VAMP 265
Transformer, generator and motor
differential protection relay
Operation and configuration
instructions
Technical description
VM265.EN011
Operation and configuration
instructions
Table of Contents
VM265.EN011
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1. General ................................................................................... 4
1.1. Relay features ..................................................................... 4
1.2. User interface ...................................................................... 5
1.3. Operating Safety ................................................................ 5
2. Local panel user interface .................................................... 6
2.1. Relay front panel ................................................................ 6
2.1.1. Display ......................................................................... 7
2.1.2. Menu navigation and pointers ................................ 8
2.1.3. Keypad ........................................................................ 8
2.1.4. Operation Indicators ................................................. 9
2.1.5. Adjusting display contrast ..................................... 10
2.2. Local panel operations .................................................. 11
2.2.1. Navigating in menus .............................................. 11
2.2.2. Menu structure of protection functions .............. 14
2.2.3. Setting groups ......................................................... 18
2.2.4. Fault logs .................................................................. 19
2.2.5. Operating levels ...................................................... 20
2.3. Operating measures ....................................................... 22
2.3.1. Control functions .................................................... 22
2.3.2. Measured data ....................................................... 23
2.3.3. Reading event register .......................................... 25
2.3.4. Forced control (Force) ........................................... 26
2.4. Configuration and parameter setting ......................... 27
2.4.1. Parameter setting ................................................... 28
2.4.2. Setting range limits ................................................. 29
2.4.3. Disturbance recorder menu DR ........................... 30
2.4.4. Configuring digital inputs DI .................................. 30
2.4.5. Configuring digital outputs DO ............................ 31
2.4.6. Protection menu Prot ............................................. 31
2.4.7. Configuration menu CONF ................................... 32
2.4.8. Protocol menu Bus .................................................. 34
2.4.9. Single line diagram editing ................................... 37
2.4.10. Blocking and interlocking configuration ............. 37
3. VAMPSET PC software .......................................................... 38
1.1 Relay features
1 General
Operation and configuration
instructions
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IEEE/
ANSI code
IEC symbol
Function name
50/51
3I>, 3I>>, 3I’>,
3I’>>
Overcurrent protection
87
∆I>, ∆I>>
Differential overcurrent protection
46
I2>, I’2>
Current unbalance protection
49
T>
Thermal overload protection
50N/51N
I0>, I0>>,
I0>>>, I0>>>>
Earth fault protection
51F2
If2>
Second harmonic O/C stage
50BF
CBFP
Circuit-breaker failure protection
99
Prg1…8
Programmable stages
50ARC
50NARC
ArcI>, ArcI’>
ArcI01>, ArcI02>
Optional arc fault protection
1. General
This first part (Operation and configuration) of the publication
contains general descriptions of the functions, of the
differential protection relay as well as operation instructions. It
also includes instructions for parameterization and
configuration of the relay and instructions for changing
settings.
The second part (Technical description) of the publication
includes detailed protection function descriptions as well as
application examples and technical data sheets.
The Mounting and Commissioning Instructions are published
in a separate publication with the code VMMC.EN0xx.
1.1. Relay features
VAMP 265 differential protection relay is ideal for transformer,
motor, generator and short cable (100) differential protection.
The relay features the following protection functions.
List of protection functions
Further the relay includes a disturbance recorder. Arc
protection is optionally available.
The relay communicates with other systems using common
protocols, such as the Modbus RTU, ModbusTCP, Profibus DP,
IEC 60870-5-103, SPA bus and DNP 3.0, IEC 61850 and IEC
60870-5-101.
Operation and configuration
instructions
1 General
1.2 User interface
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The terminals on the rear panel of the relay may
carry dangerous voltages, even if the auxiliary
voltage is switched off. A live current transformer
secondary circuit must not be opened.
Disconnecting a live circuit may cause dangerous
voltages! Any operational measures must be carried
out according to national and local handling
directives and instructions.
!
1.2. User interface
The relay can be controlled in three ways:
Locally with the push-buttons on the relay front panel
Locally using a PC connected to the serial port on the front
panel or on the rear panel of the relay (both cannot be used
simultaneously)
Via remote control over the remote control port on the relay
rear panel.
1.3. Operating Safety
Carefully read through all operation instructions before any
operational measures are carried out.
2.1 Relay front panel
2 Local panel user interface
Operation and configuration
instructions
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2. Local panel user interface
2.1. Relay front panel
The figure below shows, as an example, the front panel of the
relay VAMP 265 and the location of the user interface elements
used for local control.
Figure 2.1-1. The front panel of VAMP 265
1. LCD dot matrix display
2. Keypad
3. LED indicators
4. RS 232 serial communication port for PC
Operation and configuration
instructions
2 Local panel user interface
2.1 Relay front panel
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2.1.1. Display
The relay is provided with a backlightedt 128x64 LCD dot
matrix display. The display enables showing 21 characters in
one row and eight rows at the same time. The display has two
different purposes: one is to show the single line diagram of the
relay with the object status, measurement values, identification
etc. (Figure 2.1.1-1). The other purpose is to show the
configuration and parameterization values of the relay (Figure
2.1.1-2).
Figure 2.1.1-1 Sections of the LCD dot matrix display
1. Freely configurable single-line diagram
2. Five controllable objects
3. Six object statuses
4. Bay identification
5. Local/Remote selection
6. Auto-reclose on/off selection (if applicable)
7. Freely selectable measurement values (max. six values)
Figure 2.1.1-2 Sections of the LCD dot matrix display
1. Main menu column
2. The heading of the active menu
3. The cursor of the main menu
4. Possible navigating directions (push buttons)
5. Measured/setting parameter
6. Measured/set value
2.1 Relay front panel
2 Local panel user interface
Operation and configuration
instructions
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Backlight control
Display backlight can be switched on with a digital input,
virtual input or virtual output. LOCALPANEL CONF/Display
backlight ctrl setting is used for selecting trigger input for
backlight control. When the selected input activates (rising
edge), display backlight is set on for 60 minutes.
2.1.2. Menu navigation and pointers
1. Use the arrow keys UP and DOWN to move up and down in
the main menu, that is, on the left-hand side of the display.
The active main menu option is indicated with a cursor. The
options in the main menu items are abbreviations, e.g. Evnt
= events.
2. After any selection, the arrow symbols in the upper left
corner of the display show the possible navigating directions
(applicable navigation keys) in the menu.
3. The name of the active submenu and a possible ANSI code
of the selected function are shown in the upper part of the
display, e.g. CURRENTS.
4. Further, each display holds the measured values and units
of one or more quantities or parameters, e.g. Ilmax 300A.
2.1.3. Keypad
You can navigate in the menu and set the required parameter
values using the keypad and the guidance given in the display.
Furthermore, the keypad is used to control objects and switches
on the single line diagram display. The keypad is composed of
four arrow keys, one cancel key, one enter key and one info key.
Figure 2.1.3-1 Keys on the keypad
1. Enter and confirmation key (ENTER)
2. Cancel key (CANCEL)
3. Up/Down [Increase/Decrease] arrow keys (UP/DOWN)
4. Keys for selecting submenus [selecting a digit in a
numerical value] (LEFT/RIGHT)
5. Additional information key (INFO)
NOTE! The term, which is used for the buttons in this manual, is inside the
brackets.
Operation and configuration
instructions
2 Local panel user interface
2.1 Relay front panel
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LED indicator
Meaning
Measure/ Remarks
Power LED lit
The auxiliary power has
been switched on
Normal operation state
Error LED lit
Internal fault, operates in
parallel with the self
supervision output relay
The relay attempts to
reboot [REBOOT]. If the
error LED remains lit,
call for maintenance.
Com LED lit or
flashing
The serial bus is in use
and transferring
information
Normal operation state
Alarm LED lit
One or several signals of
the output relay matrix
have been assigned to
output LA and the output
has been activated by one
of the signals. (For more
information about output
matrix, please see chapter
2.4.5).
The LED is switched off
when the signal that
caused output Al to
activate, e.g. the START
signal, is reset. The
resetting depends on the
type of configuration,
connected or latched.
Trip LED lit
One or several signals of
the output relay matrix
have been assigned to
output Tr, and the output
has been activated by one
of the signals. (For more
information about output
relay configuration, please
see chapter 2.4.5).
The LED is switched off
when the signal that
caused output Tr to
activate, e.g. the TRIP
signal, is reset. The
resetting depends on the
type of configuration,
connected or latched.
A- C LED lit
Application-related status
indicators.
Configurable
2.1.4. Operation Indicators
The relay is provided with eight LED indicators:
Figure 2.1.4-1. Operation indicators of the relay
2.1 Relay front panel
2 Local panel user interface
Operation and configuration
instructions
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Resetting latched indicators and output relays
All the indicators and output relays can be given a latching
function in the configuration.
There are several ways to reset latched indicators and relays:
From the alarm list, move back to the initial display by
pushing the CANCEL key for approx. 3 s. Then reset the
latched indicators and output relays by pushing the ENTER
key.
Acknowledge each event in the alarm list one by one by
pushing the ENTER key equivalent times. Then, in the
initial display, reset the latched indicators and output
relays by pushing the ENTER key.
The latched indicators and relays can also be reset via a remote
communication bus or via a digital input configured for that
purpose.
2.1.5. Adjusting display contrast
The readability of the LCD varies with the brightness and the
temperature of the environment. The contrast of the display
can be adjusted via the PC user interface, see chapter 3.
Operation and configuration
instructions
2 Local panel user interface
2.2 Local panel operations
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2.2. Local panel operations
The front panel can be used to control objects, change the local/
remote status, read the measured values, set parameters, and
to configure relay functions. Some parameters, however, can
only be set by means of a PC connected to one of the local
communication ports. Some parameters are factory-set.
2.2.1. Navigating in menus
All the menu functions are based on the main menu/submenu
structure:
1. Use the arrow keys UP and DOWN to move up and down in
the main menu.
2. To move to a submenu, repeatedly push the RIGHT key
until the required submenu is shown. Correspondingly,
push the LEFT key to return to the main menu.
3. Push the ENTER key to confirm the selected submenu. If
there are more than six items in the selected submenu, a
black line appears to the right side of the display (Figure
2.2.1-1). It is then possible to scroll down in the submenu.
4. Push the CANCEL key to cancel a selection.
5. Pushing the UP or DOWN key in any position of a sub-
menu, when it is not selected, brings you directly one step
up or down in the main menu.
The active main menu selection is indicated with black background color. The possible navigating directions in the menu
are shown in the upper-left corner by means of black triangular
symbols.
Figure 2.2.1-1. Example of scroll indication
2.2 Local panel operations
2 Local panel user interface
Operation and configuration
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Figure 2.2.1-2. Principles of the menu structure and navigation in the
menus
6. Push the INFO key to obtain additional information about
any menu item.
7. Push the CANCEL key to revert to the normal display.
Main menu
The general menu structure is shown in Figure 2.2.1-2. The
menu is dependent on the user’s configuration and the options
according the order code. For example only the enabled
protection stages will appear in the menu.
Operation and configuration
instructions
2 Local panel user interface
2.2 Local panel operations
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Main
menu
Number of
menus
Description
ANSI code
Note
1 Interactive mimic display
1
5 Double size measurements defined by the
user
1
1 Title screen with device name, time and
firmware version.
I
13
Current measurements
Dema
15
Demand values
Umax
5
Time stamped min & max of voltages
Imax
9
Time stamped min & max of currents
Mont
21
Maximum values of the last 31 days and
the last twelve months
Evnt
2
Events
DR 2 Disturbance recorder
2
Runh
2
Running hour counter. Active time of a
selected digital input and time stamps of
the latest start and stop.
TIMR
6
Day and week timers
DI 5 Digital inputs including virtual inputs
DO 4 Digital outputs (relays) and output
matrix
ExtAI
3
External analogue inputs
3 ExDI
3
External digital inputs
3 ExDO
3
External digital outputs
3
Prot
27
Protection counters, combined
overcurrent status, protection status,
protection enabling, cold load and inrush
detectionIf2> and block matrix
ΔI> 7 1st differential stages
ΔI>>
5
2nd differential stage
I> 5 1st overcurrent stage (primary side)
50/51
4
I>> 3 2nd overcurrent stage (primary side)
50/51
4
I’> 5 1st overcurrent stage (secondary side)
50/51
4
I’>>
3
2nd overcurrent stage (secondary side)
50/51
4
I2> 3 Current unbalance stage (primary side)
46 4 I’2>
3
Current unbalance stage (secondary side)
46 4 T> 3 Thermal overload stage
49 4 Io> 5 1st earth fault stage
50N/51N
4
Io>>
3
2nd earth fault stage
50N/51N
4
Io>>>
3
3rd earth fault stage
50N/51N
4
Io>>>>
3
4th earth fault stage
50N/51N
4
Prg1
3
1st programmable stage
4 Prg2
3
2nd programmable stage
4 Prg3
3
3rd programmable stage
4 Prg4
3
4th programmable stage
4
Prg5
3
5th programmable stage
4 Prg6
3
6th programmable stage
4
A list of the local main menu
2.2 Local panel operations
2 Local panel user interface
Operation and configuration
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Main
menu
Number of
menus
Description
ANSI code
Note
Prg7
3
7th programmable stage
4 Prg8
3
8th programmable stage
4 If2>
3
Second harmonic O/C stage
51F2
4
CBFP
3
Circuit breaker failure protection
50BF
4
CBWE
4
Circuit breaker wearing supervision
4 CTSV
1
CT supervisor
4 CT’SV
1
CT’ supervisor
4
ArcI>
4
Optional arc protection stage for phaseto-phase faults and delayed light signal.
50ARC
4
ArcIo>
3
Optional arc protection stage for earth
faults. Current input = I01
50NARC
4
ArcIo2>
3
Optional arc protection stage for earth
faults. Current input = I02
50NARC
4
OBJ
11
Object definitions
5 Lgic
2
Status and counters of user's logic
1 CONF
10+2
Device setup, scaling etc.
6 Bus
13
Serial port and protocol configuration
7 Diag
6
Device selfdiagnosis
Notes
1
Configuration is done with VAMPSET
2
Recording files are read with VAMPSET
3
The menu is visible only if protocol "ExternalIO" is selected for one of the
serial ports. Serial ports are configured in menu "Bus".
4
The menu is visible only if the stage is enabled.
5
Objects are circuit breakers, disconnectors etc.. Their position or status can
be displayed and controlled in the interactive mimic display.
6
There are two extra menus, which are visible only if the access level
"operator" or "configurator" has been opened with the corresponding
password.
7
Detailed protocol configuration is done with VAMPSET.
2.2.2. Menu structure of protection functions
The general structure of all protection function menus is
similar although the details do differ from stage to stage. As an
example the details of the second overcurrent stage I>> menus
are shown below.
Operation and configuration
instructions
2 Local panel user interface
2.2 Local panel operations
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Status –
The stage is not detecting any fault at the moment. The
stage can also be forced to pick-up or trip if the operating
level is "Configurator" and the force flag below is on.
Operating levels are explained in chapter 2.2.5.
SCntr 5
The stage has picked-up a fault five times since the last
reset of restart. This value can be cleared if the operating
level is at least "Operator".
TCntr 1
The stage has tripped two times since the last reset of
restart. This value can be cleared if the operating level is
at least "Operator".
SetGrp 1
The active setting group is one. This value can be edited if
the operating level is at least “Operator”. Setting groups are
explained in chapter 2.2.3.
SGrpDI -
The setting group is not controlled by any digital input.
This value can be edited if the operating level is at least
“Configurator”.
Force Off
The status forcing and output relay forcing is disabled. This
force flag status can be set to “On” or back to “Off” if the
operating level is at least “Configurator”. If no front panel
button is pressed within five minutes and there is no
VAMPSET communication, the force flag will be set to “Off”
position. The forcing is explained in chapter 2.3.4.
First menu of I>> 50/51 stage
Figure 2.2.2-1 First menu of I>> 50/51 stage
This is the status, start and trip counter and setting group
menu. The content is:
2.2 Local panel operations
2 Local panel user interface
Operation and configuration
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Stage setting group 1
These are the group 1 setting values. The other setting
group can be seen by pressing push buttons ENTER and
then RIGHT or LEFT. Setting groups are explained in
chapter 2.2.3.
Ilmax 403A
The maximum of the three measured phase currents is at
the moment 403 A. This is the value the stage is
supervising.
Status –
Status of the stage. This is just a copy of the status value in
the first menu.
I>> 1013 A
The pick-up limit is 1013 A in primary value.
I>> 2.50xIn
The pick-up limit is 2.50 times the rated current of the
protected object. This value can be edited if the operating
level is at least "Operator". Operating levels are explained
in chapter 2.2.5.
t>> 0.60s
The total operation delay is set to 600 ms. This value can be
edited if the operating level is at least "Operator".
Second menu of I>> 50/51 stage
Figure 2.2.2-2. Second menu (next on the right) of I>> 50/51 stage
This is the main setting menu. The content is:
Operation and configuration
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2.2 Local panel operations
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FAULT LOG 1
This is the latest of the eight available logs. You may move
between the logs by pressing push buttons ENTER and
then RIGHT or LEFT.
2006-09-14
Date of the log.
12:25:10.288
Time of the log.
Type 1-2
The overcurrent fault has been detected in phases L1 and
L2 (A & B, red & yellow, R&S, u&v).
Flt 2.86xIn
The fault current has been 2.86 per unit.
Load 0.99xIn
The average load current before the fault has been 0.99 pu.
EDly 81%
The elapsed operation delay has been 81% of the setting
0.60 s = 0.49 s. Any registered elapsed delay less than 100
% means that the stage has not tripped, because the fault
duration has been shorter than the delay setting.
SetGrp 1
The setting group has been 1. This line can be reached by
pressing ENTER and several times the DOWN button.
Third menu of I>> 50/51 stage
Figure 2.2.2-3. Third and last menu (next on the right) of I>> 50/51 stage
This is the menu for registered values by the I>> stage. Fault
logs are explained in chapter 2.2.4.
2.2 Local panel operations
2 Local panel user interface
Operation and configuration
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2.2.3. Setting groups
Most of the protection functions of the relay have two setting
groups. These groups are useful for example when the network
topology is changed frequently. The active group can be
changed by a digital input, through remote communication or
locally by using the local panel.
The active setting group of each protection function can be
selected separately. Figure 2.2.3-1 shows an example where the
changing of the I> setting group is handled with digital input
one (SGrpDI). If the digital input is TRUE, the active setting
group is group two and correspondingly, the active group is
group one, if the digital input is FALSE. If no digital input is
selected (SGrpDI = -), the active group can be selected by
changing the value of the parameter SetGrp.
Figure 2.2.3-1. Example of protection submenu with setting group
parameters
The changing of the setting parameters can be done easily.
When the desired submenu has been found (with the arrow
keys), press the ENTER key to select the submenu. Now the
selected setting group is indicated in the down-left corner of the
display (See Figure 2.2.3-2). Set1 is setting group one and Set2
is setting group two. When the needed changes, to the selected
setting group, have been done, press the LEFT or the RIGHT
key to select another group (the LEFT key is used when the
active setting group is 2 and the RIGHT key is used when the
active setting group is 1).
Figure 2.2.3-2. Example of I> setting submenu
Operation and configuration
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2 Local panel user interface
2.2 Local panel operations
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2.2.4. Fault logs
All the protection functions include fault logs. The fault log of a
function can register up to eight different faults with time
stamp information, fault values etc. Each function has its own
logs (See Figure 2.2.4-1).
Figure 2.2.4-1. Example of fault log
To see the values of, for example, log two, press the ENTER key
to select the current log (log one). The current log number is
then indicated in the down-left corner of the display (See
Figure 2.2.4-2, Log2 = log two). The log two is selected by
pressing the RIGHT key once.
Figure 2.2.4-2. Example of selected fault log
2.2 Local panel operations
2 Local panel user interface
Operation and configuration
instructions
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Use:
Possible to read e.g. parameter values,
measurements and events
Opening:
Level permanently open
Closing:
Closing not possible
Use:
Possible to control objects and to change e.g.
the settings of the protection stages
Opening:
Default password is 1
Setting state:
Push ENTER
Closing:
The level is automatically closed after 10
minutes idle time. Giving the password 9999
can also close the level.
Use:
The configurator level is needed during the
commissioning of the relay. E.g. the scaling of
the voltage and current transformers can be
set.
Opening:
Default password is 2
Setting state:
Push ENTER
Closing:
The level is automatically closed after 10
minutes idle time. Giving the password 9999
can also close the level.
2.2.5. Operating levels
The relay has three operating levels: User level, Operator level
and Configurator level. The purpose of the access levels is to
prevent accidental change of relay configurations, parameters
or settings.
USER level
OPERATOR level
CONFIGURATOR level
Operation and configuration
instructions
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2.2 Local panel operations
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Command
Description
get pwd_break
Get the break code (Example:
6569403)
get serno
Get the serial number of the relay
(Example: 12345)
Command
Description
set pwd_break=4435876
Restore the factory default
passwords (“4435876” is just an
example. The actual code should be
asked from VAMP Ltd.)
Opening access
1. Push the INFO key and the ENTER key on the front panel.
Figure 2.2.5-1. Opening the access level
2. Enter the password needed for the desired level: the
password can contain four digits. The digits are supplied
one by one by first moving to the position of the digit using
the RIGHT key and then setting the desired digit value
using the UP key.
3. Push the ENTER key.
Password handling
The passwords can only be changed using VAMPSET software
connected to the local RS-232 port on the relay.
It is possible to restore the password(s) in case the password is
lost or forgotten. In order to restore the password(s), a relay
program is needed. The serial port settings are 38400 bps, 8
data bits, no parity and one stop bit. The bit rate is
configurable via the front panel.
Send both the numbers to vampsupport@vamp.fi and ask for a
password break. A device specific break code is sent back to
you. That code will be valid for the next two weeks.
Now the passwords are restored to the default values (See
chapter 2.2.5).
2.3 Operating measures
2 Local panel user interface
Operation and configuration
instructions
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2.3. Operating measures
2.3.1. Control functions
The default display of the local panel is a single-line diagram
including relay identification, Local/Remote indication, Autoreclose on/off selection and selected analogue measurement
values.
Please note that the operator password must be active in order
to be able to control the objects. Please refer to page 21 opening
access.
Toggling Local/Remote control
1. Push the ENTER key. The previously activated object starts
to blink.
2. Select the Local/Remote object (“L” or “R” squared) by using
the arrow keys.
3. Push the ENTER key. The L/R dialog opens. Select
“REMOTE” to enable remote control and disable local
control. Select “LOCAL” to enable local control and disable
remote control.
4. Confirm the setting by pushing the ENTER key. The
Local/Remote state will change.
Object control
1. Push the ENTER key. The previously activated object starts
to blink.
2. Select the object to control by using the arrow keys. Please
note that only controllable objects can be selected.
3. Push the ENTER key. A control dialog opens.
4. Select the “Open” or “Close” command by using the UP and
DOWN arrow keys.
5. Confirm the operation by pushing the ENTER key. The
state of the object changes.
Toggling virtual inputs
1. Push the ENTER key. The previously activated object starts
to blink.
2. Select the virtual input object (empty or black square)
3. The dialog opens
4. Select “VIon” to activate the virtual input or select “VIoff” to
deactivate the virtual input
Operation and configuration
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2.3 Operating measures
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Value
Menu/Submenu
Description
f
P/POWER
Frequency [Hz]
IL1
I/PHASE CURRENTS
Phase current IL1 [A]
IL2
I/PHASE CURRENTS
Phase current IL2 [A]
IL3
I/PHASE CURRENTS
Phase current IL3 [A]
IL1da
I/PHASE CURRENTS
15 min average for IL1 [A]
IL2da
I/PHASE CURRENTS
15 min average for IL2 [A]
IL3da
I/PHASE CURRENTS
15 min average for IL3 [A]
I’L1
I/PHASE CURRENTS
Phase current I’L1 [A]
I’L2
I/PHASE CURRENTS
Phase current I’L2 [A]
I’L3
I/PHASE CURRENTS
Phase current I’L3 [A]
I’L1da
I/PHASE CURRENTS
15 min average for I’L1 [A]
I’L2da
I/PHASE CURRENTS
15 min average for I’L2 [A]
I’L3da
I/PHASE CURRENTS
15 min average for I’L3 [A]
Io
I/SYMMETRIC
CURRENTS
Primary value of zerosequence/
residual current Io [A]
Io2
I/SYMMETRIC
CURRENTS
Primary value of zerosequence/residual current Io2 [A]
IoC
I/SYMMETRIC
CURRENTS
Calculated Io [A]
I1
I/SYMMETRIC
CURRENTS
Positive sequence current [A]
I2
I/SYMMETRIC
CURRENTS
Negative sequence current [A]
I2/I1
I/SYMMETRIC
CURRENTS
Negative sequence current related to
positive sequence current (for
unbalance protection) [%]
I’1
I/SYMMETRIC
CURRENTS
Positive sequence current [A]
I’2
I/SYMMETRIC
CURRENTS
Negative sequence current [A]
I’2/I’1
I/SYMMETRIC
CURRENTS
Negative sequence current related to
positive sequence current (for
unbalance protection) [%]
THDIL
I/HARM.
DISTORTION
Total harmonic distortion of the mean
value of phase currents [%]
THDIL1
I/HARM.
DISTORTION
Total harmonic distortion of phase
current IL1 [%]
THDIL2
I/HARM.
DISTORTION
Total harmonic distortion of phase
current IL2 [%]
THDIL3
I/HARM.
DISTORTION
Total harmonic distortion of phase
current IL3 [%]
THDI’L1
I/HARM.
DISTORTION
Total harmonic distortion of phase
current I’L1 [%]
2.3.2. Measured data
The measured values can be read from the main menus and
their submenus. Furthermore, any measurement value in the
following table can be displayed on the main view next to the
single line diagram. Up to six measurements can be shown.
2.3 Operating measures
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Value
Menu/Submenu
Description
THDI’L2
I/HARM.
DISTORTION
Total harmonic distortion of phase
current I’L2 [%]
THDI’L3
I/HARM.
DISTORTION
Total harmonic distortion of phase
current I’L3 [%]
Diagram
I/HARMONICS of IL1
Harmonics of phase current IL1 [%]
(see Figure 2.3.2-1)
Diagram
I/HARMONICS of IL2
Harmonics of phase current IL2 [%]
(see Figure 2.3.2-1)
Diagram
I/HARMONICS of IL3
Harmonics of phase current IL3 [%]
(see Figure 2.3.2-1)
Diagram
I/HARMONICS of I’L1
Harmonics of phase current I’L1 [%]
(see Figure 2.3.2-1)
Diagram
I/HARMONICS of I’L2
Harmonics of phase current I’L2 [%]
(see Figure 2.3.2-1)
Diagram
I/HARMONICS of I’L3
Harmonics of phase current I’L3 [%]
(see Figure 2.3.2-1)
Figure 2.3.2-1. Example of harmonics bar display
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2.3.3. Reading event register
The event register can be read from the Evnt submenu:
1. Push the RIGHT key once.
2. The EVENT LIST appears. The display contains a list of all
the events that have been configured to be included in the
event register.
Figure 2.3.3-1 Example of an event register
3. Scroll through the event list with the UP and DOWN keys.
4. Exit the event list by pushing the LEFT key.
It is possible to set the order in which the events are sorted. If
the “Order” -parameter is set to “New-Old”, then the first event
in the EVENT LIST is the most recent event.
2.3 Operating measures
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2.3.4. Forced control (Force)
In some menus it is possible to switch a signal on and off by
using a force function. This feature can be used, for instance,
for testing a certain function. The force function can be
activated as follows:
1. Move to the setting state of the desired function, for
example DO (see Chapter 2.4, on page 27).
2. Select the Force function (the background color of the force
text is black).
Figure 2.3.4-1. Selecting Force function
3. Push the ENTER key.
4. Push the UP or DOWN key to change the "OFF" text to
"ON", that is, to activate the Force function.
5. Push the ENTER key to return to the selection list. Choose
the signal to be controlled by force with the UP and DOWN
keys, for instance the T1 signal.
6. Push the ENTER key to confirm the selection. Signal T1
can now be controlled by force.
7. Push the UP or DOWN key to change the selection from "0"
(not alert) to "1" (alert) or vice versa.
8. Push the ENTER key to execute the forced control operation
of the selected function, e.g., making the output relay of T1
to pick up.
9. Repeat the steps 7 and 8 to alternate between the on and off
state of the function.
10. Repeat the steps 1...4 to exit the Force function.
11. Push the CANCEL key to return to the main menu.
NOTE! All the interlockings and blockings are bypassed when the force control
is used.
Operation and configuration
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2.4 Configuration and parameter
setting
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2.4. Configuration and parameter setting
The minimum procedure to configure a relay is
1. Open the access level "Configurator". The default password
for configurator access level is 2.
2. Set the rated values in menu [CONF] including at least
current transformers and a protected transformer rating.
Also the date and time settings are in this same main
menu.
3. Enable the needed protection functions and disable the rest
of the protection functions in main menu [Prot].
4. Set the setting parameter of the enable protection stages
according the application.
5. Connect the output relays to the start and trip signals of the
enabled protection stages using the output matrix. This can
be done in main menu [DO], although the VAMPSET
program is recommended for output matrix editing.
6. Configure the needed digital inputs in main menu [DI].
7. Configure blocking and interlockings for protection stages
using the block matrix. This can be done in main menu
[Prot], although VAMPSET is recommended for block
matrix editing.
Some of the parameters can only be changed via the RS-232
serial port using the VAMPSET software. Such parameters,
(for example passwords, blockings and mimic configuration) are
normally set only during commissioning.
Some of the parameters require the restarting of the relay. This
restarting is done automatically when necessary. If a
parameter change requires restarting, the display will show as
Figure 2.4-1.
Figure 2.4-1 Example of auto-reset display
Press CANCEL to return to the setting view. If a parameter
must be changed, press the ENTER key again. The parameter
can now be set. When the parameter change is confirmed with
the ENTER key, a [RESTART]- text appears to the top-right
corner of the display. This means that auto-resetting is
2.4 Configuration and parameter
setting
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Operation and configuration
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pending. If no key is pressed, the auto-reset will be executed
within few seconds.
2.4.1. Parameter setting
1. Move to the setting state of the desired menu (for example
CONF/CURRENT SCALING) by pushing the ENTER key.
The Pick text appears in the upper-left part of the display.
2. Enter the password associated with the configuration level
by pushing the INFO key and then using the arrow keys
and the ENTER key (default value is 0002). For more
information about the access levels, please refer to Chapter
2.2.5.
3. Scroll through the parameters using the UP and DOWN
keys. A parameter can be set if the background color of the
line is black. If the parameter cannot be set the parameter
is framed.
4. Select the desired parameter (for example Inom) with the
ENTER key.
5. Use the UP and DOWN keys to change a parameter value.
If the value contains more than one digit, use the LEFT and
RIGHT keys to shift from digit to digit, and the UP and
DOWN keys to change the digits.
6. Push the ENTER key to accept a new value. If you want to
leave the parameter value unchanged, exit the edit state by
pushing the CANCEL key.
Figure 2.4.1-1.Changing parameters
Operation and configuration
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2.4 Configuration and parameter
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2.4.2. Setting range limits
If the given parameter setting values are out-of-range values, a
fault message will be shown when the setting is confirmed with
the ENTER key. Adjust the setting to be within the allowed
range.
Figure 2.4.2-1 Example of a fault message
The allowed setting range is shown in the display in the setting
mode. To view the range, push the INFO key. Push the
CANCEL key to return to the setting mode.
Figure 2.4.2-2. Allowed setting ranges show in the display
2.4 Configuration and parameter
setting
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Operation and configuration
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2.4.3. Disturbance recorder menu DR
Via the submenus of the disturbance recorder menu the
following functions and features can be read and set:
DISTURBANCE RECORDER
Recording mode (Mode)
Sample rate (Rate)
Recording time (Time)
Pre trig time (PreTrig)
Manual trigger (MnlTrig)
Count of ready records (ReadyRe)
REC. COUPLING
Add a link to the recorder (AddLink)
Clear all links (ClrLnks)
Available links:
DO, DI
IL, I’L
I2/In, I2/I1, I2, I1, IoCalc, I2/In, I’2/I’1, I’2, I’1, I’oCalc
f
Io2, Io1
IL3, IL2, IL1, I’L3, I’L2, I’L1
IL1RMS, IL2RMS, IL3RMS
ILmin, ILmax, I’Lmin, I’Lmax
ΔIl1, ΔIl2, ΔIl3
IL1w, IL2w, IL3w, I’L1w, I’L2w, I’L3w
2.4.4. Configuring digital inputs DI
The following functions can be read and set via the submenus
of the digital inputs menu:
The status of digital inputs (DIGITAL INPUTS 1-6)
Operation counters (DI COUNTERS)
Operation delay (DELAYs for DigIn)
The polarity of the input signal (INPUT POLARITY). Either
normally open (NO) or normally closed (NC) circuit.
Event enabling EVENT MASK1
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2.4.5. Configuring digital outputs DO
The following functions can be read and set via the submenus
of the digital outputs menu:
The status of the output relays (RELAY OUTPUTS1 and 2)
The forcing of the output relays (RELAY OUTPUTS1 and 2)
(only if Force = ON):
o Forced control (0 or 1) of the Trip relays
o Forced control (0 or 1) of the Alarm relays
o Forced control (0 or 1) of the IF relay
The configuration of the output signals to the output relays.
The configuration of the operation indicators (LED) Alarm
and Trip and application specific alarm leds A, B and C
(that is, the output relay matrix).
NOTE! The amount of Trip and Alarm relays depends on the relay type and
optional hardware.
2.4.6. Protection menu Prot
The following functions can be read and set via the submenus
of the Prot menu:
Reset all the counters (PROTECTION SET/ClAll)
Read the status of all the protection functions (PROTECT
STATUS 1-x)
Enable and disable protection functions (ENABLED
STAGES 1-x)
Define the interlockings between signals (only with
VAMPSET).
Each stage of the protection functions can be disabled or
enabled individually in the Prot menu. When a stage is
enabled, it will be in operation immediately without a need to
reset the relay.
The relay includes several protection functions. However, the
processor capacity limits the number of protection functions
that can be active at the same time.
2.4 Configuration and parameter
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2.4.7. Configuration menu CONF
The following functions and features can be read and set via
the submenus of the configuration menu:
DEVICE SETUP
Bit rate for the command line interface in ports X4 and the
front panel. The front panel is always using this setting. If
SPABUS is selected for the rear panel local port X4, the bit
rate is according SPABUS settings.
Access level [Acc]
LANGUAGE
List of available languages in the relay
CURRENT SCALING
Rated phase CT primary current (Inom)
Rated phase CT secondary current (Isec)
Rated input of the relay [Iinput]. 5 A or 1 A. This is specified
in the order code of the device.
Rated phase CT’ primary current (I’nom)
Rated phase CT’ secondary current (I’sec)
Rated input of the relay [I’input]. 5 A or 1 A. This is
specified in the order code of the device.
Rated value of I
Rated value of I
Rated I01 input of the relay [Ioinp]. 5 A or 1 A. This is
specified in the order code of the device.
Rated value of I
Rated value of I
Rated I02 input of the relay [Io2inp]. 5A, 1 A or 0.2 A. This
is specified in the order code of the device.
The rated input values are usually equal to the rated secondary
value of the CT.
CT primary current (Ionom)
0
CT secondary current (Iosec)
0
CT primary current (Io2nom)
02
CT secondary current (Io2sec)
02
The rated CT secondary may be greater than the rated input
but the continuous current must be less than four times the
rated input. In compensated, high impedance earthed and
isolated networks using cable transformer to measure residual
current I0, it is quite usual to use a relay with 1 A or 0.2 A
input although the CT is 5 A or 1A. This increases the
measurement accuracy.
The rated CT secondary may also be less than the rated input
but the measurement accuracy near zero current will decrease.
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TRANSFORMER SETTING
Rated voltage in IL side (typically high voltage side)
Rated voltage in I’L side (typically low voltage side)
Rated power of transformer
Connection group of transformer
Zero current compensation in IL side (If transformer is
earthed in IL side, this must set as “ON”)
Zero current compensation in I’L side (If transformer is
earthed in I’L side, this must set as “ON”)
Connection group of the unit transformer, if any. IEC
marking with capital letters Y and D for HV side and small
case letters y and d for LV side combined with the dial hour
is used. For example Yd11 means a wye-delta transformer
where the delta side phase-to-ground voltages are leading
30 the wye side phase-to-ground voltages.
DEVICE INFO
Relay type (Type VAMP 265)
Serial number (SerN)
Software version (PrgVer)
Bootcode version (BootVer)
DATE/TIME SETUP
Day, month and year (Date)
Time of day (Time)
Date format (Style). The choices are "yyyy-mm-dd",
"dd.nn.yyyy" and "mm/dd/yyyy".
CLOCK SYNCHRONISATION
Digital input for minute sync pulse (SyncDI). If any digital
input is not used for synchronization, select "".
Daylight saving time for NTP synchronization (DST).
Detected source of synchronization (SyScr).
Synchronization message counter (MsgCnt).
Latest synchronization deviation (Dev).
The following parameters are visible only when the access level
is higher than "User".
Offset, i.e. constant error, of the synchronization source
(SyOS).
Auto adjust interval (AAIntv).
Average drift direction (AvDrft): "Lead" or "lag".
Average synchronization deviation (FilDev).
2.4 Configuration and parameter
setting
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2.4.8. Protocol menu Bus
There are three communication ports in the rear panel. In
addition there is a connector in the front panel overruling the
local port in the rear panel.
REMOTE PORT X5
Communication protocol for remote port X5 [Protocol].
Message counter [Msg#]. This can be used to verify that the
device is receiving messages.
Communication error counter [Errors].
Communication time-out error counter [Tout].
Information of bit rate/data bits/parity/stop bits.
This value is not directly editable. Editing is done in the
appropriate protocol setting menus.
The counters are useful when testing the communication.
LOCAL PORT X4 (pins 2, 3 and 5)
This port is disabled, if a cable is connected to the front panel
connector.
Communication protocol for the local port X4 [Protocol]. For
VAMPSET use "None" or "SPABUS".
Message counter [Msg#]. This can be used to verify that the
device is receiving messages.
Communication error counter [Errors].
Communication time-out error counter [Tout].
Information of bit rate/data bits/parity/stop bits.
This value is not directly editable. Editing is done in the
appropriate protocol setting menus. For VAMPSET and
protocol "None" the setting is done in menu CONF/DEVICE
SETUP.
PC (LOCAL/SPA BUS)
This is a second menu for local port X4. The VAMPSET
communication status is showed.
Bytes/size of the transmitter buffer [Tx].
Message counter [Msg#]. This can be used to verify that the
device is receiving messages.
Communication error counter [Errors]
Communication time-out error counter [Tout].
Same information as in the previous menu.
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EXTENSION PORT X4 (pins 7, 8 and 5)
Communication protocol for extension port X4 [Protocol].
Message counter [Msg#]. This can be used to verify that the
device is receiving messages.
Communication error counter [Errors].
Communication time-out error counter [Tout].
Information of bit rate/data bits/parity/stop bits.
This value is not directly editable. Editing is done in the
appropriate protocol setting menus.
Ethernet port
These parameters are used by the ethernet interface. For
changing the nnn.nnn.nnn.nnn style parameter values,
VAMPSET is recommended.
Ethernet port protocol [Protoc].
IP Port for protocol [Port]
IP address [IpAddr].
Net mask [NetMsk].
Gateway [Gatew].
Name server [NameSw].
Network time protocol (NTP) server [NTPSvr].
TCP Keep alive interval [KeepAlive]
MAC address [MAC]
IP Port for Vampset [VS Port]
Message counter [Msg#]
Error counter [Errors]
Timeout counter [Tout]
MODBUS
Modbus addres for this slave device [Addr]. This address
has to be unique within the system.
Modbus bit rate [bit/s]. Default is "9600".
Parity [Parity]. Default is "Even".
For details see the technical description part of the manual.
EXTERNAL I/O protocol
This is a Modbus master protocol to communicate with the
extension I/O modules connected to the extension port. Only
one instance of this protocol is possible.
Bit rate [bit/s]. Default is "9600".
Parity [Parity]. Default is "Even".
For details see the technical description part of the manual.
2.4 Configuration and parameter
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SPA BUS
Several instances of this protocol are possible.
SPABUS addres for this device [Addr]. This address has to
be unique within the system.
Bit rate [bit/s]. Default is "9600".
Event numbering style [Emode]. Default is "Channel".
For details see the technical description part of the manual.
IEC 60870-5-101
Bit rate [bit/s]. Default is “9600”.
[Parity].
Link layer address for this device [LLAddr].
ASDU address [ALAddr].
For details see the technical description part of the manual.
IEC 60870-5-103
Only one instance of this protocol is possible.
Address for this device [Addr]. This address has to be
unique within the system.
Bit rate [bit/s]. Default is "9600".
Minimum measurement response interval [MeasInt].
ASDU6 response time mode [SyncRe].
For details see the technical description part of the manual.
IEC 103 DISTURBANCE RECORDINGS
For details see the technical description part of the manual.
PROFIBUS
Only one instance of this protocol is possible.
[Mode]
Bit rate [bit/s]. Use 2400 bps. This parameter is the bit rate
between the main CPU and the Profibus ASIC. The actual
Profibus bit rate is automatically set by the Profibus master
and can be up to 12 Mbit/s.
Event numbering style [Emode].
Size of the Profibus Tx buffer [InBuf].
Size of the Profibus Rx buffer [OutBuf].
When configuring the Profibus master system, the length of
these buffers are needed. The size of the both buffers is set
indirectly when configuring the data items for Profibus.
Address for this slave device [Addr]. This address has to be
unique within the system.
Profibus converter type [Conv]. If the shown type is a dash
“-“, either Profibus protocol has not been selected or the
device has not restarted after protocol change or there is a
communication problem between the main CPU and the
Profibus ASIC.
Operation and configuration
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2.4 Configuration and parameter
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For details see the technical description part of the manual.
DNP3
Only one instance of this protocol is possible.
Bit rate [bit/s]. Default is "9600".
[Parity].
Addres for this device [SlvAddr]. This address has to be
unique within the system.
Master's addres [MstrAddr].
For further details see the technical description part of the
manual.
2.4.9. Single line diagram editing
The single-line diagram is drawn with the VAMPSET software.
For more information, please refer to the VAMPSET manual
(VMV.EN0xx).
Figure 2.4.9-1. Single line diagram.
2.4.10. Blocking and interlocking configuration
The configuration of the blockings and interlockings is done
with the VAMPSET software. Any start or trip signal can be
used for blocking the operation of any protection stage.
Furthermore, the interlocking between objects can be
configured in the same blocking matrix of the VAMPSET
software. For more information, please refer to the VAMPSET
manual (VMV.EN0xx).
3 VAMPSET PC software
Operation and configuration
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3. VAMPSET PC software
The PC user interface can be used for:
On-site parameterization of the relay
Loading relay software from a computer
Reading measured values, registered values and events to a
computer.
Continuous monitoring of all values and events.
Two RS 232 serial ports are available for connecting a local PC
with VAMPSET to the relay; one on the front panel and one on
the rear panel of the relay. These two serial ports are connected
in parallel. However, if the connection cables are connected to
both ports, only the port on the front panel will be active. To
connect a PC to a serial port, use a connection cable of type VX
003-3.
The VAMPSET program can also use TCP/IP LAN connection.
Optional hardware is required.
There is a free of charge PC program called VAMPSET
available for configuration and setting of VAMP relays. Please
download the latest VAMPSET.exe from our web page
www.vamp.fi. For more information about the VAMPSET
software, please refer to the user’s manual with the code
VMV.EN0xx. Also the VAMPSET user’s manual is available at
our web site.
Technical description Table of Contents
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Table of Contents
1. Introduction .......................................................................... 42
1.1. Main features ................................................................... 43
1.2. Principles of numerical protection techniques .......... 44
2. Protection functions ............................................................. 46
2.1. Maximum number of protection stages in one
application ................................................................................ 46
2.2. List of protection functions ............................................. 46
2.3. General features of protection stages ........................ 47
2.4. Differential overcurrent protection ΔI> (87) ................ 51
2.5. Overcurrent protection I> (50/51) ................................ 56
2.6. Current unbalance protection I2>, I’2> (46) ................ 60
2.7. Earth fault protection I0> (50N/51N) ............................. 63
2.8. Thermal overload protection T> (49) ........................... 68
2.9. Second harmonic O/C stage If2>(51F2) ...................... 72
2.10. Circuit-breaker failure protection CBFP (50BF) ........... 73
2.11. Arc fault protection (50ARC/50NARC) (optional) ..... 75
2.12. Programmable stages (99) ............................................ 79
2.13. Inverse time operation ................................................... 81
2.13.1. Standard inverse delays IEC, IEEE, IEEE2, RI ........ 84
2.13.2. Free parametrisation using IEC, IEEE and IEEE2
equations ............................................................................. 94
2.13.3. Programmable inverse time curves ..................... 95
3. Supporting functions ............................................................ 96
3.1. Event log ........................................................................... 96
3.2. Disturbance recorder ..................................................... 98
3.3. Current transformer supervision .................................. 103
3.4. Circuit breaker condition monitoring ......................... 104
3.5. System clock and synchronization ............................. 109
3.6. Running hour counter ................................................... 112
3.7. Timers ............................................................................... 113
3.8. Combined overcurrent status ..................................... 115
3.9. Self-supervision ............................................................... 117
4. Measurement functions ..................................................... 118
4.1. Measurement accuracy .............................................. 119
4.2. Harmonics and Total Harmonic Distortion (THD) ...... 120
4.3. RMS values ..................................................................... 120
4.4. Demand values ............................................................. 121
4.5. Minimum and maximum values.................................. 121
4.6. Maximum values of the last 31 days and twelve
months ..................................................................................... 122
4.7. Primary, secondary and per unit scaling................... 123
4.7.1. Current scaling ...................................................... 123
5. Control functions ................................................................ 126
5.1. Output relays ................................................................. 126
5.2. Digital inputs ................................................................... 127
Table of Contents Technical description
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VM265.EN011
5.3. Virtual inputs and outputs ............................................ 129
5.4. Output matrix ................................................................. 130
5.5. Blocking matrix .............................................................. 131
5.6. Controllable objects ..................................................... 132
5.6.1. Local/Remote selection ...................................... 134
5.7. Logic functions .............................................................. 134
6. Communication ................................................................. 135
6.1. Communication ports .................................................. 135
6.1.1. Local port X4 ......................................................... 136
6.1.2. Remote port X5 ..................................................... 138
6.1.3. Extension port X4 ................................................... 139
6.1.4. Ethernet port .......................................................... 140
6.2. Communication protocols .......................................... 141
6.2.1. PC communication .............................................. 141
6.2.2. Modbus TCP and Modbus RTU ........................... 141
6.2.3. Profibus DP ............................................................. 142
6.2.4. SPA-bus ................................................................... 144
6.2.5. IEC 60870-5-103 ..................................................... 145
6.2.6. DNP 3.0 ................................................................... 147
6.2.7. IEC 60870-5-101 ..................................................... 148
6.2.8. External I/O (Modbus RTU master) ..................... 149
6.2.9. IEC 61850 ................................................................ 149
6.2.10. EtherNet/IP ............................................................. 151
7. Applications ........................................................................ 153
7.1. Restricted earth fault protection ................................ 153
7.2. Restricted earth fault protection for a transformer with
neutral connection ................................................................ 154
7.2.1. CT Requirements ................................................... 155
7.3. Calculating the stabilizing resistance RS, VDR value
and actual sensitivity ............................................................. 156
7.3.1. Value of stabilizing resistor RS .............................. 156
7.3.2. Voltage limitation ................................................. 157
7.3.3. Actual operating sensitivity ................................. 157
7.3.4. Example ................................................................. 158
7.4. Current Transformer Selection ..................................... 159
7.4.1. CT classification according IEC 60044-1, 1996 . 159
7.4.2. CT Requirement for Protection ........................... 162
7.5. Protection of a Dyn11 transformer ............................. 165
7.6. Protection of a YNd11 transformer ............................. 167
7.7. Protection of generator and block transformer ....... 168
7.8. Application example of differential protection using
VAMP 265 ................................................................................ 169
7.9. Trip Circuit Supervision .................................................. 170
7.9.1. Trip circuit supervision with one digital input .... 170
7.9.2. Trip circuit supervision with DI19 and DI20 ........ 178
8. Connections ....................................................................... 182
8.1. Rear panel view ............................................................ 182
Technical description Table of Contents
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8.2. Auxiliary voltage ............................................................ 186
8.3. Serial communication connectors ............................. 186
8.3.1. Front panel connector ......................................... 186
8.3.2. Rear panel connector X5 (REMOTE) .................. 187
8.3.3. X4 rear panel connector (local RS232 and
extension RS485 ports) ..................................................... 192
8.4. Optional two channel arc protection card.............. 192
8.5. Optional digital I/O card (DI19/DI20) ......................... 193
8.6. External I/O extension modules .................................. 194
8.6.1. External LED module VAM 16D ........................... 194
8.6.2. External input / output module .......................... 194
8.7. Block diagrams .............................................................. 200
8.8. Block diagrams of option modules ............................ 201
8.8.1. Optional arc protection ...................................... 201
8.8.2. Optional DI19/DI20 ............................................... 201
8.9. Connection examples .................................................. 202
9. Technical data ................................................................... 203
9.1. Connections................................................................... 203
9.1.1. Measuring circuitry ............................................... 203
9.1.2. Auxiliary voltage ................................................... 203
9.1.3. Digital inputs .......................................................... 204
9.1.4. Trip contacts .......................................................... 204
9.1.5. Alarm contacts ..................................................... 204
9.1.6. Local serial communication port ....................... 204
9.1.7. Remote control connection ............................... 205
9.1.8. Arc protection interface (option) ...................... 205
9.2. Tests and environmental conditions .......................... 205
9.2.1. Disturbance tests .................................................. 205
9.2.2. Test voltages .......................................................... 206
9.2.3. Mechanical tests .................................................. 206
9.2.4. Environmental conditions .................................... 206
9.2.5. Casing .................................................................... 206
9.2.6. Package................................................................. 206
9.3. Protection functions ...................................................... 207
9.3.1. Differential protection .......................................... 207
9.3.2. Non-directional current protection ................... 208
9.3.3. Second harmonic function ................................. 210
9.3.4. Circuit-breaker failure protection ...................... 210
9.3.5. Arc fault protection stages (option) .................. 211
9.4. Supporting functions ..................................................... 212
9.4.1. Disturbance recorder (DR) .................................. 212
10. Abbreviations and symbols .............................................. 213
11. Construction ....................................................................... 214
12. Order information ............................................................... 215
13. Revision history ................................................................... 216
14. Reference information ....................................................... 218
1.1 Main features
1 Introduction
Technical description
42
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VM265.EN011
1. Introduction
This part of the user manual describes the protection functions,
provides a few application examples and contains technical
data.
Mounting and commissioning instructions are given in a
separate mounting and commissioning manual
(VMMC.EN0xx).
The numerical VAMP differential protection include all the
essential protection functions needed to protect transformers
for distribution networks of utilities, industry, power plants
and offshore applications as well as motor and generator
differential protection. Further, the device includes several
programmable functions, such as arc (option), thermal and
circuit breaker protection and communication protocols for
various protection and communication situations.
The generator, transformer and motor differential protection
relay VAMP 265 can be used for selective differential
overcurrent, short-circuit protection of generators, transformers and motors in solidly or impedance earthed power
systems. The relay can also be used for single, two or threephase overcurrent and/or sensitive earth fault protection.
The modern technology in association with an extensive selfsupervision system and a reliable construction ensures an
extremely high availability for the VAMP 265 protection relay
Technical description
1 Introduction
1.1 Main features
VM265.EN011
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1.1. Main features
The main features of VAMP 265 are
Fully digital signal handling with a powerful 16-bit
microprocessor, and high measuring accuracy on all the
setting ranges due to an accurate 16-bit A/D conversion
technique.
Wide setting ranges for the protection functions, e.g. the
earth fault protection can reach a sensitivity of 0.5%.
The device can be matched to the requirements of the
application by disabling the functions that are not needed.
Flexible control and blocking possibilities due to digital
signal control inputs (DI) and outputs (DO).
Easy adaptability of the relay to various substations and
alarm systems due to flexible signal-grouping matrix in the
relay .
Freely configurable display with six measurement values.
Freely configurable interlocking schemes with basic logic
functions.
Recording of events and fault values into an event register
from which the data can be read via a keypad and a local
HMI or by means of a PC based VAMPSET user interface.
Latest events and indications are in non-volatile memory.
Easy configuration, parameterisation and reading of
information via local HMI, or with a VAMPSET user
interface.
Easy connection to power plant automation system due to a
versatile serial connection and several available
communication protocols.
Built-in, self-regulating ac/dc converter for auxiliary power
supply from any source within the range from 40 to 265 V dc
or ac. The alternative power supply is for 18 to 36 V dc.
Built-in disturbance recorder for evaluating all the analogue
and digital signals.
Eight (8) programmable stages for alarming or protection
purposes
1.2 Principles of numerical
protection techniques
1 Introduction
Technical description
44
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VM265.EN011
1.2. Principles of numerical protection
techniques
The manager is using numerical technology. This means that
all the signal filtering, protection and control functions are
implemented through digital processing.
The numerical technique used in the manager is primarily
based on an adapted Fast Fourier Transformation (FFT)
algorithm. Synchronized sampling of the measured voltage and
current signals is used. The sample rate is 32 samples/cycle
within the frequency range 45 Hz ... 65 Hz. The frequency is
measured from the voltage signals and used to synchronize the
sampling rate. Therefore secondary testing of a brand new
device should be started with voltage protection functions and
voltage injection to let the relay learn the local frequency. The
learned frequency is used for sampling rate synchronization
when no voltage is present. The local network frequency can
also be manually given for the relay.
Apart from the FFT calculations, some protection functions also
require the symmetrical components to be calculated for
obtaining the positive, negative and zero phase sequence
components of the measured quantity. For example, the
function of the unbalanced load protection stage is based on the
use of the negative phase sequence component of the current.
Figure 1.2-1 shows a hardware block diagram of the relay. The
main components are the current and voltage inputs, digital
input elements, output relays, A/D converters and the
microcomputer and a power supply unit.
Figure 1.2-2 shows the inputs and outputs of a general
protection function. The FFT block is calculating the
fundamental frequency phasors and also harmonics used by
some protection functions. The block matrix is used for simple
interlocking. (More complex interlocking is done with the
user's programmable logic.) The output matrix is used to
connect the pick-up and trip signals from protection blocks to
the output relays and indicators.
Figure 1.2-3 shows a block diagram of a basic overcurrent or
overvoltage function with definite and inverse operation time.
Technical description
1 Introduction
1.2 Principles of numerical
protection techniques
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Figure 1.2-1. Principle block diagram of the VAMP 265 hardware.
Figure 1.2-2. Block diagram of signal processing and protection software.
Figure 1.2-3. Block diagram of a basic protection function.
2.1 Maximum number of protection
stages in one application
2 Protection functions
Technical description
46
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VM265.EN011
IEEE/
ANSI code
IEC symbol
Function name
50/51
3I>, 3I>>, 3I‟>,
3I‟>>
Overcurrent protection
87
∆I>, ∆I>>
Differential overcurrent protection
46
I2>, I‟2>
Current unbalance protection
49
T>
Thermal overload protection
50N/51N
I0>,
I0>>,
I0>>>,
I0>>>>
Earth fault protection
50BF
CBFP
Circuit-breaker failure protection
99
Prg1...8
Programmable stages
50ARC
50NARC
ArcI>, ArcI‟>
ArcI01>, ArcI02>
Optional arc fault protection
2. Protection functions
Each protection stage can independently be enabled or disabled
according to the requirements of the intended application.
2.1. Maximum number of protection
stages in one application
The device limits the maximum number of enabled stages to
about 30, depending of the type of the stages. For more
information, please see the configuration instructions in
chapter 2.4 in the first part of this manual.
2.2. List of protection functions
Technical description
2 Protection functions
2.3 General features of protection
stages
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Ok = „„
The stage is not detecting any fault.
Blocked
The stage is detecting a fault but blocked by
some reason.
Start
The stage is counting the operation delay.
Trip
The stage has tripped and the fault is still on.
2.3. General features of protection stages
Setting groups
Most stages have two setting groups. Changing between
setting groups can be controlled manually or using any of the
digital inputs, virtual inputs, virtual outputs or LED indicator
signals. By using virtual I/O the active setting group can be
controlled using the local panel mimic display, any
communication protocol or using the inbuilt programmable
logic functions.
Forcing start or trip condition for testing
The status of a protection stage can be one of the followings:
The blocking reason may be an active signal via the block
matrix from other stages, the programmable logic or any digital
input. Some stages also have inbuilt blocking logic. For
example an under frequency stage is blocked if voltage is too
low. For more details about block matrix, see chapter 5.5.
Forcing start or trip condition for testing purposes
There is a "Force flag" parameter which, when activated, allows
forcing the status of any protection stage to be "start" or "trip"
for a half second. By using this forcing feature any current or
voltage injection to the relay is not necessary to check the
output matrix configuration, to check the wiring from the
output relays to the circuit breaker and also to check that
communication protocols are correctly transferring event
information to a SCADA system.
After testing the force flag will automatically reset 5-minute
after the last local panel push button activity.
The force flag also enables forcing of the output relays and
forcing the optional mA outputs.
2.3 General features of protection
stages
2 Protection functions
Technical description
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VM265.EN011
Start and trip signals
Every protection stage has two internal binary output signals:
start and trip. The start signal is issued when a fault has been
detected. The trip signal is issued after the configured
operation delay unless the fault disappears before the end of
the delay time.
Output matrix
Using the output matrix the user connects the internal start
and trip signals to the output relays and indicators. For more
details see chapter 5.4.
Blocking
Any protection function, except arc protection, can be blocked
with internal and external signals using the block matrix
(chapter 5.5). Internal signals are for example logic outputs and
start and trip signals from other stages and external signals
are for example digital and virtual inputs.
Some protection stages have also inbuilt blocking functions. For
example under-frequency protection has inbuilt under-voltage
blocking to avoid tripping when the voltage is off.
When a protection stage is blocked, it won't pick-up in case of a
fault condition is detected. If blocking is activated during the
operation delay, the delay counting is frozen until the blocking
goes off or the pick-up reason, i.e. the fault condition,
disappears. If the stage is already tripping, the blocking has no
effect.
Retardation time
Retardation time is the time a protection relay needs to notice,
that a fault has been cleared during the operation time delay.
This parameter is important when grading the operation time
delay settings between relays.
Figure 2.3-1. Definition for retardation time. If the delay setting would be
slightly shorter, an unselective trip might occur (the dash line pulse).
Technical description
2 Protection functions
2.3 General features of protection
stages
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For example when there is a big fault in an outgoing feeder, it
might start i.e. pick-up both the incoming and outgoing feeder
relay. However the fault must be cleared by the outgoing
feeder relay and the incoming feeder relay must not trip.
Although the operating delay setting of the incoming feeder is
more than at the outgoing feeder, the incoming feeder might
still trip, if the operation time difference is not big enough. The
difference must be more than the retardation time of the
incoming feeder relay plus the operating time of the outgoing
feeder circuit breaker.
Figure 2.3-1 shows an overcurrent fault seen by the incoming
feeder, when the outgoing feeder does clear the fault. If the
operation delay setting would be slightly shorter or if the fault
duration would be slightly longer than in the figure, an
unselective trip might happen (the dashed 40 ms pulse in the
figure). In VAMP relays the retardation time is less than 50
ms.
Reset time (release time)
Figure 2.3-2 shows an example of reset time i.e. release delay,
when the relay is clearing an overcurrent fault. When the
relay's trip contacts are closed the circuit breaker (CB) starts to
open. After the CB contacts are open the fault current will still
flow through an arc between the opened contacts. The current
is finally cut off when the arc extinguishes at the next zero
crossing of the current. This is the start moment of the reset
delay. After the reset delay the trip contacts and start contact
are opened unless latching is configured. The reset time varies
from fault to fault depending on the fault size. After a big fault
the time is longer. The reset time also depends on the specific
protection stage. The maximum reset time for each stage is
specified in chapter 9.3. For most stages it is less than 95 ms.
Figure 2.3-2. Reset time is the time it takes the trip or start relay contacts
to open after the fault has been cleared.
2.3 General features of protection
stages
2 Protection functions
Technical description
50
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VM265.EN011
Hysteresis or dead band
When comparing a measured value against a pick-up value,
some amount of hysteresis is needed to avoid oscillation near
equilibrium situation. With zero hysteresis any noise in the
measured signal or any noise in the measurement itself would
cause unwanted oscillation between fault-on and fault-off
situations.
Figure 2.3-3. Behaviour of a greater than comparator. For example in
overcurrent and overvoltage stages the hysteresis (dead band) acts
according this figure.
Figure 2.3-4. Behaviour of a less than comparator. For example in undervoltage and under frequency stages the hysteresis (dead band) acts
according this figure.
Technical description
2 Protection functions
2.4 Differential overcurrent
protection ΔI> (87)
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3
3
3
133
322
211
LLWL
LLWL
LLWL
III
III
III
2.4. Differential overcurrent protection ΔI>
(87)
The differential overcurrent protection comprises two
separately adjustable stages, stage I> and stage I>>.
The differential protection is based on winding currents
difference between IL and I‟L side. In transformer applications
the current calculation depends on transformer connection
group. E.g. in Yy0 connection measured currents are also
winding currents, see Figure 2.4-1. In generator applications
the connection group is always Yy0 and measured currents are
also winding currents.
Figure 2.4-1 Winding currents in connection group Yy0.
In the second example if transformer IL side is connected to
open delta, e.g. Dy11, then winding currents are calculated in
delta side (IL side), see Figure 2.4-2.
Figure 2.4-2 Winding currents in connection group Dy11.
Equation 1: Winding current calculation in delta side, Dy11
connection
2.4 Differential overcurrent
protection ΔI> (87)
2 Protection functions
Technical description
52
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VM265.EN011
33
22
11
''
''
''
LWL
LWL
LWL
II
II
II
2
'WW
b
III
WW
d
III '
Equation 2: Winding currents in star side, Dy11 connection
Equation 3: Bias current
Equation 4: Differential current
Bias current calculation is only used in protection stage I>.
Bias current describes the average current flow in transformer.
Bias and differential currents are calculated individually for
each phase.
If transformer is earthed, e.g. connection group Dyn11, then
zero current must be compensated before differential and bias
current calculation. Zero current compensation can be selected
individually for IL and I‟L side.
Table 2.4-1 describe connection group and zero current compensation for different connection groups. If protection area is only generator then connection group setting is always Yy0, see
Table 2.4-2. Also the settings of Un and U‟n are set to be the
same, e.g. generator nominal voltage.
Technical description
2 Protection functions
2.4 Differential overcurrent
protection ΔI> (87)
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Transformator
Relay setting
Connection group
ConnGrp
Io cmps
I'o cmps
YNy0
Yy0
ON
OFF
YNyn0
Yy0
ON
ON
Yy0
Yy0
OFF
OFF
Yyn0
Yy0
OFF
ON
YNy6
Yy6
ON
OFF
YNyn6
Yy6
ON
ON
Yy6
Yy6
OFF
OFF
Yyn6
Yy6
OFF
ON
Yd1
Yd1
OFF
OFF
YNd1
Yd1
ON
OFF
Yd5
Yd5
OFF
OFF
YNd5
Yd5
ON
OFF
Yd7
Yd7
OFF
OFF
YNd7
Yd7
ON
OFF
Yd11
Yd11
OFF
OFF
YNd11
Yd11
ON
OFF
Dy1
Dy1
OFF
OFF
Dyn1
Dy1
OFF
ON
Dy5
Dy5
OFF
OFF
Dyn5
Dy5
OFF
ON
Dy7
Dy7
OFF
OFF
Dyn7
Dy7
OFF
ON
Dy11
Dy11
OFF
OFF
Dyn11
Dy11
OFF
ON
Genarator only
Relay setting
ConnGrp
Io cmps
I'o cmps
None earthing
Yy0
OFF
OFF
Table 2.4-1 Zero current compensation in transformer applications
Table 2.4-2 Zero current compensation in generator applications
2.4 Differential overcurrent
protection ΔI> (87)
2 Protection functions
Technical description
54
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VM265.EN011
Figure 2.4-3 Block diagram of the differential overcurrent stage I>.
The stage I> can be configured to operate as shown in Figure
2.4-4. This dual slope characteristic allows more differential
current at higher currents before tripping.
Figure 2.4-4 Example of differential overcurrent characteristics.
The stage also includes second harmonics blocking. The second
harmonic is calculated from winding currents. Harmonic ratio
is:
100 x I
f2_Winding
/ I
Fast differential overcurrent stage I>> does not include slope
characteristics and second harmonics blocking.
f1_Winding
[%].
Technical description
2 Protection functions
2.4 Differential overcurrent
protection ΔI> (87)
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Parameter
Value/unit
Measured
values (1
L1
L2
L3
xIn
Current difference value
Setting
values (2
I>
%ln
Setting value
Slope1
%
Slope 1 setting
Ibias2
xIn
Bias current start of slope 2
Slope2
%
Slope 2 setting
Harm2>
On/Off
2. harmonic blocking
enable/disable
Harm2>
%
2. harmonic block limit
TCntr
Cumulative trip counter
Type
1-N, 2-N,
3-N
Fault type/single-phase fault e.g.:
1-N = fault on phase L1
1-2, 2-3,
1-3
Fault type/two-phase fault e.g.: 2-3
= fault between L2 and L3
1-2-3
Fault type/three-phase fault
Flt
xIn
Max. value of fault differential
current as compared to In
Bias
xIn
Value of bias current of faulted
phase as compared to In
Load
xIn
1 s mean value of pre-fault phase
currents IL1…IL3
Parameters of the differential overcurrent stages I>> (87):
Parameter
Value/unit
Measured
values
L1
L2
L3
xIn
Current difference value
Setting
values
I>>
xIn
Setting value
Recorded
values
TCntr
Cumulative trip counter
Type
1-N, 2-N,
3-N
Fault type/single-phase fault e.g.:
1-N = fault on phase L1
1-2, 2-3,
1-3
Fault type/two-phase fault e.g.: 2-3
= fault between L2 and L3
1-2-3
Fault type/three-phase fault
Flt
xIn
Max. value of fault differential
current as compared to In
Load
xIn
1 s mean value of pre-fault phase
currents IL1…IL3
Parameters of the differential overcurrent stages I> (87):
1) Measurement ranges are described in section 9.1.1.
2) Setting ranges are described in section 9.3.2.
2.5 Overcurrent protection I>
(50/51)
2 Protection functions
Technical description
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2.5. Overcurrent protection I> (50/51)
Overcurrent protection is used against short circuit faults and
heavy overloads.
The overcurrent function measures the fundamental frequency
component of the phase currents. The protection is sensitive for
the highest of the three phase currents. Whenever this value
exceeds the user's pick-up setting of a particular stage, this
stage picks up and a start signal is issued. If the fault
situation remains on longer than the user's operation delay
setting, a trip signal is issued.
Two independent stages
There are two separately adjustable overcurrent stages: I>, I>>
I‟>and I‟>>. The first stage I> can be configured for definite
time (DT) or inverse time operation characteristic (IDMT). The
stage I>> has definite time operation characteristic. By using
the definite delay type and setting the delay to its minimum, an
instantaneous (ANSI 50) operation is obtained.
Figure 2.5-1 shows a functional block diagram of the I>
overcurrent stage with definite time and inverse time operation
time. Figure 2.5-2 shows a functional block diagram of the I>>
overcurrent stage with definite time operation delay.
Inverse operation time
Inverse delay means that the operation time depends on the
amount the measured current exceeds the pick-up setting. The
bigger the fault current is the faster will be the operation.
Accomplished inverse delays are available for the I> stage. The
inverse delay types are described in chapter 2.13. The relay will
show the currently used inverse delay curve graph on the local
panel display.
Inverse time limitation
The maximum measured secondary current is 50xIN. This
limits the scope of inverse curves with high pick-up settings.
See chapter 2.13 for more information.
Setting groups
There are two settings groups available for each stage.
Switching between setting groups can be controlled by digital
inputs, virtual inputs (mimic display, communication, logic)
and manually.
Technical description
2 Protection functions
2.5 Overcurrent protection I>
(50/51)
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Parameter
Value
Unit
Description
Note
Status
Blocked
Start
Trip
Current status of the stage
F
F
TripTime
s Estimated time to trip
SCntr
Cumulative start counter
Clr
TCntr
Cumulative trip counter
Clr
SetGrp
1 or 2
Active setting group
Set
SGrpDI
-
DIx
VIx
LEDx
VOx
Digital signal to select the
active setting group
None
Digital input
Virtual input
LED indicator signal
Virtual output
Set
Force
Off
On
Force flag for status forcing for
test purposes. This is a
common flag for all stages and
output relays, too. This flag is
automatically reset 5 minutes
after the last front panel push
button pressing.
Set
ILmax A
The supervised value. Max. of
IL1, IL2 and IL3
Figure 2.5-1 Block diagram of the three-phase overcurrent stage I> and I'>.
Figure 2.5-2 Block diagram of the three-phase overcurrent stage I>> and
I‟>>.
Parameters of the overcurrent stage I> and I’> (50/51)
2.5 Overcurrent protection I>
(50/51)
2 Protection functions
Technical description
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Parameter
Value
Unit
Description
Note
I> A
Pick-up value scaled to
primary value
I> xIgn
Pick-up setting
Set
Curve
DT
IEC
IEEE
IEEE2
RI
PrgN
Delay curve family:
Definite time
Inverse time. See chapter 2.13.
Pre 1996
Set
Type
DT
NI
VI
EI
LTI
Paramet
ers
Delay type.
Definite time
Inverse time. See chapter 2.13.
Set
t> s
Definite operation time (for
definite time only)
Set
k>
Inverse delay multiplier (for
inverse time only)
Set
Dly20x
s Delay at 20xIset
Dly4x s
Delay at 4xIset
Dly2x s
Delay at 2xIset
Dly1x s
Delay at 1xIset
A, B, C, D,
E
User's constants for standard
equations. Type=Parameters.
See chapter 2.13.
Set
For details of setting ranges see chapter 9.3.
Set = An editable parameter (password needed)
C = Can be cleared to zero
F = Editable when force flag is on
Technical description
2 Protection functions
2.5 Overcurrent protection I>
(50/51)
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Parameter
Value
Unit
Description
Note
Status
Blocked
Start
Trip
Current status of the stage
F
F
SCntr
Cumulative start counter
C
TCntr
Cumulative trip counter
C
SetGrp
1 or 2
Active setting group
Set
SGrpDI
-
DIx
VIx
LEDx
VOx
Digital signal to select the
active setting group
None
Digital input
Virtual input
LED indicator signal
Virtual output
Set
Force
Off
On
Force flag for status forcing for
test purposes. This is a
common flag for all stages and
output relays, too.
Automatically reset by a 5minute timeout.
Set
ILmax A
The supervised value. Max. of
IL1, IL2 and IL3
I>>, I>>>
A Pick-up value scaled to
primary value
I>>, I>>>
xIn
Pick-up setting
Set
t>>, t>>>
s Definite operation time
Set
Parameters of the overcurrent stages I>>, I’>> (50/51)
For details of setting ranges see chapter 9.3.
Set = An editable parameter (password needed)
C = Can be cleared to zero
F = Editable when force flag is on
Recorded values of the latest eight faults
There are detailed information available of the eight latest
faults: Time stamp, fault type, fault current, load current
before the fault, elapsed delay and setting group.
2.6 Current unbalance protection
I2>, I’2> (46)
2 Protection functions
Technical description
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Parameter
Value
Unit
Description
yyyy-mm-dd
Time stamp of the recording, date
hh:mm:ss.ms
Time stamp, time of day
Type
1-N
2-N
3-N
1-2
2-3
3-1
1-2-3
Fault type
Ground fault
Ground fault
Ground fault
Two phase fault
Two phase fault
Two phase fault
Three phase fault
Flt xIgn
Maximum fault current
Load
xIgn
1 s average phase currents before
the fault
EDly %
Elapsed time of the operating time
setting. 100% = trip
SetGrp
1
2
Active setting group during fault
2
2
2
2
1
K
I
I
K
t
N
t = Operation time
K1 = Delay multiplier
I2 = Measured and calculated negative sequence phase
current of fundamental frequency.
IN = Rated current
Recorded values of the overcurrent stages (8 latest faults)
I>, I>>, I>>> (50/51)
2.6. Current unbalance protection I
(46)
The current unbalance stage protects against unbalanced
phase currents and single phasing. The protection is based on
the negative sequence current.
Both definite time and inverse time characteristics are
available. The inverse delay is based on Equation 2.6-1. Only
the base frequency components of the phase currents are used
to calculate the negative sequence value I2.
Inverse delay
The inverse delay is based on the following equation.
Equation 2.6-1
, where
>, I’2>
2
Technical description
2 Protection functions
2.6 Current unbalance protection
I2>, I’2> (46)
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K2 = Pick-up setting I2> in pu. The maximum allowed
degree of unbalance.
K1 = 15 s
I2 = 22.9 % = 0.229 xIN
K2 = 5 % = 0.05 xIN
4.300
05.0
1
229.0
15
2
2
t
Example:
The operation time in this example will be five minutes.
More stages (definite time delay only)
If more than one definite time delay stages are needed for
current unbalance protection, the freely programmable stages
can be used (chapter 2.12).
Setting groups
There are two settings groups available. Switching between
setting groups can be controlled by digital inputs, virtual
inputs (mimic display, communication, logic) and manually.
Figure 2.6-1. Inverse operation delay of current unbalance stage I2>. The
longest delay is limited to 1000 seconds (=16min 40s).
2.6 Current unbalance protection
I2>, I’2> (46)
2 Protection functions
Technical description
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Parameter
Value
Unit
Description
Note
Status
Blocked
Start
Trip
Current status of the stage
F
F
SCntr
Cumulative start counter
C
TCntr
Cumulative trip counter
C
SetGrp
1 or 2
Active setting group
Set
SGrpDI
-
DIx
VIx
LEDx
VOx
Digital signal to select the
active setting group
None
Digital input
Virtual input
LED indicator signal
Virtual output
Set
Force
Off
On
Force flag for status forcing for
test purposes. This is a
common flag for all stages and
output relays, too.
Automatically reset by a 5minute timeout.
Set
I2/In %In
The supervised value.
I2> %In
Pick-up setting
Set
t> s
Definite operation time
(Type=DT)
Set
Type
DT
INV
Definite time
Inverse time (Equation )
Set
K1 s
Delay multiplier (Type =INV)
Set
Parameter
Value
Unit
Description
yyyy-mm-dd
Time stamp of the recording, date
hh:mm:ss.ms
Time stamp, time of day
Flt %In
Maximum unbalance current
EDly %
Elapsed time of the operating time
setting. 100% = trip
SetGrp
1
2
Active setting group during the
fault
Parameters of the current unbalance stage I2>, I’2> (46)
For details of setting ranges see chapter 9.3.
Set = An editable parameter (password needed)
C = Can be cleared to zero
F = Editable when force flag is on
Recorded values of the latest eight faults
There is detailed information available of the eight latest
faults: Time stamp, unbalance current, elapsed delay and
setting group.
Recorded values of the current unbalance stage (8 latest
faults) I2>, I’2> (46)
Technical description
2 Protection functions
2.7 Earth fault protection I0>
(50N/51N)
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2.7. Earth fault protection I
Undirectional earth fault protection is used for earth faults in
low impedance earthed networks. In high impedance earthed
networks, compensated networks and isolated networks
undirectional earth fault can be used as back-up protection.
The undirectional earth fault function is sensitive to the
fundamental frequency component of the residual current 3I0.
The attenuation of the third harmonic is more than 60 dB.
Whenever this fundamental value exceeds the user's pick-up
setting of a particular stage, this stage picks up and a start
signal is issued. If the fault situation remains on longer than
the user's operation time delay setting, a trip signal is issued.
> (50N/51N)
0
Figure 2.7-1. Block diagram of the earth fault stage I0>
Figure 2.7-2. Block diagram of the earth fault stages I0>>, I0>>> and I0>>>>
Figure 2.7-1 shows a functional block diagram of the I0> earth
overcurrent stage with definite time and inverse time operation
time. Figure 2.7-2 shows a functional block diagram of the
I0>>, I0>>> and I0>>>> earth fault stages with definite time
operation delay.
2.7 Earth fault protection I0>
(50N/51N)
2 Protection functions
Technical description
64
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Input signal selection
Each stage can be connected to supervise any of the following
inputs and signals:
Input I
Input I
Calculated signal I
earthed networks. I
Calculated signal I‟
earthed networks. I‟
for all networks other than rigidly earthed.
01
for all networks other than rigidly earthed.
02
for rigidly and low impedance
0Calc
= I
0Calc
for rigidly and low impedance
0Calc
0Calc
= I‟
L1
L1
+ I
+ I‟
L2
L2
+ IL3.
+ I‟
L3.
Additionally the stage I0> have two more input signal
alternatives to measure current peaks to detect a restriking
intermittent earth fault:
I
I
to measure the peak value of input I01.
01Peak
to measure the peak value of input I02.
02Peak
Intermittent earth fault detection
Short earth faults make the protection to start (pick up), but
will not cause trip. When starting happens often enough, such
intermittent faults can be cleared using the intermittent time
setting.
When a new start happens within the set intermittent time,
the operation delay counter is not cleared between adjacent
faults and finally the stage will trip. By using input signals
I
01Peak
or I
a single one-millisecond current peak is enough
02Peak
to start the stage and increase the delay counter by 20 ms. For
example if the operating time is 120 ms, and the time between
two peaks does not exceed the intermittent time setting, the
sixth peak will cause a trip.
Four independent undirectional earth fault overcurrent stages
There are four separately adjustable earth fault stages: I0>,
I0>>, I0>>>, and I0>>>>. The first stage I0> can be configured
for definite time (DT) or inverse time operation characteristic
(IDMT). The other stages have definite time operation
characteristic. By using the definite delay type and setting the
delay to its minimum, an instantaneous (ANSI 50N) operation
is obtained.
Technical description
2 Protection functions
2.7 Earth fault protection I0>
(50N/51N)
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Parameter
Value
Unit
Description
Note
Status
Blocked
Start
Trip
Current status of the stage
F
F
TripTime
s Estimated time to trip
SCntr
Cumulative start counter
Clr
TCntr
Cumulative trip counter
Clr
SetGrp
1 or 2
Active setting group
Set
SGrpDI
-
DIx
VIx
LEDx
VOx
Digital signal to select the
active setting group
None
Digital input
Virtual input
LED indicator signal
Virtual output
Set
Force
Off
On
Force flag for status forcing for
test purposes. This is a
common flag for all stages and
output relays, too.
Automatically reset by a 5minute timeout.
Set
Inverse operation time (I0> stage only)
Inverse delay means that the operation time depends on the
amount the measured current exceeds the pick-up setting. The
bigger the fault current is the faster will be the operation.
Accomplished inverse delays are available for the I0> stage.
The inverse delay types are described in chapter 2.13. The
relay will show a scaleable graph of the configured delay on the
local panel display.
Inverse time limitation
The maximum measured secondary residual current is 10xI0N
and maximum measured phase current is 50xIN. This limits the
scope of inverse curves with high pick-up settings. See chapter
2.13 for more information.
Setting groups
There are two settings groups available for each stage.
Switching between setting groups can be controlled by digital
inputs, virtual inputs (mimic display, communication, logic)
and manually.
Parameters of the undirectional earth fault stage
I0> (50N/51N)
2.7 Earth fault protection I0>
(50N/51N)
2 Protection functions
Technical description
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Parameter
Value
Unit
Description
Note
Io
Io2
IoCalc
IoPeak
Io2Peak
I‟oCalc
pu
The supervised value
according the parameter
"Input" below.
Io> A
Pick-up value scaled to
primary value
Io> pu
Pick-up setting relative to the
parameter "Input" and the
corresponding CT value
Set
Curve
DT
IEC
IEEE
IEEE2
RI
PrgN
Delay curve family:
Definite time
Inverse time. See chapter 2.13.
Set
Type
DT
NI
VI
EI
LTI
Parame-
ters
Delay type.
Definite time
Inverse time. See chapter 2.13.
Set
t> s
Definite operation time (for
definite time only)
Set
k>
Inverse delay multiplier (for
inverse time only)
Set
Input
Io1
Io2
IoCalc
Io1Peak
Io2Peak
I‟oCalc
X1-7&8. See chapter 8
X1-9&10
IL1 + IL2 + IL3
X1-7&8 peak mode
X1-9&10 peak mode
I‟L1 + I‟L2 + I‟L3
Set
Intrmt s
Intermittent time
Set
Dly20x
s Delay at 20xIset
Dly4x s
Delay at 4xIset
Dly2x s
Delay at 2xIset
Dly1x s
Delay at 1xIset
A, B, C, D,
E
User's constants for standard
equations. Type=Parameters.
See chapter 2.13.
Set
For details of setting ranges see chapter 9.3.
Set = An editable parameter (password needed)
C = Can be cleared to zero
F = Editable when force flag is on
Technical description
2 Protection functions
2.7 Earth fault protection I0>
(50N/51N)
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Parameter
Value
Unit
Description
Note
Status
Blocked
Start
Trip
Current status of the stage
F
F
TripTime
s Estimated time to trip
SCntr
Cumulative start counter
Clr
TCntr
Cumulative trip counter
Clr
SetGrp
1 or 2
Active setting group
Set
SGrpDI
-
DIx
VIx
LEDx
VOx
Digital signal to select the
active setting group
None
Digital input
Virtual input
LED indicator signal
Virtual output
Set
Force
Off
On
Force flag for status forcing for
test purposes. This is a
common flag for all stages and
output relays, too.
Automatically reset by a 5minute timeout.
Set
Io
Io2
IoCalc
pu
The supervised value
according the parameter
"Input" below.
Io>>
Io>>>
Io>>>>
A Pick-up value scaled to
primary value
Io>>
Io>>>
Io>>>>
pu
Pick-up setting relative to the
parameter "Input" and the
corresponding CT value
Set
t> s
Definite operation time (for
definite time only)
Set
Input
Io1
Io2
IoCalc
I‟oCalc
X1-7&8. See chapter 8
X1-9&10
IL1 + IL2 + IL3
I‟L1 + I‟L2 + I‟L3
Set
Parameters of the undirectional earth fault stages
I0>>, I0>>>, I0>>>> (50N/51N)
For details of setting ranges see chapter 9.3.
Set = An editable parameter (password needed)
C = Can be cleared to zero
F = Editable when force flag is on
Recorded values of the latest eight faults
There is detailed information available of the eight latest earth
faults: Time stamp, fault current, elapsed delay and setting
group.
2.8 Thermal overload protection T>
(49)
2 Protection functions
Technical description
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Parameter
Value
Unit
Description
yyyy-mm-dd
Time stamp of the recording, date
hh:mm:ss.ms
Time stamp, time of day
Flt pu
Maximum earth fault current
EDly %
Elapsed time of the operating time
setting. 100% = trip
SetGrp
1
2
Active setting group during fault
Trip time:
22
2
2
ln
aI
II
t
P
Alarm:
alarmIkka
e
mod
(Alarm 60% = 0.6)
Trip:
e
Ikka
mod
Release time:
22
2
ln
Ia
I
Ct
P
Trip release:
e
Ika
mod
95.0
Start release:
alarmIka
e
mod
95.0
(Alarm 60% = 0.6)
T = Operation time
=
Thermal time constant tau (Setting value)
ln = Natural logarithm function
I = Measured rms phase current (the max. value of
three phase currents)
Ip
=
Preload current,
nP
IkI
(If temperature
rise is 120%
2.1
). This parameter is the
memory of the algorithm and corresponds to the
actual temperature rise.
k = Overload factor (Maximum continuous current), i.e.
service factor. (Setting value)
Recorded values of the undirectional earth fault stages (8
latest faults) I0>, I0>>, I0>>>, I0>>>> (50N/51N)
2.8. Thermal overload protection T> (49)
The thermal overload function protects the transformer against
excessive temperatures.
Thermal model
The temperature is calculated using rms values of phase
currents and a thermal model according IEC 60255-8. The rms
values is calculated using harmonic components up to the 15th.
Technical description
2 Protection functions
2.8 Thermal overload protection T>
(49)
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k
=
Ambient temperature factor (Permitted current due
to tamb). See Figure 2.8-1
I
mode
=
The rated current (In or I
mot
)
C
=
Cooling time coefficient (cooling time constant =
C
x
n
IkkI
max
Time constant for cooling situation
If the transformer's fan is stopped, the cooling will be slower
than with an active fan. Therefore there is a coefficient c for
thermal constant available to be used as cooling time constant,
when current is less than 0.3xIn.
Heat capacitance, service factor and ambient temperature
The trip level is determined by the maximum allowed
continuous current I
temperature rise
transformer. I
depends of the given service factor k and
max
ambient temperature
corresponding to the 100 %
max
i.e. the heat capacitance of the
TRIP
and settings I
AMB
max40
and I
max70
according the following equation.
The value of ambient temperature compensation factor k
depends on the ambient temperature
and I
. See Figure 2.8-1. Ambient temperature is not in use
max70
and settings I
AMB
max40
when k = 1. This is true when
I
max40
is 1.0
Samb is “n/a” (no ambient temperature sensor)
TAMB is +40 °C.
Figure 2.8-1 Ambient temperature correction of the overload stage T>.
2.8 Thermal overload protection T>
(49)
2 Protection functions
Technical description
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Example of a behaviour of the thermal model
Figure 2.8-1 shows an example of the thermal model behaviour.
In this example = 30 minutes, k = 1.06 and k = 1 and the
current has been zero for a long time and thus the initial
temperature rise is 0 %. At time = 50 minutes the current
changes to 0.85xIN and the temperature rise starts to approach
value (0.85/1.06)2 = 64 % according the time constant. At
time=300 min, the temperature is about stable, and the current
increases to 5 % over the maximum defined by the rated
current and the service factor k. The temperature rise starts to
approach value 110 %. At about 340 minutes the temperature
rise is 100 % and a trip follows.
Initial temperature rise after restart
When the relay is switched on, an initial temperature rise of
70 % is used. Depending of the actual current, the calculated
temperature rise then starts to approach the final value.
Alarm function
The thermal overload stage is provided with a separately
settable alarm function. When the alarm limit is reached the
stage activates its start signal.
Figure 2.8-1. Example of the thermal model behaviour.
Technical description
2 Protection functions
2.8 Thermal overload protection T>
(49)
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Parameter
Value
Unit
Description
Note
Status
Blocked
Start
Trip
Current status of the stage
F
F
Time
hh:mm:s
s
Estimated time to trip
SCntr
Cumulative start counter
C
TCntr
Cumulative trip counter
C
Force
Off
On
Force flag for status forcing for
test purposes. This is a
common flag for all stages and
output relays, too.
Automatically reset by a 5minute timeout.
Set
T %
Calculated temperature rise.
Trip limit is 100 %.
F
MaxRMS
Arms
Measured current. Highest of
the three phases.
Imax A
kxIgn. Current corresponding
to the 100 % temperature rise.
k> xIn
Allowed overload (service
factor)
Set
Alarm %
Alarm level
Set
tau min
Thermal time constant
Set
ctau xtau
Coefficient for cooling time
constant. Default = 1.0
Set
kTamb
xIn
Ambient temperature
corrected max. allowed
continuous current
Imax40
%In
Allowed load at Tamb +40 C.
Default = 100 %.
Set
Imax70
%In
Allowed load at Tamb +70 C.
Set
Tamb
C
Ambient temperature.
Editable Samb=n/a. Default =
+40 C
Set
Samb
n/a
ExtAI1..
.16
Sensor for ambient
temperature
No sensor in use for Tamb
External Analogue input 1...16
Set
Parameters of the thermal overload stage T> (49)
For details of setting ranges see chapter 9.3.
Set = An editable parameter (password needed)
C = Can be cleared to zero
F = Editable when force flag is on
2.9 Second harmonic O/C stage
If2>(51F2)
2 Protection functions
Technical description
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Parameter
Value
Unit
Default
Description
If2>
10…100
%
10
Setting value If2/Ifund
t_f2
0.05…300.0
s
0.05
Definite operating time
S_On
Enabled;
Disabled
-
Enabled
Start on event
S_Off
Enabled;
Disabled
-
Enabled
Start off event
T_On
Enabled;
Disabled
-
Enabled
Trip on event
T_Off
Enabled;
Disabled
-
Enabled
Trip off event
2.9. Second harmonic O/C stage I
This stage is mainly used to block other stages. The ratio
between the second harmonic component and the fundamental
frequency component is measured on all the phase currents.
When the ratio in any phase exceeds the setting value, the
stage gives a start signal. After a settable delay, the stage gives
a trip signal.
The start and trip signals can be used for blocking the other
stages.
The trip delay is irrelevant if only the start signal is used for
blocking.
The trip delay of the stages to be blocked must be more than 60
ms to ensure a proper blocking.
>(51F2)
f2
Figure 2.9-1 Block diagram of the second harmonic stage.
Setting parameters of second harmonic blocking 2.Ha(51F2):
Technical description
2 Protection functions
2.10 Circuit-breaker failure
protection CBFP (50BF)
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Parameter
Value
Unit
Description
Measured
values
IL1H2.
% 2. harmonic of IL1,
proportional to the
fundamental value of
IL1
IL2H2.
% 2. harmonic of IL2
IL3H2.
% 2. harmonic of IL3
Recorded
values
Flt %
The max. fault value
EDly
%
Elapsed time as
compared to the set
operating time; 100%
= tripping
Measured and recorded values of second harmonic
blocking 2.Ha(51F2):
2.10. Circuit-breaker failure protection CBFP
(50BF)
The circuit breaker failure protection can be used to trip any
upstream circuit breaker (CB), if the fault has not disappeared
within a given time after the initial trip command. A different
output contact of the relay must be used for this backup trip.
The operation of the circuit-breaker failure protection (CBFP)
is based on the supervision of the signal to the selected trip
relay and the time the fault remains on after the trip command.
If this time is longer than the operating time of the CBFP
stage, the CBFP stage activates another output relay, which
will remain activated until the primary trip relay resets.
The CBFP stage is supervising all the protection stages using
the same selected trip relay, since it supervises the control
signal of this relay. See chapter 5.4 for details about the output
matrix and the trip relays.
2.10 Circuit-breaker failure
protection CBFP (50BF)
2 Protection functions
Technical description
74
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Parameter
Value
Unit
Description
Note
Status
Blocked
Start
Trip
Current status of the stage
F
F
SCntr
Cumulative start counter
C
TCntr
Cumulative trip counter
C
Force
Off
On
Force flag for status forcing for
test purposes. This is a
common flag for all stages and
output relays, too.
Automatically reset by a 5minute timeout.
Set
CBrelay
1
2
The supervised output relay*).
Relay T1
Relay T2
Set
t> s
Definite operation time.
Set
Parameter
Value
Unit
Description
yyyy-mm-dd
Time stamp of the recording, date
hh:mm:ss.ms
Time stamp, time of day
EDly %
Elapsed time of the operating time
setting. 100% = trip
Parameters of the circuit breaker failure stage CBFP (50BF)
For details of setting ranges see chapter 9.3.
Set = An editable parameter (password needed)
C = Can be cleared to zero
F = Editable when force flag is on
*) This setting is used by the circuit breaker condition monitoring, too. See
chapter 3.4.
Recorded values of the latest eight faults
There are detailed information available of the eight latest
faults: Time stamp and elapsed delay.
Recorded values of the circuit breaker failure stage (8 latest
faults) CBFP (50BF)
Technical description
2 Protection functions
2.11 Arc fault protection
(50ARC/50NARC) (optional)
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ArcI>
for phase-to-phase arc faults. Current inputs
IL1, IL2, IL3 are used.
ArcI‟>
for phase-to-phase arc faults. Current inputs
I‟L1, I‟L2, I‟L3 are used.
ArcI01>
for phase-to-earth arc faults. Current input
I01 is used.
ArcI02>
for phase-to-earth arc faults. Current input
I02 is used.
No sensor selected. The stage will not work.
S1
Light sensor S1.
S2
Light sensor S2.
S1/S2
Either one of the light sensors S1 or S2.
BI
Binary input of the arc card. 48 Vdc.
S1/BI
Light sensor S1 or the binary input.
S2/BI
Light sensor S2 or the binary input.
S1/S2/BI
Light sensor S1 or S2 or the binary input.
2.11. Arc fault protection (50ARC/50NARC)
(optional)
NOTE! This protection function needs optional hardware in slot X6. More details
of the hardware can be found in chapters 8.4 and 9.1.8).
Arc protection is used for fast arc protection. The function is
based on simultaneous light and current measurement. Special
arc sensors are used to measure the light of an arc.
Three stages for arc faults
There are three separate stages for the various current inputs:
Light channel selection
The light information source to the stages can be selected from
the following list.
Binary input
The binary input (BI) on the arc option card (see chapter 8.4)
can be used to get the light indication from another relay to
build selective arc protection systems. The BI signal can also
be connected to any of the output relays, BO, indicators etc.
offered by the output matrix (See chapter 5.4). BI is a dry input
for 48 Vdc signal from binary outputs of other VAMP relays or
dedicated arc protection devices by VAMP.
2.11 Arc fault protection
(50ARC/50NARC) (optional)
2 Protection functions
Technical description
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ArcI>:
1 pu = 1xIN = rated phase current CT value
ArcI‟>:
1 pu = 1xI‟N = rated phase current CT value
ArcI01>:
1 pu = 1xI
01N
= rated residual current CT value
for input I01.
ArcI02>:
1 pu = 1xI
02N
= rated residual current CT value
for input I02.
Binary output
The binary output (BO) on the arc option card (see chapters 8.4
and 8.5) can be used to give the light indication signal or any
other signal or signals to another relay's binary input to build
selective arc protection systems. Selection of the BO connected
signal(s) is done with the output matrix (See chapter 5.4). BO
is an internally wetted 48 Vdc signal for BI of other VAMP
relays or dedicated arc protection devices by VAMP.
Delayed light indication signal
There is a delayed light indication output signal available for
building selective arc protection systems. Any light source
combination and a delay can be configured. The resulting
signal is available in the output matrix to be connected to BO,
output relays etc.
Pick up scaling
The per unit (pu) values for pick up setting are based on the
current transformer values.
Technical description
2 Protection functions
2.11 Arc fault protection
(50ARC/50NARC) (optional)
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Parameter
Value
Unit
Description
Note
Status
Start
Trip
Current status of the stage
Light detected according ArcIn
Light and overcurrent detected
F
F
LCntr
Cumulative light indication
counter. S1, S2 or BI.
C
SCntr
Cumulative light indication
counter for the selected inputs
according parameter ArcIn
C
TCntr
Cumulative trip counter
C
Force
Off
On
Force flag for status forcing for
test purposes. This is a
common flag for all stages and
output relays, too.
Automatically reset by a 5minute timeout.
Set
ILmax
I‟Lmax
Io1
Io2
Value of the supervised signal
Stage ArcI>
Stage ArcI‟>
Stage ArcI01>
Stage ArcI02>
ArcI>
ArcI‟>
ArcIo1>
ArcIo2>
pu
pu
pu
pu
Pick up setting xI
N
Pick up setting xI‟
N
Pick up setting xI
01N
Pick up setting xI
02N
Set
ArcIn
S1
S2
S1/S2
BI
S1/BI
S2/BI
S1/S2/BI
Light indication source
selection
No sensor selected
Sensor 1 at terminals X6:4-5
Sensor 2 at terminals X6:6-7
Terminals X6:1-3
Set
Delayed light signal output
Ldly s
Delay for delayed light output
signal
Set
LdlyCn
S1
S2
S1/S2
BI
S1/BI
S2/BI
S1/S2/BI
Light indication source
selection
No sensor selected
Sensor 1 at terminals X6:4-5
Sensor 2 at terminals X6:6-7
Terminals X6:1-3
Set
Parameters of arc protection stages
ArcI>, ArcI’>, ArcI01>, ArcI02> (50ARC/50NARC)
For details of setting ranges see chapter 9.3.
Set = An editable parameter (password needed)
2.11 Arc fault protection
(50ARC/50NARC) (optional)
2 Protection functions
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Parameter
Value
Unit
Description
yyyy-mm-dd
Time stamp of the recording, date
hh:mm:ss.ms
Time stamp, time of day
Type pu
Fault type value. Only for ArcI>
stage.
Flt pu
Fault value
Load pu
Pre fault current. Only for ArcI>
stage.
EDly %
Elapsed time of the operating time
setting. 100% = trip
C = Can be cleared to zero
F = Editable when force flag is on
Recorded values of the latest eight faults
There are detailed information available of the eight latest
faults: Time stamp, fault type, fault value, load current before
the fault and elapsed delay.
Recorded values of the arc protection stages
ArcI>, ArcI’>, ArcI01>, ArcI02> (50ARC/50NARC)
Technical description
2 Protection functions
2.12 Programmable stages (99)
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Priority
If operation times less than 60 milliseconds are needed
select 10 ms. For operation times under one second 20 ms
is recommended. For longer operation times and THD
signals 100 ms is recommended.
Link
The name of the supervised signal (see table below).
Cmp
Compare mode. „>‟ for over or „<‟ for under comparison.
Pick-up
Limit of the stage. The available setting range and the
unit depend on the selected signal.
t
Definite time operation delay
Hyster
Dead band (hysteresis)
NoCmp
Only used with compare mode under („<‟). This is the limit
to start the comparison. Signal values under NoCmp are
not regarded as fault.
Alarm stages link signals
Task interval
IL1 – IL3, IL1W-IL3W, I‟L1W-I‟L3W, IL, I‟L
100ms
Io, Io2, Iocalc, I‟oCalc, I1, I2, I2/I1, I2/In, I‟1, I‟2, I‟2/I‟1,
I‟2/In, dIL1, dIL2, dIL3
THDIL1, THDIL2, THDIL3
2.12. Programmable stages (99)
For special applications the user can built his own protection
stages by selecting the supervised signal and the comparison
mode.
The following parameters are available:
Available signals to be supervised by the programmable
stages
Eight independent stages
The relay has eight independent programmable stages. Each
programmable stage can be enabled or disabled to fit the
intended application.
2.12 Programmable stages (99)
2 Protection functions
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Parameter
Value
Unit
Description
Note
Status
Blocked
Start
Trip
Current status of the stage
F
F
SCntr
Cumulative start counter
C
TCntr
Cumulative trip counter
C
SetGrp
1 or 2
Active setting group
Set
SGrpDI
-
DIx
VIx
LEDx
VOx
Digital signal to select the
active setting group
None
Digital input
Virtual input
LED indicator signal
Virtual output
Set
Force
Off
On
Force flag for status forcing for
test purposes. This is a
common flag for all stages and
output relays, too.
Automatically reset by a 5minute timeout.
Set
Link
(See
table
above)
Name for the supervised signal
Set
(See table
above)
Value of the supervised signal
Cmp
>
<
Mode of comparison
Over protection
Under protection
Set
Pickup
Pick up value scaled to
primary level
Pickup
pu
Pick up setting in pu
Set
t s
Definite operation time.
Set
Hyster
% Dead band setting
Set
NoCmp
pu
Minimum value to start under
comparison. (Mode='<')
Set
Setting groups
There are two settings groups available. Switching between
setting groups can be controlled by digital inputs, virtual
inputs (mimic display, communication, logic) and manually.
There are two identical stages available with independent
setting parameters.
Parameters of the programmable stages PrgN (99)
Set = An editable parameter (password needed)
C = Can be cleared to zero
F = Editable when force flag is on
Technical description
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2.13 Inverse time operation
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Parameter
Value
Unit
Description
yyyy-mm-dd
Time stamp of the recording, date
hh:mm:ss.ms
Time stamp, time of day
Flt pu
Fault value
EDly %
Elapsed time of the operating time
setting. 100% = trip
SetGrp
1
2
Active setting group during fault
Recorded values of the latest eight faults
There are detailed information available of the eight latest
faults: Time stamp, fault value and elapsed delay.
Recorded values of the programmable stages PrgN (99)
2.13. Inverse time operation
The inverse time operation - i.e. inverse delay minimum time
(IDMT) type of operation - is available for several protection
functions. The common principle, formulae and graphic
representations of the available inverse delay types are
described in this chapter.
Inverse delay means that the operation time depends on the
measured real time process values during a fault. For example
with an overcurrent stage using inverse delay a bigger a fault
current gives faster operation. The alternative to inverse
delay is definite delay. With definite delay a preset time is
used and the operation time does not depend on the size of a
fault..
Stage specific inverse delay
Some protection functions have their own specific type of
inverse delay. Details of these dedicated inverse delays are
described with the appropriate protection function.
Operation modes
There are three operation modes to use the inverse time
characteristics:
Standard delays
Using standard delay characteristics by selecting a curve
family (IEC, IEEE, IEEE2, RI) and a delay type (Normal
inverse, Very inverse etc). See chapter 2.13.1.
Standard delay formulae with free parameters
Selecting a curve family (IEC, IEEE, IEEE2) and defining
one's own parameters for the selected delay formula. This
mode is activated by setting delay type to „Parameters‟, and
then editing the delay function parameters A ... E. See
chapter 2.13.2.
2.13 Inverse time operation
2 Protection functions
Technical description
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Fully programmable inverse delay characteristics
Building the characteristics by setting 16 [current, time]
points. The relay interpolates the values between given
points with 2nd degree polynomials. This mode is activated
by setting curve family to „PrgN‟'. There are maximum three
different programmable curves available at the same time.
Each programmed curve can be used by any number of
protection stages. See chapter 2.13.3.
Local panel graph
The relay will show a graph of the currently used inverse delay
on the local panel display. Up and down keys can be used for
zooming. Also the delays at 20xI
SET
, 4xI
and 2xI
SET
SET
are
shown.
Inverse time setting error signal
If there are any errors in the inverse delay configuration the
appropriate protection stage will use definite time delay.
There is a signal „Setting Error‟ available in output matrix,
which indicates three different situations:
1. Settings are currently changed with VAMPSET or local
panel, and there is temporarily an illegal combination of
curve/delay/points. For example if previous settings were
IEC/NI and then curve family is changed to IEEE, the
setting error will active, because there is no NI type
available for IEEE curves. After changing valid delay type
for IEEE mode (for example MI), the „Setting Error‟ signal
will release.
There are errors in formula parameters A…E, and the
device is not able to build the delay curve
There are errors in the programmable curve configuration
and the device is not able to interpolate values between the
given points.
Limitation
The maximum measured phase current is 50xIn and the
maximum directly measured earth fault current is 5xI0n. This
limits the scope of inverse curves when the setting is more than
2.5xIn (overcurrent stages and earth fault stages using I
input) or 0.25xI
input). The In and I
(earth fault stages using I01 input or I
01n
01n
and I
depend on the order code (See
02n
0Calc
02
chapter 12). The table below gives the limit values in secondary
amperes.
Technical description
2 Protection functions
2.13 Inverse time operation
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RATED INPUT
Maximum secondary scaled setting
enabling inverse delay times up to
20x setting
Order code
IL
I’L
I01
I02 IL1, IL2,
IL3 &
I
0Calc
I’L1, I’L2,
I’L3 &
I’
0Calc
I01
I02
VAMP 265-1_
1 1 2.5 A
2.5 A
VAMP 265-3_
1 5 2.5 A
12.5 A
VAMP 265-4_
5 1 12.5 A
2.5 A
VAMP 265-5_
5 5 12.5 A
12.5 A
VAMP 265-_A
5 5 1.25 A
1.25 A
VAMP 265-_B
5 1 1.25 A
0.25 A
VAMP 265-_C
1 5 0.25 A
1.25 A
VAMP 265-_D
1 1 0.25 A
0.25 A
Example of limitation
CT = 750/5
I
N
= 577 A
CT0 = 100/1 (a cable CT for I0)
Secondary scaled I
is now 3.85 A
GNsec
For 5 A CT secondaries and 1 A residual current inputs VAMP
relay VAMP 265-5D7AAA is used. It has 5 A phase current
inputs and 1 A residual inputs.
For overcurrent stage I> the table below gives 12.5 A. Thus the
maximum setting for I> stage giving full inverse delay range is
12.5 A / 3.85 A = 3.25 xIgn.
For earth fault stage I0> and input I01 the table below gives
0.25 A. Thus the maximum setting for I0> stage giving full
inverse delay range is 0.25 A / 1 A = 0.25 pu. This equals a 25 A
primary earth fault current.
When using input signal I
the corresponding setting is 12.5
0Calc
A / 1 A = 12.5 pu. This equals a 9375 A of primary earth fault
current.
2.13 Inverse time operation
2 Protection functions
Technical description
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Delay type
Curve family
DT
IEC
IEEE
IEEE2
RI
DT
Definite time
X
NI1
Normal inverse
X X
VI
Very inverse
X X X
EI
Extremely inverse
X X X
LTI
Long time inverse
X X
LTEI
Long time extremely inverse
X
LTVI
Long time very inverse
X
MI
Moderately inverse
X X
STI
Short time inverse
X
STEI
Short time extremely inverse
X
RI
Old ASEA type
X
RXIDG
Old ASEA type
X
2.13.1. Standard inverse delays IEC, IEEE, IEEE2, RI
The available standard inverse delays are divided in four
categories IEC, IEEE, IEEE2 and RI called delay curve
families. Each category of family contains a set of different
delay types according the following table.
Inverse time setting error signal
The inverse time setting error signal will be activated, if the
delay category is changed and the old delay type doesn't exist
in the new category. See chapter 2.13 for more details.
Limitations
The minimum definite time delay start latest, when the
measured value is twenty times the setting. However, there are
limitations at high setting values due to the measurement
range. See chapter 2.13 for more details.
Table 2.13.1-1 Available standard delay families and the
available delay types within each family.
IEC inverse time operation
The operation time depends on the measured value and other
parameters according Equation 2.13.1-1. Actually this equation
can only be used to draw graphs or when the measured value I
is constant during the fault. A modified version is implemented
in the relay for real time usage.
Technical description
2 Protection functions
2.13 Inverse time operation
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1
B
pickup
I
I
Ak
t
Delay type
Parameter
A
B
NI
Normal inverse
0.14
0.02
EI
Extremely inverse
80
2
VI
Very inverse
13.5
1
LTI
Long time inverse
120
1
0.5
1
2
4
14.050.0
02.0
t
Equation 2.13.1-1
t = Operation delay in seconds
k = User‟s multiplier
I = Measured value
Ipickup = User‟s pick up setting
A, B = Constants parameters according Table.
There are three different delay types according IEC 60255-3,
Normal inverse (NI), Extremely inverse (EI), Very inverse (VI)
and a VI extension, Long time inverse (LTI).
Table 2.13.1-2 Constants for IEC inverse delay equation
Example for Delay type "Normal inverse (NI) ":
k = 0.50
I = 4 pu (constant current)
I
= 2 pu
pickup
A = 0.14
B = 0.02
2.13 Inverse time operation
2 Protection functions
Technical description
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Figure 2.13.1-1 IEC normal inverse
delay.
Figure 2.13.1-2 IEC extremely inverse
delay.
Figure 2.13.1-3 IEC very inverse
delay.
Figure 2.13.1-4 IEC long time inverse
delay.
The operation time in this example will be 5 seconds. The same
result can be read from Figure 2.13.1-1 .
Technical description
2 Protection functions
2.13 Inverse time operation
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B
I
I
A
kt
C
pickup
1
Delay type
Parameter
A B C
LTI
Long time inverse
0.086
0.185
0.02
LTVI
Long time very inverse
28.55
0.712
2
LTEI
Long time extremely
inverse
64.07
0.250
2
MI
Moderately inverse
0.0515
0.1140
0.02
VI
Very inverse
19.61
0.491
2
EI
Extremely inverse
28.2
0.1217
2
STI
Short time inverse
0.16758
0.11858
0.02
STEI
Short time extremely
inverse
1.281
0.005
2
IEEE/ANSI inverse time operation
There are three different delay types according IEEE Std
C37.112-1996 (MI, VI, EI) and many de facto versions
according Table 2.12.1-3. The IEEE standard defines inverse
delay for both trip and release operations. However, in the
VAMP relay only the trip time is inverse according the
standard but the release time is constant.
The operation delay depends on the measured value and other
parameters according Equation 2.13.1-1. Actually this equation
can only be used to draw graphs or when the measured value I
is constant during the fault. A modified version is implemented
in the relay for real time usage.
Equation 2.13.1-1
t = Operation delay in seconds
k = User‟s multiplier
I = Measured value
I
= User‟s pick up setting
pickup
A,B,C = Constant parameter according Table 2.13.1-3.
Table 2.13.1-3 Constants for IEEE/ANSI inverse delay equation
2.13 Inverse time operation
2 Protection functions
Technical description
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9.11140.0
1
2
4
0515.0
50.0
02.0
t
Figure 2.13.1-5 ANSI/IEEE long
time inverse delay
Figure 2.13.1-6 ANSI/IEEE long
time very inverse delay
Example for Delay type "Moderately inverse (MI)":
k = 0.50
I = 4 pu
I
pickup
= 2 pu
A = 0.0515
B = 0.114
C = 0.02
The operation time in this example will be 1.9 seconds. The
same result can be read from Figure 2.13.1-8.
Technical description
2 Protection functions
2.13 Inverse time operation
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Figure 2.13.1-7 ANSI/IEEE long
time extremely inverse delay
Figure 2.13.1-8 ANSI/IEEE
moderately inverse delay
Figure 2.13.1-9 ANSI/IEEE short
time inverse delay
Figure 2.13.1-10 ANSI/IEEE short
time extremely inverse delay
2.13 Inverse time operation
2 Protection functions
Technical description
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32
C
I
I
E
C
I
I
D
C
I
I
B
Akt
pickuppickup
pickup
Delay type
Parameter
A B C D E
MI
Moderately inverse
0.1735
0.6791
0.8
-0.08
0.1271
NI
Normally inverse
0.0274
2.2614
0.3
-.1899
9.1272
VI
Very inverse
0.0615
0.7989
0.34
-0.284
4.0505
EI
Extremely inverse
0.0399
0.2294
0.5
3.0094
0.7222
IEEE2 inverse time operation
Before the year 1996 and ANSI standard C37.112
microprocessor relays were using equations approximating the
behaviour of various induction disc type relays. A quite
popular approximation is Equation 2.13.1-2, which in VAMP
device is called IEEE2. Another name could be IAC, because
the old General Electric IAC relays have been modeled using
the same equation.
There are four different delay types according Table 2.13.1-1.
The old electromechanical induction disc relays have inverse
delay for both trip and release operations. However, in VAMP
device only the trip time is inverse the release time being
constant.
The operation delay depends on the measured value and other
parameters according Equation 2.13.1-2. Actually this equation
can only be used to draw graphs or when the measured value I
is constant during the fault. A modified version is implemented
in the relay for real time usage.
Equation 2.13.1-2
t = Operation delay in seconds
k = User‟s multiplier
I = Measured value
I
pickup
= User‟s pick up setting
A,B,C,D = Constant parameter according Table 2.13.1-1.
Table 2.13.1-1 Constants for IEEE2 inverse delay equation
Technical description
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2.13 Inverse time operation
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38.0
8.0
2
4
127.0
8.0
2
4
08.0
8.0
2
4
6791.0
1735.05.0
32
t
Figure 2.13.1-11 IEEE2 moderately
inverse delay
Figure 2.13.1-12 IEEE2 normal
inverse delay
Example for Delay type "Moderately inverse (MI)":
k = 0.50
I = 4 pu
I
= 2 pu
pickup
A = 0.1735
B = 0.6791
C = 0.8
D = -0.08
E = 0.127
The operation time in this example will be 0.38 seconds. The
same result can be read from Figure 2.13.1-11.
2.13 Inverse time operation
2 Protection functions
Technical description
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Figure 2.13.1-13 IEEE2 very inverse
delay
Figure 2.13.1-14 IEEE2 extremely
inverse delay
pickup
RI
I
I
k
t
236.0
339.0
pickup
RXIDG
Ik
I
t ln35.18.5
RI and RXIDG type inverse time operation
These two inverse delay types have their origin in old ASEA
(nowadays ABB) earth fault relays.
The operation delay of types RI and RXIDG depends on the
measured value and other parameters according Equation
2.13.1-3 and Equation 2.13.1-4. Actually these equations can
only be used to draw graphs or when the measured value I is
constant during the fault. Modified versions are implemented
in the relay for real time usage.
Equation 2.13.1-3. RI
Equation 2.13.1-4 RXIDG
t = Operation delay in seconds
k = User‟s multiplier
I = Measured value
I
= User‟s pick up setting
pickup
Technical description
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2.13 Inverse time operation
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3.2
2
4
236.0
339.0
5.0
RI
t
9.3
25.0
4
ln35.18.5
RXIDG
t
Figure 2.13.1-15 Inverse delay of
type RI.
Figure 2.13.1-16 Inverse delay of
type RXIDG.
Example for Delay type RI :
k = 0.50
I = 4 pu
I
= 2 pu
pickup
The operation time in this example will be 2.3 seconds. The
same result can be read from Figure 2.13.1-15.
Example for Delay type RXIDG:
k = 0.50
I = 4 pu
I
= 2 pu
pickup
The operation time in this example will be 3.9 seconds. The
same result can be read from Figure 2.13.1-16.
2.13 Inverse time operation
2 Protection functions
Technical description
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37.0
8.0
2
4
1947.0
8.0
2
4
4180.0
8.0
2
4
8630.0
2078.05.0
32
t
2.13.2. Free parametrisation using IEC, IEEE and IEEE2
equations
This mode is activated by setting delay type to „Parameters‟,
and then editing the delay function constants, i.e. the
parameters A ... E. The idea is to use the standard equations
with one‟s own constants instead of the standardized constants
as in the previous chapter.
Example for GE-IAC51 delay type inverse:
k = 0.50
I = 4 pu
I
= 2 pu
pickup
A = 0.2078
B = 0.8630
C = 0.8000
D = 0.4180
E = 0.1947
The operation time in this example will be 0.37 seconds.
The resulting time/current characteristic of this example
matches quite well with the characteristic of the old
electromechanical IAC51 induction disc relay.
Inverse time setting error signal
The inverse time setting error signal will become active, if
interpolation with the given parameters is not possible. See
chapter 2.13 for more details.
Limitations
The minimum definite time delay start latest, when the
measured value is twenty times the setting. However, there are
limitations at high setting values due to the measurement
range. See chapter 2.13 for more details.
Technical description
2 Protection functions
2.13 Inverse time operation
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Point
Current I/I
pick-up
Operation delay
1
1.00
10.00 s
2
2.00
6.50 s
3
5.00
4.00 s
4
10.00
3.00 s
5
20.00
2.00 s
6
40.00
1.00 s
7
1.00
0.00 s
8
1.00
0.00 s
9
1.00
0.00 s
10
1.00
0.00 s
11
1.00
0.00 s
12
1.00
0.00 s
13
1.00
0.00 s
14
1.00
0.00 s
15
1.00
0.00 s
16
1.00
0.00 s
2.13.3. Programmable inverse time curves
Only with VAMPSET, requires rebooting.
The [current, time] curve points are programmed using
VAMPSET PC program. There are some rules for defining the
curve points:
configuration must begin from the topmost row
row order must be as follows: the smallest current (longest
operation time) on the top and the largest current (shortest
operation time) on the bottom
all unused rows (on the bottom) should be filled with [1.00
0.00s]
Here is an example configuration of curve points:
Inverse time setting error signal
The inverse time setting error signal will be activated, if
interpolation with the given points fails. See chapter 2.13 for
more details.
Limitations
The minimum definite time delay start latest, when the
measured value is twenty times the setting. However, there are
limitations at high setting values due to the measurement
range. See chapter 2.13 for more details.
3.1 Event log
3 Supporting functions
Technical description
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EVENT
Description
Local
panel
Communication
protocols
Code: 30E2
Channel 30,
event 2
Yes
Yes
U> trip on
Event text
Yes
No
112.0 %Ugn
Fault value
Yes
No
2007-01-31
Date
Yes
Yes
08:35:13.413
Time
Yes
Yes
Type: U12,23,31
Fault type
Yes
No
3. Supporting functions
3.1. Event log
Event log is a buffer of event codes and time stamps including
date and time. For example each start-on, start-off, trip-on or
trip-off of any protection stage has a unique event number code.
Such a code and the corresponding time stamp is called an
event. The event codes are listed in a separate document
VAMP2xx_Events.pdf.
As an example of information included with a typical event an
overvoltage trip event of the first 59 stage U> is shown in the
following table.
Events are the major data for a SCADA system. SCADA
systems are reading events using any of the available
communication protocols. Event log can also be scanned using
the front panel or using VAMPSET. With VAMSET the events
can be stored to a file especially in case the relay is not
connected to any SCADA system.
Only the latest event can be read when using communication
protocols or VAMPSET. Every reading increments the internal
read pointer to the event buffer. (In case of communication
error, the latest event can be reread any number of times using
an other parameter.) On the local panel scanning the event
buffer back and forth is possible.
Event enabling/masking
In case of an uninteresting event, it can be masked, which
prevents the particular event(s) to be written in the event
buffer.
As a default there is room for 200 latest events in the buffer.
Event buffer size can be modified from 50 to 2000 in all v.10.xx
softwares. Modification can be done in “Local panel conf” –
menu. Alarm screen (popup screen) can also be enabled in this
same menu when Vampset –setting tool is used. The oldest one
Technical description
3 Supporting functions
3.1 Event log
VM265.EN011
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Parameter
Value
Description
Note
Count
Number of events
ClrEn
Clear
Clear event buffer
Set
Order
Old-
New
New-
Old
Order of the event buffer for local
display
Set
FVSca
PU
Pri
Scaling of event fault value
Per unit scaling
Primary scaling
Set
Display
Alarms
On
Off
Alarm pop-up display is enabled
No alarm display
Set
FORMAT OF EVENTS ON THE LOCAL DISPLAY
Code: CHENN
CH = event channel, NN=event code
Event description
Event channel and code in plain text
yyyy-mm-dd
Date (for available date formats see chapter 3.5)
hh:mm:ss.nnn
Time
will be overwritten, when a new event does occur. The shown
resolution of a time stamp is one millisecond, but the actual
resolution depends of the particular function creating the
event. For example most protection stages create events with
10 ms or 20 ms resolution. The absolute accuracy of all time
stamps depends on the time synchronizing of the relay. See
chapter 3.5 for system clock synchronizing.
Event buffer overflow
The normal procedure is to poll events from the device all the
time. If this is not done, the event buffer will eventually
overflow. On the local screen this is indicated with string
"OVF" after the event code.
Setting parameters for events
3.2 Disturbance recorder
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3.2. Disturbance recorder
The disturbance recorder can be used to record all the
measured signals, that is, currents, voltages and the status
information of digital inputs (DI) and digital outputs (DO). The
digital inputs include also the arc protection signals S1, S2, BI
and BO, if the optional arc protection is available.
Triggering the recorder
The recorder can be triggered by any start or trip signal from
any protection stage or by a digital input. The triggering signal
is selected in the output matrix (vertical signal DR). The
recording can also be triggered manually. All recordings are
time stamped.
Reading recordings
The recordings can be uploaded, viewed and analysed with the
VAMPSET program. The recording is in COMTRADE format.
This means that also other programs can be used to view and
analyse the recordings made by the relay.
For more details, please see a separate VAMPSET manual.
Number of channels
At the maximum, there can be 12 recordings, and the
maximum selection of channels in one recording is also 12
(limited in waveform recording). The digital inputs reserve one
channel (includes all the inputs). Also the digital outputs
reserve one channel (includes all the outputs). If digital inputs
and outputs are recorded, there will be still 10 channels left for
analogue waveforms.
Technical description
3 Supporting functions
3.2 Disturbance recorder
VM265.EN011
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Channel
Description
Available for
waveform
IL1, IL2, IL3
Phase current
Yes
I‟L1, I‟L2, I‟L3
Phase current
Yes
Io1, Io2
Measured residual current
Yes
f
Frequency
IoCalc
Phasor sum Io = (IL1+IL2+IL3)/3
I‟oCalc
Phasor sum Io = (I‟L1+I‟L2+I‟L3)/3
I1, I‟1
Positive sequence current
I2, I‟2
Negative sequence current
I2/I1, I‟2/I‟1
Relative current unbalance
I2/In, I‟2/I‟n
Current unbalance [xIGN]
IL
Average (IL1 + IL2 + IL3)/3
I‟L
Average (I‟L1 + I‟L2 + I‟L3)/3
DO
Digital outputs
Yes
DI
Digital inputs
Yes
THDIL1
Total harmonic distortion of IL1
THDI‟L1
Total harmonic distortion of I‟L1
THDIL2
Total harmonic distortion of IL2
THDI‟L2
Total harmonic distortion of I‟L2
THDIL3
Total harmonic distortion of IL3
THDI‟L3
Total harmonic distortion of I‟L3
IL1RMS
IL1 RMS for average sampling
IL2RMS
IL2 RMS for average sampling
IL3RMS
IL3 RMS for average sampling
ILmin
I‟Lmin
ILmax
I‟Lmax
ΔIL1,ΔIL2,ΔIL3
IL1w,IL2w,IL3w
I‟L1w,I‟L2w,I‟L3w
Available channels
The following channels i.e. signals can be linked to a
disturbance recorder:
3.2 Disturbance recorder
3 Supporting functions
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Parameter
Value
Unit
Description
Note
Mode
Saturated
Overflow
Behaviour in memory full
situation:
No more recordings are
accepted
The oldest recorder will be
overwritten
Set
SR
32/cycle
16/cycle
8/cycle
1/10ms
1/20ms
1/200ms
1/1s
1/5s
1/10s
1/15s
1/30s
1/1min
Sample rate
Waveform
Waveform
Waveform
One cycle value *)
One cycle value
**)
Average
Average
Average
Average
Average
Average
Average
Set
Time s
Recording length
Set
PreTrig
% Amount of recording data
before the trig moment
Set
MaxLen
s Maximum time setting.
This value depends on
sample rate, number and
type of the selected
channels and the
configured recording
length.
Status
Run
Trig
FULL
Status of recording
Not active
Waiting a triggering
Recording
Memory is full in saturated
mode
ManTrig
Trig
Manual triggering
Set
ReadyRec
n/m
n = Available recordings
m = maximum number of
recordings
The value of 'm' depends on
sample rate, number and
type of the selected
channels and the
configured recording
length.
Disturbance recorder parameters
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