buyer's guide line differential protection ied red 670

Buyer's GuidePre-configuredLine differential protection IED RED 670 1MRK 505 164-BENRevision: GPage 1

Issued: February 2007Data subject to change without noticeFeatures Four configuration alternatives for single- or multi-breaker arrangements available ready to connect

For overhead lines and cables

For transformer feeders

For single and/or three phase tripping

High impedance differential protection for tee-feeders

Phase-segregated line differential protection with up to six stabilized inputs for up to five line terminals with:

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

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

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

- Power transformers can be included in the protected 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 for single- or multi-breaker arrangements:

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

- For automatic or manual synchrocheck and with different settings

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

- Two functions with priority circuits for multi-breaker arrangements

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

communication or with local switches through binary inputs

Selectable additional software functions such as distance protection, control and monitoring

Built-in data communication modules for station bus IEC 61850-8-1

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

Integrated disturbance and event recorder for up to 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 below 0.5% 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 event recorder

Six independent groups of complete setting parameters with password protection

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

Remote end data communication modules for C37.94 and G.703

Application The RED 670 IED is used for the protection, con-trol and monitoring of overhead lines and cables in all types of networks. The IED can be used up to the highest voltage levels. It is suitable for the pro-

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

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

1MRK 505 164-BENRevision: G, Page 2for protection of cable feeders to generator block transformers.

The phase segregated current differential protec-tion provides an excellent sensitivity for high resistive faults and gives a secure phase selection. The availability of six stabilized current inputs allows use on multi-breaker arrangements in three terminal applications or up to five terminal appli-cations with single breaker arrangements. Remote communication based on the IEEE C37.94 stan-dard can be redundant when required for important installations. Charging current compensation allows high sensitivity also on long overhead lines and cables. A full scheme distance protection is included as independent protection or as back-up at remote end communication failures. Eight chan-nels for intertrip and binary signals are available in the 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 with the 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 are examples of the available functions allowing the user 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, closing of 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 product an excellent choice for both new installations and the refurbishment of existing installations.

Four packages has been defined for following applications:

Single-breaker (double or single bus) with three 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 basic functions active to allow direct use. Optional func-tions are not configured but a maximum configura-tion with all optional functions are available as template in the graphical configuration tool. Inter-face to analogue and binary IO are configurable from 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.


1MRK 505 164-BENRevision: G, Page 3Figure 1: The single breaker packages for single- and three phase tripping typical arrangement for one protection sub-system is shown here. The differential function is more sensitive than any earth fault 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

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3U>

59

3U50/51


1MRK 505 164-BENRevision: G, Page 4Figure 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 fault or 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->O CLO

SE

TRIP

25

94/86

79

3Id/I>

CB1

CB2

TRIPCB1/3

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3U>

59

3U50/51


1MRK 505 164-BENRevision: G, Page 5Available functionsANSI Function description Single breaker,

3-phase tripping (A31)

Multi breaker, 3-phase tripping (B31)

Singel breaker, 1-phase tripping (A32)


Basic Option (Qty/ option design)




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, with in-zone transformers,

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

87LT Line differential protection 6 CT sets, with in-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 protection81 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 protectionGeneral 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


1MRK 505 164-BENRevision: G, Page 6Functionality Differential protection

High impedance differential protection (PDIF, 87)The high impedance differential protection can be used when the involved CT cores have same turn ratio and similar magnetizing characteristic. It uti-lizes an external summation of the phases and neu-tral current and a series resistor and a voltage dependent resistor externally to the relay.

Line differential protection, 3 or 6 CT 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 sensitivity and provides phase selection information for sin-gle-pole tripping.

The three terminal version is used for conventional two-terminal lines with or without 1 1/2 circuit breaker arrangement in one end, as well as three terminal lines with single breaker arrangements at all terminals.

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

85 Current reversal and weak-end infeed logic for distance protection (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

residual overcurrent protection (PSCH) - 1/C04 - 1/C04 - 1/C04 - 1/C04

85 Current reversal and weak-end infeed logic for residual overcurrent protection (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 communicationIEC61850-8-1 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 Function description Single breaker, 3-phase tripping (A31)


Singel breaker, 1-phase tripping (A32)






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RED670

RED670

Protected zone

Comm. Channel


1MRK 505 164-BENRevision: G, Page 7The six terminal version is used for conventional two-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 the same time as it has excellent stability for external faults. Current samples from all CTs are exchanged between the IEDs in the line ends (mas-ter-master mode) or sent to one IED (master-slave mode) for evaluation.

A restrained dual biased slope evaluation is made where the bias current is the highest phase current in 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 trip-ping of internal faults with very high currents.

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

considered to be negligible, and special measures need only to be taken in the event of a short circuit on the LV side of the transformer. In this applica-tion, the tripping of the differential protection can be time delayed for low differential currents in order to achieve coordination with down stream over current relays.

A line charging current compensation provides increased 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 in the line differential protection zone. Both two- and three-winding transformers are correctly repre-sented with vector group compensations made in the algorithm. The function includes 2nd and 5th 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 transfer for line differential protection (MDIF)The line differential communication can be arranged 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. This means that a 64 kbit/s communication channel is needed between every IED included in the same line differential protection zone. In the latter, cur-rent samples are sent from all slave IEDs to one master IED where the evaluation is made, and trip

Protected zone

Comm. Channel

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RED670

RED670

RED670

Comm. ChannelComm. Channel

RED670

RED670

RED670

Protected zone

Comm. Channel

Comm. Channel

Comm. Channel

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1MRK 505 164-BENRevision: G, Page 8signals are sent to the remote ends when needed. In this 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 geographically apart from each other, must be time coordinated so that the current differential algorithm can be exe-cuted correctly. In RED 670 it is possible to make this coordination in two different ways. The echo method of time synchronizing is normally used whereas for applications where transmit and receive times can differ, the optional built in GPS receivers shall be used.

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

Distance protection

Distance protection zones (PDIS, 21)The line distance protection is a three zone full scheme protection with three fault loops for phase to phase faults and three fault loops for phase to earth fault for each of the independent zones. Indi-vidual settings for each zone resistive and reactive reach gives flexibility for use on overhead lines and 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 (see figure 8).

Figure 8: Typical distance protection zone with load 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

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RED670

Protected zone

Comm.Channels

RED670

RED670

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RED670

RED670

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R

X

Forwardoperation

Reverseoperation


1MRK 505 164-BENRevision: G, Page 9able built in phase selection makes the function suitable in applications with single phase auto-reclosing.

Built-in adaptive load compensation algorithm prevents overreaching of zone1 at load exporting end at phase-to-earth faults on heavily loaded power lines.

The distance protection zones can operate, inde-pendent of each other, in directional (forward or reverse) or non-directional mode. This makes them suitable, together with different communication schemes, 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 fault currents during a power swing can block the power swing detection function to allow fault clearance.

Automatic switch onto fault logic (PSOF)Automatic switch onto fault logic is a function that gives 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 is dead.

Current protection

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

Four step phase overcurrent protection (POCM, 51_67)The four step phase overcurrent function has an inverse or definite time delay independent for each step separately.

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

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

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

eighty percent of the power line at minimum source impedance. The function can be configured to measure the residual current from the three phase current inputs or the current from a separate current input.

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

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

The function can be set to be directional, forward, reverse or non-directional independently for each of 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 functionality are available as well.

The function can be configured to measure the residual current from the three phase current inputs or the current from a separate current input.

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

A thermal overload will often not be detected by other 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 an I2t characteristic with settable time constant and a thermal memory.

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

Breaker failure protection (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.


1MRK 505 164-BENRevision: G, Page 10A current check with extremely short reset time is used as a check criteria to achieve a high security against unnecessary operation.

The breaker failure protection can be single- or three-phase started to allow use with single phase tripping applications. For the three-phase version of the breaker failure protection the current criteria can be set to operate only if two out of four e.g. two phases or one phase plus the residual current starts. This gives a higher security to the back-up trip 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 an incorrect starting due to mistakes during testing.

Stub protection (PTOC, 50STB)When a power line is taken out of service for maintenance and the line disconnector is opened in multi-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 the current transformers and the open disconnector. The three phase instantaneous overcurrent function is released from a NO (b) auxiliary contact on the line disconnector.

Pole discordance protection (RPLD, 52PD)Single pole operated circuit breakers can due to electrical or mechanical failures end up with the different poles in different positions (close-open). This can cause negative and zero sequence cur-rents which gives thermal stress on rotating machines 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 on information from auxiliary contacts of the circuit breaker for the three phases with additional criteria from unsymmetrical phase current when required.

Voltage protection

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

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

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

The function can be used as open line end detector, normally then combined with directional reactive over-power function or as system voltage supervi-sion, normally then giving alarm only or switching in reactors or switch out capacitor banks to control the voltage.

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

The overvoltage function has an extremely high reset ratio to allow setting close to system service voltage.

Two step residual overvoltage protection (POVM, 59N)Residual voltages will occur in the power system during earth faults.

The function can be configured to calculate the residual voltage from the three phase voltage input transformers or from a single phase voltage input transformer fed from an open delta or neutral point voltage transformer.

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

Frequency protection

Underfrequency protection (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-up etc.

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

Up to two independent under frequency function instances are available.

Overfrequency protection (PTOF, 81)Overfrequency will occur at sudden load drops or shunt faults in the power network. In some cases close to generating part governor problems can also cause overfrequency.

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

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


1MRK 505 164-BENRevision: G, Page 11phase, phase-to-phase or positive sequence voltage measurement.

Up to two independent over frequency function instances are available.

Rate-of-change frequency protection (PFRC, 81)Rate of change of frequency function gives an early 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 voltage measurement.

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

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

Multipurpose protection

General current and voltage protection (GAPC)The function can be utilized as a negative sequence current protection detecting unsymmetri-cal conditions such as open phase or unsymmetri-cal faults.

The function can also be used to improve phase selection for high resistive earth faults, outside the distance 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 currents and this phase selection will be used in conjunc-tion with the detection of the earth fault from the directional earth fault protection function.

Secondary system supervision

Current circuit supervision (RDIF)Open or short circuited current transformer cores can cause unwanted operation of many protection functions such as differential, earth fault current and negative sequence current functions.

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

The current circuit supervision function compares the 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 the circuit and is used as alarm or to block protection functions expected to give unwanted tripping.

Fuse failure supervision (RFUF)Failures in the secondary circuits of the voltage transformer 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 sequence voltage without any zero sequence current. This is a useful principle in a directly earthed system and can detect one or two phase fuse failures.

The method based on detection of negative sequence voltage without any negative sequence current. This is a useful principle in a non-directly earthed system and can detect one or two phase fuse failures.

The method based on detection of du/dt-di/dt where a change of the voltage is compared to a change in the current. Only voltage changes means a voltage transformer fault. This principle can detect 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 ensure that closing can be done safely.

The function includes a built-in voltage selection scheme 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 different settings, e.g. the allowed frequency difference can be set to allow wider limits for the auto-reclose attempt than for the manual closing.

Autorecloser (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 faults respectively.

Multiple autoreclosing functions are provided for multi-breaker arrangements. A priority circuit allows one circuit breaker to close first and the second will only close if the fault proved to be transient.


1MRK 505 164-BENRevision: G, Page 12Each autoreclosing function can be configured to co-operate with a synchrocheck function.

Apparatus control (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 from other functions such as interlocking, synchro-check, operator place selection and external or internal blockings.

InterlockingThe interlocking function blocks the possibility to operate primary switching devices, for instance when a disconnector is under load, in order to pre-vent material damage and/or accidental human injury.

Each apparatus control function has interlocking modules included for different switchyard arrange-ments, where each function handles interlocking of one bay. The interlocking function is distributed to each IED and is not dependent on any central func-tion. For the station-wide interlocking, the IEDs communicate via the system-wide interbay bus (IEC 61850-8-1) or by using hard wired binary inputs/outputs. The interlocking conditions depend on the circuit configuration and apparatus position status 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 modules containing logic for the interlocking conditions. The interlocking conditions can be altered, to meet the customers specific requirements, by adding configurable logic by means of the graphical con-figuration tool.

Scheme communication

Scheme communication logic for distance protection and directional residual overcurrent protection (PSCH, 85)To achieve instantaneous fault clearance for all line 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-in communication module (LDCM) can be used for scheme communication signalling when included.

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

Current reversal and weak-end infeed logic for distance protection and directional residual overcurrent protection (PSCH, 85)The current reversal function is used to prevent unwanted operations due to current reversal when

using permissive overreach protection schemes in application with parallel lines when the overreach from the two ends overlaps on the parallel line.

The weak-end infeed logic is used in cases where the apparent power behind the protection can be too low to activate the distance protection func-tion. When activated, received carrier signal together with local under voltage criteria and no reverse 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, local acceleration logic (ZCLC) can be used. This logic enables 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 auto re-closer (zone extension) or by the loss of load current (loss-of-load acceleration).

Logic

Tripping logic (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 prolongation to ensure a trip pulse of sufficient length, as well as all functionality necessary for correct co-operation with autoreclosing functions.

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

Trip matrix logic (GGIO, 94X)Twelve trip matrix logic blocks are included in the IED. 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 in the PCM 600 engineering tool and this allows the user to adapt the signals to the physical tripping outputs according to the specific application needs.

Configurable logic blocksA high number of logic blocks and timers are available for user to adapt the configuration to the specific application needs.

Fixed signal function blockThe fixed signals function block generates a num-ber of pre-set (fixed) signals that can be used in the configuration of an IED, either for forcing the unused inputs in the other function blocks to a cer-tain level/value, or for creating a certain logic.


1MRK 505 164-BENRevision: G, Page 13Monitoring

Measurements (MMXU)The service value function is used to get on-line information from the IED. These service values makes it possible to display on-line information on the local HMI and on the Substation automation system 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 currents

and 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 measure and process signals from different measuring transducers. Many devices used in process control represent various parameters such as frequency, temperature and DC battery voltage as low current values, usually in 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 is equipped with the mA input module.

Event counter (GGIO)The function consists of six counters which are used 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 be used 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 is accomplished by the disturbance report functional-ity.

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

The disturbance report functionality is a common name 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 flexibility regarding configuration, starting conditions, recording times and large storage capacity.

A disturbance is defined as an activation of an input in the DRAx or DRBy function blocks which is 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 the IED in the standard Comtrade format. The same applies to all events, which are continuously saved in a ring-buffer. The Local Human Machine Inter-face (LHMI) is used to get information about the recordings, but the disturbance report files may be uploaded to the PCM 600 (Protection and Control IED Manager) and further analysis using the dis-turbance handling tool.

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

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

Indications (RDRE)To get fast, condensed and reliable information about disturbances in the primary and/or in the secondary system it is important to know e.g. binary signals that have changed status during a disturbance. This information is used in the short perspective to get information via the LHMI in a straightforward way.

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

The Indication list function shows all selected binary input signals connected to the Disturbance Report function that have changed status during a disturbance.

Event recorder (RDRE)Quick, complete and reliable information about disturbances 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


1MRK 505 164-BENRevision: G, Page 14actions) and in the long term (e.g. Functional Analysis).

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

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

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

Trip value recorder (RDRE)Information about the pre-fault and fault values for currents and voltages are vital for the disturbance evaluation.

The Trip value recorder calculates the values of all selected analogue input signals connected to the Disturbance report function. The result is magni-tude and phase angle before and during the fault for 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 (Comtrade file).

Disturbance recorder (RDRE)The Disturbance Recorder function supplies fast, complete and reliable information about distur-bances 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. corrective actions) and long perspective (e.g. Functional Analysis).

The Disturbance Recorder acquires sampled data from all selected analogue input and binary signals connected to the Disturbance Report function (maximum 40 analog and 96 binary signals). The binary signals are the same signals as available under the event recorder function.

The function is characterized by great flexibility and is not dependent on the operation of protection functions. It can record disturbances not detected by protection functions.

The disturbance recorder information for the last 100 disturbances are saved in the IED and the Local Human Machine Interface (LHMI) is used to view the list of recordings.

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

Event function block. The event function block is used for LON and SPA communication.

Analog and double indication values are also transferred through the event block.

Fault locator (RFLO)The accurate fault locator is an essential compo-nent to minimize the outages after a persistent fault and/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 high accuracy achieved by compensating for load cur-rent and for the mutual zero sequence effect on double 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 the fault position. The fault can be recalculated with new source data at the actual fault to further increase the accuracy.

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

Metering

Pulse counter logic (GGIO)The pulse counter logic function counts externally generated binary pulses, for instance pulses com-ing from an external energy meter, for calculation of energy consumption values. The pulses are cap-tured by the binary input module and then read by the pulse counter function. A scaled service value is available over the station bus. The special Binary input module with enhanced pulse counting capabilities must be ordered to achieve this func-tionality.

Basic IED functions

Time synchronizationUse the time synchronization source selector to select a common source of absolute time for the IED when it is a part of a protection system. This makes comparison of events and disturbance data between all IEDs in a SA system possible.

Human machine interfaceThe local human machine interface is available in a small, and a medium sized model. The principle difference 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 single line diagram with up to 15 objects on each page.


1MRK 505 164-BENRevision: G, Page 15Six 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 is divided into zones, each of them with a well-defined functionality:

Status indication LEDs Alarm indication LEDs which consists of 15

LEDs (6 red and 9 yellow) with user printable label. All LEDs are configurable from the PCM 600 tool

Liquid crystal display (LCD) Keypad with push buttons for control and nav-

igation purposes, switch for selection between local and remote control and reset

An isolated RJ45 communication port

Figure 9: Small graphic HMI

Figure 10: Medium graphic HMI, 15 controllable objects

Station communication

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 the Substation Automation (SA) bus or Substation Monitoring (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 communication protocolSingle or double optical Ethernet ports for the new substation communication standard IEC61850-8-1 for the station bus are provided. IEC61850-8-1 allows intelligent devices (IEDs) from different vendors to exchange information and simplifies SA engineering. Peer- to peer communication according 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 between existing ABB IED's and the new IED 670.


1MRK 505 164-BENRevision: G, Page 16SPA communication protocolA single glass or plastic port is provided for the ABB SPA protocol. This allows extensions of sim-ple substation automation systems but the main use is for Substation Monitoring Systems SMS.

IEC 60870-5-103 communication protocolA single glass or plastic port is provided for the IEC60870-5-103 standard. This allows design of simple substation automation systems including equipment from different vendors. Disturbance files uploading is provided.

Single command, 16 signalsThe IEDs can receive commands either from a substation automation system or from the local human-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 IEC60870-5-103 communication protocols the Event and Multiple Command function blocks are used as the commu-nication interface for vertical communication to station HMI and gateway and as interface for hori-zontal peer-to-peer communication (over LON only).

Remote communication

Binary signal transfer to remote end, 8 signalsThe binary signal transfer function can be used for sending and receiving of eight communication scheme related signals, transfer trip and/or other binary signals between line differential IEDs. The number of function blocks depends on the number of remote terminals. An IED can communicate with 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) is used for communication between the IEDs situated at distances


1MRK 505 164-BENRevision: G, Page 17module 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 IED communicates.

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

GPS time synchronization module (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 measuring transformers. The module has twelve inputs in dif-ferent combinations.

High impedance resistor unitThe high impedance resistor unit, with resistors for pick-up value setting and a voltage dependent resistor, is available in a single phase unit and a three phase unit. Both are mounted on a 1/1 19 inch apparatus plate with compression type term-nals.

Layout and dimensions

Dimensions

Mounting alternativesFollowing mounting alternatives (IP40 protection 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) 210.1 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 mounting alternatives.

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


1MRK 505 164-BENRevision: G, Page 18Connection diagrams

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

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

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

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, BTRM 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, BLDCM X313:A, BTRM X401, 411

Module Rear PositionsPSM X11BIM, BOM or IOM X31 and X32 etc. to X131 and X132MIM X31, X41, etc. or X131GSM X131SLM X301:A, B, C, DOEM X311:A, B, C, DLDCM X312:A, BLDCM X313:A, BTRM 1 X401TRM 2 X411


1MRK 505 164-BENRevision: G, Page 19Figure 13: Transformer input module (TRM)

CT/VT-input designation according to figure 13Current/voltage configuration (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, 5A and 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 XA corresponds to rear position X31, X41, etc. and input contacts named XB to rear position X32, X42, etc.

Figure 15: mA input module (MIM)


1MRK 505 164-BENRevision: G, Page 20Figure 16: Binary in/out module (IOM). Input contacts named XA corresponds to rear position 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 connector for plastic as ordered

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

5) Front communication port, Ethernet, RJ45 connector

Figure 18: Power supply module (PSM)

Figure 19: GPS time synchronization module (GSM)


1MRK 505 164-BENRevision: G, Page 21Figure 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.


1MRK 505 164-BENRevision: G, Page 22Figure 21: Typical connection diagram for a single breaker arrangement with control integrated.

CC

TC

TC

P1

-QB1-QB2

-QA1

-BI1

QB1-OPENQB1-CLQB2-OPENQB2-CL

QA1-OPENQA1-CL

QA1-SPR UNCH

QA1-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 < 40 ms 48 V/1 A

110 V/0.4 A220 V/0.2 A250 V/0.15 A

Parameter Reference value Nominal range InfluenceAmbient temperature, oper-ate value

+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 - -

Dependence on Reference value Within nominal range InfluenceRipple, in DC auxiliary voltageOperative range

max. 2%Full wave rectified

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%Interruption interval

050 ms No restart0 s Correct behaviour at

power downRestart time


1MRK 505 164-BENRevision: G, Page 27Table 16: Insulation

Table 17: Environmental tests

Table 18: CE compliance

Table 19: Mechanical tests

Differential protectionTable 20: High impedance differential protection (PDIF, 87)

Table 21: Line differential protection (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 -25C IEC 60068-2-1Storage test Test Ad for 16 h at -40C IEC 60068-2-1Dry heat test Test Bd for 16 h at +70C 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 and humidity 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 Ur for U < Ur

1.0% of U for U > UrReset ratio >95% -Maximum continuous voltage U>Trip2/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 -

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

2.0% of I at I >IrSlopeSection2 (10.0-50.0)% -SlopeSection3 (30.0-100.0)% -EndSection 1 (20150)% of Ibase -EndSection 2 (1001000)% of Ibase -Unrestrained limit function (1005000)% of Ibase 2.0% of Ir at I Ir

2.0% of I at I > IrSecond harmonic blocking (5.0100.0)% of fundamental 2.0% of IrFifth harmonic blocking (5.0100.0)% of fundamental 5.0% of IrInverse characteristics, see table 71 and table 72

19 curve types See table 71 and table 72

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

Test Type test values Reference standards


1MRK 505 164-BENRevision: G, Page 28Distance protectionTable 22: Distance protection zones (PDIS, 21)

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

Table 24: Power swing detection (RPSB, 78)

Table 25: Automatic switch onto fault logic (PSOF)

Reset time 15 ms typically at 10 to 0 x Id -Critical impulse time 2 ms typically at 0 to 10 x Id -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 Ibase -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 UrCurrent range: (0.5-30) x IrAngle: 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


1MRK 505 164-BENRevision: G, Page 29Current protectionTable 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 lbase 1.0% of Ir at I Ir

1.0% of I at I > IrReset 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 -Operate time 10 ms typically at 0 to 10 x Iset -Reset time 35 ms typically at 10 to 0 x Iset -Critical impulse time 2 ms typically at 0 to 10 x Iset -Dynamic overreach < 5% at = 100 ms -

Function Setting range AccuracyOperate current (1-2500)% of lbase 1.0% of Ir at I Ir

1.0% of I at I > IrReset ratio > 95% -Min. operating current (1-100)% of lbase 1.0% of IrRelay 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 IrIndependent 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 x Iset -Reset time, start function 25 ms typically at 2 to 0 x Iset -Critical impulse time 10 ms typically at 0 to 2 x Iset -Impulse margin time 15 ms typically -


1.0% of I at I > IrReset 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 -Operate time 10 ms typically at 0 to 10 x Iset -Reset time 35 ms typically at 10 to 0 x Iset -Critical impulse time 2 ms typically at 0 to 10 x Iset -Dynamic overreach < 5% at = 100 ms -


1.0% of I at I > IrReset ratio > 95% -Operate current for directional compari-son

(1100)% of lbase 1.0% of Ir

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 IrRelay characteristic angle (-180 to 180) degrees 2.0 degreesMinimum polarizing voltage (1100)% of Ubase 1.0% of UrOperate time, start function 25 ms typically at 0 to 2 x Iset -Reset time, start function 25 ms typically at 2 to 0 x Iset -Critical impulse time 10 ms typically at 0 to 2 x Iset -Impulse margin time 15 ms typically -


1MRK 505 164-BENRevision: G, Page 30Table 30: Thermal overload protection, one time constant (PTTR, 26)

Table 31: Breaker failure protection (RBRF, 50BF)

Table 32: Stub protection (PTOC, 50STB)

Table 33: Pole discordance protection (RPLD, 52PD)

Voltage protectionTable 34: Two step undervoltage protection (PUVM, 27)

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

I = Imeasured

Ip = load current before overload occursTime constant = (01000) minutes

IEC 60255-8, class 5 + 200 ms

Alarm temperature (0-200)C 2.0% of heat content tripTrip 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 lbase 1.0% of Ir at I Ir

1.0% of I at I > IrReset ratio, phase current > 95% -Operate residual current (2-200)% of lbase 1.0% of Ir at I Ir

1.0% of I at I > IrReset ratio, residual current > 95% -Phase current level for blocking of con-tact 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 msOperate time for current detection 10 ms typically -Reset time for current detection 15 ms maximum -

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

1.0% of I at I > IrReset ratio > 95% -Definite time (0.000-60.000) s 0.5% 10 msOperate time, start function 25 ms typically at 0 to 2 x Iset -Reset time, start function 25 ms typically at 2 to 0 x Iset -Critical impulse time 10 ms typically at 0 to 2 x Iset -Impulse margin time 15 ms typically -

Function Range or value AccuracyOperate current (0100% of Ibase 1.0% of IrTime delay (0.000-60.000) s 0.5% 10 ms

2 2

2 2lnp

b

I It

I I

=

Function Range or value AccuracyOperate voltage, low and high step (1100)% of Ubase 1.0% of UrAbsolute hysteresis (0100)% of Ubase 1.0% of UrInternal blocking level, low and high step

(1100)% of Ubase 1.0% of Ur

Inverse time characteristics for low and 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 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 -Impulse margin time 15 ms typically -


1MRK 505 164-BENRevision: G, Page 31Table 35: Two step overvoltage protection (POVM, 59)

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

Frequency protectionTable 37: Underfrequency protection (PTUF, 81)

Table 38: Overfrequency protection (PTOF, 81)

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

Function Range or value AccuracyOperate voltage, low and high step (1-200)% of Ubase 1.0% of Ur at U < Ur

1.0% of U at U > UrAbsolute hysteresis (0100)% of Ubase 1.0% of Ur at U < Ur

1.0% of U at U > UrInverse time characteristics for low and 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 Uset -Reset time, start function 25 ms typically at 2 to 0 x Uset -Critical impulse time 10 ms typically at 0 to 2 x Uset -Impulse margin time 15 ms typically -

Function Range or value AccuracyOperate voltage, low and high step (1-200)% of Ubase 1.0% of Ur at U < Ur 1.0% of U at U

> UrAbsolute hysteresis (0100)% of Ubase 1.0% of Ur at U < Ur

1.0% of U at U > UrInverse time characteristics for low and 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 Uset -Reset time, start function 25 ms typically at 2 to 0 x Uset -Critical impulse time 10 ms typically at 0 to 2 x Uset -Impulse margin time 15 ms typically -

Function Range or value AccuracyOperate 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 msReset time, definite time function (0.000-60.000)s 0.5% + 10 msVoltage dependent time delay

U=Umeasured

Settings:UNom=(50-150)% of UbaseUMin=(50-150)% of UbaseExponent=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 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 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/s Operate value, internal blocking level (0-100)% of Ubase 1.0% of UrOperate time, start function 100 ms typically -

( )ExponentU UMin

t tMax tMin tMinUNom UMin

= +


1MRK 505 164-BENRevision: G, Page 32Multipurpose protectionTable 40: General current and voltage protection (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 Ibase 1.0% of Ir for IIrStart undercurrent, step 1 and 2 (2 - 150)% of Ibase 1.0% of Ir for IIrDefinite time delay (0.00 - 6000.00) s 0.5% 10 msOperate time start overcurrent 25 ms typically at 0 to 2 x Iset -Reset time start overcurrent 25 ms typically at 2 to 0 x Iset -Operate time start undercurrent 25 ms typically at 2 to 0 x Iset -Reset time start undercurrent 25 ms typically at 0 to 2 x Iset -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 - 3.000TR: 0.005 - 600.000CR: 0.1 - 10.0

See table 71 and table 72

Voltage level where voltage memory 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 UUr

Start undervoltage, step 1 and 2 (2.0 - 150.0)% of Ubase 1.0% of Ur for UUr

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

Directional function Settable: NonDir, forward and reverse -Relay characteristic angle (-180 to +180) degrees 2.0 degreesRelay operate angle (1 to 90) degrees 2.0 degreesReset ratio, overcurrent > 95% -Reset ratio, undercurrent < 105% -Reset ratio, overvoltage > 95% -Reset ratio, undervoltage < 105% -Overcurrent:Critical impulse time 10 ms typically at 0 to 2 x Iset -Impulse margin time 15 ms typically -Undercurrent:Critical impulse time 10 ms typically at 2 to 0 x Iset -Impulse margin time 15 ms typically -Overvoltage:Critical impulse time 10 ms typically at 0 to 2 x Uset -Impulse margin time 15 ms typically -


1MRK 505 164-BENRevision: G, Page 33Secondary system supervisionTable 41: Current circuit supervision (RDIF)

Table 42: Fuse failure supervision (RFUF)

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

Table 44: Autorecloser (RREC, 79)

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


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

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

5.0% of I at I > Ir

Function Range or value AccuracyOperate voltage, zero sequence (1-100)% of Ubase 1.0% of UrOperate current, zero sequence (1100)% of Ibase 1.0% of IrOperate voltage, negative sequence (1100)% of Ubase 1.0% of UrOperate current, negative sequence (1100)% of Ibase 1.0% of IrOperate voltage change level (1100)% of Ubase 5.0% of UrOperate current change level (1100)% of Ibase 5.0% of Ir

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

1.0% of U at U > UrReset ratio, synchrocheck > 95% -Frequency difference limit between bus and line

(0.003-1.000) Hz 2.0 mHz

Phase angle difference limit between bus and line

(5.0-90.0) degrees 2.0 degrees

Voltage difference limit between bus 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 msVoltage high limit for energizing check (50.0-120.0)% of Ubase 1.0% of Ur at U Ur

1.0% of U at U > UrReset ratio, voltage high limit > 95% -Voltage low limit for energizing check (10.0-80.0)% of Ubase 1.0% of UrReset ratio, voltage low limit < 105% -Maximum voltage for energizing (80.0-140.0)% of Ubase 1.0% of Ur at U Ur

1.0% of U at U > UrTime 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 -


1MRK 505 164-BENRevision: G, Page 34Scheme communicationTable 45: Scheme communication logic for distance protection (PSCH, 85)

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

Table 47: Scheme communication logic for residual overcurrent protection (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 AR becomes 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 guard detection

(0.000-60.000) s 0.5% 10 ms

Operation mode of unblocking logic OffNoRestartRestart

-

Function Range or value AccuracyDetection level phase to neutral voltage (10-90)% of Ubase 1.0% of UrDetection level phase to phase voltage (10-90)% of Ubase 1.0% of UrReset ratio 95% -


1MRK 505 164-BENRevision: G, Page 35LogicTable 49: Tripping logic (PTRC, 94)

Table 50: Configurable logic blocks

MonitoringTable 51: Measurements (MMXU)

Table 52: Supervision of mA input signals (MVGGIO)

Table 53: Event counter (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 infeed logic

(0.00060.000) s 0.5% 10 ms


Function Range or value AccuracyTrip action 3-ph, 1/3-ph, 1/2/3-ph -Minimum trip pulse length (0.000-60.000) s 0.5% 10 msTimers (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) fr 2.0 mHzVoltage (0.1-1.5) Ur 0.5% of Ur at U Ur

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

0.5% of I at I > IrActive 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 Ur0.2 x Ir < I < 4.0 x Ir


Apparent power, S 0.1 x Ur < U < 1.5 x Ur0.2 x Ir < I < 4.0 x Ir


Power factor, cos () 0.1 x Ur < U < 1.5 x Ur0.2 x Ir < I < 4.0 x Ir

0.02

Function Range or value AccuracymA measuring function 5, 10, 20 mA

0-5, 0-10, 0-20, 4-20 mA 0.1 % of set value 0.005 mA

Max current of transducer to input (-20.00 to +20.00) mAMin current of transducer to input (-20.00 to +20.00) mAAlarm level for input (-20.00 to +20.00) mAWarning level for input (-20.00 to +20.00) mAAlarm hysteresis for input (0.0-20.0) mA

Function Range or value AccuracyCounter value 0-10000 -Max. count up speed 10 pulses/s -


1MRK 505 164-BENRevision: G, Page 36Table 54: Disturbance report (RDRE)

Table 55: Fault locator (RFLO)

MeteringTable 56: Pulse counter logic (GGIO)

Station communicationTable 57: IEC 61850-8-1 communication protocol

Table 58: LON communication protocol

Table 59: SPA communication protocol

Table 60: IEC 60870-5-103 communication 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 Trip Value recorder per recording

30 -

Maximum number of indications in a disturbance report

96 -

Maximum number of events in the Event recording per recording

150 -

Maximum number of events in the Event list

1000, first in - first out -

Maximum total recording time (3.4 s recording 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 UrCurrent range: (0.5-30) x Ir

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


1MRK 505 164-BENRevision: G, Page 37Table 61: SLM LON port

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

Remote communicationTable 63: Line data communication module (LDCM)

Hardware

IEDTable 64: Case

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

Table 66: Weight

Connection systemTable 67: CT and VT circuit connectors

Table 68: Binary I/O connection system

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 valueType 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 SynchronousTransmission 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 areaTerminal blocks of feed through type 250 V AC, 20 A 4 mm2

Connector type Rated voltage Maximum conductor areaScrew compression type 250 V AC 2.5 mm2

2 1 mm2


1MRK 505 164-BENRevision: G, Page 38Basic IED functionsTable 69: Self supervision with internal event list

Table 70: Time synchronization, time tagging

Inverse characteristicsTable 71: Inverse time characteristics ANSI

Table 72: Inverse time characteristics IEC

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

Function ValueTime tagging resolution, Events and Sampled Measurement Values

1 ms

Time tagging error with synchronization once/min (minute pulse synchronization), Events and Sampled Measurement Values

1.0 ms typically

Time tagging error with SNTP synchronization, Sampled Measurement Values

1.0 ms typically

Function Range or value AccuracyOperate characteristic:

Reset characteristic:

I = Imeasured/Iset

k = 0.05-999 in steps of 0.01 unless 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=21.6

ANSI Normal Inverse no 3 A=0.0086, B=0.0185, P=0.02, tr=0.46

ANSI Moderately Inverse no 4 A=0.0515, B=0.1140, P=0.02, tr=4.85

ANSI 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=

trt kI

( )1=

P

At k

I


1MRK 505 164-BENRevision: G, Page 39Table 73: Inverse time characteristics for Two step undervoltage protection (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 0.001TR=(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

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 AccuracyType A curve:

U< = UsetU = Umeasured

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

Type B 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


( )= +

P

At B k

I C

( )=

PR

TRt k

I CR

1

0.2360.339

=

t k

I

5.8 1.35=

tI

Ink

=<

= UsetU = Umeasured

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

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

=

>

buyer's guide line differential protection ied red 670

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