1MRK502017-BEN a en BuyerAs Guide Generator Protection IED REG 670 Customized 1.1

8/13/2019 1MRK502017-BEN a en BuyerAs Guide Generator Protection IED REG 670 Customized 1.1

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Buyer's GuideGenerator protection IEDREG 670 Customized

1MRK 502 017-BENProduct version: 1.1

Revision: AIssued: November 2007

Data subject to change without notice

Features For generators and transformers in hydro,pump-storage-, gas-, combined cycle-, steam-,nuclear- and cogeneration stations

Generator and transformer protection and moni-toring integrated in one IED

Generator differential protection with:

- Percentage bias restraint

- Internal/external fault discriminator (negativesequence based)

- Can handle full DC offset in fault current

- Wide frequency operational range

- Up to four stabilized inputs

Transformer differential protection with:

- Percentage bias restraint

- Waveform and Second harmonic restraint fortransformer inrush

- Fifth harmonic restraint for overexcitation

- High sensitivity for interturn faults

- Up to six stabilized inputs

Restricted earth fault protection for all direct orlow impedance earthed windings

- Extremely fast operation

- High sensitivity

- High and low impedance based

Pole slip protection

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

- Discrimination between generating andmotoring direction of rotor phase angle

- Trip after a set number of slips

- Trip within a set rotor angle

Loss of/under excitation

- Positive sequence measurement

- Two zones for alarm and trip

- Directional element for zone restriction

Directional power protection

- Reverse-, low forward-, active-, reactivepower protection

- Phase angle compensation

- Two steps (alarm/trip)

100% stator earth fault

- 95% by fundamental frequency measure-

ment- 100% by 3rdharmonic measurement and

restraint characteristic

- Accurate for all load conditions

Back-up underimpedance protection

- Full-scheme distance protection with Mhocharacteristic (Three zones)

- Voltage controlled/restraint overcurrent

Instantaneous high speed short circuit functionwith low transient overreach

Directional overcurrent protection with four steps

- Each step can be inverse or definite timedelayed

- Each step can be directional or non-direc-tional

Multipurpose protection

- Negative phase sequence (inverse or definitetime delayed)

- Rotor earth fault protection

- Accidental energizing/dead machine protec-tion

Directional earth fault protection with four steps

- Each step can be inverse or definite timedelayed

- Each step can be directional or non-direc-tional


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1MRK 502 017-BEN

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- Each step can be blocked on second har-monic component

Selectable additional software functions such asbreaker failure, overexcitation protection, ther-

mal overload protection, voltage and frequencyprotection and monitoring

Wide frequency range for operation (5Hz - 95Hz)

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

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

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

Current, voltage, power and energy measuringwith high accuracy

Function for energy calculation and demand

handling

- Outputs from measurement function (MMXU)can be used to calculate energy. Active aswell as reactive values are calculated inimport respectively export direction. Values

can be read or generated as pulses. Maxi-mum demand power values are also calcu-lated by the function.

Time synchronization over station bus protocolor by using additional GPS or IRIG-B time syn-chronization modules

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

Versatile local human-machine interface

Extensive self-supervision with internal eventrecorder

Six independent groups of complete setting

parameters with password protection

Powerful software PC tool for configuration, set-ting and disturbance evaluation

Functions Differential protection- Generator differential protection (PDIF, 87G)

- Transformer differential protection, two wind-ing (PDIF, 87T)

- Transformer differential protection, threewinding (PDIF, 87T)

- Restricted earth fault protection (PDIF, 87N)

- High impedance differential protection(PDIF, 87X)

Impedance protection

- Distance protection zones, Mho (PDIS, 21)

- Pole slip protection (PPAM, 78)

- Loss of excitation (PDIS, 40)

Current protection

- Instantaneous phase overcurrent protection(PIOC, 50)

- Four step phase overcurrent protection(POCM, 51/67)

- Instantaneous residual overcurrent protection(PIOC, 50N)

- Four step residual overcurrent protection

(PEFM, 51N/67N)- Sensitive directional residual over current

and power protection (PSDE)

- Thermal overload protection, two time con-stants (PTTR, 49)

- Breaker failure protection (RBRF, 50BF)

- Pole discordance protection (RPLD, 52PD)

- Directional underpower protection (PDUP,37)

- Directional overpower protection (PDOP, 32)

Voltage protection

- Two step undervoltage protection(PUVM, 27)

- Two step overvoltage protection (POVM, 59)

- Two step residual overvoltage protection(POVM, 59N)

- Overexcitation protection (PVPH, 24)

- Voltage differential protection (PTOV, 60)

- 100% stator earth fault 3rd harmonic (PHIZ,59THD)

Frequency protection

- Underfrequency protection (PTUF, 81)

- Overfrequency protection (PTOF, 81)- Rate-of-change frequency protection

(PFRC, 81)


- General current and voltage protection(GAPC)

Secondary system supervision

- Current circuit supervision (RDIF)

- Fuse failure supervision (RFUF)

Control

- Synchronizing, synchrocheck and energizingcheck (RSYN, 25)

- Apparatus control for up to 6 bays, max 30app. (6CBs) incl. Interlocking (APC30)

Logic

- Tripping logic (PTRC, 94)

- Trip matrix logic

- Configurable logic blocks

- Fixed signal function block

Monitoring

- Measurements (MMXU)

- Supervision of mA input signals (MVGGIO)

- Event counter (GGIO)

- Event function

- Disturbance report (RDRE)

Metering


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- Energy metering (MMTR)

- Pulse counter logic (GGIO)

Station communication

- IEC61850-8-1 communication

- LON communication protocol

- SPA communication protocol

- IEC 60870-5-103 communication protocol

- Horizontal communication via GOOSE

- DNP3.0 communication

- Single command, 16 signals

- Multiple Command, 16 signals each

- Ethernet configuration of links

Remote communication

- Binary signal transfer

Basic IED functions- Self supervision with internal event list

- Time synchronization (TIME)

- Parameter setting groups

- Test mode functionality (TEST)

- Change lock function

- IED identif iers

- Rated system frequency

Hardware

- Power supply module (PSM)

- Binary input module (BIM)

- Binary output module (BOM)

- Static binary output module (SOM)

- Binary in/out module (IOM)

- mA input module (MIM)

- Transformer input module

- Optical ethernet module (OEM)

- SPA/LON/IEC module (SLM)

- DNP3.0 Serial communication module(RS485)

- Line data communication module (LDCM)

- GPS time synchronization module (GSM)

- IRIG-B time synchronization module (IRIG-B)

Accessories

- GPS antenna, including mounting kit

- External interface converter from C37.94 toG703 resp G703.E1

- High impedance resistor unit

- Test switch module RTXP24

- On/off switch

- Injection module for rotor E/F RXTTE4

- Winston bridge for rotor E/F YWX111

Appl ication The REG 670 IED is used for protection, controland monitoring of generators and generator-trans-

former blocks from relatively small units up to thelargest generating units. The IED has a compre-hensive function library, covering the requirementsfor most generator applications. The large numberof analog inputs available enables, together withthe large functional library, integration of manyfunctions in one IED. In typical applications twounits can provide total functionality, also providinga high degree of redundancy. REG 670 can as wellbe used for protection and control of shunt reac-tors.

The protection function library includes differen-tial protection for generator, block, auxiliary trans-former and the whole generator block. Stator earth

fault protection, both traditional 95% protection aswell as 100% 3rdharmonic based stator earth faultprotection are included. The 100% protection usesa differential voltage approach giving high sensi-tivity and a high degree of security. Well provenalgorithms for pole slip, underexcitation, rotorearth fault, negative sequence current protections,etc. are included in the IED.

The generator differential protection in the REG670 IED adapted to operate correctly for generator

applications where factors as long DC time con-stants and requirement on short trip time have beenconsidered.

As many of the protection functions can be used asmultiple instances there are possibilities to protectmore than one object in one IED. It is possible tohave protection for an auxiliary power transformerintegrated in the same IED having main protec-tions for the generator. The concept thus enablesvery cost effective solutions.

The REG 670 IED also enables valuable monitor-ing possibilities as many of the process values canbe transferred to an operator HMI.

The wide application flexibility makes this productan excellent choice for both new installations andfor refurbishment in existing power plants.

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

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


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Figure 1: Generator protection with generator differential as main protection

GI

U

OC4 PTOC

51/67 3I> BF

CV GAPC

64R Re

STEF PHIZ

59THD U3d/N

GEN PDIF

87G 3Id/I

SA PTUF

81 f

SDD RFUF

60FL

OEX PVPH

24 U/f>

UV2 PTUV

27 3U

CV MMXU

Meter.

Option

SDE PSDE

32N P0->

REG 670*1.1 A20

Gen Diff + Back-up 12AI

ZMH PDIS

21 ZBF

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 m ight require a different analog input!

en07000052.vsd

CCS RDIF

87CT I2d/I


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1MRK 502 017-BEN

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Figure 2: Generator protection with transformer differential as main protection including open CT detec-tion in the function

GI

U

CCS RDIF

87CT I2d/I

CV GAPC

64R Re

STEF PHIZ

59THD U3d/N

SA PTUF

81 f

SDD RFUF

60FL

OEX PVPH

24 U/f>

UV2 PTUV

27 3U

CV MMXU

Meter.

Option

REG 670*1.1 A20


ZMH PDIS

21 Z BF

CV GAPC

46 I2>

TR PTTR

49 Ith

PSP PPAM

78 Ucos

T2W PDIF

87T 3Id/I

CV GAPC

51/27 U

SES RSYN

25

CV GAPC

51V I>/U

PH PIOC

50 3I>>

CC RPLD

52PD PD

OC4 PTOC

51/67 3I>


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

+ RXTTE4

SDE PSDE

32N P0->

CV GAPC

50AE U/I>

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Figure 3: Generator and generator transformer in the same protection zone

GI

U

CV GAPC

64R Re

STEF PHIZ

59THD U3d/N

SA PTUF

81 f

SDD RFUF

60FL

OEX PVPH

24 U/f>

UV2 PTUV

27 3U

CV MMXU

Meter.

Option

REG 670*1.1 A20


ZMH PDIS

21 Z/U

PH PIOC

50 3I>>

CC RPLD

52PD PD

OC4 PTOC

51/67 3I>


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

+ RXTTE4

CCS RDIF

87CT I2d/I

OC4 PTOC

51/67 3I>

CC RBRF

50BF 3I> BF

SDE PSDE

32N P0->

EF4 PTOC

51N/67N IN->

CV GAPC

50AE U/I>

en07000054.vsd


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1MRK 502 017-BEN

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Figure 4: Generator protection based on high impedance principle

GI

U

CV GAPC

64R Re

STEF PHIZ

59THD U3d/N

SA PTUF

81 f

SDD RFUF

60FL

OEX PVPH

24 U/f>

UV2 PTUV

27 3U

CV MMXU

Meter.

Option

REG 670*1.1 A20


ZMH PDIS

21 Z BF

CV GAPC

46 I2>

TR PTTR

49 Ith

PSP PPAM

78 Ucos

CV GAPC

51/27 U

SES RSYN

25

CV GAPC

51V I>/U

PH PIOC

50 3I>>

CC RPLD

52PD PD

OC4 PTOC

51/67 3I>


Please note that the use of functio n might r equire a different analog input!

+ RXTTE4

SDE PSDE

32N P0->

HZ PDIF

87 IdN

CV GAPC

50AE U/I>

en07000055.vsd


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Revision: A, Page 9

Figure 6: Generator protection and optional overall differential protection with 5 stabilized CT inputs

en07000057.vsd

GI

U

CV GAPC

64R Re

GEN PDIF

87G 3Id/I

SA PTUF

81 f

SDD RFUF

60FL

OEX PVPH

24 U/f>

UV2 PTUV

27 3U

CV MMXUMeter.

Option

SDE PSDE

32N P0->

REG 670*1.1 B30


ZMH PDIS

21 Z BF

CV GAPC

46 I2>

TR PTTR

49 Ith

PSP PPAM78 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>


+ RXTTE4

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

STEF PHIZ

59THDU3d/N

T2W PDIF

87T 3Id/I

REF PDIF

8 7N IdN/I

Auxil iary Bus

T3W PDIF

87T 3Id/I

EF4 PTOC

51N/67N IN->

EF4 PTOC

51N/67N IN->

OC4 PTOC

51/67 3I>

CC RBRF50BF 3I> BF

OC4 PTOC51/67 3I>

OC4 PTOC

51/67 3I>

Main Protection

Back-up ProtectionROV2 PTOV

59N UN>

CT S


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1MRK 502 017-BEN

Revision: A, Page 10

Figure 7: Generator and generator transformer protection in one IED. configuration allows full duplicationof protection functions including overall differential protection.

en07000058.vsd

GI

U

CV GAPC

64R Re

STEF PHIZ

59THD U3d/N

TR PTTR

49 Ith

SA PTUF

81 f

REF PDIF

87N IdN/I

OV2 PTOV

59 3U>

T3W PDIF

87T 3Id/I

REG 670*1.1 C30

T2W PDIF

87T 3Id/I

ROV2 PTOV

59N UN>

Generator and block transformer protection 24AI

CV GAPC

46 I2>

OC4 PTOC

51/67 3I>

TR PTTR

49 Ith

CC RBRF

50BF 3I> BF

CT S

SDD RFUF

60FL

SDD RFUF

60FL

ZMH PDIS

21 Z

CV GAPC

51/27 U

SES RSYN

25

CV GAPC

51V I>/U

PH PIOC

50 3I>>

CC RPLD

52PD PD

OC4 PTOC

51/67 3I>


Please note that the use of function m ight require a different analog inp ut!

CV GAPC

50AE U/I>

CCS RDIF

87CT I2d/I

+ RXTTE4GEN PDIF

87G 3Id/I

OC4 PTOC

51/67 3I>

CC RBRF

50BF 3I> BF

OC4 PTOC

51/67 3I>


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1MRK 502 017-BEN


Figure 8: Generator and generator transformer protection in one IED. Configuration allows full duplicationof protection functions including overall differential protection.

GI

U

CCS RDIF

87CT I2d/I

CCS RDIF

87CT I2d/I

CV GAPC

64R Re

STEF PHIZ

59THD U3d/N

GEN PDIF

87G 3Id/I

TR PTTR

49 Ith

SA PTUF

81 f

CCS RDIF

87CT I2d/I

REF PDIF

87N IdN/I

OV2 PTOV

59 3U>

T3W PDIF

87T 3Id/I

REG 670*1.1 C30

T2W PDIF

87T 3Id/I

ROV2 PTOV

59N UN>

Generator and block transformer protection 24AI

CCS RDIF

87CT I2d/I

CV GAPC

46 I2>

OC4 PTOC

51/67 3I>

TR PTTR

49 Ith

CC RBRF

50BF 3I> BF

SDD RFUF

60FL

SDD RFUF

60FL

ZMH PDIS

21 Z

SDE PSDE

32N P0->

CV GAPC

51/27 U

SES RSYN

25

CV GAPC

51V I>/U

PH PIOC

50 3I>>

CC RPLD

52PD PD

OC4 PTOC

51/67 3I>


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

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1MRK 502 017-BEN


Functionality Differential protection

Generator diff erential protection

(PDIF, 87G)Short circuit between the phases of the statorwindings causes normally very large fault currents.The short circuit gives risk of damages on insula-tion, windings and stator core. The large short cir-cuit currents cause large current forces, which candamage other components in the power plant, suchas turbine and generator-turbine shaft.

To limit the damages in connection to stator wind-ing short circuits, the fault clearance must be asfast as possible (instantaneous). If the generatorblock is connected to the power system close toother generating blocks, the fast fault clearance isessential to maintain the transient stability of the

non-faulted generators.Normally the short circuit fault current is verylarge, i.e. significantly larger than the generatorrated current. There is a risk that a short circuit canoccur between phases close to the neutral point ofthe generator, thus causing a relatively small faultcurrent. The fault current fed from the generatoritself can also be limited due to low excitation ofthe generator. Therefore it is desired that the detec-tion of generator phase to phase short circuits shallbe relatively sensitive, thus detecting small faultcurrents.

It is also of great importance that the generatorshort circuit protection does not trip for externalfaults, when large fault current is fed from the gen-erator.

In order to combine fast fault clearance, sensitivityand selectivity the generator current differentialprotection is normally the best choice for phase tophase generator short circuits.

The generator differential protection is also wellsuited to give fast, sensitive and selective faultclearance if used for shunt reactors and small bus-bars.

Transformer differentialprotection (PDIF, 87T)

The REx 670 differential function for two wind-ing and three winding transformers is providedwith internal CT ratio matching and vector groupcompensation, when required zero sequence cur-rent elimination is made internally in the software.

The function can be provided with up to six threephase sets of current inputs. All current inputs areprovided with percentage bias restraint features,making the REx 670 suitable for two- or threewinding transformers in multi-breaker stationarrangements.

The setting facilities cover for applications of thedifferential protection to all types of power trans-formers and autotransformers with or withouton-load tap-changer as well as for shunt reactor orand local feeder within the station. An adaptivestabilizing feature is included for heavythrough-faults. By introducing the tap changerposition, the differential protection pick-up can beset to optimum sensitivity covering internal faultswith low fault level.

Stabilization is included for inrush currents respec-tively for overexcitation condition. Adaptive stabi-lization is also included for system recovery inrush

and CT saturation for external faults. A fast highset unrestrained differential current protection is

2-winding applications

2-winding power trans-former

2-winding power trans-former with unconnecteddelta tertiary winding

2-winding power trans-former with 2 circuit break-ers on one side

2-winding power trans-former with 2 circuit break-ers and 2 CT-sets on bothsides

3-winding applications

3-winding power trans-former with all three wind-ings connected

3-winding power trans-former with 2 circuit break-ers and 2 CT-sets on oneside

Autotransformer with 2 cir-cuit breakers and 2CT-sets on 2 out of 3 sides

Figure 9: CT group arrangement for differential

protection and other protections

xx05000048.vsd

xx05000049.vsd

xx05000050.vsd

xx05000051.vsd

xx05000052.vsd

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1MRK 502 017-BEN


included for very high speed tripping at high inter-nal fault currents.

Innovative sensitive differential protection feature,

based on the theory of symmetrical components,offers best possible coverage for power trans-former windings turn-to-turn faults.

High impedance differential protection(PDIF, 87)The high impedance differential protection can beused when the involved CT cores have the sameturn ratio and similar magnetizing characteristic. Itutilizes an external summation of the phases andneutral current and a series resistor and a voltagedependent resistor externally to the relay.

Restricted earth faultprotection (PDIF, 87N)The function can be used on all directly or lowimpedance earthed windings. The restricted earthfault function can provide higher sensitivity (downto 5%) and higher speed as it measures individu-ally on each winding and thus do not need harmon-ics stabilization.

The low impedance function is a percentage biasedfunction with an additional zero sequence currentdirectional comparison criteria. This gives excel-lent sensitivity and stability for through faults. Thefunction allows use of different CT ratios and mag-netizing characteristics on the phase and neutralCT cores and mixing with other functions and pro-tection IED's on the same cores.

Impedance protection

Full-scheme distance measuring, Mhocharacterist ic, PDIS 21The numerical mho line distance protection is athree zone full scheme protection for back-updetection of short circuit and earth faults. The threezones have fully independent measuring and set-tings which gives high flexibility for all types oflines.

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

The function can be used as underimpedanceback-up protection for transformers and genera-tors.

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

Pole slip protection (PPAM, 78)The situation with pole slip of a generator can becaused by different reasons.

A short circuit may occur in the external powergrid, close to the generator. If the fault clearingtime is too long, the generator will accelerate somuch, that the synchronism cannot be maintained.

Un-damped oscillations occur in the power sys-tem, where generator groups at different locations,oscillate against each other. If the connectionbetween the generators is too weak the magnitudeof the oscillations will increase until the angularstability is lost.

The operation of a generator having pole slip willgive risk of damages to the generator, shaft andturbine.

At each pole slip there will be significant

torque impact on the generator-turbine shaft.

In asynchronous operation there will be induc-

tion of currents in parts of the generator nor-

mally not carrying current, thus resulting in

increased heating. The consequence can be

damages on insulation and stator/rotor iron.

The pole slip protection function shall detect poleslip conditions and trip the generator as fast as pos-sible if the locus of the measured impedance isinside the generator-transformer block. If the cen-tre of pole slip is outside in the power grid, the firstaction should be to split the network into two parts,after line protection action. If this fails thereshould be operation of the generator pole slip pro-tection in zone 2, to prevent further damages to the

generator, shaft and turbine.

Loss of exci tation (PDIS, 40)There are limits for the under-excitation of a syn-chronous machine. A reduction of the excitationcurrent weakens the coupling between the rotorand the external power system. The machine maylose the synchronism and start to operate like aninduction machine. Then, the reactive consump-tion will increase. Even if the machine does notloose synchronism it may not be acceptable tooperate in this state for a long time. Theunder-excitation increases the generation of heat inthe end region of the synchronous machine. Thelocal heating may damage the insulation of the sta-

tor winding and even the iron core.

To prevent damages to the generator it should betripped at under-excitation.

Current protection

Instantaneous phase overcurrentprotection (PIOC, 50)The instantaneous three phase overcurrent functionhas a low transient overreach and short trippingtime to allow use as a high set short-circuit protec-tion function, with the reach limited to less thantypical eighty percent of the fault current at mini-

mum source impedance.


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1MRK 502 017-BEN


Four step phase overcurrentprotection (POCM, 51/67)The four step phase overcurrent function has aninverse or definite time delay independent for each

step separately.

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

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

Instantaneous residual overcurrentprotection (PIOC, 50N)The single input overcurrent function has a lowtransient overreach and short tripping times toallow use for instantaneous earth fault protection,

with the reach limited to less than typical eightypercent of the line at minimum source impedance.The function can be configured to measure theresidual current from the three phase current inputsor the current from a separate current input.

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

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

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

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

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

Directional operation can be combined togetherwith corresponding communication blocks intopermissive or blocking teleprotection scheme.Current reversal and weak-end infeed functionalityare available as well.

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

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

is also available one nondirectional 3I0 step andone 3U0 overvoltage tripping step.

Thermal overload protection, two timeconstants (PTTR, 49)If the temperature of a power transformer/genera-tor reaches too high values the equipment might bedamaged. The insulation within the trans-former/generator will have forced ageing. As aconsequence of this the risk of internal phase tophase or phase to earth faults will increase. Hightemperature will degrade the quality of the trans-former/generator oil.

The thermal overload protection estimates theinternal heat content of the transformer/generator(temperature) continuously. This estimation ismade by using a thermal model of the trans-former/generator with two time constants, which is

based on current measurement.

Two warning levels are available. This enablesactions in the power system to be done before dan-gerous temperatures are reached. If the tempera-ture continues to increase to the trip value, theprotection initiates trip of the protected trans-former/generator.

Breaker failure protection (RBRF, 50BF)The circuit breaker failure function ensures fastback-up tripping of surrounding breakers. Thebreaker failure protection operation can be currentbased, contact based or adaptive combinationbetween these two principles.

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

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

The function can be programmed to give a single-

or three phase re-trip of the own breaker to avoidunnecessary tripping of surrounding breakers at anincorrect initiation due to mistakes during testing.

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

Normally the own breaker is tripped to correct the

positions. If the situation consists the remote end


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1MRK 502 017-BEN


can be intertripped to clear the unsymmetrical loadsituation.

The pole discordance function operates based on

information from auxiliary contacts of the circuitbreaker for the three phases with additional criteriafrom unsymmetrical phase current when required.

Directional over/underpower protection(PDOP, 32) and (PDUP, 37)These two functions can be used wherever ahigh/low active, reactive or apparent power protec-tion or alarming is required. Alternatively they canbe used to check the direction of active or reactivepower flow in the power system. There are numberof applications where such functionality is needed.Some of them are:

generator reverse power protection

generator low forward power protection

detection of over/under excited generator

detection of reversed active power flow

detection of high reactive power flow

excessive line/cable loading with active or

reactive power

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

Voltage protection

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

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

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

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

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

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

voltage.

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

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

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

Overexcitation p rotection (PVPH, 24)When the laminated core of a power transformeror generator is subjected to a magnetic flux densitybeyond its design limits, stray flux will flow intonon-laminated components not designed to carry

flux and cause eddy currents to flow. The eddycurrents can cause excessive heating and severedamage to insulation and adjacent parts in a rela-tively short time. Function has settable inverseoperating curve and independent alarm stage.

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

95% and 100% Stator earth fault protectionbased on 3rd harmonicStator earth fault is a fault type having relativelyhigh fault rate. The generator systems normallyhave high impedance earthing, i.e. earthing via aneutral point resistor. This resistor is normallydimensioned to give an earth fault current in therange 5 15 A at a solid earth fault directly at thegenerator high voltage terminal. The relativelysmall earth fault currents give much less thermaland mechanical stress on the generator, comparedto the short circuit case. Anyhow, the earth faultsin the generator have to be detected and the gener-ator has to be tripped, even if longer fault time

compared to short circuits, can be allowed.In normal non-faulted operation of the generatingunit the neutral point voltage is close to zero, andthere is no zero sequence current flow in the gener-ator. When a phase-to-earth fault occurs the neutralpoint voltage will increase and there will be a cur-rent flow through the neutral point resistor.

To detect an earth fault on the windings of a gener-ating unit one may use a neutral point overvoltagerelay, a neutral point overcurrent relay, a zerosequence overvoltage relay or a residual differen-tial protection. These protection schemes are sim-ple and have served well during many years.However, at best these simple schemes protectonly 95% of the stator winding. They leave 5% atthe neutral end unprotected. Under unfavourable


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1MRK 502 017-BEN


conditions the blind zone may extend to 20% fromthe neutral.

The 95% stator earth fault typically measures the

fundamental frequency voltage component in thegenerator star point and it operates when it exceedsthe preset value. By using this principle earth faultprotection for approximately 95% of the statorwinding can be protected. In order to protect thelast 5% of the stator winding close to the neutralend the third harmonic voltage measurement canbe performed. In REG 670 either third harmonicdifferential principle of neutral point third har-monic undervoltage principle can be provided.Combination of these two measuring principlesprovide coverage for entire stator winding againstearth faults.

Rotor earth faul t (GAPC, 64R)The field winding, including the rotor winding andthe non-rotating excitation equipment, is alwaysinsulated from the metallic parts of the rotor. Theinsulation resistance is high if the rotor is cooledby air or by hydrogen. The insulation resistance ismuch lower if the rotor winding is cooled by water.This is true even if the insulation is intact. A faultin the insulation of the field circuit will result in aconducting path from the field winding to earth.This means that the fault has caused a field earthfault.

The field circuit of a synchronous generator is nor-mally unearthed. Therefore, a single earth fault onthe field winding will cause only a very small fault

current. Thus the earth fault does not produce anydamage in the generator. Furthermore, it will notaffect the operation of a generating unit in anyway. However, the existence of a single earth faultincreases the electric stress at other points in thefield circuit. This means that the risk for a secondearth fault at another point on the field winding hasincreased considerably. A second earth fault willcause a field short-circuit with severe conse-quences.

The rotor earth fault protection is based on injec-tion of an AC voltage to the isolated field circuit.In non-faulted conditions there will be no currentflow associated to this injected voltage. If a rotor

earth fault occurs, this condition will be detectedby the rotor earth fault protection. Depending onthe generator owner philosophy this operationalstate will be alarmed and/or the generator will betripped.

Frequency protection

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

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

etc.

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

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

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

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

measurement.

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

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

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

Each step can discriminate between positive ornegative change of frequency.


General current and voltageprotection (GAPC)The protection module is recommended as a gen-eral backup protection with many possible applica-tion areas due to its flexible measuring and settingfacilities.

The built-in overcurrent protection feature has two

settable current levels. Both of them can be usedeither with definite time or inverse time character-istic. The overcurrent protection steps can be madedirectional with selectable voltage polarizingquantity. Additionally they can be voltage and/orcurrent controlled/restrained. 2nd harmonicrestraining facility is available as well. At too lowpolarizing voltage the overcurrent feature can beeither blocked, made non directional or ordered touse voltage memory in accordance with a parame-ter setting.

Additionally two overvoltage and two undervolt-age steps, either with definite time or inverse timecharacteristic, are available within each function.

The general function suits applications with under-impedance and voltage controlled overcurrent


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1MRK 502 017-BEN


solutions. The general function can also be utilizedfor generator transformer protection applicationswhere positive, negative or zero sequence compo-nents of current and voltage quantities is typically

required.

Additionally generator applications such as loss offield, inadvertent energizing, stator or rotor over-load, circuit breaker head flash-over and openphase detection are just a few of possible protec-tion arrangements with these functions.

Secondary system supervision

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

and negative sequence current functions.

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

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

A detection of a difference indicates a fault in thecircuit and is used as alarm or to block protection

functions expected to give unwanted tripping.

Fuse failure supervision (RFUF)Failures in the secondary circuits of the voltagetransformer can cause unwanted operation of dis-tance protection, undervoltage protection, neutralpoint voltage protection, energizing function (syn-chronism check) etc. The fuse failure supervisionfunction prevents such unwanted operations.

There are three methods to detect fuse failures.

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

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

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

Control

Synchronizing, synchrocheck and energiz-

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

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

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

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

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

Apparatus contro l (APC)

The apparatus control is a function for control andsupervision of circuit breakers, disconnectors andearthing switches within a bay. Permission to oper-ate is given after evaluation of conditions fromother functions such as interlocking, synchro-check, operator place selection and external orinternal blockings.

Logic rotating switch for function selectionand LHMI presentation (SLGGIO)The SLGGIO function block (or the selectorswitch function block) is used within the CAP toolin order to get a selector switch functionality simi-lar with the one provided by a hardware selectorswitch. Hardware selector switches are used exten-sively by utilities, in order to have different func-tions operating on pre-set values. Hardwareswitches are however sources for maintenanceissues, lower system reliability and extended pur-chase portfolio. The virtual selector switches elim-inate all these problems.

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

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


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1MRK 502 017-BEN


Single point generic control 8 signals(SPC8GGIO)The SC function block is a collection of 8 singlepoint commands, designed to bring in commands

from REMOTE (SCADA) or LOCAL (HMI) tothose parts of the logic configuration that do notneed complicated function blocks that have thecapability to receive commands (for exampleSCSWI). In this way, simple commands can besent directly to the IED outputs, without confirma-tion. Confirmation (status) of the result of the com-mands is supposed to be achieved by other means,such as binary inputs and SPGGIO functionblocks.

Logic

Tripp ing logic (PTRC, 94)A function block for protection tripping is pro-vided for each circuit breaker involved in the trip-ping of the fault. It provides the pulse prolongationto ensure a trip pulse of sufficient length, as well asall functionality necessary for correct co-operationwith autoreclosing functions.

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

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

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

Configurable logic blocksA number of logic blocks and timers are availablefor user to adapt the configuration to the specificapplication needs.

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

Monitoring

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

measured voltages, currents, frequency, active,

reactive and apparent power and power factor,

the primary and secondary phasors,

differential currents, bias currents,

positive, negative and zero sequence currents

and voltages,

mA, input currents

pulse counters,

event counters

measured values and other information of the

different parameters for included functions,

logical values of all binary in- and outputs and

general IED information.

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

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

The function requires that the IED is equippedwith the mA input module.

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

Disturbance report (RDRE)Complete and reliable information about distur-bances in the primary and/or in the secondary sys-tem together with continuous event-logging isaccomplished by the disturbance report functional-ity.

The disturbance report, always included in theIED, acquires sampled data of all selected analoginput and binary signals connected to the functionblock i.e. maximum 40 analog and 96 binary sig-nals.

The disturbance report functionality is a commonname for several functions:

Event List (EL)

Indications (IND)

Event recorder (ER)

Trip Value recorder (TVR)

Disturbance recorder (DR)

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


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

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

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

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

a complement to specific disturbance recorderfunctions.

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

Indications (RDRE)To get fast, condensed and reliable informationabout disturbances in the primary and/or in thesecondary system it is important to know e.g.binary signals that have changed status during adisturbance. This information is used in the shortperspective to get information via the LHMI in astraightforward way.

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

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

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

ary system is vital e.g. time tagged events loggedduring disturbances. This information is used fordifferent purposes in the short term (e.g. correctiveactions) and in the long term (e.g. FunctionalAnalysis).

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

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

The event recording information is an integrated

part of the disturbance record (Comtrade file).

Trip value recorder (RDRE)Information about the pre-fault and fault values forcurrents and voltages are vital for the disturbanceevaluation.

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

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

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

Disturbance recorder (RDRE)

The Disturbance Recorder function supplies fast,complete and reliable information about distur-bances in the power system. It facilitates under-standing system behavior and related primary andsecondary equipment during and after a distur-bance. Recorded information is used for differentpurposes in the short perspective (e.g. correctiveactions) and long perspective (e.g. FunctionalAnalysis).

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

under the event recorder function.

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

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

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

can be sent at change or cyclically from the IED tothe station level. These events are created from anyavailable signal in the IED that is connected to theEvent function block. The event function block isused for LON and SPA communication.

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

Measured value expander blockThe functions MMXU (SVR, CP and VP), MSQI(CSQ and VSQ) and MVGGIO (MV) are providedwith measurement supervision functionality. Allmeasured values can be supervised with four setta-ble limits, i.e. low-low limit, low limit, high limit

and high-high limit. The measure value expanderblock (XP) has been introduced to be able to trans-


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1MRK 502 017-BEN


late the integer output signal from the measuringfunctions to 5 binary signals i.e. below low-lowlimit, below low limit, normal, above high-highlimit or above high limit. The output signals can be

used as conditions in the configurable logic.

Metering

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

tionality.

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

Basic IED functions

Time synchronizationUse the time synchronization source selector toselect a common source of absolute time for theIED when it is a part of a protection system. Thismakes comparison of events and disturbance databetween all IEDs in a SA system possible.

Human machine interfaceThe local human machine interface is available ina small, and a medium sized model. The principledifference between the two is the size of the LCD.The small size LCD can display seven line of textand the medium size LCD can display the singleline diagram with up to 15 objects on each page.

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

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

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

Status indication LEDs

Alarm indication LEDs which consists of 15

LEDs (6 red and 9 yellow) with user printable

label. All LEDs are configurable from the

PCM 600 tool

Liquid crystal display (LCD)

Keypad with push buttons for control and nav-

igation purposes, switch for selection between

local and remote control and reset An isolated RJ45 communication port

Figure 10: Small graphic HMI


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1MRK 502 017-BEN


Figure 11: Example of medium graphic HMI

Station communication

OverviewEach IED is provided with a communication inter-

face, enabling it to connect to one or many substa-tion level systems or equipment, either on theSubstation Automation (SA) bus or SubstationMonitoring (SM) bus.

Following communication protocols are available:

IEC 61850-8-1 communication protocol

LON communication protocol

SPA or IEC 60870-5-103 communication pro-

tocol

DNP3.0 communication protocol

Theoretically, several protocols can be combined

in the same IED.

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

Serial communication, LONExisting stations with ABB station bus LON can

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

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

SPA communication protocolA single glass or plastic port is provided for theABB SPA protocol. This allows extensions of sim-ple substation automation systems but the mainuse is for Substation Monitoring Systems SMS.

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

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

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

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

Multiple command and transmit

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

Remote communication

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

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

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


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1MRK 502 017-BEN


Line data communication module, shortand medium range (LDCM)The line data communication module (LDCM) isused for communication between the IEDs situated

at distances


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1MRK 502 017-BEN


Layout and dimensions

Dimensions

Mounting alternativesFollowing mounting alternatives (IP40 protection

from the front) are available:

19 rack mounting kit

Wall mounting kit

See ordering for details about available mountingalternatives.

Figure 12: 1/2 x 19 case with rear cover Figure 13: 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)

xx05000003.vsd

CB

E

F

A

D

xx05000004.vsd


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1MRK 502 017-BEN


Connectiondiagrams

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

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

Module Rear Positions

PSM X11

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

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

SLM X301:A, B, C, D

IRIG-B 1) X302

OEM X311:A, B, C, D

RS485 or LDCM 2) 3) X312

LDCM 2) X313

TRM X401

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

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

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

Note!

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


PSM X11

BIM, BOM, SOM, IOMor MIM

X31 and X32 etc. to X161 and X162

BIM, BOM, SOM, IOM,MIM or GSM

X161, X162

SLM X301:A, B, C, D

IRIG-B or LDCM 1,2) X302

LDCM 2) X303

OEM X311:A, B, C, D

RS485 or LDCM 2) 3) X312

LDCM 2) X313

TRM X401


2) LDCM installation sequence: P31:2, P31:3, P30:2 andP30:3


Note!

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


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1MRK 502 017-BEN


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


PSM X11

BIM, BOM, SOM, IOMor MIM

X31 and X32 etc. to X131 and X132

BIM, BOM, SOM, IOM,MIM or GSM

X131, X132

SLM X301:A, B, C, D

IRIG-B or LDCM 1,2) X302

LDCM 2) X303

OEM X311:A, B, C, D

RS485 or LDCM 2) 3) X312

LDCM 2) X313

LDCM 2) X322

LDCM 2) X323

TRM 1 X401

TRM 2 X411


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


Note!

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

Figure 14: Transformer inputmodule (TRM)

CT/VT-input designationaccording to figure 14

Current/voltageconfiguration (50/60 Hz)

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

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

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

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

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

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

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

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

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


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


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

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

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


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

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

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


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Figure 15: Binary input module (BIM). Input contacts named XAcorresponds to rear position X31, X41, etc. and inputcontacts named XB to rear position X32, X42, etc.

Figure 16: mA input module (MIM)


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Figure 17: Communication interfaces (OEM, LDCM, SLM and HMI)

Note to figure 17

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

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

3) Rear communication port RS485, terminal block

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

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

6) Rear communication prot IEC 61850, ST-connector

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

8) Front communication port Ethernet, 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 18: Power supply module (PSM)

Figure 19: GPS time synchronization module(GSM)


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Figure 21: Static output module (SOM)

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


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Figure 22: Binary in/out module (IOM). Input contacts named XA corresponds to rear position X31, X41,etc. and output contacts named XB to rear position X32, X42, etc.


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Technical data General

Definitions

Energizing quantities, rated values and limits

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

Table 5: MIM - mA input module

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

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

Reference value:

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

Nominal range:

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

Operative range:

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

Quantity Rated value Nominal range

Current Ir= 1 or 5 A (0.2-40) IrOperative range (0-100) x Ir

Permissive overload 4 Ircont.

100 Irfor 1 s*)

Burden < 150 mVA at Ir= 5 A

< 20 mVA at Ir= 1 A

Ac voltage Ur= 110 V 0.5288 V

Operative range (0340) V

Permissive overload 420 V cont.

450 V 10 s

Burden < 20 mVA at 110 V

Frequency f r= 50/60 Hz 5%*)max. 350 A for 1 s when COMBITEST test switch is included.

Quantity: Rated value: Nominal range:

Input range 5, 10, 20mA

0-5, 0-10, 0-20, 4-20mA

-

Input resistance Rin= 194 Ohm -

Power consumption

each mA-board

each mA input

4 W

0.1 W

-

Quantity Rated value

Number of channels 1 or 2

Standard IEEE 802.3u 100BASE-FX

Type of fiber 62.5/125 m multimode fibre

Wave length 1300 nm

Optical connector Type STCommunication speed Fast Ethernet 100 MB


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

EL = (90 - 250) V

EL 20%

EL 20%

Power consumption 50 W typically -

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


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Binary inputs and outputsTable 8: BIM - Binary input module

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

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

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


Binary inputs 16 -

DC voltage, RL 24/40 V

48/60 V

110/125 V

220/250 V

RL 20%RL 20%

RL 20%

RL 20%

Power consumption

24/40 V

48/60 V

110/125 V

220/250 V

max. 0.05 W/input

max. 0.1 W/input

max. 0.2 W/input

max. 0.4 W/input

-

Counter input frequency 10 pulses/s max -

Oscil lating signal discr iminator Blocking set table 140 Hz

Release settable 130 Hz

Quantity Rated value Nominal rangeBinary inputs 16 -


48/60 V

110/125 V

220/250 V

RL 20%

RL 20%

RL 20%

RL 20%

Power consumption

24/40 V

48/60 V

110/125 V

220/250 V

max. 0.05 W/input

max. 0.1 W/input

max. 0.2 W/input

max. 0.4 W/input

-

Counter input frequency 10 pulses/s max -

Balanced counter input frequency 40 pulses/s max -

Oscil lating signal discr iminator Blocking set table 140 Hz

Release settable 130 Hz


Binary inputs 8 -


48/60 V

110/125 V

220/250 V

RL 20%

RL 20%

RL 20%

RL 20%

Power consumption

24/40 V

48/60 V

110/125 V

220/250 V

max. 0.05 W/input

max. 0.1 W/input

max. 0.2 W/input

max. 0.4 W/input

-

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

Binary outputs 10 2

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

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

Current carrying capacity

Continuous

1 s

8 A

10 A

8 A

10 A

Making capacity at inductive load withL/R>10 ms

0.2 s

1.0 s30 A

10 A

0.4 A

0.4 A


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

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

Influencing factorsTab le 14: Temperature and humidi ty inf luence

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

Breaking capacity for DC with L/R < 40ms

48 V/1 A

110 V/0.4 A

125 V/0.35 A

220 V/0.2 A

250 V/0.15 A

48 V/1 A

110 V/0.4 A

125 V/0.35 A

220 V/0.2 A

250 V/0.15 A

Maximum capacitive load - 10 nF

Function or quantity Trip and Signal relays

Static binary outputs 6

Electromechanical relay outputs 6

Max system voltage 250 V AC, DC

Test voltage across open contact, 1 min 1000 V rms

Current carrying capacity

Continuous

1 s

8 A

10 A

Static binary outputs:

Making capacity at capacitive load with the maximum

capacitance of 0.2 F

0.2 s

1.0 s

20 A

10 A

Electromechanical relay outputs:

Making capacity at inductive load with L/R>10 ms

0.2 s

1.0 s

30 A

10 A

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

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

110 V/0.4 A

125 V/0.35 A

220 V/0.2 A

250 V/0.15 A

Operating time, Static outputs 10 ms

0.2 s

1.0 s

30 A

10 A

Breaking capacity for AC, cos >0.4 250 V/8.0 ABreaking capacity for DC with L/R < 40 ms 48 V/1 A

110 V/0.4 A

125 V/0.35 A

220 V/0.2 A

250 V/0.15 A

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

Parameter Reference value Nominal range Influence

Ambient temperature, oper-ate value

+20C -10C to +55C 0.02% /C

Relative humidity

Operative range

10%-90%

0%-95%

10%-90% -

Storage temperature -40C to +70C - -


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

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

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

Table 18: Insulation

Tabl e 19: En vi ro nm ental tes ts

Dependence on Reference value Within nominal range Influence

Ripple, in DC auxiliary voltage

Operative range

max. 2%

Full wave rectified

12% of EL 0.01% /%

Auxiliary voltage dependence, operate value 20% of EL 0.01% /%Interrupted auxiliary DC voltage 24-60 V DC 20%

90-250 V DC 20%

Interruption interval

050 ms

No restart

0s Correct behaviour atpower down

Restart time 100 Mat 500 VDC

Test Type test value Reference standard

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

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


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Table 20: CE compliance

Tab le 21: Mech ani cal t es ts

Differential protectionTable 22: Generator d if ferent ia l protect ion (PDIF, 87G)

Table 23: Transformer di f ferent ia l protect ion (PDIF, 87T)

Table 24: Restricted earth fault protection, low impedance (PDIF, 87N)

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

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

IEC 60068-2-78

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

IEC 60068-2-30

Test According to

Immunity EN 50263

Emissivity EN 50263

Low voltage directive EN 50178

Test Type test values Reference standards

Vibration Class I IEC 60255-21-1

Shock and bump Class I IEC 60255-21-2

Seismic Class I IEC 60255-21-3

Function Range or value Accuracy

Reset ratio > 95% -

Unrestrained differential current limit (1-50)pu of Ibase 2.0% of set value

Base sensitivity function (0.051.00)pu of Ibase 2.0% of IrNegative sequence current level (0.020.2)pu of Ibase 1.0% of IrOperate time, restrained function 25 ms typically at 0 t o 2 x set

level-

Reset time, restrained function 20 ms typically at 2 to 0 x setlevel

-

Operate time, unrestrained function 12 ms typically at 0 to 5 x setlevel

-

Reset time, unrestrained function 25 ms typically at 5 t o 0 x setlevel

-

Operate time, negative sequence unrestrained func-tion

15 ms typically at 0 to 5 x setlevel

-

Cri tical impulse t ime, unrestrained function 2 ms typically at 0 to 5 x setlevel

-


Operating characteristic Adaptable 2.0% of Irfor I < Ir2.0% of I for I > I r

Reset ratio > 95% -

Unrestrained differential current limit (100-5000)% of Ibaseon highvoltage winding

2.0% of set value

Base sensitivity function (10-60)% of Ibase 2.0% of IrSecond harmonic blocking (5.0-100.0)% of fundamental 2.0% of IrFifth harmonic blocking (5.0-100.0)% of fundamental 5.0% of Ir

Connection type for each of the windings Y-wye or D-delta -Phase displacement between high voltage winding,W1 and each of the windings, w2 and w3. Hournotation

011 -

Operate time, restrained function 25 ms typically at 0 to 2 x Id -

Reset time, restrained function 20 ms typically at 2 to 0 x Id -

Operate time, unrestrained function 12 ms typically at 0 to 5 x Id -

Reset time, unrestrained function 25 ms typically at 5 to 0 x Id -

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


Operate characteristic Adaptable 2.0% of Irfor I < Ir2.0% of I for I > I r

Reset ratio >95% -

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

Test Type test value Reference standard


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Table 25: High impedance di f ferent ial protect ion (PDIF, 87)

Impedance protectionTable 26: Full-scheme distance protection, Mho characteristic (PDIS, 21)

Tab le 27: Po le sl ip protec tion (PPAM, 78)

Tab le 28: Loss o f exci tat ion (PDIS, 40)

Current protectionTable 29: Instantaneous phase overcurrent protection (PIOC, 50)

Directional characteristic Fixed 180 degrees or 60 to 90degrees

2.0 degree

Operate time 20 ms typically at 0 to 10 x Id -

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

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


Operate voltage (20-400) V 1.0% of Urfor U < Ur1.0% of U for U > U r

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 -



Number of zones with selectable direc-tions

3 with selectable direction -

Minimum operate current (1030)% of IBase -

Positive sequence impedance,phaseearth loop

(0.0053000.000) /phase 2.0% static accuracy

Conditions:

Voltage range: (0.1-1.1) x Ur

Current range: (0.5-30) x Ir

Angle: at 0 degrees and 85 degrees

Positive sequence impedance angle,phaseearth loop

(1090) degrees

Reverse reach, phaseearth loop (Mag-nitude)

(0.0053000.000) /phase

Impedance reach for phasephase ele-ments

(0.0053000.000) /phase

Angle for positive sequence impedance,phasephase elements

(1090) degrees

Reverse reach of phasephase loop (0.0053000.000) /phase

Magnitude of earth return compensationfactor KN

(0.003.00)

Angle for earth compensation factor KN (-180180) degrees

Dynamic overreach


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Table 30: Four step phase overcurrent protection (POCM, 51/67)

Table 31: Instantaneous residual overcurrent protection (PIOC, 50N)

Table 32: Four step residual overcurrent protection (PEFM, 51N/67N)

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

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

Reset time 35 ms typically at 10 to 0 x Iset

-


Dynamic overreach < 5% at = 100 ms -

Function Setting range Accuracy

Operate current (1-2500)% of lbase 1.0% of Irat I Ir1.0% of I at I > I r

Reset ratio > 95% -

Min. operating current (1-100)% of lbase 1.0% of IrRelay characteristic angle (RCA) (-70.0 -50.0) degrees 2.0 degrees

Maximum forward angle (40.070.0) degrees 2.0 degrees

Minimum forward angle (75.090.0) degrees 2.0 degrees

Second harmonic blocking (5100)% of fundamental 2.0% of IrIndependent time delay (0.000-60.000) s 0.5% 10 ms

Minimum operate time (0.000-60.000) s 0.5% 10 msInverse characteristics, see table 84and table 85

19 curve types See table 84and table 85

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

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


Impulse margin time 15 ms typically -



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

Reset time 35 ms typically at 10 to 0 x Iset -


Dynamic overreach < 5% at = 100 ms -



Reset ratio > 95% -

Operate current for di

Documents

1MRK502017-BEN a en BuyerAs Guide Generator Protection IED REG 670 Customized 1.1