Category: ABB

Application

The RED 670 IED is used for the protection, control and monitoring of overhead lines and cables in all types of networks. 

The IED can be used up to the highest voltage levels. 

It is suitable for the protection of heavily loaded lines and multi-terminal lines where the requirement for tripping is one-,two-, and/or three pole. 

The IED is also suitable for protection of cable feeders to generator block transformers.

The phase segregated current differential protection provides an excellent sensitivity for high resistive faults and gives a secure phase selection.

The availability of six stabilized current inputs allows use on multi-breaker arrangements in three

terminal applications or up to five terminal applications with single breaker arrangements.

Remote communication based on the IEEE C37.94 standard can be redundant when required for important installations. 

Charging current compensation allows high sensitivity also on long overhead lines and cables.

A full scheme distance protection is included as independent protection or as back-up at remote end communication failures. 

Eight channels for intertrip and binary signals are available in the communication between the IEDs.

• 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 (RBDR)

– Fault locator (RFLO)

• Metering

– 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 for interlocking

– Single command, 16 signals

– Multiple Command, 80 blocks with 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 identifiers

– Rated system frequency

• Hardware

– Power supply module (PSM)

– Binary input module (BIM)

– Binary output module (BOM)

– Binary in/out module (IOM)

– mA input module (MIM)

– Transformer input module, standard compression connection terminals (TRM)

– Optical ethernet module (OEM)

– SPA/LON/IEC module (SLM)

– Line data communication module (LDCM)

– GPS time synchronization module (GSM)

• Accessories

– GPS antenna, including mounting kit

– External interface converter from C37.94 to  G703

– High impedance resistor unit

– Test switch module RTXP24

– On/off switch

• 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)

• Frequency protection

– Underfrequency protection (PTUF, 81)

– Overfrequency protection (PTOF, 81)

– Rate-of-change frequency protection (PFRC, 81)

• Multipurpose protection

– General current and voltage protection (GAPC)

• Secondary system supervision

– Current circuit supervision (RDIF)

– Fuse failure supervision (RFUF)

• Control

– Synchrocheck and energizing check (RSYN, 25)

– Autorecloser (RREC, 79)

– Apparatus control for single bay, max 8 app.(1CB) incl. Interlocking (APC8)

– Apparatus control for single bay, max 15 app.(2CBs) incl. Interlocking (APC15)

• Scheme communication

– Scheme communication logic for distance protection (PSCH, 85)

– Current reversal and weak-end infeed logic for distance protection (PSCH, 85)

– Local acceleration logic (PLAL)

– Scheme communication logic for residual overcurrent protection (PSCH, 85)

– Current reversal and weak-end infeed logic for residual overcurrent protection (PSCH, 85)

Functions

• Differential protection

– High impedance differential protection(PDIF, 87X)

• Line differential protection

– Line differential protection, 3 CT sets, 2-3 line ends (PDIF, 87L)

– Line differential protection, 6 CT sets, 3-5 line ends (PDIF, 87L)

– Line differential protection 3 CT sets, with in-zone transformers, 2-3 line ends (PDIF, 87LT)

– Line differential protection 6 CT sets, with in-zone transformers, 3-5 line ends (PDIF, 87LT)

• Distance protection

– Distance protection zones (PDIS, 21)

– Phase selection with load encroachment (PDIS, 21)

– Power swing detection (RPSB, 78)

– Automatic switch onto fault logic (PSOF)

• 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)

– Thermal overload protection, one time constant (PTTR, 26)

– Breaker failure protection (RBRF, 50BF)

– Stub protection (PTOC, 50STB)

– Pole discordance protection (RPLD, 52PD)

• Synchrocheck and dead-line check function for single- or multi-breaker arrangements:

– Selectable energizing direction

– Two functions with built-in voltage selection

– For automatic or manual synchrocheck and with different settings

• Auto-reclosing function for single- two-, and/or three-phase reclosing:

– Two functions with priority circuits for multi-breaker arrangements

– Co-operation with synchrocheck function

– Can be switched On-Off from remote through communication or with local switches through binary inputs

• Selectable additional software functions such as distance protection, control and monitoring

• Built-in data communication modules for station bus IEC 61850-8-1

• Data communication modules for station bus IEC 60870-5-103. LON and SPA

• Integrated disturbance and event recorder for up to 40 analog and 96 binary signals

• Time synchronization over IEC 61850-8-1. LON,SPA, binary input or with optional GPS module

• Analog measurements accuracy up to below 0.5% for power and 0.25% for current and voltage and with site calibration to optimize total accuracy

• Versatile local human-machine interface

• Extensive self-supervision with internal event recorder

• Six independent groups of complete setting parameters with password protection

• Powerful software PC tool for setting, disturbance evaluation and configuration

• Remote end data communication modules for C37.94 and G.703

Features

• A protection, control, and monitoring IED with extensive functional library and configuration

possibilities and expandable hardware design to meet specific user requirements

• For overhead lines and cables

• For transformer feeders

• For single and/or three phase tripping

• High impedance differential protection for tee-feeders

• Phase-segregated line differential protection with up to six stabilized inputs for up to five line terminals with:

– Charging current compensation

– Separate inputs for each CT in double breaker, ring and one and a half breaker

installations for improved through fault stability

– Suitable for multiplexed, route switched, as well as dedicated fibre, communication networks using C37.94 protocol

– Power transformers can be included in the protected zone

– Transfer of up to eight binary signals

– Time synchronization with the echo-method or built-in GPS

• Full scheme phase-to-phase and phase-to-earth distance protection with up to three zones:

– All types of scheme communication

– Load encroachment feature

Entry-level numerical relay for distribution networks

REF601 is a dedicated feeder protection and control relay intended for the protection and 

control of utility and industrial power systems in primary and secondary distribution networks. 

The relay provides an optimized composition of protection, monitoring and control functionality in one unit, with the best performance and usability in its class.

Besides the conventional current transformer interface based variant, the relay also supports a variant based on Rogowski current sensors’ analog interface. 

This helps to obtain a compact medium voltage switchgear equipment size reduc­tion with improved performance and standardization.

Scope

Main protection for overhead lines and cable feeders in solidly earthed, resistance-earthed or isolated networks

Inrush current stabilization function for distribution transformers

Product benefits

Compact, flexible and simple to handle

Speedy commissioning through selective test function for protection functions, binary signals and communication features

Easily configurable binary inputs and outputs

Extensive self-supervision of the relay hardware and software

Enhanced safety with usage of sensors variant / detachable terminals with CT shorting facility

Press fit mounting arrangement facilitates easy and fast installation

Product features

Overcurrent, earth-fault, phase-discontinuity, negative-phase sequence and thermal-overload protections, 

inrush current detection, circuit-breaker control, reclosing and measurement

Preconfigured functionality facilitates easy and fast commissioning

Universal power supply 24-265 V AC/DC

Configurable binary inputs/outputs using local HMI or communication interface

Specific variant with site selectable CT selection (1 or 5A), Boolean logic and timers

Site selectable Modbus and IEC 60870-5-103 protocols

Resetting the trip commands/signals

The following resetting modes can be selected for each binary output (tripping or signal outputs):

· Latches until manually reset

· Resets automatically after a delay

Inspection/maintenance

A binary input can be assigned that excludes a bay unit from evaluation by the protection system. 

It is used while performing maintenance or inspection activities on the primary equipment respectively.

Redundant power supplies (Optional)

The central unit may be ordered with a redundant power supply.

Time synchronization

The absolute time accuracy with respect to an external time reference depends on the method of synchronization

7. Requirements

Optical fiber cables

A distributed busbar protection layout requires optical fiber cables and connectors with the following characteristics:

· 2 optical fiber cores per bay unit

· glass fibers with gradient index

· diameter of core 62.5/50 µm, sheath 125 µm

· maximum permissible attenuation ≤ 8 dB/6dB

· LC connector (for 62.5/50 µm optical fibers)

· rodent protected and longitudinally waterproof if in cable ducts

Please observe the permissible bending radius when laying the cables.

Additional features

Self-supervision

All the system functions are continuously monitored to ensure the maximum reliability and availability of the

protection. In the event of a failure, incorrect response or inconsistency, the corresponding action is taken to

establish a safe status, an alarm is given and an event is registered for subsequent diagnostic analysis.

Important items of hardware (e.g. auxiliary supplies, A/D converters and main and program memories) are

subjected to various tests when the system is switched on and also during operation. 

A watchdog continuously monitors the integrity of the software functions and the

exchange of data via the REB500 process bus is also continuously supervised.

Extension of the system

The system functions are determined by software,configured using the software configuration tool.

The system can be completely engineered in advance to correspond to the final state of the station. 

The software modules for new bays or features can be activated using

the HMI500 when the primary plant is installed or the features are needed.

Additional system functions, e.g. breaker failure or end fault protection can be easily activated at any time without extra hardware.

System design

Bay unit (500BU04)

The bay unit is the interface between the protection and the primary system process comprised of the main CTs,

isolators and circuit-breaker and performs the associated data acquisition, pre-processing, control functions and bay

level protection functions. It also provides the electrical insulation between the primary system and the internal

electronics of the protection.

The bay unit contains four input CTs for measuring phase and neutral currents with terminals for 1 A and 5 A.

Additional interposing CTs are not required, because any differences between the CT ratios are compensated by

appropriately configuring the software parameter of the respective bay units.

The bay unit optionally contains five input voltage transformers for the measurement of the three-phase voltages and two busbar voltages to allow the recording of

voltage disturbances. (see Chapter 10).

After acquisition, the analog current and voltage signals are converted to numerical signals which are preprocessed and filtered.

Zero-sequence voltage and zerocurrent signals are also calculated internally. 

The process data are transferred at regular intervals from the bay units to the central processing unit via the REB500 process bus.

Every bay unit has a minimum of 21 binary inputs and 19 binary outputs. The binary I/O module can be used to

detect and process the positions of isolators and couplers,blocking signals, starting signals, external resetting signals, etc.

The binary input channels operate according to a patented pulse modulation principle in a nominal range of 24 to 250 V DC. 

The PC-based HMI program provides settingsfor the threshold voltage of the binary inputs.

Out of the 19 binary outputs, 6 are equipped with power output relays and 13 are signal output relays (see contact data in Chapter 10).