ABB RELION 650 SERIES User manual

Relion® 650 SERIES
Busbar protection REB650
Version 1.1 ANSI
Product guide

Contents
1. 650 series overview................................................................. 3
2. Application.................................................................................3
3. Available functions...................................................................5
4. Differential protection............................................................9
5. Current protection...................................................................9
6. Voltage protection..................................................................11
7. Secondary system supervision............................................11
8. Control.......................................................................................12
9. Logic.......................................................................................... 12
10. Monitoring.............................................................................. 13
11. Metering.................................................................................. 15
12. Human Machine interface...................................................15
13. Basic IED functions...............................................................16
14. Station communication...................................................... 16
15. Hardware description.......................................................... 17
16. Connection diagrams.......................................................... 19
17. Technical data....................................................................... 20
18. Ordering..................................................................................43
Disclaimer
The information in this document is subject to change without notice and should not be construed as a commitment by ABB Power Grids. ABB Power Grids
assumes no responsibility for any errors that may appear in this document.
© Copyright 2011 ABB Power Grids. All rights reserved.
Trademarks
ABB and Relion are registered trademarks of ABB Group. All other brand or product names mentioned in this document may be trademarks or registered
trademarks of their respective holders.
Busbar protection REB650
1MRK 505 265-BUS B
Version 1.1 ANSI
2 ABB Power Grids

1. 650 series overview GUID-420ACE74-2F34-4991-8DA3-967843F6BFFF v2
The 650 series IEDs provide optimum 'off-the-shelf',
ready-to-use solutions. It is configured with complete
protection functionality and default parameters to meet
the needs of a wide range of applications for generation
transmission and sub-transmission grids.
The 650 series IEDs include:
• Complete ready to use solutions optimized for a wide
range of applications for generation, transmission and
sub-transmission grids.
• Support for user-defined names in the local language for
signal and function engineering.
• Minimized parameter settings based on default values
and ABB's new global base value concept. You only need
to set those parameters specific to your own
application, such as the line data.
• GOOSE messaging for horizontal communication.
• Extended HMI functionality with 15 dynamic three-color-
indication LEDs per page, on up to three pages, and
configurable push-button shortcuts for different
actions.
• Programmable LED text-based labels.
• Settable 1A/5A -rated current inputs.
2. Application GUID-1D0AE9E6-1A32-4D83-BC31-0E1740DC88B7 v2
The numerical busbar protection REB650 IED provides its
users with a wide variety of application opportunities.
Designed primarily for the protection of single busbars
with or without sectionalizers in high impedance based
applications, it also offers high impedance differential
protection for generators, autotransformers, shunt
reactors and capacitor banks. Its I/O capability allows you
to protect up to three 3-phase high impedance differential
protection zones with a single IED.
A number of additional protection functions are available
for the protection of the bus tie bay. The additional
protection functions include different types of phase and
ground fault overcurrent protection and overvoltage/
undervoltage protection.
One pre-configured package has been defined for the
following application:
• Complete busbar protection for two busbar sections
(zone 1 and 2), with the possibility for check zone (A03A)
For the high impedance differential protection, the
differential current process is made in the analogue
current transformer circuits where the differential current
is connected to the IED via a high ohmic resistor. In
REB650, a current input is used for each phase and
protection zone.
The package is configured and ready for direct use.
Analogue inputs and binary input/output circuits are pre-
defined.
The pre-configured IED can be changed and adapted to
suit specific applications with the graphical configuration
tool.
Busbar protection REB650
Version 1.1 ANSI
1MRK 505 265-BUS B
Issued: May 2020
Revision: B
ABB Power Grids 3
© Copyright 2011 ABB Power Grids. All rights reserved

REB650-A03A
ROV2 PTOV
59N 3Uo>
UV2 PTUV
27 3U<
OV2 PTOV
59 3U>
ROV2 PTOV
59N 3Uo>
UV2 PTUV
27 3U<
OV2 PTOV
59 3U>
HZ PDIF
87N IdN
HZ PDIF
87N IdN
HZ PDIF
87N IdN
EF4 PTOC
67N
OC4 PTOC
67
DNS PTOC
67Q
CC RPLD
52PD PD
CC RBRF
50BF 3I> BF
Zone 1
Zone 2
Zone 3 (used in this example as check zone)
Bus 1
Bus Coupler
Feeder Bays Feeder Bays
TRM module with 6I+4U
AIM module with 6I+4U
Bus 2
VT1 VT2
IEC61850
ANSI IEC
Function Enabled
in Settings
ANSI11000145_1_en.vsd
3I> I2> IN>
Y
Y
Y
Y
DNP
ANSI IEC
Function Disabled in Settings
IEC60870-5-103
ANSI IEC
ANSI11000145 V1 EN-US
Figure 1. A typical busbar protection for two busbar sections with the possibility of a check zone
Busbar protection REB650
1MRK 505 265-BUS B
Version 1.1 ANSI
4 ABB Power Grids
© Copyright 2011 ABB Power Grids. All rights reserved

3. Available functions
Main protection functions GUID-35C75FDE-9C6C-44CE-8BDB-6CCB9541EDFE v2.1.1
IEC 61850/
Function block
name
ANSI Function description Busbar
REB650 (A03A)
HiZ/3Ph
Differential protection
HZPDIF 87 1Ph High impedance differential protection 9
Back-up protection functions GUID-47D5EAC9-5F4A-4A3D-B813-4E50A2BCCDC3 v2.1.1
IEC 61850/
Function
block name
ANSI Function description Busbar
REB650 (A03A)
HiZ/3Ph
Current protection
OC4PTOC 51/67 Four step directional phase overcurrent protection 1
EF4PTOC 51N/67N Four step directional residual overcurrent protection 1
TRPTTR 49 Thermal overload protection, two time constants 1
CCRBRF 50BF Breaker failure protection 1
CCRPLD 52PD Pole discordance protection 1
DNSPTOC 46 Negative sequence based overcurrent function 1
Voltage protection
UV2PTUV 27 Two step undervoltage protection 2
OV2PTOV 59 Two step overvoltage protection 2
ROV2PTOV 59N Two step residual overvoltage protection 2
Busbar protection REB650
1MRK 505 265-BUS B
Version 1.1 ANSI
ABB Power Grids 5
© Copyright 2011 ABB Power Grids. All rights reserved

Control and monitoring functions GUID-C4EC0541-2883-4185-90AB-BAEB25A5E249 v2.1.1
IEC 61850/Function
block name
ANSI Function description Busbar
REB650 (A03A) HiZ/3Ph
Control
QCBAY Bay control 1
LOCREM Handling of LR-switch positions 1
LOCREMCTRL LHMI control of Permitted Source To Operate (PSTO) 1
SLGGIO Logic Rotating Switch for function selection and LHMI presentation 15
VSGGIO Selector mini switch extension 20
DPGGIO IEC 61850 generic communication I/O functions double point 16
SPC8GGIO Single point generic control 8 signals 5
AUTOBITS AutomationBits, command function for DNP3.0 3
I103CMD Function commands for IEC60870-5-103 1
I103IEDCMD IED commands for IEC60870-5-103 1
I103USRCMD Function commands user defined for IEC60870-5-103 4
I103GENCMD Function commands generic for IEC60870-5-103 50
I103POSCMD IED commands with position and select for IEC60870-5-103 50
Secondary system supervision
SDDRFUF Fuse failure supervision 2
TCSSCBR Breaker close/trip circuit monitoring 3
Logic
SMPPTRC 94 Tripping logic 6
TMAGGIO Trip matrix logic 12
OR Configurable logic blocks, OR gate 283
INVERTER Configurable logic blocks, Inverter gate 140
PULSETIMER Configurable logic blocks, Pulse timer 40
GATE Configurable logic blocks, Controllable gate 40
XOR Configurable logic blocks, exclusive OR gate 40
LOOPDELAY Configurable logic blocks, loop delay 40
TIMERSET Configurable logic blocks, timer function block 40
AND Configurable logic blocks, AND gate 280
SRMEMORY Configurable logic blocks, set-reset memory flip-flop gate 40
RSMEMORY Configurable logic blocks, reset-set memory flip-flop gate 40
Busbar protection REB650
1MRK 505 265-BUS B
Version 1.1 ANSI
6 ABB Power Grids
© Copyright 2011 ABB Power Grids. All rights reserved

IEC 61850/Function
block name
ANSI Function description Busbar
REB650 (A03A) HiZ/3Ph
FXDSIGN Fixed signal function block 1
B16I Boolean 16 to Integer conversion 16
B16IFCVI Boolean 16 to Integer conversion with logic node representation 16
IB16A Integer to Boolean 16 conversion 16
IB16FCVB Integer to Boolean 16 conversion with logic node representation 16
Monitoring
CVMMXN Measurements 6
CMMXU Phase current measurement 10
VMMXU Phase-phase voltage measurement 6
CMSQI Current sequence component measurement 6
VMSQI Voltage sequence measurement 6
VNMMXU Phase-neutral voltage measurement 6
CNTGGIO Event counter 5
DRPRDRE Disturbance report 1
AxRADR Analog input signals 4
BxRBDR Binary input signals 6
SPGGIO IEC 61850 generic communication I/O functions 64
SP16GGIO IEC 61850 generic communication I/O functions 16 inputs 16
MVGGIO IEC 61850 generic communication I/O functions 16
MVEXP Measured value expander block 66
SPVNZBAT Station battery supervision 1
SSIMG 63 Insulation gas monitoring function 2
SSIML 71 Insulation liquid monitoring function 2
SSCBR Circuit breaker condition monitoring 1
I103MEAS Measurands for IEC60870-5-103 1
I103MEASUSR Measurands user defined signals for IEC60870-5-103 3
I103AR Function status auto-recloser for IEC60870-5-103 1
I103EF Function status earth-fault for IEC60870-5-103 1
I103FLTPROT Function status fault protection for IEC60870-5-103 1
I103IED IED status for IEC60870-5-103 1
I103SUPERV Supervison status for IEC60870-5-103 1
Busbar protection REB650
1MRK 505 265-BUS B
Version 1.1 ANSI
ABB Power Grids 7
© Copyright 2011 ABB Power Grids. All rights reserved

IEC 61850/Function
block name
ANSI Function description Busbar
REB650 (A03A) HiZ/3Ph
I103USRDEF Status for user defined signals for IEC60870-5-103 20
Metering
PCGGIO Pulse counter logic 16
ETPMMTR Function for energy calculation and demand handling 3
Designed to communicate GUID-22F345AB-6250-40E7-9B80-36EA4D8EDA62 v2.2.1
IEC 61850/Function
block name
ANSI Function description Busbar
REB650 (A03A)
HiZ/3Ph
Station communication
IEC 61850 communication protocol, LAN1 1
DNP3.0 for TCP/IP communication protocol, LAN1 1
IEC61870-5-103 IEC60870-5-103 serial communication via ST 1
GOOSEINTLKRCV Horizontal communication via GOOSE for interlocking 59
GOOSEBINRCV GOOSE binary receive 4
GOOSEDPRCV GOOSE function block to receive a double point value 32
GOOSEINTRCV GOOSE function block to receive an integer value 32
GOOSEMVRCV GOOSE function block to receive a mesurand value 16
GOOSESPRCV GOOSE function block to receive a single point value 64
Busbar protection REB650
1MRK 505 265-BUS B
Version 1.1 ANSI
8 ABB Power Grids
© Copyright 2011 ABB Power Grids. All rights reserved

Basic IED functions GUID-1DA8FC6E-D726-407B-84D3-0796B00D636F v2
IEC 61850/Function
block name
Function description
Basic functions included in all products
INTERRSIG Self supervision with internal event list 1
SELFSUPEVLST Self supervision with internal event list 1
SNTP Time synchronization 1
TIMESYNCHGEN Time synchronization 1
DTSBEGIN, DTSEND,
TIMEZONE
Time synchronization, daylight saving 1
IRIG-B Time synchronization 1
SETGRPS Setting group handling 1
ACTVGRP Parameter setting groups 1
TESTMODE Test mode functionality 1
CHNGLCK Change lock function 1
TERMINALID IED identifiers 1
PRODINF Product information 1
PRIMVAL Primary system values 1
SMAI_20_1-12 Signal matrix for analog inputs 2
3PHSUM Summation block 3 phase 12
GBASVAL Global base values for settings 6
ATHSTAT Authority status 1
ATHCHCK Authority check 1
FTPACCS FTP access with password 1
DOSFRNT Denial of service, frame rate control for front port 1
DOSLAN1 Denial of service, frame rate control for LAN1 1
DOSSCKT Denial of service, socket flow control 1
4. Differential protection
Restricted earth fault protection REFPDIF
1Ph High impedance differential protection HZPDIF
(87) M13071-3 v8
The 1Ph High impedance differential protection (HZPDIF,
87) function can be used when the involved CTs have the
same turns ratio and similar magnetizing characteristics.
It utilizes an external summation of the currents in the
interconnected CTs, a series resistor, and a voltage
dependent resistor which are mounted externally
connected to the IED.
Three instances of 1Ph High impedance differential
protection function (HZPDIF, 87) can be used to provide a
three phase differential protection function to be used for
example as busbar protection. One instance of HZPDIF
(87) can also be used as high impedance REF protection.
5. Current protection
Four step phase overcurrent protection OC4PTOC
(51/67) M12846-3 v9
The four step phase overcurrent protection function
OC4PTOC (51/67) has independent inverse time delay
Busbar protection REB650
1MRK 505 265-BUS B
Version 1.1 ANSI
ABB Power Grids 9
© Copyright 2011 ABB Power Grids. All rights reserved

settings for step 1 and 4. Step 2 and 3 are always definite
time delayed.
All IEC and ANSI inverse time characteristics are available.
The directional function is voltage polarized with memory.
The function can be set to be directional or non-
directional independently for each of the steps.
Four step residual overcurrent protection EF4PTOC
(51N_67N) M13667-3 v11
The four step residual overcurrent protection (EF4PTOC,
51N/67N) has independent inverse time delay settings for
step 1 and 4. Step 2 and 3 are always definite time
delayed.
All IEC and ANSI inverse time characteristics are available.
The directional function includes 3 options
• voltage polarized
• current polarized
• dual polarized
EF4PTOC (51N/67N) can be set directional or non-
directional independently for each of the steps.
Second harmonic blocking can be set individually for each
step.
Thermal overload protection, two time constant
TRPTTR (49) M13243-3 v7
If a power transformer or generator reaches very high
temperatures the equipment might be damaged. The
insulation within the transformer/generator will have
forced ageing. As a consequence of this the risk of
internal phase-to-phase or phase-to-ground faults will
increase. High temperature will degrade the quality of the
transformer/generator insulation.
The thermal overload protection estimates the internal
heat content of the transformer/generator (temperature)
continuously. This estimation is made by using a thermal
model of the transformer/generator with two time
constants, which is based on current measurement.
Two warning pickup levels are available. This enables
actions in the power system to be done before dangerous
temperatures are reached. If the temperature continues to
increase to the trip value, the protection initiates a trip of
the protected transformer/generator.
Breaker failure protection CCRBRF (50BF) M11550-6 v9
Breaker failure protection (CCRBRF, 50BF) ensures fast
back-up tripping of surrounding breakers in case the
protected breaker fails to open. CCRBRF (50BF) can be
current based, contact based, or an adaptive combination
of these two conditions.
Current check with extremely short reset time is used as
check criterion to achieve high security against
unnecessary operation.
Contact check criteria can be used where the fault current
through the breaker is small.
Breaker failure protection (CCRBRF, 50BF) current criteria
can be fulfilled by one or two phase currents, or one phase
current plus residual current. When those currents exceed
the user defined settings, the function is activated. These
conditions increase the security of the back-up trip
command.
CCRBRF (50BF) function can be programmed to give a
three-phase re-trip of the protected breaker to avoid
unnecessary tripping of surrounding breakers.
Pole discordance protection CCRPLD (52PD) M13269-3 v10
Circuit breakers and disconnectors can end up with their
phase poles in different positions (close-open), due to
electrical or mechanical failures.An open phase can cause
negative and zero sequence currents which cause thermal
stress on rotating machines and can cause unwanted
operation of zero sequence or negative sequence current
functions.
Normally the affected breaker is tripped to correct such a
situation. If the situation warrants the surrounding
breakers should be tripped to clear the unsymmetrical
load situation.
The pole discrepancy function operates based on
information from the circuit breaker logic with additional
criteria from unsymmetrical phase currents when
required.
Negative sequence based overcurrent function
DNSPTOC (46) GUID-CFD34404-5934-41EE-8AAC-A5FD2B9B4E33 v3
Negative sequence based overcurrent function (DNSPTOC,
46) may be used in power line applications where the
reverse zero sequence source is weak or open, the forward
source impedance is strong and it is desired to detect
forward ground faults.
Additionally, it is applied in applications on underground
cables, where zero sequence impedance depends on the
fault current return paths, but the cable negative
sequence impedance is practically constant.
Busbar protection REB650
1MRK 505 265-BUS B
Version 1.1 ANSI
10 ABB Power Grids
© Copyright 2011 ABB Power Grids. All rights reserved

The directional function is current and voltage polarized.
The function can be set to forward, reverse or non-
directional independently for each step.
DNSPTOC (46) protects against all unbalanced faults
including phase-to-phase faults. The minimum pickup
current of the function must be set to above the normal
system unbalance level in order to avoid unintentional
tripping.
6. Voltage protection
Two step undervoltage protection UV2PTUV (27) M13789-3 v7
Undervoltages can occur in the power system during
faults or abnormal conditions. Two step undervoltage
protection (UV2PTUV, 27) function can be used to open
circuit breakers to prepare for system restoration at
power outages or as long-time delayed back-up to primary
protection.
UV2PTUV (27) has two voltage steps, where step 1 is
settable as inverse or definite time delayed. Step 2 is
always definite time delayed.
Two step overvoltage protection OV2PTOV (59) M13798-3 v7
Overvoltages may occur in the power system during
abnormal conditions such as sudden power loss, tap
changer regulating failures, open line ends on long lines
etc.
OV2PTOV (59) has two voltage steps, where step 1 can be
set as inverse or definite time delayed. Step 2 is always
definite time delayed.
OV2PTOV (59) has an extremely high reset ratio to allow
settings close to system service voltage.
Two step residual overvoltage protection ROV2PTOV
(59N) M13808-3 v8
Residual voltages may occur in the power system during
ground faults.
Two step residual overvoltage protection ROV2PTOV (59N)
function calculates the residual voltage from the three-
phase voltage input transformers or measures it from a
single voltage input transformer fed from a broken delta
or neutral point voltage transformer.
ROV2PTOV (59N) has two voltage steps, where step 1 can
be set as inverse or definite time delayed. Step 2 is always
definite time delayed.
7. Secondary system supervision
Fuse failure supervision SDDRFUF SEMOD113820-4 v5
The aim of the fuse failure supervision function
(SDDRFUF) is to block voltage measuring functions at
failures in the secondary circuits between the voltage
transformer and the IED in order to avoid unwanted
operations that otherwise might occur.
The fuse failure supervision function basically has three
different algorithms, negative sequence and zero
sequence based algorithms and an additional delta
voltage and delta current algorithm.
The negative sequence detection algorithm is
recommended for IEDs used in isolated or high-impedance
grounded networks. It is based on the negative-sequence
measuring quantities, a high value of voltage without the
presence of the negative-sequence current 3I2.
The zero sequence detection algorithm is recommended
for IEDs used in directly or low impedance grounded
networks. It is based on the zero sequence measuring
quantities, a high value of voltage 3V0 without the
presence of the residual current 3I0.
A criterion based on delta current and delta voltage
measurements can be added to the fuse failure
supervision function in order to detect a three phase fuse
failure, which in practice is more associated with voltage
transformer switching during station operations.
For better adaptation to system requirements, an
operation mode setting has been introduced which makes
it possible to select the operating conditions for negative
sequence and zero sequence based function. The selection
of different operation modes makes it possible to choose
different interaction possibilities between the negative
sequence and zero sequence based algorithm.
Breaker close/trip circuit monitoring TCSSCBR
GUID-EE8A480D-59AB-423D-9567-317A111EF846 v8
The trip circuit monitoring function TCSSCBR is designed
for supervision of control circuits. A fault in a control
circuit is detected by using a dedicated output contact
that contains the monitoring functionality.
The function picks up and trips when TCSSCBR detects a
trip circuit failure. The trip time characteristic for the
function is of definite time (DT) type. The function trips
after a predefined operating time and resets when the
fault disappears.
Busbar protection REB650
1MRK 505 265-BUS B
Version 1.1 ANSI
ABB Power Grids 11
© Copyright 2011 ABB Power Grids. All rights reserved

8. Control
Bay control QCBAY M13447-3 v5
The Bay control QCBAY function is used together with
Local remote and local remote control functions to handle
the selection of the operator place per bay. QCBAY also
provides blocking functions that can be distributed to
different apparatuses within the bay.
Local remote LOCREM /Local remote control
LOCREMCTRL M17086-3 v4
The signals from the local HMI or from an external local/
remote switch are applied via the function blocks LOCREM
and LOCREMCTRL to the Bay control (QCBAY) function
block. A parameter in function block LOCREM is set to
choose if the switch signals are coming from the local HMI
or from an external hardware switch connected via binary
inputs.
Logic rotating switch for function selection and LHMI
presentation SLGGIO SEMOD114908-4 v6
The logic rotating switch for function selection and LHMI
presentation function (SLGGIO) (or the selector switch
function block) is used to get a selector switch
functionality similar to the one provided by a hardware
selector switch. Hardware selector switches are used
extensively by utilities, in order to have different functions
operating on pre-set values. Hardware switches are
however sources for maintenance issues, lower system
reliability and an extended purchase portfolio. The logic
selector switches eliminate all these problems.
Selector mini switch VSGGIO SEMOD158756-5 v5
The Selector mini switch VSGGIO function block is a
multipurpose function used for a variety of applications,
as a general purpose switch.
VSGGIO can be controlled from the menu or from a symbol
on the single line diagram (SLD) on the local HMI.
IEC 61850 generic communication I/O functions
DPGGIO SEMOD55850-5 v3
The IEC 61850 generic communication I/O functions
(DPGGIO) function block is used to send double
indications to other systems or equipment in the
substation. It is especially used in the interlocking and
reservation station-wide logics.
Single point generic control 8 signals SPC8GGIO
SEMOD176462-4 v5
The Single point generic control 8 signals (SPC8GGIO)
function block is a collection of 8 single point commands,
designed to bring in commands from REMOTE (SCADA) to
those parts of the logic configuration that do not need
extensive command receiving functionality (for example,
SCSWI). In this way, simple commands can be sent directly
to the IED outputs, without confirmation. Confirmation
(status) of the result of the commands is supposed to be
achieved by other means, such as binary inputs and
SPGGIO function blocks. The commands can be pulsed or
steady.
AutomationBits AUTOBITS SEMOD158591-5 v4
The Automation bits function (AUTOBITS) is used to
configure the DNP3 protocol command handling.
9. Logic
Tripping logic SMPPTRC (94) M12275-3 v5
A function block for protection tripping is provided for
each circuit breaker involved in the tripping of the fault. It
provides pulse prolongation to ensure a trip pulse of
sufficient length, as well as all functionality necessary for
correct co-operation with autoreclosing functions.
The trip function block includes functionality for breaker
lock-out.
Trip matrix logic TMAGGIO M15321-3 v7
Trip matrix logic TMAGGIO function is used to route trip
signals and other logical output signals to different
output contacts on the IED.
TMAGGIO output signals and the physical outputs allows
the user to adapt the signals to the physical tripping
outputs according to the specific application needs.
Configurable logic blocks M11396-4 v10
A number of logic blocks and timers are available for the
user to adapt the configuration to the specific application
needs.
•OR function block.
•INVERTER function blocks that inverts the input signal.
•PULSETIMER function block can be used, for example,
for pulse extensions or limiting of operation of outputs.
•GATE function block is used for whether or not a signal
should be able to pass from the input to the output.
•XOR function block.
•LOOPDELAY function block used to delay the output
signal one execution cycle.
•TIMERSET function has pick-up and drop-out delayed
outputs related to the input signal. The timer has a
settable time delay.
Busbar protection REB650
1MRK 505 265-BUS B
Version 1.1 ANSI
12 ABB Power Grids
© Copyright 2011 ABB Power Grids. All rights reserved

•AND function block.
•SRMEMORY function block is a flip-flop that can set or
reset an output from two inputs respectively. Each block
has two outputs where one is inverted. The memory
setting controls if the block's output should reset or
return to the state it was, after a power interruption.
•RSMEMORY function block is a flip-flop that can reset or
set an output from two inputs respectively. Each block
has two outputs where one is inverted. The memory
setting controls if the block's output should reset or
return to the state it was, after a power interruption.
Reset input has priority.
Boolean 16 to Integer conversion B16I SEMOD175725-4 v3
Boolean 16 to integer conversion function (B16I) is used to
transform a set of 16 binary (logical) signals into an
integer.
Boolean 16 to Integer conversion with logic node
representation B16IFCVI SEMOD175781-4 v4
Boolean 16 to integer conversion with logic node
representation function (B16IFCVI) is used to transform a
set of 16 binary (logical) signals into an integer.
Integer to Boolean 16 conversion IB16A SEMOD158373-5 v3
Integer to boolean 16 conversion function (IB16A) is used
to transform an integer into a set of 16 binary (logical)
signals.
Integer to Boolean 16 conversion with logic node
representation IB16FCVB SEMOD158421-5 v4
Integer to boolean conversion with logic node
representation function (IB16FCVB) is used to transform
an integer to 16 binary (logic) signals.
IB16FCVB function can receive remote values over
IEC61850 depending on the operator position input
(PSTO).
10. Monitoring
Measurements CVMMXN, CMMXU, VNMMXU, VMMXU,
CMSQI, VMSQI M12024-3 v6
The measurement functions are used to get on-line
information from the IED. These service values make it
possible to display on-line information on the local HMI
and on the Substation automation system about:
• measured voltages, currents, frequency, active, reactive
and apparent power and power factor
• primary and secondary phasors
• current sequence components
• voltage sequence components
Event counter CNTGGIO M13407-3 v6
Event counter (CNTGGIO) has six counters which are used
for storing the number of times each counter input has
been activated.
Disturbance report DRPRDRE M12153-3 v8
Complete and reliable information about disturbances in
the primary and/or in the secondary system together with
continuous event-logging is accomplished by the
disturbance report functionality.
Disturbance report DRPRDRE, always included in the IED,
acquires sampled data of all selected analog input and
binary signals connected to the function block with a,
maximum of 40 analog and 96 binary signals.
The Disturbance report functionality is a common name
for several functions:
• Sequential of events
• Indications
• Event recorder
• Trip value recorder
• Disturbance recorder
The Disturbance report function is characterized by great
flexibility regarding configuration, initiating conditions,
recording times, and large storage capacity.
A disturbance is defined as an activation of an input to the
AxRADR or BxRBDR function blocks, which are set to
trigger the disturbance recorder. All signals 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 the IED in
the standard Comtrade format. The same applies to all
events, which are continuously saved in a FIFO-buffer. The
local HMI is used to get information about the recordings.
The disturbance report files may be uploaded to PCM600
for further analysis using the disturbance handling tool.
Sequential of events DRPRDRE M12412-6 v7
Continuous event-logging is useful for monitoring the
system from an overview perspective and is a complement
to specific disturbance recorder functions.
Busbar protection REB650
1MRK 505 265-BUS B
Version 1.1 ANSI
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The sequential of events logs all binary input signals
connected to the Disturbance report function. The list
may contain up to 1000 time-tagged events stored in a
FIFO-buffer.
Indications DRPRDRE M12030-3 v4
To get fast, condensed and reliable information about
disturbances in the primary and/or in the secondary
system it is important to know, for example binary signals
that have changed status during a disturbance. This
information is used in the short perspective to get
information via the local HMI in a straightforward way.
There are three LEDs on the local HMI (green, yellow and
red), which will display status information about the IED
and the Disturbance report function (trigged).
The Indication list function shows all selected binary input
signals connected to the Disturbance report function that
have changed status during a disturbance.
Event recorder DRPRDRE M12033-3 v7
Quick, complete and reliable information about
disturbances in the primary and/or in the secondary
system is vital, for example, time-tagged events logged
during disturbances. This information is used for different
purposes in the short term (for example corrective
actions) and in the long term (for example functional
analysis).
The event recorder logs all selected binary input signals
connected to the Disturbance report function. Each
recording can contain up to 150 time-tagged events.
The event recorder information is available for the
disturbances locally in the IED.
The event recording information is an integrated part of
the disturbance record (Comtrade file).
Trip value recorder DRPRDRE M12128-3 v6
Information about the pre-fault and fault values for
currents and voltages are vital for the disturbance
evaluation.
The Trip value recorder calculates the values of all selected
analog input signals connected to the Disturbance report
function. The result is magnitude and phase angle before
and during the fault for each analog input signal.
The trip value recorder information is available for the
disturbances locally in the IED.
The trip value recorder information is an integrated part
of the disturbance record (Comtrade file).
Disturbance recorder DRPRDRE M12156-3 v8
The Disturbance recorder function supplies fast, complete
and reliable information about disturbances in the power
system. It facilitates understanding system behavior and
related primary and secondary equipment during and
after a disturbance. Recorded information is used for
different purposes in the short perspective (for example
corrective actions) and long perspective (for example
functional analysis).
The Disturbance recorder acquires sampled data from
selected analog- and binary signals connected to the
Disturbance report function (maximum 40 analog and 96
binary signals). The binary signals available are the same
as for the event recorder function.
The function is characterized by great flexibility and is not
dependent on the operation of protection functions. It can
record disturbances not detected by protection functions.
Up to three seconds of data before the trigger instant can
be saved in the disturbance file.
The disturbance recorder information for up to 100
disturbances are saved in the IED and the local HMI is used
to view the list of recordings.
Measured value expander block MVEXP SEMOD52450-4 v5
The current and voltage measurements functions
(CVMMXN, CMMXU, VMMXU and VNMMXU), current and
voltage sequence measurement functions (CMSQI and
VMSQI) and IEC 61850 generic communication I/O
functions (MVGGIO) are provided with measurement
supervision functionality. All measured values can be
supervised with four settable limits: low-low limit, low
limit, high limit and high-high limit. The measure value
expander block has been introduced to enable translating
the integer output signal from the measuring functions to
5 binary signals: below low-low limit, below low limit,
normal, above high-high limit or above high limit. The
output signals can be used as conditions in the
configurable logic or for alarming purpose.
Station battery supervision SPVNZBAT
GUID-D435B51F-8B7F-472D-90E6-3257FFDC0570 v1
The station battery supervision function SPVNZBAT is
used for monitoring battery terminal voltage.
SPVNZBAT activates the start and alarm outputs when the
battery terminal voltage exceeds the set upper limit or
drops below the set lower limit. A time delay for the
overvoltage and undervoltage alarms can be set according
to definite time characteristics.
Busbar protection REB650
1MRK 505 265-BUS B
Version 1.1 ANSI
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In the definite time (DT) mode, SPVNZBAT operates after a
predefined operate time and resets when the battery
undervoltage or overvoltage condition disappears.
Insulation gas monitoring function SSIMG
GUID-0692CD0D-F33E-4370-AC91-B216CAAAFC28 v3
Insulation gas monitoring function SSIMG (63) is used for
monitoring the circuit breaker condition. Binary
information based on the gas pressure in the circuit
breaker is used as input signals to the function. In
addition, the function generates alarms based on received
information.
Insulation liquid monitoring function SSIML
GUID-3B1A665F-60A5-4343-85F4-AD9C066CBE8D v3
Insulation liquid monitoring function SSIML (71) is used
for monitoring the circuit breaker condition. Binary
information based on the oil level in the circuit breaker is
used as input signals to the function. In addition, the
function generates alarms based on received information.
Circuit breaker monitoring SSCBR GUID-E1FD74C3-B9B6-4E11-AA1B-7E7F822FB4DD v7
The circuit breaker condition monitoring function SSCBR
is used to monitor different parameters of the circuit
breaker. The breaker requires maintenance when the
number of operations has reached a predefined value. For
proper functioning of the circuit breaker, it is essential to
monitor the circuit breaker operation, spring charge
indication, breaker wear, travel time, number of operation
cycles and accumulated energy. The energy is calculated
from the measured input currents as a sum of I^2 t values.
Alarms are generated when the calculated values exceed
the threshold settings.
The function contains a blocking functionality. It is
possible to block the function outputs, if desired.
11. Metering
Pulse counter logic PCGGIO M13394-3 v6
Pulse counter (PCGGIO) function counts externally
generated binary pulses, for instance pulses coming from
an external energy meter, for calculation of energy
consumption values. The pulses are captured by the BIO
(binary input/output) module and then read by the
PCGGIO function. A scaled service value is available over
the station bus.
Function for energy calculation and demand handling
ETPMMTR SEMOD153641-8 v5
Outputs from the Measurements (CVMMXN) function can
be used to calculate energy consumption. Active as well as
reactive values are calculated in import and export
direction. Values can be read or generated as pulses.
Maximum demand power values are also calculated by the
function.
12. Human Machine interface
Local HMI AMU0600442 v7
GUID-DA949D6F-070D-4D84-82AC-6791EF64F84F V1 EN-US
Figure 2. Local human-machine interface
The LHMI of the IED contains the following elements:
• Display (LCD)
• Buttons
• LED indicators
• Communication port
The LHMI is used for setting, monitoring and controlling .
GUID-CABB3689-DEA5-4611-A492-13B3D6632846 v3
The Local human machine interface, LHMI includes a
graphical monochrome LCD with a resolution of 320x240
pixels. The character size may vary depending on selected
language. The amount of characters and rows fitting the
view depends on the character size and the view that is
shown.
The LHMI can be detached from the main unit. The
detached LHMI can be wall mounted up to a distance of
five meters from the main unit. The units are connected
with the Ethernet cable included in the delivery.
The LHMI is simple and easy to understand. The whole
front plate is divided into zones, each with a well-defined
functionality:
Busbar protection REB650
1MRK 505 265-BUS B
Version 1.1 ANSI
ABB Power Grids 15
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• Status indication LEDs
•Alarm indication LEDs which can indicate three states
with the colors green, yellow and red, with user
printable label. All LEDs are configurable from the
PCM600 tool
• Liquid crystal display (LCD)
• Keypad with push buttons for control and navigation
purposes, switch for selection between local and remote
control and reset
• Five user programmable function buttons
• An isolated RJ45 communication port for PCM600
13. Basic IED functions
Self supervision with internal event list M11399-3 v4
The Self supervision with internal event list (INTERRSIG
and SELFSUPEVLST) function reacts to internal system
events generated by the different built-in self-supervision
elements. The internal events are saved in an internal
event list.
Time synchronization GUID-057C610F-C070-4EA6-B2C9-3C49F33B2F7C v3
Use time synchronization to achieve a common time base
for the IEDs in a protection and control system. This
makes comparison of events and disturbance data
between all IEDs in the system possible.
Time-tagging of internal events and disturbances are an
excellent help when evaluating faults. Without time
synchronization, only the events within the IED can be
compared to one another. With time synchronization,
events and disturbances within the entire station, and
even between line ends, can be compared during
evaluation.
In the IED, the internal time can be synchronized from a
number of sources:
• SNTP
• IRIG-B
• DNP
• IEC60870-5-103
Parameter setting groups ACTVGRP M12006-6 v3
Use the four sets of settings to optimize the IED
operation for different system conditions. Creating and
switching between fine-tuned setting sets, either from
the local HMI or configurable binary inputs, results in a
highly adaptable IED that can cope with a variety of
system scenarios.
Test mode functionality TESTMODE M11407-3 v5
The protection and control IEDs may have many included
functions. To make the testing procedure easier, the IEDs
include the feature that allows individual blocking of a
single-, several-, or all functions.
There are two ways of entering the test mode:
• By configuration, activating an input signal of the
function block TESTMODE
• By setting the IED in test mode in the local HMI
While the IED is in test mode, all functions are blocked.
Any function can be unblocked individually regarding
functionality and event signaling. This enables the user to
follow the operation of one or several related functions to
check functionality and to check parts of the
configuration, and so on.
Change lock function CHNGLCK GUID-00784FC0-B39D-462D-854B-AAF62626DD0A v1
Change lock function (CHNGLCK) is used to block further
changes to the IED configuration and settings once the
commissioning is complete. The purpose is to block
inadvertent IED configuration changes beyond a certain
point in time.
Authority status ATHSTAT SEMOD158529-5 v4
Authority status (ATHSTAT) function is an indication
function block for user log-on activity.
Authority check ATHCHCK SEMOD117051-23 v3
To safeguard the interests of our customers, both the IED
and the tools that are accessing the IED are protected, by
means of authorization handling. The authorization
handling of the IED and the PCM600 is implemented at
both access points to the IED:
• local, through the local HMI
• remote, through the communication ports
14. Station communication
IEC 61850-8-1 communication protocol M14787-3 v6
The IED supports the communication protocols IEC
61850-8-1 and DNP3 over TCP/IP. All operational
information and controls are available through these
protocols. However, some communication functionality,
for example, horizontal communication (GOOSE) between
the IEDs, is only enabled by the IEC 61850-8-1
communication protocol.
Busbar protection REB650
1MRK 505 265-BUS B
Version 1.1 ANSI
16 ABB Power Grids
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The IED is equipped with an optical Ethernet rear port for
the substation communication standard IEC 61850-8-1.
IEC 61850-8-1 protocol allows intelligent electrical devices
(IEDs) from different vendors to exchange information
and simplifies system engineering. Peer-to-peer
communication according to GOOSE is part of the
standard. Disturbance files uploading is provided.
Disturbance files are accessed using the IEC 61850-8-1
protocol. Disturbance files are available to any Ethernet
based application via FTP in the standard Comtrade
format. Further, the IED can send and receive binary
values, double point values and measured values (for
example from MMXU functions), together with their
quality, using the IEC 61850-8-1 GOOSE profile. The IED
meets the GOOSE performance requirements for tripping
applications in substations, as defined by the IEC 61850
standard. The IED interoperates with other IEC 61850-
compliant IEDs, tools, and systems and simultaneously
reports events to five different clients on the IEC 61850
station bus.
The event system has a rate limiter to reduce CPU load.
The event channel has a quota of 10 events/second. If the
quota is exceeded the event channel transmission is
blocked until the event changes is below the quota, no
event is lost.
All communication connectors, except for the front port
connector, are placed on integrated communication
modules. The IED is connected to Ethernet-based
communication systems via the fibre-optic multimode LC
connector (100BASE-FX).
The IED supports SNTP and IRIG-B time synchronization
methods with a time-stamping resolution of 1 ms.
• Ethernet based: SNTP and DNP3
• With time synchronization wiring: IRIG-B
The IED supports IEC 60870-5-103 time synchronization
methods with a time stamping resolution of 5 ms.
Table 1. Supported communication interface and protocol
alternatives
Interfaces/
Protocols
Ethernet
100BASE-FX LC
ST connector
IEC 61850-8-1 ●
DNP3 ●
IEC 60870-5-103 ●
● = Supported
Horizontal communication via GOOSE for interlocking
GUID-92ECE152-892C-4214-95DE-B92718689434 v2
GOOSE communication can be used for exchanging
information between IEDs via the IEC 61850-8-1 station
communication bus. This is typically used for sending
apparatus position indications for interlocking or
reservation signals for 1-of-n control. GOOSE can also be
used to exchange any boolean, integer, double point and
analog measured values between IEDs.
DNP3 protocol GUID-54A54716-23BD-4E7C-8245-DE2B4C75E8DC v1
DNP3 (Distributed Network Protocol) is a set of
communications protocols used to communicate data
between components in process automation systems. For
a detailed description of the DNP3 protocol, see the DNP3
Communication protocol manual.
IEC 60870-5-103 communication protocol M11874-3 v3
IEC 60870-5-103 is an unbalanced (master-slave) protocol
for coded-bit serial communication exchanging
information with a control system, and with a data
transfer rate up to 38400 bit/s. In IEC terminology, a
primary station is a master and a secondary station is a
slave. The communication is based on a point-to-point
principle. The master must have software that can
interpret IEC 60870-5-103 communication messages.
15. Hardware description
Layout and dimensions IP14539-1 v1
Mounting alternatives
M16079-3 v6
The following mounting alternatives are available (IP40
protection from the front):
• 19” rack mounting kit
• Wall mounting kit
• Flush mounting kit
• 19" dual rack mounting kit
See ordering for details about available mounting
alternatives.
Busbar protection REB650
1MRK 505 265-BUS B
Version 1.1 ANSI
ABB Power Grids 17
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Flush mounting the IED
GUID-C8BEC79C-FF1B-4FEA-936E-EB19877D6CF8 v1
H
I
K
J
C
F
G
B
A
E
D
IEC09000672.ai
IEC09000672 V1 EN-US
Figure 3. Flush mounting the IED into a panel cut-out
A 240 mm G 21.55 mm
B 21.55 mm H 220 mm
C 227 mm I 265.9 mm
D 228.9 mm J 300 mm
E 272 mm K 254 mm
F∅6 mm
A
B
C
IEC09000673.ai
IEC09000673 V1 EN-US
Figure 4. Flush mounted IED
A 222 mm
B 27 mm
C 13 mm
Rack mounting the IED
GUID-A12870EB-5DA7-4B3B-9AED-B2D9F259B6B3 v1
A
C
B
E
D
IEC09000676.ai
IEC09000676 V1 EN-US
Figure 5. Rack mounted IED
A 224 mm + 12 mm with ring-lug connector
B 25.5 mm
C 482.6 mm (19")
D 265.9 mm (6U)
E 13 mm
A
B
C
E
D
IEC09000677.ai
IEC09000677 V1 EN-US
Figure 6. Two rack mounted IEDs side by side
A 224 mm + 12 mm with ring-lug connector
B 25.5 mm
C 482.6 mm (19")
D 13 mm
E 265.9 mm (6U)
Busbar protection REB650
1MRK 505 265-BUS B
Version 1.1 ANSI
18 ABB Power Grids
© Copyright 2011 ABB Power Grids. All rights reserved

Wall mounting the IED
GUID-5EE62F6C-F0F4-4C01-897A-DF27BCDE07BF v2
C
F
G
B
A
E
D
IEC09000678.ai
IEC09000678 V1 EN-US
Figure 7. Wall mounting the IED
A 270 mm E 190.5 mm
B 252.5 mm F 296 mm
C∅6.8 mm G 13 mm
D 268.9 mm
GUID-5C185EAC-13D0-40BD-8511-58CA53EFF7DE V1 EN-US
Figure 8. Main unit and detached LHMI display
A 25.5 mm E 258.6 mm
B 220 mm F 265.9 mm
C 13 mm G 224 mm
D 265.9 mm
16. Connection diagrams GUID-72A67452-D1F2-44C9-9172-05160EDFEC5D v2.2.1
The connection diagrams are delivered on the IED
Connectivity package DVD as part of the product delivery.
The latest versions of the connection diagrams can be
downloaded from
http://www.abb.com/substationautomation.
Connection diagrams for Configured products
Connection diagram, REB650 1.1, (HiZ/3Ph) A03A
1MRK006502-MB
Busbar protection REB650
1MRK 505 265-BUS B
Version 1.1 ANSI
ABB Power Grids 19
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17. Technical data
General IP11376-1 v2M10993-1 v3
Definitions
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 the
specified requirements
Operative range The range of values of a given energizing quantity for which the equipment, under specified conditions, is able to perform
its intended functions according to the specified requirements
Energizing quantities, rated values and limits IP15765-1 v2
Analog inputs
GUID-80AA04F6-C989-4E8A-81C0-1A9A7458ADCC v5
Table 2. Energizing inputs
Description Value
Rated frequency 50/60 Hz
Operating range Rated frequency ± 5 Hz
Current inputs Rated current, In0.1/0.5 A1) 1/5 A2)
Thermal withstand capability:
•Continuously 4 A 20 A
• For 1 s 100 A 500 A
• For 10 s 20 A 100 A
Dynamic current withstand:
• Half-wave value 250 A 1250 A
Input impedance <100 mΩ <20 mΩ
Voltage inputs Rated voltage, Vn100 V AC/ 110 V AC/ 115 V AC/ 120 V AC
Voltage withstand:
• Continuous 420 V rms
• For 10 s 450 V rms
Burden at rated voltage <0.05 VA
1) Residual current
2) Phase currents or residual current
Busbar protection REB650
1MRK 505 265-BUS B
Version 1.1 ANSI
20 ABB Power Grids
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