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Page 1

Buyer's GuideLine differential protection IEDRED 670 Pre-configured

1MRK 505164-BENRevision: G

Issued: February 2007Data subject to change without notice

Features Four configuration alternatives for single- ormulti-breaker arrangements available ready toconnect

For overhead lines and cables

For transformer feeders

For single and/or three phase tripping

High impedance differential protection fortee-feeders

Phase-segregated line differential protectionwith up to six stabilized inputs for up to five lineterminals with:

- Charging current compensation- Separate inputs for each CT in double

breaker, ring and one and a half breakerinstallations for improved through fault stabil-ity

- Suitable for multiplexed, route switched, aswell as dedicated fibre, communication net-works using C37.94 protocol

- Power transformers can be included in theprotected zone

- Transfer of up to eight binary signals- Time synchronization with the echo-method

or built-in GPS Full scheme phase-to-phase and phase-to-earth

distance protection with up to three zones:

- All types of scheme communication- Load encroachment feature

Synchrocheck and dead-line check function forsingle- or multi-breaker arrangements:

- Selectable energizing direction- Two functions with built-in voltage selection

- For automatic or manual synchrocheck andwith different settings

Auto-reclosing function for single- two-, and/orthree-phase reclosing:

- Two functions with priority circuits formulti-breaker arrangements

- Co-operation with synchrocheck function- Can be switched On-Off from remote through

communication or with local switches throughbinary inputs

Selectable additional software functions such asdistance protection, control and monitoring

Built-in data communication modules for stationbus IEC 61850-8-1

Data communication modules for station busIEC 60870-5-103, LON and SPA

Integrated disturbance and event recorder for upto 40 analog and 96 binary signals

Time synchronization over IEC 61850-8-1, LON,SPA, binary input or with optional GPS module

Analog measurements accuracy up to below0.5% for power and 0.25% for current and volt-age and with site calibration to optimize total

accuracy Versatile local human-machine interface

Extensive self-supervision with internal eventrecorder

Six independent groups of complete settingparameters with password protection

Powerful software PC tool for setting, distur-bance evaluation and configuration

Remote end data communication modules forC37.94 and G.703

Appl ication The RED 670 IED is used for the protection, con-trol and monitoring of overhead lines and cables inall types of networks. The IED can be used up tothe highest voltage levels. It is suitable for the pro-

tection of heavily loaded lines and multi-terminallines where the requirement for tripping is one-,two-, and/or three pole. The IED is also suitable


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Line differential protection IED RED 670 Buyer's GuidePre-configured

1MRK 505 164-BENRevision: G, Page 2

for protection of cable feeders to generator block transformers.

The phase segregated current differential protec-tion provides an excellent sensitivity for highresistive faults and gives a secure phase selection.The availability of six stabilized current inputsallows use on multi-breaker arrangements in threeterminal applications or up to five terminal appli-cations with single breaker arrangements. Remotecommunication based on the IEEE C37.94 stan-dard can be redundant when required for importantinstallations. Charging current compensationallows high sensitivity also on long overhead linesand cables. A full scheme distance protection isincluded as independent protection or as back-upat remote end communication failures. Eight chan-nels for intertrip and binary signals are available inthe communication between the IEDs.

The auto-reclose for single-, two- and/or three phase reclosing includes priority circuits for multi-breaker arrangements. It co-operates withthe synchrocheck function with high-speed or delayed reclosing.

High set instantaneous phase and earth overcur-rent, four step directional or un-directional delayed

phase and earth overcurrent, thermal overload and two step under and overvoltage functions areexamples of the available functions allowing theuser to fulfill any application requirement.

The IED can also be provided with a full control

and interlocking functionality including co-opera-tion with the synchrocheck function to allow inte-gration of the main or back-up control.

The advanced logic capability, where the user logic is prepared with a graphical tool, allows spe-cial applications such as automatic opening of dis-connectors in multi-breaker arrangements, closingof breaker rings, load transfer logics etc. The

graphical configuration tool ensures simple and fast testing and commissioning.

Serial data communication is via optical connec-tions to ensure immunity against disturbances.

The wide application flexibility makes this productan excellent choice for both new installations and the refurbishment of existing installations.

Four packages has been defined for followingapplications:

Single-breaker (double or single bus) withthree phase tripping (A31)

Single-breaker (double or single bus) with sin-gle 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 sin-

gle phase tripping (B32)

The packages are configured and set with basicfunctions active to allow direct use. Optional func-tions are not configured but a maximum configura-tion with all optional functions are available astemplate in the graphical configuration tool. Inter-face to analogue and binary IO are configurablefrom the Signal matrix tool without need of con-figuration changes. Analogue and tripping IO has

been pre-defined for basic use on the, as standard supplied one binary input module and one binary

output module. Add IO as required for your appli-cation at ordering. Other signals need to be applied as required for each application.

For details on included basic functions refer to sec-tion "Available functions".

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


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1MRK 505164-BENRevision: G, P age 3

Figure 1: The single breaker packages for single- and three phase tripping typical arrangement for oneprotection sub-system is shown here. The differential function is more sensitive than any earthfault or directional earth fault function and these functions are thus an option.

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

50/51


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Figure 2: The multi breaker packages for single- and three phase tripping typical arrangement for one pro-tection sub-system is shown here. The differential function is more sensitive than any earth faultor directional earth fault function and these functions are thus an option. Auto-reclose, Synchro-check and Breaker failure functions are included for each of the two breakers.

SC/VCO->I

I->O

CLOSE

TRIP

BUS A

87L

79 25

94/86

3I>

50BF

TRIP BUSBAR&CB2

3I>

50BF

SC/VCO->I

I->OC L O S E

T R I P

25

94/86

79

3Id/I>

CB1

CB2

TRIPCB1/3

en05000303.vsd TO REMOTE END:FIBRE OPTIC OR TO MUX

3U>

59

3U50/51


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Avail ablefunctions ANSI Func tio n descri pti on Single b reaker,

3-phase tripp ing(A31)

Multi breaker,

3-phase tripp ing(B31)

Singel breaker,

1-phase trip ping(A32)

Multi breaker,

1-phase trip ping(B32)B asic Option

(Qty/optiondesign)

Basic Option(Qty/optiondesign)



Differential protection

(Only one alternative can be selected)87 High impedance differential protection (PDIF) - 3/A02 - 3/A02 - 3/A02 - 3/A0287L Line differential protection, 3 CT sets, 2-3 line ends (PDIF) 1 - - - 1 - - -87L Line differential protection, 6 CT sets, 3-5 line ends (PDIF) - 1/A04 1 - - 1/A04 1 -87LT Line differential protection 3 CT sets, within-zone transformers,

2-3 line ends (PDIF)- 1/A05 - - - 1/A05 - -

87LT Line differential protection 6 CT sets, within-zone transformers,3-5 line ends (PDIF)

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

Distance protection21 Distance protection zones (PDIS) - 3/B01 - 3/B01 - 3/B01 - 3/B0121 Phase selection with load enchroachment (PDIS) - 1/B01 - 1/B01 - 1/B01 - 1/B01

Directional impedance (RDIR) 1/B01 1/B01 1/B01 1/B0178 Power swing detection (RPSB) - 1/B01 - 1/B01 - 1/B01 - 1/B01

Automatic switch onto fault logic (PSOF) - 1/B01 - 1/B01 - 1/B01 - 1/B01

Current protection50 Instantaneous phase overcurrent protection (PIOC) 1 - 1 - 1 - 1 -51/67 Four step phase overcurrent protection (POCM) 1 - 1 - 1 - 1 -50N Instantaneous residual overcurrent protection (PIOC) - 1/C04 - 1/C04 - 1/C04 - 1/C0451N/67N Four step residual overcurrent protection (PEFM) - 1/C04 - 1/C04 - 1/C04 - 1/C0426 Thermal overload protection, one time constant (PTTR) 1 - 1 - 1 - 1 -50BF Breaker failure protection (RBRF) 1 - 2 - 1 - 2 -

50STB Stub protection (PTOC) - - 1 - - - 1 -52PD Pole discordance protection (RPLD) - - - - 1 - 2 -

Voltage protection27 Two step undervoltage protection (PUVM) 1 - 1 - 1 - 1 -59 Two step overvoltage protection (POVM) 1 - 1 - 1 - 1 -59N Two step residual overvoltage protection (POVM) 1 - 1 - 1 - 1 -

Frequency pr otection81 Underfrequency protection (PTUF) - 2/E02 - 2/E02 - 2/E02 - 2/E0281 Overfrequency protection (PTOF) - 2/E02 - 2/E02 - 2/E02 - 2/E0281 Rate-of-change frequency protection (PFRC) - 2/E02 - 2/E02 - 2/E02 - 2/E02

Multipurpose protection

General current and voltage protection (GAPC) - 4/F01 - 4/F01 - 4/F01 - 4/F01

Secondary system supervisionCurrent circuit supervision (RDIF) 1 - 2 - 1 - 2 -Fuse failure supervision (RFUF) 3 - 3 - 3 - 3 -

Control25 Synchrocheck and energizing check (RSYN) 1 - 2 - 1 - 2 -79 Autorecloser (RREC) 1 - 2 - 1 - 2 -

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

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

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

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

Scheme communication85 Scheme communication logic for distance protection (PSCH) - 1/B01 - 1/B01 - 1/B01 - 1/B01


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Functionality Differential protection

High impedance differential protection(PDIF, 87)The high impedance differential protection can beused when the involved CT cores have same turnratio and similar magnetizing characteristic. It uti-lizes an external summation of the phases and neu-

tral current and a series resistor and a voltagedependent resistor externally to the relay.

Line differential protection, 3 or 6CT sets (PDIF, 87L)The line differential function compares the cur-rents entering and leaving the protected overhead line or cable. It offers phase-segregated true cur-rent differential protection with high sensitivityand provides phase selection information for sin-gle-pole tripping.

The three terminal version is used for conventionaltwo-terminal lines with or without 1 1/2 circuit

breaker arrangement in one end, as well as threeterminal lines with single breaker arrangements atall terminals.

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

85 Current reversal and weak-end infeed logic fordistanceprotection (PSCH)

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

Local acceleration logic (PLAL) - 1/B01 - 1/B01 - 1/B01 - 1/B0185 Scheme communication logic for

residualovercurrent protection (PSCH)- 1/C04 - 1/C04 - 1/C04 - 1/C04

85 Current reversal and weak-end infeed logic forresidualovercurrentprotection (PSCH)

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

Logic94 Tripping logic (PTRC) 1 - 2 - 1 - 2 -

Trip matrix logic (GGIO) 12 - 12 - 12 - 12 -

MonitoringMeasurements (MMXU) 3/10/3 - 3/10/3 - 3/10/3 - 3/10/3 -Event counter (GGIO) 5 - 5 - 5 - 5 -Disturbance report (RDRE) 1 - 1 - 1 - 1 -Fault locator (RFLO) 1 - 1 - 1 - 1 -

MeteringPulse counter logic (GGIO) 16 - 16 - 16 - 16 -

Station commu nicationIEC61850-8-1 Communication 1 - 1 - 1 - 1 -LON communication protocol 1 - 1 - 1 - 1 -SPA communication protocol 1 - 1 - 1 - 1 -IEC60870-5-103 communication protocol 1 - 1 - 1 - 1 -Single command, 16 signals 3 - 3 - 3 - 3 -Multiple command and transmit 60/10 - 60/10 - 60/10 - 60/10 -

Remote communicationBinary signal transfer 4 - 4 - 4 - 4 -

ANSI Func tio n descri pt ion Sing le br eaker,3-phase tripp ing(A31)

Multi breaker,3-phase tripp ing(B31)

Singel breaker,1-phase tripp ing(A32)

Multi breaker,1-phase trippi ng(B32)

Basic Option

(Qty/optiondesign)

Basic Option

(Qty/optiondesign)

Basic Option

(Qty/optiondesign)

Basic Option

(Qty/optiondesign)

en05000039.vsd

RED670

RED670

Protected zone

Comm. Channel


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The six terminal version is used for conventionaltwo-terminal lines with 1 1/2 circuit breaker

arrangements in both ends, as well as multi termi-nal lines with up to five terminals.

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

The current differential algorithm in RED 670 pro-vides high sensitivity for internal faults, at thesame time as it has excellent stability for externalfaults. Current samples from all CTs areexchanged between the IEDs in the line ends (mas-ter-master mode) or sent to one IED (master-slavemode) for evaluation.

A restrained dual biased slope evaluation is madewhere the bias current is the highest phase currentin any line end giving a secure through fault stabil-ity even with heavily saturated CTs. In addition to

the restrained evaluation, an unrestrained high dif-ferential current setting can be used for fast tripping of internal faults with very high currents.

A special feature with RED 670 is that applica-tions with small power transformers (rated currentless than 50% of differential current setting) con-nected as line taps without measurement in the tapcan be handled. The normal load current is here

considered to be negligible, and special measuresneed only to be taken in the event of a short circuiton the LV side of the transformer. In this applica-tion, the tripping of the differential protection can

be time delayed for low differential currents inorder to achieve coordination with down streamover current relays.

A line charging current compensation providesincreased sensitivity of the differential function.

Line differential protection 3 or 6 CT sets,

with in-zone transformers (PDIF, 87LT)One or two power transformers can be included inthe line differential protection zone. Both two- and three-winding transformers are correctly repre-sented with vector group compensations made inthe algorithm. The function includes 2 nd and 5 th harmonic restraint and zero sequence current elim-ination.

Figure 5: Example of application on a three-terminal line with a power transformer in the protection zone

Analog signal tr ansfer for line differential protection (MDIF)The line differential communication can bearranged as a master-master system or a mas-

ter-slave system alternatively. In the former, cur-rent samples are exchanged between all terminals,

and an evaluation is made in each terminal. Thismeans that a 64 kbit/s communication channel isneeded between every IED included in the sameline differential protection zone. In the latter, cur-

rent samples are sent from all slave IEDs to onemaster IED where the evaluation is made, and trip

Protected zone

Comm. Channel

en05000040.vsd

RED670

RED670

RED670

Comm. ChannelComm. Channel

RED670

RED670 RED670

Protected zone

Comm. Channel

Comm. Channel

Comm. Channel

en05000042.vsd


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signals are sent to the remote ends when needed. Inthis system, a 64 kbit/s communication channel is

only needed between the master, and each one of the slave terminals.

Figure 6: Five terminal line with master-master system

Figure 7: Five terminal line with master-slave system

Current samples from IEDs located geographicallyapart from each other, must be time coordinated sothat the current differential algorithm can be exe-cuted correctly. In RED 670 it is possible to makethis coordination in two different ways. The echomethod of time synchronizing is normally used whereas for applications where transmit and receive times can differ, the optional built in GPSreceivers shall be used.

The communication link is continuously moni-tored, and an automatic switchover to a standbylink is possible after a preset time.

Distance p rotection

Distance pro tection zones (PDIS, 21)The line distance protection is a three zone fullscheme protection with three fault loops for phaseto phase faults and three fault loops for phase toearth fault for each of the independent zones. Indi-vidual settings for each zone resistive and reactivereach gives flexibility for use on overhead linesand cables of different types and lengths.

The function has a functionality for load encroach-ment which increases the possibility to detect high

resistive faults on heavily loaded lines (seefigure 8).

Figure 8: Typical distance protection zone withload encroachment function activated

The independent measurement of impedance for each fault loop together with a sensitive and reli-

Protected zone

Comm.Channels

RED670

RED670

RED670

RED670

RED670

en05000043.vsd

RED670

Protected zone

Comm.Channels

RED670

RED670

en05000044.vsd

RED670

RED670

en05000034.vsd

R

X

Forwardoperation

Reverseoperation


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able built in phase selection makes the functionsuitable in applications with single phaseauto-reclosing.

Built-in adaptive load compensation algorithm prevents overreaching of zone1 at load exportingend at phase-to-earth faults on heavily loaded

power lines.

The distance protection zones can operate, independent of each other, in directional (forward or reverse) or non-directional mode. This makes themsuitable, together with different communicationschemes, for the protection of power lines and cables in complex network configurations, such as

parallel lines, multi-terminal lines etc.

Power swing detection (RPSB, 78)Power swings may occur after disconnection of heavy loads or trip of big generation plants.

Power swing detection function is used to detect power swings and initiate block of selected dis-tance protection zones. Occurrence of earth faultcurrents during a power swing can block the power swing detection function to allow fault clearance.

Automatic swit ch on to fault logic (PSOF)Automatic switch onto fault logic is a function thatgives an instantaneous trip at closing of breaker onto a fault. A dead line detection check is pro-vided to activate the function when the line isdead.

Current prot ection

Instantaneous phase overcurrentprot ection (PIOC, 50)The instantaneous three phase overcurrent functionhas a low transient overreach and short trippingtime to allow use as a high set short-circuit protec-tion function, with the reach limited to less thantypical eighty percent of the power line at mini-mum source impedance.

Four step phase overcurrentprotection (POCM, 51_67)The four step phase overcurrent function has aninverse or definite time delay independent for eachstep separately.

All IEC and ANSI time delayed characteristics areavailable together with an optional user defined time characteristic.

The function can be set to be directional or non-directional independently for each of thesteps.

Instantaneous residual overcurrentprotection (PIOC, 50N)The single input overcurrent function has a lowtransient overreach and short tripping times toallow use as a high set short circuit protectionfunction, with the reach limited to less than typical

eighty percent of the power line at minimumsource impedance. The function can be configured to measure the residual current from the three

phase current inputs or the current from a separatecurrent input.

Four step residual overcurrentprotection (PEFM, 51N/67N)The four step single input overcurrent function hasan inverse or definite time delay independent for each step separately.

All IEC and ANSI time delayed characteristics areavailable together with an optional user defined characteristic.

The function can be set to be directional, forward,reverse or non-directional independently for eachof the steps.

A second harmonic blocking can be set individu-ally for each step.

The function can be used as main protection for phase to earth faults.

The function can be used to provide a system back-up e.g. in the case of the primary protection being out of service due to communication or volt-age transformer circuit failure.

Directional operation can be combined together with corresponding communication blocks into

permissive or blocking teleprotection scheme.Current reversal and weak-end infeed functionalityare available as well.

The function can be configured to measure theresidual current from the three phase current inputsor the current from a separate current input.

Thermal overload protection, one ti meconstant (PTTR, 26)The increasing utilizing of the power system closer to the thermal limits have generated a need of athermal overload function also for power lines.

A thermal overload will often not be detected byother protection functions and the introduction of the thermal overload function can allow the pro-tected circuit to operate closer to the thermal lim-its.

The three phase current measuring function has anI2t characteristic with settable time constant and athermal memory.

An alarm level gives early warning to allow opera-tors to take action well before the line will betripped.

Breaker failu re pro tection (RBRF, 50BF)The circuit breaker failure function ensures fast

back-up tripping of surrounding breakers. The breaker failure protection operation can be current based, contact based or adaptive combination between these two principles.


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A current check with extremely short reset time isused as a check criteria to achieve a high securityagainst unnecessary operation.

The breaker failure protection can be single- or three-phase started to allow use with single phasetripping applications. For the three-phase versionof the breaker failure protection the current criteriacan be set to operate only if two out of four e.g.two phases or one phase plus the residual currentstarts. This gives a higher security to the back-uptrip command.

The function can be programmed to give a single-or three phase re-trip of the own breaker to avoid unnecessary tripping of surrounding breakers at anincorrect starting due to mistakes during testing.

Stub p rotecti on (PTOC, 50STB)When a power line is taken out of service for maintenance and the line disconnector is opened inmulti-breaker arrangements the voltage transform-ers will mostly be outside on the disconnected part.The primary line distance protection will thus not

be able to operate and must be blocked.

The stub protection covers the zone between thecurrent transformers and the open disconnector.The three phase instantaneous overcurrent functionis released from a NO (b) auxiliary contact on theline disconnector.

Pole disco rdance protecti on (RPLD, 52PD)Single pole operated circuit breakers can due toelectrical or mechanical failures end up with thedifferent poles in different positions (close-open).This can cause negative and zero sequence cur-rents which gives thermal stress on rotatingmachines and can cause unwanted operation of zero sequence current functions.

Normally the own breaker is tripped to correct the positions. If the situation consists the remote end can be intertripped to clear the unsymmetrical load situation.

The pole discordance function operates based oninformation from auxiliary contacts of the circuit

breaker for the three phases with additional criteria

from unsymmetrical phase current when required.

Voltage protect ion

Two step undervoltageprotection (PUVM, 27)Undervoltages can occur in the power system dur-ing faults or abnormal conditions. The functioncan be used to open circuit breakers to prepare for system restoration at power outages or aslong-time delayed back-up to primary protection.

The function has two voltage steps, each withinverse or definite time delay.

Two step overvoltageprotection (POVM, 59)Overvoltages will occur in the power system dur-ing abnormal conditions such as sudden power loss, tap changer regulating failures, open lineends on long lines.

The function can be used as open line end detector,normally then combined with directional reactiveover-power function or as system voltage supervi-sion, normally then giving alarm only or switchingin reactors or switch out capacitor banks to controlthe voltage.

The function has two voltage steps, each of themwith inverse or definite time delayed.

The overvoltage function has an extremely highreset ratio to allow setting close to system service

voltage.

Two step residual overvoltageprotection (POVM, 59N)Residual voltages will occur in the power systemduring earth faults.

The function can be configured to calculate theresidual voltage from the three phase voltage inputtransformers or from a single phase voltage inputtransformer fed from an open delta or neutral pointvoltage transformer.

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

Frequency p rotection

Underfrequency prot ection (PTUF, 81)Underfrequency occurs as a result of lack of gener-ation in the network.

The function can be used for load shedding sys-tems, remedial action schemes, gas turbine start-upetc.

The function is provided with an undervoltage blocking. The operation may be based on single phase, phase-to-phase or positive sequence voltagemeasurement.

Up to two independent under frequency functioninstances are available.

Overfrequency prot ection (PTOF, 81)Overfrequency will occur at sudden load drops or shunt faults in the power network. In some casesclose to generating part governor problems canalso cause overfrequency.

The function can be used for generation shedding,remedial action schemes etc. It can also be used asa sub-nominal frequency stage initiating load restoring.

The function is provided with an undervoltage blocking. The operation may be based on single


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1MRK 505164-BENRevision: G, Page 11

phase, phase-to-phase or positive sequence voltagemeasurement.

Up to two independent over frequency functioninstances are available.

Rate-of-change frequencyprotection (PFRC, 81)Rate of change of frequency function gives anearly indication of a main disturbance in the sys-tem.

The function can be used for generation shedding,load shedding, remedial action schemes etc.

The function is provided with an undervoltage blocking. The operation may be based on single phase, phase-to-phase or positive sequence voltagemeasurement.

Each step can discriminate between positive or negative change of frequency.

Up to two independent rate-of-change frequencyfunction instances are available.

Multipurpose protection

General current and voltageprotection (GAPC)The function can be utilized as a negativesequence current protection detecting unsymmetri-cal conditions such as open phase or unsymmetri-

cal faults.The function can also be used to improve phaseselection for high resistive earth faults, outside thedistance protection reach, for the transmission line.Three functions are used which measures the neu-tral current and each of the three phase voltages.This will give an independence from load currentsand this phase selection will be used in conjunc-tion with the detection of the earth fault from thedirectional earth fault protection function.

Secondary sys tem supervision

Current circuit supervision (RDIF)Open or short circuited current transformer corescan cause unwanted operation of many protectionfunctions such as differential, earth fault currentand negative sequence current functions.

It must be remembered that a blocking of protec-tion functions at an occurring open CT circuit willmean that the situation will remain and extremelyhigh voltages will stress the secondary circuit.

The current circuit supervision function comparesthe residual current from a three phase set of cur-rent transformer cores with the neutral point cur-rent on a separate input taken from another set of cores on the current transformer.

A detection of a difference indicates a fault in thecircuit and is used as alarm or to block protectionfunctions expected to give unwanted tripping.

Fuse failure supervision (RFUF)Failures in the secondary circuits of the voltagetransformer can cause unwanted operation of dis-tance protection, undervoltage protection, neutral

point voltage protection, energizing function (syn-chrocheck) etc. The fuse failure supervision func-tion prevents such unwanted operations.

There are three methods to detect fuse failures.

The method based on detection of zero sequencevoltage without any zero sequence current. This isa useful principle in a directly earthed system and can detect one or two phase fuse failures.

The method based on detection of negativesequence voltage without any negative sequencecurrent. This is a useful principle in a non-directlyearthed system and can detect one or two phasefuse failures.

The method based on detection of du/dt-di/dtwhere a change of the voltage is compared to achange in the current. Only voltage changes meansa voltage transformer fault. This principle candetect one, two or three phase fuse failures.

Control

Synchrocheck and energizing check(RSYN, 25)The synchrocheck function checks that the volt-ages on both sides of the circuit breaker are in syn-chronism, or with at least one side dead to ensurethat closing can be done safely.

The function includes a built-in voltage selectionscheme for double bus and one- and a half or ring

busbar arrangements.

Manual closing as well as automatic reclosing can be checked by the function and can have differentsettings, e.g. the allowed frequency difference can

be set to allow wider limits for the auto-recloseattempt than for the manual closing.

Autorec loser (RREC, 79)The autoreclosing function provides high-speed and/or delayed auto-reclosing for single or multi-breaker applications.

Up to five reclosing attempts can be programmed.The first attempt can be single-, two and/or three

phase for single phase or multi-phase faultsrespectively.

Multiple autoreclosing functions are provided for multi-breaker arrangements. A priority circuitallows one circuit breaker to close first and thesecond will only close if the fault proved to betransient.


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Each autoreclosing function can be configured toco-operate with a synchrocheck function.

Apparat us cont ro l (APC)The apparatus control is a function for control and supervision of circuit breakers, disconnectors and earthing switches within a bay. Permission to oper-ate is given after evaluation of conditions fromother functions such as interlocking, synchro-check, operator place selection and external or internal blockings.

InterlockingThe interlocking function blocks the possibility tooperate primary switching devices, for instancewhen a disconnector is under load, in order to pre-vent material damage and/or accidental humaninjury.

Each apparatus control function has interlockingmodules included for different switchyard arrange-ments, where each function handles interlocking of one bay. The interlocking function is distributed toeach IED and is not dependent on any central func-tion. For the station-wide interlocking, the IEDscommunicate via the system-wide interbay bus(IEC 61850-8-1) or by using hard wired binaryinputs/outputs. The interlocking conditions depend on the circuit configuration and apparatus positionstatus at any given time.

For easy and safe implementation of the interlock-ing function, the IED is delivered with standard-ized and tested software interlocking modulescontaining logic for the interlocking conditions.The interlocking conditions can be altered, to meetthe customers specific requirements, by addingconfigurable logic by means of the graphical con-figuration tool.

Scheme communication

Scheme communication logic for distance protection and directionalresidual overcurrent protection (PSCH, 85)To achieve instantaneous fault clearance for allline faults, a scheme communication logic is pro-vided. All types of communication schemes e.g.

permissive underreach, permissive overreach, blocking, intertrip etc. are available. The built-incommunication module (LDCM) can be used for scheme communication signalling when included.

Logic for loss of load and/or local acceleration inco-operation with autoreclose function is also pro-vided for application where no communicationchannel is available.

Current reversal and weak-end in feed logicfor distance protection and directionalresidual overcurrent protection (PSCH, 85)The current reversal function is used to preventunwanted operations due to current reversal when

using permissive overreach protection schemes inapplication with parallel lines when the overreachfrom the two ends overlaps on the parallel line.

The weak-end infeed logic is used in cases wherethe apparent power behind the protection can betoo low to activate the distance protection func-tion. When activated, received carrier signaltogether with local under voltage criteria and noreverse zone operation gives an instantaneous trip.The received signal is also echoed back to acceler-ate the sending end.

Local acceleration logic (PLAL)To achieve fast clearing of faults on the whole line,when no communication channel is available, localacceleration logic (ZCLC) can be used. This logicenables fast fault clearing during certain condi-tions, but naturally, it can not fully replace a com-munication channel.

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

Logic

Tripp ing logi c (PTRC, 94)A function block for protection tripping is pro-vided for each circuit breaker involved in the trip-

ping of the fault. It provides the pulse prolongationto ensure a trip pulse of sufficient length, as well asall functionality necessary for correct co-operationwith autoreclosing functions.

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

Trip matrix logi c (GGIO, 94X)Twelve trip matrix logic blocks are included in theIED. The function blocks are used in the configu-ration of the IED to route trip signals and/or other logical output signals to the different output relays.

The matrix and the physical outputs will be seen inthe PCM 600 engineering tool and this allows theuser to adapt the signals to the physical trippingoutputs according to the specific application needs.

Configurable logic blocksA high number of logic blocks and timers areavailable for user to adapt the configuration to thespecific application needs.

Fixed signal function b lockThe fixed signals function block generates a num-

ber of pre-set (fixed) signals that can be used in theconfiguration of an IED, either for forcing theunused inputs in the other function blocks to a cer-tain level/value, or for creating a certain logic.


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Monitoring

Measurements (MMXU)

The service value function is used to get on-lineinformation from the IED. These service valuesmakes it possible to display on-line information onthe local HMI and on the Substation automationsystem about:

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

the primary and secondary phasors,

differential currents, bias currents,

positive, negative and zero sequence currentsand voltages,

mA,

pulse counters, measured values and other information of the

different parameters for included functions,

logical values of all binary in- and outputs and

general IED information.

Supervision of mA input signals (MVGGIO)The main purpose of the function is to measureand process signals from different measuringtransducers. Many devices used in process controlrepresent various parameters such as frequency,temperature and DC battery voltage as low currentvalues, usually in the range 4-20 mA or 0-20 mA.

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

The function requires that the IED is equipped with the mA input module.

Event counter (GGIO)The function consists of six counters which areused for storing the number of times each counter has been activated. It is also provided with a com-mon blocking function for all six counters, to beused for example at testing. Every counter can sep-arately be set on or off by a parameter setting.

Disturbance report (RDRE)Complete and reliable information about distur-

bances in the primary and/or in the secondary sys-tem together with continuous event-logging isaccomplished by the disturbance report functional-ity.

The disturbance report, always included in theIED, acquires sampled data of all selected ana-logue input and binary signals connected to thefunction block i.e. maximum 40 analogue and 96

binary signals.

The disturbance report functionality is a commonname for several functions:

Event List (EL)

Indications (IND)

Event recorder (ER)

Trip Value recorder (TVR)

Disturbance recorder (DR)

Fault Locator (FL)

The function is characterized by great flexibilityregarding configuration, starting conditions,recording times and large storage capacity.

A disturbance is defined as an activation of aninput in the DRAx or DRBy function blocks whichis set to trigger the disturbance recorder. All sig-nals from start of pre-fault time to the end of

post-fault time, will be included in the recording.

Every disturbance report recording is saved in theIED in the standard Comtrade format. The sameapplies to all events, which are continuously saved in a ring-buffer. The Local Human Machine Inter-face (LHMI) is used to get information about therecordings, but the disturbance report files may beuploaded to the PCM 600 (Protection and ControlIED Manager) and further analysis using the dis-turbance handling tool.

Event list (RDRE)Continuous event-logging is useful for monitoringof the system from an overview perspective and isa complement to specific disturbance recorder functions.

The event list logs all binary input signals con-nected to the Disturbance report function. The listmay contain of up to 1000 time-tagged eventsstored in a ring-buffer.

Indicati ons (RDRE)To get fast, condensed and reliable informationabout disturbances in the primary and/or in thesecondary system it is important to know e.g.

binary signals that have changed status during adisturbance. This information is used in the short

perspective to get information via the LHMI in astraightforward way.

There are three LEDs on the LHMI (green, yellowand red), which will display status informationabout the IED and the Disturbance Report function(trigged).

The Indication list function shows all selected binary input signals connected to the DisturbanceReport function that have changed status during adisturbance.

Event r ecorder (RDRE)Quick, complete and reliable information aboutdisturbances in the primary and/or in the second-ary system is vital e.g. time tagged events logged during disturbances. This information is used for different purposes in the short term (e.g. corrective


14/48



actions) and in the long term (e.g. FunctionalAnalysis).

The event recorder logs all selected binary inputsignals connected to the Disturbance Report func-tion. Each recording can contain up to 150time-tagged events.

The event recorder information is available for thedisturbances locally in the IED.

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

Trip value recor der (RDRE)Information about the pre-fault and fault values for currents and voltages are vital for the disturbanceevaluation.

The Trip value recorder calculates the values of allselected analogue input signals connected to theDisturbance report function. The result is magni-tude and phase angle before and during the faultfor each analogue input signal.

The trip value recorder information is available for the disturbances locally in the IED.

The trip value recorder information is an inte-grated part of the disturbance record (Comtradefile).

Disturb ance recorder (RDRE)The Disturbance Recorder function supplies fast,

complete and reliable information about disturbances in the power system. It facilitates under-standing system behavior and related primary and secondary equipment during and after a distur-

bance. Recorded information is used for different purposes in the short perspective (e.g. correctiveactions) and long perspective (e.g. FunctionalAnalysis).

The Disturbance Recorder acquires sampled datafrom all selected analogue input and binary signalsconnected to the Disturbance Report function(maximum 40 analog and 96 binary signals). The

binary signals are the same signals as availableunder the event recorder function.

The function is characterized by great flexibilityand is not dependent on the operation of protectionfunctions. It can record disturbances not detected

by protection functions.

The disturbance recorder information for the last100 disturbances are saved in the IED and theLocal Human Machine Interface (LHMI) is used to view the list of recordings.

Event function (EV)When using a Substation Automation system withLON or SPA communication, time-tagged eventscan be sent at change or cyclically from the IED tothe station level. These events are created from anyavailable signal in the IED that is connected to the

Event function block. The event function block isused for LON and SPA communication.

Analog and double indication values are alsotransferred through the event block.

Fault locator (RFLO)The accurate fault locator is an essential compo-nent to minimize the outages after a persistent faultand/or to pin-point a weak spot on the line.

The built-in fault locator is an impedance measur-ing function giving the distance to the fault in per-cent, km or miles. The main advantage is the highaccuracy achieved by compensating for load cur-rent and for the mutual zero sequence effect ondouble circuit lines.

The compensation includes setting of the remote

and local sources and calculation of the distribu-tion of fault currents from each side. This distribu-tion of fault current, together with recorded load (pre-fault) currents, is used to exactly calculate thefault position. The fault can be recalculated withnew source data at the actual fault to further increase the accuracy.

Specially on heavily loaded long lines (where thefault locator is most important) where the sourcevoltage angles can be up to 35-40 degrees apart theaccuracy can be still maintained with the advanced compensation included in fault locator.

MeteringPulse count er logi c (GGIO)The pulse counter logic function counts externallygenerated binary pulses, for instance pulses com-ing from an external energy meter, for calculationof energy consumption values. The pulses are cap-tured by the binary input module and then read bythe pulse counter function. A scaled service valueis available over the station bus. The specialBinary input module with enhanced pulse countingcapabilities must be ordered to achieve this func-tionality.

Basic IED functionsTime synchronizationUse the time synchronization source selector toselect a common source of absolute time for theIED when it is a part of a protection system. Thismakes comparison of events and disturbance data

between all IEDs in a SA system possible.

Human machine interfaceThe local human machine interface is available ina small, and a medium sized model. The principledifference between the two is the size of the LCD.The small size LCD can display seven line of text

and the medium size LCD can display the singleline diagram with up to 15 objects on each page.


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Six SLD pages can be defined.

The local human machine interface is equipped with an LCD that can display the single line dia-gram with up to 15 objects.

The local human-machine interface is simple and easy to understand the whole front plate isdivided into zones, each of them with awell-defined functionality:

Status indication LEDs

Alarm indication LEDs which consists of 15LEDs (6 red and 9 yellow) with user printablelabel. All LEDs are configurable from thePCM 600 tool

Liquid crystal display (LCD)

Keypad with push buttons for control and nav-igation purposes, switch for selection betweenlocal and remote control and reset

An isolated RJ45 communication port

Figure 9: Small graphic HMI

Figure 10: Medium graphic HMI, 15 controllableobjects

Station communi cation

OverviewEach IED is provided with a communication inter-face, enabling it to connect to one or many substa-tion level systems or equipment, either on theSubstation Automation (SA) bus or SubstationMonitoring (SM) bus.

Following communication protocols are available:

IEC 61850-8-1 communication protocol

LON communication protocol

SPA or IEC 60870-5-103 communication pro-tocol

Theoretically, several protocols can be combined in the same IED.

IEC 61850-8-1 commun ication protoco lSingle or double optical Ethernet ports for the newsubstation communication standard IEC61850-8-1for the station bus are provided. IEC61850-8-1allows intelligent devices (IEDs) from differentvendors to exchange information and simplifiesSA engineering. Peer- to peer communicationaccording to GOOSE is part of the standard. Dis-turbance files uploading is provided.

Serial communication, LONExisting stations with ABB station bus LON can

be extended with use of the optical LON interface.This allows full SA functionality including

peer-to-peer messaging and cooperation betweenexisting ABB IED's and the new IED 670.


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SPA communi cation prot ocolA single glass or plastic port is provided for theABB SPA protocol. This allows extensions of sim-

ple substation automation systems but the mainuse is for Substation Monitoring Systems SMS.

IEC 60870-5-103 commun ication protocolA single glass or plastic port is provided for theIEC60870-5-103 standard. This allows design of simple substation automation systems includingequipment from different vendors. Disturbancefiles uploading is provided.

Single command, 16 signalsThe IEDs can receive commands either from asubstation automation system or from the localhuman-machine interface, LHMI. The command function block has outputs that can be used, for

example, to control high voltage apparatuses or for other user defined functionality.

Multiple command and transmitWhen 670 IED's are used in Substation Automa-tion systems with LON, SPA or IEC60870-5-103communication protocols the Event and MultipleCommand function blocks are used as the commu-nication interface for vertical communication tostation HMI and gateway and as interface for hori-zontal peer-to-peer communication (over LONonly).

Remote communication

Binary signal transfer to remote end,

8 signalsThe binary signal transfer function can be used for sending and receiving of eight communicationscheme related signals, transfer trip and/or other

binary signals between line differential IEDs. Thenumber of function blocks depends on the number of remote terminals. An IED can communicatewith up to 4 remote IEDs. Each function block cor-responds to one communication channel.

Line data communication module, short,medium and long range (LDCM)The line data communication module (LDCM) isused for communication between the IEDs situated at distances


17/48



module has two optical ports for plastic/plastic, plastic/glass, or glass/glass.

Line data communication module (LDCM)The line data communication module is used for

binary signal transfer. Each module has one optical port, one for each remote end to which the IEDcommunicates.

Alternative cards for Short range (900 nm multimode) are available.

GPS time synchr onization modul e (GSM)This module includes the GPS receiver used for time synchronization. The GPS has one SMA con-tact for connection to an antenna.

Transformer input module (TRM)The transformer input module is used to galvani-cally separate and transform the secondary cur-rents and voltages generated by the measuringtransformers. The module has twelve inputs in dif-ferent combinations.

High impedance resistor uni tThe high impedance resistor unit, with resistors for

pick-up value setting and a voltage dependentresistor, is available in a single phase unit and athree phase unit. Both are mounted on a 1/1 19inch apparatus plate with compression type term-nals.

Layout and dimensions

Dimensions

Mounting alternativesFollowing mounting alternatives (IP40 protectionfrom the front) are available:

19 rack mounting kit

Flush mounting kit with cut-out dimensions:

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

- 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 available mountingalternatives.

Figure 11: 1/2 x 19 case with rear cover Figure 12: Side-by-side mounting

Case size A B C D E F6U, 1/2 x 19 265.9 223.7 201.1 242.1 252.9 205.76U, 3/4 x 19 265.9 336.0 201.1 242.1 252.9 318.06U, 1/1 x 19 265.9 448.1 201.1 242.1 252.9 430.3

(mm)

xx05000003.vsd

CB

E

F

A

D

xx05000004.vsd


18/48



Connectiondiagrams

Tab le 1: Des ignat ions fo r 1/2 x 19 cas ing wi th 1 TRM s lo t

Tab le 2: Des ignat ions for 3/4 x 19 casing with 2TRM slot

Tab le 3: Des ignat ions for 1/1 x 19 casing with 2 TRM s lo ts

Module Rear PositionsPSM X11BIM, BOM or IOM X31 and X32 etc. to X51 and X52GSM X51SLM X301:A, B, C, DOEM X311:A, B, C, DLDCM X312:A, BLDCM X313:A, B

TRM X401

Module Rear PositionsPSM X11BIM, BOM, IOM or MIM X31 and X32 etc. to X71 and X72GSM X71SLM X301:A, B, C, DLDCM X302:A, BLDCM X303:A, BOEM X311:A, B, C, DLDCM X312:A, B

LDCM X313:A, B TRM X401, 411

Module Rear PositionsPSM X11BIM, BOM or IOM X31 and X32 etc. to X131 and X132

MIM X31, X41, etc. or X131GSM X131SLM X301:A, B, C, DOEM X311:A, B, C, DLDCM X312:A, BLDCM X313:A, B

TRM 1 X401 TRM 2 X411


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Figure 13: Transformer inputmodule (TRM)

CT/VT-input designation according to figure 13Current/voltageconfiguration (50/60 Hz)

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

9I and 3U, 1A 1A 1A 1A 1A 1A 1A 1A 1A 1A 0-220V 0-220V 0-220V9I and 3U, 5A 5A 5A 5A 5A 5A 5A 5A 5A 5A 0-220V 0-220V 0-220V5I, 1A and 4I, 5Aand 3U

1A 1A 1A 1A 1A 5A 5A 5A 5A 0-220V 0-220V 0-220V

6I and 6U, 1A 1A 1A 1A 1A 1A 1A 0-220V 0-220V 0-220V 0-220V 0-220V 0-220V6I and 6U, 5A 5A 5A 5A 5A 5A 5A 0-220V 0-220V 0-220V 0-220V 0-220V 0-220V

Figure 14: Binary input module (BIM). Input contacts named XAcorresponds to rear position X31, X41, etc. and inputcontacts named XB to rear position X32, X42, etc.

Figure 15: mA input module (MIM)


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Figure 16: Binary in/out module (IOM). Input contacts named XA corresponds to rearposition X31, X41, etc. and output contacts named XB to rear position X32,X42, etc.

Figure 17: Communication interfaces (OEM,LDCM, SLM and HMI)Note to figure 171) Rear communication port IEC 61850, ST-connector2) Rear communication port C37.94, ST-connector3) Rear communication port SPA/ IEC 60870-5-103,

ST connector for glass alt. HFBR Snap-in connectorfor plastic as ordered

4) Rear communication port LON, STconnector forglass alt. HFBR Snap-in connector for plastic asordered

5) Front communication port, Ethernet, RJ 45 connector

Figure 18: Power supply module (PSM)

Figure 19: GPS time synchronization module(GSM)


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Figure 20: Binary output module (BOM). Output contacts named XA corresponds to rear position X31,X41, etc. and output contacts named XB to rear position X32, X42, etc.


22/48



Figure 21: Typical connection diagram for a single breaker arrangement with control integrated.

CC

T

C TC

P1

-QB1-QB2

-QA1

-BI1

QB1-OPENQB1-CLQB2-OPENQB2-CL

QA1-OPENQA1-CL

QA1-SPR UNCHQA1-PD

CLOSE QA1

TRIP QA1 L1,L2,L3

MAIN 2 TRIP

-QB9

MCB-OK

MCB-OK

BUS ABUS B

QB9-OPENQB9-CL

BBP-TRIP

ST BFP L1

ST BFP 3PH

START AR

INHIBIT AR

3PH TRIP

1PH AR IN PROG

CR Z10 ms0.2 s1.0 s

30 A10 A

Breaking capacity for AC, cos >0.4 250 V/8.0 ABreaking capacity for DC with L/R


27/48



Table 16: Insulation

Tabl e 17: En vi ro nm ental tes ts

Table 18: CE compliance

Tabl e 19: Mec hani cal tes ts

Differential p rotectionTable 20: High impedance different ial protect ion (PDIF, 87)

Table 21: Line different ial protect ion (PDIF, 87L, 87LT)

Radiated electromagnetic field disturbance 20 V/m, 80-2500 MHz EN 61000-4-3Radiated electromagnetic field disturbance 35 V/m

26-1000 MHzIEEE/ANSI C37.90.2

Conducted electromagnetic field distur-bance

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

Radiated emission 30-1000 MHz IEC 60255-25Conducted emission 0.15-30 MHz IEC 60255-25

Test Type test values Reference standardDielectric test 2.0 kV AC, 1 min. IEC 60255-5Impulse voltage test 5 kV, 1.2/50 s, 0.5 JInsulation resistance >100 M at 500 VDC

Test Type test value Reference standardCold test Test Ad for 16 h at -25 C IEC 60068-2-1Storage 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 60068-2-2Damp heat test, steady state Test Ca for 4 days at +40 C and humidity

93%IEC 60068-2-3

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

IEC 60068-2-30

Test According toImmunity EN 61000-6-2Emissivity EN 61000-6-4Low voltage directive EN 50178

Test Type test values Reference standardsVibration Class I IEC 60255-21-1Shock and bump Class I IEC 60255-21-2Seismic Class I IEC 60255-21-3

Function Range or value AccuracyOperate voltage (20-400) V 1.0% of U r for U U rReset ratio >95% -Maximum continuous voltage U>Trip 2/series resistor 200 W -Operate time 10 ms typically at 0 to 10 x U d -Reset time 90 ms typically at 10 to 0 x U d -Critical impulse time 2 ms typically at 0 to 10 x U d -

Function Range or value AccuracyMinimum operate current (20-200)% of I base 2.0% of I r at I Ir

2.0% of I at I >I rSlopeSection2 (10.0-50.0)% -SlopeSection3 (30.0-100.0)% -EndSection 1 (20150)% of I base -EndSection 2 (1001000)% of I base -Unrestrained limit function (1005000)% of I base 2.0% of I r at I Ir

2.0% of I at I >I rSecond harmonic blocking (5.0100.0)% of fundamental 2.0% of I rFifth harmonic blocking (5.0100.0)% of fundamental 5.0% of I rInverse characteristics, see table 71 andtable 72

19 curve types See table 71 and table 72

Operate time 25 ms typically at 0 to 10 x I d -

Test Type test values Reference standards


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Distance p rotectionTable 22: Distance protect ion zones (PDIS, 21)

Table 23: Phase select ion with load encroachment (PDIS,21)

Tab le 24: Power swing detec tion (RPSB, 78)

Table 25: Automatic switch onto faul t logic (PSOF)

Reset time 15 ms typically at 10 to 0 x I d -Critical impulse time 2 ms typically at 0 to 10 x I d -Charging current compensation On/Off -

Function Range or value Accuracy

Function Range or value AccuracyNumber of zones 3 with selectable direction -Minimum operate current (10-30)% of I base -Positive sequence reactance (0.50-3000.00) /phase 2.0% static accuracy

2.0 degrees static angular accuracyConditions:Voltage range: (0.1-1.1) x U rCurrent range: (0.5-30) x I rAngle: at 0 degrees and 85 degrees

Positive sequence resistance (0.10-1000.00) /phaseZero sequence reactance (0.50-9000.00) /phaseZero sequence resistance (0.50-3000.00) /phaseFault resistance, Ph-E (1.00-9000.00) /loopFault resistance, Ph-Ph (1.00-3000.00) /loop

Dynamic overreach


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Current prot ectionTable 26: Instantaneous phase overcurrent protection (PIOC, 50)

Table 27: Four step phase overcurrent protection (POCM, 51/67)

Table 28: Instantaneous residual overcurrent protection (PIOC, 50N)

Table 29: Four step residual overcurrent protection (PEFM, 51N/67N)

Function Range or value AccuracyOperate current (1-2500)% of l base 1.0% of I r at I Ir

1.0% of I at I >I rReset ratio >95% -Operate time 25 ms typically at 0 to 2 x I set -Reset time 25 ms typically at 2 to 0 x I set -Critical impulse time 10 ms typically at 0 to 2 x I set -Operate time 10 ms typically at 0 to 10 x I set -Reset time 35 ms typically at 10 to 0 x I set -Critical impulse time 2 ms typically at 0 to 10 x I set -Dynamic overreach I r

Reset ratio >95% -Min. operating current (1-100)% of l base 1.0% of I rRelay characteristic angle (RCA) (-70.0 -50.0) degrees 2.0 degreesMaximum forward angle (40.070.0) degrees 2.0 degreesMinimum forward angle (75.090.0) degrees 2.0 degreesSecond harmonic blocking (5100)% of fundamental 2.0% of I rIndependent time delay (0.000-60.000) s 0.5% 10 msMinimum operate time (0.000-60.000) s 0.5% 10 msInverse characteristics, see table 71 and table 72


Operate time, start function 25 ms typically at 0 to 2 xI set -Reset time, start function 25 ms typically at 2 to0 xI set -Critical impulse time 10 ms typically at 0 to 2 x I set -Impulse margin time 15 ms typically -

Function Range or value AccuracyOperate current (1-2500)% of l base 1.0% of I r at I Ir

1.0% of I at I >I rReset ratio >95% -Operate time 25 ms typically at 0 to 2 x I set -Reset time 25 ms typically at 2 to 0 x I set -Critical impulse time 10 ms typically at 0 to 2 x I set -Operate time 10 ms typically at 0 to 10 x I set -Reset time 35 ms typically at 10 to 0 x I set -Critical impulse time 2 ms typically at 0 to 10 x I set -Dynamic overreach I rReset ratio >95% -Operate current for directional compari-son

(1100)% of l base 1.0% of I r

Timers (0.000-60.000) s 0.5% 10 msInverse characteristics, see table 71 and table 72


Second harmonic restrain operation (5100)% of fundamental 2.0% of I rRelay characteristic angle (-180 to 180) degrees 2.0 degreesMinimum polarizing voltage (1100)% of U base 1.0% of U rOperate time, start function 25 ms typically at 0 to 2 xI set -Reset time, start function 25 ms typically at 2 to0 xI set -Critical impulse time 10 ms typically at 0 to 2 x I set -

Impulse margin time 15 ms typically -


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Table 30: Thermal overload protection, one time constant (PTTR, 26)

Table 31: Breaker fai lure protect ion (RBRF, 50BF)

Tab le 32: Stub protec tion (PTOC, 50STB)

Table 33: Pole discordance protect ion (RPLD,52PD)

Voltage protect ionTable 34: Two step undervol tage protect ion (PUVM, 27)

Function Range or value AccuracyReference current (0-400)% of I base 1.0% of I rStart temperature reference (0-400) C 1.0 COperate time:

I =Imeasured

Ip =load current before overload occurs Time constant =(01000) 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 tripReset level temperature (0-400) C 2.0% of heat content trip

Function Range or value AccuracyOperate phase current (5-200)% of l base 1.0% of I r at I Ir

1.0% of I at I >I rReset ratio, phase current >95% -Operate residual current (2-200)% of l base 1.0% of I r at I Ir

1.0% of I at I >I rReset ratio, residual current >95% -Phase current level for blocking of con-tact function

(5-200)% of l base 1.0% of I r at I Ir 1.0% of I at I >I r

Reset ratio >95% - Timers (0.000-60.000) s 0.5% 10 msOperate time for current detection 10 ms typically -Reset time for current detection 15 ms maximum -


Operate current (1-2500)% of I base 1.0% of I r at I Ir 1.0% of I at I >I rReset ratio >95% -Definite time (0.000-60.000) s 0.5% 10 msOperate time, start function 25 ms typically at 0 to 2 x I set -Reset time, start function 25 ms typically at 2 to0 xI set -Critical impulse time 10 ms typically at 0 to 2 x I set -Impulse margin time 15 ms typically -

Function Range or value AccuracyOperate current (0100% of I base 1.0% of I r

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

2 2

2 2ln p

b

I I t

I I

=

Function Range or value AccuracyOperate voltage, low and high step (1100)% of U base 1.0% of U rAbsolute hysteresis (0100)% of U base 1.0% of U rInternal blocking level, low and highstep

(1100)% of U base 1.0% of U r

Inverse time characteristics for lowand high step, see table 73

- See table 73

Definite time delays (0.000-60.000) s 0.5% 10 msMinimum operate time, inverse char-acteristics

(0.00060.000) s 0.5% 10 ms

Operate time, start function 25 ms typically at 2 to 0 x U set -Reset time, start function 25 ms typically at 0 to 2x U set -Critical impulse time 10 ms typically at 2 to 0 x U set -

Impulse margin time 15 ms typically -


31/48



Table 35: Two step overvol tage protection (POVM, 59)

Table 36: Two step residual overvoltage protection (POVM, 59N)

Frequency pr otectionTable 37: Underfrequency protect ion (PTUF, 81)

Table 38: Overfrequency protect ion (PTOF, 81)

Table 39: Rate-of-change frequency protect ion (PFRC, 81)

Function Range or value AccuracyOperate voltage, low and high step (1-200)% of U base 1.0% of U r at U UrAbsolute hysteresis (0100)% of U base 1.0% of U r at U U rInverse time characteristics for lowand high step, see table 74

- See table 74

Definite time delays (0.000-60.000) s 0.5% 10 msMinimum operate time, Inverse char-acteristics

(0.000-60.000) s 0.5% 10 ms

Operate time, start function 25 ms typically at 0 to 2 x U set -Reset time, start function 25 ms typically at 2 to 0 x U set -Critical impulse time 10 ms typically at 0 to 2 x U set -Impulse margin time 15 ms typically -

Function Range or value AccuracyOperate voltage, low and high step (1-200)% of U base 1.0% of U r at U U rAbsolute hysteresis (0100)% of U base 1.0% of U r at U U rInverse time characteristics for lowand high step, see table 75

- See table 75

Definite time setting (0.00060.000) s 0.5% 10 msMinimum operate time (0.000-60.000) s 0.5% 10 msOperate time, start function 25 ms typically at 0 to 2 x U set -Reset time, start function 25 ms typically at 2 to 0 x U set -Critical impulse time 10 ms typically at 0 to 2 x U set -Impulse margin time 15 ms typically -

Function Range or value AccuracyOperate value, start function (35.00-75.00) Hz 2.0 mHzOperate 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 msReset time, definite time function (0.000-60.000)s 0.5% +10 msVoltage dependent time delay

U=Umeasured

Settings:UNom=(50-150)% of U baseUMin=(50-150)% of U baseExponent=0.0-5.0tMax=(0.001-60.000)stMin=(0.000-60.000)s

Class 5 +200 ms

Function Range or value AccuracyOperate value, start function (35.00-75.00) Hz 2.0 mHzOperate 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 msReset time, definite time function (0.000-60.000)s 0.5% +10 ms

Function Range or value AccuracyOperate value, start function (-10.00-10.00) Hz/s 10.0 mHz/sOperate value, internal blocking level (0-100)% of U base 1.0% of U rOperate time, start function 100 ms typically -

( ) Exponent

U UMint tMax tMin tMin

UNom UMin

= +


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Multipurpose protectionTable 40: General current and vol tage protect ion (GAPC)Function Range or value AccuracyMeasuring current input phase1, phase2, phase3, PosSeq,

NegSeq, 3*ZeroSeq, MaxPh, MinPh,UnbalancePh, phase1-phase2,phase2-phase3, phase3-phase1,MaxPh-Ph, MinPh-Ph, Unbalan-cePh-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, Unbalan-cePh-Ph

-

Base voltage (0.05 - 2000.00) kV -Start overcurrent, step 1 and 2 (2 - 5000)% of I base 1.0% of I r for II rStart undercurrent, step 1 and2 (2 - 150)% of I base 1.0% of I r for II rDefinite time delay (0.00 - 6000.00) s 0.5% 10 msOperate time start overcurrent 25 ms typically at 0 to 2 x I set -Reset time start overcurrent 25 ms typically at 2 to 0 x I set -Operate time start undercurrent 25 ms typically at 2to 0 x I set -Reset time start undercurrent 25 ms typically at 0 to 2 x I set -See table 71 and table 72 Parameter ranges for customer

defined 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 - 3.000

TR: 0.005 - 600.000CR: 0.1 - 10.0

See table 71 and table 72

Voltage level where voltage memorytakes over

(0.0 - 5.0)% of U base 1.0% of U r

Start overvoltage, step 1 and 2 (2.0 - 200.0)% of U base 1.0% of U r for UU r

Start undervoltage, step 1 and 2 (2.0 - 150.0)% of U base 1.0% of U r for UU r

Operate time, start overvoltage 25 ms typically at 0 to 2 x U set -Reset time, start overvoltage 25 ms typically at 2 to 0 x U set -Operate time start undervoltage 25 ms typically 2 to 0 x U set -Reset time start undervoltage 25 ms typically at 0 to 2 x U set -High and low voltage limit, voltagedependent operation

(1.0 - 200.0)% of U base 1.0% of U r for UU r

Directional function Settable: NonDir, forward and reverse -Relay characteristic angle (-180 to +180) degrees 2.0degreesRelay operate angle (1 to 90) degrees 2.0degreesReset ratio, overcurrent >95% -Reset ratio, undercurrent 95% -Reset ratio, undervoltage


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Secondary sys tem supervisionTab le 41: Curren t ci rcui t supervi sion (RDIF)

Tab le 42: Fuse fai lu re supervi sion (RFUF)

ControlTable 43: Synchrocheck and energizing check (RSYN, 25)

Tab le 44: A ut or ec lo ser (RREC, 79)

Undervoltage:Critical impulse time 10 ms typically at 2 to 0 x U set -Impulse margin time 15 ms typically -


Function Range or value AccuracyOperate current (5-200)% of I r 10.0% of I r at I Ir

10.0% of I at I >I rBlock current (5-500)% of I r 5.0% of I r at I Ir

5.0% of I at I >I r

Function Range or value AccuracyOperate voltage, zero sequence (1-100)% of U base 1.0% of U rOperate current, zero sequence (1100)% of I base 1.0% of I rOperate voltage, negative sequence (1100)% of U base 1.0% of U rOperate current, negative sequence (1100)% of I base 1.0% of I rOperate voltage change level (1100)% of U base 5.0% of U rOperate current change level (1100)% of I base 5.0% of I r

Function Range or value AccuracyPhase shift, line -bus (-180 to 180) degrees -Voltage ratio, U bus /Uline (0.20-5.00)% of U base -Voltage high limit for synchrocheck (50.0-120.0)% of U base 1.0% of U r at U Ur

1.0% of U at U >U rReset ratio, synchrocheck >95% -Frequency difference limit between busand line

(0.003-1.000) Hz 2.0 mHz

Phase angle difference limit betweenbus and line

(5.0-90.0) degrees 2.0 degrees

Voltage difference limit between busand line

(2.0-50.0)% of U base 1.0% of U r

Time delay output for synchrocheck (0.000-60.000) s 0.5% 10 msVoltage high limit for energizing check (50.0-120.0)% of U base 1.0% of U r at U Ur

1.0% of U at U >U rReset ratio, voltage high limit >95% -Voltage low limit for energizing check (10.0-80.0)% of U base 1.0% of U rReset ratio, voltage low limit U r Time delay for energizing check (0.000-60.000) s 0.5% 10 msOperate time for synchrocheck function 160 ms typically -

Operate time for energizing function 80 ms typically -

Function Range or value AccuracyNumber of autoreclosing shots 1 - 5 -Number of autoreclosing programs 8 -


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Scheme communicationTable 45: Scheme communicat ion logic for distanceprotect ion (PSCH, 85)

Table 46: Current reversal and weak-end infeed logic for distance protection (PSCH, 85)

Table 47: Scheme communicat ion logic for residual overcurrent protect ion (PSCH, 85)

Table 48: Current reversal and weak-end infeed logic for residual overcurrent protection (PSCH, 85)

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) sAutorecloser maximum wait time for sync (0.00-6000.00) sMaximum trip pulse duration (0.000-60.000) sInhibit reset time (0.000-60.000) sReclaim time (0.00-6000.00) sMinimum 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) sCB check time before unsuccessful (0.00-6000.00) sWait for master release (0.00-6000.00) sWait time after close command before pro-ceeding to next shot

(0.000-60.000) s


Function Range or value AccuracyScheme type Intertrip

Permissive URPermissive ORBlocking

-

Co-ordination time for blocking communica-tion scheme

(0.000-60.000) s 0.5% 10 ms

Minimum duration of a carrier send signal (0.000-60.000) s 0.5% 10 msSecurity timer for loss of carrier guarddetection

(0.000-60.000) s 0.5% 10 ms

Operation mode of unblocking logic Off NoRestartRestart

-

Function Range or value AccuracyDetection level phase to neutral voltage (10-90)% of U base 1.0% of U rDetection level phase to phase voltage (10-90)% of U base 1.0% of U rReset ratio 95% -


35/48



LogicTab le 49: Tr ipping log ic (PTRC, 94)

Tab le 50: Co nf ig ur ab le l og ic bl oc ks

MonitoringTab le 51: Meas ur em en ts (MMXU)

Table 52: Supervis ion of mA input s ignals (MVGGIO)

Tab le 53: Ev en t c ou nt er (GGIO)

Operate time for current reversal (0.000-60.000) s 0.5% 10 msDelay time for current reversal (0.000-60.000) s 0.5% 10 msCoordination time for weak-end infeedlogic

(0.00060.000) s 0.5% 10 ms


Function Range or value Accuracy 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

Logic block Quantity with update rate Range or value Accuracyfast 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 (0.00090000.000) s 0.5% 10 msLogicPulseTimer 10 10 20 (0.00090000.000) s 0.5% 10 msLogicTimerSet 10 10 20 (0.00090000.000) s 0.5% 10 msLogicLoopDelay 10 10 20 (0.00090000.000) s 0.5% 10 ms

Function Range or value AccuracyFrequency (0.95-1.05) f r 2.0 mHzVoltage (0.1-1.5) Ur 0.5% of U r at U Ur

0.5% of U at U >U rConnected current (0.2-4.0) Ir 0.5% of I r at I Ir

0.5% of I at I >I rActive power, P 0.1 x U r


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Tab le 54: Disturbance r epor t (RDRE)

Tab le 55: Fau lt l oc at or (RFL O)

MeteringTab le 56: Pu ls e c ou nt er l og ic (GGIO)

Station communicationTable 57: IEC 61850-8-1 communicat ion protocol

Tab le 58: L ON co mm un ic at io n p ro to co l

Tab le 59: SPA co mm un ic at io n p ro to co l

Table 60: IEC 60870-5-103 communicat ion protocol

Function Range or value AccuracyPre-fault time (0.050.30) s -Post-fault time (0.15.0) s -Limit time (0.56.0) s -Maximum number of recordings 100 -

Time tagging resolution 1 ms See Table 70: "Time synchronization,time tagging".

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 theEvent recording per recording

150 -

Maximum number of events in theEvent list

1000, first in - first out -

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

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

-

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

-

Recording bandwidth (5-300) Hz -

Function Value or range AccuracyReactive and resistive reach (0.001-1500.000) /phase 2.0% static accuracy

2.0% degrees static angular accuracyConditions:Voltage range: (0.1-1.1) x U rCurrent range: (0.5-30) x I r

Phase selection According to input signals -Maximum number of fault locations 100 -

Function Setting range AccuracyInput frequency See Binary Input Module (BIM) -Cycle time for report of counter value (03600) s -

Function ValueProtocol IEC 61850-8-1Communication speed for the IEDs 100BASE-FX

Function ValueProtocol LONCommunication speed 1.25 Mbit/s

Function ValueProtocol SPACommunication speed 300, 1200, 2400, 4800, 9600, 19200 or 38400 BdSlave number 1 to 899

Function ValueProtocol IEC 60870-5-103Communication speed 9600, 19200 Bd


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Table 61: SLM LON port

Table 62: SLM SPA/IEC 60870-5-103 port

Remote communicationTable 63: Line data communicat ion module (LDCM)

Hardware

IEDTable 64: Case

Table 65: Water and dust protection level according to IEC 60529

Table 66: Weight

Connection systemTab le 67: CT an d VT ci rc ui t c on nec to rs

Tab le 68: B inary I/O connec tion sys tem

Quantity Range or valueOptical connector Glass fibre: type ST

Plastic fibre: type HFBR snap-inFibre, optical budget Glass fibre: 11 dB (1000 m typically *)

Plastic fibre: 7 dB (10 m typically *)Fibre diameter Glass fibre: 62.5/125 m

Plastic fibre: 1 mm*) depending on optical budget calculation

Quantity Range or valueOptical connector Glass fibre: type ST

Plastic fibre: type HFBR snap-inFibre, optical budget Glass fibre: 11 dB (1000 m typically *)

Plastic fibre: 7 dB (25 m typically *)Fibre diameter Glass fibre: 62.5/125 m

Plastic fibre: 1 mm

*) depending on optical budget calculation

Quantity Range or value Type of fibre Graded-index multimode 62.5/125 m or 50/125 mWave length 820 nmOptical budgetGraded-index multimode 62.5/125 mGraded-index multimode 50/125 m

13 dB (typical distance 3 km *)9 dB (typical distance 2 km *)

Optical connector Type STProtocol C37.94Data transmission Synchronous

Transmission rate 64 kbit/sClock source Internal or derived from received signal*) depending on optical budget calculation

Material Steel sheetFront plate Steel sheet profile with cut-out for HMISurface treatment Aluzink preplated steelFinish Light grey (RAL 7035)

Front IP40 (IP54 with sealing strip)

Rear, sides, top and bottom IP20

Case size Weight6U, 1/2 x 19 10 kg6U, 3/4 x 19 15 kg6U, 1/1 x 19 18 kg

Connector type Rated voltage and current Maximum conductor area Terminal blocks of feed through type 250 V AC, 20 A 4 mm 2

Connector type Rated voltage Maximum conductor area

Screw compression type 250 V AC 2.5 mm2

2 1 mm 2


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Basic IED functionsTable 69: Self supervision with internal event l ist

Tab le 70: Time synchron izat ion, time tagging

Inverse characteristicsTab le 71: Inver se time charac ter is ti cs ANSI

Tab le 72: Inver se time charac ter is ti cs IEC

Data ValueRecording manner Continuous, event controlledList size 1000 events, first in-first out

Function Value Time tagging resolution, Events and Sampled MeasurementValues

1 ms

Time tagging error with synchronization once/min (minutepulse synchronization), Events and Sampled MeasurementValues

1.0 ms typically

Time tagging error with SNTP synchronization, SampledMeasurement Values

1.0 ms typically


Operate characteristic:

Reset characteristic:

I =Imeasured /Iset

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

-

ANSI Extremely Inverse no 1 A=28.2, B=0.1217, P=2.0,tr=29.1

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

ANSI Very inverse no 2 A=19.61, B=0.491, P=2.0,tr=21.6ANSI Normal Inverse no 3 A=0.0086, B=0.0185, P=0.02,

tr=0.46ANSI Moderately Inverse no 4 A=0.0515, B=0.1140, P=0.02,

tr=4.85ANSI Long Time Extremely Inverse no 6 A=64.07, B=0.250, P=2.0, tr=30ANSI Long Time Very Inverse no 7 A=28.55, B=0.712, P=2.0,

tr=13.46ANSI Long Time Inverse no 8 k=(0.01-1.20) in steps of 0.01

A=0.086, B=0.185, P=0.02,tr=4.6

Function Range or value AccuracyOperate characteristic:

I =Imeasured /Iset

k =(0.05-1.10) in steps of 0.01 -

Time delay to reset, IEC inverse time (0.000-60.000) s 0.5% of set time 10 msIEC Normal Inverse no 9 A=0.14, P=0.02 IEC 60255-3, class 5 +40 msIEC Very inverse no 10 A=13.5, P=1.0IEC Inverse no 11 A=0.14, P=0.02IEC Extremely inverse no 12 A=80.0, P=2.0IEC Short-time inverse no 13 A=0.05, P=0.04IEC Long-time inverse no 14 A=120, P=1.0

( )1= +

P

At B k

I

( )2 1=

tr t kI

( )1=

P

At k

I


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Table 73: Inverse time character ist ics for Two step undervol tage protect ion (PUVM, 27)

Customer defined characteristic no 17Operate characteristic:

Reset characteristic:

I =Imeasured /Iset

k=0.5-999 in steps of 0.1A=(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 0.001

TR=(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

RI inverse characteristic no 18

I =Imeasured /Iset

k=(0.05-999) in steps of 0.01 IEC 60255-3, class 5 +40 ms

Logarithmic inverse characteristic no 19

I =Imeasured /Iset

k=(0.05-1.10) in steps of 0.01 IEC 60255-3, class 5 +40 ms

Function Range or value Accuracy Type A curve:

U


40/48



Table 74: Inverse time character ist ics for Two step overvol tage protect ion (POVM,59)Function Range or value Accuracy

Type A curve:

U>=U setU =Umeasured

k =(0.05-1.10) in steps of 0.01 Class 5 +40ms

Type B curve: k =(0.05-1.10) in steps of 0.01

Type C curve: k =(0.05-1.10) in steps of 0.01

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

= >

>

tk

U U

U

2.0

480

32 0.5 0.035

=

>

>

tk

U U

U

3.0

480

32 0.5 0.035

=

>

>

tk

U U

U

= +

>

>

P

k At D

U UB C

U


41/48



Table 75: Inverse time characteristics for Two step residual overvoltage protection (POVM, 59N)Function Range or value Accuracy

Type A curve:

U&g

abb relay red 670

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