AQ-F255
Feeder protection IED
Data sheet
AQ -F255
Data sheet
Version: 1.00
Table of contents
1A
AQ
Q-200 Bene
Benefits
fits .......................................................................................................................... 4
2A
AQ
Q-200 Inno
Innovvations ..................................................................................................................... 5
2.1 Ultra-accurate measurement technology ............................................................................... 5
2.2 Intermittent earth fault protection ........................................................................................... 6
2.3 Broad range multi-criteria earth-fault protection ..................................................................... 7
2.4 Disturbance recorder and power quality................................................................................. 8
2.5 Cable end differential protection............................................................................................. 9
3A
AQtiv
Qtiva
ate 200 Se
Settting and config
configura
uration
tion soft
softw
war
are
e suit
suite
e ................................................................ 10
4 Connections of A
AQ
Q-F255
-F255............................................................................................................
............................................................................................................ 11
5 Applic
Applica
ation example and its connections .................................................................................... 12
6F
Functions
unctions incl
included
uded in A
AQ
Q-F255 .................................................................................................. 13
7A
AQ
Q-200 P
Prrotection functions ...................................................................................................... 17
7.1 Line differential protection (87L)........................................................................................... 17
7.2 Non-directional overcurrent protection (50/51)..................................................................... 17
7.3 Non-directional earth fault protection (50N/51N) .................................................................. 17
7.4 Directional overcurrent protection (67)................................................................................. 18
7.5 Directional earth fault protection (67N/32N)......................................................................... 18
7.6 Intermittent earth fault protection (67NT) ............................................................................. 18
7.7 Negative sequence overcurrent/ phase current reversal/ current unbalance protection (46/
46R/46L) ................................................................................................................................... 19
7.8 Harmonic overcurrent protection (50H/51H/68H)................................................................. 19
7.9 Circuit breaker failure protection (50BF/52BF) ..................................................................... 19
7.10 Low-impedance or high-impedance restricted earth fault/ cable end differential
protection (87N) ........................................................................................................................ 19
7.11 Overvoltage protection (59) ............................................................................................... 20
7.12 Undervoltage protection (27) ............................................................................................. 20
7.13 Neutral overvoltage protection (59N) ................................................................................. 20
7.14 Sequence voltage protection (47/27P/59PN) ..................................................................... 20
7.15 Rate-of-change of frequency (81R) .................................................................................... 20
7.16 Overfrequency and underfrequency protection (81O/81U)................................................. 21
7.17 Overpower, underpower and reverse power protection (32O, 32U, 32R)............................ 21
7.18 Line thermal overload protection (49F)............................................................................... 21
7.19 Voltage memory................................................................................................................. 21
7.20 Programmable stage (99) .................................................................................................. 22
7.21 Arc fault protection (50Arc/50NArc)................................................................................... 22
8A
AQ
Q-200 Contr
Control
ol functions
functions...........................................................................................................
........................................................................................................... 23
8.1 Setting group selection ........................................................................................................ 23
8.2 Cicruit breaker object control and monitoring ....................................................................... 23
8.3 Auto-recloser (79) ............................................................................................................... 23
8.4 Cold load pick-up (CLPU) .................................................................................................... 24
8.5 Switch-on-to-fault (SOTF) .................................................................................................... 24
8.6 Synchrocheck (ΔV/Δa/Δf; 25) .............................................................................................. 24
8.7 Vector jump (78).................................................................................................................. 24
9A
AQ
Q-200 Monit
Monitoring
oring functions
functions......................................................................................................
...................................................................................................... 25
9.1 Current transformer supervision........................................................................................... 25
9.2 Voltage transformer supervision (60) ................................................................................... 25
9.3 Disturbance recorder (DR)................................................................................................... 25
9.4 Circuit breaker wear ............................................................................................................ 25
9.5 Fault locator (21FL) ............................................................................................................. 25
10 D
Dimensions
imensions and installa
installation
tion ...................................................................................................... 26
11 T
Technic
echnical
al da
data
ta .......................................................................................................................... 29
11.1 Current measurement........................................................................................................ 29
11.2 Voltage measurement ........................................................................................................ 30
11.3 Power and energy measurement........................................................................................ 31
11.4 Frequency measurement ................................................................................................... 31
© Arcteq Relays Ltd
MM00003
1
AQ -F255
Data sheet
Version: 1.00
11.5 Auxiliary voltage................................................................................................................. 32
11.6 CPU communication ports ................................................................................................. 32
11.7 CPU digital inputs .............................................................................................................. 33
11.8 CPU digital outputs............................................................................................................ 34
11.9 Digital input module ........................................................................................................... 35
11.10 Digital output module....................................................................................................... 35
11.11 Arc protection module ..................................................................................................... 35
11.12 Milliampere module (mA out & mA in) .............................................................................. 37
11.13 RTD input module ............................................................................................................ 37
11.14 RS-232 & serial fiber communication module................................................................... 37
11.15 Double LC 100 Mbps Ethernet communication module .................................................... 38
11.16 CPU & Power supply........................................................................................................ 38
11.17 Display ............................................................................................................................ 38
11.18 Tests and environmental .................................................................................................. 38
11.19 Protection functions ......................................................................................................... 40
11.20 Control functions ............................................................................................................. 57
11.21 Monitoring functions ........................................................................................................ 61
12 Or
Ordering
dering inf
informa
ormation
tion ................................................................................................................ 66
13 Contact and rre
efer
erence
ence inf
informa
ormation
tion............................................................................................
............................................................................................ 68
2
© Arcteq Relays Ltd
MM00003
AQ -F255
Data sheet
Version: 1.00
Copyright
Copyright © Arcteq Relays Ltd. 2021. All rights reserved.
© Arcteq Relays Ltd
MM00003
3
AQ -F255
Data sheet
Version: 1.00
1 AQ-200 Benefits
The AQ-200 series provides an optimal protection and control solution for any utility, power plant, windpower, off-shore, marine, industrial, commercial or institutional electrical protection and control
applications. The AQ-200 series offers integrated or segregated protection control, monitoring,
measuring solutions with powerful complementary monitoring, measuring, communication and
diagnostics information. The AQ-200 is developed using the latest available technologies providing a
totally new dimension and options to protection and control engineers.
VER
VERS
SATILE P
PR
ROTEC
TECTION
TION DESIGN
COMMUNICA
COMMUNICATION
TION
AQ-200 series is characterized by fast,
versatile and dependable protection functions
with uniquely wide operating frequency band
of 6…75Hz making AQ-200 perfect choice for
the most demanding protection applications
including rotating machines.
Native Ethernet communication provides for fast
and seamless communication. The AQ-200
communicates using variety of standard
protocols including IEC 61850 substation
communication standard with fast GOOSE
messaging.
MODULARIT
MODULARITY
Y
SAVINGS IN ENGINEERING TIME
Fully modular hardware construction gives a
high level of flexibility; additional I/O or
communication cards can be simply plugged in
according to application needs.
AQtivate 200 free of charge software suite saves
valuable engineering time by offering an intuitive
and easy to use human machine interface.
Download all relay settings instantly using native
100Mb/s Ethernet connection either at IED front
port or rear port through Ethernet network.
US
USABILIT
ABILITY
Y
Maximum use of the IEDs is guaranteed by
features such as guided wizards, sophisticated
setting aids, highly customizable HMI, file
storage of pdf or other supportive documents
and extensive user log information. Track down
a complete user history register including
setting change and other operational history
STAND
ANDARDIZ
ARDIZED
ED HARD
HARDW
WARE
Trouble free logistics and stocking with highly
standardized hardware design. Five CT inputs
with software settable secondary currents and
software configurable digital input thresholds for
voltage are standard features of AQ-200 series.
PERF
ERFORMANCE
ORMANCE
The AQ-200 series offers truly sub-cycle
instantaneous triptimes. You can add a fast
integrated arc protection to your traditional
protection scheme. Powerful PLC programming
is included for the most demanding
applications
allowing
for
extensive
customization. Up to 100 disturbance records
of up to 10 seconds each and 10 000 events
are stored in non-volatile memory.
4
© Arcteq Relays Ltd
MM00003
AQ -F255
Data sheet
Version: 1.00
2 AQ-200 Innovations
2.1 Ultra-accurate measurement technology
ACCUR
CCURA
ATE AND FREQUENC
FREQUENCY
Y INDEP
INDEPENDENT
ENDENT
Arcteq’s AQ-200 series protection and control
IEDs are deploying patented measurement
technology. This has resulted in a very unique
combination of class 0.2S power and energy
measurement
accuracy,
full
dynamic
measurement range and frequency independent
measurement and protection in a single device.
Therefore the AQ-200 series is well applicable
for any applications requiring accurate
measurement alone, or combination of
measurement and protection. Frequency
independent measurement technology allows for
more accurate rotating machine protections as
well.
PATENTED MEA
MEASUREMENT
SUREMENT AL
ALGORITHM
GORITHM
The
system
frequency
independent
measurement accuracy has been achieved in
AQ-200 series devices by adjusting the sample
rate of the measurement channels according to
the measured system frequency in a way that
FFT (Fast Fourier Transformation) calculation can
always make use of full power cycle buffer.
Furthermore, all analog channels are calibrated
against 8 system frequency points for both,
magnitude and angle. This frequency dependent
correction compensates the used measurement
hardware frequency dependencies as the
measurement hardware is not linear considering
the measured analog signal frequency. Therefore
the magnitude and angle measurements need to
be calibrated against frequency to obtain high
accuracy. Furthermore, the measured channels
FFT result fundamental frequency component is
corrected for magnitude and angle errors by
Arcteq AQ-200 series patented calibration
algorithms.
© Arcteq Relays Ltd
MM00003
5
AQ -F255
Data sheet
Version: 1.00
2.2 Intermittent earth fault protection
BA
BACK
CKGR
GROUND
OUND
Underground cabling of the distribution networks
makes them less vulnerable to disturbances, but
at the same time leading to higher earth fault
currents. Networks are compensated with
Petersen coils to keep earth fault currents on
lower level. Typically an intermittent earth-fault
is a 0.05-1 millisecond self-extinguishing flashover fault from phase to ground causing heavy
transient spikes into the electric network.
Traditional non-intermittent directional earth fault
protection is unable to operate correctly in this
type of fault since it is typically based into FFT
(Fast Fourier Transformation) processing results
based on fundamental frequency RMS values.
AR
ARC
CTEQ P
PA
ATENTED SOL
SOLUTION
UTION
Arcteq’s breakthrough IED technology in AQ-200
series with patented very accurate measurement
technology (better than 0.2% for energy and
power measurement) combined with up to
3.2kHz sampling rate lays the foundation for
accurate algorithms of fast phenomenon such as
intermittent earth-fault protection. The algorithm
makes use of the accurate measurement and
sampling technology by searching for spikes in
I0 and U0 generated by intermittent earth fault
strike through. Algorithm is able to remove all
unnecessary
and
confusing
data
and
concentrate only on the spikes. By calculating
the delta of raw samples using an innovative
patented admittance based formula the polarity
of the spikes in I0 and U0 is determined
accurately distinguishing effectively a faulty
feeder over healthy background feeder. The
algorithms have been proven effective in
extensive field tests with electrical utilities, and
have been installed in networks since 2014.
The triptime of the intermittent earth fault
protection is set to 500 ms. From this disturbance
record from AQ-F215 or AQ-F255 relay can be
read that the relay detects the intermittent earth
faults and trips within the set time.
6
The AQ-F215 and AQ-F255 feeder terminal is
equipped with the intermittent earth fault
protection. The protection algorithm combined
with 0.2S measurement class and 3.2 kHz
sampling frequency, enables it to detect and
isolate intermittent earth faults with high
accuracy
The algorithms have been proven effective in
extensive field tests with electrical utilities, and
have been installed in networks since 2014.
© Arcteq Relays Ltd
MM00003
AQ -F255
Data sheet
Version: 1.00
2.3 Broad range multi-criteria earth-fault protection
THE P
PR
ROBLEM
The increase of medium voltage cabling,
connection of distributed generation and
compensated networks (Petersen coil) along
with distributed compensation has led to new
challenges in earth-fault protection of
distribution feeders. Challenging combinations
of short cable feeders, long overhead feeders
and mixed cable and overhead network is
increasing significantly among distribution
system operators. Relaying on conventional
protection methods may lead to either nuisance
trips of healthy feeders or undetected faults in
faulty feeders. When protecting compensated
long-distance cables and overhead lines it is
in some cases difficult to distinguish between
healthy- and faulty feeder when protection is
based on merely measuring the angle and
magnitude of residual voltage and currents.
Earth fault protection often requires information
on
network
status
(ungrounded
or
compensated). When changing between these
two statuses setting group must be changed
and especially in case of distributed
compensation the change may be difficult or
impossible to arrange.
THE SOL
SOLUTION:
UTION: NEW BR
BRO
OAD R
RANGE
ANGE MODE
WITH MUL
MULTI-CRITERIA
TI-CRITERIA DETEC
DETECTION
TION
New broad range mode available in AQ-200
series protection and control IEDs can protect
against earth-fault in both ungrounded and
compensated networks without setting
changes. The algorithm reliability is further
increased using a new multi- -criteria detection.
This optional additional tripping condition for
compensated
networks
uses
Arcteq’s
patented, high-resolution intermittent earthfault algorithm with added symmetrical
component calculation of phase currents and
voltages. If this mode is activated the tripping
criteria comprises of a measured residual
current in the third or fourth quadrant and the
symmetrical components of voltages and
currents detecting a fault. No extra
parameterization is required compared to
traditional method. Multi-criteria algorithm can
be tested with Comtrade files supplied by
Arcteq. Function requires connection of
3-phase currents, residual current and zero
sequence voltage to operate correctly. To avoid
unnecessary trips due to CT errors,
encroachment area in compensated long
healthy feeders can be added.
© Arcteq Relays Ltd
MM00003
Operation of new broad range mode covers both
ungrounded and compensated networks and is
equipped with optional additional multi-criteria
detection for compensated networks to increase
the protection reliability.
For a complete coverage of feeder earth-faults
in compensated networks, the intermittent /
transient type of earth-faults are to be protected
by Arcteq’s patented intermittent earth-fault
protection stage available in the AQ 200 series
feeder protection IEDs.
7
AQ -F255
Data sheet
Version: 1.00
2.4 Disturbance recorder and power quality
DIS
DISTURBANCE
TURBANCE RECORDER CAP
CAPA
ACIT
CITY
Y
The disturbance recorder in AQ 200 series
IEDs is a high capacity and fully digital recorder
integrated to protection relay. Maximum
sample rate of the recorder analog channels is
64 samples per cycle. The recorder supports
96 digital channels simultaneously with
measured 9 analog channels. Even all
measured and calculated values can be
registered as digital channels with 5ms sample
time. This feature is useful in for instance motor
start up sequence, as users can track fully
sampled analogue waveform values and every
5ms sampled RMS values simultaneously. The
memory capacity in AQ 200 series IEDs allows
for up to 100 nonvolatile records with total of
500 second recording time with full sample rate
and maximum number of recorded channels.
Recorder output is in general comtrade format
and it is compatible with most viewers and relay
test sets. The comtrade file is based on the
IEEE Std C37.111-1999 standard.
DOCUMENTING V
VOL
OLT
TAGE S
SA
AGS AND
SWELLS WITH DIS
DISTURBANCE
TURBANCE RECORDER
AQ 200 series’ disturbance recorder is a great
tool for analyzing the performance of the power
system in network disturbance situations.
Voltage sags and swells are often monitored
for power quality analyzes. The disturbance
recorder can be triggered with any signal in
the IED. Over -and undervoltage or any
programmable protection stages can be used
to trigger the recorder. With Arcteq’s fast acting
protection stages the voltage sags and swells
of as little as 10-15ms can be recorded and
documented.
HARMONICS MONIT
MONITORING
ORING
The AQ 200 series IEDs are measuring
harmonics of up to 31st order for both currents
and voltages. Arcteq’s innovative and unique
harmonic overcurrent stages (50/50h) can be
used for alarming, tripping and triggering the
disturbance recorder. Freely settable harmonic
overcurrent stages can monitor and act on any
of the current harmonics from 2nd to 19th
order. The disturbance recorder can record
harmonic content up to 31st order.
DIS
DISTURBANCE
TURBANCE RECORDER SET
SETTING
TING EXAMP
EXAMPLES
LES
8
© Arcteq Relays Ltd
MM00003
AQ -F255
Data sheet
Version: 1.00
2.5 Cable end differential protection
CABLE END F
FA
AUL
ULT
TS AND AR
ARC
C FLA
FLASH
SH
INCIDENT
INCIDENTS
S
As per empiric data, the most common nonhuman intruded fault location is the cable
compartment, and more precisely the cable
end. Degrading insulation level or faulty cable
connections are the most common causes for
cable end faults. Cable faults often start by a
small earth-leakage developing to full singlephase faults. Further, if not detected and
tripped, the single-phase faults may develop to
cross country or 3-phase faults.
COMP
COMPENS
ENSA
ATED CABLE END DIFFERENTIAL
PROTEC
TECTION
TION
Cable end differential protection without natural
unbalance compensation in use. Phase current
CT errors are causing significant differential
current. Compensation is essential to have a
sensitive protection setting
Arcteq has developed a proactive cable end
protection which provides an early detection of
cable end fault. Typically cable end protection
is implemented as an alarming function
indicating the need of preventive maintenance.
Operating principle is based on low impedance
differential protection with settable bias
characteristics.
Differential
current
is
calculated in between of summed phase
currents and selected residual current input
measured by a core balance CT.
The function provides natural measurement
unbalance compensation to have higher
operating sensitivity for monitoring cable end
faults. When calculating the residual current
from phase currents the natural unbalance may
be in total up to 10% with CT’s of class 5P.
When the natural unbalance current is
compensated the differential settings may be
set more sensitively.
If in the cable end should occur any faults the
cable end differential catches the difference in
between of the ingoing and outgoing residual
currents and the resulting signal can be used
for alarming or tripping purpose.
THE BENEFIT
Cable end differential protection uses the
elements already available in the protection
scheme: 3-phase CT’s and residual core
balance CT. There is no need for extra
hardware or wiring. The sensitive compensated
cable end differential protection can be used
with no extra cost to provide additional
switchgear and personnel safety.
© Arcteq Relays Ltd
MM00003
Compensated cable end differential protection
during a small earth-leakage current. Due to
natural unbalance compensation the function
can alarm correctly even on small differential
currents
9
AQ -F255
Data sheet
Version: 1.00
3 AQtivate 200 Setting and configuration software suite
All AQ-200 series IEDs can be conveniently
configured and set using easy to use and
powerful AQtivate 200 free of charge software
suite. Protection setting, I/O configuration, logic
programming, HMI display, communication
protocol parameters and sophisticated on-line
monitoring are in-built functions of the software
suite. The AQtivate 200 can be used in off-line
or on-line mode through Ethernet connection at
the relay front port or network at relay rear ports.
Inbuilt AQviewer software provides for comtrade
disturbance recorder analysis. The AQtivate 200
runs on all Windows operating systems and is
backwards compatible with older firmware
versions.
Clear grouping of IED functions guarantees
familiar working experience with AQtivate 200
software suite. Only the activated functions are
displayed
for
convenient
setting
and
commissioning.
With the AQ 250 graphical mimic editor it is easy
to build informative color displays for the IED’s.
10
With the logic editor the functionality of the IED
can be extended by using common logic gates.
On-line status displays of vectors, logic, blocking
and matrix signals save time in troubleshooting
and project commissioning and testing stage.
© Arcteq Relays Ltd
MM00003
AQ -F255
Data sheet
Version: 1.00
4 Connections of AQ-F255
AQ-F255
Device I/O
DI
DO
CT
VT
Add-on
5+1
3 (IL)
2 (I0)
4 voltage
channels
11 slots
1...3
Protection functions
I>
50/51
I0d>
87N
(4)
(1)
I0>
(4)
50N/51N
CBFP
(1)
50BF
/52BF
I2>
(4)
46/46R
/46L
TF>
(1)
49F
Ih>
50H/51H
/68H
(4)
Current-based
Iarc>/I0arc>
50Arc>/50NArc>
OPTIONAL
Voltage-based
U>
59
(4)
U<
(4)
27
U0>
(4)
59N
f>/<
81O/81U
∆α
Idir>
67
I0int>
67NT
(4)
(4)
78
Voltage and
current-based
I0dir>
67N
(4)
P>
32O
(1)
P<
32U
(8)
(1)
df/dt >/<
81R
U1/2>/<
47/27P
/59PN
(1)
Pr
32R
(1)
(4)
(1)
Monitoring functions
THD
CTS
VTS
CBW
DR
21FL
Circuit
breaker
wear
Disturbance
recorder
Fault
locator
31st
Control functions
© Arcteq Relays Ltd
MM00003
0→1
∆V/∆a/∆f
79
25
OBJ
CLPU
SOTF
SGS
Cold load
pick-up
Switch-onto-fault
1...8
11
AQ -F255
Data sheet
Version: 1.00
5 Application example and its connections
This chapter presents an application example for the feeder protection IED.
Since three line-to-neutral voltages and the zero sequence voltage (U4) are connected, this application
uses the voltage measurement mode "3LN+U0" (see the image below). Additionally, the three phase
currents and the residual current (I01) are also connected. The digital inputs are connected to indicate
the breaker status, while the digital outputs are used for breaker control.
12
© Arcteq Relays Ltd
MM00003
AQ -F255
Data sheet
Version: 1.00
6 Functions included in AQ-F255
The AQ-F255 feeder protection relay includes the following functions as well as the number of stages
for those functions.
Functionality package
Name
(number
of
stages)
IEC
ANSI
Description
LDIF (1)
IdL>
87L
Line differential
protection
(optional)
NOC (4)
I>
I>>
I>>>
I>>>>
50/51
Non-directional
overcurrent
protection
X
DOC (4)
Idir>
Idir>>
Idir>>>
Idir>>>>
67
Directional
overcurrent
protection
X
NEF (4)
I0>
I0>>
I0>>>
I0>>>>
50N/
51N
Non-directional
earth fault
protection
X
DEF (4)
I0dir>
I0dir>>
I0dir>>>
I0dir>>>>
67N/
32N
Directional earth
fault protection
X
X
IEF (1)
I0int>
67NT
Intermittent earth
fault protection
X
X
OV (4)
U>
U>>
U>>>
U>>>>
59
Overvoltage
protection
X
X
UV (4)
U<
U<<
U<<<
U<<<<
27
Undervoltage
protection
X
X
NOV (4)
U0>
U0>>
U0>>>
U0>>>>
59N
Neutral
overvoltage
protection
X
X
81O/
81U
Overfrequency
and
underfrequency
protection
X
X
FRQV
(8)
© Arcteq Relays Ltd
MM00003
f>
f>>
f>>>
f>>>>
f<
f<<
f<<<
f<<<<
A
B
C
X
X
X
X
X
X
13
AQ -F255
Data sheet
Version: 1.00
Functionality package
Name
(number
of
stages)
IEC
ANSI
Description
A
ROCOF
(1)
df/dt>/<
(1…8)
81R
Rate-of-change of
frequency
X
CUB (4)
I2>
I2>>
I2>>>
I2>>>>
46/
46R/
46L
Negative
sequence
overcurrent/
phase current
reversal/
current unbalance
protection
X
VUB (4)
U1/U2>/<
U1/U2>>/<<
U1/
U2>>>/<<<
U1/
U2>>>>/<<<<
47/
27P/
59PN
Sequence voltage
protection
X
B
C
X
X
X
X
Harmonic
overcurrent
protection
14
HOC (4)
Ih>
Ih>>
Ih>>>
Ih>>>>
50H/
51H/
68H
CBFP
(1)
CBFP
50BF/
52BF
The detection and
blocking or
tripping based on
a selectable
harmonic. The
phase currents
and the residual
currents have
separate stages.
X
X
X
Circuit breaker
failure protection
X
X
X
X
X
X
REF (1)
I0d>
87N
Lowimpedance or
high-impedance
restricted earth
fault/ cable end
differential
protection
TOLF
(1)
TF>
49F
Line thermal
overload
protection
X
X
X
PGS (1)
PGx>/<
99
Programmable
stage
X
X
X
OPW (1)
P>
32O
Overpower
protection
X
X
UPW (1)
P<
32U
Underpower
protection
X
X
RPW (1)
Pr
32R
Reverse power
protection
X
X
VMEM
(1)
-
-
Voltage memory
X
X
© Arcteq Relays Ltd
MM00003
AQ -F255
Data sheet
Version: 1.00
Functionality package
Name
(number
of
stages)
IEC
ANSI
Description
A
B
C
ARC (1)
IArc>/I0Arc>
50Arc/
50NArc
Arc fault
protection
(optional)
X
X
X
Functionality package
Name
IEC
ANSI
Description
A
B
C
SGS
-
-
Setting group
selection
X
X
X
X
X
X
X
X
X
X
X
OBJ
-
-
Object control
and monitoring
(10 objects
available)
Indicator object
monitoring
CIN
-
-
CLPU
CLPU
-
Cold load pick-up
X
U0>
RECL
-
79N
Zero sequence
recloser
X
SOTF
SOTF
-
Switch-on-to-fault
X
SYN
ΔV/
Δa/Δf
25
Synchrocheck
X
X
VJP
∆φ
78
Vector jump
X
X
AR
0→
1
79
Auto-recloser
X
(10 indicators
available)
X
X
X
X
X
Functionality package
Name
IEC
ANSI
Description
A
B
C
CTS
-
-
Current transformer
supervision
X
X
X
VTS
-
60
Voltage transformer
supervision
X
DR
-
-
Disturbance
recorder
X
X
X
CBW
-
-
Circuit breaker
wear monitor
X
X
X
THD
-
-
Total harmonic
distortion
X
X
X
FLX
-
21FL
Fault locator
X
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Functionality package
16
Name
IEC
ANSI
Description
A
B
C
MR
-
-
Measurement
recorder
X
X
X
VREC
-
-
Measurement value
recorder
X
X
X
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7 AQ-200 Protection functions
7.1 Line differential protection (87L)
The line differential protection provides main protection for two terminal transmission lines. The
operating principle is based on Kirchhoff’s current law which stated that the current entering and
leaving the protection zone is equal, and synchronized Fourier basic harmonic comparison between the
line ends.
The devices at both line ends sample the phase currents and calculate the Fourier basic harmonic
components. These components are exchanged between the devices synchronized via communication
channels. The differential characteristic is a biased characteristic with two break points. Additionally, an
unbiased overcurrent stage is applied, based on the calculated differential current.
7.2 Non-directional overcurrent protection (50/51)
The non-directional overcurrent function is used for instant and time-delayed overcurrent and shortcircuit protection. Four stages of the function are included. The operating decisions are based on
phase current magnitude, constantly measured by the function. The available phase current
magnitudes are equal to RMS values, to TRMS values (including harmonics up to 32nd), or to peak-topeak values. Definite time, IEC or ANSI inverse time curves with settable reset delays.
7.3 Non-directional earth fault protection (50N/51N)
The non-directional earth fault function is used for instant and time-delayed earth fault protection. Four
stages of the function are included. The operating characteristics are based on the selected neutral
current magnitudes which the function measures constantly. The available analog measurement
channels are I01 and I02 (residual current measurement) and I0Calc (residual current calculated from
phase current). The user can select these channels to use RMS values, TRMS values (including
harmonics up to 32nd), or peak-to-peak values. The blocking signal and the setting group selection
control the operating characteristics of the function during normal operation, i.e. the user or userdefined logic can change function parameters while the function is running.
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7.4 Directional overcurrent protection (67)
The directional overcurrent function is used for instant and time-delayed overcurrent and short-circuits.
The operating decisions are based on phase current magnitudes which the function constantly
measures. Function uses direction of calculated positive sequence voltage and setting parameters to
determine the forward direction of pick-up sector. The selectable monitored phase current magnitudes
are equal to RMS values, to TRMS values (including harmonics up to 31st), or to peak-to-peak values.
The blocking signal and the setting group selection control the operating characteristics of the function
during normal operation, i.e. the user or user-defined logic can change function parameters while the
function is running.
7.5 Directional earth fault protection (67N/32N)
The directional earth fault function is used for instant and time-delayed earth fault protection. The
operating decisions are based on selected grounding type, selected neutral current and voltage
magnitudes which the function constantly measures. The available residual current magnitudes are
RMS values, TRMS values (including harmonics up to 31st), or peak-to-peak values that come from
inputs I01 or I02 (residual current measurement) or from I0Calc (residual current calculated from phase
current measurements). The current angle is compared to the angle of measured or calculated zero
sequence voltage. A certain amount of zero sequence voltage has to be present to activate the trip.
The blocking signal and the setting group selection control the operating characteristics of the function
during normal operation, i.e. the user or user-defined logic can change function parameters while the
function is running.
7.6 Intermittent earth fault protection (67NT)
The intermittent earth fault is a transient type of single-phase-to-earth fault where the actual fault
phenomenon lasts for about a few hundred microseconds. The intermittent earth fault is commonly
seen in Petersen coil grounded (compensated) medium voltage networks. The intermittent earth fault is
commonly thought only as a cable network problem but it can also occur in overhead line networks.
The key point for this type of fault appearance is the compensation of earth fault currents with a
Petersen coil.
This phenomenon is becoming more frequent as more utilities networks are replacing overhead lines
with cables dug into the ground. This development in distribution networks is very understandable
as overhead lines are more vulnerable to possible seasonal storm damages. Also, the annual
maintenance costs as well as the annual power-down time are both significantly lower with
underground cable networks than with overhead line networks. However, the problem at hand is
caused by the increasing amount of cabling in the network which in turn causes dramatic increases
in the capacitive earth fault currents in the distribution networks. When the capacitive earth fault
current increases in the network, it becomes necessary to detect the earth fault current with a
Petersen coil.
Problems caused by intermittent earth fault are normally seen in compensated network substations: an
earth fault can trip multiple feeders simultaneously, or an entire substation can be tripped by residual
voltage back-up protection from the incomer. This is typical of old-fashioned relay protection as it is not
capable of differentiating between a normal consistent earth fault and an intermittent earth fault. As the
intermittent earth fault is a transient type of fault where the actual fault lasts only for a few hundred
microseconds, this causes traditional directional earth fault protection relays to lose their directional
sensitivity, and as a result their directional decision algorithms go haywire and the trip decisions will be
completely random. Typically, when a whole substation goes dark the logs of all protection relays show
how they have experienced multiple incorrect directional earth fault starts and releases, as well as an
incomer relay residual voltage trip. This is also the worst case scenario. In another typical scenario a
few feeders, including the correct faulty feeder, have tripped at the same time. In this case, as in the
previous, all the relays' logs show various incorrect directional earth fault starts and releases.
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Previously, these scenarios were usually ignored and filed under 'Mysteries of the universe'
because they only occured once or twice a year and because disturbance recordings were not
commonly used in normal medium-voltage substations for fault verification. However, when disturbance
recorders were introduced as a common feature of protection relays this phenomenon received a name
and defined characteristics. One such characteristic is the occurence of high magnitude current
spikes, which –compared to residual voltage– are in the opposite direction of the current spike in
faulty feeders and concurrent in healthy feeders. Handling these unique characteristics requires a
completely different set of tools than what traditional directional earth fault protection can offer.
7.7 Negative sequence overcurrent/ phase current reversal/ current
unbalance protection (46/46R/46L)
The current unbalance function is used for instant and time-delayed unbalanced network protection
and for detecting broken conductors. The number of stages in the function depends on the
relay model. The operating decisions are based on negative and positive sequence current magnitudes
which the function constantly measures. In the broken conductor mode (I2/I1) the minimum allowed
loading current is also monitored in the phase current magnitudes.
There are two possible operating modes available: the I2 mode monitors the negative sequence
current, while the I2/I1 mode monitors the ratio between the negative sequence current and the
positive sequence current. The relay calculates the symmetrical component magnitudes in use from
the phase current inputs IL1, IL2 and IL3. The zero sequence current is also recorded into the registers
as well as the angles of the positive, negative and zero sequence currents in order to better verify any
fault cases. The blocking signal and the setting group selection control the operating characteristics of
the function during normal operation, i.e. the user or user-defined logic can change function
parameters while the function is running.
7.8 Harmonic overcurrent protection (50H/51H/68H)
The harmonic overcurrent function is used for non-directional instant and time-delayed overcurrent
detection and clearing. The number of stages in the function depends on the relay model. The function
constantly measures the selected harmonic component of the selected measurement channels, the
value being either absolute value or relative to the RMS value. The blocking signal and the setting
group selection control the operating characteristics of the function during normal operation, i.e. the
user or user-defined logic can change function parameters while the function is running.
7.9 Circuit breaker failure protection (50BF/52BF)
The circuit breaker failure protection function is used for monitoring the circuit breaker operation after it
has received a TRIP signal. The function can also be used to retrip a failing breaker; if the retrip fails, an
incomer breaker can be tripped by using the function's CBFP output. The retrip functionality can be
disabled if the breaker does not have two trip coils.
7.10 Low-impedance or high-impedance restricted earth fault/ cable end
differential protection (87N)
The low-impedance or high-impedance restricted earth fault function is used for residual differential
current measurement for transformers. This function can also be used as the cable end differential
function. The operating principle is low-impedance differential protection with bias characteristics the
user can set. A differential current is calculated with the sum of the phase currents and the selected
residual current input. In cable end differential mode the function provides natural measurement
unbalance compensation for higher operating sensitivity in monitoring cable end faults.
The restricted earth fault function constantly monitors phase currents and selected residual current
instant values as well as calculated bias current and differential current magnitudes.
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7.11 Overvoltage protection (59)
The overvoltage function is used for instant and time-delayed overvoltage protection. Each device with
a voltage protection module has four (4) available stages of the function (U>, U>>, U>>>, U>>>>). The
function constantly measures phase voltage magnitudes or line-to-line magnitudes. Overvoltage
protection is based on line-to-line RMS measurement or to line-to-neutral RMS measurement (as the
user selects). If the protection is based on line-to-line voltage, overvoltage protection is not affected by
earth faults in isolated or compensated networks. The blocking signal and the setting group selection
control the operating characteristics of the function during normal operation, i.e. the user or userdefined logic can change function parameters while the function is running.
7.12 Undervoltage protection (27)
The undervoltage function is used for instant and time-delayed undervoltage protection. The function
constantly measures phase voltage magnitudes or line-to-line voltage magnitudes.
Undervoltage protection is based on line-to-line voltages or to line-to-neutral voltages (as the user
selects). If the protection is based on line-to-line voltage, undervoltage protection is not affected by
earth faults in isolated or compensated networks. Undervoltage protection has two blocking stages:
internal blocking (based on voltage measurement and low voltage), or external blocking (e.g. during
voltage transformer fuse failure). The blocking signal and the setting group selection control the
operating characteristics of the function during normal operation, i.e. the user or user-defined logic can
change function parameters while the function is running.
7.13 Neutral overvoltage protection (59N)
The neutral overvoltage function is used for non-directional instant and time-delayed earth fault
protection. The function constantly measures phase-to-earth voltage magnitudes and calculates the
zero sequence component or measures a dedicated voltage input. Neutral overvoltage protection is
scaled to line-to-line RMS level. When the line-to-line voltage of a system is 100 V in the secondary
side, the earth fault is 100 % of the Un and the calculated zero sequence voltage reaches 100/√3 V =
57.74 V.
7.14 Sequence voltage protection (47/27P/59PN)
The sequence voltage function is used for instant and time-delayed voltage protection. It has positive
and negative sequence protection for both overvoltage and undervoltage (the user selects the needed
function). The function constantly measures the RMS value of phase-to-earth voltage
magnitudes, or line-to-line and neutral voltage magnitudes to calculate the positive or negative
sequence voltage. The user can select the voltage used. Sequence voltage is based on the
system's line-to-line voltage level. Protection stages can be set to protect against both undervoltage
and overvoltage. The blocking signal and the setting group selection control the operating
characteristics of the function during normal operation, i.e. the user or user-defined logic can change
function parameters while the function is running.
7.15 Rate-of-change of frequency (81R)
The rate-of-change of frequency function is used to detect fast drops or increases in frequency. If the
load changes fast this function detects and clears the frequency-based faults faster than conventional
underfrequency and overfrequency protections. One of the most common causes for the frequency to
deviate from its nominal value is an unbalance between the generated power and the load demand. If
the unbalance is big the frequency changes rapidly.
The rate-of-change of frequency protection can also be applied to detect a loss of mains situation. Loss
of mains is a situation where a part of the network (incorporating generation) loses its connection with
the rest of the system (i.e. becomes an islanded network). A generator that is not disconnected from
the network can cause safety hazards. A generator can also be automatically reconnected to the
network, which can cause damage to the generator and the network.
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7.16 Overfrequency and underfrequency protection (81O/81U)
The frequency protection function can be used both in overfrequency and in underfrequency situations,
and it has four (4) stages for both. Frequency protection can be applied to protect feeder, bus,
transformer, motor and generator applications. The difference between the generated power and the
load demand can cause the frequency to drop below or rise above the allowed level. When the
consumption is larger than the generated power, the frequency may drop. When more power is
generated than is consumed, overfrequency can occur.
In generator applications too big a load or a malfunction in the power controller can cause the
frequency to decrease. Underfrequency causes damage to turbine wings through vibration as well
as heating due to increased iron losses, dropped cooling efficieny and over-magnetization in step-up
transformers. Overfrequency protection prevents the generator from running too fast which can cause
damage to the generator turbine.
Underfrequency and overfrequency protection can be used as an indicator of an accidental island
operation in distributed generation and in some consumers (as it is unlikely that the consumed and
generated power are the same). Overfrequency is also often used to control power generation to keep
the system's frequency consistent.
7.17 Overpower, underpower and reverse power protection (32O, 32U,
32R)
The overpower, underpower and reverse power functions are used for instant and time-delayed active
power protection. In applications like feeder, generator and motor protection overpower function is
used to detect overload situations by measuring three-phase active power. Underpower protection
function is used to detect loss of load conditions when there is no significant loss of current. In
generator protection applications the reverse power protection function is used to prevent damage in
situations where a synchronous generator is running like a motor when the generator draws active
power. Reverse power protection is not used to protect the generator itself but to protect the
generator's turbine.
7.18 Line thermal overload protection (49F)
The line thermal overload function is used for the thermal capacity monitoring and protection of cables
and overhead lines. This function can also be used for any single time constant application like inductor
chokes, certain types of transformers and any other static units which do not have active cooling apart
from the cables and overhead lines. The function constantly monitors the instant values of phase
TRMS currents (including harmonics up to 31st) and calculates the set thermal replica status in 5 ms
cycles. The function includes a total memory function of the load current conditions according to IEC
60255-8. The function is based on a thermal replica which represents the protected object's or cable's
thermal loading in relation to the current going through the object. The thermal replica includes the
calculated thermal capacity that the "memory" uses; it is an integral function which tells this function
apart from a normal overcurrent function and its operating principle for overload protection
applications.
7.19 Voltage memory
Certain protection functions (such as impedance or directional overcurrent) use the relay's measured
current and voltage to determine whether the electrical network fault appears to be inside the
protected area. The determination is made by comparing the angle between the operating quantity
(zone/tripping area) and the actual measured quantity. The function then produces an output when the
required terms are met.
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In close-in faults the system voltage on the secondary side may fall down to a few volts or close to
nothing. In such cases, when the measured voltage is absent, the fault direction cannot be solved. As
backup, non-directional protection can be used for tripping, but in such cases the selectivity of the
network will reduce. However, an angle memory for voltage can be used to prevent this from
happening. An adjustable voltage level with pre-fault voltage angles can be used as a reference for
fault direction and/or distance. The reference can be set manually for duration. Thanks to the
configurable voltage memory even time-delayed backup tripping can be initiated.
7.20 Programmable stage (99)
The programmable stage is a stage that the user can program to create more advanced applications,
either as an individual stage or together with programmable logic. The relay has ten programmable
stages, and each can be set to follow one to three analog measurements. The programmable stages
have three available pick up terms options: overX, underX and rate-of-change of the selected signal.
Each stage includes a definite time delay to trip after a pick-up has been triggered.
7.21 Arc fault protection (50Arc/50NArc)
Arc faults occur for a multitude of reasons: e.g. insulation failure, incorrect operation of the protected
device, corrosion, overvoltage, dirt, moisture, incorrect wiring, or even because of aging caused by
electric load. It is important to detect the arc as fast as possible in order to minimize its effects. Using
arc sensors to detect arc faults is much faster than merely measuring currents and voltages. In busbar
protection IEDs with normal protection can be too slow to disconnect arcs within a safe time frame. For
example, it may be necessary to delay operation time for hundreds of milliseconds when setting up an
overcurrent protection relay to control the feeder breakers to achieve selectivity. This delay can be
avoided by using arc protection. The arc protection card has a high-speed output to trip signals faster
as well as to extend the speed of arc protection.
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8 AQ-200 Control functions
8.1 Setting group selection
All relay types support up to eight (8) separate setting groups. The Setting group selection function
block controls the availability and selection of the setting groups. By default, only Setting group 1
(SG1) is active and therefore the selection logic is idle. When more than one setting group is enabled,
the setting group selector logic takes control of the setting group activations based on the logic and
conditions the user has programmed.
8.2 Cicruit breaker object control and monitoring
The object control and monitoring function takes care of both for circuit breakers and disconnectors.
The monitoring and controlling are based on the statuses of the relay's configured digital inputs and
outputs. The number of controllable and monitored objects in each relay depends on the device type
and amount of digital inputs. One controllable object requires a minimum of two (2) output contacts.
The status monitoring of one monitored object usually requires two (2) digital inputs. Alternatively,
object status monitoring can be performed with a single digital input: the input's active state and its
zero state (switched to 1 with a NOT gate in the Logic editor).
An object can be controlled manually or automatically. Manual control can be done by local control, or
by remote control. Local manual control can be done by relays front panel (HMI) or by external push
buttons connected to relays digital inputs. Manual remote control can be done through one of the
various communication protocols available (Modbus, IEC101/103/104 etc.). The function supports the
modes "Direct control" and "Select before execute" while controlled remotely. Automatic controlling can
be done with functions like auto-reclosing function (ANSI 79).
8.3 Auto-recloser (79)
Auto-reclosing means a coordinated de-energization and re-energization of overhead lines (both
transmission and distribution). Its purpose is to clear transient and semi-permanent fault causes from
the line and automatically restore the supply to the line. These types of faults account for approximately
80...95 % of all faults found in transmission and distribution networks. The majority of these fault types
can be cleared with high-speed auto-reclosing, while the rest can be cleared with delayed autoreclosing by de-energizing the faulty line for a longer period of time.
Only a minority of overhead line faults are of the permanent type which require maintenance or repair
in the actual fault location. This type of fault include lightning striking the line, a tree branch touching
the line, an arc caused by animals, and a short-circuit caused by some other object touching the line. If
the fault is permanent (e.g. a broken insulator or a fallen tree leaning on the overhead line), the autorecloser cannot clear the fault and the faulty feeder is locked and prevented from closing until the
cause of the fault is repaired in the actual fault location. Also, when a fault cannot be cleared by autoreclosing the line, any close-distance short-circuits should avoid initiating the auto-recloser because
that would only cause unnecessary stress for the lines and the circuit breakers. Similar situations also
rise in mixed networks since cable network faults cannot be cleared with the auto-recloser. The
function must therefore be aware of the fault location before applying the auto-recloser to the faulty
line.
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8.4 Cold load pick-up (CLPU)
The cold load pick-up function is used for detecting so-called cold load situations, where a loss of load
diversity has occured after distribution has been re-energized. The characteristics of cold load
situations vary according to the types of loads individual feeders have. This means that the this function
needs to be set specifically according to the load type of the feeder it is monitoring. For example, in
residential areas there are relatively many thermostat-controlled devices (such as heating and cooling
machinery) which normally run in asynchronous cycles. When restoring power after a longer power
outage, these devices demand the full start-up power which can cause the inrush current to be
significantly higher than what the load current was before the outage. This is uncommon in industrial
environments since the restoring of the production process takes several hours, or even days, and the
power level goes back to the level it was before the outage. However, some areas of the industrial
network may find the cold load pick-up function useful.
8.5 Switch-on-to-fault (SOTF)
The switch-on-to-fault (SOTF) function is used for speeding up the tripping when the breaker is closed
towards a fault or forgotten earthing to reduce the damage in the fault location. The function can be
used to control protection functions, or it can be used to directly trip a breaker if any of the connected
protection functions starts during the set SOTF time.
8.6 Synchrocheck (ΔV/Δa/Δf; 25)
Checking the synchronization is important to ensure the safe closing of the circuit breaker between two
systems. Closing the circuit breaker when the systems are not synchronized can cause several
problems such as current surges which damage the interconnecting elements.
8.7 Vector jump (78)
Distribution systems may include different kinds of distributed power generation sources, such as wind
farms and diesel or fuel generators. When a fault occurs in the distribution system, it is usually detected
and isolated by the protection system closest to the faulty point, resulting in the electrical power system
shutting dow either partially or completely. The remaining distributed generators try to deliver the
power to the part of the distribution system that has been disconnected from the grid, and usually an
overload condition can be expected. Under such overload conditions, it is normal to have a drop in
voltage and frequency. This overload results in the final system disconnection from the islanding
generator(s). The disconnection depends greatly on the ratio between the power generation and the
demand of the islanded system. When any power is supplied to a load only from distributed generators,
(due to the opening of the main switch), the situation is called an isolated island operation or an
islanded operation of the electrical distribution network.
The vector jump control function is suitable to detect most islanding situations and to switch off the
mains breaker in order to let the generator only supply loads according to their rated power value.
Therefore, an overload does not cause any mechanical stress to the generator unit(s). The vector jump
relay should be located either on the mains side of the operated breaker or on the islanding generator
side.
The vector jump function is used for instant tripping and has only one operating stage. The function has
an algorithm which follows the samples of chosen measured voltages (64 samples/cycle). The
reference voltage used can be all or any of the phase-to-phase or phase-to-neutral voltages.
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9 AQ-200 Monitoring functions
9.1 Current transformer supervision
The current transformer supervision function (abbreviated CTS in this document) is used for monitoring
the CTs as well as the wirings between the device and the CT inputs for malfunctions and wire breaks.
An open CT circuit can generate dangerously high voltages into the CT secondary side, and
cause unintended activations of current balance monitoring functions.
9.2 Voltage transformer supervision (60)
Voltage transformer supervision is used to detect errors in the secondary circuit of the voltage
transformer during fuse failure. This signal is mostly used as an alarming function or to disable
functions that require adequate voltage measurement.
9.3 Disturbance recorder (DR)
The disturbance recorder is a high-capacity (64 MB) and fully digital recorder integrated to the
protection relay. The maximum sample rate of the recorder's analog channels is 64 samples per cycle.
The recorder also supports 95 digital channels simultaneously with the twenty (20) measured analog
channels.
The recorder provides a great tool to analyze the performance of the power system during network
disturbance situations. The recorder's output is in general COMTRADE format and it is compatible with
most viewers and injection devices. The files are based on the IEEE standard C37.111-1999. Captured
recordings can be injected as playback with secondary testing tools that support the COMTRADE file
format. Playback of files might help to analyze the fault, or can be simply used for educational
purposes.
9.4 Circuit breaker wear
The circuit breaker wear function is used for monitoring the circuit breaker's lifetime and its
maintenance needs caused by interrupting currents and mechanical wear. The function uses the circuit
breaker's manufacturer-supplied data for the breaker operating cycles in relation to the interrupted
current magnitudes. The function is integrated into the object control function and can be enabled and
set under that function's settings. However, the circuit breaker wear function is an independent function
and it initializes as an independent instance which has its own events and settings not related to the
object it is linked to.
9.5 Fault locator (21FL)
The fault locator function is used for recording an estimated distance to the point where a fault has
occurred. It is mostly used in directional overcurrent protection or distance protection applications but
can be also triggered by other protections. The function can be used if all three phase currents and
three phase voltages have been connected to the relay. The triggering signals, the triggering current
and "Reactance per km" must be set in the configuration.
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10 Dimensions and installation
The device can be installed either to a standard 19” rack or to a switchgear panel with cutouts. The
desired installation type is defined in the order code. When installing to a rack, the device takes a half
(½) of the rack's width, meaning that a total of two devices can be installed to the same rack next to
one another.
The figures below describe the device dimensions (first figure), the device installation (second), and the
panel cutout dimensions and device spacing (third).
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11 Technical data
11.1 Current measurement
Connections
Measurement
channels/CT inputs
Three phase current inputs: IL1 (A), IL2 (B), IL3 (C)
Two residual current inputs: Coarse residual current input I01,
Fine residual current input I02
Phase current inputs (A, B, C)
Sample rate
64 samples per cycle in frequency range 6...75Hz
Rated current IN
5 A (configurable 0.2…10 A)
30 A (continuous)
Thermal withstand
100 A (for 10 s)
500 A (for 1 s)
1250 A (for 0.01 s)
Frequency
measurement range
From 6…75Hz fundamental, up to the 31st harmonic current
Current measurement
range
25 mA…250 A (RMS)
0.005…4.000 × IN < ±0.5 % or < ±15 mA
Current measurement
inaccuracy
4…20 × IN < ±0.5 %
20…50 × IN < ±1.0 %
Angle measurement
inaccuracy
< ±0.2° (I> 0.1 A)
< ±1.0° (I≤ 0.1 A)
Burden (50/60 Hz)
<0.1 VA
Transient overreach
<8 %
Coarse residual current input (I01)
Rated current IN
1 A (configurable 0.1…10 A)
25 A (continuous)
Thermal withstand
100 A (for 10 s)
500 A (for 1 s)
1250 A (for 0.01 s)
Frequency
measurement range
From 6…75 Hz fundamental, up to the 31st harmonic current
Current measurement
range
5 mA…150 A (RMS)
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Current measurement
inaccuracy
Angle measurement
inaccuracy
0.002…10.000 × IN < ±0.5 % or < ±3 mA
10…150 × IN < ±0.5 %
< ±0.2° (I> 0.05 A)
< ±1.0° (I≤ 0.05 A)
Burden (50/60Hz)
<0.1 VA
Transient overreach
<5 %
Fine residual current input (I02)
Rated current IN
0.2 A (configurable 0.001…10 A)
25 A (continuous)
Thermal withstand
100 A (for 10 s)
500 A (for 1 s)
1250 A (for 0.01 s)
Frequency
measurement range
From 6…75 Hz fundamental, up to the 31st harmonic current
Current measurement
range
1 mA…75 A (RMS)
Current measurement
inaccuracy
Angle measurement
inaccuracy
0.002…25.000 × IN < ±0.5 % or < ±0.6 mA
25…375 × IN < ±1.0 %
< ±0.2° (I> 0.01 A)
< ±1.0° (I≤ 0.01 A)
Burden (50/60Hz)
<0.1 VA
Transient overreach
<5 %
Terminal block connection
Terminal block
Phoenix Contact FRONT 4-H-6,35
Solid or stranded wire
Maximum wire
diameter
4 mm2
NO
NOTE!
TE!
Current measurement accuracy has been verified with 50/60 Hz.
The amplitude difference is 0.2 % and the angle difference is 0.5 degrees higher at 16.67 Hz and other
frequencies.
11.2 Voltage measurement
Connection
Measurement channels/VT inputs
4 independent VT inputs (U1, U2, U3 and U4)
Measurement
30
© Arcteq Relays Ltd
MM00003
AQ -F255
Data sheet
Version: 1.00
Sample rate
64 samples per cycle in frequency range 6...75Hz
Voltage measuring range
0.50…480.00 V (RMS)
1…2 V ±1.5 %
Voltage measurement inaccuracy
2…10 V ±0.5 %
10…480 V ±0.35 %
±0.2 degrees (15…300 V)
Angle measurement inaccuracy
±1.5 degrees (1…15 V)
7…75 Hz fundamental, up to the 31st harmonic
voltage
Voltage measurement bandwidth
(freq.)
Terminal block connection
Terminal block
Phoenix Contact PC 5/8-STCL1-7.62
Solid or stranded wire
Maximum wire diameter
6 mm2
Input impedance
24.5…24.6 MΩ
Burder (50/60 Hz)
<0.02 VA
Thermal withstand
630 VRMS (continuous)
NO
NOTE!
TE!
Voltage measurement accuracy has been verified with 50/60 Hz.
The amplitude difference is 0.2 % and the angle difference is 0.5 degrees higher at 16.67 Hz and other
frequencies.
11.3 Power and energy measurement
Power measurement P, Q,
S
Inaccuracy
Energy measurement
Energy and power metering
inaccuracy
Frequency range 6…75 Hz
0.3 % <1.2 × IN or 3 VA secondary
1.0 % >1.2 × IN or 3 VA secondary
Frequency range 6…75 Hz
0.5% down to 1A RMS (50/60Hz) as standard
0.2% down to 1A RMS (50/60Hz) option available (see the
order code for details)
11.4 Frequency measurement
Frequency measurement performance
Frequency measuring
range
6…75 Hz fundamental, up to the 31st harmonic current or
voltage
Inaccuracy
10 mHz
© Arcteq Relays Ltd
MM00003
31
AQ -F255
Data sheet
Version: 1.00
11.5 Auxiliary voltage
Rated values
Rated auxiliary voltage
85…265 V (AC/DC)
< 20 W
Power consumption
< 40 W
Maximum permitted interrupt time
< 40 ms with 110 VDC
DC ripple
< 15 %
Terminal block connection
Terminal block
Phoenix Contact MSTB 2,5/5-ST-5,08
Solid or stranded wire
2.5 mm2
Maximum wire diameter
Rated values
Rated auxiliary voltage
18…72 VDC
< 20 W
Power consumption
< 40 W
Maximum permitted interrupt time
< 40 ms with 24 VDC
DC ripple
< 15 %
Terminal block connection
Terminal block
Phoenix Contact MSTB 2,5/5-ST-5,08
Solid or stranded wire
2.5 mm2
Maximum wire diameter
11.6 CPU communication ports
Port
Port media
Copper Ethernet RJ-45
Number of ports
1
PC-protocols
Port protocols
FTP
Telnet
Features
Data transfer rate
100 MB
System integration
Cannot be used for system protocols, only for local programming
Port
32
© Arcteq Relays Ltd
MM00003
AQ -F255
Data sheet
Version: 1.00
Port media
Copper Ethernet RJ-45
Number of ports
1
Features
IEC 61850
IEC 104
Port protocols
Modbus/TCP
DNP3
FTP
Telnet
Data transfer rate
100 MB
System integration
Can be used for system protocols and for local programming
Port
Port media
Copper RS-485
Number of ports
1
Features
Modbus/RTU
IEC 103
Port protocols
IEC 101
DNP3
SPA
Data transfer rate
65 580 kB/s
System integration
Can be used for system protocols
11.7 CPU digital inputs
Rated values
Rated auxiliary voltage
265 V (AC/DC)
Nominal voltage
Order code defined: 24, 110, 220 V (AC/DC)
Pick-up threshold
Release threshold
Order code defined: 19, 90,170 V
Order code defined: 14, 65, 132 V
Scanning rate
5 ms
Settings
Pick-up delay
Software settable: 0…1800 s
Polarity
Software settable: Normally On/Normally Off
Current drain
2 mA
Terminal block connection
© Arcteq Relays Ltd
MM00003
33
AQ -F255
Data sheet
Version: 1.00
Terminal block
Phoenix Contact MSTB 2,5/5-ST-5,08
Solid or stranded wire
Maximum wire diameter
2.5 mm2
11.8 CPU digital outputs
Rated values
Rated auxiliary voltage
265 V (AC/DC)
Continuous carry
5A
Make and carry 0.5 s
Make and carry 3 s
30 A
15 A
Breaking capacity, DC (L/R = 40 ms)
at 48 VDC
at 110 VDC
at 220 VDC
1A
0.4 A
0.2 A
Control rate
5 ms
Settings
Polarity
Software settable: Normally On/Normally Off
Terminal block connection
Terminal block
Phoenix Contact MSTB 2,5/5-ST-5,08
Solid or stranded wire
Maximum wire diameter
2.5 mm2
Rated values
Rated auxiliary voltage
265 V (AC/DC)
Continuous carry
5A
Make and carry 0.5 s
Make and carry 3 s
30 A
15 A
Breaking capacity, DC (L/R = 40 ms)
at 48 VDC
at 110 VDC
at 220 VDC
1A
0.4 A
0.2 A
Control rate
5 ms
Settings
Polarity
Software settable: Normally On/Normally Off
Terminal block connection
34
Terminal block
Phoenix Contact MSTB 2,5/5-ST-5,08
Solid or stranded wire
Maximum wire diameter
2.5 mm2
© Arcteq Relays Ltd
MM00003
AQ -F255
Data sheet
Version: 1.00
11.9 Digital input module
Rated values
Rated auxiliary voltage
5…265 V (AC/DC)
Current drain
2 mA
Scanning rate
Activation/release delay
5 ms
5...11 ms
Settings
Pick-up threshold
Release threshold
Software settable: 16…200 V, setting step 1 V
Software settable: 10…200 V, setting step 1 V
Pick-up delay
Software settable: 0…1800 s
Drop-off delay
Software settable: 0…1800 s
Polarity
Software settable: Normally On/Normally Off
Terminal block connection
Terminal block
Phoenix Contact MSTB 2,5/5-ST-5,08
Solid or stranded wire
Maximum wire diameter
2.5 mm2
11.10 Digital output module
Rated values
Rated auxiliary voltage
265 V (AC/DC)
Continuous carry
5A
Make and carry 0.5 s
Make and carry 3 s
30 A
15 A
Breaking capacity, DC (L/R = 40 ms)
at 48 VDC
at 110 VDC
at 220 VDC
1A
0.4 A
0.2 A
Control rate
5 ms
Settings
Polarity
Software settable: Normally On/Normally Off
Terminal block connection
Terminal block
Phoenix Contact MSTB 2,5/5-ST-5,08
Solid or stranded wire
Maximum wire diameter
2.5 mm2
11.11 Arc protection module
Connections
Input arc point sensor channels
© Arcteq Relays Ltd
MM00003
S1, S2, S3, S4 (pressure and light, or light only)
35
AQ -F255
Data sheet
Version: 1.00
Sensors per channel
3
Performance
Pick-up light intensity
8, 25 or 50 kLx (the sensor is selectable in the
order code)
Inaccuracy:
- Point sensor detection radius
180 degrees
Start and instant operating time
(light only)
Typically <5 ms (dedicated semiconductor outputs)
Typically <10 ms (regular output relays)
Rated values
Rated auxiliary voltage
250 VDC
Continuous carry
2A
Make and carry 0.5 s
Make and carry 3 s
15 A
6A
Breaking capacity, DC (L/R = 40 ms)
1 A/110 W
Control rate
5 ms
Operation delay
<1 ms
Polarity
Normally Off
Contact material
Semiconductor
Terminal block connection
Terminal block
Phoenix Contact MSTB 2,5/5-ST-5,08
Solid or stranded wire
2.5 mm2
Maximum wire diameter
Rated values
Voltage withstand
265 VDC
Rated auxiliary voltage
Pick-up threshold
Release threshold
24 VDC
≥16 VDC
≤15 VDC
Scanning rate
5 ms
Polarity
Normally Off
Current drain
3 mA
Terminal block connection
Terminal block
Phoenix Contact MSTB 2,5/5-ST-5,08
Solid or stranded wire
Maximum wire diameter
2.5 mm2
NO
NOTE!
TE! Polarity has to be correct.
36
© Arcteq Relays Ltd
MM00003
AQ -F255
Data sheet
Version: 1.00
11.12 Milliampere module (mA out & mA in)
Signals
Output magnitudes
4 × mA output signal (DC)
Input magnitudes
1 × mA input signal (DC)
mA input
Range (hardware)
0...33 mA
Range (measurement)
0...24 mA
Inaccuracy
±0.1 mA
Update cycle
5...10 000 ms, setting step 5 ms
Response time @ 5 ms cycle
~ 15 ms (13...18 ms)
Update cycle time inaccuracy
Max. +20 ms above the set cycle
mA input scaling range
Output scaling range
0...4000 mA
-1 000 000.0000…1 000 000.0000, setting step
0.0001
mA output
Inaccuracy @ 0...24 mA
±0.01 mA
Response time @ 5 ms cycle
[fixed]
< 5 ms
mA output scaling range
Source signal scaling range
0...24 mA, setting step 0.001 mA
-1 000 000.000…1 000 000.0000, setting step
0.0001
11.13 RTD input module
Channels 1-8
2/3/4-wire RTD and thermocouple sensors
Pt100 or Pt1000
Type K, Type J, Type T and Type S
Channels 7 & 8 support mA measurement
11.14 RS-232 & serial fiber communication module
Ports
RS-232
Serial fiber (GG/PP/GP/PG)
Serial port wavelength
660 nm
Cable type
© Arcteq Relays Ltd
MM00003
37
AQ -F255
Data sheet
Version: 1.00
1 mm plastic fiber
11.15 Double LC 100 Mbps Ethernet communication module
Protocols
Protocols
HSR and PRP
Ports
Quantity of fiber ports
2
Communication port C & D
LC fiber connector
Wavelength 1300 nm
Fiber cable
50/125 μm or 62.5/125 μm multimode (glass)
11.16 CPU & Power supply
11.17 Display
Dimensions and resolution
Number of dots/resolution
800 x 480
Size
154.08 × 85.92 mm (6.06 × 3.38 in)
Display
Type of display
TFT
Color
RGB color
11.18 Tests and environmental
Electrical environment compatibility
All tests
CE-approved and tested according to EN 60255-26
Emissions
Conducted emissions:
EN 60255-26 Ch. 5.2, CISPR 22
Radiated emissions:
150 kHz…30 MHz
30…1 000 MHz
EN 60255-26 Ch. 5.1, CISPR 11
Immunity
38
Electrostatic discharge (ESD):
Air discharge 15 kV
EN 60255-26, IEC 61000-4-2
Contact discharge 8 kV
Electrical fast transients (EFT):
Power supply input 4 kV, 5/50 ns, 5 kHz
EN 60255-26, IEC 61000-4-4
Other inputs and outputs 4 kV, 5/50 ns, 5 kHz
© Arcteq Relays Ltd
MM00003
AQ -F255
Data sheet
Version: 1.00
Surge:
Between wires: 2 kV, 1.2/50 µs
EN 60255-26, IEC 61000-4-5
Between wire and earth: 4 kV, 1.2/50 µs
Radiated RF electromagnetic field:
f = 80…1 000 MHz, 10 V/m
EN 60255-26, IEC 61000-4-3
Conducted RF field:
f = 150 kHz…80 MHz, 10 V (RMS)
EN 60255-26, IEC 61000-4-6
Dielectric voltage test
EN 60255-27, IEC 60255-5, EN 60255-1
2 kV, 50 Hz, 1 min
Impulse voltage test
EN 60255-27, IEC 60255-5
5 kV, 1.2/50 µs, 0.5 J
Physical environment compatibility
Vibration test
EN 60255-1, EN 60255-27, IEC 60255-21-1
2…13.2 Hz, ± 3.5 mm
13.2…100 Hz, ± 1.0 g
Shock and bump test
EN 60255-1, EN 60255-27, IEC 60255-21-2
20 g, 1 000 bumps/dir.
Damp heat (cyclic)
EN 60255-1, IEC 60068-2-30
Operational: +25…+55 °C, 93…97 % (RH), 12+12h
Dry heat
EN 60255-1, IEC 60068-2-2
Storage: +70 °C, 16 h
Operational: +55 °C, 16 h
Cold test
EN 60255-1, IEC 60068-2-1
Storage: –40 °C, 16 h
Operational: –20 °C, 16 h
IP classes
Casing protection class
IP54 (front)
IP21 (rear)
Temperature ranges
Ambient service temperature range
–35…+70 °C
Transport and storage temperature range
–40…+70 °C
Other
© Arcteq Relays Ltd
MM00003
39
AQ -F255
Data sheet
Version: 1.00
Altitude
<2000 m
Overvoltage category
III
Pollution degree
2
Casing and package
Without packaging (net)
Dimensions
Height: 208 mm
Width: 257 mm (½ rack)
Depth: 165 mm (no cards or connectors)
Weight
1.5 kg
With packaging (gross)
Dimensions
Weight
Height: 250 mm
Width: 343 mm
Depth: 256 mm
2.0 kg
11.19 Protection functions
Non-dir
Non-directional
ectional o
ovver
ercurr
current
ent pr
pro
otection (I>; 50/51)
Measurement inputs
Current inputs
Phase current inputs: IL1 (A), IL2 (B), IL3 (C)
Current input magnitudes
RMS phase currents
TRMS phase currents
Peak-to-peak phase currents
Pick-up
Pick-up current setting
0.10…50.00 × In, setting step 0.01 × In
Inrush 2nd harmonic blocking
0.10…50.00 %Ifund, setting step 0.01
%Ifund
Inaccuracy:
- Current
-2
nd
harmonic blocking
±0.5 %Iset or ±15 mA (0.10…4.0 × Iset)
±1.0 %-unit of the 2nd harmonic setting
Operation time
Definite time function operating time
setting
40
0.00…1800.00 s, setting step 0.005 s
Inaccuracy:
- Definite time: Im/Iset ratio > 3
- Definite time: Im/Iset ratio = 1.05…3
±1.0 % or ±20 ms
±1.0 % or ±30 ms
IDMT setting parameters:
- k Time dial setting for IDMT
- A IDMT constant
- B IDMT constant
- C IDMT constant
0.01…25.00, step 0.01
0…250.0000, step 0.0001
0…5.0000, step 0.0001
0…250.0000, step 0.0001
© Arcteq Relays Ltd
MM00003
AQ -F255
Data sheet
Version: 1.00
Inaccuracy:
- IDMT operating time
- IDMT minimum operating time
±1.5 % or ±20 ms
±20 ms
Retardation time (overshoot)
<30 ms
Instant operation time
Start time and instant operation time (trip):
- Im/Iset ratio > 3
- Im/Iset ratio = 1.05…3
<35 ms (typically 25 ms)
<50 ms
Reset
Reset ratio
97 % of the pick-up current setting
Reset time setting
Inaccuracy: Reset time
0.010…10.000 s, step 0.005 s
±1.0 % or ±50 ms
Instant reset time and start-up reset
<50 ms
No
Notte!
• The release delay does not apply to phase-specific tripping.
Non-dir
Non-directional
ectional ear
earth
th fa
fault
ult pr
pro
otection (I0>; 50N/51N)
Measurement inputs
Current input (selectable)
Residual current channel I01 (Coarse)
Residual current channel I02 (Fine)
Calculated residual current: IL1 (A), IL2 (B), IL3
(C)
Current input magnitudes
RMS residual current (I01, I02 or calculated I0)
TRMS residual current (I01 or I02)
Peak-to-peak residual current (I01 or I02)
Pick-up
Used magnitude
Measured residual current I01 (1 A)
Measured residual current I02 (0.2 A)
Calculated residual current I0Calc (5 A)
Pick-up current setting
0.0001…40.00 × In, setting step 0.0001 × In
Inaccuracy:
- Starting I01 (1 A)
- Starting I02 (0.2 A)
- Starting I0Calc (5 A)
±0.5 %I0set or ±3 mA (0.005…10.0 × Iset)
±1.5 %I0set or ±1.0 mA (0.005…25.0 × Iset)
±1.0 %I0set or ±15 mA (0.005…4.0 × Iset)
Operating time
Definite time function operating time
setting
0.00…1800.00 s, setting step 0.005 s
Inaccuracy:
- Definite time: Im/Iset ratio > 3
- Definite time: Im/Iset ratio = 1.05…3
±1.0 % or ±20 ms
±1.0 % or ±30 ms
IDMT setting parameters:
- k Time dial setting for IDMT
- A IDMT constant
- B IDMT constant
- C IDMT constant
0.01…25.00, step 0.01
0…250.0000, step 0.0001
0…5.0000, step 0.0001
0…250.0000, step 0.0001
© Arcteq Relays Ltd
MM00003
41
AQ -F255
Data sheet
Version: 1.00
Inaccuracy:
- IDMT operating time
- IDMT minimum operating time
±1.5 % or ±20 ms
±20 ms
Retardation time (overshoot)
<30 ms
Instant operation time
Start time and instant operation time
(trip):
- Im/Iset ratio > 3.5
- Im/Iset ratio = 1.05…3.5
<50 ms (typically 35 ms)
<55 ms
Reset
Reset ratio
97 % of the pick-up current setting
Reset time setting
Inaccuracy: Reset time
0.010…10.000 s, step 0.005 s
±1.0 % or ±50 ms
Instant reset time and start-up reset
<50 ms
No
Notte!
• The operation and reset time accuracy does not apply when the measured secondary
current in I02 is 1…20 mA. The pick-up is tuned to be more sensitive and the operation times
vary because of this.
Dir
irectional
ectional o
ovver
ercurr
current
ent pr
pro
otection (Idir>; 67)
Input signals
Current inputs
Phase current inputs: IL1 (A), IL2 (B), IL3 (C)
Current input magnitudes
RMS phase currents
TRMS phase currents
Peak-to-peak phase currents
Current input calculations
Positive sequence current angle
Voltage inputs
UL1, UL2, UL3
UL12, UL23, UL31 + U0
Voltage input calculations
Positive sequence voltage angle
Pick-up
Characteristic direction
Directional, non-directional
Operating sector center
-180.0…180.0 deg, setting step 0.1 deg
Operating sector size (+/-)
1.00…170.00 deg, setting step 0.10 deg
Pick-up current setting
0.10…40.00 × In, setting step 0.01 × In
Inaccuracy:
- Current
- U1/I1 angle (U > 15 V)
- U1/I1 angle (U = 1…15 V)
±0.5 %Iset or ±15 mA (0.10…4.0 × Iset)
±0.20°
±1.5°
Operation time
42
Definite time function operating time setting
0.00…1800.00 s, setting step 0.005 s
Inaccuracy:
- Definite time: Im/Iset ratio > 3
- Definite time: Im/Iset ratio = 1.05…3
±1.0 % or ±20 ms
±1.0 % or ±35 ms
© Arcteq Relays Ltd
MM00003
AQ -F255
Data sheet
Version: 1.00
IDMT setting parameters:
- k Time dial setting for IDMT
- A IDMT constant
- B IDMT constant
- C IDMT constant
0.01…25.00, step 0.01
0…250.0000, step 0.0001
0…5.0000, step 0.0001
0…250.0000, step 0.0001
Inaccuracy:
- IDMT operating time
- IDMT minimum operating time
±1.5 % or ±20 ms
±20 ms
Instant operation time
Start time and instant operation time (trip):
- Im/Iset ratio > 3
- Im/Iset ratio = 1.05…3
<40 ms (typically 30 ms)
<50 ms
Reset
Reset ratio:
- Current
- U1/I1 angle
97 % of the pick-up current setting
2.0°
Reset time setting
Inaccuracy: Reset time
0.010…10.000 s, step 0.005 s
±1.0 % or ±50 ms
Instant reset time and start-up reset
<50 ms
No
Notte!
• The minimum voltage for direction solving is 1.0 V secondary. During three-phase shortcircuits the angle memory is active for 0.5 seconds in case the voltage drops below 1.0 V.
Dir
irectional
ectional ear
earth
th fa
fault
ult pr
pro
otection (I0dir>; 67N/32N)
Measurement inputs
Current input (selectable)
Residual current channel I01 (Coarse)
Residual current channel I02 (Fine)
Calculated residual current: IL1 (A), IL2 (B), IL3
(C)
Current input magnitudes
RMS residual current (I01, I02 or calculated I0)
TRMS residual current (I01 or I02)
Peak-to-peak residual current (I01 or I02)
Voltage input (selectable)
Residual voltage from U3 or U4 voltage
channel
Residual voltage calculated from UL1, UL2, UL3
Voltage input magnitudes
RMS residual voltage U0
Calculated RMS residual voltage U0
Pick-up
Characteristic direction
Unearthed (Varmetric 90°)
Petersen coil GND (Wattmetric 180°)
Earthed (Adjustable sector)
When the earthed mode is active:
- Tripping area center
- Tripping area size (+/-)
0.00…360.00 deg, setting step 0.10 deg
45.00…135.00 deg, setting step 0.10 deg
Pick-up current setting
Pick-up voltage setting
0.005…40.00 × In, setting step 0.001 × In
1.00…75.00 %U0n, setting step 0.01 %U0n
© Arcteq Relays Ltd
MM00003
43
AQ -F255
Data sheet
Version: 1.00
Inaccuracy:
- Starting I01 (1 A)
- Starting I02 (0.2 A)
- Starting I0Calc (5 A)
- Voltage U0 and U0Calc
- U0/I0 angle (U > 15 V)
- U0/I0 angle (U = 1…15 V)
±0.5 %I0set or ±3 mA (0.005…10.0 × Iset)
±1.5 %I0set or ±1.0 mA (0.005…25.0 × Iset)
±1.5 %I0set or ±15 mA (0.005…4.0 × Iset)
±1.0 %U0set or ±30 mV
±0.2° (I0Calc ±1.0°)
±1.0°
Operation time
Definite time function operating time
setting
0.00…1800.00 s, setting step 0.005 s
Inaccuracy:
- Definite time (Im/Iset ratio 1.05→)
IDMT setting parameters:
- k Time dial setting for IDMT
- A IDMT constant
- B IDMT constant
- C IDMT constant
±1.0 % or ±45 ms
0.01…25.00, step 0.01
0…250.0000, step 0.0001
0…5.0000, step 0.0001
0…250.0000, step 0.0001
Inaccuracy:
- IDMT operating time
- IDMT minimum operating time
±1.5 % or ±25 ms
±20 ms
Instant operation time
Start time and instant operation time
(trip):
- Im/Iset ratio > 3
- Im/Iset ratio = 1.05…3
<55 ms (typically 45 ms)
<65 ms
Reset
Current and voltage reset
U0/I0 angle
97 % of the pick-up current and voltage
setting
2.0°
Reset time setting
Inaccuracy: Reset time
0.000…150.000 s, step 0.005 s
±1.0 % or ±45 ms
Instant reset time and start-up reset
<50 ms
Int
Intermit
ermitttent ear
earth
th fa
fault
ult pr
pro
otection (I0int>; 67NT
67NT))
Measurement inputs
Current inputs (selectable)
Residual current channel I01 (Coarse)
Residual current channel I02 (Fine)
Current input magnitudes
Residual current samples
Voltage inputs (selectable)
Residual voltage from U3 or U4 voltage
channel
Voltage input magnitude
Zero sequence voltage samples
Pick-up settings
44
Spikes to trip
1…50, setting step 1
Pick-up current setting
Pick-up voltage setting
0.05…40.00 × In, setting step 0.001 × In
1.00…100.00 %U0n, setting step 0.01 %U0n
© Arcteq Relays Ltd
MM00003
AQ -F255
Data sheet
Version: 1.00
Pick-up inaccuracy
Starting I01 (1 A)
Starting I02 (0.2 A)
Voltage U0
±0.5 %I0set or ±3 mA (0.005…10.0 x Iset)
±1.5 %I0set or ±1.0 mA (0.005…25.0 x Iset)
±1.0 %U0set or ±30 mV
Operation time setting
Definite time function operating time
setting
0.00…1800.00 s, setting step 0.005 s
Operation time inaccuracy
Definite time: Im/Iset ratio 1.05→
±1.0 % or ±30 ms
Instant operation time
Start time and instant operation time
(trip):
- Im/Iset ratio 1.05→
<15 ms
Reset time
Reset time setting (FWD and REV)
Inaccuracy: Reset time
0.000…1800.000 s, step 0.005 s
±1.0 % or ±35 ms
Instant reset time and start-up reset
<50 ms
Nega
Negativ
tive
e sequence o
ovver
ercurr
current/
ent/ pha
phase
se curr
current
ent rre
eversal/ curr
current
ent unbalance
pr
pro
otection (I2>; 46/46R/46L)
Measurement inputs
Current inputs
Phase current inputs: IL1 (A), IL2 (B), IL3
(C)
Current input calculations
Positive sequence current (I1)
Negative sequence current (I2)
Pick-up
Used magnitude
Negative sequence component I2pu
Relative unbalance I2/I1
Pick-up setting
0.01…40.00 × In, setting step 0.01 × In
(I2pu)
1.00…200.00 %, setting step 0.01 % (I2/
I1)
Minimum phase current (at least one phase
above)
0.01…2.00 × In, setting step 0.01 × In
Inaccuracy:
- Starting I2pu
- Starting I2/I1
±1.0 %-unit or ±100 mA (0.10…4.0 × In)
±1.0 %-unit or ±100 mA (0.10…4.0 × In)
Operating time
Definite time function operating time setting
0.00…1800.00 s, setting step 0.005 s
Inaccuracy:
- Definite time (Im/Iset ratio > 1.05)
±1.5 % or ±60 ms
© Arcteq Relays Ltd
MM00003
45
AQ -F255
Data sheet
Version: 1.00
IDMT setting parameters:
- k Time dial setting for IDMT
- A IDMT Constant
- B IDMT Constant
- C IDMT Constant
0.01…25.00, step 0.01
0…250.0000, step 0.0001
0…5.0000, step 0.0001
0…250.0000, step 0.0001
Inaccuracy:
- IDMT operating time
- IDMT minimum operating time
±2.0 % or ±30 ms
±20 ms
Retardation time (overshoot)
<5 ms
Instant operation time
Start time and instant operation time (trip):
- Im/Iset ratio > 1.05
<70 ms
Reset
Reset ratio
97 % of the pick-up setting
Reset time setting
Inaccuracy: Reset time
0.010…10.000 s, step 0.005 s
±1.5 % or ±60 ms
Instant reset time and start-up reset
<55 ms
Harmonic o
ovver
ercurr
current
ent pr
pro
otection (Ih>; 50H/51H/68H)
Measurement inputs
Current inputs
Phase current inputs: IL1 (A), IL2 (B), IL3 (C)
Residual current channel I01 (Coarse)
Residual current channel I02 (Fine)
Pick-up
Harmonic selection
2nd, 3rd, 4th, 5th, 6th 7th, 9th, 11th, 13th, 15th, 17th
or 19th
Used magnitude
Harmonic per unit (× IN)
Harmonic relative (Ih/IL)
Pick-up setting
0.05…2.00 × IN, setting step 0.01 × IN (× IN)
5.00…200.00 %, setting step 0.01 % (Ih/IL)
Inaccuracy:
- Starting × IN
- Starting × Ih/IL
<0.03 × IN (2nd, 3rd, 5th)
<0.03 × IN tolerance to Ih (2nd, 3rd, 5th)
Operation time
Definite time function operating time
setting
46
0.00…1800.00 s, setting step 0.005 s
Inaccuracy:
- Definite time (IM/ISET ratio >1.05)
±1.0 % or ±35 ms
IDMT setting parameters:
k Time dial setting for IDMT
A IDMT constant
B IDMT constant
C IDMT constant
0.01…25.00, step 0.01
0…250.0000, step 0.0001
0…5.0000, step 0.0001
0…250.0000, step 0.0001
Inaccuracy:
- IDMT operating time
- IDMT minimum operating time
±1.5 % or ±20 ms
±20 ms
© Arcteq Relays Ltd
MM00003
AQ -F255
Data sheet
Version: 1.00
Instant operation time
Start time and instant operation time
(trip):
IM/ISET ratio >1.05
<50 ms
Reset
Reset ratio
95 % of the pick-up setting
Reset time setting
Inaccuracy: Reset time
0.010…10.000 s, step 0.005 s
±1.0 % or ±35 ms
Instant reset time and start-up reset
<50 ms
No
Notte!
• Harmonics generally: The amplitude of the harmonic content has to be least 0.02 × IN when
the relative mode (Ih/IL) is used.
• Blocking: To achieve fast activation for blocking purposes with the harmonic
overcurrent stage, note that the harmonic stage may be activated by a rapid load change or
fault situation. An intentional activation lasts for approximately 20 ms if a harmonic
component is not present. The harmonic stage stays active if the harmonic content is above
the pick-up limit.
• Tripping: When using the harmonic overcurrent stage for tripping, please ensure that the
operation time is set to 20 ms (DT) or longer to avoid nuisance tripping caused by the abovementioned reasons.
Cir
Circuit
cuit br
break
eaker
er fail
failur
ure
e pr
pro
otection (CBFP; 50BF/52BF
50BF/52BF))
Measurement inputs
Current inputs
Phase current inputs: IL1 (A), IL2 (B), IL3 (C)
Residual current channel I01 (Coarse)
Residual current channel I02 (Fine)
Current input magnitudes
RMS phase currents
RMS residual current (I01, I02 or calculated I0)
Pick-up
Monitored signals
Digital input status, digital output status, logical
signals
Pick-up current setting:
- IL1…IL3
- I01, I02, I0Calc
0.10…40.00 × IN, setting step 0.01 × IN
0.005…40.00 × IN, setting step 0.005 × IN
Inaccuracy:
- Starting phase current (5A)
- Starting I01 (1 A)
- Starting I02 (0.2 A)
- Starting I0Calc (5 A)
±0.5 %ISET or ±15 mA (0.10…4.0 × ISET)
±0.5 %I0SET or ±3 mA (0.005…10.0 × ISET)
±1.5 %I0SET or ±1.0 mA (0.005…25.0 × ISET)
±1.0 %I0SET or ±15 mA (0.005…4.0 × ISET)
Operation time
Definite time function operating time
setting
Inaccuracy:
- Current criteria (IM/ISET ratio 1.05→)
- DO or DI only
0.050…1800.000 s, setting step 0.005 s
±1.0 % or ±55 ms
±15 ms
Reset
© Arcteq Relays Ltd
MM00003
47
AQ -F255
Data sheet
Version: 1.00
Reset ratio
97 % of the pick-up current setting
Reset time
<50 ms
Low-impedance or hig
high-impedance
h-impedance rrestrict
estricted
ed ear
earth
th fa
fault/
ult/ c
cable
able end diff
differ
erential
ential
pr
pro
otection (I0d>; 87N)
Measurement inputs
Current inputs
Phase current inputs: IL1 (A), IL2 (B), IL3 (C)
Residual current channel I01 (Coarse)
Residual current channel I02 (Fine)
Current input calculations
Calculated bias and residual differential currents
Pick-up
Operating modes
Restricted earth fault
Cable end differential
Characteristics
Biased differential with 3 settable sections and 2
slopes
Pick-up current sensitivity
setting
Slope 1
Slope 2
Bias (Turnpoint 1 & 2)
0.01…50.00 % (IN), setting step 0.01 %
0.00…150.00 %, setting step 0.01 %
0.00…250.00 %, setting step 0.01 %
0.01…50.00 × IN, setting step 0.01 × IN
Inaccuracy
- Starting
±3% of the set pick-up value > 0.5 × IN setting.
±5 mA < 0.5 × IN setting
Operation time
Instant operation time
1.05 x ISET
<30 ms
Reset
Reset ratio
No hysteresis
Reset time
<40 ms
Ov
Over
ervvolta
oltage
ge pr
pro
otection (U>; 59)
Measurement inputs
Voltage inputs
UL1, UL2, UL3
UL12, UL23, UL31 (+ U0)
Voltage input magnitudes
RMS line-to-line or line-to-neutral voltages
Pick-up
Pick-up terms
1 voltage
2 voltages
3 voltages
Pick-up setting
50.00…150.00 %UN, setting step 0.01
%UN
Inaccuracy:
- Voltage
±1.5 %USET
Operating time
48
© Arcteq Relays Ltd
MM00003
AQ -F255
Data sheet
Version: 1.00
Definite time function operating time
setting
0.00…1800.00 s, setting step 0.005 s
Inaccuracy:
- Definite time (UM/USET ratio 1.05→)
±1.0 % or ±35 ms
IDMT setting parameters:
k Time dial setting for IDMT
A IDMT constant
B IDMT constant
C IDMT constant
0.01…25.00, step 0.01
0…250.0000, step 0.0001
0…5.0000, step 0.0001
0…250.0000, step 0.0001
Inaccuracy:
- IDMT operating time
- IDMT minimum operating time
±1.5 % or ±20 ms
±20 ms
Instant operation time
Start time and instant operation time (trip):
- UM/USET ratio 1.05→
<50 ms
Reset
Reset ratio
97 % of the pick-up voltage setting
Reset time setting
Inaccuracy: Reset time
0.010…10.000 s, step 0.005 s
±1.0 % or ±45 ms
Instant reset time and start-up reset
<50 ms
Under
Undervvolta
oltage
ge pr
pro
otection (U<; 27)
Measurement inputs
Voltage inputs
UL1, UL2, UL3
UL12, UL23, UL31 (+ U0)
Voltage input magnitudes
RMS line-to-line or line-to-neutral voltages
Pick-up
Pick-up terms
1 voltage
2 voltages
3 voltages
Pick-up setting
0.00…120.00 %UN, setting step 0.01 %UN
Inaccuracy:
- Voltage
±1.5 %USET or ±30 mV
Low voltage block
Pick-up setting
0.00…80.00 %UN, setting step 0.01 %UN
Inaccuracy:
- Voltage
±1.5 %USET or ±30 mV
Operation time
Definite time function operating time setting
0.00…1800.00 s, setting step 0.005 s
Inaccuracy:
- Definite time (UM/USET ratio 1.05→)
±1.0 % or ±35 ms
© Arcteq Relays Ltd
MM00003
49
AQ -F255
Data sheet
Version: 1.00
IDMT setting parameters:
k Time dial setting for IDMT
A IDMT constant
B IDMT constant
C IDMT constant
0.01…25.00, step 0.01
0…250.0000, step 0.0001
0…5.0000, step 0.0001
0…250.0000, step 0.0001
Inaccuracy:
- IDMT operating time
- IDMT minimum operating time
±1.5 % or ±20 ms
±20 ms
Instant operation time
Start time and instant operation time (trip):
- UM/USET ratio 1.05→
<65 ms
Retardation time (overshoot)
<30 ms
Reset
Reset ratio
103 % of the pick-up voltage setting
Reset time setting
Inaccuracy: Reset time
0.010…10.000 s, step 0.005 s
±1.0 % or ±45 ms
Instant reset time and start-up reset
<50 ms
No
Notte!
• The low-voltage block is not in use when its pick-up setting is set to 0 %. The undervoltage
function is in trip stage when the LV block is disabled and the device has no voltage injection.
• After the low voltage blocking condition, the undervoltage stage does not trip unless the
voltage exceeds the pick-up setting first.
Ne
Neutral
utral o
ovver
ervvolta
oltage
ge pr
pro
otection (U0>; 59N)
Measurement inputs
Voltage input (selectable)
Residual voltage from U3 or U4 voltage
channel
Residual voltage calculated from UL1, UL2,
UL3
Voltage input magnitudes
RMS residual voltage U0
Calculated RMS residual voltage U0
Pick-up
Pick-up voltage setting
1.00…50.00 % U0N, setting step 0.01 × IN
Inaccuracy:
- Voltage U0
- Voltage U0Calc
±1.5 %U0SET or ±30 mV
±150 mV
Operation time
Definite time function operating time
setting
50
0.00…1800.00 s, setting step 0.005 s
Inaccuracy:
- Definite time (U0M/U0SET ratio 1.05→)
±1.0 % or ±45 ms
IDMT setting parameters:
k Time dial setting for IDMT
A IDMT constant
B IDMT constant
C IDMT constant
0.01…25.00, step 0.01
0…250.0000, step 0.0001
0…5.0000, step 0.0001
0…250.0000, step 0.0001
© Arcteq Relays Ltd
MM00003
AQ -F255
Data sheet
Version: 1.00
Inaccuracy:
- IDMT operating time
- IDMT minimum operating time
±1.5 % or ±20 ms
±20 ms
Instant operation time
Start time and instant operation time
(trip):
- U0M/U0SET ratio 1.05→
<50 ms
Reset
Reset ratio
97 % of the pick-up voltage setting
Reset time setting
Inaccuracy: Reset time
0.000 … 150.000 s, step 0.005 s
±1.0 % or ±50 ms
Instant reset time and start-up reset
<50 ms
Sequence vvolta
oltage
ge pr
pro
otection (U1/U2>/<; 47/27P/59NP)
Measurement inputs
Voltage inputs
UL1, UL2, UL3
UL12, UL23, UL31 (+ U0)
Voltage input calculations
Positive sequence voltage (I1)
Negative sequence voltage (I2)
Pick-up
Pick-up setting
5.00…150.00 %UN, setting step 0.01 %UN
Inaccuracy:
- Voltage
±1.5 %USET or ±30 mV
Low voltage block
Pick-up setting
1.00…80.00 %UN, setting step 0.01 %UN
Inaccuracy:
-Voltage
±1.5 %USET or ±30 mV
Operation time
Definite time function operating time setting
0.00…1800.00 s, setting step 0.005 s
Inaccuracy
-Definite Time (UM/USET ratio 1.05→)
±1.0 % or ±35 ms
IDMT setting parameters:
k Time dial setting for IDMT
A IDMT constant
B IDMT constant
C IDMT constant
0.01…25.00, step 0.01
0…250.0000, step 0.0001
0…5.0000, step 0.0001
0…250.0000, step 0.0001
Inaccuracy:
- IDMT operating time
- IDMT minimum operating time
±1.5 % or ±20 ms
±20 ms
Instant operation time
Start time and instant operation time (trip):
- UM/USET ratio <0.95/1.05→
<65 ms
Reset
Reset ratio
© Arcteq Relays Ltd
MM00003
97 or 103 % of the pick-up voltage setting
51
AQ -F255
Data sheet
Version: 1.00
Reset time setting
Inaccuracy: Reset time
0.010…10.000 s, step 0.005 s
±1.0 % or ±35 ms
Instant reset time and start-up reset
<50 ms
Ov
Overfr
erfrequency
equency and underfr
underfrequency
equency pr
pro
otection ((f>/<;
f>/<; 81O/81U)
Input signals
Sampling mode
Fixed
Tracking
Frequency reference 1
Frequency reference 2
Frequency reference 3
CT1IL1, CT2IL1, VT1U1, VT2U1
CT1IL2, CT2IL2, VT1U2, VT2U2
CT1IL3, CT2IL3, VT1U3, VT2U3
Pick-up
f> pick-up setting
f< pick-up setting
Inaccuracy (sampling mode):
- Fixed
- Tracking
10.00…70.00 Hz, setting step 0.01 Hz
7.00…65.00 Hz, setting step 0.01 Hz
±20 mHz (50/60 Hz fixed frequency)
±20 mHz (U > 30 V secondary)
±20 mHz (I > 30 % of rated secondary)
Operation time
Definite time function operating time
setting
Inaccuracy:
- Definite time (IM/ISET ratio +/- 50 mHz)
0.00…1800.00 s, setting step 0.005 s
±1.5 % or ±50 ms (max. step size: 100 mHz)
Instant operation time
Start time and instant operation time
(trip):
- IM/ISET ratio +/- 50 mHz (Fixed)
- IM/ISET ratio +/- 50 mHz (Tracking)
<70 ms (max. step size: 100 mHz)
<3 cycles or <60 ms (max. step size: 100
mHz)
Reset
Reset ratio
Instant reset time and start-up reset:
- IM/ISET ratio +/- 50 mHz (Fixed)
- IM/ISET ratio +/- 50 mHz (Tracking)
0.020 Hz
<110 ms (max. step size: 100 mHz)
<3 cycles or <70 ms (max. step size: 100
mHz)
No
Notte!
• The secondary voltage must exceed 2 volts or the current must exceed 0.25 amperes (peakto peak) in order for the function to measure frequency.
• The frequency is measured two seconds after a signal is received.
• The fixed frequency mode: When the fixed mode is used, the system's nominal frequency
should be set to 50 or 60 Hz.
• The tracked frequency mode: When tracked mode is used, the system's nominal frequency
can be anything between 7...75 Hz.
Ra
Ratte -of-change of fr
frequency
equency pr
pro
otection (df/dt>/<; 81R)
Input signals
52
© Arcteq Relays Ltd
MM00003
AQ -F255
Data sheet
Version: 1.00
Sampling mode
Fixed
Tracking
Frequency reference 1
Frequency reference 2
Frequency reference 3
CT1IL1, CT2IL1, VT1U1, VT2U1
CT1IL2, CT2IL2, VT1U2, VT2U2
CT1IL3, CT2IL3, VT1U3, VT2U3
Pick-up
df/dt >/< pick-up setting
0.15…1.00 Hz/s, setting step 0.01 Hz
f> limit
10.00…70.00 Hz, setting step 0.01 Hz
f< limit
7.00…65.00 Hz, setting step 0.01 Hz
Pick-up inaccuracy
- df/dt
±5.0 %ISET or ±20 mHz/s
- frequency
±15 mHz (U > 30 V secondary)
±20 mHz (I > 30 % of rated secondary)
Operation time
Definite time function operating time
setting
0.00…1800.00 s, setting step 0.005 s
Inaccuracy:
- Definite time (IM/ISET ratio +/- 50 mHz)
±1.5 % or ±110 ms (max. step size: 100
mHz)
Start time and instant operation time (trip):
- fM/fSET ratio +/- 20 mHz (overreach)
<200 ms
- fM/fSET ratio +/- 200 mHz (overreach)
<90 ms
Reset
f< and f> frequency limit
±0.020 Hz
df/dt
±10.0 % of pick-up or 50 mHz/s
Instant reset time and start-up reset:
<325 ms (max. step size: 100 mHz)
- fM/fSET ratio +/- 50 mHz
No
Notte!
• Frequency is measured two seconds after a signal is received.
Line thermal o
ovverload pr
pro
otection (TF>; 49F
49F))
Measurement inputs
Current inputs
Phase current inputs: IL1 (A), IL2 (B), IL3 (C)
Current input magnitudes
TRMS phase currents (up to the 31st harmonic)
Settings
Time constants τ
1
Time constant value
0.0…500.00 min, step 0.1 min
Service factor
(maximum overloading)
0.01…5.00 × IN, step 0.01 × IN
© Arcteq Relays Ltd
MM00003
53
AQ -F255
Data sheet
Version: 1.00
Thermal model biasing
- Ambient temperature (Set –60.0…500.0 deg, step 0.1
deg and RTD)
- Negative sequence current
Thermal replica temperature
estimates
Selectable between °C and °F
Outputs
- Alarm 1
- Alarm 2
- Thermal trip
- Trip delay
- Restart inhibit
0…150 %, step 1 %
0…150 %, step 1 %
0…150 %, step 1 %
0.000…3600.000 s, step 0.005 s
0…150 %, step 1 %
Inaccuracy
- Starting
- Operating time
±0.5 % of the set pick-up value
±5 % or ± 500 ms
Ov
Overpo
erpow
wer (P>; 32O), underpo
underpow
wer (P<; 32U) and rre
everse po
pow
wer (P
(Prr; 32R) pr
pro
otection
Measurement inputs
Current inputs
Phase current inputs: IL1 (A), IL2 (B), IL3 (C)
Voltage inputs
UL1, UL2, UL3
UL12, UL23, UL31 (+ U0)
Calculated measurement
Three-phase active power
Pick-up
P>
Prev>
0.10…150 000.00 kW, setting step 0.01 kW
-15 000.00…-1.00 kW, setting step 0.01
kW
P<
Low-power blocking PSET<
0.00…150 000.00 kW, setting step 0.01 kW
0.00…100 000.00 kW, setting step 0.01 kW
Inaccuracy:
- Active power
Typically <1.0 %PSET
Operation time
Definite time function operating time
setting
Inaccuracy:
- Definite time (PM/PSET ratio 1.05→)
0.00…1800.00 s, setting step 0.005 s
±1.0 % or ±35 ms
Instant operation time
Start time and instant operation time (trip):
- PM/PSET ratio 1.05→
<50 ms
Reset
Reset ratio
97 or 103 %PSET
Reset time setting
Inaccuracy: Reset time
0.000…150.000 s, step 0.005 s
±1.0 % or ±35 ms
Instant reset time and start-up reset
<50 ms
No
Notte!
54
© Arcteq Relays Ltd
MM00003
AQ -F255
Data sheet
Version: 1.00
• Voltage measurement starts from 0.5 V and current measurement from 50 mA. In case either
or both are missing the power measurement is forced to 0 kW. If the settings allow it (lowpower blocking = 0 kW), the P< might be in the trip state during this condition. The trip is
released when the function begins to measure the voltage and the current again.
• When the low-power blocking is set to zero, it is not in use. Also, all power measurements
below 1.00 kW are forced to zero ("P< blocked").
Resistance ttempera
emperattur
ure
e de
dettect
ectors
ors
Inputs
Resistance input
magnitudes
Measured temperatures measured by RTD sensors
Alarm channels
12 individual alarm channels
Settable alarms
24 alarms available (two per each alarm channel)
Pick-up
Alarm setting range
Inaccuracy
Reset ratio
101.00…2000.00 deg, setting step 0.1 deg (either < or
> setting)
±3 % of the set pick-up value
97 % of the pick-up setting
Operation
Operating time
Typically <500 ms
Line diff
differ
erential
ential pr
pro
otection (Idb>/Idi>; 87L)
Measurement inputs
Current inputs
Current input magnitudes
Phase current inputs: IL1 (A), IL2 (B), IL3 (C)
Residual current channel I01 (Coarse)
Residual current channel I02 (Fine)
Calculated residual current: IL1 (A), IL2 (B), IL3 (C)
The phase currents of the local and the remote sides.
Phase currents 2nd and 5th harmonic measurement.
Characteristics (differential and REF)
Differential calculation mode
Bias calculation mode
Add or subtract (CT direction)
Average or maximum (sensitivity)
Idb> pick-up
0.01…100.00 %, step 0.01 %, default 10.00 %
Turnpoint 1
0.01…50.00 × IN, step 0.01 × IN, default 1.00 × IN
Slope 1
0.01…250.00 %, step 0.01 %, default 10.00 %
Turnpoint 2
0.01…50.00 × IN, step 0.01 × IN, default 3.00 × IN
Slope 2
0.01…250.00 %, step 0.01 %, default 200.00 %
Idi> pick-up
200.00...1500.00 %, step 0.01 %, default 600.00 %
Internal harmonic blocking
selection
None, 2nd harmonic, 5th harmonic, both 2nd and 5th
harmonic.
2nd harmonic blocking pick-up
0.01…50.00 %, step 0.01 %, default 15.00 %
5th harmonic blocking pick-up
0.01…50.00 %, step 0.01 %, default 35.00 %
© Arcteq Relays Ltd
MM00003
55
AQ -F255
Data sheet
Version: 1.00
Inaccuracy:
- Differential current
±3.0 %ISET or ±30 mA (0.10…4.0 × ISET)
Instant operation time
Instant operation time >1.05 ×
ISET
<40 ms (Harmonic blocking active)
Instant operation time >3.00 ×
ISET
<30 ms (Harmonic blocking active)
Reset
Reset ratio: differential current
97 % of the differential current setting (typically)
Reset time
<45 ms
Ar
Arc
c fa
fault
ult pr
pro
otection (IAr
(IArc>/I0Ar
c>/I0Arc>;
c>; 50Ar
50Arc/50NAr
c/50NArc)
c) (op
optional)
tional)
Measurement inputs
Current inputs
Phase current inputs: IL1 (A), IL2 (B), IL3 (C)
Residual current channel I01 (Coarse)
Residual current channel I02 (Fine)
Current input magnitudes
Sample-based phase current measurement
Sample-based residual current measurement
Arc point sensor inputs
Channels S1, S2, S3, S4 (pressure and light sensor, or
light-only sensor)
Up to four (4) sensors per channel
System frequency operating
range
6.00…75.00 Hz
Pick-up
Pick-up current setting (phase
current)
Pick-up current setting (residual
current)
Pick-up light intensity
0.50…40.00 × IN, setting step 0.01 × IN
0.10…40.00 × IN, setting step 0.01 × IN
8, 25 or 50 kLx (the sensor is selected in the order
code)
Starting inaccuracy (IArc>
and I0Arc>)
±3 % of the set pick-up value > 0.5 × IN setting. 5 mA <
0.5 × IN setting.
Point sensor detection radius
180 degrees
Operation time
Light only:
- Semiconductor outputs HSO1
and HSO2
- Regular relay outputs
Light + current criteria (zone
1…4):
- Semiconductor outputs HSO1
and HSO2
- Regular relay outputs
Arc BI only:
- Semiconductor outputs HSO1
and HSO2
- Regular relay outputs
56
Typically 7 ms (3…12 ms)
Typically 10 ms (6.5…15 ms)
Typically 10 ms (6.5…14 ms)
Typically 14 ms (10…18 ms)
Typically 7 ms (2…12 ms)
Typically 10 ms (6.5…15 ms)
© Arcteq Relays Ltd
MM00003
AQ -F255
Data sheet
Version: 1.00
Reset
Reset ratio for current
97 % of the pick-up setting
Reset time
<35 ms
No
Notte!
• The maximum length of the arc sensor cable is 200 meters.
Volta
oltage
ge memory
Measurement inputs
Voltage inputs
UL1, UL2, UL3
UL12, UL23, UL31 + U0
Current inputs (back-up frequency)
Phase current inputs: IL1 (A), IL2 (B), IL3 (C)
Pick-up
Pick-up voltage setting
Pick-up current setting (optional)
2.00…50.00 %UN, setting step 0.01 x %UN
0.01…50.00 × IN, setting step 0.01 × IN
Inaccuracy:
- Voltage
- Current
±1.5 %USET or ±30 mV
±0.5 %ISET or ±15 mA (0.10…4.0 × ISET)
Operation time
Angle memory activation delay
<20 ms (typically 5 ms)
Maximum active time
0.020…50.000 s, setting step 0.005 s
Inaccuracy:
- Definite time (UM/USET ratio >1.05)
±1.0 % or ±35 ms
Angle memory
Angle drift while voltage is absent
±1.0° per 1 second
Reset
Reset ratio:
- Voltage memory (voltage)
- Voltage memory (current)
103 % of the pick-up voltage setting
97 % of the pick-up current setting
Reset time
<50 ms
Note!
• Voltage memory is activated only when all line voltages fall below set pick-up value.
• Voltage memory activation captures healthy situation voltage angles, one cycle before actual
activation (50Hz/20ms before “bolted” fault)
11.20 Control functions
Se
Settting gr
group
oup selection
Settings and control modes
© Arcteq Relays Ltd
MM00003
57
AQ -F255
Data sheet
Version: 1.00
Setting
groups
8 independent, control-prioritized setting groups
Control
scale
Common for all installed functions which support setting groups
Control mode
Local
Any digital signal available in the device
Remote
Force change overrule of local controls either from the setting tool, HMI or
SCADA
Operation time
Reaction
time
<5 ms from receiving the control signal
Ob
Object
ject contr
control
ol and monit
monitoring
oring
Signals
Input signals
Digital inputs
Software signals
Output signals
Close command output
Open command output
Operation time
Breaker traverse time setting
0.02…500.00 s, setting step 0.02 s
Max. close/open command pulse
length
0.02…500.00 s, setting step 0.02 s
Control termination time out setting
0.02…500.00 s, setting step 0.02 s
Inaccuracy:
- Definite time operating time
±0.5 % or ±10 ms
Breaker control operation time
External object control time
<75 ms
Object control during auto-reclosing
See the technical sheet for the auto-reclosing
function.
Aut
uto-r
o-reclosing
eclosing (0 → 1; 79)
Input signals
Input signals
Software signals (protection, logics, etc.)
Binary inputs
Requests
REQ1-5
5 priority request inputs; can be set parallel as
signals to each request
Shots
1-5 shots
5 independent or scheme-controlled shots in each
AR request
Operation time
58
© Arcteq Relays Ltd
MM00003
AQ -F255
Data sheet
Version: 1.00
Operating time settings:
- Lockout after successful AR
- Object close reclaim time
- AR shot starting delay
- AR shot dead time delay
- AR shot action time
- AR shot specific reclaim time
0.000…1800.000 s, setting step 0.005 s
0.000…1800.000 s, setting step 0.005 s
0.000…1800.000 s, setting step 0.005 s
0.000…1800.000 s, setting step 0.005 s
0.000…1800.000 s, setting step 0.005 s
0.000…1800.000 s, setting step 0.005 s
Inaccuracy
AR starting (from a protection
stage's START signal)
±1.0 % or ±30 ms (AR delay)
AR starting (from a protection stage's
TRIP signal)
Trip delay inaccuracy +25 ms (Protection + AR
delay)
Dead time
±1.0 % or ±35 ms (AR delay)
Action time
±1.0 % or ±30 ms (AR delay)
Instant starting time
Instant operation time
Protection activation delay + 15 ms (Protection +
AR delay)
Cold load pick-up (CLP
(CLPU)
U)
Measurement inputs
Current inputs
Phase current inputs: IL1 (A), IL2 (B), IL3
(C)
Current input magnitudes
RMS phase currents
Pick-up
Pick-up current setting
- ILOW/IHIGH/IOVER
0.01…40.00 × IN, setting step 0.01 × IN
Reset ratio
97 % of the pick-up current setting
Inaccuracy:
- Current
±0.5 %ISET or ±15 mA (0.10…4.0 × ISET)
Operation time
Definite time function operating time
settings:
- tSET
- tMAX
- tMIN
Inaccuracy:
- Definite time (IM/ISET ratio = 1.05/0.95)
0.000…1800.000 s, setting step 0.005 s
0.000…1800.000 s, setting step 0.005 s
0.000…1800.000 s, setting step 0.005 s
±1.0 % or ±45 ms
Instant operation time
CLPU activation and release
<45 ms (measured from the trip contact)
No
Notte!
• A single-phase current (IL1, IL2 or IL3) is enough to prolong or release the blocking during an
overcurrent condition.
© Arcteq Relays Ltd
MM00003
59
AQ -F255
Data sheet
Version: 1.00
Swit
Switch-on-t
ch-on-to-fa
o-fault
ult (SO
(SOTF
TF))
Initialization signals
SOTF activate input
Any IED blocking input signal (Object closed signal, etc.)
Pick-up
SOTF function input
Any IED blocking input signal (I> or similar)
SOTF activation time
Activation time
<40 ms (measured from the trip contact)
SOTF release time
Release time setting
0.000…1800.000 s, setting step 0.005 s
Inaccuracy:
- Definite time
±1.0 % or ±30 ms
SOTF instant release time
<40 ms (measured from the trip contact)
Vect
ector
or jump (Δφ
(Δφ;; 78)
Measurement inputs
Voltage inputs
UL1, UL2, UL3
UL12, UL23, UL31 + U0
Monitored voltages
Any or all system line-to-line voltage(s)
Any or all system line-to-neutral voltage(s)
Specifically chosen line-to-line or line-to-neutral
voltage
U4 channel voltage
Pick-up
Pick-up setting
0.05…30.00°, setting step 0.01°
Inaccuracy:
- Voltage angle
±30% overreach or 1.00 °
Low-voltage blocking
Pick-up setting
0.01…100.00 %UN, setting step 0.01 %UN
Inaccuracy:
- Voltage
±1.5 %USET or ±30 mV
Instant operation time
Alarm and trip operation time:
- (Im/Iset ratio > ±30% overreach or
1.00 °)
<40 ms (typically 30 ms) 50/60 Hz
<50 ms (typically 40 ms) 16.67 Hz
Reset
Trip pulse
~5-10ms
Synchr
ynchrocheck
ocheck (ΔV/Δa/Δf; 25)
Input signals
Voltage inputs
60
U1, U2, U3 or U4 voltage channel
© Arcteq Relays Ltd
MM00003
AQ -F255
Data sheet
Version: 1.00
Voltage input magnitudes
RMS line-to-line or line-to-neutral voltages
U3 or U4 voltage channel RMS
Pick-up
U diff < setting
2.00…50.00 %UN, setting step 0.01 %UN
Angle diff < setting
3.0…90.0 deg, setting step 0.10 deg
Freq diff < setting
0.05…0.50 Hz, setting step 0.01 Hz
Inaccuracy:
- Voltage
- Frequency
- Angle
±3.0 %USET or ±0.3 %UN
±25 mHz (U> 30 V secondary)
±1.5° (U> 30 V secondary)
Reset
Reset ratio:
- Voltage
- Frequency
- Angle
99 % of the pick-up voltage setting
20 mHz
±2.0°
Activation time
Activation (to LD/DL/DD)
Activation (to Live Live)
<35 ms
<60 ms
Reset
<40 ms
Bypass modes
Voltage check mode
(excluding LL)
LL+LD, LL+DL, LL+DD, LL+LD+DL, LL+LD+DD,
LL+DL+DD, bypass
U live > limit
U dead < limit
0.10…100.00 %UN, setting step 0.01 %UN
0.00…100.00 %UN, setting step 0.01 %UN
No
Notte!
• Voltage is scaled to the primary amplitude; therefore, the different sized PT secondaries are
possible.
• The minimum voltage for direction and frequency solving is 20.0 %UN.
• U< dead limit is not in use when set to 0 %UN.
• When SYN3 is used, SYN1 and SYN2 must have the same reference voltage.
• In 3LN mode the synchronization to the L-N and L-L voltages is possible. In 3LL/2LL modes
the synchronization is only supported to the L-L voltage.
11.21 Monitoring functions
Curr
Current
ent transf
transformer
ormer super
supervision
vision
Measurement inputs
Current inputs
Phase current inputs: IL1 (A), IL2 (B), IL3 (C)
Residual current channel I01 (Coarse)
(optional)
Residual current channel I02 (Fine) (optional)
Current input magnitudes
RMS phase currents
RMS residual current (I01, I02) (optional)
Pick-up
© Arcteq Relays Ltd
MM00003
61
AQ -F255
Data sheet
Version: 1.00
Pick-up current settings:
- ISET high limit
- ISET low limit
- ISUM difference
- ISET ratio
- I2/I1 ratio
Inaccuracy:
- Starting IL1, IL2, IL3
- Starting I2/I1
- Starting I01 (1 A)
- Starting I02 (0.2 A)
0.10…40.00 × IN, setting step 0.01 × IN
0.10…40.00 × IN, setting step 0.01 × IN
0.10…40.00 × IN, setting step 0.01 × IN
0.01…100.00 %, setting step 0.01 %
0.01…100.00 %, setting step 0.01 %
±0.5 %ISET or ±15 mA (0.10…4.0 × ISET)
±1.0 %I2SET / I1SET or ±100 mA (0.10…4.0
× IN)
±0.5 %I0SET or ±3 mA (0.005…10.0 × ISET)
±1.5 %I0SET or ±1.0 mA (0.005…25.0 × ISET)
Time delay for alarm
Definite time function operating time
setting
Inaccuracy_
- Definite time (IM/ISET ratio > 1.05)
Instant operation time (alarm):
- IM/ISET ratio > 1.05
0.00…1800.00 s, setting step 0.005 s
±2.0 % or ±80 ms
<80 ms (<50 ms in differential protection
relays)
Reset
Reset ratio
97/103 % of the pick-up current setting
Instant reset time and start-up reset
<80 ms (<50 ms in differential protection
relays)
Volta
oltage
ge transf
transformer
ormer super
supervision
vision (60)
Measurement inputs
Voltage inputs
UL1, UL2, UL3
UL12, UL23, UL31
Voltage input magnitudes
RMS line-to-line or line-to-neutral voltages
Pick-up
Pick-up settings:
- Voltage (low pick-up)
- Voltage (high pick-up)
- Angle shift limit
0.05…0.50 × UN, setting step 0.01 × UN
0.50…1.10 × UN, setting step 0.01 × UN
2.00…90.00 deg, setting step 0.10 deg
Inaccuracy:
- Voltage
- U angle (U> 1 V)
±1.5 %USET
±1.5°
External line/bus side pick-up (optional)
0→1
Time delay for alarm
62
Definite time function operating time setting
0.00…1800.00 s, setting step 0.005 s
Inaccuracy:
- Definite time (UM/USET ratio > 1.05/0.95)
±1.0 % or ±35 ms
Instant operation time (alarm):
- UM/USET ratio > 1.05/0.95
<80 ms
VTS MCB trip bus/line (external input)
<50 ms
© Arcteq Relays Ltd
MM00003
AQ -F255
Data sheet
Version: 1.00
Reset
Reset ratio
97/103 % of the pick-up voltage setting
Reset time setting
Inaccuracy: Reset time
0.010…10.000 s, step 0.005 s
±2.0 % or ±80 ms
Instant reset time and start-up reset
<50 ms
VTS MCB trip bus/line (external input)
<50 ms
No
Notte!
• When turning on the auxiliary power of an IED, the normal condition of a stage has to be
fulfilled before tripping.
Dist
isturbance
urbance rrecor
ecorder
der
Recorded values
Recorder
analog channels
0…20 channels
Freely selectable
Recorder digital
channels
0…95 channels
Freely selectable analog and binary signals
5 ms sample rate (FFT)
Performance
Sample rate
8, 16, 32 or 64 samples/cycle
Recording
length
0.000…1800.000 s, setting step 0.001 s
The maximum length is determined by the chosen signals.
Number of
recordings
0…100, 60 MB of shared flash memory reserved
The maximum number of recordings according to the chosen signals
and operation time setting combined
Cir
Circuit
cuit br
break
eaker
er w
wear
ear monit
monitoring
oring
Pick-up
Breaker characteristics settings:
- Nominal breaking current
- Maximum breaking current
- Operations with nominal current
- Operations with maximum
breaking current
Pick-up setting for Alarm 1 and
Alarm 2
0.00…100.00 kA, setting step 0.001 kA
0.00…100.00 kA, setting step 0.001 kA
0…200 000 operations, setting step 1 operation
0…200 000 operations, setting step 1 operation
0…200 000 operations, setting step 1 operation
Inaccuracy
Inaccuracy for current/operations
counter:
- Current measurement element
- Operation counter
0.1× IN > I < 2 × IN ±0.2 % of the measured
current, rest 0.5 %
±0.5 % of operations deducted
Total harmonic dist
distor
ortion
tion
Input signals
© Arcteq Relays Ltd
MM00003
63
AQ -F255
Data sheet
Version: 1.00
Current inputs
Current input magnitudes
Phase current inputs: IL1 (A), IL2 (B), IL3 (C)
Residual current channel I01 (Coarse)
Residual current channel I02 (Fine)
Current measurement channels (FFT result) up to
the 31st harmonic component.
Pick-up
Operating modes
Power THD
Amplitude THD
Pick-up setting for all comparators
0.10…200.00 % , setting step 0.01 %
Inaccuracy
±3 % of the set pick-up value > 0.5 × IN setting; 5
mA < 0.5 × IN setting.
Time delay
Definite time function operating time
setting for all timers
Inaccuracy:
- Definite time operating time
- Instant operating time, when
IM/ISET ratio > 3
- Instant operating time, when
IM/ISET ratio 1.05 < IM/ISET < 3
0.00…1800.00 s, setting step 0.005 s
±0.5 % or ±10 ms
Typically <20ms
Typically <25 ms
Reset
Reset time
Typically <10 ms
Reset ratio
97 %
Fault loc
loca
ator (21FL)
Input signals
Current inputs
Phase current inputs: IL1 (A), IL2
(B), IL3 (C)
Voltage inputs
UL1, UL2, UL3
UL12, UL23, UL31 + U0
Calculated reactance magnitudes when line-toneutral voltages available
XL12, XL23, XL31, XL1, XL2, XL3
Calculated reactance magnitudes when line-toline voltages available
XL12, XL23, XL31
Pick-up
Trigger current >
Inaccuracy:
- Triggering
0.00…40.00 × IN, setting step
0.01 × IN
±0.5 %ISET or ±15 mA (0.10…4.0
× ISET)
Reactance
Reactance per kilometer
Inaccuracy:
- Reactance
64
0.000…5.000 s, setting step
0.001 Ω/km
±5.0 % (typically)
© Arcteq Relays Ltd
MM00003
AQ -F255
Data sheet
Version: 1.00
Operation (Triggering)
Activation
From the trip signal of any
protection stage
Minimum operation time
At least 0.040 s of stage operation
time required
© Arcteq Relays Ltd
MM00003
65
AQ -F255
Data sheet
Version: 1.00
12 Ordering information
Accessories
66
Or
Order
der code
Descrip
Description
tion
No
Notte
Manufact
Manufactur
urer
er
ADAM-4015-CE
External 6-channel 2 or 3 wires
RTD Input module, preconfigured
Requires an
external power
module
Advanced
Co. Ltd.
© Arcteq Relays Ltd
MM00003
AQ -F255
Data sheet
Version: 1.00
ADAM-4018+BE
External 8-ch Thermocouple
mA Input module, preconfigured
AQX121
Raising frame 120mm
Arcteq Ltd.
AQX122
Raising frame 40mm
Arcteq Ltd.
AQX098
Wall mounting bracket
Arcteq Ltd.
AQ-01A
Light point sensor unit (8,000
lux threshold)
Max. cable
length 200 m
Arcteq Ltd.
AQ-01B
Light point sensor unit (25,000
lux threshold)
Max. cable
length 200 m
Arcteq Ltd.
AQ-01C
Light point sensor unit (50,000
lux threshold)
Max. cable
length 200 m
Arcteq Ltd.
AQ-02A
Pressure and light point sensor
unit (8,000 lux threshold)
Max. cable
length 200 m
Arcteq Ltd.
AQ-02B
Pressure and light point sensor
unit (25,000 lux threshold)
Max. cable
length 200 m
Arcteq Ltd.
AQ-02C
Pressure and light point sensor
unit (50,000 lux threshold)
Max. cable
length 200 m
Arcteq Ltd.
© Arcteq Relays Ltd
MM00003
Requires an
external power
module
Advanced
Co. Ltd.
67
AQ -F255
Data sheet
Version: 1.00
13 Contact and reference information
Manufacturer
Arcteq Relays Ltd.
Visiting and postal address
Kvartsikatu 2 A 1
65300 Vaasa, Finland
Contacts
68
Phone:
+358 10 3221 370
Fax:
+358 10 3221 389
Website (general):
arcteq.fi
Website (technical support):
support.arcteq.fi
E-mail (sales):
sales@arcteq.fi
© Arcteq Relays Ltd
MM00003