ABB Relion REB500 User manual

Relion®
Distributed busbar protection REB500
Product Guide

Distributed busbar protection REB500 1MRK 505 352-BEN
Product version: 8.2 Issued: 2016-03-01
Revision: -
2ABB
Contents
1. Main features ............................................................................4
2. Application.................................................................................4
3. Mode of installation...................................................................9
4. System design.........................................................................10
5. Functionality............................................................................12
6. Additional features ..................................................................16
7. Requirements..........................................................................16
8. REB500 Process bus configuration .......................................18
9. Hardware description..............................................................19
10. Connection diagrams..............................................................21
11. Technical Data........................................................................29
12. Ordering for customized IED..................................................42
13. Manuals...................................................................................48

Disclaimer
The information in this document is subject to change without notice and should not be construed as a commitment by ABB. ABB assumes no
responsibility for any errors that may appear in this document.
© Copyright 2016 ABB.
All rights reserved.
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ABB and Relion are registered trademarks of the ABB Group. All other brand or product names mentioned in this document may be trademarks or
registered trademarks of their respective holders.

Distributed busbar protection REB500 1MRK 505 352-BEN
Product version: 8.2 Issued: 2016-03-01
Revision: -
4ABB
1. Application
REB500
The numerical busbar protection REB500 is designed for
the high-speed (sub-cycle), selective protection of MV, HV
and EHV busbar installations at a nominal frequency of
50, 60 Hz
The modular system structure is enabling the protection to
be easily configured to suit the layout of the primary
system.
The flexibility of the system enables all configurations of
busbars from single to quadruple, with transfer buses or
ring busbars and 1½ breaker schemes to be protected.
In 1½ breaker schemes the busbars and entire diameters,
including Stub/T-Zone can be protected. An integrated
tripping scheme allows saving external logics as well as
wiring.
The system is scalable for up to 60 feeders (bay units)
and a total of 32 busbar zones.
The numerical busbar protection REB500 detects all
phase and earth faults in solidly grounded and resistive-
grounded power systems and phase faults in ungrounded
systems and systems with Petersen coils.
The main CTs supplying the currents to the busbar
protection have to fulfill only modest performance
requirements (see page 17). The protection operates
discriminatively for all faults inside the zone of protection
and remains reliably stable for all faults outside the zone
of protection.
REB500 bay protection (optional)
The system provides an option to extend the functional
scope of REB500 by a set of predefined bay protection
functions used as main 2 or back-up line protection.
Version ‘Line variant L-V2’ includes distance, directional/
non directional overcurrent and directional earthfault
protection functions (see Table 2).
As regards the level of voltages and frequencies busbar
and station protection have the same application area.
For details on application and technical data refer to the
REB500 Application Manual for bay protection functions.
Typical substation layouts
Figure 1. Single busbar
Figure 2. Double busbar

Distributed busbar protection REB500 1MRK 505 352-BEN
Product version: 8.2 Issued: 2016-03-01
Revision: -
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BI1
QA1
QB1 QB2 QB3
BI1
QA1
QB1 QB2 QB3 QB1 QB2 QB3
QB2
QB1
QB3
QB1 QB2 QB3
BI1
QA1
QB1 QB2 QB3
BI1
QA1
QB1 QB2 QB3
BI1
QA1
Figure 3. Triple busbar
Figure 4. 1 ½ breaker system

Distributed busbar protection REB500 1MRK 505 352-BEN
Product version: 8.2 Issued: 2016-03-01
Revision: -
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Functional overview
Table 1. Included functionalities (●standard, ○optional)
Protection function
Main functionality IEEE REB500 IEC 61850
Busbar protection 87B BBP PDIF ●
Busbar protection with neutral current 87BN I0 PDIF ○
Breaker failure protection including neutral current detection 50BF BFP RBRF ○
End-fault protection 51/62EF EFP PTOC ○
Breaker pole discrepancy 51/62PD PDF PTOC ○
Overcurrent release feature 51 PTOC ○
Voltage release feature 59/27 GAPC ○
Check zone 87CZ BBP CZ PDIF ●
Current plausibility check ●
Overcurrent protection (definite time) 51 OCDT PTOC ○
Trip command redirection 94RD PSCH ●
Software matrix for inputs / outputs /trip matrix ●
Event recording up to 1000 events ER ●
Disturbance recorder (4 x I, 5 x U) up to 20 s 95DR DR RDRE ○
Disturbance recorder (busbar protection data) up to 20 s 95DR DR RDRE ○
Communication interface IEC 61850-8-1 Com ○
Communication interface IEC 60870-5-103 Com ○
Time synchronization (SNTP, IRIG-B, PPS, IEC60870-5-103) ●
Redundant power supply for central unit ○
Isolator supervision ●
Differential current supervision ●
Comprehensive self-supervision ●
Dynamic Busbar replica with display of currents ●
Test generator for commissioning and maintenance ●
Detached Local HMI ●
Delay / Integrator function ●
Binary logic and flip-flop functions ●

Distributed busbar protection REB500 1MRK 505 352-BEN
Product version: 8.2 Issued: 2016-03-01
Revision: -
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Table 2 Bay protection functions of line variant L-V2 (optional)
Bay protection function
Main functionality IEEE REB500 IEC 61850
Distance protection 21 DIST PDIS
Definite time over and undercurrent protection 51 OCDT PTOC
Inverse time overcurrent protection 51 OCINV PTOC
Directional overcurrent definite time protection 67 DIROCDT PTOC
Directional overcurrent inverse time protection 67 DIROCINV PTOC
Inverse time earthfault overcurrent protection 51N I0INV PTOC
Peak value over and undercurrent protection 50 OCINST PTOC
Definite time over and undervoltage protection 59/27 OVDT PTOV
Three phase current plausibility 46 CHKI3PH PTOC
Three phase voltage plausibility 47 CHKU3PH PTOV

Distributed busbar protection REB500 1MRK 505 352-BEN
Product version: 8.2 Issued: 2016-03-01
Revision: -
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2. Main features
Low-impedance busbar protection
·High functional reliability due to two independent
measurement criteria:
-stabilized differential current algorithm
-directional current comparison algorithm
·Short tripping times independent of the plant’s size or
busbar configuration
·Phase Segregated measurement
·Stub and T-zone protection
·Reduced CT performance requirements
-High through-fault stability even in case of CT
saturation
-No switching of CT circuits
Modular and flexible architecture
·Multiple modes of installation
-Centralized layout:
Installation of bay units and central unit in one or
several cubicles
-Distributed layout:
Bay units distributed with short connections to CTs,
isolators, circuit breakers, etc.
·Interference-proof connections between bay units and
central unit by fiber-optic cables (max. 2000m)
·Replacement of existing busbar protection schemes
without restrictions e.g. in case of substation extensions
·Easily extensible
·Only one hardware version for
-Settable 1A and 5A rated current inputs
-Nominal frequencies of 50Hz and 60Hz
·Minimum number of spare parts needed due to
standardization and low number of varying units
Seamless substation automation integration
·User-friendly, PC-based interface (HMI)
·Operator integration into PCM600 for readout of
configuration, events and disturbance records.
·Communication with substation monitoring and control
system
-via IEC 61850-8-1 Edition 1 or Edition 2
-via IEC 60870-5-103
·Local HMI with comprehensive system information on
every unit
Supervision
·Fully numerical signal processing
·Comprehensive self-supervision
·Integrated event recording
·Integrated disturbance recording for power system
currents and voltages
·Optional redundant power supply for central units
Cyber security
·Secure communication
·User Access Management
·User Activity Logging
·Centralized account management
·Verified robustness
Additional options
·Breaker failure protection
·Check-zone protection
·End-fault protection
·Definite time overcurrent protection
·Breaker pole discrepancy protection
·Current and voltage release criteria for busbar
protection
·Separate I0measurement for impedance-grounded
networks
·Advanced user configurable logic capability

Distributed busbar protection REB500 1MRK 505 352-BEN
Product version: 8.2 Issued: 2016-03-01
Revision: -
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3. Mode of installation
There are three versions of installing the numerical busbar
protection REB500:
Distributed installation
In this case, the bay units are installed in casings or
cubicles in the individual switchgear bays distributed
around the station and are connected to the central
processing unit by optical fiber cables (see Figure 5). The
central processing unit is normally located in a central
cubicle or in a central relay room.
Centralized installation
The central processing unit and the bay units are mounted
in 19"racks (up to two bay units each rack), according to
the size of the busbar system in one or more cubicles (see
Figure 6). A centralized installation is the ideal solution for
upgrading existing stations, since very little additional
wiring is required and compared with older kinds of busbar
protection, much more functionality can be packed into the
same space.
Combined centralized and distributed installation
Basically, the only difference between a distributed and a
centralized scheme is the mounting location of the bay
units and therefore it is possible to mix the two
philosophies.
Figure 5. Distributed installation

Distributed busbar protection REB500 1MRK 505 352-BEN
Product version: 8.2 Issued: 2016-03-01
Revision: -
10 ABB
Figure 6. Centralized installation
4. 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 pre-
processed and filtered. Zero-sequence voltage and zero-
current 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 settings
for 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).
Additional 12 inputs and 6 precision outputs are available
as an option. The precision outputs are based on