Life cycle services

ABB offers full support for all protection and

control relays throughout their entire lifecycle.

Our extensive life cycle services include training,

customer support, maintenance and

modernization.

Main customer benefits

• Flexible solution for demanding utility and

industrial power distribution systems with

integration of protection, control, monitoring

and supervision in one relay 

Automatic voltage regulation

• Fast GOOSE messaging according to IEC 61850

for less interpanel wiring and supervised communication

• Wide application coverage – feeder, transformer,

motor and generator protection and control

• Functional scalability and flexible configurability 

– easy tailoring of convenient pre-configurations

to application-specific requirements with

freely selectable functions

• Detached HMI – as an option to the integrated

HMI – beneficial from a wiring perspective

because of the large amount of IOs

• Large graphical display for showing

customizable SLDs, accessible either locally

or through a web browser-based HMI

• Extensive life cycle services

Standardized communication

The 630 series relays fully support Edition 1

of the IEC 61850 standard for communication

and interoperability of substation automation

devices. The relays also support the DNP3

(TCP/IP) and IEC 60870-5-103 communication

protocols and are able to use two protocols

simultaneously. The supported communication

protocols, including IEC 61850. offer seamless

connectivity to various station automation

and SCADA systems.

The implementation of the IEC 61850 standard

covers both vertical and horizontal

communication, including GOOSE messaging

according to IEC 61850-8-1 with both binary and

analog signals. Analog GOOSE messaging enables

fast transfer of analog measured values over

the station bus. This facilitates, for example,

sharing of RTD input values, such as surrounding

temperature, with other relays. GOOSE messaging

is an alternative to traditional hardwiring signaling

for exchanging interlocking information between

the relays. For time-critical applications, the 630

series relays support synchronization over

Ethernet using SNTP or over a separate bus

using IRIG-B.

Human-machine interface

The 630 series relays are equipped with a large

graphical display that can show customizable

single-line diagrams (SLD) with position

indication for the circuit breaker, disconnectors

and the earthing switch. Also measured values

provided by the configuration can be displayed.

The SLDs can be flexibly adjusted to meet user

requirements using PCM600 and accessed not

only locally but also via the web browser-based

human-machine interface (HMI).

The 630 series HMI is distinguished by fifteen

three-color LEDs and five configurable push

buttons that can be used as control buttons for

various tasks, such as blocking, adjusting setting

groups or triggering the disturbance recorder.

The five push buttons can also be conveniently

used as menu shortcuts. Another distinguishing

feature is the detached HMI, as an option

to the integrated HMI, which is highly beneficial

from a wiring perspective due to the large

number of IOs the 630 series relays are equipped with.

Functional scalability and flexible configurability make the

Relion® 630 series of relays from ABB ideal for demanding power

distribution applications.

630 series

Flexibility for demanding utility and industrial power distribution systems

The 630 protection and control series of relays is a member of ABB’s

Relion® product family. The 630 series relays are characterized by their

functional scalability and flexible configurability.

Flexible adaptation to application-specific requirements

The 630 series relays can be used in either single

or double-busbar applications with one or two

breakers and numerous switching devices.

They also support a substantial number of both

manually and motor-operated disconnectors and

earthing switches. Consequently, the 630 series

relays can be used to control various types of switchgear.

The 630 series relays offer predefined

configurations, designed to match the most

typical protection and control requirements for

fast and easy setup. The pre-configurations

can be used as such or easily tailored to meet

application-specific requirements – with

freely selectable functions – using the

IEC 61850-compliant Protection and Control

IED Manager PCM600.

Flexibility and high functionality for generator protection and control applications

Not active product since 2024

REG630 is a comprehensive generator management relay for the protection, control,

measurement and supervision of small and medium sized power generators and 

generator-transformer units in utility and power distribution systems.

REG630 is a member of ABB’s Relion® family and part of its 630 protection and control product series.

Scope

• REG630 has been designed to be the main protection for generator and generator-transformer units

Product benefits

• Freely configurable functionality to meet application specific requirements

• Extensive functionality and scalable hardware for the most demanding applications

• All-in-one solution with integration of protection, control, monitoring and supervision in one relay

• Large integrated or detached HMI with user configurable push buttons, making it easy to use

• Extensive life-cycle services

Product features

• Generator differential protection, 3rd harmonic based stator earth-fault protection,

reverse power protection and extensive interconnection protection for distributed generation

• Optional RTD/mA module to be used for various protection and monitoring purposes in generator applications

• 8 RTD/mA inputs and 4 mA outputs

• Supports native IEC 61850 Edition 1. including GOOSE messaging for less wiring and supervised communication

• Supports DNP3 (TCP/IP) and IEC 60870-5-103 communication protocols

The IEC 60870-5-103 implementation supports two parallel

serial bus connections to two different masters. Besides basic

standard functionality, the relay supports changing of the active

setting group and uploading of disturbance recordings in IEC

60870-5-103 format. Further, IEC 60870-5-103 can be used at

the same time with the IEC 61850 protocol.

DNP3 supports both serial and TCP modes for the connection

of up to five masters. Changing the active setting and reading

fault records are supported. DNP serial and DNP TCP can be

used in parallel. If required, both IEC 61850 and DNP can be run

simultaneously.

The relay supports Profibus DPV1 with support of SPA-ZC 302

Profibus adapter. If Profibus is required, the relay must be

ordered with Modbus serial options. Modbus implementation

includes SPA protocol emulation functionality. This functionality

enables connection to SPA-ZC 302.

When the relay uses the RS-485 bus for the serial

communication, both two- and four-wire connections are

supported. Termination and pull-up/down resistors can be

configured with DIP switch on the communication card so that

external resistors are not needed.

HSR applies the PRP principle of parallel operation to a single

ring. For each message sent, the node sends two frames, one

through each port. Both frames circulate in opposite directions

over the ring. Every node forwards the frames it receives from

one port to another to reach the next node. When the

originating sender node receives the frame it sent, the sender

node discards the frame to avoid loops. The HSR ring supports

the connection of up to 30 relays. If more than 30 relays are to

be connected, it is recommended to split the network into

several rings to guarantee the performance for real-time

applications.

The relay can be connected to Ethernet-based communication

systems in a station bus using the RJ-45 connector (100Base

TX) or the multimode fiber optic LC connector (100Base-FX). A

dedicated protection communication port uses a pluggable

multimode or single-mode fiber optic LC connector (100Base

FX). If connection to a serial bus is required, the RS-485 or

fiber-optic serial communication ports can be used.

Modbus implementation supports RTU, ASCII and TCP modes.

Besides standard Modbus functionality, the relay supports

retrieval of time-stamped events, changing the active setting

group and uploading of the latest fault records. If a Modbus

TCP connection is used, five clients can be connected to the

relay simultaneously. Further, Modbus serial and Modbus TCP

can be used in parallel, and, if required, both IEC 61850 and

Modbus can be run simultaneously.

Modbus and DNP3 protocols.

The IEC 61850 standard specifies network redundancy which

improves the system availability for the substation

communication. The network redundancy is based on two

complementary protocols defined in the IEC 62439-3 standard:

PRP and HSR protocols. Both protocols are able to overcome a

failure of a link or switch with a zero switchover time. In both

protocols, each network node has two identical Ethernet ports

dedicated for one network connection.

The protocols rely on the duplication of all transmitted

information and provide a zero switchover time if the links or

switches fail, thus fulfilling all the stringent real-time

requirements of substation automation.

In PRP, each network node is attached to two independent

networks operated in parallel. The networks are completely

separated to ensure failure independence and can have

different topologies. As the networks operate in parallel, they

provide zero-time recovery and continuous checking of

redundancy to avoid failures.

The relay also supports IEC 61850 process bus concept by

sending and receiving sampled values of currents and voltages.

With this functionality the galvanic interpanel wiring can be

replaced with Ethernet communication. The analog values are

transferred as sampled values using the IEC 61850-9-2 LE

protocol. REX640 supports publishing of one and subscribing

of four sampled value streams. The intended application for

sampled values are current-based differential protection

functions or sharing the voltage values with the relays that have

voltage-based protection or supervision functions. The relay

can receive up to four sampled value streams and totally 16

measurements can be connected into the protection relay

application.

Relays with process bus based applications use IEEE 1588

edition 2 for high-accuracy time synchronization.

For redundant Ethernet communication in station bus, the relay

offers either two optical or two galvanic Ethernet network

interfaces. An optional third port with optical or galvanic

Ethernet network interface is also available. The relay also

provides an optional fiber-optic port for dedicated protection

communication which can be used for up to 50 km distances

depending on the selected fiber transceiver. The intended

teleprotection applications for this port are line differential and

line distance protection communication or binary signal

transfer. The optional third Ethernet interface provides

connectivity for any other Ethernet device to an IEC 61850

station bus inside a switchgear bay, for example connection of

a remote I/O. Ethernet network redundancy can be achieved

using the high-availability seamless redundancy (HSR) protocol

or the parallel redundancy protocol (PRP), or with a self-healing

ring using RSTP in the managed switches. Ethernet

redundancy can be applied to the Ethernet-based IEC 61850.

Station communication

Operational information and controls are available through a

wide range of communication protocols including IEC 61850

Edition 2. IEC 61850-9-2 LE, IEC 60870-5-103. IEC

60870-5-104. Modbus® and DNP3. The Profibus DPV1

communication protocol is supported via the protocol

converter SPA-ZC 302. Full communication capabilities, for

example, horizontal communication between the relays, are

only enabled by IEC 61850.

The IEC 61850 protocol is a core part of the relay as the

protection and control application is fully based on standard

modelling. The relay supports Edition 2 and Edition 1 versions

of the standard. With Edition 2 support, the relay has the latest

functionality modelling for substation applications and the best

interoperability for modern substations. The relay supports

flexible product naming (FPN) facilitating the mapping of relay’s

IEC 61850 data model to a customer defined IEC 61850 data

model.

The IEC 61850 communication implementation supports

monitoring and control functions. Additionally, parameter

settings, disturbance recordings and fault records can be

accessed using the IEC 61850 protocol. Disturbance

recordings are available to any Ethernet-based application in

the standard COMTRADE file format. The relay supports

simultaneous event reporting to five different clients on the

station bus.

The relay can send binary and analog signals to other devices

using the IEC 61850-8-1 GOOSE (Generic Object Oriented

Substation Event) profile. Binary GOOSE messaging can, for

example, be used for protection and interlocking-based

protection schemes. The relay meets the GOOSE performance

requirements for tripping applications in distribution

substations, as defined by the IEC 61850 standard (class P1.

<3 ms data exchange between the devices). The relay also

supports the sending and receiving of analog values using

GOOSE messaging. Analog GOOSE messaging enables easy

transfer of analog measurement values over the station bus,

thus facilitating, for example, the sending of measurement

values between the relays when controlling transformers

running in parallel.