEC 61850-8-1). OEMX311:C, DNote!2-4 LDCM can be included depending ofavailability of IRIG-B respective RS485 modules.When IRIG-B, RS485 and 4 pc of LDCM are inuse, needs a second ADM.


ABB 33


Figure 13. Transformer input module (TRM)

Indicates high polarity

CT/VT-input designation according to figure 13

Curr

ent/

volt

age

confi

gura

tion

(50/

60 H

z)

AI01 AI02 AI03 AI04 AI05 AI06 AI07 AI08 AI09 AI10 AI11 AI12

12I, 1A 1A 1A 1A 1A 1A 1A 1A 1A 1A 1A 1A 1A

12I, 5A 5A 5A 5A 5A 5A 5A 5A 5A 5A 5A 5A 5A

9I+3U,1A

1A 1A 1A 1A 1A 1A 1A 1A 1A 110-220V 110-220V 110-220V

9I+3U,5A

5A 5A 5A 5A 5A 5A 5A 5A 5A 110-220V 110-220V 110-220V

5I, 1A+4I, 5A+3U

1A 1A 1A 1A 1A 5A 5A 5A 5A 110-220V 110-220V 110-220V

7I+5U,1A

1A 1A 1A 1A 1A 1A 1A 110-220V 110-220V 110-220V 110-220V 110-220V

7I+5U,5A

5A 5A 5A 5A 5A 5A 5A 110-220V 110-220V 110-220V 110-220V 110-220V

6I+6U,1A

1A 1A 1A 1A 1A 1A 110-220V 110-220V 110-220V 110-220V 110-220V 110-220V

6I+6U,5A

5A 5A 5A 5A 5A 5A 110-220V 110-220V 110-220V 110-220V 110-220V 110-220V

3I, 5A+3I, 1A+6U

5 A 5 A 5 A 1A 1A 1A 110-220V 110-220V 110-220V 110-220V 110-220V 110-220V

6I, 1A 1A 1A 1A 1A 1A 1A - - - - - -

6I, 5A 5A 5A 5A 5A 5A 5A - - - - - -

Note that internal polarity can be adjusted by setting of analog input CT neutral direction and/or on SMAI pre-processing function blocks.


34 ABB


Figure 14. Binary input module (BIM). Inputcontacts named XA corresponds torear position X31, X41, and so on,and input contacts named XB torear position X32, X42, and so on.


Figure 15. mA input module (MIM)


ABB 35


Figure 16. Communication interfaces (OEM, LDCM, SLM and HMI)

Note to figure 16

1) Rear communication port SPA/IEC 61850-5-103, ST-connector for glass alt. HFBR Snap-in connector forplastic as ordered

2) Rear communication port LON, ST connector for glass alt. HFBR Snap-in connector for plastic as ordered

3) Rear communication port RS485, terminal block

4) Time synchronization port IRIG-B, BNC-connector

5) Time synchronization port PPS or Optical IRIG-B, ST-connector

6) Rear communication port IEC 61850-8-1 for X311:A, B, ST-connector

7) Rear communication port C37.94, ST-connector

8) Front communication port Ethernet, RJ45 connector

9) Rear communication port 15-pole female micro D-sub, 1.27 mm (0.050") pitch

10) Rear communication port, terminal block


Figure 17. Power supply module (PSM)


36 ABB


Figure 18. GPS time synchronization module (GSM)


Figure 19. Binary output module (BOM). Output contacts named XA corresponds to rearposition X31, X41, and so on, and output contacts named XB to rear positionX32, X42, and so on.


ABB 37


Figure 20. Static output module (SOM)


Figure 21. Binary in/out module (IOM). Input contacts named XA corresponds to rear positionX31, X41, and so on, and output contacts named XB to rear position X32, X42,and so on.


38 ABB

7. 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

Analog inputs

Table 4. TRM - Energizing quantities, rated values and limits

Quantity Rated value Nominal range

Current Ir = 1 or 5 A (0.2-40) × Ir

Operative range (0-100) x Ir

Permissive overload 4 × Ir cont.

100 × Ir for 1 s *)

Burden < 150 mVA at Ir = 5 A

< 20 mVA at Ir = 1 A

Ac voltage Ur = 110 V 0.5–288 V

Operative range (0–340) V

Permissive overload 420 V cont.450 V 10 s

Burden < 20 mVA at 110 V

Frequency fr = 50/60 Hz ± 5%

*) max. 350 A for 1 s when COMBITEST test switch is included.


ABB 39

Table 5. MIM - mA input module

Quantity: Rated value: Nominal range:

Input resistance Rin = 194 Ohm -

Input range ± 5, ± 10, ± 20mA0-5, 0-10, 0-20, 4-20mA

-

Power consumptioneach mA-boardeach mA input

£ 4 W£ 0.1 W

-

Table 6. OEM - Optical ethernet module

Quantity Rated value

Number of channels 1 or 2

Standard IEEE 802.3u 100BASE-FX

Type of fiber 62.5/125 mm multimode fibre

Wave length 1300 nm

Optical connector Type ST

Communication speed Fast Ethernet 100 MB

Auxiliary DC voltage

Table 7. PSM - Power supply module


Auxiliary dc voltage, EL (input) EL = (24 - 60) VEL = (90 - 250) V

EL ± 20%EL ± 20%

Power consumption 50 W typically -

Auxiliary DC power in-rush < 5 A during 0.1 s -


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Binary inputs and outputs

Table 8. BIM - Binary input module


Binary inputs 16 -

DC voltage, RL 24/40 V48/60 V110/125 V220/250 V

RL ± 20%RL ± 20%RL ± 20%RL ± 20%

Power consumption24/40 V48/60 V110/125 V220/250 V

max. 0.05 W/inputmax. 0.1 W/inputmax. 0.2 W/inputmax. 0.4 W/input

-

Counter input frequency 10 pulses/s max -

Oscillating signal discriminator Blocking settable 1–40 HzRelease settable 1–30 Hz

Table 9. BIM - Binary input module with enhanced pulse counting capabilities


Binary inputs 16 -


RL ± 20%RL ± 20%RL ± 20%RL ± 20%



-

Counter input frequency 10 pulses/s max -

Balanced counter input frequency 40 pulses/s max -

Oscillating signal discriminator Blocking settable 1–40 HzRelease settable 1–30 Hz


ABB 41

Table 10. IOM - Binary input/output module


Binary inputs 8 -


RL ± 20%RL ± 20%RL ± 20%RL ± 20%



-

Table 11. IOM - Binary input/output module contact data (reference standard: IEC61810-2)

Function or quantity Trip and signal relays Fast signal relays(parallel reed relay)

Binary outputs 10 2

Max system voltage 250 V AC, DC 250 V AC, DC

Test voltage across open contact, 1 min 1000 V rms 800 V DC

Current carrying capacityContinuous1 s

8 A10 A

8 A10 A

Making capacity at inductive load withL/R>10 ms0.2 s1.0 s

30 A10 A

0.4 A0.4 A

Breaking capacity for AC, cos φ > 0.4 250 V/8.0 A 250 V/8.0 A

Breaking capacity for DC with L/R < 40ms

48 V/1 A110 V/0.4 A125 V/0.35 A220 V/0.2 A250 V/0.15 A

48 V/1 A110 V/0.4 A125 V/0.35 A220 V/0.2 A250 V/0.15 A

Maximum capacitive load - 10 nF


42 ABB

Table 12. SOM - Static Output Module (reference standard: IEC 61810-2): Static binaryoutputs

Function of quantity Static binary output trip

Rated voltage 48 - 60 VDC 110 - 250 VDC

Number of outputs 6 6

Impedance open state ~300 kΩ ~810 kΩ

Test voltage across opencontact, 1 min

No galvanic separation No galvanic separation

Current carrying capacity:

Continuous 5A 5A

1.0s 10A 10A

Making capacity at capacitiveload with the maximumcapacitance of 0.2 μF :

0.2s 30A 30A

1.0s 10A 10A

Breaking capacity for DC with L/R ≤ 40ms

48V / 1A 110V / 0.4A

60V / 0,75A 125V / 0.35A

220V / 0.2A

250V / 0.15A

Operating time <1ms <1ms


ABB 43

Table 13. SOM - Static Output module data (reference standard: IEC 61810-2):Electromechanical relay outputs

Function of quantity Trip and signal relays

Max system voltage 250V AC/DC

Number of outputs 6

Test voltage across open contact, 1 min 1000V rms

Current carrying capacity:

Continuous 8A

1.0s 10A

Making capacity at capacitive load with themaximum capacitance of 0.2 μF:

0.2s 30A

1.0s 10A

Breaking capacity for DC with L/R ≤ 40ms 48V / 1A

110V / 0.4A

125V / 0,35A

220V / 0,2A

250V / 0.15A

Table 14. BOM - Binary output module contact data (reference standard: IEC 61810-2)

Function or quantity Trip and Signal relays

Binary outputs 24

Max system voltage 250 V AC, DC

Test voltage across open contact, 1 min 1000 V rms

Current carrying capacityContinuous1 s

8 A10 A

Making capacity at inductive load with L/R>10 ms0.2 s1.0 s

30 A10 A

Breaking capacity for AC, cos j>0.4 250 V/8.0 A

Breaking capacity for DC with L/R < 40 ms 48 V/1 A110 V/0.4 A125 V/0.35 A220 V/0.2 A250 V/0.15 A


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Influencing factors

Table 15. Temperature and humidity influence

Parameter Reference value Nominal range Influence

Ambienttemperature, operatevalue

+20 °C -10 °C to +55 °C 0.02% /°C

Relative humidityOperative range

10%-90%0%-95%

10%-90% -

Storage temperature -40 °C to +70 °C - -

Table 16. Auxiliary DC supply voltage influence on functionality during operation

Dependence on Referencevalue

Withinnominal range

Influence

Ripple, in DC auxiliary voltageOperative range

max. 2%Full waverectified

12% of EL 0.01% /%

Auxiliary voltage dependence,operate value

± 20% of EL 0.01% /%

Interrupted auxiliary DC voltage

24-60 V DC ±20%90-250 V DC ±20%

Interruptioninterval0–50 ms

No restart

0–∞ s Correct behaviour atpower down

Restart time <180 s

Table 17. Frequency influence (reference standard: IEC 60255–6)

Dependence on Within nominal range Influence

Frequency dependence, operatevalue

fr ± 2.5 Hz for 50 Hz

fr ± 3.0 Hz for 60 Hz

± 1.0% / Hz

Harmonic frequencydependence (20% content)

2nd, 3rd and 5th harmonic of fr ± 1.0%

Harmonic frequencydependence for distanceprotection (10% content)

2nd, 3rd and 5th harmonic of fr ± 6.0%


ABB 45

Type tests according to standards

Table 18. Electromagnetic compatibility

Test Type test values Reference standards

1 MHz burst disturbance 2.5 kV IEC 60255-22-1, Class III

Ring wave immunity test 2-4 kV IEC 61000-4-12, Class III

Surge withstand capability test 2.5 kV, oscillatory4.0 kV, fast transient

IEEE/ANSI C37.90.1

Electrostatic dischargeDirect applicationIndirect application

15 kV air discharge8 kV contact discharge8 kV contact discharge

IEC 60255-22-2, Class IV IEC 61000-4-2, Class IV

Electrostatic dischargeDirect applicationIndirect application

15 kV air discharge8 kV contact discharge8 kV contact discharge

IEEE/ANSI C37.90.1

Fast transient disturbance 4 kV IEC 60255-22-4, Class A

Surge immunity test 1-2 kV, 1.2/50 mshigh energy

IEC 60255-22-5

Power frequency immunity test 150-300 V,50 Hz

IEC 60255-22-7, Class A

Conducted common modeimmunity test

15 Hz-150 kHz IEC 61000-4-16, Class IV

Power frequency magnetic field test 1000 A/m, 3 s IEC 61000-4-8, Class V

Damped oscillatory magnetic fieldtest

100 A/m IEC 61000-4-10, Class V

Radiated electromagnetic fielddisturbance

20 V/m, 80-1000 MHz IEC 60255-22-3


20 V/m, 80-2500 MHz EN 61000-4-3


35 V/m26-1000 MHz

IEEE/ANSI C37.90.2

Conducted electromagnetic fielddisturbance

10 V, 0.15-80 MHz IEC 60255-22-6

Radiated emission 30-1000 MHz IEC 60255-25

Conducted emission 0.15-30 MHz IEC 60255-25


46 ABB

Table 19. Insulation

Test Type test values Reference standard

Dielectric test 2.0 kV AC, 1 min. IEC 60255-5

Impulse voltage test 5 kV, 1.2/50 ms, 0.5 J

Insulation resistance >100 MW at 500 VDC

Table 20. Environmental tests

Test Type test value Reference standard

Cold test Test Ad for 16 h at -25°C IEC 60068-2-1

Storage test Test Ad for 16 h at -40°C IEC 60068-2-1

Dry heat test Test Bd for 16 h at +70°C IEC 60068-2-2

Damp heat test, steady state Test Ca for 4 days at +40 °C andhumidity 93%

IEC 60068-2-78

Damp heat test, cyclic Test Db for 6 cycles at +25 to +55°C and humidity 93 to 95% (1 cycle= 24 hours)

IEC 60068-2-30

Table 21. CE compliance

Test According to

Immunity EN 50263

Emissivity EN 50263

Low voltage directive EN 50178

Table 22. Mechanical tests

Test Type test values Reference standards

Vibration response test Class II IEC 60255-21-1

Vibration endurance test Class I IEC 60255-21-1

Shock response test Class II IEC 60255-21-2

Shock withstand test Class I IEC 60255-21-2

Bump test Class I IEC 60255-21-2

Seismic test Class II IEC 60255-21-3


ABB 47

Differential protection

Table 23. High impedance differential protection (PDIF, 87)

Function Range or value Accuracy

Operate voltage (20-400) V ± 1.0% of Ur for U < Ur

± 1.0% of U for U > Ur

Reset ratio >95% -

Maximum continuous voltage U>TripPickup2/series resistor≤200 W

-

Operate time 10 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 24. Line differential protection (PDIF, 87L, 87LT)


Minimum operate current (20-200)% of Ibase ± 2.0% of Ir at I £ Ir± 2.0% of I at I >I r

SlopeSection2 (10.0-50.0)% -

SlopeSection3 (30.0-100.0)% -

EndSection 1 (20–150)% of Ibase -

EndSection 2 (100–1000)% of Ibase -

Unrestrained limit function (100–5000)% of Ibase ± 2.0% of Ir at I ≤ Ir± 2.0% of I at I > Ir

Second harmonic blocking (5.0–100.0)% of fundamental ± 2.0% of Ir

Fifth harmonic blocking (5.0–100.0)% of fundamental ± 6.0% of Ir

Inverse characteristics, seetable 98 and table 99

19 curve types See table 98 and table 99

Operate time 25 ms typically at 0 to 10 x Id -

Reset time 15 ms typically at 10 to 0 x Id -

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

Charging currentcompensation

On/Off -


48 ABB


Table 25. Distance measuring zone, Quad ZMQPDIS


Number of zones 3 with selectabledirection

-

Minimum operateresidual current, zone 1

(5-30)% of IBase -

Minimum operate current,phase-to-phase and phase-to-earth

(10-30)% of IBase -

Positive sequencereactance, zone 1

(0.10-3000.00) Ω/phase

± 2.0% 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

Positive sequencereactance, zone 2-3

(0.50-3000.00) Ω/phase

Positive sequenceresistance

(0.10-1000.00) Ω/phase

Zero sequence reactance,zone 1

(0.10-9000.00) Ω/phase

Zero sequence reactance,zone 2-3

(0.50-9000.00) Ω/phase

Zero sequence resistance (0.50-3000.00) Ω/phase

Fault resistance, phase-to-earth

(1.00-9000.00) Ω/loop

Fault resistance, phase-to-phase

(1.00-3000.00) Ω/loop

Dynamic overreach <5% at 85degreesmeasured withCVT’s and0.5<SIR<30

-

Impedance zone timers (0.000-60.000) s ± 0.5% ± 10 ms

Operate time 24 ms typically -

Reset ratio 105% typically -

Reset time 30 ms typically -


ABB 49

Table 26. Distance measuring zone, quadrilateral characteristic for series compensatedlines ZMCPDIS, ZMCAPDIS


Number of zones 3 with selectable direction -

Minimum operateresidual current, zone 1

(5-30)% of IBase -

Minimum operate current,Ph-Ph and Ph-E

(10-30)% of IBase -

Positive sequencereactance

(0.50-3000.00) Ω/phase ± 2.0% static accuracy± 2.0 degrees static angular accuracyConditions:Voltage range: (0.1-1.1) x Ur


Positive sequenceresistance

(0.10-1000.00) Ω/phase

Zero sequence reactance (0.50-9000.00) Ω/phase

Zero sequence resistance (0.50-3000.00) Ω/phase

Fault resistance, Ph-E (1.00-9000.00) Ω/loop

Fault resistance, Ph-Ph (1.00-3000.00) Ω/loop

Dynamic overreach <5% at 85 degreesmeasured with CCVT’sand 0.5<SIR<30

-

Impedance zone timers (0.000-60.000) s ± 0.5% ± 10 ms

Operate time 24 ms typically -




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Table 27. Full-scheme distance protection, Mho characteristic ZMHPDIS


Number of zones withselectable directions

3 with selectabledirection

-

Minimum operate current (10–30)% of IBase -

Positive sequenceimpedance, phase-to-earth loop

(0.005–3000.000) W/phase

± 2.0% static accuracyConditions:Voltage range: (0.1-1.1) x Ur


Positive sequenceimpedance angle, phase-to-earth loop

(10–90) degrees

Reverse reach, phase-to-earth loop (Magnitude)

(0.005–3000.000) Ω/phase

Magnitude of earth returncompensation factor KN

(0.00–3.00)

Angle for earthcompensation factor KN

(-180–180) degrees

Dynamic overreach <5% at 85 degreesmeasured with CVT’sand 0.5<SIR<30

-

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

Operate time 20 ms typically (withstatic outputs)

-




ABB 51

Table 28. Phase selection with load encroachment, quadrilateral characteristic


Minimum operate current (5-30)% of IBase ± 1.0% of IBase

Reactive reach, positivesequence , forward andreverse

(0.50–3000.00) Ω/phase ± 2.0% static accuracy± 2.0 degrees static angular accuracyConditions:Voltage range: (0.1-1.1) x UBaseCurrent range: (0.5-30) x IBaseAngle: at 0 degrees and 85 degrees

Resistive reach, positivesequence

(0.10–1000.00) Ω/phase

Reactive reach, zerosequence, forward andreverse

(0.50–9000.00) Ω/phase

Resistive reach, zerosequence

(0.50–3000.00) Ω/phase

Fault resistance, phase-to-earth faults, forward andreverse

(1.00–9000.00) Ω/loop

Fault resistance, phase-to-phase faults, forward andreverse

(0.50–3000.00) Ω/loop

Load encroachmentcriteria:Load resistance, forwardand reverseSafety load impedanceangle

(1.00–3000.00) Ω/phase(5-70) degrees


Table 29. Faulty phase identification with load encroachment FMPSPDIS


Minimum operate current (5-30)% of IBase ± 1.0% of Ir

Load encroachmentcriteria: Load resistance,forward and reverse

(0.5–3000) W/phase(5–70) degrees

± 2.0% static accuracyConditions:Voltage range: (0.1–1.1) x Un

Current range: (0.5–30) x InAngle: at 0 degrees and 85degrees


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Table 30. Power swing detection ZMRPSB


Reactive reach (0.10-3000.00) W/phase

± 2.0% static accuracyConditions:Voltage range: (0.1-1.1) x Ur

Current range: (0.5-30) x IrAngle: at 0 degrees and 85 degreesResistive reach (0.10–1000.00)W/loop

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

Table 31. Pole slip protection (PPAM, 78)


Impedance reach (0.00–1000.00)% of Zbase ± 2.0% of Ur/Ir

Characteristic angle (72.00–90.00) degrees ± 5.0 degrees

Start and trip angles (0.0–180.0) degrees ± 5.0 degrees

Zone 1 and Zone 2 tripcounters

(1-20) -

Table 32. Automatic switch onto fault logic, voltage and current based ZCVPSOF

Parameter Range orvalue

Accuracy

Operate voltage, detection of dead line (1–100)% ofUBase

± 1.0% of Ur

Operate current, detection of dead line (1–100)% ofIBase

± 1.0% of Ir

Delay following dead line detectioninput before Automatic switch into faultlogic function is automatically turned On

(0.000–60.000) s

± 0.5% ± 10 ms

Time period after circuit breaker closurein which Automatic switch into faultlogic function is active

(0.000–60.000) s

± 0.5% ± 10 ms


ABB 53

Current protection

Table 33. Instantaneous phase overcurrent protection PHPIOC


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

Reset ratio > 95% -

Operate time 25 ms typically at 0 to 2 x Iset -

Reset time 25 ms typically at 2 to 0 x Iset -

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




Dynamic overreach < 5% at t = 100 ms -


54 ABB

Table 34. Four step phase overcurrent protection OC4PTOC

Function Setting range Accuracy


Reset ratio > 95% -

Min. operating current (1-100)% of lBase ± 1.0% of Ir

Relay characteristic angle(RCA)

(-70.0– -50.0) degrees ± 2.0 degrees

Maximum forward angle (40.0–70.0) degrees ± 2.0 degrees

Minimum forward angle (75.0–90.0) degrees ± 2.0 degrees

2nd harmonic blocking (5–100)% of fundamental ± 2.0% of Ir

Independent time delay (0.000-60.000) s ± 0.5% ± 10 ms

Minimum operate time (0.000-60.000) s ± 0.5% ± 10 ms

Inverse characteristics,see table 98, table 99 andtable 100

19 curve types See table 98, table 99 andtable 100

Operate time, startfunction

25 ms typically at 0 to 2 x Iset -

Reset time, start function 25 ms typically at 2 to 0 x Iset -


Impulse margin time 15 ms typically -


ABB 55

Table 35. Instantaneous residual overcurrent protection EFPIOC



Reset ratio > 95% -







Dynamic overreach < 5% at t = 100 ms -


56 ABB

Table 36. Four step residual overcurrent protection EF4PTOC



Reset ratio > 95% -

Operate current fordirectional comparison

(1–100)% of lBase ± 1.0% of Ir

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



Second harmonic restrainoperation

(5–100)% of fundamental ± 2.0% of Ir

Relay characteristic angle (-180 to 180) degrees ± 2.0 degrees

Minimum polarizingvoltage

(1–100)% of UBase ± 0.5% of Ur

Minimum polarizingcurrent

(1-30)% of IBase ±0.25% 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 -







ABB 57

Table 37. 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 ±1.0 mA±0.5 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 ±1.0 mA±0.5 mA

Operate level for nondirectional 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 nondirectional 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 ±1.0 mA± 0.5 mA

Residual release voltagefor all directional modes

(0.01-200.00)% 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% ± 10 ms



Relay characteristic angleRCA

(-179 to 180) degrees ± 2.0 degrees

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


58 ABB

Table 37. Sensitive directional residual overcurrent and power protection SDEPSDE ,continued


Operate time, nondirectional residual overcurrent


Reset time, nondirectional residual overcurrent





Table 38. Thermal overload protection, one time constant LPTTR


Reference current (0-400)% of IBase ± 1.0% of Ir

Start temperaturereference

(0-400)°C ± 1.0°C

Operate time:

2 2

2 2ln p

b

I It

I It

æ ö-ç ÷= ×ç ÷-è ø

EQUATION1356 V1 EN (Equation 1)

I = actual measuredcurrentIp = load current before

overload occursIb = base current, IBase

Time constant t = (0–1000) minutes

IEC 60255-8, class 5 + 200 ms

Alarm temperature (0-200)°C ± 2.0% of heat content trip

Trip temperature (0-400)°C ± 2.0% of heat content trip

Reset level temperature (0-400)°C ± 2.0% of heat content trip


ABB 59

Table 39. 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

10 ms typically -

Reset time for currentdetection

15 ms maximum -

Table 40. Stub protection STBPTOC


Operating current (1-2500)% of IBase ± 1.0% of Ir at I £ Ir± 1.0% of I at I > Ir

Reset ratio > 95% -

Definite time (0.000-60.000) s ± 0.5% ± 10 ms

Operating time, start function 25 ms typically at 0 to 2 x Iset -

Resetting time, startfunction 25 ms typically at 2 to 0 x Iset -



Table 41. Pole discordance protection CCRPLD


Operate current (0–100)% of IBase ± 1.0% of Ir

Time delay (0.000-60.000) s ± 0.5% ± 10 ms


60 ABB

Table 42. Directional underpower protection GUPPDUP


Power level (0.0–500.0)% of Sbase At low setting:(0.5-2.0)% of Sbase(2.0-10)% of Sbase

± 1.0% of Sr at S < Sr

± 1.0% of S at S > Sr

< ±50% of set value< ± 20% of set value

Characteristic angle (-180.0–180.0) degrees 2 degrees

Timers (0.00-6000.00) s ± 0.5% ± 10 ms

Table 43. Directional overpower protection GOPPDOP


Power level (0.0–500.0)% of Sbase

At low setting:(0.5-2.0)% of Sbase

(2.0-10)% of Sbase

± 1.0% of Sr at S < Sr

± 1.0% of S at S > Sr

< ± 50% of set value< ± 20% of set value

Characteristic angle (-180.0–180.0) degrees 2 degrees

Timers (0.00-6000.00) s ± 0.5% ± 10 ms

Table 44. Broken conductor check BRCPTOC


Minimum phase currentfor operation

(5–100)% of IBase ± 0.1% of Ir

Unbalance currentoperation

(0–100)% of maximumcurrent

± 0.1% of Ir

Timer (0.00-6000.00) s ± 0.5% ± 10 ms


ABB 61

Voltage protection

Table 45. Two step undervoltage protection UV2PTUV


Operate voltage, low andhigh step

(1–100)% of UBase ± 1.0% of Ur

Absolute hysteresis (0–100)% of UBase ± 1.0% of Ur

Internal blocking level, lowand high step

(1–100)% of UBase ± 1.0% of Ur

Inverse time characteristicsfor low and high step, seetable 101

- See table 101

Definite time delays (0.000-60.000) s ± 0.5% ±10 ms

Minimum operate time,inverse characteristics

(0.000–60.000) s ± 0.5% ± 10 ms

Operate time, start function 25 ms typically at 2 to 0.5 x Uset -

Reset time, start function 25 ms typically at 0 to 2 x Uset -

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


Table 46. Two step overvoltage protection OV2PTOV



(1-200)% of Ubase ± 1.0% of Ur at U < Ur

± 1.0% of U at U > Ur

Absolute hysteresis (0–100)% of Ubase ± 1.0% of Ur at U < Ur

± 1.0% of U at U > Ur


- See table 102

Definite time delays (0.000-60.000) s ± 0.5% ± 10 ms

Minimum operate time,Inverse characteristics

(0.000-60.000) s ± 0.5% ± 10 ms

Operate time, start function 25 ms typically at 0 to 2 x Uset -





62 ABB

Table 47. Two step residual overvoltage protection ROV2PTOV



(1-200)% of Ubase ± 1.0% of Ur at U < Ur

± 1.0% of U at U > Ur

Absolute hysteresis (0–100)% of Ubase ± 1.0% of Ur at U < Ur

± 1.0% of U at U > Ur


- See table 103

Definite time setting (0.000–60.000) s ± 0.5% ± 10 ms

Minimum operate time (0.000-60.000) s ± 0.5% ± 10 ms

Operate time, start function 25 ms typically at 0 to 2 x Uset -




Table 48. Overexcitation protection OEXPVPH


Operate value, start (100–180)% of (Ubase/frated) ± 1.0% of U

Operate value, alarm (50–120)% of start level ± 1.0% of Ur at U ≤ Ur

± 1.0% of U at U > Ur

Operate value, high level (100–200)% of (Ubase/frated) ± 1.0% of U

Curve type IEEE or customer defined

2

(0.18 ):

( 1)k

IEEE tM

×=

-


where M = relative (V/Hz) = (E/f)/(Ur/fr)

Class 5 + 40 ms

Minimum time delay forinverse function

(0.000–60.000) s ± 0.5% ± 10 ms

Maximum time delay forinverse function

(0.00–9000.00) s ± 0.5% ± 10 ms

Alarm time delay (0.000–60.000) s ± 0.5% ± 10 ms


ABB 63

Table 49. Voltage differential protection (PTOV)


Voltage difference foralarm and trip

(0.0–100.0) % of Ubase ± 0.5 % of Ur

Under voltage level (0.0–100.0) % of Ubase ± 0.5% of Ur

Timers (0.000–60.000)s ± 0.5% ± 10 ms

Table 50. Loss of voltage check LOVPTUV


Operate voltage (0–100)% of Ubase ± 0.5% of Ur

Pulse timer (0.050–60.000) s ± 0.5% ± 10 ms

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


Table 51. Underfrequency protection SAPTUF


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

Operate time, start function 100 ms typically -

Reset time, start function 100 ms typically -

Operate time, definite time function (0.000-60.000)s ± 0.5% ± 10 ms

Reset time, definite time function (0.000-60.000)s ± 0.5% ± 10 ms

Voltage dependent time delay

( )ExponentU UMin

t tMax tMin tMinUNom UMin

-= × - +

-é ùê úë û


U=Umeasured

Settings:UNom=(50-150)% ofUbase

UMin=(50-150)% of Ubase

Exponent=0.0-5.0tMax=(0.000-60.000)stMin=(0.000-60.000)s

Class 5 + 200 ms


64 ABB

Table 52. Overfrequency protection SAPTOF


Operate value, start function (35.00-75.00) Hz ± 2.0 mHz at symmetricalthree-phase voltage


Reset time, start function 100 ms typically -

Operate time, definite time function (0.000-60.000)s ± 0.5% ± 10 ms

Reset time, definite time function (0.000-60.000)s ± 0.5% ± 10 ms

Table 53. Rate-of-change frequency protection SAPFRC


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

Operate value, internal blockinglevel

(0-100)% of Ubase ± 1.0% of Ur



ABB 65


Table 54. General current and voltage protection (GAPC)


Measuring current input phase1, phase2, phase3,PosSeq, NegSeq, 3*ZeroSeq,MaxPh, MinPh, UnbalancePh,phase1-phase2, phase2-phase3,phase3-phase1, MaxPh-Ph,MinPh-Ph, UnbalancePh-Ph

-

Base current (1 - 99999) A -

Measuring voltage input phase1, phase2, phase3,PosSeq, -NegSeq, -3*ZeroSeq,MaxPh, MinPh, UnbalancePh,phase1-phase2, phase2-phase3,phase3-phase1, MaxPh-Ph,MinPh-Ph, UnbalancePh-Ph

-

Base voltage (0.05 - 2000.00) kV -

Start overcurrent, step 1 and 2 (2 - 5000)% of Ibase ± 1.0% of Ir for I<Ir± 1.0% of I for I>Ir

Start undercurrent, step 1and 2

(2 - 150)% of Ibase ± 1.0% of Ir for I<Ir± 1.0% of I for I>Ir

Definite time delay (0.00 - 6000.00) s ± 0.5% ± 10 ms

Operate time startovercurrent


Reset time start overcurrent 25 ms typically at 2 to 0 x Iset -

Operate time startundercurrent


Reset time start undercurrent 25 ms typically at 0 to 2 x Iset -

See table 98 and table 99 Parameter ranges for customerdefined characteristic no 17:k: 0.05 - 999.00A: 0.0000 - 999.0000B: 0.0000 - 99.0000C: 0.0000 - 1.0000P: 0.0001 - 10.0000PR: 0.005 - 3.000TR: 0.005 - 600.000CR: 0.1 - 10.0

See table 98 and table 99


66 ABB

Table 54. General current and voltage protection (GAPC), continued


Voltage level where voltagememory takes over

(0.0 - 5.0)% of Ubase ± 1.0% of Ur

Start overvoltage, step 1 and 2 (2.0 - 200.0)% of Ubase ± 1.0% of Ur for U<Ur

± 1.0% of U for U>Ur

Start undervoltage, step 1and 2

(2.0 - 150.0)% of Ubase ± 1.0% of Ur for U<Ur


Operate time, startovervoltage

25 ms typically at 0 to 2 x Uset -

Reset time, start overvoltage 25 ms typically at 2 to 0 x Uset -

Operate time startundervoltage

25 ms typically 2 to 0 x Uset -

Reset time start undervoltage 25 ms typically at 0 to 2 x Uset -

High and low voltage limit,voltage dependent operation

(1.0 - 200.0)% of Ubase ± 1.0% of Ur for U<Ur


Directional function Settable: NonDir, forward andreverse

-

Relay characteristic angle (-180 to +180) degrees ± 2.0 degrees

Relay operate angle (1 to 90) degrees ± 2.0 degrees

Reset ratio, overcurrent > 95% -

Reset ratio, undercurrent < 105% -

Reset ratio, overvoltage > 95% -

Reset ratio, undervoltage < 105% -

Overcurrent:



Undercurrent:



Overvoltage:




ABB 67

Table 54. General current and voltage protection (GAPC), continued


Undervoltage:




Table 55. Current circuit supervision CCSRDIF


Operate current (5-200)% of Ir ± 10.0% of Ir at I £ Ir± 10.0% of I at I > Ir

Block current (5-500)% of Ir ± 5.0% of Ir at I £ Ir± 5.0% of I at I > Ir

Table 56. 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 ± 1.0% 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


68 ABB

Control

Table 57. Synchronizing, synchrocheck and energizing check SESRSYN


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

Voltage ratio, Ubus/Uline (0.40-25.000) % of UBase -

Voltage high limit for synchronizingand synchrocheck

(50.0-120.0)% of UBase ± 1.0% of Ur at U ≤ Ur

± 1.0% of U at U >Ur

Reset ratio, synchrocheck > 95% -

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

(2.0-50.0)% of UBase ± 1.0% of Ur

Time delay output for synchrocheck (0.000-60.000) s ± 0.5% ± 10 ms

Voltage high limit for energizingcheck

(50.0-120.0)% of UBase ± 1.0% of Ur at U ≤ Ur


Reset ratio, voltage high limit > 95% -

Voltage low limit for energizingcheck

(10.0-80.0)% of UBase ± 1.0% of Ur

Reset ratio, voltage low limit < 105% -

Maximum voltage for energizing (50.0-180.0)% of UBase ± 1.0% of Ur at U ≤ Ur


Time delay for energizing check (0.000-60.000) s ± 0.5% ± 10 ms

Operate time for synchrocheckfunction

160 ms typically -

Operate time for energizing function 80 ms typically -


ABB 69

Table 58. Autorecloser SMBRREC


Number of autoreclosing shots 1 - 5 -

Number of autoreclosing programs 8 -

Autoreclosing open time:shot 1 - t1 1Phshot 1 - t1 2Phshot 1 - t1 3PhHSshot 1 - t1 3PhDld

(0.000-60.000) s

± 0.5% ± 10 ms

shot 2 - t2shot 3 - t3shot 4 - t4shot 5 - t5

(0.00-6000.00) s

Extended autorecloser open time (0.000-60.000) s

Autorecloser maximum wait time for sync (0.00-6000.00) s

Maximum trip pulse duration (0.000-60.000) s

Inhibit reset time (0.000-60.000) s

Reclaim time (0.00-6000.00) s

Minimum time CB must be closed before ARbecomes ready for autoreclosing cycle

(0.00-6000.00) s

Circuit breaker closing pulse length (0.000-60.000) s

CB check time before unsuccessful (0.00-6000.00) s

Wait for master release (0.00-6000.00) s

Wait time after close command beforeproceeding to next shot

(0.000-60.000) s


70 ABB


Table 59. Scheme communication logic for distance or overcurrent protection ZCPSCH


Scheme type IntertripPermissive UnderreachPermissive OverreachBlocking

-

Co-ordination time forblocking communicationscheme

(0.000-60.000) s ± 0.5% ± 10 ms

Minimum duration of a sendsignal

(0.000-60.000) s ± 0.5% ± 10 ms

Security timer for loss ofguard signal detection

(0.000-60.000) s ± 0.5% ± 10 ms

Operation mode ofunblocking logic

OffNoRestartRestart

-

Table 60. Phase segregated scheme communication logic for distance protection (PSCH,85)


Scheme type IntertripPermissive URPermissive ORBlocking

-

Co-ordination time forblocking communicationscheme

(0.000-60.000) s ± 0.5% ± 10 ms

Minimum duration of acarrier send signal

(0.000-60.000) s ± 0.5% ± 10 ms

Security timer for loss ofcarrier guard detection

(0.000-60.000) s ± 0.5% ± 10 ms

Operation mode ofunblocking logic

OffNoRestartRestart

-


ABB 71

Table 61. Current reversal and weak-end infeed logic for distance protectionZCRWPSCH


Detection level phase-to-neutral voltage

(10-90)% of UBase ± 1.0% of Ur

Detection level phase-to-phase voltage

(10-90)% of UBase ± 1.0% of Ur

Reset ratio <105% -

Operate time for currentreversal logic

(0.000-60.000) s ± 0.5% ± 10 ms

Delay time for currentreversal

(0.000-60.000) s ± 0.5% ± 10 ms

Coordination time forweak-end infeed logic

(0.000-60.000) s ± 0.5% ± 10 ms

Table 62. Scheme communication logic for residual overcurrent protection ECPSCH


Scheme type Permissive UnderreachingPermissive OverreachingBlocking

-

Communication schemecoordination time

(0.000-60.000) s ± 0.5% ± 10 ms

Table 63. Current reversal and weak-end infeed logic for residual overcurrent protectionECRWPSCH


Operating mode of WEIlogic

OffEchoEcho & Trip

-

Operate voltage 3Uo for

WEI trip

(5-70)% of UBase ± 1.0% of Ur

Reset ratio >95% -

Operate time for currentreversal logic

(0.000-60.000) s ± 0.5% ± 10 ms


(0.000-60.000) s ± 0.5% ± 10 ms


(0.000–60.000) s ± 0.5% ± 10 ms


72 ABB

Table 64. Current reversal and weak-end infeed logic for phase segregatedcommunication (PSCH, 85)


Detection level phase toneutral voltage

(10-90)% of Ubase ± 1.0% of Ur

Detection level phase tophase voltage

(10-90)% of Ubase ± 1.0% of Ur

Reset ratio <105% -

Operate time for currentreversal

(0.000-60.000) s ± 0.5% ± 10 ms


(0.000-60.000) s ± 0.5% ± 10 ms


(0.000-60.000) s ± 0.5% ± 10 ms

Logic

Table 65. Tripping logic SMPPTRC


Trip action 3-ph, 1/3-ph, 1/2/3-ph -

Minimum trip pulse length (0.000-60.000) s ± 0.5% ± 10 ms

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


ABB 73

Table 66. Configurable logic blocks

Logic block Quantity with cycle time Range or value Accuracy

fast medium normal

LogicAND 60 60 160 - -

LogicOR 60 60 160 - -

LogicXOR 10 10 20 - -

LogicInverter 30 30 80 - -

LogicSRMemory 10 10 20 - -

LogicGate 10 10 20 - -

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

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

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

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

Monitoring

Table 67. Measurements CVMMXN


Frequency (0.95-1.05) × fr ± 2.0 mHz

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< U < 1.5 x Ur

0.2 x Ir < I < 4.0 x Ir

± 1.0% of Sr at S ≤ Sr

± 1.0% of S at S > Sr

Reactive power, Q 0.1 x Ur< U < 1.5 x Ur

0.2 x Ir < I < 4.0 x Ir


± 1.0% of S at S > Sr

Apparent power, S 0.1 x Ur < U < 1.5 x Ur

0.2 x Ir< I < 4.0 x Ir


± 1.0% 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


74 ABB

Table 68. Supervision of mA input signals (MVGGIO)


mA measuring function ± 5, ± 10, ± 20 mA0-5, 0-10, 0-20, 4-20 mA

± 0.1 % of set value ± 0.005 mA

Max current oftransducer to input

(-20.00 to +20.00) mA

Min current oftransducer to input

(-20.00 to +20.00) mA

Alarm level for input (-20.00 to +20.00) mA

Warning level for input (-20.00 to +20.00) mA

Alarm hysteresis forinput

(0.0-20.0) mA

Table 69. Event counter CNTGGIO


Counter value 0-10000 -

Max. count up speed 10 pulses/s -


ABB 75

Table 70. Disturbance report DRPRDRE


Pre-fault time (0.05–1.00) s -

Post-fault time (0.1–10.0) s -

Limit time (0.5–10.0) s -

Maximum number of recordings 100 -

Time tagging resolution 1 ms See table 94

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 -

Table 71. Fault locator LMBRFLO

Function Value or range Accuracy

Reactive and resistivereach

(0.001-1500.000) Ω/phase ± 2.0% static accuracy± 2.0% degrees static angularaccuracyConditions:Voltage range: (0.1-1.1) x Ur

Current range: (0.5-30) x Ir

Phase selection According to input signals -

Maximum number of faultlocations

100 -


76 ABB

Table 72. Event list

Function Value

Buffer capacity Maximum number of events inthe list

1000

Resolution 1 ms

Accuracy Depending on timesynchronizing

Table 73. Indications

Function Value

Buffer capacity Maximum number of indications presentedfor single disturbance

96

Maximum number of recorded disturbances 100

Table 74. Event recorder

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 75. Trip value recorder

Function Value

Buffer capacity

Maximum number of analog inputs 30



ABB 77

Table 76. Disturbance recorder

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

Metering

Table 77. Pulse counter PCGGIO

Function Setting range Accuracy

Input frequency See Binary Input Module (BIM) -

Cycle time for report ofcounter value

(1–3600) s -

Table 78. Energy metering ETPMMTR


Energy metering kWh Export/Import,kvarh Export/Import

Input from MMXU. No extra errorat steady load


Table 79. IEC 61850-8-1 communication protocol

Function Value

Protocol IEC 61850-8-1

Communication speed for the IEDs 100BASE-FX

Table 80. LON communication protocol

Function Value

Protocol LON

Communication speed 1.25 Mbit/s


78 ABB

Table 81. SPA communication protocol

Function Value

Protocol SPA

Communication speed 300, 1200, 2400, 4800, 9600, 19200 or 38400 Bd

Slave number 1 to 899

Table 82. IEC 60870-5-103 communication protocol

Function Value

Protocol IEC 60870-5-103

Communication speed 9600, 19200 Bd

Table 83. SLM – LON port

Quantity Range or value

Optical connector Glass fibre: type STPlastic fibre: type HFBR snap-in

Fibre, optical budget Glass fibre: 11 dB (1000 m typically *)Plastic fibre: 7 dB (10 m typically *)

Fibre diameter Glass fibre: 62.5/125 mmPlastic fibre: 1 mm

*) depending on optical budget calculation

Table 84. SLM – SPA/IEC 60870-5-103 port


Optical connector Glass fibre: type STPlastic fibre: type HFBR snap-in

Fibre, optical budget Glass fibre: 11 dB (3000ft/1000 m typically *)Plastic fibre: 7 dB (80ft/25 m typically *)

Fibre diameter Glass fibre: 62.5/125 mmPlastic fibre: 1 mm

*) depending on optical budget calculation


ABB 79

Table 85. Galvanic X.21 line data communication module (X.21-LDCM)


Connector, X.21 Micro D-sub, 15-pole male, 1.27 mm (0.050") pitch

Connector, ground selection 2 pole screw terminal

Standard CCITT X21

Communication speed 64 kbit/s

Insulation 1 kV

Maximum cable length 100 m

Table 86. Galvanic RS485 communication module


Communication speed 2400–19200 bauds

External connectors RS-485 6-pole connectorSoft ground 2-pole connector



80 ABB

Table 87. Line data communication module

Characteristic Range or value

Type of LDCM Short range(SR)

Medium range(MR)

Long range (LR)

Type of fibre Graded-indexmultimode62.5/125 µmor 50/125 µm

Singlemode9/125 µm

Singlemode 9/125 µm

Wave length 850 nm 1310 nm 1550 nm

Optical budgetGraded-index multimode62.5/125 mm, Graded-index multimode50/125 mm

13 dB (typicaldistanceabout 3 km *)9 dB (typicaldistanceabout 2 km *)

22 dB (typicaldistance 80 km *)

26 dB (typical distance110 km *)

Optical connector Type ST Type FC/PC Type FC/PC

Protocol C37.94 C37.94implementation**)

C37.94 implementation **)

Data transmission Synchronous Synchronous Synchronous

Transmission rate / Data rate 2 Mb/s / 64kbit/s

2 Mb/s / 64 kbit/s

2 Mb/s / 64 kbit/s

Clock source Internal orderived fromreceivedsignal

Internal orderived fromreceived signal

Internal or derived fromreceived signal

*) depending on optical budget calculation**) C37.94 originally defined just for multimode; using same header, configuration and dataformat as C37.94

Hardware


ABB 81

IED

Table 88. Case

Material Steel sheet

Front plate Steel sheet profile with cut-out for HMI

Surface treatment Aluzink preplated steel

Finish Light grey (RAL 7035)

Table 89. Water and dust protection level according to IEC 60529

Front IP40 (IP54 with sealing strip)

Rear, sides, topand bottom

IP20

Table 90. Weight

Case size Weight

6U, 1/2 x 19” £ 10 kg

6U, 3/4 x 19” £ 15 kg

6U, 1/1 x 19” £ 18 kg

Connection system

Table 91. CT and VT circuit connectors

Connector type Rated voltage andcurrent

Maximum conductorarea

Terminal blocks of feed throughtype

250 V AC, 20 A 4 mm2

Terminal blocks suitable for ringlug terminals

250 V AC, 20 A 4 mm2

Table 92. Binary I/O connection system

Connector type Rated voltage Maximum conductorarea

Screw compression type 250 V AC 2.5 mm2

2 × 1 mm2

Terminal blocks suitable for ringlug terminals

300 V AC 3 mm2


82 ABB

Basic IED functions

Table 93. Self supervision with internal event list

Data Value

Recording manner Continuous, event controlled

List size 1000 events, first in-first out

Table 94. Time synchronization, time tagging

Function Value

Time tagging resolution, events and sampled measurement values 1 ms

Time tagging error with synchronization once/min (minute pulsesynchronization), events and sampled measurement values

± 1.0 ms typically

Time tagging error with SNTP synchronization, sampledmeasurement values

± 1.0 ms typically

Table 95. GPS time synchronization module (GSM)


Receiver – ±1µs relative UTC

Time to reliable time reference withantenna in new position or after powerloss longer than 1 month

<30 minutes –

Time to reliable time reference after apower loss longer than 48 hours

<15 minutes –

Time to reliable time reference after apower loss shorter than 48 hours

<5 minutes –

Table 96. GPS – Antenna and cable

Function Value

Max antenna cable attenuation 26 db @ 1.6 GHz

Antenna cable impedance 50 ohm

Lightning protection Must be provided externally

Antenna cable connector SMA in receiver endTNC in antenna end


ABB 83

Table 97. IRIG-B

Quantity Rated value

Number of channels IRIG-B 1

Number of channels PPS 1

Electrical connector IRIG-B BNC

Optical connector PPS and IRIG-B Type ST

Type of fibre 62.5/125 μm multimode fibre

Inverse characteristic

Table 98. ANSI Inverse time characteristics


Operating characteristic:

( )1= + ×

-

æ öç ÷ç ÷è ø

P

At B k

I

EQUATION1249-SMALL V1 EN

Reset characteristic:

( )2 1= ×

-

trt kI


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 , tr=29.1 ANSI/IEEE C37.112,class 5 + 30 ms

ANSI Very inverse A=19.61, B=0.491, P=2.0 , tr=21.6

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, tr=4.85

ANSI Long Time ExtremelyInverse

A=64.07, B=0.250, P=2.0, tr=30

ANSI Long Time Very Inverse A=28.55, B=0.712, P=2.0, tr=13.46

ANSI Long Time Inverse k=(0.05-999) in steps of 0.01A=0.086, B=0.185, P=0.02, tr=4.6


84 ABB

Table 99. IEC Inverse time characteristics


Operating characteristic:

( )1= ×

-


P

At k

I


I = Imeasured/Iset

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

Time delay to reset, IEC inversetime

(0.000-60.000) s ± 0.5% of set time ±10 ms

IEC Normal Inverse A=0.14, P=0.02 IEC 60255-3, 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

Programmable characteristicOperate characteristic:

( )= + ×

-


P

At B k

I C


Reset characteristic:

( )= ×

-PR

TRt k

I CR


I = Imeasured/Iset

k = (0.05-999) in steps of 0.01A=(0.005-200.000) in steps of 0.001B=(0.00-20.00) in steps of 0.01C=(0.1-10.0) in steps of 0.1P=(0.005-3.000) in steps of 0.001TR=(0.005-100.000) in steps of 0.001CR=(0.1-10.0) in steps of 0.1PR=(0.005-3.000) in steps of 0.001

IEC 60255, class 5 +40 ms


ABB 85

Table 100. 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 60255-3, 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 60255-3, class 5+ 40 ms


86 ABB

Table 101. Inverse time characteristics for Two step undervoltage protection (PUVM, 27)


Type A curve:

=< -

<

æ öç ÷è ø

kt

U U

U

EQUATION1431-SMALL V1 EN (Equation 4)

U< = Uset

U = UVmeasured

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

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

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

Programmable curve:

×= +

< -× -

<

é ùê úê úê úæ öê úç ÷ë è ø û

P

k At D

U UB C

U


U< = Uset

U = Umeasured

k = (0.05-1.10) in steps of0.01A = (0.005-200.000) in stepsof 0.001B = (0.50-100.00) in steps of0.01C = (0.0-1.0) in steps of 0.1D = (0.000-60.000) in stepsof 0.001P = (0.000-3.000) in steps of0.001


ABB 87

Table 102. Inverse time characteristics for Two step overvoltage protection (POVM, 59)


Type A curve:

=- >

>

æ öç ÷è ø

tk

U U

U


U> = Uset

U = Umeasured

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

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) in steps of0.01

Type C curve:

3.0

480

32 0.5 0.035

=×

- >× - -

>

æ öç ÷è ø

tk

U U

U


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

Programmable curve:

×= +

- >× -

>

æ öç ÷è ø

P

k At D

U UB C

U


k = (0.05-1.10) in steps of0.01A = (0.005-200.000) in stepsof 0.001B = (0.50-100.00) in steps of0.01C = (0.0-1.0) in steps of 0.1D = (0.000-60.000) in stepsof 0.001P = (0.000-3.000) in steps of0.001


88 ABB

Table 103. Inverse time characteristics for Two step residual overvoltage protection(POVM, 59N)


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

Programmable curve:

×= +

- >× -

>

æ öç ÷è ø

P

k At D

U UB C

U


k = (0.05-1.10) insteps of 0.01A = (0.005-200.000)in steps of 0.001B = (0.50-100.00) insteps of 0.01C = (0.0-1.0) insteps of 0.1D = (0.000-60.000)in steps of 0.001P = (0.000-3.000) insteps of 0.001


ABB 89

8. 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: RED670*1.1-A31-A03B01C04F01-X0-A-A-B-A-A6X0-DAS-AA-XD. Using the code of each position #1-12 specified asRED670*1-2 2-3 3 3 3 3 3 3 3-4 4-5-6-7 7-8-9 9 9-10 10 10 10 10 10 10 10 10 10 10-11 11 11 11 11 11-12 12

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

RED670* - - - - - . - -

- 10 - 11 - 12

- . -

Posi

tion

SOFTWARE #1 Notes and Rules

Version number

Version no 1.1

Selection for position #1.

Configuration alternatives #2 Notes and Rules

Single breaker, 3-phase tripping A31

Multi breaker, 3-phase tripping B31

Single breaker, 1-phase tripping A32

Multi breaker, 1-phase tripping B32

ACT configuration

ABB standard configuration X00



90 ABB

Software options #3 Notes and Rules

No option X00 All fields in the ordering form donot need to be filled in

High impedance differentialprotection

A02

Line differential protecion 6 CT sets,3-5 line ends

A04 Note: Only one Line differentialprotection have to be selectedNote: A04/A05 only in A31/A32 Line differential protecion 3 CT sets,

with in-zone transformers, 2-3 lineends

A05

Line differential protecion 6 CT sets,with in-zone transformers, 3-5 lineends

A06

Line distance protection B01 Note: Only one Line distanceprotection, B01/B06/B07, can beselected

Power swing logic B03

Phase segregated schemecommunication

B05 Note: Only for A32/B32

Line distance protection,quadrilateral series compensationlines, 3 zones

B06

Line distance protection mho, 3 zones B07

Pole slip detection B21

Residual overcurrent proteciton C04

Sensitive directional residualovercurrent and power protection

C16

Directional power protection C17

Overexcitation protection D03

Frequency protections - line E02

General current and voltageprotection

F01

Autorecloser, 1 circuit breaker H04 Note: H04 only for A31/A32

Autorecloser, 2 circuit breaker H05 Note: H05 only for B31/B32

Apparatus control 8 objects H07 Note: Only one Apparatuscontrol can be orderedNote: H07 only for A31/A32,H08 only for B31/B32

Apparatus control 15 objects H08

Selection for postition #3

First HMI language #4 Notes and Rules

HMI language, English IEC B1

HMI language, English US B2

Additional HMI language

No second HMI language X0

German A1

Russian A2

French A3

Spanish A4

Italian A5

Polish A6

Hungarian A7

Czech A8

Swedish A9



ABB 91

Casing #5 Notes and Rules

1/2 x 19" case A Note: Only 1/2 case for A31/A32

3/4 x 19" case 2 TRM slots C

1/1 x 19" case 2 TRM slots E


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

No mounting kit included X

19" rack mounting kit for 1/2 x 19" case of 2xRHGS6 or RHGS12 A Note: Only for A31/A32

19" rack mounting kit for 3/4 x 19" case or 3xRGHS6 B

19" rack mounting kit for 1/1 x 19" case C

Wall mounting kit D

Flush mounting kit E

Flush mounting kit + IP54 mounting seal F


Connection type for Power supply, Input/output and Communication modules #7 Notes and Rules

Compression terminals K

Auxiliary power supply

24-60 VDC A

90-250 VDC B


Human machine interface #8 Notes and Rules

Small size - text only, IEC symbols A

Medium size - graphic display, IEC symbols B

Medium size - graphic display, ANSI symbols C


Connection type for Analog modules #9 Notes and Rules

Compression terminals A

Ringlug terminals B

Analog system

First TRM, 6I+6U 1A, 100/220V 6

First TRM, 6I+6U 5A, 100/220V 7

First TRM, 3I, 5A + 3I, 1A + 6U, 100/220V 16 Note: Only for A31/A32

No second TRM included X0

Second TRM, 9I+3U 1A, 110/220V 3


Second TRM, 5I, 1A+4I, 5A+3U, 110/220V 5



Second TRM, 6I, 1A, 110/220V 8

Second TRM, 6I, 5A, 110/220V 9

Second TRM, 7I+5U 1A, 110/220V 12

Second TRM, 7I+5U 5A, 110/220V 13

Second TRM, 3I, 5A + 3I, 1A + 6U, 100/220V 16 Note: Only for A31/A32



92 ABB

Binary input/output module, mAand time synchronizating boards.Note: 1BIM and 1 BOM included InA31/A32/B31/B32, 1 IOM basic inA21.

#10 Notes and Rules

Slot position (rear view)

X31

X41

X51

X61

X71

X81

X91

X10

1

X11

1

X12

1

X13

1 Note: Max 3 positions in 1/2rack, 5 in 3/4 rack with 2 TRMand 11 in 1/1 rack with 2 TRM

1/2 Case with 1 TRM Note: Only 1/2 case for A31/A32

3/4 Case with 2 TRM

1/1 Case with 2 TRM

No board in slot X X X X X X X X X

Binary output module 24 outputrelays (BOM)

A A A A A A A A A A Note: Maximum 4 (BOM+SOM+MIM) boards.

BIM 16 inputs, RL24-30 VDC B B B B B B B B B B Note: Select BIM in pos X31

BIM 16 inputs, RL48-60 VDC C C C C C C C C C C

BIM 16 inputs, RL110-125 VDC D D D D D D D D D D

BIM 16 inputs, RL220-250 VDC E E E E E E E E E E

BIMp 16 inputs, RL24-30 VDC forpulse counting

F F F F F F F F F


G G G G G G G G G


H H H H H H H H H


K K K K K K K K K

IOM 8 inputs, 10+2 output, RL24-30VDC

L L L L L L L L L

IOM 8 inputs, 10+2 output, RL48-60VDC

M M M M M M M M M

IOM 8 inputs, 10+2 output,RL110-125 VDC

N N N N N N N N N

IOM 8 inputs, 10+2 output,RL220-250 VDC

P P P P P P P P P

IOM with MOV 8 inputs, 10-2output, 24-30 VDC

U U U U U U U U U


V V V V V V V V V


W W W W W W W W W


Y Y Y Y Y Y Y Y Y

mA input module MIM 6 channels R R R R R R R R Note: Max 4 (BOM+SOM+MIM)board in 1/1 case. Max 1 MIM+3BOM in 3/4 case. No MIM boardin 1/2 case

GPS time synchronization module(in last slot)

S S S

SOM Static outputs module, 12outputs, 48-60 VDC

T1 T1 T1 T1 T1 T1 T1 T1 T1 Note: Max 4 (BOM+SOM+MIM)board.

SOM static outputs module, 12outputs, 110-250 VDC

T2 T2 T2 T2 T2 T2 T2 T2 T2



ABB 93

Remote end communication, DNP serial comm.and time synchronization modules

#11 Notes and Rules


X31

2

X31

3

X30

2

X30

3

X32

2

X32

3

Available slots in 1/2 case with 1TRM Note: Only for A31/A32. 1 LDCMin A31/A32. Max 1 LDCM

Available slots in 3/4 & 1/1 case with 2 TRM Note: Generally max 4 LDCM butpower dissipation may limit thequantity.

No remote communication board included X X X X X

Optical short range LDCM A A A A A A

Optical medium range, LDCM 1310 nm B B B B B B

Optical long range, LDCM 1550 nm C C C C C C

Galvanic X21 line data communication module E E E E E E

IRIG-B Time synchronization module, with PPS F

Galvanic RS485 communication module G G G Note: No RS485 in position X313in B31/B32


Serial communication unit for station communication #12 Notes and Rules


X30

1

X31

1

No first communication board included X

No second communication board included X

Serial and LON communication module (plastic) A Note: Optical ethernet module, 2glass interfaces is not allowedtogether with SLM.

Serial (plastic) and LON (glass) communication module B

Serial and LON communication module (glass) C

Optical ethernet module, 1 glass interface D

Optical ethernet module, 2 glass interfaces E


Guidelines

Carefully read and follow the set of rules to ensure problem-free order management. Be aware that certainfunctions can only be ordered in combination with other functions and that some functions require specifichardware selections.

Basic hardware and functions

Manuals on CD

Operator’s manual (English)

Installation and commissioning manual (English)

Technical reference manual (English)

Application manual (English)

Getting started guide (English)


94 ABB

Basic IED functions

Self-supervision with internal event list

Time and synchronization error

Time synchronization

Parameter setting groups

Test mode functionality

Change lock function

IED Identifiers

Product information

Misc Base common

IED Runtime comp

Rated system frequency

Signal Matrix for binary inputs

Signal Matrix for binary outputs

Signal Matrix for mA inputs

Signal Matrix for analog inputs

Summation block 3 phase

Parameter setting function for HMI in PCM 600

Local HMI signals

Authority status

Authority check

FTP access with password

SPA communication mapping

Hardware

Numeric processing module

Accessories

GPS antenna and mounting details

GPS antenna, including mounting kits Quantity: 1MRK 001 640-AA

Cable for antenna, 20 m Quantity: 1MRK 001 665-AA

Cable for antenna, 40 m Quantity: 1MRK 001 665-BA


ABB 95

Interface converter (for remote end data communication)

External interface converter from C37.94 to G703 including1U 19” rack mounting accessories

Quantity: 1 2 3 4 1MRK 002 245-AA

External interface converter from C37.94 to G703.E1 Quantity: 1 2 3 4 1MRK 002 245-BA

Test switch

The test system COMBITEST intended for usewith the IED 670 products is described in1MRK 512 001-BEN and 1MRK 001024-CA.Please refer to the website: www.abb.com/substationautomation and ABB ProductGuide > High Voltage Products > Protectionand Control > Modular Relay > TestEquipment for detailed information. When FTswitches are considered, please refer to thewebsite:www.abb.com>ProductGuide>MediumVoltage Products>Protection and Control(Distribution) for detailed information.

Due to the high flexibility of our product andthe wide variety of applications possible thetest switches needs to be selected for eachspecific application.

Select your suitable test switch base on theavailable contacts arrangements shown in thereference documentation.

However our proposal for suitable variants are;

Single breaker/Single or Three Phase tripwith internal neutral on current circuits(ordering number RK926 315-AK).

Single breaker/Single or Three Phase tripwith external neutral on current circuits(ordering number RK926 315-AC).

Multi-breaker/Single or Three Phase trip withinternal neutral on current circuits (orderingnumber RK926 315-BE).

Multi-breaker/Single or Three Phase trip withexternal neutral on current circuit (orderingnumber RK926 315-BV).

The normally open "In test mode" contact29-30 on the RTXP test switches should beconnected to the input of the test functionblock to allow activation of functionsindividually during testing.

Test switches type RTXP 24 are orderedseparately. Please refer to Section "Relateddocuments" for reference to correspondingdocuments.

RHGS 6 Case or RHGS 12 Case with mountedRTXP 24 and the on/off switch for dc-supplyare ordered separately. Please refer to Section"Related documents"for reference tocorresponding documents.

Protection cover

Protective cover for rear side of RHGS6, 6U, 1/4 x 19” Quantity: 1MRK 002 420-AE

Protective cover for rear side of IED, 6U, 1/2 x 19” Quantity: 1MRK 002 420-AC

Protective cover for rear side of IED, 6U, 3/4 x 19” Quantity: 1MRK 002 420-AB

Protective cover for rear side of IED, 6U, 1/1 x 19” Quantity: 1MRK 002 420-AA


96 ABB

External resistor unit for high impedance differential protection

High impedance resistor unit 1-ph with resistor 1.8 kOhms andvoltage dependent resistor for 20-100V operating voltage

Quantity: 1 2 3 RK795101-MA


Quantity: RK795101-MB


Quantity: 1 2 3 RK795101-CB


Quantity: RK795101-DC

Combiflex

Key switch for lock-out of settings via LCD-HMI Quantity: 1MRK 000 611-A

Note: To connect the key switch, leads with 10 A Combiflex socket on one end must be used.

Side-by-side mounting kit Quantity: 1MRK 002 420-Z

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

Manuals

Note: One (1) IED Connect CD containing user documentation (Operator’s manual, Technical referencemanual, Installation and commissioning manual, Application manual and Getting started guide),Connectivity packages and LED label template is always included for each IED.

Rule: Specify additional quantity of IED Connect CD requested. Quantity: 1MRK 002 290-AB


ABB 97

User documentation

Rule: Specify the number of printed manuals requestedOperator’s manual

IEC Quantity: 1MRK 505 184-UEN

ANSI Quantity: 1MRK 505 184-UUS

Technical reference manual IEC Quantity: 1MRK 505 183-UEN


Installation and commissioning manual IEC Quantity: 1MRK 505 185-UEN


Application manual IEC Quantity: 1MRK 505 186-UEN


Engineering guide IED 670 products Quantity: 1MRK 511 179-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


98 ABB

Related documents

Documents related to RED670 Identity number

Operator’s manual 1MRK 505 184-UEN

Installation and commissioning manual 1MRK 505 185-UEN

Technical reference manual 1MRK 505 183-UEN

Application manual 1MRK 505 186-UEN

Buyer’s guide 1MRK 505 188-BEN

Sample specification SA2005-001281

Connection diagram, Single breaker arr. Three phase tripping arr. 1MRK 002 801-BA

Connection diagram, Single breaker arr. Single phase tripping arr. 1MRK 002 801-CA

Connection diagram, Multi breaker arr. Three phase tripping arr. 1MRK 002 801-DA

Connection diagram, Multi breaker arr. Single phase tripping arr. 1MRK 002 801-EA

Setting example 1, 230 kV Short cable line with 1 1/2CB arr. 1MRK 505 175-WEN

Connection and Installation components 1MRK 513 003-BEN

Test system, COMBITEST 1MRK 512 001-BEN

Accessories for IED 670 1MRK 514 012-BEN

Getting started guide IED 670 1MRK 500 080-UEN

SPA and LON signal list for IED 670, ver. 1.1 1MRK 500 083-WEN

IEC 61850 Data objects list for IED 670, ver. 1.1 1MRK 500 084-WEN

Engineering guide IED 670 products 1MRK 511 179-UEN

Communication set-up for RED 670 Differential protection and 670 series 1MRK 505 197-UEN

More information can be found on www.abb.com/substationautomation.


ABB 99

HTTP://WWW.ABB.COM/SUBSTATIONAUTOMATION

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

1MR

K 5

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