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Relion® 670 series

Generator protection REG670Pre-configuredProduct Guide

Contents

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

2. Available functions...............................................6

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

5. Hardware description.........................................23

6. Connection diagrams.........................................26

7. Technical data....................................................33

8. Ordering.............................................................76

Disclaimer

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

© Copyright 2010 ABB AB.

All rights reserved.

Trademarks

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

Generator protection REG670 1MRK 502 019-BEN BPre-configuredProduct version: 1.1 Issued: June 2010

2 ABB

1. Application

The REG670 is used for protection, controland monitoring of generators and generator-transformer blocks from relatively small unitsup to the largest generating units. The IEDhas a comprehensive function library,covering the requirements for most generatorapplications. The large number of analoginputs available enables, together with thelarge functional library, integration of manyfunctions in one IED. In typical applicationstwo units can provide total functionality, alsoproviding a high degree of redundancy.REG670 can as well be used for protectionand control of shunt reactors.

The protection function library includesdifferential protection for generator, block,auxiliary transformer and the wholegenerator block. Stator earth fault protection,both traditional 95% protection as well as

100% 3rd harmonic based stator earth faultprotection are included. The 100% protectionuses a differential voltage approach givinghigh sensitivity and a high degree of security.Well proven algorithms for pole slip,underexcitation, rotor earth fault, negativesequence current protections, and so on, areincluded in the IED.

The generator differential protection in theREG670 adapted to operate correctly forgenerator applications where factors as longDC time constants and requirement on shorttrip time have been considered.

As many of the protection functions can beused as multiple instances there arepossibilities to protect more than one objectin one IED. It is possible to have protectionfor an auxiliary power transformer integratedin the same IED having main protections forthe generator. The concept thus enables verycost effective solutions.

The REG670 also enables valuablemonitoring possibilities as many of theprocess values can be transferred to anoperator HMI.

The wide application flexibility makes thisproduct an excellent choice for both newinstallations and for refurbishment in existingpower plants.

Serial data communication is via opticalconnections to ensure immunity againstdisturbances.

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

Generator protection REG670 1MRK 502 019-BEN BPre-configuredProduct version: 1.1 Issued: June 2010Customized Revision: B

ABB 3

GI

U

OC4 PTOC

51/67 3I>

CV GAPC

64R Re<

ROV2 PTOV

59N UN>

STEF PHIZ

59THD U3d/N

GEN PDIF

87G 3Id/I

SA PTUF

81 f<

SA PTOF

81 f>

SDD RFUF

60FL

OEX PVPH

24 U/f>

UV2 PTUV

27 3U<

OV2 PTOV

59 3U>

CV MMXU

Meter.

Option

SDE PSDE

32N P0->

REG 670*1.1 – A20

Gen Diff + Back-up 12AI

ZMH PDIS

21 Z<

LEX PDIS

40 F <

GUP PDUP

37 P<

GOP PDOP

32 P

CV GAPC

46 I2>

CV GAPC

51/27 U

ROV2 PTOV

59N UN>

CC RBRF

50BF 3I> BF

TR PTTR

49 Ith

PSP PPAM

78 Ucos

SES RSYN

25

CV GAPC

51V I>/U

PH PIOC

50 3I>>

CV GAPC

50AE U/I>

CC RPLD

52PD PD

OC4 PTOC

51/67 3I>

Other functions available from the function library

+ RXTTE4

Please note that the use of function might require a different analog input!

en07000049.vsd

CC RDIF

87CT I2d/I

Function alternatives for 87G/GEN PDIF

T2W PDIF

87T 3Id/I

HZ PDIF

87 IdN

IEC07000049 V1 EN

Figure 1. Typical generator protection application with generator differential and back-upprotection, including 12 analog input transformers and half 19" case size.


4 ABB

en07000050.vsd

GI

U

CV GAPC64R Re<

ROV2 PTOV59N UN>

GEN PDIF87G 3Id/I

SA PTUF81 f<

SA PTOF81 f>

SDD RFUF60FL

OEX PVPH24 U/f>

UV2 PTUV27 3U<

OV2 PTOV59 3U>

CV MMXUMeter.

Option

SDE PSDE32N P0->

REG 670*1.1 – B30

Gen Diff + Back-up 24AI

ZMH PDIS21 Z<

LEX PDIS40 F <

GUP PDUP37 P<

GOP PDOP32 Pß

CCS RDIF87CT I2d/I

CV GAPC51/27 U

ROV2 PTOV59N UN>

OC4 PTOC51/67 3I>

CC RBRF50BF 3I> BF

CV GAPC46 I2>

TR PTTR49 Ith

PSP PPAM78 Ucos

SES RSYN25

CV GAPC51V I>/U

PH PIOC50 3I>>

CV GAPC50AE U/I>

CC RPLD52PD PD

OC4 PTOC51/67 3I>


+ RXTTE4

STEF PHIZ59THD U3d/N

T2W PDIF87T 3Id/I

REF PDIF87N IdN/I

Auxiliary Bus

EF4 PTOC51N/67N IN->

OC4 PTOC51/67 3I>

OC4 PTOC51/67 3I>

CC RBRF50BF 3I> BF


OC4 PTOC51/67 3I>

Main Protection

Back-up Protection

ROV2 PTOV59N UN>

T3W PDIF87T 3Id/I

CT S

IEC07000050 V1 EN

Figure 2. Enhanced generator protection application with generator differential and back-upprotection, including 24 analog input transformers and full 19" case size. Optionalpole slip protection and overall differential protection can be activated.


ABB 5

en07000051.vsd

GI

U

CV GAPC64R Re<

ROV2 PTOV59N UN>

STEF PHIZ59THD U3d/N

TR PTTR49 Ith

SA PTUF81 f<

CV MMXU

Meter.


REF PDIF87N IdN/I

OV2 PTOV59 3U>

T3W PDIF87T 3Id/I

REG 670*1.1 – C30

T2W PDIF87T 3Id/I

ROV2 PTOV59N UN>

Generator and block transformer protection 24AI

CV GAPC46 I2>

OC4 PTOC51/67 3I>

TR PTTR49 Ith

CC RBRF50BF 3I> BF

CT S

SDD RFUF

60FL

SDD RFUF

60FL

ZMH PDIS21 Z<

LEX PDIS40 F <

GUP PDUP37 P<

GOP PDOP32 Pß

PSP PPAM78 Ucos

Option

SA PTOF81 f>

OEX PVPH24 U/f>

UV2 PTUV27 3U<

OV2 PTOV59 3U>

SDE PSDE32N P0->

CV GAPC51/27 U

SES RSYN25

CV GAPC51V I>/U

PH PIOC50 3I>>

CC RPLD52PD PD

OC4 PTOC51/67 3I>


CV GAPC50AE U/I>

CCS RDIF87CT I2d/I

OC4 PTOC51/67 3I>

OC4 PTOC51/67 3I>

CC RBRF50BF 3I> BF

GEN PDIF87G 3Id/I+ RXTTE4

IEC07000051 V1 EN

Figure 3. Block protection including generator and generator transformer protection with 24analog input transformers and full 19" rack. The application is prepared to coverhydro as well as gas turbine arrangements.


6 ABB

2. Available functions

ANSI Function description Gen Diff + Back-up 12AI (A20)

Gen Diff + Back-up 24AI (B30)

Gen and blocktransformerprotection (C30)

Basic Option(Qty/optiondesign)



Differential protection

87T Transformer differential protection, two winding(T2WPDIF)

- 1/A11 - 1/A13 1 -

87T Transformer differential protection, three winding(T3WPDIF)

- - - 1/A13 1 -

87 1 phase High impedance differential protection(HZPDIF)

- 3/A02 3 - 6 -

87G Generator differential protection (GENPDIF) 1 - 2 - 2 -

87N Restricted earth fault protection, low impedance(REFPDIF)

- - - 1/A01 1 -

Impedance protection

21 Full-scheme distance protection, mho characteristic(ZMHPDIS)

3 - 3 - 3 -

21 Directional impedance element for mho characteristic(ZDMRDIR)

1 - 1 - 1 -

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

40 Loss of excitation (LEXPDIS) 1 - 2 - 2 -

Current protection

50 Instantaneous phase overcurrent protection (PHPIOC) 1 - 2 - 2 -

51/67 Four step phase overcurrent protection (OC4PTOC) 4 - 4 - 4 -

50N Instantaneous residual overcurrent protection(EFPIOC)

1 - 2 - 2 -

51N/67N

Four step residual overcurrent protection (EF4PTOC) 1 - 5 - 5 -

67N Sensitive directional residual overcurrent and powerprotection (SDEPSDE)

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

49 Thermal overload protection, two time constants(TRPTTR)

1 - 2 - 3 -

50BF Breaker failure protection (CCRBRF) 2 - 4 - 4 -

52PD Pole-discordance protection (CCRPLD) 2 - 2 - 2 -

32U Directional underpower protection (GUPPDUP) 2 - 4 - 4 -

32O Directional overpower protection (GOPPDOP) 2 - 4 - 4 -

Voltage protection

27 Two step undervoltage protection (UV2PTUV) 2 - 2 - 2 -

59 Two step overvoltage protection (OV2PTOV) 2 - 2 - 2 -

59N Two step residual overvoltage protection (ROV2PTOV) 3 - 3 - 3 -

24 Overexcitation protection (OEXPVPH) 1 - 1 - 2 -

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

59THD 100% stator e/f 3rd harmonic (STEFPHIZ) - 1/D21 1 - 1 -

Frequency protection

81 Underfrequency protection (SAPTUF) 3 - 6 - 6 -

81 Overfrequency protection (SAPTOF) 3 - 6 - 6 -

81 Rate-of-change frequency protection (SAPFRC) 1 - 3 - 3 -


ABB 7

ANSI Function description Gen Diff + Back-up 12AI (A20)

Gen Diff + Back-up 24AI (B30)

Gen and blocktransformerprotection (C30)




Multipurpose protection

General current and voltage protection (CVGAPC) 12 - 12 - 12 -

Secondary system supervision

Current circuit supervision (CCSRDIF) 4 - 5 - 5 -

Fuse failure supervision (SDDRFUF) 2 - 3 - 3 -

Control

25 Synchrocheck, energizing check and synchronizing(SESRSYN)

1 - 2 - 2 -

Apparatus control for up to 6 bays, max 30apparatuses incl. interlocking (APC30)

- 1/H09 - 1/H09 - 1/H09

Logic rotating switch for function selection and LHMIpresentation (SLGGIO)

15 - 15 - 15 -

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

Logic

94 Tripping logic (SMPPTRC) 2 - 4 - 4 -

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

Monitoring

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

Event counter (CNTGGIO) 5 - 5 - 5 -

Disturbance report (DRPRDRE) 1 - 1 - 1 -

IEC61850 generic communication I/O functions(SPGGIO)

64 64 64

Measured value expander block (RANGE_XP) 66 - 66 - 66 -

Metering

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

Function for energy calculation and demand handling(ETPMMTR)

6 - 6 - 6 -

Station communication

IEC61850-8-1 Communication *) 1 - 1 - 1 -

LON communication protocol *) 1 - 1 - 1 -

SPA communication protocol *) 1 - 1 - 1 -

IEC60870-5-103 communication protocol *) 1 - 1 - 1 -

DNP3.0 for TCP/IP and EIA-485 communicationprotocol

Single command, 16 signals 4 - 4 - 4 -

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

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

Remote communication

Binary signal transfer 6 - 6 - 6 -


8 ABB

4. Functionality


Generator differential protection GENPDIF

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

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

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

It is also of great importance that thegenerator differential protection does not tripfor external faults, with large fault currentsflowing from the generator.

To combine fast fault clearance, as well assensitivity and selectivity, the generatordifferential protection is normally the bestchoice for phase-to-phase generator shortcircuits.

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

Transformer differential protectionT2WPDIF/T3WPDIF

The functions Transformer differentialprotection, two-winding (T2WPDIF) andTransformer differential protection, three-winding (T3WPDIF) are provided withinternal CT ratio matching and vector groupcompensation and when required zerosequence current elimination is also madeinternally in the software.

The function can be provided with up to sixthree phase sets of current inputs. All currentinputs are provided with percentage biasrestraint features, making the IED suitable fortwo- or three-winding transformers in multi-breaker station arrangements.


ABB 9

Two-winding applications

xx05000048.vsd

IEC05000048 V1 EN

two-windingpowertransformer

xx05000049.vsd

IEC05000049 V1 EN

two-windingpowertransformer withunconnecteddelta tertiarywinding

xx05000050.vsd

IEC05000050 V1 EN

two-windingpowertransformer withtwo circuitbreakers on oneside

xx05000051.vsd

IEC05000051 V1 EN

two-windingpowertransformer withtwo circuitbreakers and twoCT-sets on bothsides

Three-winding applications

xx05000052.vsd

IEC05000052 V1 EN

three-windingpowertransformer withall threewindingsconnected

xx05000053.vsd

IEC05000053 V1 EN

three-windingpowertransformer withtwo circuitbreakers and twoCT-sets on oneside

xx05000057.vsd

IEC05000057 V1 EN

Autotransformerwith two circuitbreakers and twoCT-sets on twoout of three sides

Figure 4. CT group arrangement fordifferential protection andother protections

The setting facilities cover for applications ofthe differential protection to all types ofpower transformers and autotransformerswith or without load tap changer as well asfor shunt reactors or and local feeders withinthe station. An adaptive stabilizing feature isincluded for heavy through-faults. Byintroducing the load tap changer position, thedifferential protection pick-up can be set tooptimum sensitivity thus covering internalfaults with low fault level.

Stabilization is included for inrush currentsrespectively for overexcitation condition.Adaptive stabilization is also included forsystem recovery inrush and CT saturation forexternal faults. A fast high set unrestraineddifferential current protection is included forvery high speed tripping at high internal faultcurrents.

Innovative sensitive differential protectionfeature, based on the theory of symmetricalcomponents, offers best possible coverage forpower transformer windings turn-to-turnfaults.


10 ABB

1Ph High impedance differentialprotection HZPDIF

The 1Ph High impedance differentialprotection HZPDIF function can be usedwhen the involved CT cores have the sameturn ratio and similar magnetizingcharacteristic. It utilizes an externalsummation of the phases and neutral currentand a series resistor and a voltage dependentresistor externally to the IED.

Restricted earth fault protection (PDIF,87N)

Restricted earth-fault protection, lowimpedance function (REFPDIF) can be usedon all directly or low impedance earthedwindings. REFPDIF function can providehigher sensitivity (down to 5%) and higherspeed as it measures individually on eachwinding and thus do not need inrushstabilization.

The low impedance function is a percentagebiased function with an additional zerosequence current directional comparisoncriteria. This gives excellent sensitivity andstability for through faults. The functionallows use of different CT ratios andmagnetizing characteristics on the phase andneutral CT cores and mixing with otherfunctions and protection IEDs on the samecores.


Full-scheme distance measuring, Mhocharacteristic ZMHPDIS

The numerical mho line distance protection isathree zone full scheme protection for back-up detection of short circuit and earth faults.The three zones have fully independentmeasuring and settings, which gives highflexibility for all types of lines.

The function can be used as underimpedance back-up protection fortransformers and generators.

Directional impedance element for Mhocharacteristic ZDMRDIR

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

Pole slip protection PSPPPAM

The situation with pole slip of a generatorcan be caused by different reasons.

A short circuit may occur in the externalpower grid, close to the generator. If the faultclearing time is too long, the generator willaccelerate so much, that the synchronismcannot be maintained.

Un-damped oscillations occur in the powersystem, where generator groups at differentlocations, oscillate against each other. If theconnection between the generators is tooweak the magnitude of the oscillations willincrease until the angular stability is lost.

The operation of a generator having pole slipwill give risk of damages to the generator,shaft and turbine.

• At each pole slip there will be significanttorque impact on the generator-turbineshaft.

• In asynchronous operation there will beinduction of currents in parts of thegenerator normally not carrying current,thus resulting in increased heating. Theconsequence can be damages oninsulation and stator/rotor iron.

The Pole slip protection (PSPPPAM) functionshall detect pole slip conditions and trip thegenerator as fast as possible if the locus ofthe measured impedance is inside thegenerator-transformer block. If the centre ofpole slip is outside in the power grid, thefirst action should be to split the networkinto two parts, after line protection action. Ifthis fails there should be operation of thegenerator PSPPPAM in zone 2, to preventfurther damages to the generator, shaft andturbine.


ABB 11

Loss of excitation LEXPDIS

There are limits for the loss of excitation(LEXPDIS) of a synchronous machine. Areduction of the excitation current weakensthe coupling between the rotor and theexternal power system. The machine maylose the synchronism and start to operate likean induction machine. Then, the reactiveconsumption will increase. Even if themachine does not loose synchronism it maynot be acceptable to operate in this state for along time. LEXPDIS increases the generationof heat in the end region of the synchronousmachine. The local heating may damage theinsulation of the stator winding and even theiron core.

To prevent damages to the generator itshould be tripped at under-excitation.

Current protection

Instantaneous phase overcurrentprotection PHPIOC

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

Four step phase overcurrent protectionOC4PTOC

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

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

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

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

Instantaneous residual overcurrentprotection EFPIOC

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

Four step residual overcurrent protectionEF4PTOC

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

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

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

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

A second harmonic blocking can be setindividually for each step.

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

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

EF4PTOC can be configured to measure theresidual current from the three-phase currentinputs or the current from a separate currentinput.

Sensitive directional residual overcurrentand power protection SDEPSDE

In isolated networks or in networks withhigh impedance earthing, the earth faultcurrent is significantly smaller than the shortcircuit currents. In addition to this, the


12 ABB

magnitude of the fault current is almostindependent on the fault location in thenetwork. The protection can be selected touse either the residual current or residualpower component 3U0·3I0·cos j, foroperating quantity with maintained shortcircuit capacity. There is also available onenondirectional 3I0 step and one 3U0overvoltage tripping step.

Thermal overload protection, two timeconstant TRPTTR

If the temperature of a power transformer/generator reaches very high values theequipment might be damaged. The insulationwithin the transformer/generator will haveforced ageing. As a consequence of this therisk of internal phase-to-phase or phase-to-earth faults will increase. High temperaturewill degrade the quality of the transformer/generator oil.

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

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

Breaker failure protection CCRBRF

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

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

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

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

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

Pole discordance protection CCRPLD

Single pole operated circuit breakers can dueto electrical or mechanical failures end upwith the different poles in different positions(close-open). This can cause negative andzero sequence currents which gives thermalstress on rotating machines and can causeunwanted operation of zero sequence ornegative sequence current functions.

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

The Polediscordance protection functionCCRPLD operates based on information fromauxiliary contacts of the circuit breaker forthe three phases with additional criteria fromunsymmetrical phase current when required.

Directional over/underpower protectionGOPPDOP/GUPPDUP

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

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


ABB 13

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

Voltage protection

Two step undervoltage protectionUV2PTUV

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

UV2PTUV has two voltage steps, each withinverse or definite time delay.

Two step overvoltage protection OV2PTOV

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

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

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

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

Two step residual overvoltage protectionROV2PTOV

Residual voltages may occur in the powersystem during earth faults.

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

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

Overexcitation protection OEXPVPH

When the laminated core of a powertransformer or generator is subjected to amagnetic flux density beyond its designlimits, stray flux will flow into non-laminatedcomponents not designed to carry flux andcause eddy currents to flow. The eddycurrents can cause excessive heating andsevere damage to insulation and adjacentparts in a relatively short time. Overexcitationprotection OEXPVPH has settable inverseoperating curve and independent alarm stage.

Voltage differential protection VDCPTOV

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

95% and 100% Stator earth fault protectionbased on 3rd harmonic STEFPHIZ

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

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


14 ABB

will increase and there will be a current flowthrough the neutral point resistor.

To detect an earth fault on the windings of agenerating unit one may use a neutral pointovervoltage IED, a neutral point overcurrentIED, a zero sequence overvoltage IED or aresidual differential protection. Theseprotection schemes are simple and haveserved well during many years. However, atbest these simple schemes protect only 95%of the stator winding. They leave 5% at theneutral end unprotected. Under unfavorableconditions the blind zone may extend to 20%from the neutral.

The 95% stator earth fault measures thefundamental frequency voltage component inthe generator star point and it operates whenit exceeds the preset value. By applying thisprinciple approximately 95% of the statorwinding can be protected. In order to protectthe last 5% of the stator winding close to theneutral end the 3rd harmonic voltagemeasurement can be performed. In REG 670either the 3rd harmonic differential principleor the neutral point 3rd harmonicundervoltage principle can be applied.Combination of these two measuringprinciples provides coverage for entire statorwinding against earth faults.

Rotor earth fault (GAPC, 64R)

The field winding, including the rotorwinding and the non-rotating excitationequipment, is always insulated from themetallic parts of the rotor. The insulationresistance is high if the rotor is cooled by airor by hydrogen. The insulation resistance ismuch lower if the rotor winding is cooled bywater. This is true even if the insulation isintact. A fault in the insulation of the fieldcircuit will result in a conducting path fromthe field winding to earth. This means thatthe fault has caused a field earth fault.

The field circuit of a synchronous generatoris normally unearthed. Therefore, a singleearth fault on the field winding will causeonly a very small fault current. Thus the earthfault does not produce any damage in the

generator. Furthermore, it will not affect theoperation of a generating unit in any way.However, the existence of a single earth faultincreases the electric stress at other points inthe field circuit. This means that the risk for asecond earth fault at another point on thefield winding has increased considerably. Asecond earth fault will cause a field short-circuit with severe consequences.

The rotor earth fault protection is based oninjection of an AC voltage to the isolated fieldcircuit. In non-faulted conditions there willbe no current flow associated to this injectedvoltage. If a rotor earth fault occurs, thiscondition will be detected by the rotor earthfault protection. Depending on the generatorowner philosophy this operational state willbe alarmed and/or the generator will betripped.


Underfrequency protection SAPTUF

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

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

SAPTUF is provided with an under voltageblocking.

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

Overfrequency protection SAPTOF

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

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

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


ABB 15

SAPTOF is provided with an undervoltageblocking. The operation is based on single-phase, phase-to-phase or positive-sequencevoltage measurement.

Rate-of-change frequency protectionSAPFRC

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

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


General current and voltage protectionCVGAPC

The protection module is recommended as ageneral backup protection with manypossible application areas due to its flexiblemeasuring and setting facilities.

The built-in overcurrent protection featurehas two settable current levels. Both of themcan be used either with definite time orinverse time characteristic. The overcurrentprotection steps can be made directional withselectable voltage polarizing quantity.Additionally they can be voltage and/orcurrent controlled/restrained. 2nd harmonicrestraining facility is available as well. At toolow polarizing voltage the overcurrent featurecan be either blocked, made non directionalor ordered to use voltage memory inaccordance with a parameter setting.

Additionally two overvoltage and twoundervoltage steps, either with definite timeor inverse time characteristic, are availablewithin each function.

The general function suits applications withunderimpedance and voltage controlledovercurrent solutions. The general functioncan also be utilized for generator transformer

protection applications where positive,negative or zero sequence components ofcurrent and voltage quantities are typicallyrequired.


Current circuit supervision CCSRDIF

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

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

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

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

Fuse failure supervision (RFUF)

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

There are three methods to detect fuse failures.

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

The method based on detection of negativesequence voltage without any negativesequence current. This is a useful principle in


16 ABB

a non-directly earthed system and can detectone or two phase fuse failures.

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

Control

Synchronizing, synchrocheck andenergizing check SESRSYN

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

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

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

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

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

Apparatus control APC

The apparatus control is a function forcontrol and supervision of circuit breakers,disconnectors and earthing switches within abay. Permission to operate is given afterevaluation of conditions from other functionssuch as interlocking, synchrocheck, operator

place selection and external or internalblockings.

Features in the apparatus control function:

• Select-Execute principle to give highreliability

• Selection function to prevent simultaneousoperation

• Selection and supervision of operator place• Command supervision• Block/deblock of operation• Block/deblock of updating of position

indications• Substitution of position indications• Overriding of interlocking functions• Overriding of synchrocheck• Operation counter• Suppression of Mid position

Two types of command models can be used:

• Direct with normal security• SBO (Select-Before-Operate) with enhanced

security

Normal security means that only thecommand is evaluated and the resultingposition is not supervised. Enhanced securitymeans that the command is evaluated with anadditional supervision of the status value ofthe control object. The command securitywith enhanced security is always terminatedby a CommandTermination service primitive.

Control operation can be performed from thelocal HMI under authority control if so defined.

Logic rotating switch for functionselection and LHMI presentation SLGGIO

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


ABB 17

and extended purchase portfolio. The virtualselector switches eliminate all these problems.

Selector mini switch VSGGIO

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

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

Single point generic control 8 signalsSPC8GGIO

The Single point generic control 8 signals(SPC8GGIO) function block is a collection of8 single point commands, designed to bringin commands from REMOTE (SCADA) tothose parts of the logic configuration that donot need complicated function blocks thathave the capability to receive commands (forexample, SCSWI). In this way, simplecommands can be sent directly to the IEDoutputs, without confirmation. Confirmation(status) of the result of the commands issupposed to be achieved by other means,such as binary inputs and SPGGIO functionblocks.

Logic

Tripping logic SMPPTRC

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

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

Trip matrix logic TMAGGIO

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

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

Configurable logic blocks

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

• OR function block.

• INVERTER function blocks that inverts theinput signal.

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

• GATE function block is used for controllingif a signal should be able to pass from theinput to the output or not depending on asetting.

• XOR function block.

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

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

• AND function block.

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

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


18 ABB

before the interruption, or be reset. Resetinput has priority.

Fixed signal function block

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

Monitoring

Measurements

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

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

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

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

of the different parameters for includedfunctions

• logical values of all binary in- andoutputs and

• general IED information.

Supervision of mA input signals (MVGGIO)

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

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

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

Event counter CNTGGIO

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

Disturbance report DRPRDRE

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

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

Disturbance report functionality is a commonname for several functions:

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

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

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

Every disturbance report recording is savedin the IED in the standard Comtrade format.The same applies to all events, which arecontinuously saved in a ring-buffer. The localHMI is used to get information about therecordings, but the disturbance report filesmay be uploaded to PCM600 and furtheranalysis using the disturbance handling tool.


ABB 19

Event list DRPRDRE

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

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

Indications DRPRDRE

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

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

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

Event recorder DRPRDRE

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

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

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

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

Trip value recorder DRPRDRE

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

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

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

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

Disturbance recorder DRPRDRE

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

The Disturbance recorder acquires sampleddata from all selected analog input andbinary signals connected to the Disturbancereport function (maximum 40 analog and 96binary signals). The binary signals are thesame signals as available under the eventrecorder function.

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

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


20 ABB

Event function

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

Analog and double indication values are alsotransferred through EVENT function.

Measured value expander block RANGE_XP

The current and voltage measurementsfunctions (CVMMXU, CMMXU, VMMXU andVNMMXU), current and voltage sequencemeasurement functions (CMSQI and VMSQI)and IEC 61850 generic communication I/Ofunctions (MVGGIO) are provided withmeasurement supervision functionality. Allmeasured values can be supervised with foursettable limits that is low-low limit, low limit,high limit and high-high limit. The measurevalue expander block (RANGE_XP) has beenintroduced to be able to translate the integeroutput signal from the measuring functions to5 binary signals that is below low-low limit,below low limit, normal, above high-highlimit or above high limit. The output signalscan be used as conditions in the configurablelogic.

Metering

Pulse counter logic PCGGIO

Pulse counter (PCGGIO) function countsexternally generated binary pulses, forinstance pulses coming from an externalenergy meter, for calculation of energyconsumption values. The pulses are capturedby the binary input module and then read bythe pulse counter function. A scaled servicevalue is available over the station bus. Thespecial Binary input module with enhancedpulse counting capabilities must be orderedto achieve this functionality.

Function for energy calculation anddemand handling ETPMMTR

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

Basic IED functions

Time synchronization

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

Human machine interface

The local HMI is divided into zones withdifferent functionality.

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

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

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

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

• Isolated RJ45 communication port.


ABB 21

IEC07000083 V1 EN

Figure 5. Example of medium graphic HMI


Overview

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

Following communication protocols areavailable:

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

protocol• DNP3.0 communication protocol

Theoretically, several protocols can becombined in the same IED.

IEC 61850-8-1 communication protocol

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

61850-8-1 protocol allows intelligent devices(IEDs) from different vendors to exchangeinformation and simplifies systemengineering. Peer-to-peer communicationaccording to GOOSE is part of the standard.Disturbance files uploading is provided.

Serial communication, LON

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

SPA communication protocol

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

IEC 60870-5-103 communication protocol

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

DNP3.0 communication protocol

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

Single command, 16 signals

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


22 ABB

Multiple command and transmit

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


Analog and binary signal transfer toremote end

Three analog and eight binary signals can beexchanged between two IEDs. Thisfunctionality is mainly used for the linedifferential protection. However it can beused in other products as well. An IED cancommunicate with up to 4 remote IEDs.

Binary signal transfer to remote end, 192signals

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

Line data communication module, shortand medium range LDCM

The line data communication module (LDCM)is used for communication between the IEDssituated at distances <60 km or from the IEDto optical to electrical converter with G.703or G.703E1 interface located on a distances<3 km away. The LDCM module sends andreceives data, to and from another LDCMmodule. The IEEE/ANSI C37.94 standardformat is used.

5. Hardware description

Hardware modules

Power supply module PSM

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

Binary input module BIM

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

Binary output module BOM

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

Static binary output module SOM

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

Binary input/output module (IOM)

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


ABB 23

mA input module MIM

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

Optical ethernet module OEM

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

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

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

Line data communication module LDCM

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

Alternative cards for Medium range (1310 nmsingle mode) and Short range (850 nm multimode) are available.

Galvanic RS485 serial communicationmodule

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

GPS time synchronization module GSM

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

IRIG-B Time synchronizing module

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

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

Transformer input module TRM

The transformer input module is used togalvanically separate and transform thesecondary currents and voltages generated bythe measuring transformers. The module hastwelve inputs in different combinations ofcurrents and voltage inputs.

Alternative connectors of Ring lug orCompression type can be ordered.

High impedance resistor unit

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

Layout and dimensions

Dimensions


24 ABB

xx05000003.vsd

CB

E

F

A

D

IEC05000003 V1 EN

Figure 6. 1/2 x 19” case with rear cover

xx05000004.vsd

IEC05000004 V1 EN

Figure 7. 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, 1/1 x 19” 265.9 448.1 201.1 242.1 252.9 430.3

(mm)

Mounting alternatives

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

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

dimensions:


ABB 25

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

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

• Wall mounting kit

See ordering for details about availablemounting alternatives.


26 ABB

6. Connection diagrams

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

IEC08000471 BG V1 EN

Module Rear Positions

PSM X11

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

BIM, BOM, SOM, IOM orGSM

X51, X52

SLM X301:A, B, C, D

IRIG-B 1) X302

OEM X311:A, B, C, D

RS485 or LDCM 2) 3) X312

LDCM 2) X313

TRM X401

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


ABB 27

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


Module Rear Positions

PSM X11

BIM, BOM, SOM,IOM or MIM

X31 and X32 etc. to X131and X132

BIM, BOM, SOM,IOM, MIM orGSM

X131, X132

SLM X301:A, B, C, D

IRIG-B or LDCM1,2)

X302

LDCM 2) X303

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

RS485 or LDCM2) 3)

X312

LDCM 2) X313

LDCM 2) X322

LDCM 2) X323

TRM 1 X401

TRM 2 X411

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


28 ABB


Figure 8. Transformer input module (TRM)

￭ Indicates high polarity

CT/VT-input designation according to figure 8

Curr

ent/

volt

age

confi

gura

tion

(50/

60 H

z)

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

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

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

9I+3U,1A

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

9I+3U,5A

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

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

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

7I+5U,1A

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

7I+5U,5A

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

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

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

6I+6U,1A

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

6I+6U,5A

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

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

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

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


ABB 29


Figure 9. Binary input module (BIM). Inputcontacts named XA corresponds torear position X31, X41, and so on,and input contacts named XB torear position X32, X42, and so on.


Figure 10. mA input module (MIM)


30 ABB


Figure 11. Communication interfaces (OEM, LDCM, SLM and HMI)

Note to figure 11

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

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

3) Rear communication port RS485, terminal block

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

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

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

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

8) Front communication port Ethernet, RJ45 connector

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

10) Rear communication port, terminal block


Figure 12. Power supply module (PSM)


ABB 31


Figure 13. GPS time synchronization module (GSM)


Figure 14. Binary output module (BOM). Output contacts named XA corresponds to rearposition X31, X41, and so on, and output contacts named XB to rear positionX32, X42, and so on.


32 ABB


Figure 15. Static output module (SOM)


Figure 16. Binary in/out module (IOM). Input contacts named XA corresponds to rear positionX31, X41, and so on, and output contacts named XB to rear position X32, X42,and so on.


ABB 33

7. Technical data

General

Definitions

Referencevalue

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

Nominalrange

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

Operativerange

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

Energizing quantities, rated valuesand limits

Analog inputs

Table 3. TRM - Energizing quantities, rated values and limits

Quantity Rated value Nominal range

Current Ir = 1 or 5 A (0.2-40) × Ir

Operative range (0-100) x Ir

Permissive overload 4 × Ir cont.

100 × Ir for 1 s *)

Burden < 150 mVA at Ir = 5 A

< 20 mVA at Ir = 1 A

Ac voltage Ur = 110 V 0.5–288 V

Operative range (0–340) V

Permissive overload 420 V cont.450 V 10 s

Burden < 20 mVA at 110 V

Frequency fr = 50/60 Hz ± 5%

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


34 ABB

Table 4. MIM - mA input module

Quantity: Rated value: Nominal range:

Input resistance Rin = 194 Ohm -

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

-

Power consumptioneach mA-boardeach mA input

£ 4 W£ 0.1 W

-

Table 5. OEM - Optical ethernet module

Quantity Rated value

Number of channels 1 or 2

Standard IEEE 802.3u 100BASE-FX

Type of fiber 62.5/125 mm multimode fibre

Wave length 1300 nm

Optical connector Type ST

Communication speed Fast Ethernet 100 MB

Auxiliary DC voltage

Table 6. PSM - Power supply module


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

EL ± 20%EL ± 20%

Power consumption 50 W typically -

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


ABB 35

Binary inputs and outputs

Table 7. BIM - Binary input module


Binary inputs 16 -

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

RL ± 20%RL ± 20%RL ± 20%RL ± 20%

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

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

-

Counter input frequency 10 pulses/s max -

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

Table 8. BIM - Binary input module with enhanced pulse counting capabilities


Binary inputs 16 -


RL ± 20%RL ± 20%RL ± 20%RL ± 20%



-

Counter input frequency 10 pulses/s max -

Balanced counter input frequency 40 pulses/s max -

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


36 ABB

Table 9. IOM - Binary input/output module


Binary inputs 8 -


RL ± 20%RL ± 20%RL ± 20%RL ± 20%



-

Table 10. IOM - Binary input/output module contact data (reference standard: IEC61810-2)

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

Binary outputs 10 2

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

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

Current carrying capacityContinuous1 s

8 A10 A

8 A10 A

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

30 A10 A

0.4 A0.4 A

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

Breaking capacity for DC with L/R < 40ms

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

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

Maximum capacitive load - 10 nF


ABB 37

Table 11. SOM - Static Output Module (reference standard: IEC 61810-2): Static binaryoutputs

Function of quantity Static binary output trip

Rated voltage 48 - 60 VDC 110 - 250 VDC

Number of outputs 6 6

Impedance open state ~300 kΩ ~810 kΩ

Test voltage across opencontact, 1 min

No galvanic separation No galvanic separation

Current carrying capacity:

Continuous 5A 5A

1.0s 10A 10A

Making capacity at capacitiveload with the maximumcapacitance of 0.2 μF :

0.2s 30A 30A

1.0s 10A 10A

Breaking capacity for DC with L/R ≤ 40ms

48V / 1A 110V / 0.4A

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

220V / 0.2A

250V / 0.15A

Operating time <1ms <1ms


38 ABB

Table 12. SOM - Static Output module data (reference standard: IEC 61810-2):Electromechanical relay outputs

Function of quantity Trip and signal relays

Max system voltage 250V AC/DC

Number of outputs 6

Test voltage across open contact, 1 min 1000V rms

Current carrying capacity:

Continuous 8A

1.0s 10A

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

0.2s 30A

1.0s 10A

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

110V / 0.4A

125V / 0,35A

220V / 0,2A

250V / 0.15A

Table 13. BOM - Binary output module contact data (reference standard: IEC 61810-2)

Function or quantity Trip and Signal relays

Binary outputs 24

Max system voltage 250 V AC, DC

Test voltage across open contact, 1 min 1000 V rms

Current carrying capacityContinuous1 s

8 A10 A

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

30 A10 A

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

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


ABB 39

Influencing factors

Table 14. Temperature and humidity influence

Parameter Reference value Nominal range Influence

Ambienttemperature, operatevalue

+20 °C -10 °C to +55 °C 0.02% /°C

Relative humidityOperative range

10%-90%0%-95%

10%-90% -

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

Table 15. Auxiliary DC supply voltage influence on functionality during operation

Dependence on Referencevalue

Withinnominal range

Influence

Ripple, in DC auxiliary voltageOperative range

max. 2%Full waverectified

12% of EL 0.01% /%

Auxiliary voltage dependence,operate value

± 20% of EL 0.01% /%

Interrupted auxiliary DC voltage

24-60 V DC ±20%90-250 V DC ±20%

Interruptioninterval0–50 ms

No restart

0–∞ s Correct behaviour atpower down

Restart time <180 s

Table 16. Frequency influence (reference standard: IEC 60255–6)

Dependence on Within nominal range Influence

Frequency dependence, operatevalue

fr ± 2.5 Hz for 50 Hz

fr ± 3.0 Hz for 60 Hz

± 1.0% / Hz

Harmonic frequencydependence (20% content)

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


40 ABB

Type tests according to standards

Table 17. Electromagnetic compatibility

Test Type test values Reference standards

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

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

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

IEEE/ANSI C37.90.1

Electrostatic dischargeDirect applicationIndirect application

15 kV air discharge8 kV contact discharge8 kV contact discharge

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

Electrostatic dischargeDirect applicationIndirect application

15 kV air discharge8 kV contact discharge8 kV contact discharge

IEEE/ANSI C37.90.1

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

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

IEC 60255-22-5

Power frequency immunity test 150-300 V,50 Hz

IEC 60255-22-7, Class A

Conducted common modeimmunity test

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

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

Damped oscillatory magnetic fieldtest

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

Radiated electromagnetic fielddisturbance

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


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


35 V/m26-1000 MHz

IEEE/ANSI C37.90.2

Conducted electromagnetic fielddisturbance

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

Radiated emission 30-1000 MHz IEC 60255-25

Conducted emission 0.15-30 MHz IEC 60255-25


ABB 41

Table 18. Insulation

Test Type test values Reference standard

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

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

Insulation resistance >100 MW at 500 VDC

Table 19. Environmental tests

Test Type test value Reference standard

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

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

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

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

IEC 60068-2-78

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

IEC 60068-2-30

Table 20. CE compliance

Test According to

Immunity EN 50263

Emissivity EN 50263

Low voltage directive EN 50178

Table 21. Mechanical tests

Test Type test values Reference standards

Vibration response test Class II IEC 60255-21-1

Vibration endurance test Class I IEC 60255-21-1

Shock response test Class II IEC 60255-21-2

Shock withstand test Class I IEC 60255-21-2

Bump test Class I IEC 60255-21-2

Seismic test Class II IEC 60255-21-3


42 ABB


Table 22. Generator differential protection (PDIF, 87G)

Function Range or value Accuracy

Reset ratio > 95% -

Unrestrained differential currentlimit

(1-50)pu of Ibase ± 2.0% of set value

Base sensitivity function (0.05–1.00)pu ofIbase

± 2.0% of Ir

Negative sequence current level (0.02–0.2)pu ofIbase

± 1.0% of Ir

Operate time, restrained function 25 ms typically at0 to 2 x set level

-

Reset time, restrained function 20 ms typically at2 to 0 x set level

-

Operate time, unrestrainedfunction

12 ms typically at0 to 5 x set level

-

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

-

Operate time, negative sequenceunrestrained function

15 ms typically at0 to 5 x set level

-

Critical impulse time, unrestrainedfunction

2 ms typically at 0to 5 x set level

-


ABB 43

Table 23. Transformer differential protection T2WPDIF, T3WPDIF


Operating characteristic Adaptable ± 2.0% of Ir for I < Ir± 2.0% of Ir for I > Ir

Reset ratio > 95% -

Unrestrained differential currentlimit

(100-5000)% ofIBase on highvoltage winding

± 2.0% of set value

Base sensitivity function (10-60)% of IBase ± 2.0% of Ir

Second harmonic blocking (5.0-100.0)% offundamental

± 2.0% of Ir

Fifth harmonic blocking (5.0-100.0)% offundamental

± 5.0% of Ir

Connection type for each of thewindings

Y or D -

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

0–11 -

Operate time, restrained function 25 ms typically at0 to 2 x Id

-

Reset time, restrained function 20 ms typically at2 to 0 x Id

-

Operate time, unrestrainedfunction

12 ms typically at0 to 5 x Id

-

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

-

Critical impulse time 2 ms typically at 0to 5 x Id

-


44 ABB

Table 24. Restricted earth fault protection, low impedance REFPDIF


Operate characteristic Adaptable ± 2.0% of Irr for I < IrBase

± 2.0% of I for I > IrBase

Reset ratio >95% -

Base sensitivity function (4.0-100.0)% of IBase ± 2.0% of Ir

Directional characteristic Fixed 180 degrees or ± 60to ± 90 degrees

± 2.0 degree

Operate time 20 ms typically at 0 to 10x Idiff

-

Reset time 25 ms typically at 10 to 0x Idiff

-

Second harmonic blocking (5.0-100.0)% offundamental

± 2.0% of IrBase

Table 25. High impedance differential protection (PDIF, 87)


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

± 1.0% of U for U > Ur

Reset ratio >95% -

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

-

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

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

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


ABB 45

Table 26. Full-scheme distance protection, Mho characteristic ZMHPDIS


Number of zones withselectable directions

3 with selectabledirection

-

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

Positive sequenceimpedance, phase-to-earth loop

(0.005–3000.000) W/phase

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

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

Positive sequenceimpedance angle, phase-to-earth loop

(10–90) degrees

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

(0.005–3000.000) Ω/phase

Magnitude of earth returncompensation factor KN

(0.00–3.00)

Angle for earthcompensation factor KN

(-180–180) degrees

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

-

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

Operate time 20 ms typically (withstatic outputs)

-

Reset ratio 105% typically -

Reset time 30 ms typically -

Table 27. Pole slip protection (PPAM, 78)


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

Characteristic angle (72.00–90.00) degrees ± 5.0 degrees

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

Zone 1 and Zone 2 tripcounters

(1-20) -


46 ABB

Table 28. Loss of excitation (PDIS, 40)


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

± 2.0% of Ur/Ir

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

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

Current protection

Table 29. Instantaneous phase overcurrent protection PHPIOC


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

Reset ratio > 95% -

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

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

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




Dynamic overreach < 5% at t = 100 ms -


ABB 47

Table 30. Four step phase overcurrent protection OC4PTOC

Function Setting range Accuracy


Reset ratio > 95% -

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

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

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

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

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

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

Inverse characteristics,see table 84, table 85 andtable 86

19 curve types See table 84, table 85 andtable 86

Operate time, startfunction

25 ms typically at 0 to 2 x Iset -

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


Impulse margin time 15 ms typically -

Table 31. Instantaneous residual overcurrent protection EFPIOC



Reset ratio > 95% -







Dynamic overreach < 5% at t = 100 ms -


48 ABB

Table 32. Four step residual overcurrent protection EF4PTOC



Reset ratio > 95% -

Operate current fordirectional comparison

(1–100)% of lBase ± 1.0% of Ir

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



Second harmonic restrainoperation

(5–100)% of fundamental ± 2.0% of Ir

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

Minimum polarizingvoltage

(1–100)% of UBase ± 0.5% of Ur

Minimum polarizingcurrent

(1-30)% of IBase ±0.25% of Ir

Real part of source Zused for currentpolarization

(0.50-1000.00) W/phase -

Imaginary part of sourceZ used for currentpolarization

(0.50–3000.00) W/phase -







ABB 49

Table 33. Sensitive directional residual overcurrent and power protection SDEPSDE


Operate level for 3I0·cosjdirectional residualovercurrent

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

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

Operate level for 3I0·3U0

· cosj directional residualpower

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

± 1.0% of Sr at S £ Sr

± 1.0% of S at S > Sr

± 10% of set value

Operate level for 3I0 and

j residual overcurrent


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

Operate level for nondirectional overcurrent

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

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

Operate level for nondirectional residualovervoltage

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

± 0.5% of U at U > Ur

Residual release currentfor all directional modes


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

Residual release voltagefor all directional modes

(0.01-200.00)% of UBase ± 0.5% of Ur at U£Ur

± 0.5% of U at U > Ur

Reset ratio > 95% -

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



Relay characteristic angleRCA

(-179 to 180) degrees ± 2.0 degrees

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


50 ABB

Table 33. Sensitive directional residual overcurrent and power protection SDEPSDE ,continued


Operate time, nondirectional residual overcurrent


Reset time, nondirectional residual overcurrent





Table 34. Thermal overload protection, two time constants TRPTTR


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

Operate time:

2 2

2 2ln p

b

I It

I It

æ ö-ç ÷= ×ç ÷-è ø

EQUATION1356 V1 EN (Equation 1)

I = Imeasured

Ip = load current before

overload occurs

Time constant τ = (1–500)minutes

IEC 60255–8, class 5 + 200 ms

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

± 2.0% of heat content trip

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

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

± 2.0% of heat content trip


ABB 51

Table 35. Breaker failure protection CCRBRF


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

Reset ratio, phase current > 95% -

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

Reset ratio, residual current > 95% -

Phase current level forblocking of contact function

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

Reset ratio > 95% -

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

Operate time for currentdetection

10 ms typically -

Reset time for currentdetection

15 ms maximum -

Table 36. Pole discordance protection CCRPLD


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

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

Table 37. Directional underpower protection GUPPDUP


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

± 1.0% of Sr at S < Sr

± 1.0% of S at S > Sr

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

Characteristic angle (-180.0–180.0) degrees 2 degrees

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


52 ABB

Table 38. Directional overpower protection GOPPDOP


Power level (0.0–500.0)% of Sbase

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

(2.0-10)% of Sbase

± 1.0% of Sr at S < Sr

± 1.0% of S at S > Sr

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

Characteristic angle (-180.0–180.0) degrees 2 degrees

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

Voltage protection

Table 39. Two step undervoltage protection UV2PTUV


Operate voltage, low andhigh step

(1–100)% of UBase ± 1.0% of Ur

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

Internal blocking level, lowand high step

(1–100)% of UBase ± 1.0% of Ur

Inverse time characteristicsfor low and high step, seetable 87

- See table 87

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

Minimum operate time,inverse characteristics

(0.000–60.000) s ± 0.5% ± 10 ms

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

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

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



ABB 53

Table 40. Two step overvoltage protection OV2PTOV



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

± 1.0% of U at U > Ur

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

± 1.0% of U at U > Ur


- See table 88

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

Minimum operate time,Inverse characteristics

(0.000-60.000) s ± 0.5% ± 10 ms

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




Table 41. Two step residual overvoltage protection ROV2PTOV



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

± 1.0% of U at U > Ur

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

± 1.0% of U at U > Ur


- See table 89

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

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

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





54 ABB

Table 42. Overexcitation protection OEXPVPH


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

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

± 1.0% of U at U > Ur

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

Curve type IEEE or customer defined

2

(0.18 ):

( 1)k

IEEE tM

×=

-


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

Class 5 + 40 ms

Minimum time delay forinverse function

(0.000–60.000) s ± 0.5% ± 10 ms

Maximum time delay forinverse function

(0.00–9000.00) s ± 0.5% ± 10 ms

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

Table 43. Voltage differential protection (PTOV)


Voltage difference foralarm and trip

(0.0–100.0) % of Ubase ± 0.5 % of Ur

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

Timers (0.000–60.000)s ± 0.5% ± 10 ms


ABB 55

Table 44. 100% stator earth fault protection (PHIZ, 59THD)


Fundamental frequencylevel UN (95% Stator EF)

(1.0–50.0)% of Ubase ± 0.5% of Ur

Third harmonicdifferential level

(0.5–10.0)% of Ubase ± 0.5% of Ur

Third harmonicdifferential block level

(0.1–10.0)% of Ubase ± 0.5% of Ur

Timers (0.020–60.000) s ± 0.5% ± 10 ms

Filter characteristic:FundamentalThird harmonic

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

-

Table 45. Rotor earth fault protection (PHIZ, 59THD) Based on General current andvoltage protection (GAPC) and (RXTTE4)


Permitted field voltagemaximum

1200 V DC -

Supply voltage 120 or230 V

50/60 Hz -

Operate earth faultresistance value

Approx. 1–20 kΩ -

Influence of harmonics inthe DC field voltage

Negligible influence of 50V, 150 Hz or 50 V, 300 Hz

-

Permitted leakagecapacitance

(1–5) μF

Permitted shaft earthingresistance

Maximum 200 Ω -

Protective resistor 220 Ω, 100 W, plate 135 x160 mm

-


56 ABB


Table 46. Underfrequency protection SAPTUF


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

Operate time, start function 100 ms typically -

Reset time, start function 100 ms typically -

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

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

Voltage dependent time delay

( )ExponentU UMin

t tMax tMin tMinUNom UMin

-= × - +

-é ùê úë û


U=Umeasured

Settings:UNom=(50-150)% ofUbase

UMin=(50-150)% of Ubase

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

Class 5 + 200 ms

Table 47. Overfrequency protection SAPTOF


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


Reset time, start function 100 ms typically -

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

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

Table 48. Rate-of-change frequency protection SAPFRC


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

Operate value, internal blockinglevel

(0-100)% of Ubase ± 1.0% of Ur



ABB 57

Table 49. General current and voltage protection (GAPC)


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

-

Base current (1 - 99999) A -

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

-

Base voltage (0.05 - 2000.00) kV -

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

Start undercurrent, step 1and 2

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

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

Operate time startovercurrent


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

Operate time startundercurrent


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

See table 84 and table 85 Parameter ranges for customerdefined characteristic no 17:k: 0.05 - 999.00A: 0.0000 - 999.0000B: 0.0000 - 99.0000C: 0.0000 - 1.0000P: 0.0001 - 10.0000PR: 0.005 - 3.000TR: 0.005 - 600.000CR: 0.1 - 10.0

See table 84 and table 85


58 ABB

Table 49. General current and voltage protection (GAPC), continued


Voltage level where voltagememory takes over

(0.0 - 5.0)% of Ubase ± 1.0% of Ur

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

± 1.0% of U for U>Ur

Start undervoltage, step 1and 2

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


Operate time, startovervoltage

25 ms typically at 0 to 2 x Uset -

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

Operate time startundervoltage

25 ms typically 2 to 0 x Uset -

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

High and low voltage limit,voltage dependent operation

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


Directional function Settable: NonDir, forward andreverse

-

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

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

Reset ratio, overcurrent > 95% -

Reset ratio, undercurrent < 105% -

Reset ratio, overvoltage > 95% -

Reset ratio, undervoltage < 105% -

Overcurrent:



Undercurrent:



Overvoltage:




ABB 59

Table 49. General current and voltage protection (GAPC), continued


Undervoltage:




Table 50. Current circuit supervision CCSRDIF


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

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

Table 51. Fuse failure supervision SDDRFUF


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

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

Operate voltage, negativesequence

(1–100)% of UBase ± 1.0% of Ur

Operate current, negativesequence

(1–100)% of IBase ± 1.0% of Ir

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

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


60 ABB

Control

Table 52. Synchronizing, synchrocheck and energizing check SESRSYN


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

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

Voltage high limit for synchronizingand synchrocheck

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

± 1.0% of U at U >Ur

Reset ratio, synchrocheck > 95% -

Frequency difference limit betweenbus and line

(0.003-1.000) Hz ± 2.0 mHz

Phase angle difference limitbetween bus and line

(5.0-90.0) degrees ± 2.0 degrees

Voltage difference limit betweenbus and line

(2.0-50.0)% of UBase ± 1.0% of Ur

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

Voltage high limit for energizingcheck

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


Reset ratio, voltage high limit > 95% -

Voltage low limit for energizingcheck

(10.0-80.0)% of UBase ± 1.0% of Ur

Reset ratio, voltage low limit < 105% -

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


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

Operate time for synchrocheckfunction

160 ms typically -

Operate time for energizing function 80 ms typically -

Logic

Table 53. Tripping logic SMPPTRC


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

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

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


ABB 61

Table 54. Configurable logic blocks

Logic block Quantity with cycle time Range or value Accuracy

fast medium normal

LogicAND 60 60 160 - -

LogicOR 60 60 160 - -

LogicXOR 10 10 20 - -

LogicInverter 30 30 80 - -

LogicSRMemory 10 10 20 - -

LogicGate 10 10 20 - -

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

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

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

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

Monitoring

Table 55. Measurements CVMMXN


Frequency (0.95-1.05) × fr ± 2.0 mHz

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

± 0.5% of U at U > Ur

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

Active power, P 0.1 x Ur Sr

Reactive power, Q 0.1 x Ur Sr

Apparent power, S 0.1 x Ur Sr

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

0.2 x Ir< I < 4.0 x Ir

± 0.02


62 ABB

Table 56. Supervision of mA input signals (MVGGIO)


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

± 0.1 % of set value ± 0.005 mA

Max current oftransducer to input

(-20.00 to +20.00) mA

Min current oftransducer to input

(-20.00 to +20.00) mA

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

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

Alarm hysteresis forinput

(0.0-20.0) mA

Table 57. Event counter CNTGGIO


Counter value 0-10000 -

Max. count up speed 10 pulses/s -


ABB 63

Table 58. Disturbance report DRPRDRE


Pre-fault time (0.05–1.00) s -

Post-fault time (0.1–10.0) s -

Limit time (0.5–10.0) s -

Maximum number of recordings 100 -

Time tagging resolution 1 ms See table 80

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

-

Maximum number of binary inputs 96 -

Maximum number of phasors in the TripValue recorder per recording

30 -

Maximum number of indications in adisturbance report

96 -

Maximum number of events in the Eventrecording per recording

150 -

Maximum number of events in the Eventlist

1000, first in - first out -

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

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

-

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

-

Recording bandwidth (5-300) Hz -

Table 59. Event list

Function Value

Buffer capacity Maximum number of events inthe list

1000

Resolution 1 ms

Accuracy Depending on timesynchronizing


64 ABB

Table 60. Indications

Function Value

Buffer capacity Maximum number of indications presentedfor single disturbance

96

Maximum number of recorded disturbances 100

Table 61. Event recorder

Function Value

Buffer capacity Maximum number of events in disturbance report 150

Maximum number of disturbance reports 100

Resolution 1 ms

Accuracy Depending ontimesynchronizing

Table 62. Trip value recorder

Function Value

Buffer capacity

Maximum number of analog inputs 30


Table 63. Disturbance recorder

Function Value

Buffer capacity Maximum number of analog inputs 40

Maximum number of binary inputs 96


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

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

Metering

Table 64. Pulse counter PCGGIO

Function Setting range Accuracy

Input frequency See Binary Input Module (BIM) -

Cycle time for report ofcounter value

(1–3600) s -


ABB 65

Table 65. Energy metering ETPMMTR


Energy metering kWh Export/Import,kvarh Export/Import

Input from MMXU. No extra errorat steady load


Table 66. IEC 61850-8-1 communication protocol

Function Value

Protocol IEC 61850-8-1

Communication speed for the IEDs 100BASE-FX

Table 67. LON communication protocol

Function Value

Protocol LON

Communication speed 1.25 Mbit/s

Table 68. SPA communication protocol

Function Value

Protocol SPA

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

Slave number 1 to 899

Table 69. IEC 60870-5-103 communication protocol

Function Value

Protocol IEC 60870-5-103

Communication speed 9600, 19200 Bd


66 ABB

Table 70. SLM – LON port

Quantity Range or value

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

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

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

*) depending on optical budget calculation

Table 71. SLM – SPA/IEC 60870-5-103 port


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

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

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

*) depending on optical budget calculation

Table 72. Galvanic RS485 communication module


Communication speed 2400–19200 bauds

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



ABB 67

Table 73. Line data communication module

Characteristic Range or value

Type of LDCM Short range(SR)

Medium range(MR)

Long range (LR)

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

Singlemode9/125 µm

Singlemode 9/125 µm

Wave length 850 nm 1310 nm 1550 nm

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

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

22 dB (typicaldistance 80 km *)

26 dB (typical distance110 km *)

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

Protocol C37.94 C37.94implementation**)

C37.94 implementation **)

Data transmission Synchronous Synchronous Synchronous

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

2 Mb/s / 64 kbit/s

2 Mb/s / 64 kbit/s

Clock source Internal orderived fromreceivedsignal

Internal orderived fromreceived signal

Internal or derived fromreceived signal

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

Hardware


68 ABB

IED

Table 74. Case

Material Steel sheet

Front plate Steel sheet profile with cut-out for HMI

Surface treatment Aluzink preplated steel

Finish Light grey (RAL 7035)

Table 75. Water and dust protection level according to IEC 60529

Front IP40 (IP54 with sealing strip)

Rear, sides, topand bottom

IP20

Table 76. Weight

Case size Weight

6U, 1/2 x 19” £ 10 kg

6U, 1/1 x 19” £ 18 kg

Connection system

Table 77. CT and VT circuit connectors

Connector type Rated voltage andcurrent

Maximum conductorarea

Terminal blocks of feed throughtype

250 V AC, 20 A 4 mm2

Terminal blocks suitable for ringlug terminals

250 V AC, 20 A 4 mm2

Table 78. Binary I/O connection system

Connector type Rated voltage Maximum conductorarea

Screw compression type 250 V AC 2.5 mm2

2 × 1 mm2

Terminal blocks suitable for ringlug terminals

300 V AC 3 mm2


ABB 69

Basic IED functions

Table 79. Self supervision with internal event list

Data Value

Recording manner Continuous, event controlled

List size 1000 events, first in-first out

Table 80. Time synchronization, time tagging

Function Value

Time tagging resolution, events and sampled measurement values 1 ms

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

± 1.0 ms typically

Time tagging error with SNTP synchronization, sampledmeasurement values

± 1.0 ms typically

Table 81. GPS time synchronization module (GSM)


Receiver – ±1µs relative UTC

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

<30 minutes –

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

<15 minutes –

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

<5 minutes –

Table 82. GPS – Antenna and cable

Function Value

Max antenna cable attenuation 26 db @ 1.6 GHz

Antenna cable impedance 50 ohm

Lightning protection Must be provided externally

Antenna cable connector SMA in receiver endTNC in antenna end


70 ABB

Table 83. IRIG-B

Quantity Rated value

Number of channels IRIG-B 1

Number of channels PPS 1

Electrical connector IRIG-B BNC

Optical connector PPS and IRIG-B Type ST

Type of fibre 62.5/125 μm multimode fibre

Inverse characteristic

Table 84. ANSI Inverse time characteristics


Operating characteristic:

( )1= + ×

-

æ öç ÷ç ÷è ø

P

At B k

I

EQUATION1249-SMALL V1 EN

Reset characteristic:

( )2 1= ×

-

trt kI


I = Imeasured/Iset

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

-

ANSI Extremely Inverse A=28.2, B=0.1217, P=2.0 , tr=29.1 ANSI/IEEE C37.112,class 5 + 30 ms

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

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

ANSI Moderately Inverse A=0.0515, B=0.1140, P=0.02, tr=4.85

ANSI Long Time ExtremelyInverse

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

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

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


ABB 71

Table 85. IEC Inverse time characteristics


Operating characteristic:

( )1= ×

-


P

At k

I


I = Imeasured/Iset

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

Time delay to reset, IEC inversetime

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

IEC Normal Inverse A=0.14, P=0.02 IEC 60255-3, class 5+ 40 ms

IEC Very inverse A=13.5, P=1.0

IEC Inverse A=0.14, P=0.02

IEC Extremely inverse A=80.0, P=2.0

IEC Short time inverse A=0.05, P=0.04

IEC Long time inverse A=120, P=1.0

Programmable characteristicOperate characteristic:

( )= + ×

-


P

At B k

I C


Reset characteristic:

( )= ×

-PR

TRt k

I CR


I = Imeasured/Iset

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

IEC 60255, class 5 +40 ms


72 ABB

Table 86. RI and RD type inverse time characteristics


RI type inverse characteristic

1

0.2360.339

= ×

-

t k

I


I = Imeasured/Iset

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

RD type logarithmic inversecharacteristic

5.8 1.35= - ×æ öç ÷è ø

tI

Ink


I = Imeasured/Iset

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


ABB 73

Table 87. Inverse time characteristics for Two step undervoltage protection (PUVM, 27)


Type A curve:

=< -

<

æ öç ÷è ø

kt

U U

U

EQUATION1431-SMALL V1 EN (Equation 4)

U< = Uset

U = UVmeasured

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

Class 5 +40 ms

Type B curve:

2.0

4800.055

32 0.5

×= +

< -× -

<

æ öç ÷è ø

kt

U U

U


U< = Uset

U = Umeasured

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

Programmable curve:

×= +

< -× -

<

é ùê úê úê úæ öê úç ÷ë è ø û

P

k At D

U UB C

U


U< = Uset

U = Umeasured

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


74 ABB

Table 88. Inverse time characteristics for Two step overvoltage protection (POVM, 59)


Type A curve:

=- >

>

æ öç ÷è ø

tk

U U

U


U> = Uset

U = Umeasured

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

Class 5 +40 ms

Type B curve:

2.0

480

32 0.5 0.035

=×

- >× - -

>

æ öç ÷è ø

tk

U U

U


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

Type C curve:

3.0

480

32 0.5 0.035

=×

- >× - -

>

æ öç ÷è ø

tk

U U

U


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

Programmable curve:

×= +

- >× -

>

æ öç ÷è ø

P

k At D

U UB C

U


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


ABB 75

Table 89. Inverse time characteristics for Two step residual overvoltage protection(POVM, 59N)


Type A curve:

=- >

>

æ öç ÷è ø

tk

U U

U


U> = Uset

U = Umeasured

k = (0.05-1.10) insteps of 0.01

Class 5 +40 ms

Type B curve:

2.0

480

32 0.5 0.035

=×

- >× - -

>

æ öç ÷è ø

tk

U U

U


k = (0.05-1.10) insteps of 0.01

Type C curve:

3.0

480

32 0.5 0.035

=×

- >× - -

>

æ öç ÷è ø

tk

U U

U


k = (0.05-1.10) insteps of 0.01

Programmable curve:

×= +

- >× -

>

æ öç ÷è ø

P

k At D

U UB C

U


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


76 ABB

8. Ordering

GuidelinesCarefully read and follow the set of rules to ensure problem-free order management.Please refer to the available functions table for included application functions.PCM600 can be used to make changes and/or additions to the delivered factory configuration of the pre-configured.

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

Example code: REG670*1.1-A20X00-X00-X0-A-B-A6-X0-CA-XD. Using the code of each position #1-12 specified as REG670*1-2 2-3 33 3 3-4 4-5-6-7 7-8-9 9 9-10 10 10 10 10 10 10 10 10 10 10-11 11 11 11 11 11-12 12

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

REG670* - - - - - . - -

- 10 - 11 - 12

- . -

Posi

tion

SOFTWARE #1 Notes and Rules

Version number

Version no 1.1

Selection for position #1.

Configuration alternatives #2 Notes and Rules

Gen diff + backup 12 AI A20

Gen diff + backup 24 AI B30

Gen and block transformer protection 24 AI C30

ACT configuration

ABB standard configuration X00


Software options #3 Notes and Rules

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

Restricted earth fault protection, low impedance A01 Note: A01 only for B30

High impedance differential protection - 3 blocks A02 Note: A02 only for A20

Transformer differential protection, 2 winding A11 Note: A11 only for A20

Transformer differential protection, 2 and 3 winding A13 Note: A13 only for B30

Pole slip protection B21

Sensitive directional residual overcurrent andpower protection

C16

100% Stator E/F 3rd harmonic D21 Note: D21 only for A20

Apparatus control 30 objects H09

Selection for position #3


ABB 77

First local HMI user dialogue language #4 Notes and Rules

HMI language, English IEC B1

HMI language, English US B2

Additional local HMI user dialogue language

No second HMI language X0

German A1

Russian A2

French A3

Spanish A4

Italian A5

Polish A6

Hungarian A7

Czech A8

Swedish A9


Casing #5 Notes and Rules

1/2 x 19" case A Note: Only for A20

1/1 x 19" case 2 TRM slots E Note: Only for B20 and C30


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

No mounting kit included X

19" rack mounting kit for 1/2 x 19" case of 2xRHGS6 or RHGS12 A Note: Only for A20

19" rack mounting kit for 1/1 x 19" case C Note: Only for B30 and C30

Wall mounting kit D Note: Wall mounting notrecommended withcommunication modules withfibre connection (SLM, OEM,LDCM)

Flush mounting kit E

Flush mounting kit + IP54 mounting seal F


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

Compression terminals K

Auxiliary power supply

24-60 VDC A

90-250 VDC B


Human machine hardware interface #8 Notes and Rules

Small size - text only, IEC keypad symbols A

Medium size - graphic display, IEC keypad symbols B

Medium size - graphic display, ANSI keypad symbols C



78 ABB

Connection type for Analog modules #9 Notes and Rules

Compression terminals A

Ringlug terminals B

Analog system

First TRM, 9I+3U 1A, 110/220V 3 Note: Only for B30/C30

First TRM, 9I+3U 5A, 110/220V 4 Note: Only for B30/C30

First TRM, 5I, 1A+4I, 5A+3U, 110/220V 5 Note: Only for B30/C30

First TRM, 7I+5U 1A, 110/220V 12 Note: Only for A20

First TRM, 7I+5U 5A, 110/220V 13 Note: Only for A20

First TRM 6I, 5A+1I, 1A+5U, 50/60 Hz, 100/220V 14 Note: Only for A20

No second TRM included X0 Note: B30/C30 must include asecond TRM

Second TRM, 9I+3U 1A, 110/220V 3 Note: Only for B30

Second TRM, 9I+3U 5A, 110/220V 4 Note: Only for B30

Second TRM, 5I, 1A+4I, 5A+3U, 110/220V 5 Note: Only for B30

Second TRM, 6I+6U 1A, 100/220V 6 Note: Only for C30

Second TRM, 6I+6U 5A, 100/220V 7 Note: Only for C30



ABB 79

Binary input/output module, mAand time synchronization boards.Note: 1BIM and 1 BOM included.

#10 Notes and Rules

Slot position (rear view)

X31

X41

X51

X61

X71

X81

X91

X10

1

X11

1

X12

1

X13

1 Note: Max 3 positions in 1/2rack and 11 in 1/1 rack with 2TRM and 14 in 1/1 rack with 1TRM

1/2 Case with 1 TRM Note: Only for A20

1/1 Case with 2 TRM Note: Only for B30/C30

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

Binary output module 24 outputrelays (BOM)

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

BIM 16 inputs, RL24-30 VDC B B B B B B B B B B Note: Select 1 BIM in position X31

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

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

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

BIMp 16 inputs, RL24-30 VDC forpulse counting

F F F F F F F F F


G G G G G G G G G


H H H H H H H H H


K K K K K K K K K

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

L L L L L L L L L

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

M M M M M M M M M

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

N N N N N N N N N

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

P P P P P P P P P

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

U U U U U U U U U


V V V V V V V V V


W W W W W W W W W


Y Y Y Y Y Y Y Y Y

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

GPS time synchronization module(in last slot)

S S

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

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

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

T2 T2 T2 T2 T2 T2 T2 T2 T2



80 ABB

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

#11 Notes and Rules


X31

2

X31

3

X30

2

X30

3

X32

2

X32

3

Available slots in 1/2 case with 1TRM Note: Max 1 LDCM

Available slots in 1/1 case with 2 TRM slots Note: Max 2 LDCM

No remote communication board included X X X X X X

Optical short range LDCM A A A A A A Note: Not in A21Note: Max 2 LDCM (same ordifferent type) can be selected

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

IRIG-B Time synchronization module, with PPS F

Galvanic RS485 communication module G G G G


Serial communication unit for station communication #12 Notes and Rules


X30

1

X31

1

No first communication board included X

No second communication board included X

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

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

Serial and LON communication module (glass) C

Optical ethernet module, 1 channel glass D

Optical ethernet module, 2 channel glass E


Guidelines

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

Basic hardware and functions

Manuals on CD

Operator’s manual (English)

Installation and commissioning manual (English)

Technical reference manual (English)

Application manual (English)

Getting started guide (English)


ABB 81

Basic IED functions

Self-supervision with internal event list

Time and synchronization error

Time synchronization

Parameter setting groups

Test mode functionality

Change lock function

IED Identifiers

Product information

Misc Base common

IED Runtime comp

Rated system frequency

Signal Matrix for binary inputs

Signal Matrix for binary outputs

Signal Matrix for mA inputs

Signal Matrix for analog inputs

Summation block 3 phase

Parameter setting function for HMI in PCM 600

Local HMI signals

Authority status

Authority check

FTP access with password

SPA communication mapping

Accessories

GPS antenna and mounting details

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

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

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

Interface converter (for remote end data communication)

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

Quantity: 1 2 1MRK 002 245-AA

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


82 ABB

Test switch

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

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

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

However our proposal for suitable variants are:

Two winding transformer with internalneutral on current circuits. Two pcs can beused in applications for three windingtransformers in single or multi-breaker

arrangement (ordering number RK926 215-BD)

Two winding transformer with externalneutral on current circuits. Two pcs can beused in applications for three windingtransformers in single or multi-breakerarrangement (ordering number RK926 215-BH).

Three winding transformer with internalneutral on current circuits (ordering numberRK926 215-BX).

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

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

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

Protection cover

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

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

External resistor unit for high impedance differential protection

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

Quantity: 1 2 3 RK795101-MA


Quantity: RK795101-MB


Quantity: 1 2 3 RK795101-CB


Quantity: RK795101-DC


ABB 83

Combiflex

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

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

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

Configuration and monitoring tools

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

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

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

Manuals

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

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


84 ABB

User documentation

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

IEC Quantity: 1MRK 502 014-UEN

ANSI Quantity: 1MRK 502 014-UUS

Technical reference manual IEC Quantity: 1MRK 502 013-UEN


Installation and commissioning manual IEC Quantity: 1MRK 502 015-UEN


Application manual IEC Quantity: 1MRK 502 016-UEN


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

Reference information

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

Country: End user:

Station name: Voltage level: kV

Generator manufacturer: Rated power: MVA

Type of prime mover: steam , gas , hydro , pumpstorage , nuclear , other ______________________

Related documents

Documents related to REG670 Identity number

Operator’s manual 1MRK 502 014-UEN

Installation and commissioning manual 1MRK 502 015-UEN

Technical reference manual 1MRK 502 013-UEN

Application manual 1MRK 502 016-UEN

Buyer’s guide 1MRK 502 019-BEN


ABB 85

Connection and Installation components 1MRK 513 003-BEN

Test system, COMBITEST 1MRK 512 001-BEN

Accessories for IED 670 1MRK 514 012-BEN

Getting started guide IED 670 1MRK 500 080-UEN

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

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

Engineering guide IED 670 products 1MRK 511 179-UEN

Buyer’s guide REG 216 1MRB520004-BEN

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

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


86 ABB

HTTP://WWW.ABB.COM/SUBSTATIONAUTOMATION

Contact us

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

www.abb.com/substationautomation

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