ABB REF 610 Product manual
REF 610
Feeder Protection Relay
Technical Reference Manual
Feeder Protection Relay
Technical Reference Manual
REF 610
Issued: 05.10.2004
Version: A/05.10.2004
©Copyright 2004 ABB Oy, Distribution Automation, Vaasa, FINLAND 3
Contents
1. Introduction ...............................................................................6
1.1. About this manual .........................................................................6
1.2. The use of the relay ......................................................................6
1.3. Features ........................................................................................6
1.4. Guarantee .....................................................................................8
2. Safety information .....................................................................9
3. Instructions ..............................................................................10
3.1. Application ...................................................................................10
3.2. Requirements ..............................................................................10
3.3. Configuration ...............................................................................10
4. Technical description .............................................................13
4.1. Functional description .................................................................13
4.1.1. Product functions .............................................................13
4.1.1.1. Protection functions ............................................13
4.1.1.2. Inputs .................................................................13
4.1.1.3. Outputs ...............................................................14
4.1.1.4. Disturbance recorder ..........................................14
4.1.1.5. HMI .....................................................................14
4.1.1.6. Non-volatile memory ..........................................14
4.1.1.7. Self-supervision ..................................................14
4.1.1.8. Time synchronization .........................................15
4.1.2. Measurements .................................................................16
4.1.3. Configuration ....................................................................16
4.1.4. Protection .........................................................................18
4.1.4.1. Block diagram ....................................................18
4.1.4.2. Overcurrent protection .......................................19
4.1.4.3. Earth-fault protection ..........................................20
4.1.4.4. Thermal protection for cables .............................21
4.1.4.5. Phase discontinuity protection ...........................26
4.1.4.6. Circuit-breaker failure protection ........................26
4.1.4.7. Arc protection .....................................................26
4.1.4.8. Auto-reclose function .........................................28
4.1.4.9. Inverse definite minimum time characteristics ...34
4.1.4.10.Settings ..............................................................46
4.1.4.11.Technical data on protection functions ..............58
4.1.5. Trip-circuit supervision .....................................................62
4.1.6. Trip lockout function .........................................................63
4.1.7. Trip counters for circuit-breaker condition monitoring ......64
1MRS 755310
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1MRS 755310
Feeder Protection Relay
Technical Reference Manual
REF 610
4.1.8. Indicator LEDs and operation indication messages .........64
4.1.9. Demand values ................................................................64
4.1.10.Commissioning tests ........................................................65
4.1.11.Disturbance recorder .......................................................65
4.1.11.1.Function .............................................................65
4.1.11.2.Disturbance recorder data .................................65
4.1.11.3.Control and indication of disturbance recorder
status .................................................................66
4.1.11.4.Triggering ..........................................................67
4.1.11.5.Settings and unloading ......................................67
4.1.11.6.Event code of the disturbance recorder .............67
4.1.12.Recorded data of the last events .....................................67
4.1.13.Communication ports .......................................................69
4.1.14.IEC 60870-5-103 remote communication protocol ..........70
4.1.15.Modbus remote communication protocol .........................74
4.1.15.1.Protocol overview ..............................................74
4.1.15.2.Profile of Modbus REF 610 ...............................75
4.1.16.DNP 3.0 remote communication protocol ........................88
4.1.16.1.Protocol overview ..............................................88
4.1.16.2.Protocol parameters of REF 610 .......................88
4.1.16.3.DNP 3.0 point list of REF 610 ............................88
4.1.16.4.DNP 3.0 device profile of REF 610 ....................92
4.1.16.5.REF 610-specific DNP features .........................99
4.1.17.SPA bus communication protocol parameters ...............102
4.1.17.1.Event codes .....................................................117
4.1.18.Self-supervision (IRF) system ........................................121
4.1.19.Relay parameterization ..................................................123
4.2. Design description ....................................................................123
4.2.1. Input/output connections ...............................................123
4.2.2. Light sensor input connections ......................................128
4.2.3. Serial communication connections ................................128
4.2.4. Technical data ...............................................................133
5. Application examples .......................................................... 138
5.1. Auto-reclose function ................................................................138
5.1.1. Fast tripping and initiation of shot 1 using two
protection stages ...........................................................138
5.1.2. Fast tripping and initiation of shot 1 using start signals .139
5.1.3. Selecting adaptive sequence length ..............................140
5.2. Arc protection ............................................................................141
5.2.1. Arc protection with one REF 610 relay ..........................141
5.2.2. Arc protection with several REF 610 relays ...................142
5.2.3. Arc protection with several REF 610 relays and one
REA 101 .........................................................................143
1MRS 755310 Feeder Protection Relay
Technical Reference Manual
REF 610
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6. Ordering information ............................................................144
7. References .............................................................................146
8. Abbreviations ........................................................................147
9. Check lists .............................................................................149
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1MRS 755310
Feeder Protection Relay
Technical Reference Manual
REF 610
1. Introduction
1.1. About this manual
This manual provides thorough information on the protection relay REF 610 and its
applications, focusing on giving a technical description of the relay.
Refer to the Operator’s Manual for instructions on how to use the
Human-Machine Interface (HMI) of the relay, also known as the Man-Machine
Interface (MMI), and to the Installation Manual for installation of the relay.
1.2. The use of the relay
The feeder protection relay REF 610 is a versatile multifunction protection relay
mainly designed to protect incoming and outgoing feeders in a wide range of feeder
applications.
REF 610 is based on a microprocessor environment. A self-supervision system
continuously monitors the operation of the relay.
The HMI includes a Liquid Crystal Display (LCD) which makes the local use of the
relay safe and easy.
Local control of the relay via serial communication can be carried out with a
computer connected to the front communication port. Remote control can be carried
out via the rear connector connected to the control and monitoring system through
the serial communication bus.
1.3. Features
• Three-phase non-directional overcurrent protection with definite-time or IDMT
characteristic, low-set stage
• Three-phase non-directional overcurrent protection, high-set stage
• Three-phase non-directional overcurrent protection, instantaneous stage
• Non-directional earth-fault protection with definite-time or IDMT characteristic,
low-set stage
• Non-directional earth-fault protection, high-set stage
• Phase discontinuity protection
• Three-phase thermal overload protection for cables
• Arc protection
• two lens sensors for arc detection (optional)
• automatic reference level adjustment based on backlight intensity
• arc detection via a remote light signal
• Automatic reclosing 1...3 shots
• Circuit-breaker failure protection
• Trip counters for circuit-breaker condition monitoring
• Trip-circuit supervision with possibility to route the warning signal to a signal
output
• Trip lockout function
1MRS 755310 Feeder Protection Relay
Technical Reference Manual
REF 610
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• Four accurate current inputs
• User-selectable rated frequency 50/60 Hz
• Three normally open power output contacts
• Two change-over signal output contacts and three additional change-over signal
output contacts on the optional I/O module
• Output contact functions freely configurable for desired operation
• Two galvanically isolated digital inputs and three additional galvanically isolated
digital inputs on the optional I/O module
• Disturbance recorder
• recording time up to 80 seconds
• triggering by one or several internal or digital input signals
• records four analogue channels and up to eight user-selectable digital channels
• adjustable sampling rate
• Non-volatile memory for
• up to 100 event codes with time stamp
• setting values
• disturbance recorder data
• recorded data of the five last events with time stamp
• number of AR shots and starts/trips for protection stages
• operation indication messages and LEDs showing the status at the moment of
power failure
• HMI with an alphanumeric LCD and manoeuvring buttons
• eight programmable LEDs
• Operation indication messages displayed in either the IEC or ANSI mode
• Multi-language support
• User-selectable password protection for the HMI
• Display of primary current values
• Demand values
• All settings can be modified with a PC
• Optical front communication connection: wirelessly or via cable
• Optional rear communication module with plastic fibre-optic, combined
fibre-optic (plastic and glass) or RS-485 connection for system communication
using the SPA-bus, IEC 60870-5-103 or Modbus (RTU and ASCII)
communication protocol
• Optional DNP 3.0 rear communication module with RS-485 connection for
system communication using the DNP 3.0 communication protocol.
• Battery back-up for real-time clock
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1MRS 755310
Feeder Protection Relay
Technical Reference Manual
REF 610
• Battery charge supervision
• Continuous self-supervision of electronics and software.
• Detachable plug-in unit
1.4. Guarantee
Please inquire about the terms of guarantee from your nearest ABB representative.
1MRS 755310 Feeder Protection Relay
Technical Reference Manual
REF 610
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2. Safety information
Dangerous voltages can occur on the connectors, even though the
auxiliary voltage has been disconnected.
National and local electrical safety regulations must always be
followed.
The device contains components which are sensitive to electrostatic
discharge. Unnecessary touching of electronic components must
therefore be avoided.
The frame of the device has to be carefully earthed.
Only a competent electrician is allowed to carry out the electrical
installation.
Non-observance can result in death, personal injury or substantial
property damage.
Breaking the sealing tape on the upper handle of the device will result
in loss of warranty and proper operation will no longer be guaranteed.
When the plug-in unit has been detached from the case, do not touch
the inside of the case. The relay case internals may contain high voltage
potential and touching these may cause personal injury.
!
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1MRS 755310
Feeder Protection Relay
Technical Reference Manual
REF 610
3. Instructions
3.1. Application
REF 610 is a versatile multifunction protection relay mainly designed for protection
of incoming and outgoing feeders in MV distribution substations. REF 610 can also
be used as back-up protection for motors, transformers and generators, in industrial
as well as in utility applications.
The large number of integrated protection functions, including three-stage
overcurrent protection, two-stage, non-directional earth-fault protection as well as
thermal protection, makes REF 610 a complete protection against overcurrent and
earth faults.
The optional arc protection for detection of arc situations in air insulated metal-clad
switchgears and the auto-reclose function for automatic clearing of overhead line
faults increase the range of applications further.
The large number of digital inputs and output contacts allows a wide range of
applications.
3.2. Requirements
To secure correct and safe operation of the relay, preventive maintenance is
recommended to be performed every five years when REF 610 is operating under
the specified conditions; see below and section Technical data.
When being used for real-time clock or recorded data functions, the battery should
be changed every five years.
Environmental conditions
3.3. Configuration
Setting and connection examples
The appropriate configuration of the output contact matrix enables the use of the
signals from the protection stages as contact functions. The start signals can be used
for blocking co-operating protection relays and signalling.
Fig. 3.3.-1 and Fig. 3.3.-2 represent REF 610 with the default configuration: all trip
signals are routed to trip the circuit breaker. In Fig. 3.3.-1, the residual current is
measured via a core-balance current transformer and the output contacts are
connected to enable the use of the auto-reclose function. In Fig. 3.3.-2, the residual
current is measured via a summation connection of the phase current transformers
and the output contacts are connected to enable the use of the trip lockout function.
• Recommended temperature range (continuous) -10...+55°C
• Limit temperature range (short-term) -40...+70°C
• Temperature influence on the operation accuracy of the
protection relay within the specified service temperature range 0.1%/°C
• Transport and storage temperature range -40...+85°C
1MRS 755310 Feeder Protection Relay
Technical Reference Manual
REF 610
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Fig. 3.3.-1 Connection diagram, example 1
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SGB4 SGB3
SGB2
SGB1
SGB5
X3.1 6 5 4 3 2 1 X4.1
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16
17
SGR4 SGR3 SGR2 SGR1
SGR5
SO1 PO2
SO2
IRF
3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19
21 22 23 24
θ>
I>
I>>
I>>>
IRF
I0>
I0>>
∆I>
13
14
SGR7
SGR8
SO4
SO5
SGR6
SO3
X3.1
16 17 18 19 20 21 22 23 24
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0→1
CBFP
0
1
O
I
-
-
+
X2.1 7 8 1 2 3 4 5 6
L1
L2
L3
+
+
PO3 PO1
+
1 2
~
U
aux
+
--
~
Co Diagr1REF610_a
X5.1
X5.2
SGF1...SGF5
SGL1...SGL8
DI3
DI2
DI1
DI4
DI5
Optio al
Start
Trip
Blocki g
Start
Trip
Blocki g
Arc light output
Trip
I dicatio s cleared
Output co tacts u latched
Memorized values cleared
Setti g group selectio
Time sy c
Exter al Trip
Exter al trip
Start
Trip
Blocki g
Blocki g
Start
Trip
Start
Trip
Blocki g
Start
Trip
Alarm
Trip
Exter al Arc
Arc I>/I0>
CB Positio Ope
CB Positio Closed
AR I hibit
CB Close I hibit
Exter al AR I itiatio
Ope CB Comma d
Close CB Comma d
CB Reclosi g Failed
Shot Due
Defi ite Trip Alarm
AR Lockout
Exter al Triggeri g
Reset
Trip lockout
Optio al
Exter al Triggeri g Trip
War i g
Light se sor 1
Light se sor 2
Trip lockout
Optio al
Self-supervisio
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1MRS 755310
Feeder Protection Relay
Technical Reference Manual
REF 610
Fig. 3.3.-2 Connection diagram, example 2
2
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SGB4 SGB3
SGB2
SGB1
SGB5
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SGR4 SGR3 SGR2 SGR1
SGR5
θ>
I>
I>>
I>>>
IRF
I0>
I0>>
∆I>
13
14
SGR7
SGR8 SGR6
10
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0→1
CBFP
~
Co Diagr2REF610_a
X5.1
X5.2
X3.1 6 5 4 3 2 1 X4.1
SO1 PO2
SO2
IRF
3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19
21 22 23 24
SO4
SO5 SO3
X3.1
16 17 18 19 20 21 22 23 24
0
1
O
I
-
-
+
X2.1 7 8 1 2 3 4 5 6
L1
L2
L3
+
PO3 PO1
+
1 2
U
aux
~
SGF1...SGF5
SGL1...SGL8
DI3
DI2
DI1
DI4
DI5
Optio al
Start
Trip
Blocki g
Start
Trip
Blocki g
Arc light output
Trip
I dicatio s cleared
Output co tacts u latched
Memorized values cleared
Setti g group selectio
Time sy c
Exter al Trip
Exter al trip
Start
Trip
Blocki g
Blocki g
Start
Trip
Start
Trip
Blocki g
Start
Trip
Alarm
Trip
Exter al Arc
Arc I>/I0>
CB Positio Ope
CB Positio Closed
AR I hibit
CB Close I hibit
Exter al AR I itiatio
Ope CB Comma d
Close CB Comma d
CB Reclosi g Failed
Shot Due
Defi ite Trip Alarm
AR Lockout
Exter al Triggeri g
Reset
Trip lockout
Optio al
Exter al Triggeri g Trip
War i g
Light se sor 1
Light se sor 2
Trip lockout
Optio al
Self-supervisio
1MRS 755310 Feeder Protection Relay
Technical Reference Manual
REF 610
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4. Technical description
4.1. Functional description
4.1.1. Product functions
4.1.1.1. Protection functions
The protection functions of REF 610 with their IEC symbols and IEEE device
numbers are presented in the table below:
For descriptions of the protection functions, refer to sections:
• 4.1.4.2. Overcurrent protection
• 4.1.4.3. Earth-fault protection
• 4.1.4.4. Thermal protection for cables
• 4.1.4.5. Phase discontinuity protection
• 4.1.4.6. Circuit-breaker failure protection
• 4.1.4.7. Arc protection
• 4.1.4.8. Auto-reclose function
4.1.1.2. Inputs
REF 610 is provided with four energizing inputs, two optional light sensor inputs,
two digital inputs and three optional digital inputs controlled by an external voltage.
Three of the energizing inputs are for the phase currents and one for the earth-fault
current. For details, refer to section Input/output connections and tables 4.1.4.10-7,
4.2.1-1 and 4.2.1-5. The functions of the digital inputs are determined with the
SGB switches.
Table 4.1.1.1-1 IEC symbols and IEEE device numbers
Function description IEC symbol IEEE Device
No.
Three-phase non-directional overcurrent protection,
low-set stage I> 51
Three-phase non-directional overcurrent protection,
high-set stage I>> 50/51
Three-phase non-directional overcurrent protection,
instantaneous stage I>>> 50
Phase discontinuity protection ∆I> 46
Three-phase thermal overload protection for cables θ>49
Non-directional earth-fault protection, low-set stage I0> 51N
Non-directional earth-fault protection, high-set stage I0>> 50N/51N
Arc protection ARC 50/50NL
Circuit-breaker failure protection CBFP 62BF
Automatic reclosing 0→179
Lockout relay 86
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1MRS 755310
Feeder Protection Relay
Technical Reference Manual
REF 610
4.1.1.3. Outputs
REF 610 is provided with three power outputs (PO1, PO2 and PO3), two signal
outputs (SO1 and SO2) and three optional signal outputs (SO3, SO4 and SO5).
Switchgroups SGR1...8 are used for routing internal signals from the protection
stages, the external trip signal and signals from the auto-reclose function to the
desired signal or power output. The minimum pulse length can be configured to be
40 or 80 ms and the power outputs can all be configured to be latched.
4.1.1.4. Disturbance recorder
REF 610 includes an internal disturbance recorder which records the momentary
measured values, or the RMS curves of the measured signals, and up to eight
user-selectable digital signals: the digital input signals and the internal signals from
the protection stages. Any digital signal can be set to trigger the recorder on either
the falling or rising edge.
4.1.1.5. HMI
The HMI of REF 610 is equipped with six push-buttons, an alphanumeric
2x16 characters’ LCD, eight programmable indicator LEDs, three indicator LEDs
with fixed functionality, and an indicator LED for front communication. The
push-buttons are used for navigating in the menu structure and for adjusting setting
values.
An HMI password can be set to protect all user-changeable values from being
changed by an unauthorized person. The HMI password will remain inactive and
will thus not be required for altering parameter values until the default HMI
password has been replaced. Entering the HMI password successfully can be
selected to generate an event code. This feature can be used to indicate interaction
activities via the local HMI. For further information on the HMI, refer to the
Operator’s Manual.
4.1.1.6. Non-volatile memory
REF 610 can be configured to store various data in a non-volatile memory, which
will retain its data also in case of loss of auxiliary voltage (provided that the battery
has been inserted and is charged). Operation indication messages and LEDs,
disturbance recorder data, event codes and recorded data can all be configured to be
stored in the non-volatile memory whereas setting values will always be stored in
the EEPROM.
4.1.1.7. Self-supervision
The self-supervision system of REF 610 manages run-time fault situations and
informs the user about an existing fault. There are two types of fault indications:
internal relay fault (IRF) indications and warnings.
When the self-supervision system detects a permanent internal relay fault, which
will prevent relay operation, the green indicator LED (ready) will start to blink. At
the same time, the IRF contact, which is normally picked up, will drop off and a fault
code will appear on the LCD. The fault code is numerical and identifies the fault
type.
1MRS 755310 Feeder Protection Relay
Technical Reference Manual
REF 610
15
Fig. 4.1.1.7.-1 Permanent IRF
In case of a warning, the relay will continue to operate with full or reduced
functionality and the green indicator LED (ready) will remain lit as during normal
operation. A fault indication message (see Fig. 4.1.1.7.-2), with a possible fault code
(see Fig. 4.1.1.7.-3), will appear on the LCD indicating the type of fault. In case of
a warning due to an external fault in the trip circuit detected by the trip-circuit
supervision, or due to continuous light on the light sensor inputs, SO2 will be
activated (if SGF1/8=1).
Fig. 4.1.1.7.-2 Warning with text message
Fig. 4.1.1.7.-3 Warning with numeric code
For fault codes, refer to section Self-supervision (IRF) system.
4.1.1.8. Time synchronization
Time synchronization of the relay’s real-time clock can be realized in two different
ways: via serial communication using a communication protocol or via a digital
input.
Any digital input can be configured for time synchronization and used for either
minute-pulse or second-pulse synchronization. The synchronization pulse is
automatically selected and depends on the time range within which the pulse occurs.
The time must be set once, either via serial communication or manually via the HMI.
If the synchronization pulse differs more than +/- 0.05 seconds for second-pulse or
+/- 2 seconds for minute-pulse synchronization from the relay’s real-time clock, the
synchronization pulse will be rejected.
IntFault_a
INTERNAL FAULT
FAULT CODE :30
Warning_a
WARNING
BATTERY LOW
WarnREF6 0_a
WARNING
FAULT CODE: 33
16
1MRS 755310
Feeder Protection Relay
Technical Reference Manual
REF 610
Time synchronization is always triggered on the rising edge of the digital input
signal. The time is adjusted in steps of five milliseconds per synchronization pulse.
The typical accuracy achievable with time synchronization via a digital input is
+2.5...-2.5 milliseconds for second-pulse and +5...-5 milliseconds for minute-pulse
synchronization.
Note!
The pulse length of the digital input signal does not affect time synchronization.
4.1.2. Measurements
The table below presents the measured values which can be accessed through the
HMI:
4.1.3. Configuration
Fig. 4.1.3.-1 illustrates how the internal and digital input signals can be configured
to obtain the required protection functionality.
Table 4.1.2-1 Measured values
Indicator Description
L1 Current measured on phase IL1
L2 Current measured on phase IL2
L3 Current measured on phase IL3
I0Measured earth-fault current
∆I Calculated phase unbalance
θCalculated thermal level
I1_min One-minute demand value
In_min Demand value during the specified time range
Max I Maximum one-minute demand value during
the specified time range
1MRS 755310 Feeder Protection Relay
Technical Reference Manual
REF 610
17
Fig. 4.1.3.-1 Signal diagram
2
3
4
5
6
1
10
11
12
13
14
15
SGB4 SGB3
SGB2
SGB1
SGB5
X3.1 6 5 4 3 2 1 X4.1
1
2
3
4
5
6
7
8
9
11
12
16
17
SGR4 SGR3 SGR2 SGR1
SGR5
SO1 PO2
SO2
IRF
3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19
21 22 23 24
θ>
I>
I>>
I>>>
IRF
I0>
I0>>
∆I>
13
14
SGR7
SGR8
SO4
SO5
SGR6
SO3
X3.1
16 17 18 19 20 21 22 23 24
10
15
18
19
20
21
22
23
1
2
3
4
5
6
7
8
9
11
12
16
17
13
14
10
15
18
19
20
21
22
23
1
2
3
4
5
6
7
8
9
11
12
16
17
13
14
10
15
18
19
20
21
22
23
1
2
3
4
5
6
7
8
9
11
12
16
17
13
14
10
15
18
19
20
21
22
23
1
2
3
4
5
6
7
8
9
11
12
16
17
13
14
10
15
18
19
20
21
22
23
1
2
3
4
5
6
7
8
9
11
12
16
17
13
14
10
15
18
19
20
21
22
23
1
2
3
4
5
6
7
8
9
11
12
16
17
13
14
10
15
18
19
20
21
22
23
1
2
3
4
5
6
7
8
9
11
12
16
17
13
14
10
15
18
19
20
21
22
23
9
18
19
16
17
20
8
7
2
3
4
5
6
1
10
11
12
13
14
15
9
18
19
16
17
20
8
7
2
3
4
5
6
1
10
11
12
13
14
15
9
18
19
16
17
20
8
7
2
3
4
5
6
1
10
11
12
13
14
15
9
18
19
16
17
20
8
7
2
3
4
5
6
1
10
11
12
13
14
15
9
18
19
16
17
20
8
7
0→1
CBFP
PO3 PO1
1 2
~
Sig DiagrREF610_a
X5.1
X5.2
IL1
IL2
IL3
Io
SGF1...SGF5
SGL1...SGL8
DI3
DI2 DI1
DI4
DI5
Optio al
Start
Trip
Blocki g
Start
Trip
Blocki g
Arc light output
Trip
I dicatio s cleared
Output co tacts u latched
Memorized values cleared
Setti g group selectio
Time sy c
Exter al Trip
Exter al trip
Start
Trip
Blocki g
Blocki g
Start
Trip
Start
Trip
Blocki g
Start
Trip
Alarm
Trip
Exter al Arc
Arc I>/I0>
CB Positio Ope
CB Positio Closed
AR I hibit
CB Close I hibit
Exter al AR I itiatio
Ope CB Comma d
Close CB Comma d
CB Reclosi g Failed
Shot Due
Defi ite Trip Alarm
AR Lockout
Exter al Triggeri g
Reset
Trip lockout
Optio al
Exter al Triggeri g Trip
War i g
Light se sor 1
Light se sor 2
Trip lockout
Optio al
Self-supervisio
18
1MRS 755310
Feeder Protection Relay
Technical Reference Manual
REF 610
The functions of the relay are selected with the switches of switchgroups SGF, SGB,
SGR and SGL. The checksums of the switchgroups are found under SETTINGS in
the HMI menu. The functions of the switches are explained in detail in the
corresponding SG_ tables.
4.1.4. Protection
4.1.4.1. Block diagram
Fig. 4.1.4.1.-1 Block diagram
LED1
LED2
LED3
LED4
LED5
LED6
LED7
LED8
I
L1
I
L2
I
L3
PO1
PO2
PO3
SO1
SO2
SO3
SO4
SO5
IRF
SGB1...5
SGR1...5
I
0
SGL1...8
SGF1...SGF5
BlockDiagrREF610_a
I
L 1
I
L 2
I
L 3
I
0
θ>
CBFP
IL1
IL2
IL3
I
Io
Io
I>>> ∆I>
Start
Trip
I>>
I>
Io>>
Io>
Arc I>, Arc I0>
Programmable
LEDs
Disturbance recorder
(4 analogue + up to 8 digital channels)
Digital outputs
(Output contacts)
IRF INDICATION
START/ALARM INDICATION
TRIP INDICATION
IRF indication LED (green)
Start/Alarm (yellow) and
trip (red) indication LEDs
I> Start
I> Trip
I>> Start
I>> Trip
I>>> Start
I>>> Trip
I0> Start
I0> Trip
I0>> Start
I0>> Trip
∆I> Start
∆I> Trip
θ> Alarm
θ> Trip
Ext Trip
Open CB Cmd
Close CB Cmd
Definite Trip Alarm
CB Reclose Failled
Shot Due
AR Lockout
Arc Trip
Arc light output
The dashed line indicates optional functionality.
1) Clear indications by the digital input signal
2) Clear indications and unlatch output contacts by the
digital input signal
3) Reset indications and memorized values;unlatch output
contacts by the digital input signal
Optional digital
inputs
(I/O module)
Digital inputs DI1
DI2
DI3
DI4
DI5
Switchgroups for
digital inputs Protection relay functions
Analogue inputs
Switchgroups for
programmable LEDs
Switchgroups for
output contacts
I> Start
I> Trip
I>> Start
I>> Trip
I>>> Start
I>>> Trip
I0> Start
I0> Trip
I0>> Start
I0>> Trip
∆I> Start
∆I> Trip
θ> Alarm
θ> Trip
Trip lockout
I> Trip
I>> Trip
I>>> Trip
I0> Trip
I0>> Trip
∆I> Trip
Θ> Alarm
Θ> Trip
Trip lockout
Defi ite Trip Alarm
Shot Due
AR Lockout
CB Pos Ope
CB Pos Closed
DI1
DI2
DI3
DI4
DI5
Arc Trip
Arc light output
Reset 1 1)
Reset 2 2)
Reset 3 3)
Setti g group
Time sy c
Ext Trip
Ext Trig CBFP
Ext Trig Trip lockout
Ext Arc
Trip lockout reset
Block I>
Block I>>
Block I0>
Block I0>>
Block ∆I>
AR I hibit
CB Close I hibit
CB Pos Ope
CB Pos Closed
Ext AR I itiatio
DI1
DI2
DI3
DI4
DI5
Start
Alarm
Trip
Start
Trip
PO1
EXT TRIG PO2
Block
Start
Trip
Double
Block
Block
Start
Trip
Double
Block
Start
Trip
Block
Start
Trip
0→1, AR
Autoreclose
CB Pos Ope
CB Pos Closed
AR I hibit
CB Close I hibit
Ext AR I itiatio
I> Start
I> Trip
I>> Trip
I>>> Trip
Io> Start
Io> Trip
Io>> Trip
∆I> Trip
Θ> Alarm
Θ> Trip
Arc Trip
CBFP
Ope CB Cmd
Close CB Cmd
CB Reclose Failed
Shot Due
Defi ite Trip Alarm
AR Lockout
Block I>
Block I>>
Block I>>>
Block Io>
Block Io>>
Trip lockout
Trip lockout
Ext Trig
Reset
PO3
Light output
Trip
Light1
Light2
Ext Arc
Light se sor i put1
Light se sor i put2
Optio al arc detector i puts
(Commu icatio module) Optio al digital
outputs
(I/O module)
Warning
1MRS 755310 Feeder Protection Relay
Technical Reference Manual
REF 610
19
4.1.4.2. Overcurrent protection
The non-directional overcurrent protection detects overcurrent caused by
phase-to-phase and phase-to-earth short circuits.
When one or several phase currents exceed the set start value of the low-set stage,
I>, the stage will generate a start signal after a ~ 55 ms’ start time. When the set
operate time at definite-time characteristic or the calculated operate time at IDMT
characteristic elapses, the stage will generate a trip signal.
Stage I> has a settable resetting time (both at definite-time and IDMT
characteristics), tr, for reset coordination with existing electromechanical relays or
for reducing fault clearance timesof recurring, transient faults. If stage I> has started
and the phase currents fall below the set start value of the stage, the start of the stage
will remain active for the set resetting time. If the phase currents exceed the set start
value again, while the timer is being reset, the start of the stage will remain active.
Consequently, the set resetting time ensures that when the stage starts because of
current spikes, it will not be immediately reset. However, if stage I> has already
tripped, the stage will be reset in 50 ms after all three phase currents have fallen
below 0.5 times the set start value of the stage.
The inverse-time function of stage I> can be set to be inhibited when stage I>> and/
or I>>> starts. In this case, the operate time will be determined by stage I>> and/or
I>>>. The selection is made in SGF4.
It is possible to block the tripping of the low-set overcurrent stage by applying a
digital input signal to the relay.
When one or several phase currents exceed the set start value of the high-set stage,
I>>, the stage will generate a start signal after a ~ 30 ms’ start time. When the set
operate time at definite-time characteristic elapses, the stage will generate a trip
signal. Stage I>> can be given an instantaneous characteristic by setting the operate
time to the minimum, i.e. 0.04 s.
The set start value of stage I>> can be set to be automatically doubled in a start
situation, i.e. when the object to be protected is being connected to a network.
Consequently, a set start value below the connection inrush current level can be
selected for stage I>>. A start situation is defined as a situation where the maximum
phase current rises from a value below 0.12 x I> to a value above 1.5 x I> within less
than 60 ms. The start situation ends when all phase currents fall below 1.25 x I> and
remain below for at least 200 ms. The selection is made in SGF4.
It is possible to block the tripping of the high-set overcurrent stage by applying a
digital input signal to the relay.
Stage I>> can be set out of operation in SGF3. This state will be indicated by dashes
on the LCD and by “999” when the set start value is read via serial communication.
When one or several phase currents exceed the set start value of the instantaneous
stage, I>>>, the stage will generate a start signal after a ~ 30 ms’ start time. When
the set operate time at definite-time characteristic elapses, the stage will generate a
trip signal. Stage I>>> can be given an instantaneous characteristic by setting the
operate time to the minimum, i.e. 0.04 s.
20
1MRS 755310
Feeder Protection Relay
Technical Reference Manual
REF 610
Stage I>>> can be set out of operation in SGF3. This state will be indicated by
dashes on the LCD and by “999” when the set start value is read via serial
communication.
Stages I>> and I>>> will be reset in 50 ms after all three phase currents have fallen
below the set start value of the stage.
Note!
Stages I> and I>> can be set to be blocked by the auto-reclose function.
4.1.4.3. Earth-fault protection
The non-directional earth-fault current protection detects phase-to-earth currents,
caused by insulation failure due to ageing and thermal cycling, for instance.
When the earth-fault current exceeds the set start value of the low-set stage, I0>, the
stage will generate a start signalafter a ~ 60 ms’ start time. When thesetoperatetime
at definite-time characteristic or the calculated operate time at IDMT characteristic
elapses, the stage will generate a trip signal. The low-set stage can be given an
instantaneous characteristic by setting the operate time to the minimum, i.e. 0.05 s.
Stage I0> has a settable resetting time (both at definite-time and IDMT
characteristics), tr0, for reset coordination with existing electromechanical relays or
for reducing fault clearance times of recurring, transient faults. If stage I0> has
started and the earth-fault current falls below the set start value of the stage, the start
of the stage will remain active for the set resetting time. If the earth-fault current
exceeds the set start value again, while the timer is being reset, the start of the stage
will remain active. Consequently, the set resetting time ensures that when the stage
starts because of current spikes, it will not be immediately reset. However, if stage
I0> has already tripped, the stage will be reset in 50 ms after the earth-fault current
has fallen below 0.5 times the set start value of the stage.
The inverse-time function of stage I0> can be set to be inhibited when stage I0>>
starts. In this case, the operate time will be determined by stage I0>>. The selection
is made in SGF4.
When the earth-fault current exceeds the set start value of the high-set stage, I0>>,
the stage will generate a start signal after a ~ 40 ms’ start time. When the set operate
time at definite-time characteristic elapses, the stage will generate a trip signal. The
high-set stage can be given an instantaneous characteristic by setting the operate
time to the minimum, i.e. 0.04 s. The stage willbe reset in 50 ms after the earth-fault
current has fallen below the set start value of the stage.
The set start value of stage I0>> can be set to be automatically doubled in a start
situation, i.e. when the object to be protected is being connected to a network.
Consequently, a set start value below the connection inrush current level can be
selected for the stage. A start situation is defined as a situation where the earth-fault
current rises from a value below 0.12 x I0> to a value above 1.5 x I0> within less
than 60 ms. The start situation ends when the current falls below 1.25 x I0> and
remain below for at least 200 ms. The selection is made in SGF4.
StageI0>> canbe set out of operation in SGF3.This state will be indicated by dashes
on the LCD and by “999” when the set start value is read via serial communication.
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