1mrk505188-ben b en buyeras guide line differential protection ied red 670 pre-config 1.1

7/28/2019 1MRK505188-BEN B en BuyerAs Guide Line Differential Protection IED RED 670 Pre-Config 1.1

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Buyer's GuideLine differential protection IEDRED 670 Pre-configured

1MRK 505 188-BENProduct version: 1.1

Revision: BIssued: November 2007

Data subject to change without notice

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

A protection, , and monitoring IED with extensivefunctional library and configuration possibilitiesand expandable hardware design to meet spe-cific user requirements

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 doublebreaker, 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-methodor built-in GPS

Full scheme phase-to-phase and phase-to-earthdistance protection with up to three zones:

- Alternative choice of series compen-sated/advanced application quadrilateralfunction, quadrilateral function or mho func-tion

- Special quadrilateral version with phase pref-erence logic and sensitive directional earthfault function for high ohmic earthed system.

- All types of scheme communication includingphase segregated communication for securephase selection at simultaneous faults

- Load encroachment feature

Power swing detection including additional logic

Pole slip protection

- Detection of slips in power systems from 0.2to 8Hz

- Trip after a set number of slips

Directional power protection- Reverse-, low forward-, active-, reactive

power protection

- Phase angle compensation

- Two steps (alarm/trip)

Synchronizing, synchrocheck and dead-linecheck function for single- or multi-breakerarrangements:

- Selectable energizing direction

- Two functions with built-in voltage selection

- For automatic and manual synchronizing andsynchrocheck with different settings

- Synchronizing of asynchronous networkswith settable breaker closing time

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

- Two functions with priority circuits formulti-breaker arrangements

- Co-operation with synchronizing, synchro-check function

- Can be switched On-Off from remote throughcommunication, from medium size LHMI orwith local switches through binary inputs

Selectable additional software functions such asdistance protection, control and monitoring

Data communication modules for station bus

IEC 61850-8-1


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

1MRK 505 188-BEN

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Data communication modules for station busIEC 60870-5-103, TCP/IP or EIA-485 DNP 3.0,LON and SPA

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

Function for energy calculation and demandhandling

- Outputs from measurement function (MMXU)can be used to calculate energy. Active aswell as reactive values are calculated inimport respectively export direction. Valuescan be read or generated as pulses. Maxi-mum demand power values are also calcu-lated by the function.

Time synchronization over IEC 61850-8-1, LON,SPA, binary input or with optional GPS module(GSM) or IRIG-B module

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

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 configuration, set-ting and disturbance evaluation

Appl ication 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 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 suitablefor protection of cable feeders to generator blocktransformers.

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. Remote

communication 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 threephase reclosing includes priority circuits formulti-breaker arrangements. It co-operates withthe synchronism check function with high-speedor delayed reclosing.

High set instantaneous phase and earth overcur-rent, four step directional or un-directional delayedphase and earth overcurrent, thermal overload andtwo 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 controland interlocking functionality including co-opera-tion with the synchronism check function to allowintegration of the main or back-up control.

The advanced logic capability, where the userlogic 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 andfast 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 andthe refurbishment of existing installations.

Four packages has been defined for followingapplications:

Single-breaker (double or single bus) with

three phase tripping (A31)

Single-breaker (double or single bus) with 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 analog and binary IO are configurable fromthe Signal matrix tool without need of configura-tion changes. Analogue and tripping IO has beenpre-defined for basic use on the, as standard sup-plied one binary input module and one binary out-put module.

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

The applications are shown in figures 1 and2 forsingle resp. multi-breaker arrangement.

The application on a high ohmic earthed system isshown in figure 1.

Refer to the Application manual for pre-config-

ured analog and binary IO.


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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

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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->O CLOSE

TRIP

25

94/86

79

3Id/I>

CB1

CB2

TRIPCB1/3

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FIBRE OPTIC OR TO MUX

3U>

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3U

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AvailablefunctionsANSI Func tio n descri pti on Sing le breaker,

3-phase tripp ing(A31)

Multi breaker,

3-phase trippi ng(B31)

Singel breaker,

1-phase trippi ng(A32)

Multi breaker,

1-phase tri pping(B32)

Basic Option(Qty/optiondesign)




Differential protection

(Only one alternative can be selected)

87 1 phase High impedance differential protection (PDIF) - 3/A02 - 3/A02 - 3/A02 - 3/A02

87L 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

Impedance pr otection

21 Distance protection zones, quadrilateral characteristic (PDIS) - 3/B01 - 3/B01 - 3/B01 - 3/B01

21 Distance measuring zone, quadrilateral characteristic for seriescompensated lines (PDIS)

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

21 Full-scheme distance protection, mho characteristic (PDIS) - 3/B07 - 3/B07 - 3/B07 - 3/B07

78 Power swing detection (RPSB) - 1/B01/B06/B07

- 1/B01/B06/B07

- 1/B01/B06/B07

- 1/B01/B06/B07

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

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

Automatic switch onto fault logic, voltage and current based(PSOF)

- 1/B01/B06/B07

- 1/B01/B06/B07

- 1/B01/B06/B07

- 1/B01/B06/B07

Current protection

50 Instantaneous phase overcurrent protection (PIOC) 1 - 1 - 1 - 1 -

51/67 Four step phase overcurrent protection (PTOC) 1 - 1 - 1 - 1 -

50N Instantaneous residual overcurrent protection (PIOC) - 1/C04 - 1/C04 - 1/C04 - 1/C04

51N/67N Four step residual overcurrent protection (PTOC) - 1/C04 - 1/C04 - 1/C04 - 1/C04

67N Sensitive directinal residual overcurrent and power protection(PSDE)

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

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

52PD Pole discordance protection (RPLD) 1 - 2 - 1 - 2 -

Directional underpower protection (PDUP) - 1/C17 - 1/C17 - 1/C17 - 1/C17

Directional overpower protection (PDOP) - 1/C17 - 1/C17 - 1/C17 - 1/C17

46 Broken conductor check 1 - 1 - 1 - 1 -

Voltage protection

27 Two step undervoltage protection (PTUV) 1 - 1 - 1 - 1 -

59 Two step overvoltage protection (PTOV) 1 - 1 - 1 - 1 -59N Two step residual overvoltage protection (PTOV) 1 - 1 - 1 - 1 -

24 Overexcitation protection (PVPH) - 1/D03 - 1/D03 - 1/D03 - 1/D03

60 Voltage differential protection (PTOV) 2 - 2 - 2 - 2 -

27 Loss of voltage check 1 - 1 - 1 - 1 -

Frequency pr otection

81 Underfrequency protection (PTUF) - 2/E02 - 2/E02 - 2/E02 - 2/E02

81 Overfrequency protection (PTOF) - 2/E02 - 2/E02 - 2/E02 - 2/E02

81 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 -


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Fuse failure supervision (RFUF) 3 - 3 - 3 - 3 -

Control

25 Synchrocheck, energizing check and synchronizing (RSYN) 1 - 2 - 1 - 2 -

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

Apparatus control for single bay,max8 apparatuses (1CB) incl. interlocking (APC8)

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

Apparatus control for single bay,max15apparatuses (2CBs) incl. interlocking (APC15)

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

Logic rotating switch for function selection and LHMI presenta-tion (GGIO)

15 - 15 - 15 - 15 -

Selector mini switch (GGIO) 20 - 20 - 20 - 20 -

Scheme communication

85 Scheme communication logic for distance or overcurrent protec-tion (PSCH)

-1/B01/B06/B07

-1/B01/B06/B07

-1/B01/B06/B07

-1/B01/B06/B07

85 Phase segregated scheme communication logic for distanceprotection (PSCH)

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

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

-1/B01/B06/B07

-1/B01/B06/B07

-1/B01/B06/B07

-1/B01/B06/B07

Current reversal and weak-end infeed logic for phase segre-gated communication (PSCH)

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

Local acceleration logic (ZCLC) - 1/B01 - 1/B01 - 1/B01 - 1/B01

85 Scheme communication logic forresidualovercurrentprotection (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

Logic

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

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

Monitoring

Measurements (MMXU) 6/10/6 - 6/10/6 - 6/10/6 - 6/10/6 -

Event counter (GGIO) 5 - 5 - 5 - 5 -

Disturbance report (RDRE) 1 - 1 - 1 - 1 -

IEC61850 generic communication I/O functions (GGIO) 16 - 16 - 16 - 16 -

Fault locator (RFLO) 1 - 1 - 1 - 1 -

Measured value calculation and demand handling 66 - 66 - 66 - 66 -

Metering

Pulse counter logic (GGIO) 16 - 16 - 16 - 16 -

Function for energy calculation and demand handling (MMTR) 6 - 6 - 6 - 6 -

Station commu nication

IEC61850-8-1 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 -

DNP3.0 for TCP/IP and EiA-485 communication protocol 1 - 1 - 1 - 1 -

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

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

Remote communication

Binary signal transfer 6 - 6 - 6 - 6 -

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

ANSI Func tio n descri pt ion Single b reaker,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)


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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 the sameturn ratio and similar magnetizing characteristic. Itutilizes an external summation of the phases andneutral current and a series resistor and a voltagedependent resistor externally to the relay.

Line differential protection, 3 or 6CTsets (PDIF, 87L)The line differential function applies the Kirch-hoff's law and compares the currents entering and

leaving the protected multiterminal circuit, con-sisting of overhead power lines, power transform-ers and cables. It offers phase-segregated truecurrent 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 circuitbreaker 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

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 tothe 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 currentless than 50 % of the differential current setting)connected as line taps (i.e. as "shunt" power trans-formers), without measurements of currents in thetap, can be handled. The normal load current ishere considered to be negligible, and special mea-sures need only to be taken in the event of a shortcircuit on the LV side of the transformer. In thisapplication, the tripping of the differential protec-tion can be time delayed for low differential cur-rents in order to achieve coordination with downstream over current relays.

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

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RED670

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Comm. Channel

Protected zone

Comm. Channel

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Line differential protection 3 or 6 CT sets,with in-zone transformers (PDIF, 87LT)Two 2-winding power transformers, or one3-winding power transformer, can be included in

the line differential protection zone. Both two- and

three-winding transformers are correctly repre-sented with vector group compensations made inthe algorithm. The function includes 2ndand 5thharmonic 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 forline 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 is

needed 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 tripsignals are sent to the remote ends when needed. Inthis system, a 64 kbit/s communication channel isonly needed between the master, and each one ofthe slave terminals.

Figure 6: Five terminal line with master-master system

Figure 7: Five terminal line with master-slave system

RED670

RED670

RED670

Protected zone

Comm. Channel

Comm. Channel

Comm. Channel

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RED670

RED670

RED670

RED670

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Comm.Channels

RED670

RED670

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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 make

this coordination in two different ways. The echomethod of time synchronizing is normally usedwhereas for applications where transmit andreceive 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.

Impedance protection

Distance measuring zones,quadrilateral characteristic (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 in resistive and reac-tive reach gives flexibility for use on overheadlines and cables of different types and lengths.

Mho alternative Quad characteristic is available.

The function has a functionality for load encroach-ment which increases the possibility to detect highresistive faults on heavily loaded lines (seefigure 8).

Figure 8: Typical quadrilateral distance protectionzone with load encroachment functionactivated

The independent measurement of impedance foreach fault loop together with a sensitive and reli-able built in phase selection makes the functionsuitable in applications with single phaseauto-reclosing.

Built-in adaptive load compensation algorithmprevents overreaching of zone1 at load exporting

end at phase to earth faults on heavily loadedpower lines.

The distance protection zones can operate, inde-

pendent of each other, in directional (forward orreverse) or non-directional mode. This makes themsuitable, together with different communicationschemes, for the protection of power lines andcables in complex network configurations, such asparallel lines, multi-terminal lines etc.

Distance protection zones, quadrilateralcharacteristic for series compensatedlines (PDIS)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 reactive

reach gives flexibility for use on overhead linesand cables of different types and lengths.

Quad characteristic is available.

The function has a functionality for load encroach-ment which increases the possibility to detect highresistive faults on heavily loaded lines seefigure 9figure 8.

Figure 9: Typical quadrilateral distance protectionzone with load encroachment functionactivated


Built-in adaptive load compensation algorithm forthe quadrilateral function prevents overreaching ofzone1 at load exporting end at phase to earth faultson heavily loaded power lines.

The distance protection zones can operate, inde-pendent of each other, in directional (forward orreverse) or non-directional mode. This makes them

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suitable, together with different communicationschemes, for the protection of power lines andcables in complex network configurations, such asparallel lines, multi-terminal lines etc.

Full-scheme distance measuring, Mhocharacterist ic, PDIS 21The numerical mho line distance protection is athree zone full scheme protection for back-updetection of short circuit and earth faults. The fullscheme technique provides back-up protection ofpower lines with high sensitivity and low require-ment on remote end communication. The threezones have fully independent measuring and set-tings which gives high flexibility for all types oflines.

The modern technical solution offers fast operatingtime down to 3/4 cycles.

The IED can be used up to the highest voltage lev-els. It is suitable for the protection of heavilyloaded lines and multi-terminal lines where therequirement for tripping is one, two-, and/or threepole.


Built-in adaptive load compensation algorithmprevents overreaching at phase-to-earth faults on

heavily loaded power lines, see figure 10.

Figure 10: Load encroachment influence on theoffset mho characteristic

The distance protection zones can operate, inde-pendent of each other, in directional (forward orreverse) or non-directional mode. This makes themsuitable, together with different communicationschemes, for the protection of power lines andcables in complex network configurations, such asparallel lines, multi-terminal lines etc.

The possibility to use the phase-to-earth quadrilat-eral impedance characteristic together with themho characteristic increases the possibility toovercome eventual lack of sensitivity of the mho

element due to the shaping of the curve at remoteend faults.

The integrated control and monitoring functionsoffers effective solutions for operating and moni-toring all types of transmission and sub transmis-sion lines.

Phase selection with load encroachment(PDIS, 21)The operation of transmission networks today is inmany cases close to the stability limit. Due to envi-ronmental considerations the rate of expansion andreinforcement of the power system is reduced e.g.difficulties to get permission to build new power

lines. The ability to accurately and reliable classifythe different types of fault so that single pole trip-ping and auto-reclosing can be used plays animportant roll in this matter. The phase selectionfunction is designed to accurately select the properfault loop in the distance function dependent onthe fault type.

The heavy load transfer that is common in manytransmission networks may make fault resistancecoverage difficult to achieve. Therefore the func-tion has a built in algorithm for load encroach-ment, which gives the possibility to enlarge theresistive setting of both the phase selection and themeasuring zones without interfering with the load.

The extensive output signals from the phase selec-tion gives also important information about faultyphase(s) which can be used for fault analysis.

Directional impedance Mho (RDIR)The phase-to-earth impedance elements can beoptionally supervised by a phase unselective direc-tional function (phase unselective, because it isbased on symmetrical components).

Faulty phase identification with loadenchroachment (PDIS, 21)The operation of transmission networks today is inmany cases close to the stability limit. Due to envi-ronmental considerations the rate of expansion andreinforcement of the power system is reduced e.g.difficulties to get permission to build new powerlines. The ability to accurate and reliable classify-ing the different types of fault so that single poletripping and auto-reclosing can be used plays animportant roll in this matter. The phase selectionfunction is design to accurate select the properfault loop in the distance function dependent onthe fault type.

The heavy load transfer that is common in manytransmission networks may in some cases interferewith the distance protection zone reach and causeunwanted operation. Therefore the function has abuilt in algorithm for load encroachment, whichgives the possibility to enlarge the resistive setting

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of the measuring zones without interfering withthe load.

The output signals from the phase selection func-

tion produce important information about faultyphase(s) which can be used for fault analysis aswell.

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

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

Power swing logic (RPSL, 78)

Additional logic is available to secure tripping forfaults during power swings and prevent tripping atpower swings started by a fault in the network.

Pole slip protection (PPAM, 78)Sudden events in an electrical power system suchas large changes in load, fault occurrence or faultclearance, can cause power oscillations referred toas power swings. In a non-recoverable situation,the power swings become so severe that the syn-chronism is lost, a condition referred to as poleslipping. The main purpose of the pole slip protec-tion is to detect, evaluate, and take the requiredaction for pole slipping occurrences in the powersystem. The electrical system parts swinging toeach other can be separated with the line/s closestto the centre of the power swing allowing the twosystems to be stable as separated islands.

Automatic swi tch onto faul t logic , voltageand cur rent based (PSOF)Automatic switch onto fault logic is a function thatgives an instantaneous trip at closing of breakeronto a fault. A dead line detection check is pro-vided to activate the function when the line isdead.

Current protection

Instantaneous phase overcurrentprotection (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 fault current 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 definedtime characteristic.

The function can be set to be directional ornon-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 for instantaneous earth fault protection,with the reach limited to less than typical eightypercent of the line at minimum source impedance.The function can be configured to measure theresidual current from the three phase current inputsor the current from a separate current input.

Four step residual overcurrentprotection (PTOC, 51N/67N)The four step residual single input overcurrentfunction has an inverse or definite time delay inde-pendent for each step separately.

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

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

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

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

Directional operation can be combined togetherwith corresponding communication blocks intopermissive 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.

Sensitive directional residual overcurrentand power protection (PSDE, 67N)In isolated networks or in networks with highimpedance earthing, the earth fault current is sig-nificantly smaller than the short circuit currents. Inaddition to this, the magnitude of the fault currentis almost independent on the fault location in thenetwork. The protection can be selected to useeither the residual current or residual power com-ponent 3U03I0cos ,for operating quantity. Thereis also available one nondirectional 3I0 step andone 3U0 overvoltage tripping step.


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Thermal overload protection, one timeconstant (PTTR, 26)The increasing utilizing of the power system closerto the thermal limits have generated a need of a

thermal overload function also for power lines.

A thermal overload will often not be detected byother protection functions and the introduction ofthe 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 failure pro tection (RBRF, 50BF)The circuit breaker failure function ensures fastback-up tripping of surrounding breakers. Thebreaker failure protection operation can be currentbased, contact based or adaptive combinationbetween these two principles.

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- orthree-phase initiated to allow use with single phasetripping applications. For the three-phase version

of 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 avoidunnecessary tripping of surrounding breakers at anincorrect initiation due to mistakes during testing.

Stub p rotection (PTOC, 50STB)When a power line is taken out of service formaintenance 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 notbe 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 discordance protection (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 or negative sequence current func-tions.

Normally the own breaker is tripped to correct the

positions. If the situation consists the remote endcan be intertripped to clear the unsymmetrical loadsituation.

The pole discordance function operates based oninformation from auxiliary contacts of the circuitbreaker for the three phases with additional criteriafrom unsymmetrical phase current when required.

Directional over/underpower protection(PDOP, 32) and (PDUP, 37)These two functions can be used wherever ahigh/low active, reactive or apparent power protec-tion or alarming is required. Alternatively they canbe used to check the direction of active or reactive

power flow in the power system. There are numberof applications where such functionality is needed.Some of them are:

detection of reversed active power flow

detection of high reactive power flow

Each function has two steps with definite timedelay. Reset times for every step can be set as well.

Broken conductor checkThe main purpose of the BRC broken conductorcheck function is the detection of broken conduc-tors on protected power lines and cables (series

faults). Detection can be used to give alarm only ortrip the line breaker.

Voltage protection

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

The function has two voltage steps, each with

inverse or definite time delay.

Two step overvoltageprotection (PTOV, 59)Overvoltages will occur in the power system dur-ing abnormal conditions such as sudden powerloss, 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.


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

Two step residual overvoltageprotection (PTOV, 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.

Overexcitation p rotect ion (PVPH, 24)

When the laminated core of a power transformeror generator is subjected to a magnetic flux densitybeyond its design limits, stray flux will flow intonon-laminated components not designed to carryflux and cause eddy currents to flow. The eddycurrents can cause excessive heating and severedamage to insulation and adjacent parts in a rela-tively short time. Function has settable inverseoperating curve and independent alarm stage.

Voltage di fferential protection (PTOV, 60)A voltage differential monitoring function is avail-able. It compares the voltages from two threephase sets of voltage transformers and has one sen-sitive alarm step and one trip step. It can be used tosupervise the voltage from two fuse groups or twodifferent voltage transformers fuses as a fuse/MCBsupervision function.

Loss of voltage check (PTUV, 27)The loss of voltage detection, (PTUV, 27), is suit-able for use in networks with an automatic Systemrestoration function. The function issues athree-pole trip command to the circuit breaker, ifall three phase voltages fall below the set value fora time longer the set time and the circuit breakerremains closed.

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-upetc.

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

Overfrequency protection (PTOF, 81)Overfrequency will occur at sudden load drops orshunt faults in the power network. In some cases

close 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 loadrestoring.


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.


Each step can discriminate between positive ornegative change of frequency.

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 system 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 compares

the residual current from a three phase set of cur-rent transformer cores with the neutral point cur-


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1MRK 505 188-BEN


rent on a separate input taken from another set ofcores on the current transformer.

A detection of a difference indicates a fault in the

circuit 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, neutralpoint voltage protection, energizing function (syn-chronism check) etc. The fuse failure supervisionfunction 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 is

a useful principle in a directly earthed system andcan 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

Synchronizing, synchrocheck and energiz-ing check (RSYN, 25)The Synchronizing function allows closing ofasynchronous networks at the correct momentincluding the breaker closing time. The systemscan thus be reconnected after an auto-reclose ormanual closing which improves the network sta-bility.

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 ringbusbar arrangements.

Manual closing as well as automatic reclosing canbe checked by the function and can have differentsettings.

For systems which are running asynchronous asynchronizing function is provided. The main pur-pose of the synchronizing function is to providecontrolled closing of circuit breakers when twoasynchronous systems are going to be connected.It is used for slip frequencies that are larger than

those for synchrocheck and lower than a set maxi-mum level for the synchronizing function.

Autorecloser (RREC, 79)The autoreclosing function provides high-speedand/or delayed auto-reclosing for single ormulti-breaker applications.

Up to five reclosing attempts can be programmed.The first attempt can be single-, two and/or threephase for single phase or multi-phase faultsrespectively.

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

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

Apparatus cont rol (APC)The apparatus control is a function for control andsupervision of circuit breakers, disconnectors andearthing 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 orinternal 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 ofone 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 dependon 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.

Logic rotating switch for funct ion selectionand LHMI presentation (SLGGIO)The SLGGIO function block (or the selectorswitch function block) is used within the CAP toolin order to get a selector switch functionality simi-lar with the one provided by a hardware selectorswitch. Hardware selector switches are used exten-sively by utilities, in order to have different func-

tions operating on pre-set values. Hardwareswitches are however sources for maintenance


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issues, lower system reliability and extended pur-chase portfolio. The virtual selector switches elim-inate all these problems.

Selector min i swi tch (VSGGIO)The VSGGIO function block (or the versatileswitch function block) is a multipurpose functionused within the CAP tool for a variety of applica-tions, as a general purpose switch.

The switch can be controlled from the menu orfrom a symbol on the SLD of the LHMI.

Single point generic control 8 signals(SPC8GGIO)The SC function block is a collection of 8 singlepoint commands, designed to bring in commandsfrom REMOTE (SCADA) or LOCAL (HMI) tothose parts of the logic configuration that do notneed complicated function blocks that have thecapability to receive commands (for exampleSCSWI). In this way, simple commands can besent directly to the IED outputs, without confirma-tion. Confirmation (status) of the result of the com-mands is supposed to be achieved by other means,such as binary inputs and SPGGIO functionblocks.

Scheme communication

Scheme communication logic fordistance 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 forscheme communication signalling when included.

Phase segregated communication is also availablefor correct operation at simultaneous faults whenthree distance protection communication channelsare available between the line ends

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

Three phase or phase segregated scheme logic isavailable.

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 loadcurrent (loss-of-load acceleration).

Scheme communication log icfor residual overcurrent protection(PSCH, 85)To achieve fast fault clearance of earth faults onthe part of the line not covered by the instanta-neous step of the residual overcurrent protection,the directional residual overcurrent protection canbe supported with a logic that uses communicationchannels.

In the directional scheme, information of the faultcurrent direction must be transmitted to the otherline end. With directional comparison, an operatetime of the protection of 50 60 ms including achannel transmission time of 20 ms, can beachieved. This short operate time enables rapidautoreclosing function after the fault clearance.

The communication logic module for directional

residual current protection enables blocking aswell as permissive under/overreach schemes.

Current reversal and weak-end infeed logicfor residual overcurrent protection(PSCH, 85)The EFCA additional communication logic is asupplement to the EFC scheme communicationlogic for the residual overcurrent protection.

To achieve fast fault clearing for all earth faults onthe line, the directional earth-fault protection func-tion can be supported with logic, that uses commu-nication channels. REx 670 terminals have for thisreason available additions to scheme communica-

tion logic.

If parallel lines are connected to common busbarsat both terminals, overreaching permissive com-munication schemes can trip unselectively due tofault current reversal. This unwanted trippingaffects the healthy line when a fault is cleared onthe other line. This lack of security can result in atotal loss of interconnection between the twobuses. To avoid this type of disturbance, a faultcurrent-reversal logic (transient blocking logic)can be used.

Permissive communication schemes for residualovercurrent protection, can basically operate only

when the protection in the remote terminal candetect the fault. The detection requires a sufficient


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minimum residual fault current, out from this ter-minal. The fault current can be too low due to anopened breaker or high positive and/or zerosequence source impedance behind this terminal.

To overcome these conditions, weak end infeed(WEI) echo logic is used.

Logic

Tripp ing 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 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 logic (GGIO)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 otherlogical 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 number of logic blocks and timers are available

for user to adapt the configuration to the specificapplication 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.

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 currents

and voltages,

mA, input currents

pulse counters,

event 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 equippedwith the mA input module.

Event counter (GGIO)The function consists of six counters which areused for storing the number of times each counterinput has been activated.

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 analoginput and binary signals connected to the functionblock i.e. maximum 40 analog and 96 binary sig-nals.

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.


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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 savedin 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 li st (RDRE)Continuous event-logging is useful for monitoringof the system from an overview perspective and is

a complement to specific disturbance recorderfunctions.

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.

Indications (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 shortperspective 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 selectedbinary input signals connected to the DisturbanceReport function that have changed status during adisturbance.

Event recorder (RDRE)Quick, complete and reliable information aboutdisturbances in the primary and/or in the second-

ary system is vital e.g. time tagged events loggedduring disturbances. This information is used fordifferent purposes in the short term (e.g. correctiveactions) 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 recorder (RDRE)Information about the pre-fault and fault values forcurrents and voltages are vital for the disturbanceevaluation.

The Trip value recorder calculates the values of allselected analog input signals connected to the Dis-turbance report function. The result is magnitudeand phase angle before and during the fault foreach analog input signal.

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

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

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 andsecondary equipment during and after a distur-bance. Recorded information is used for differentpurposes in the short perspective (e.g. correctiveactions) and long perspective (e.g. FunctionalAnalysis).

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

under the event recorder function.

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

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

Event function (EV)When using a Substation Automation system withLON or SPA communication, time-tagged events

can 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 theEvent function block. The event function block isused for LON and SPA communication.

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

Fault locato r (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-


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1MRK 505 188-BEN


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 furtherincrease 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 advancedcompensation included in fault locator.

Measured value expander block

The functions MMXU (SVR, CP and VP), MSQI(CSQ and VSQ) and MVGGIO (MV) are providedwith measurement supervision functionality. Allmeasured values can be supervised with four setta-ble limits, i.e. low-low limit, low limit, high limitand high-high limit. The measure value expanderblock (XP) has been introduced to be able to trans-late the integer output signal from the measuringfunctions to 5 binary signals i.e. below low-lowlimit, below low limit, normal, above high-highlimit or above high limit. The output signals can beused as conditions in the configurable logic.

Metering

Pulse counter log ic (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.

Energy metering and demand handling(MMTR)Outputs from measurement function (MMXU) canbe used to calculate energy. Active as well as reac-tive values are calculated in import respectivelyexport direction. Values can be read or generatedas pulses. Maximum demand power values arealso calculated by the function.

Basic IED functions

Time synchronizationUse the time synchronization source selector toselect a common source of absolute time for theIED when it is a part of a protection system. This

makes comparison of events and disturbance databetween 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 textand the medium size LCD can display the singleline diagram with up to 15 objects on each page.

Up to 12 SLD pages can be defined, depending onthe product capability.

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

The local human-machine interface is simple andeasy 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 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 11: Small graphic HMI


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Figure 12: Medium graphic HMI, 15 controllableobjects

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 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

DNP3.0 communication protocol

Theoretically, several protocols can be combinedin the same IED.

IEC 61850-8-1 communication protocolSingle 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.

SPA communication protocolA 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 communication protocolA single glass or plastic port is provided for theIEC60870-5-103 standard. This allows design ofsimple substation automation systems includingequipment from different vendors. Disturbancefiles uploading is provided.

DNP3.0 communication protocolAn electrical RS485 and an optical Ethernet port is

available for the DNP3.0 communication. DNP3.0Level 2 communication with unsolicited events,time synchronizing and disturbance reporting isprovided for communication to RTUs, Gatewaysor HMI systems.

Single command, 16 signalsThe IEDs can receive commands either from asubstation automation system or from the localhuman-machine interface, LHMI. The commandfunction block has outputs that can be used, forexample, to control high voltage apparatuses or forother user defined functionality.

Multiple command and transmit

When 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

Analog and binary signal t ransfer toremote endThree analog and eight binary signals can be

exchanged between two IEDs. This functionality ismainly used for the line differential protection.However it can be used in other products as well.An IED can communicate with up to 4 remoteIEDs.

Binary signal transfer to remote end,192 signalsIf the communication channel is used for transferof binary signals only, up to 192 binary signals canbe exchanged between two IEDs. For example,this functionality can be used to send informationsuch as status of primary switchgear apparatus orintertripping signals to the remote IED. An IEDcan communicate with up to 4 remote IEDs.


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

at distances


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IRIG-B Time synchronizing moduleThe IRIG-B time synchronizing module is used foraccurate time synchronizing of the IED from a sta-tion clock.

Electrical (BNC) and optical connection (ST) for0XX and 12X IRIG-B support.

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 of currents and voltage inputs.

Alternative connectors of Ring lug or Compres-

sion type can be ordered.

High impedance resistor uni tThe high impedance resistor unit, with resistors forpick-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 alternatives

Following 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 mm10.01 inches

(w) 210.1 mm

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

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

Wall mounting kit

See ordering for details about available mountingalternatives.

Figure 13: 1/2 x 19 case with rear cover Figure 14: Side-by-side mounting

Case size A B C D E F

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

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

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

(mm)

xx05000003.vsd

CB

E

F

A

D

xx05000004.vsd


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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 fo r 3/4 x 19 cas ing wi th 2 TRM s lo t

Module Rear Positions

PSM X11

BIM, BOM, SOM or IOM X31 and X32 etc. to X51 and X52

BIM, BOM, SOM, IOM or GSM X51, X52

SLM X301:A, B, C, D

IRIG-B 1) X302

OEM X311:A, B, C, D

RS485 or LDCM 2) 3) X312

LDCM 2) X313

TRM X401

1) IRIG-B installation, when included in seat P30:2

2) LDCM installation sequence: P31:2 or P31:3

3) RS485 installation, when included in seat P31:2

Note!

1 One LDCM can be included depending of availability of IRIG-Brespective RS485 modules.


PSM X11

BIM, BOM, SOM, IOM or MIM X31 and X32 etc. to X71 and X72

BIM, BOM, SOM, IOM, MIM orGSM

X71, X72

SLM X301:A, B, C, D

IRIG-B or LDCM 1,2) X302

LDCM 2) X303

OEM X311:A, B, C, D

RS485 or LDCM 2) 3) X312

LDCM 2) X313

LDCM 2) X322

LDCM 2) X323

TRM 1 X401

TRM 2 X411


2) LDCM installation sequence: P31:2, P31:3, P32:2, P32:3, P30:2and P30:3


Note!

2-4 LDCM can be included depending of availability of IRIG-B respec-tive RS485 modules.


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


PSM X11

BIM, BOM, SOM, IOMor MIM

X31 and X32 etc. to X131 and X132

BIM, BOM, SOM, IOM,MIM or GSM

X131, X132

SLM X301:A, B, C, D

IRIG-B or LDCM 1,2) X302

LDCM 2) X303

OEM X311:A, B, C, D

RS485 or LDCM 2) 3) X312

LDCM 2) X313

LDCM 2) X322

LDCM 2) X323

TRM 1 X401

TRM 2 X411


2) LDCM installation sequence: P31:2, P31:3, P32:2, P32:3,P30:2 and P30:3


Note!

2-4 LDCM can be included depending of availability ofIRIG-B respective RS485 modules.

Figure 15: Transformer inputmodule (TRM)

CT/VT-input designation according to figure 15

Current/voltageconfiguration (50/60 Hz)

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

12I (1A) 1A 1A 1A 1A 1A 1A 1A 1A 1A 1A 1A 1A

12I (5A) 5A 5A 5A 5A 5A 5A 5A 5A 5A 5A 5A 5A

9I (1A) and 3U 1A 1A 1A 1A 1A 1A 1A 1A 1A 110-220V 110-220V 110-220V

9I (5A) and 3U 5A 5A 5A 5A 5A 5A 5A 5A 5A 110-220V 110-220V 110-220V

5I (1A) and 4I(5A) and 3U

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

7I (1A) and 5U 1A 1A 1A 1A 1A 1A 1A 110-220V 110-220V 110-220V 110-220V 110-220V

7I (5A) and 5U 5A 5A 5A 5A 5A 5A 5A 110-220V 110-220V 110-220V 110-220V 110-220V

6I (1A) and 6U 1A 1A 1A 1A 1A 1A 110-220V 110-220V 110-220V 110-220V 110-220V 110-220V

6I (5A) and 6U 5A 5A 5A 5A 5A 5A 110-220V 110-220V 110-220V 110-220V 110-220V 110-220V

6I (1A) 1A 1A 1A 1A 1A 1A - - - - - -

6I (5A) 5A 5A 5A 5A 5A 5A - - - - - -


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Figure 16: 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 17: mA input module (MIM)


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Figure 18: Communication interfaces (OEM, LDCM, SLM and HMI)

Note to figure 18

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

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

3) Rear communication port RS485, terminal block

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

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

6) Rear communication prot IEC 61850, ST-connector

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

8) Front communication port Ethernet, RJ 45 connector

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

10) Rear communication port, terminal block

Figure 19: Power supply module (PSM)

Figure 20: GPS time synchronization module(GSM)


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Figure 22: Static output module (SOM)

Figure 21: 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.


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Figure 23: 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.


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Technical data General

Definitions

Energizing quantities, rated values and limits

Analog inputsTable 4: TRM - Energiz ing quant it ies, rated values and limits

Table 5: MIM - mA input module

Tab le 6: OEM - Op ti cal ethernet mod ule

Auxi liary DC vol tageTabl e 7: PSM - Pow er sup pl y m od ul e

Reference value:

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

Nominal range:

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

Operative range:

The range of values of a given energizing quantity for which the equipment, under specified conditions, is able to performits intended functions according to the specified requirements.

Quantity Rated value Nominal range

Current Ir =1 or 5 A (0.2-40) IrOperative range (0-100) x IrPermissive overload 4 Ir cont.

100 Ir for 1 s*)

Burden


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Binary inputs and outputsTable 8: BIM - Binary input module

Tab le 9: B IM - Binary inpu t module wi th enhanced pulse count ing capab il it ies

Tab le 10: IOM - B inary input /outpu t module

Table 11: IOM - Binary input/output module contact data (reference standard: IEC 61810-2)


Binary inputs 16 -

DC voltage, RL 24/40 V48/60 V

110/125 V

220/250 V

RL 20%RL 20%

RL 20%

RL 20%

Power consumption

24/40 V

48/60 V

110/125 V

220/250 V

max. 0.05 W/input

max. 0.1 W/input

max. 0.2 W/input

max. 0.4 W/input

-

Counter input frequency 10 pulses/s max -

Oscillating signal discriminator Blocking settable 140 Hz

Release settable 130Hz

Quantity Rated value Nominal rangeBinary inputs 16 -

DC voltage, RL 24/40 V

48/60 V

110/125 V

220/250 V

RL 20%

RL 20%

RL 20%

RL 20%

Power consumption

24/40 V

48/60 V

110/125 V

220/250 V

max. 0.05 W/input

max. 0.1 W/input

max. 0.2 W/input

max. 0.4 W/input

-

Counter input frequency 10 pulses/s max -

Balanced counter input frequency 40 pulses/s max -

Oscillating signal discriminator Blocking settable 140 Hz

Release settable 130Hz


Binary inputs 8 -

DC voltage, RL 24/40 V

48/60 V

110/125 V

220/250 V

RL 20%

RL 20%

RL 20%

RL 20%

Power consumption

24/40 V

48/60 V

110/125 V

220/250 V

max. 0.05 W/input

max. 0.1 W/input

max. 0.2 W/input

max. 0.4 W/input

-

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

Binary outputs 10 2

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

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

Current carrying capacity

Continuous

1 s

8 A

10 A

8 A

10 A

Making capacity at inductive load withL/R>10 ms

0.2 s

1.0 s30 A

10 A

0.4 A

0.4 A


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Table 12: SOM - Static output module data (reference standard: IEC 61810-2)

Table 13: BOM - Binary output module contact data(referencestandard: IEC 61810-2)

Influencing factorsTab le 14: Temperature and humidi ty inf luence

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

Breaking capacity for DC with L/R 10 ms

0.2 s

1.0 s

30 A

10 A

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

Breaking capacity for DC with L/R 0.4 250 V/8.0 ABreaking capacity for DC with L/R


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Table 15: Auxi l iary DC supply vol tage inf luence on funct ional i ty during operat ion

Table 16: Frequency influence (reference standard: IEC 602556)

Type tests according to standardsTab le 17: Elec tromagnet ic compat ib il it y

Table 18: Insulation

Tabl e 19: En vi ro nm ental tes ts

Dependence on Reference value Within nominal range Influence

Ripple, in DC auxiliary voltage

Operative 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 restart

0 s Correct behaviour atpower down

Restart time 100 M at 500 VDC

Test Type test value Reference standard

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

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


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Table 20: CE compliance

Tab le 21: Mech ani cal t es ts

Differential protectionTable 22: High impedance di fferent ia l protect ion (PDIF, 87)

Table 23: Line di fferent ial protect ion (PDIF, 87L, 87LT)

Impedance protectionTable 24: Distance measuring zone, Quad (PDIS, 21)

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

Damp heat test, steady state Test Ca for 4 days at +40 C and humidity93%

IEC 60068-2-78

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 to

Immunity EN 50263

Emissivity EN 50263

Low voltage directive EN 50178

Test Type test values Reference standards

Vibration Class I IEC 60255-21-1

Shock and bump Class I IEC 60255-21-2

Seismic Class I IEC 60255-21-3

Function Range or value Accuracy

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

Reset ratio >95% -

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

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

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

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

Function Range or value Accuracy

Minimum operate current (20-200)% of Ibase 2.0% of Ir at I Ir

1mrk505188-ben b en buyeras guide line differential protection ied red 670 pre-config 1.1

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