Year: 2026

Event log

To collect sequence-of-events information, the relay has a

nonvolatile memory capable of storing 1024 events with the

associated time stamps. The event log facilitates detailed pre

and post-fault analyses of feeder faults and disturbances. The

considerable capacity to process and store data and events in

the relay supports the growing information demand of future

network configurations.

The sequence-of-events information can be accessed either via

the LHMI or remotely via the communication interface of the

relay. The information can also be accessed locally or remotely

using the Web HMI.

Recorded data

The relay can store the records of the latest 128 fault events.

The records can be used to analyze the power system events.

Each record includes, for example, current, voltage and angle

values and a time stamp. The fault recording can be triggered

by the start or the trip signal of a protection block, or by both.

The available measurement modes include DFT, RMS and

peak-to-peak. Fault records store relay measurement values

when any protection function starts. In addition, the maximum

demand current with time stamp is separately recorded. The

records are stored in the nonvolatile memory.

Disturbance recorder

The relay is provided with a disturbance recorder featuring up to

24 analog and 64 binary signal channels. The analog channels

can be set to record either the waveform or the trend of the

currents and voltages measured.

The analog channels can be set to trigger the recording function

when the measured value falls below or exceeds the set values.

The binary signal channels can be set to start a recording either

on the rising or the falling edge of the binary signal or on both.

The binary channels can be set to record external or internal

relay signals, for example, the start or trip signals of the relay

stages, or external blocking or control signals. The recorded

information is stored in a nonvolatile memory in COMTRADE

format and can be uploaded for subsequent fault analysis.

Fault locator

The relay features an optional impedance-measuring fault

location function suitable for locating short circuits in radial

distribution systems. Earth faults can be located in effectively

and low-resistance earthed networks, as well as in

compensated networks. When the fault current magnitude is at

least of the same order of magnitude or higher than the load

current, earth faults can also be located in isolated neutral

distribution networks. The fault location function identifies the

type of the fault and then calculates the distance to the fault

point. The calculations provide information on the fault

resistance value and accuracy of the estimated distance to the

fault point.

The voltage unbalance and voltage variation functions are used

for measuring short-duration voltage variations and monitoring

voltage unbalance conditions in power transmission and

distribution networks.

The voltage and current harmonics functions provide a method

for monitoring the power quality by means of the current

waveform distortion and voltage waveform distortion. The

functions provide selectable short-term 3- or 60- or 300

second sliding average and a long-term demand for total

demand distortion (TDD) and total harmonic distortion (THD).

The phase-specific harmonic content is measured for voltages

and currents, as well as DC component and fundamental

content. The dedicated harmonics measurement page in the

LHMI presents the measurements in a user-friendly manner.

Fault locator

The relay features an optional impedance-measuring fault

location function suitable for locating short circuits in radial

distribution systems. Earth faults can be located in effectively

and low-resistance earthed networks, as well as in

compensated networks. When the fault current magnitude is at

least of the same order of magnitude or higher than the load

current, earth faults can also be located in isolated neutral

distribution networks. The fault location function identifies the

type of the fault and then calculates the distance to the fault

point. The calculations provide information on the fault

resistance value and accuracy of the estimated distance to the

fault point.

Power quality

In the EN standards, power quality is defined through the

characteristics of the supply voltage. Transients, short-duration

and long-duration voltage variations and unbalance and

waveform distortions are the key characteristics describing

power quality. The distortion monitoring functions are used for

monitoring the current total demand distortion and the voltage

total harmonic distortion.

Power quality monitoring is an essential service that utilities can

provide for their industrial and key customers. A monitoring

system can provide information about system disturbances and

their possible causes. It can also detect problem conditions

throughout the system before they cause customer complaints,

equipment malfunctions and even equipment damage or

failure. Power quality problems are not limited to the utility side

of the system. In fact, the majority of power quality problems

are localized within customer facilities. Thus, power quality

monitoring is not only an effective customer service strategy but

also a way to protect a utility’s reputation for quality power and

service.

The protection relay has the following power quality monitoring

functions.

• Voltage variation

• Voltage unbalance

• Current harmonics

• Voltage harmonics

Power transformer differential protection

The relay offers low-impedance differential protection for two

winding (two restraints) and three-winding (three restraints)

power transformers. The power transformer protection

application package includes the protection for a two-winding

power transformer. If support for three-winding power

transformer is needed, the corresponding protection add-on

package can be selected. Both low-impedance differential

functions feature three-phase multi-slope stabilized stages and

an instantaneous stage to provide fast and selective protection

against short circuits, winding interturn faults and bushing

flash-overs. A second harmonic restraint with advanced

waveform-based blocking ensures stability at transformer

energization. The fifth harmonic based blocking and unblocking

limits stabilize the protection performance in moderate

overexcitation situations. In case of three-winding differential

protection, the connection group phase shift matching can be

done with 0.1 degree resolution supporting cycloconverter

applications. If the tap-changer position information is

available, it is possible to further increase the protection

sensitivity by compensating the tap-changer position error

within the measured differential current.

The power transformer protection application package also

includes high-impedance differential functions for a phase

segregated protection scheme. If this scheme is applied, the

related current transformers have to be correctly selected and

the necessary secondary circuit components, external to the

relay, defined.

Arc flash protection

The arc flash protection is available on the optional hardware

module. The module supports connection of up to four sensors.

The sensors can be of lens or loop types, or a free mixture. Both

sensor types are supervised against sensor failure. Fast tripping

increases staff safety and limits material damage, therefore it is

recommended to use static power outputs (SPO) instead of

normal power outputs (PO). This typically decreases the total

operating time with 4..6 ms compared to the normal power

outputs.

Measurements

The base functionality of the REX640 relay contains a number of

basic measurement functions for current, voltage, frequency,

symmetrical components of currents and voltages, power,

power factor and energy. These measurement functions can be

freely connected to the measured secondary quantities

available in the relay. The relay can also measure various analog

signals via RTD and mA inputs. All these measurements can be

used within the relay configuration for additional logics. The

measurements are available locally on the HMI and can be

accessed remotely via communication. The information is also

accessible via Web HMI.

The relay is also provided with a load profile recorder. The load

profile feature stores the selected load measurement data

captured periodically (demand interval). The records can be

viewed on the LHMI and are available in COMTRADE format.

The LHMI includes the necessary command, indication and

measurement features for each of the modes, thus rendering

the conventional dedicated synchronizing panel unnecessary.

REX640 also supports systems in which non-generator circuit

breakers are synchronized. The prerequisite is that all the

feeders within the system are equipped with REX640 relays.

The generator relays have to contain the ASGCSYN function

block and all the non-generator relays need to contain the

ASNSCSYN function block. In addition, all the REX640 relays

have to contain the coordinator function block ASCGAPC. The

role of ASCGAPC is to model the system primary circuit

connection state to involve the correct generators for the

synchronization of a non-generator breaker and to interact

between the ASGCSYN and ASNSCSYN function blocks. The

information exchange between ASCGAPC, ASGCSYN and

ASNSCSYN is carried out via binary and analog GOOSE

signalling as per IEC 61850-8-1. The LHMI dedicated to the

relay (breaker) works as the local user interface for a non

generator breaker synchronizing. The available synchronizing

modes are “automatic” and “semi-automatic”. A manual

synchronization of the non-generator breaker can be carried

out as a back-up solution in situations where the

communication system (IEC 61850-8-1) is not available. This

requires operator actions from two LHMIs, namely from the

LHMI of the concerned non-generator breaker and the LHMI of

the manually selected generator relay.

REX640 includes two autoreclosing functions, each with up to

five programmable autoreclosing shots of desired type and

duration. A load-shedding function performs load shedding

based on underfrequency and the rate of change of the

frequency.

To validate correct closing conditions for a circuit breaker,

REX640 contains a synchrocheck function. For installations

including synchronous generators, REX640 introduces a

synchronizer that actively controls the generator’s voltage and

frequency in order to reach a synchronous situation across the

circuit breaker. The synchronizer functionality is available for a

generator circuit breaker as well as for a non-generator

(network) circuit breaker. A complete installation-wide

synchronizing system can be built using the REX640 relays. The

maximum size of the synchronizing system is eight generator

breakers and 17 non-generator breakers.

Synchronization of a generator circuit breaker can be

implemented using a single REX640 relay including the

ASGCSYN function block. The relay interfaces the external

measurement and control circuitry via hardwired binary and

analog signals. The excitation and prime mover control signals

are based on pulse commands, either with fixed or variable

length. The synchronizer function block has three different

function modes: manual, semi-automatic and automatic. In

each of these modes, the LHMI acts as the local user interface.

The LHMI includes the necessary command, indication and

measurement features for each of the modes, thus rendering

the conventional dedicated synchronizing panel unnecessary.

REX640 also supports systems in which non-generator circuit

breakers are synchronized. The prerequisite is that all the

feeders within the system are equipped with REX640 relays.

Control

REX640 integrates functionality for controlling objects such as

circuit breakers, disconnectors, earthing switches, on-load tap

changers and Petersen coils via the LHMI or by means of

remote controls. The relay includes three circuit breaker control

blocks. In addition, the relay features 14 disconnector control

blocks intended for the motor-operated control of

disconnectors or a circuit breaker truck and three control

blocks intended for the motor-operated control of the earthing

switch. Furthermore, the relay includes eight additional

disconnector position indication blocks and three earthing

switch position indication blocks that can be used with

disconnectors and earthing switches that are only manually

controlled.

The touch screen LHMI supports a single-line diagram with

control points and position indication for the relevant primary

devices. Interlocking schemes required by the application are

configured using Signal Matrix or Application Configuration in

PCM600.

COM600S features a Web browser-based HMI, which provides

a customizable graphical display for visualizing single-line

mimic diagrams for switchgear bay solutions. The Web HMI of

COM600S also provides an overview of the whole substation,

including relay-specific single-line diagrams, which makes

information easily accessible. Substation devices and

processes can also be remotely accessed through the Web

HMI, which improves personnel safety.

In addition, COM600S can be used as a local data warehouse

for the substation’s technical documentation and for the

network data collected by the devices. The collected network

data facilitates extensive reporting and analyzing of network

fault situations by using the data historian and event handling

features of COM600S. The historical data can be used for

accurate monitoring of process and equipment performance,

using calculations based on both real-time and historical

values. A better understanding of the process dynamics is

achieved by combining time-based process measurements

with production and maintenance events.

COM600S can also function as a gateway and provide

seamless connectivity between the substation devices and

network-level control and management systems, such as

MicroSCADA Pro and System 800xA.

The GOOSE Analyzer interface in COM600S enables the

monitoring and the analysis of the horizontal IEC 61850

application during commissioning and operation at station

level. It logs all GOOSE events during substation operation to

enable improved system supervision.