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VAMP 59
Line differential protection relay
Publication version: V59/en M/A009
User Manual
Trace back information:
Workspace Main version a132
Checked in 2017-02-13
Skribenta version 4.6.323
Table of Contents
V59/en M/A009
Table of Contents
1 General .....................................................................................
7
Legal notice ......................................................................
Safety information and password protection ....................
Relay features ..................................................................
User interface ......................................................
Related documents ..........................................................
Periodical testing ..............................................................
EU directive compliance ..................................................
Abbreviations ...................................................................
2 Local panel user interface ......................................................
14
Relay front panel ..............................................................
Display ................................................................
Adjusting display contrast ...................................
Local panel operations .....................................................
Menu structure of protection functions ................
Setting groups .....................................................
Fault logs .............................................................
Operating levels ..................................................
Operating measures ........................................................
Control functions .................................................
Measured data ....................................................
Reading event register ........................................
Forced control (Force) .........................................
Configuration and parameter setting ...............................
Parameter setting ................................................
Setting range limits ..............................................
Disturbance recorder menu DR ..........................
Configuring digital inputs DI ................................
Configuring digital outputs DO ............................
Configuring analogue outputs AO (Option) .........
Protection menu Prot ..........................................
Configuration menu CONF ..................................
Protocol menu Bus ..............................................
2.4.10 Single line diagram editing ..................................
2.4.11 Blocking and Interlocking configuration ..............
3 VAMPSET PC software ...........................................................
43
Folder view .......................................................................
4 Introduction .............................................................................
45
Main features ...................................................................
Principles of numerical protection techniques .................
3
4
Table of Contents
5 Protection functions ...............................................................
48
Maximum number of protection stages in one
application ........................................................................
General features of protection stages ..............................
Application modes ............................................................
Current protection function dependencies .......................
Overcurrent protection I> (50/51) .....................................
Remote controlled overcurrent scaling ...............
> (46) ................................
Directional earth fault protection I
> (50N/51N) .................................
Earth fault faulty phase detection algorithm ........
Zero sequence voltage protection U
5.10 Thermal overload protection T> (49) ...............................
> (68F2) ......................................
5.12 Transformer over exicitation I f5
> (68F5) ..........................
5.13 Circuit breaker failure protection CBFP (50BF) ...............
5.14 Line differential protection LdI> (87L) ..............................
5.14.1 Capacitive charging current ................................
5.14.2 ANSI 85 communication (POC –signals) ............
5.14.3 Frequency adaptation .........................................
5.14.4 Second harmonic blocking ..................................
5.14.5 Fifth harmonic blocking .......................................
5.15 Programmable stages (99) ..............................................
5.16 Arc fault protection (optional) ...........................................
5.16.1 2S+BIO ................................................................
5.16.2 3S+BIO ................................................................
5.17 Inverse time operation .....................................................
5.17.1 Standard inverse delays IEC, IEEE, IEEE2, RI ...
5.17.3 Programmable inverse time curves ....................
6 Supporting functions ..............................................................
121
Event log ..........................................................................
Disturbance recorder .......................................................
Running virtual comtrade files .............................
Cold load pick-up and inrush current detection ...............
Current transformer supervision ......................................
Circuit breaker condition monitoring ................................
System clock and synchronization ...................................
Running hour counter ......................................................
Timers ..............................................................................
Combined overcurrent status ...........................................
6.10 Self-supervision ...............................................................
6.10.1 Diagnostics ..........................................................
V59/en M/A009
Table of Contents
V59/en M/A009
7 Measurement functions ..........................................................
149
Measurement accuracy ....................................................
RMS values ......................................................................
Harmonics and Total Harmonic Distortion (THD) .............
Demand values ................................................................
Minimum and maximum values .......................................
Maximum values of the last 31 days and 12 months .......
Voltage measurement modes ..........................................
Symmetric components ...................................................
Primary secondary and per unit scaling ...........................
Current scaling ....................................................
Voltage scaling ....................................................
7.10 Analogue output (option) ..................................................
7.10.1 mA scaling example ............................................
8 Control functions ....................................................................
158
Output relays ....................................................................
Digital inputs ....................................................................
Virtual inputs and outputs ................................................
Function keys / F1 & F2 ...................................................
Output matrix ...................................................................
Blocking matrix .................................................................
Controllable objects .........................................................
Controlling with DI ...............................................
Local/Remote selection .......................................
Controlling with F1 & F2 ......................................
Auto-reclose function (79) ................................................
Logic functions .................................................................
9 Communication and protocols ..............................................
177
Communication ports .......................................................
Local port (Front panel) .......................................
Remote port ........................................................
Extension port ....................................................
Ethernet port .......................................................
Communication protocols ................................................
PC communication ..............................................
Modbus TCP and Modbus RTU ..........................
DNP 3.0 ...............................................................
External I/O (Modbus RTU master) .....................
IEC 61850 ...........................................................
EtherNet/IP ..........................................................
FTP server ..........................................................
DeviceNet ............................................................
10 Application ...............................................................................
187
10.1 Line protection and auto-reclosing ...................................
5
6
Table of Contents
10.2 Trip circuit supervision .....................................................
10.2.1 Trip circuit supervision with one digital input .......
10.2.2 Trip circuit supervision with two digital inputs .....
11 Connections .............................................................................
198
11.1 Rear panel .......................................................................
11.2 Auxiliary voltage ...............................................................
11.3 Output relays ....................................................................
11.4 Serial communication connection ....................................
11.4.1 Front panel USB connector .................................
11.5 Input/output card B = 4 x DI + 1 x DI/DO .........................
11.6 Arc protection card C = Arc (2 x Arc sensor + BIO) .........
11.7 Arc protection card D = Advanced arc (3 x Arc sensor +
BIO) ..................................................................................
11.8 External option modules ..................................................
11.8.1 Third-party external input / output modules ........
11.9 Block optional diagram .....................................................
11.10 Block diagrams of optional modules ................................
11.11 Connection examples ......................................................
12 Technical data ..........................................................................
215
12.1 Connections .....................................................................
12.2 Test and environmental conditions ..................................
12.3 Protection functions .........................................................
12.3.1 Differential protection ..........................................
12.3.2 Non-directional current protection .......................
12.3.3 Directional current protection ..............................
12.3.4 Circuit-breaker failure protection CBFP (50BF) ...
12.3.5 Magnetising inrush 68F2 .....................................
12.3.6 Over exicitation 68F5 ..........................................
12.3.7 Digital input / output card (option) .......................
12.3.8 Arc fault protection (option) .................................
12.4 Supporting functions ........................................................
13 Mounting ..................................................................................
231
14 Order information ....................................................................
233
15 Firmware revision ....................................................................
235
V59/en M/A009
1 General
1
1.1
General
Legal notice
Copyright
2017 Schneider Electric. All rights reserved.
Disclaimer
No responsibility is assumed by Schneider Electric for any consequences arising out of the use of this document. This document is not intended as an instruction manual for untrained persons. This document gives instructions on device installation, commissioning and operation. However, the manual cannot cover all conceivable circumstances or include detailed information on all topics. In the event of questions or specific problems, do not take any action without proper authorization. Contact Schneider Electric and request the necessary information.
Contact information
35 rue Joseph Monier
92506 Rueil-Malmaison
FRANCE
Phone: +33 (0) 1 41 29 70 00
Fax: +33 (0) 1 41 29 71 00 www.schneider-electric.com
V59/en M/A009
7
1.2 Safety information and password protection
1.2
1 General
Safety information and password protection
Important Information
Read these instructions carefully and look at the equipment to become familiar with the device before trying to install, operate, service or maintain it. The following special messages may appear throughout this bulletin or on the equipment to warn of potential hazards or to call attention to information that clarifies or simplifies a procedure.
8
V59/en M/A009
1 General
V59/en M/A009
1.2 Safety information and password protection
The addition of either symbol to a “Danger” or “Warning” safety label indicates that an electrical hazard exists which will result in personal injury if the instructions are not followed.
This is the safety alert symbol. It is used to alert you to potential personal injury hazards. Obey all safety messages that follow this symbol to avoid possible injury or death.
DANGER
DANGER indicates an imminently hazardous situation which, if
not avoided, will result in death or serious injury.
WARNING
WARNING indicates a potentially hazardous situation which, if
not avoided, can result in death or serious injury.
CAUTION
CAUTION indicates a potentially hazardous situation which, if
not avoided, can result in minor or moderate injury.
NOTICE
NOTICE is used to address practices not related to physical
injury.
User qualification
Electrical equipment should be installed, operated, serviced, and maintained only by trained and qualified personnel. No responsibility is assumed by Schneider Electric for any consequences arising out of the use of this material. A qualified person is one who has skills and knowledge related to the construction, installation, and operation of electrical equipment and has received safety training to recognize and avoid the hazards involved.
Password protection
Use IED's password protection feature in order to protect untrained person interacting this device.
9
1.3 Relay features
1 General
WARNING
WORKING ON ENERGIZED EQUIPMENT
Do not choose lower Personal Protection Equipment while working on energized equipment.
Failure to follow these instructions can result in death or serious injury.
1.3
68F2
68F5
79
85
87L
99
IEEE/ANSI code
46
49
50/51
50ARC/ 50NARC
50BF
50N/51N
59N
67N
Relay features
The comprehensive protection functions of the relay make it ideal for utility, industrial, marine and off-shore power distribution applications. The relay features the following protection functions.
Table 1.1: List of protection functions
IEC symbol Function name
I
2
/ I
1
>
T>
I>, I>>, I>>>
ArcI>, ArcI
0
>
CBFP
I
0
>, I
0
>>, I
0
>>>, I
0
>>>>
U
0
>, U
0
>>
I
0φ
>, I
0φ
>>
I f2
>
I f5
>
AR
LdI>, LdI>>
Prg1 – 8
Current unbalance protection
Thermal overload protection
Overcurrent protection
Optional arc fault protection (with an external module)
Circuit-breaker failure protection
Earth fault protection
Zero sequence voltage protection
Directional earth-fault, low-set stage, sensitive, definite or inverse time (can be used as non directional)
Magnetishing inrush
Transfomer overexitation
Auto-reclosing
ANSI 85 communication
Line differential protection
Programmable stages
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, IEC 60870-5-101, IEC 61850, SPA bus, Ethernet / IP and DNP 3.0.
V59/en M/A009
10
1 General
1.3.1
1.4
1.5
1.4 Related documents
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 USB port on the front
• Via remote control over the optional remote control port on the relay rear panel.
Related documents
Document
VAMP Relay Mounting and Commissioning Instructions
VAMPSET Setting and Configuration Tool User Manual
Identification*
)
VRELAY_MC_xxxx
VVAMPSET_EN_M_xxxx
*) xxxx = revision number
Download the latest software and manual at www.schneider-electric.com/vamp-protection or m.vamp.fi.
Periodical testing
The protection IED, cabling and arc sensors must periodically be tested according to the end-user's safety instructions, national safety instructions or law. Manufacturer recommends functional testing being carried minimum every five (5) years.
It is proposed that the periodic testing is conducted with a secondary injection principle for those protection stages which are used in the
IED and its related units.
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11
1.6 EU directive compliance
1 General
1.6
EU directive compliance
EMC compliance
2014/30/EU
Compliance with the European Commission's EMC Directive. Product
Specific Standards were used to establish conformity:
• EN 60255-26: 2013
Product safety
2014/35/EU
Compliance with the European Commission's Low Voltage Directive.
Compliance is demonstrated by reference to generic safety standards:
• EN60255-27:2014
1.7
Abbreviations
ANSI
CB
CBFP cosφ
CT
CT
PRI
CT
SEC
Dead band
DI
DO
Document file
DSR
DST
DTR
FFT
FPGA
HMI
Hysteresis
I
N
I
SET
I
0N
12
American National Standards Institute. A standardization organisation.
Circuit breaker
Circuit breaker failure protection
Active power divided by apparent power = P/S. (See power factor PF). Negative sign indicates reverse power.
Current transformer
Nominal primary value of current transformer
Nominal secondary value of current transformer
See hysteresis.
Digital input
Digital output, output relay
Stores information about the IED settings, events and fault logs.
Data set ready. An RS232 signal. Input in front panel port of VAMP relays to disable rear panel local port.
Daylight saving time. Adjusting the official local time forward by one hour for summer time.
Data terminal ready. An RS232 signal. Output and always true (+8 Vdc) in front panel port of VAMP relays.
Fast Fourier transform. Algorithm to convert time domain signals to frequency domain or to phasors.
Field-programmable gate array
Human-machine interface
I.e. dead band. Used to avoid oscillation when comparing two near by values.
Nominal current. Rating of CT primary or secondary.
Another name for pick up setting value I>
Nominal current of I
0 input in general
V59/en M/A009
1 General
1.7 Abbreviations
P
M
PT pu
Q
RMS
S
SF
SNTP
TCS
THD
U
0SEC
U
A
U
B
U
C
U
N
UTC
VAMPSET
Webset
VT
VT
PRI
VT
SEC
IEC
IEC-101
IEC-103
IED
IEEE
LAN
Latching
LCD
LED
Local HMI
NTP
P
PF
International Electrotechnical Commission. An international standardization organisation.
Abbreviation for communication protocol defined in standard IEC 60870-5-101
Abbreviation for communication protocol defined in standard IEC 60870-5-103
Intelligent electronic device
Institute of Electrical and Electronics Engineers
Local area network. Ethernet based network for computers and IEDs.
Output relays and indication LEDs can be latched, which means that they are not released when the control signal is releasing. Releasing of latched devices is done with a separate action.
Liquid crystal display
Light-emitting diode
IED front panel with display and push-buttons
Network Time Protocol for LAN and WWW
Active power. Unit = [W]
Power factor. The absolute value is equal to cosφ, but the sign is '+' for inductive i.e. lagging current and '-' for capacitive i.e. leading current.
Nominal power of the prime mover. (Used by reverse/under power protection.)
See VT
Per unit. Depending of the context the per unit refers to any nominal value. For example for overcurrent setting 1 pu = 1 x I
N
.
Reactive power. Unit = [var] acc. IEC
Root mean square
Apparent power. Unit = [VA]
IED status inoperative
Simple Network Time Protocol for LAN and WWW
Trip circuit supervision
Total harmonic distortion
Voltage at input U c at zero ohm ground fault. (Used in voltage measurement mode “2LL+U
0
”)
Voltage input for U
12 or U
L1 depending of the voltage measurement mode
Voltage input for U
23 or U
L2 depending of the voltage measurement mode
Voltage input for U
31 or U
0 depending of the voltage measurement mode
Nominal voltage. Rating of VT primary or secondary
Coordinated Universal Time (used to be called GMT = Greenwich Mean Time)
Configuration tool for VAMP protection devices http configuration interface
Voltage transformer i.e. potential transformer PT
Nominal primary value of voltage transformer
Nominal secondary value of voltage transformer
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13
2
2.1
2 Local panel user interface
Local panel user interface
Relay front panel
The figure below shows, as an example, the front panel of the device and the location of the user interface elements used for local control.
1. Navigation push-buttons
2. LED indicators
3. LCD
4. Local port
Navigation push-button function
CANCEL push-button for returning to the previous menu. To return to the first menu item in the main menu, press the button for at least three seconds.
INFO push-button for viewing additional information, for entering the password view and for adjusting the LCD contrast.
programmable function push-button. As default F1 toggles Virtual Input 1 (VI1) On/Off programmable function push-button. As default F2 toggles Virtual Input 2 (VI2) On/Off
ENTER push-button for activating or confirming a function.
arrow UP navigation push-button for moving up in the menu or increasing a numerical value.
arrow DOWN navigation push-button for moving down in the menu or decreasing a numerical value.
arrow LEFT navigation push-button for moving backwards in a parallel menu or selecting a digit in a numerical value.
arrow RIGHT navigation push-button for moving forwards in a parallel menu or selecting a digit in a numerical value.
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14
2 Local panel user interface
2.1 Relay front panel
LED indicator
Power LED lit
Status LED lit
A- H LED lit
F1 / F2 LED lit
LED indicators
The LEDs on the local HMI can be configured in VAMPSET. To customise the LED texts on the local HMI, the texts can be written on a template and then printed on a transparency. The transparencies can be placed to the pockets beside the LEDs.
Meaning Measure/ Remarks
The auxiliary power has been switched on Normal operation state
Internal fault, operates in parallel with the self supervision output relay
The relay attempts to reboot [RE-
BOOT]. If the error LED remains lit, call for maintenance.
Application-related status indicators.
Corresponding function key pressed / activated
Configurable
Depending of function programmed to
F1 / F2
Adjusting LCD contrast
1.
On the local HMI, push and .
2. Enter the four-digit password and push
3.
•
•
Push and adjust the contrast.
To increase the contrast, push
To decrease the contrast, push
.
.
4.
To return to the main menu, push .
.
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 for approx. 3s. Then reset the latched indicators and output relays by pushing .
• Acknowledge each event in the alarm list one by one by pushing equivalent times. Then, in the initial display, reset the latched indicators and output relays by pushing .
The latched indicators and relays can also be reset via a remote communication bus or via a digital input configured for that purpose.
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15
2.1 Relay front panel
2.1.1
2 Local panel user interface
Display
The relay is provided with a backlighted 128x64 LCD dot matrix display. The display enables showing 21 characters is 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). The other
purpose is to show the configuration and parameterization values of
Figure 2.1: Sections of the LCD dot matrix display
1. Freely configurable single-line diagram
2. Controllable objects (max six objects)
3. Object status (max eight objects, including the six controllable objects)
4. Bay identification
5. Local/Remote selection
6. Auto-reclose on/off selection (if applicable)
7. Freely selectable measurement values (max. six values)
16
Figure 2.2: 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
V59/en M/A009
2 Local panel user interface
2.1.2
2.1 Relay front panel
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.
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 VAMPSET PC software.
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17
2.2 Local panel operations
2 Local panel user interface
2.2
Main menu
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 the local communication port.
Some parameters are factory-set.
Moving in the menus
Submenus
Prot protection enabling
OK
18
I pick-up setting
OK OK
moving in the menus_relay
Figure 2.3: Moving in the menus using local HMI
•
•
•
•
•
•
To move in the main menu, push
To move in submenus, push or
To enter a submenu, push down or up in the menu.
or and use
.
To edit a parameter value, push and
To go back to the previous menu, push .
.
or
.
for moving
To go back to the first menu item in the main menu, push for at least three seconds.
NOTE: To enter the parameter edit mode, give the password. When the
value is in edit mode, its background is dark.
V59/en M/A009
2 Local panel user interface
2.2 Local panel operations
Main menu
Meas
Imax
Month
Evnt
DR
Runh
TIMR
DI
DO
AO
Prot
Io>
Io>>
Io>>>
Io>>>>
Ioφ >
Ioφ >>
Uo>
Uo>>
MSTAT
LdI>
LdI>>
I>
I>>
I>>>
I2>
T>
If2>
If5>
V59/en M/A009
Main menu
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.
3
3
6
7
3
3
5
3
3
3
3
3
3
3
4
5
1
4
4
2
6
5
9
2
3
2
A list of the local main menu
Number of menus
1
5
1
14
5
17
Description
Interactive mimic display
Double size measurements defined by the user
ANSI code
Title screen with device name, time and firmware version.
Measurements
Time stamped min & max of currents
Maximum values of the last 31 days and the last twelve months
Events
Disturbance recorder
Running hour counter. Active time of a selected digital input and time stamps of the latest start and stop.
Day and week timers
Digital inputs including virtual inputs
Digital outputs (relays) and output matrix
Visible only when AO card installed
Protection counters, combined overcurrent status, protection status, protection enabling, cold load and inrush detectionIf2> and block matrix
Motor status
1st line differential stage
2nd line differential stage
1st overcurrent stage
87L
87L
50/51
50/51 2nd overcurrent stage
3rd overcurrent stage
Current unbalance stage
Thermal overload stage
Second harmonic O/C stage
Fifth harmonic O/C stage
50/51
46
49
51F2
51F5
1st earth fault stage
2nd earth fault stage
3rd earth fault stage
4th earth fault stage
1st directional earth fault stage
2nd directional earth fault stage
1st residual overvoltage stage
2nd residual overvoltage stage
67N
67N
59N
59N
50N/51N
50N/51N
50N/51N
50N/51N
Note
1
1
2
4
4
4
4
4
4
4
4
4
4
4
4
4
4
4
4
4
19
2.2 Local panel operations
2 Local panel user interface
ArcIo>
AR
OBJ
Lgic
CONF
Bus
OPT
Diag
Main menu
Prg1
Prg2
Prg3
Prg4
Prg5
Prg6
Prg7
Prg8
CBFP
CBWE
CTSV
ArcI>
Number of menus
3
3
3
3
3
3
3
3
3
5
1
11
10
2
9
4
11
11
1
9
Description
1st programmable stage
2nd programmable stage
3rd programmable stage
4th programmable stage
5th programmable stage
6th programmable stage
7th programmable stage
8th programmable stage
Circuit breaker failure protection
Circuit breaker wearing supervision
CT supervisor
ANSI code
50BF
Optional arc protection stage for phase-to-phase faults and delayed light signal.
50ARC
Optional arc protection stage for earth faults. Current input = I
0
Auto-reclose
50NARC
79
Object definitions
Status and counters of user’s logic
Device setup, scaling etc.
Serial port and protocol configuration
Option cards
Device selfdiagnosis
4
6
7
5
1
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.
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.
Note
4
4
4
4
4
4
4
4
4
4
4
4
20
V59/en M/A009
2 Local panel user interface
2.2.1
2.2 Local panel operations
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.
ExDO
Prot
I>
I>>
Iv>
I >
I>> STATUS
Status
SCntr
TCntr
SetGrp
SGrpDI
Force
-
5
2
-
1
OFF
50 / 51
Figure 2.4: First menu of I>> 50/51 stage
This is the status, start and trip counter and setting group menu.
• Status –
The stage is not detecting any fault at the moment. The stage can also be forced to pick-up or trip is the operating level is
“Configurator” and the force flag below is on. Operating levels
are explained in Chapter 2.2.4 Operating levels.
• SCntr 5
The stage has picked-up a fault five times since the last reset or restart. This value can be cleared if the operating level is at least
“Operator”.
• TCntr 2
The stage has tripped two times since the last reset or 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 2.2.2 Setting groups
• 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 Forced control (Force).
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21
2.2 Local panel operations
2 Local panel user interface
I>> SET 50 / 51
Stage setting group 1
ExDI
ExDO
Prot
I>>
CBWE
OBJ
ILmax
Status
I>>
I>> t>>
403A
-
1013A
2.50xIn
0.60s
Figure 2.5: Second menu(next on the right) of I>> 50/51 stage
This is the main setting menu.
• Stage setting group 1
These are the group 1 setting values. The other setting group can be seen by pressing push buttons and then or
Setting groups are explained in Chapter 2.2.2 Setting groups.
.
• ILmax 403A
The maximum of 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>> 2.50 x I
N
The pick-up limit is 2.50 times the rated current of the generator.
This value can be edited if the operating level is at least
“Operator”. Operating levels are explained in Chapter 2.2.4
• 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”.
22
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2.2.2
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2.2 Local panel operations
I>> LOG
FAULT LOG 1
ExDI 2006-09-14
ExDO
Prot
I>>
CBWE
OBJ
12:25:10.288
Type
Flt
Load
EDly
1-2
2.86xIn
0.99xIn
81%
SetGrp 1
50/51
Figure 2.6: 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 2.2.3 Fault logs.
• FAULT LOG 1
This is the latest of the eight available logs. You may move between the logs by pressing push buttons or .
and then
• 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 2.86 x I
N
The fault current has been 2.86 per unit.
• Load 0.99 x I
N
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 that the delay setting.
• SetGrp 1
The setting group has been 1. This line can be reached by pressing and several times .
Setting groups
Most of the protection functions of the relay have four setting groups.
These groups are useful for example when the network topology is changed frequently. The active group can be changed by a digital
23
2.2 Local panel operations
2 Local panel user interface input, through remote communication or locally by using the local panel.
The active setting group of each protection function can be selected
separately. Figure 2.7 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 2.7: 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 to select the submenu. Now the selected setting group is
indicated in the down-left corner of the display (See Figure 2.8). Set1
is setting group one and Set2 is setting group two. When the needed changes, to the selected setting group, have been done, press or to select another group ( group is 2 and is used when the active setting is used when the active setting group is 1).
Figure 2.8: Example of I> setting submenu
24
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2.2.3
2.2 Local panel operations
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. The fault logs are stored in non-volatile memory. Each function has its own logs. The fault logs are not cleared when power is switched off. The user is able to clear all logs
using VAMPSET. Each function has its own logs (Figure 2.9).
Figure 2.9: Example of fault log
To see the values of, for example, log two, press then to select the current log (log one). The current log number is then indicated
in the down-left corner of the display (SeeFigure 2.10, Log2 = log
two). The log two is selected by pressing once.
Figure 2.10: Example of selected fault log
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2.2 Local panel operations
2.2.4
2 Local panel user interface
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
Use:
Opening:
Closing:
Possible to read e.g. parameter values, measurements and events
Level permanently open
Closing not possible
OPERATOR level
Use:
Opening:
Setting state:
Possible to control objects and to change e.g. the settings of the protection stages
Default password is 1
Closing:
Push
The level is automatically closed after 10 minutes idle time. Giving the password 9999 can also close the level.
CONFIGURATOR level
Use:
Opening:
Setting state:
The configurator level is needed during the commissioning of the relay. E.g. the scaling of the voltage and current transformers can be set.
Default password is 2
Closing:
Push
The level is automatically closed after 10 minutes idle time. Giving the password 9999 can also close the level.
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Opening access
1.
Push and on the front panel
ENTER PASSWORD
2.2 Local panel operations
***
0
Figure 2.11: 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 desired digit value using .
and then setting
3. Push
.
Password handling
The passwords can only be changed using VAMPSET software connected to the USB -port in front of 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 virtual serial port settings are 38400 bps, 8 data bits, no parity and one stop bit. The bit rate is configurable via the front panel.
Command
get pwd_break get serno
Description
Get the break code (Example: 6569403)
Get the serial number of the relay (Example: 12345)
Send both the numbers to your nearest Schneider Electric Customer
Care Centre 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.
Command Description
set pwd_break=4435876 Restore the factory default passwords (“4435876” is just an example. The actual code should be asked from your nearest
Schneider Electric Customer Care Centre.)
Now the passwords are restored to the default values (See
Chapter 2.2.4 Operating levels ).
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2.3 Operating measures
2.3
2.3.1
Operating measures
Control functions
The default display of the local panel is a single-line diagram including relay identification, Local/Remote indication, Auto-reclose 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 Chapter 2.2.4 Operating levels.
Toggling Local/Remote control
1. Push
. The previously activated object starts to blink.
2. Select the Local/Remote object (“L” or “R” squared) by using arrow keys.
3. Push
. 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 change.
. The Local/Remote state will
Object control
- Using
1. Push
and /
. The previously activated object starts to blink.
2. Select the object to control by using arrow keys. Please note that only controllable objects can be selected.
3. Push
. A control dialog opens.
4. Select the “Open” or “Close” command by using the or .
5. Confirm the operation by pushing changes.
. The state of the object
- Using
1.
& in object control mode
Push or . Object assigned to the key starts to blink and a control dialog opens.
2. Confirm the operation by pushing
.
Toggling virtual inputs
1. Push
. The previously activated object starts to blink.
2. Select the virtual input object (empty or black square)
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2 Local panel user interface
2 Local panel user interface
2.3 Operating measures
3. The dialog opens
4. Select “VIon” to activate the virtual input or select “VIoff” to deactivate the virtual input
2.3.2
Value
IL1
IL2
IL3
IL1da
IL2da
IL3da
Io
IoC
I1
I2
I2/I1 f
Uo
AngDiag
THDIL
THDIL1
THDIL2
THDIL3
IL1har
IL2har
IL3har
IL1 wave
IL2 wave
IL3 wave
IL1 avg
IL2 avg
IL3 avg
Measured data
The measured values can be read from the Meas menu and its 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.
Menu/Submenu
MEAS/PHASE CURRENTS
MEAS/PHASE CURRENTS
MEAS/PHASE CURRENTS
MEAS/PHASE CURRENTS
MEAS/PHASE CURRENTS
MEAS/PHASE CURRENTS
MEAS /SYMMETRIC CURRENTS
MEAS /SYMMETRIC CURRENTS
MEAS /SYMMETRIC CURRENTS
MEAS /SYMMETRIC CURRENTS
MEAS /SYMMETRIC CURRENTS
MEAS/MISCELLANEOUS
MEAS/MISCELLANEOUS
MEAS/ANGEE DIAGRAM
MEAS /HARM. DISTORTION
MEAS /HARM. DISTORTION
MEAS /HARM. DISTORTION
MEAS /HARM. DISTORTION
MEAS/HARMONICS of IL1
MEAS/HARMONICS of IL2
MEAS/HARMONICS of IL3
MEAS/IL1 WAVEFORM
MEAS/IL2 WAVEFORM
MEAS/IL3 WAVEFORM
MEAS/IL1 AVERAGE
MEAS/IL2 AVERAGE
MEAS/IL3 AVERAGE
Description
Phase current IL1 [A]
Phase current IL2 [A]
Phase current IL3 [A]
15 min average for IL1 [A]
15 min average for IL2 [A]
15 min average for IL3 [A]
Primary value of zerosequence/ residual current Io [A]
Calculated Io [A]
Positive sequence current [A]
Negative sequence current [A]
Negative sequence current related to positive sequence current (for unbalance protection) [%]
Residual voltage Uo [%]
Frequency [Hz]
Phasors
Total harmonic distortion of the mean value of phase currents [%]
Total harmonic distortion of phase current IL1 [%]
Total harmonic distortion of phase current IL2 [%]
Total harmonic distortion of phase current IL3 [%]
Harmonics of phase current IL1 [%]
Harmonics of phase current IL2 [%]
Harmonics of phase current IL3 [%]
Waveform of IL1
Waveform of IL2
Waveform of IL3
10 min average of IL1
10 min average of IL2
10 min average of IL3
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2.3 Operating measures
2 Local panel user interface
2.3.3
Figure 2.12: Example of harmonics bar display
Reading event register
The event register can be read from the Evnt submenu:
1. Push 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 2.13: Example of an event register
3. Scroll through the event list with the
4. Exit the event list by pushing
.
and .
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.
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2.3.4
2.3 Operating measures
Forced control (Force)
In some menus it is possible to switch a function 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. Open access level Configurator.
2. Move to the setting state of the desired function, for example DO
(see Chapter 2.4 Configuration and parameter setting).
3. Select the Force function (the background color of the force text is black).
V59/en M/A009
Figure 2.14: Selecting Force function
4. Push
.
5. Push the or to change the "OFF" text to "ON", that is, to activate the Force function.
6. Push controlled by force with the signal.
to return to the selection list. Choose the signal to be and , for instance the T1
7. Push to confirm the selection. Signal T1 can now be controlled by force.
8. Push the or to change the selection from "0" (not alert) to "1" (alert) or vice versa.
9. Push to execute the forced control operation of the selected function, e.g., making the output relay of T1 to pick up.
10. Repeat the steps 7 and 8 to alternate between the on and off state of the function.
11. Repeat the steps 1 – 4 to exit the Force function.
12.
Push to return to the main menu.
NOTE: All the interlockings and blockings are bypassed when the force
control is used.
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2.4 Configuration and parameter setting
2.4
2 Local panel user interface
Configuration and parameter setting
The minimum procedure to configure a device 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, voltage transformers and motor ratings if applicable.
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 USB-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 requiresrestarting, the display will show as Figure 2.15
32
Figure 2.15: Example of auto-reset display
Press to return to the setting view. If a parameter must be changed, press again. The parameter can now be set. When the parameter change is confirmed with , a [RESTART]- text appears to the top-right corner of the display. This means that auto-resetting is pending. If no key is pressed, the auto-reset will be executed within few seconds.
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2.4.1
2.4 Configuration and parameter setting
Parameter setting
1. Move to the setting state of the desired menu (for example
CONF/CURRENT SCALING) by pushing appears in the upper-left part of the display.
. The Pick text
2. Enter the password associated with the configuration level by pushing and then using the arrow keys and (default value is 0002). For more information about the access levels,
please refer to Chapter 2.2.3 Fault logs.
3. Scroll through the parameters using the and . 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
.
5. Use the and keys to change a parameter value. If the value contains more than one digit, use the to shift from digit to digit, and the the digits.
and and keys keys to change
6. Push to accept a new value. If you want to leave the parameter value unchanged, exit the edit state by pushing .
VAMP 50 series changing parameters
Figure 2.16: Changing parameters
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2.4 Configuration and parameter setting
2.4.2
2 Local panel user interface
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
Adjust the setting to be within the allowed range.
.
Figure 2.17: Example of a fault message
The allowed setting range is shown in the display in the setting mode.
To view the range, push . Push to return to the setting mode.
2.4.3
34
Figure 2.18: Allowed setting ranges show in the display
Disturbance recorder menu DR
Via the submenus of the disturbance recorder menu the following functions and features can be read and set:
Disturbance settings
1. Manual trigger (ManTrg)
2. Status (Status)
3. Clear oldest record (Clear)
4. Clear all records (ClrAll)
5. Recording completion (Stored)
6. Count of ready records (ReadyRec)
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2.4.4
V59/en M/A009
2.4 Configuration and parameter setting
Recorder settings
1. Manual trigger (ManTrig)
2. Sample rate (SR)
3. Recording time (Time)
4. Pre trig time (PreTrig)
5. Mximum time (MaxLen)
6. Count of ready records (ReadyRec)
Rec. channels
• Add a link to the recorder (AddCh)
• Clear all links (ClrCh)
Available links
• DO, DI
• IL
• I2/In, I2/I1, I2, I1, IoCalc
• f
• Io
• IoRMS
• IL3, IL2, IL1
• IL1Rem, IL2Rem, IL3Rem
• THDIL1, THDIL2, THDIL3
• IL1RMS, IL2RMS, IL3RMS
• ILmin
• ILmax
• T
• Uo
Configuring digital inputs DI
The following functions can be read and set via the submenus of the digital inputs menu:
1. The status of digital inputs (DIGITAL INPUTS 1, 2)
2. Operation counters (DI COUNTERS)
3. Operation delay (DELAYs for DigIn)
4. The polarity of the input signal (INPUT POLARITY). Either normally open (NO) or normally closed (NC) circuit.
5. Event enabling EVENT MASK1
35
2.4 Configuration and parameter setting
2.4.5
2.4.6
2 Local panel user interface
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):
Forced control (0 or 1) of the Trip relays
Forced control (0 or 1) of the Alarm relays
Forced control (0 or 1) of the SF 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, C, D, E, F, G and H (that is, the output relay matrix).
NOTE: The amount of Trip and Alarm relays depends on the relay type and
optional hardware.
Configuring analogue outputs AO (Option)
Via the submenus of the analogue output menu the following functions can be read and set:
Analog output
• Value of AO1 (AO1)
• Forced control of analogue output (Force)
Analog output 1 – 4
• Value linked to the analogue output (Lnk1)
• (See list available links)
• Scaled minimum of linked value (Min)
• Scaled maximum of linked value (Max)
• Scaled minimum of analogue output (AOmin)
• Scaled maximum of analogue output (AOmax)
• Value of analogue output (AO1)
36
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2.4.7
2.4.8
2.4 Configuration and parameter setting
Available links:
• IL1, IL2, IL2
• F
• IL
• Io, IoCalc
• Uo
Protection menu Prot
The following functions can be read and set via the submenus of the
Prot menu:
1. Reset all the counters (PROTECTION SET/ClAll)
2. Read the status of all the protection functions (PROTECT
STATUS 1 – x)
3. Enable and disable protection functions (ENABLED STAGES 1
– x)
4. Define the interlockings using block matrix (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.
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 communication ports and the USB-port in the front panel. The front panel is always using this setting. If SPABUS is selected for the rear panel port, the bit rate is according SPABUS settings.
• Access level [Acc]
• PC access level [PCAcc]
Language
• List of available languages in the relay
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2.4 Configuration and parameter setting
2 Local panel user interface
Current scaling
• Rated phase CT primary current (Inom)
• Rated phase CT secondary current (Isec)
• Rated input of the relay [Iinput] is 5 A
• Rated value of I
0
CT primary current (Ionom)
• Rated value of I
0
CT secondary current (Iosec)
• Rated I
0 input of the relay [Ioinp] is 1 A / 5 A or 0.2 A / 1 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.
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 I
0
, 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.
Voltage scaling
• Rated U
0
VT secondary voltage (Uosec)
Device info
• Relay type (Type VAMP 59)
• 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".
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2.4 Configuration and parameter setting
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).
SW options
• Application mode, fixed Feeder (ApplMod)
• External led module installed (Ledmodule)
• Mimic display selection (MIMIC)
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2.4 Configuration and parameter setting
2.4.9
2 Local panel user interface
Protocol menu Bus
There are three optional communication ports in the rear panel. The
availability depends on the communication options (see Chapter 14
In addition there is a USB-connector in the front panel overruling the local port in the rear panel.
Remote port
• Communication protocol for remote port [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.
PC (Local/SPA-bus)
This is a second menu for local port. 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.
Extension port
• Communication protocol for extension port [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.
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2.4 Configuration and parameter setting
Ethernet port
These parameters are used by the ethernet interface module. 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 address 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 Chapter 9.2.2 Modbus TCP and Modbus RTU.
External I/O protocol
External I/O is actually a set of protocols which are designed to be used with the extension I/O modules connected to the extension port. Only one instance of this protocol is possible.
Selectable protocols:
• Modbus: This is a modbus master protocol.
Bit rate [bit/s]. Default is ”9600”.
Parity [Parity]. Default is ”Even”.
• RTDInput: This protocol is designed to be used together with
VIO 12A RTD input module.
Bit rate [bit/s]. Default is ”9600”.
Parity [Parity]. Default is ”Even”.
For details, see Chapter 9.2.4 External I/O (Modbus RTU master).
41
2.4 Configuration and parameter setting
2.4.10
2 Local panel user interface
DNP3
Only one instance of this protocol is possible.
• Bit rate [bit/s]. Default is "9600".
• [Parity].
• Address for this device [SlvAddr]. This address has to be unique within the system.
• Master's address [MstrAddr].
For details, see Chapter 9.2.3 DNP 3.0.
Single line diagram editing
The single-line diagram is drawn with the VAMPSET software. For more information, please refer to the VAMPSET manual
(VVAMPSET/EN M/xxxx).
Ba y
0 L
0A
0.000A
0kW
0Kva r
2.4.11
Figure 2.19: Single line diagram
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 (VVAMPSET/EN M/xxxx).
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3
3.1
V59/en M/A009
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
A USB port is available for connecting a local PC with VAMPSET to the relay. A standard USB-B cable can be used.
The VAMPSET program can also use the TCP/IP LAN connection.
Optional hardware is required for Ethernet connection.
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. For more information about the VAMPSET software, please refer to the user’s manual with the code VVAMPSET/EN M/xxxx. Also the VAMPSET user’s manual is available at our web site.
When the relay is connected to a PC with a USB, a virtual comport will be created. The comport number may vary depending on your computer hardware. In order to check the correct port number, please go to Windows Device Manager: Control
Panel->System->Hardware->Device Manager and under Ports
(COM&LPT) for “USB Serial Port”. The correct comport must be selected from the VAMPSET menu: Settings->Communication
Settings. Speed setting can be set up to 187500 bps. Default setting in the relay is 38400 bps which can be manually changed from the front panel of the device.
By default every new relay will create a new comport. To avoid this behavior, the user needs to add a REG_BINARY value called
IgnoreHWSerNum04036001 to the Windows registry and set it to
01. The location for this value is
HKEY_LOCAL_MACHINE\SYSTEM\CurrentControlSet\Control\UsbFlags\.
Folder view
In VAMPSET version 2.2.136, a feature called ”Folder view” was introduced.
The idea of folder view is to make it easier for the user to work with relay functions inside VAMPSET. When folder view is enabled,
VAMPSET gathers similar functions together and places them appropriately under seven different folders (GENERAL,
43
3.1 Folder view
3 VAMPSET PC software
MEASUREMENTS, INPUTS/OUTPUTS, MATRIX, LOGS and
COMMUNICATION). The contents (functions) of the folders depend on the relay type and currently selected application mode.
Folder view can be enabled in VAMPSET via Program Settings dialog
(Settings -> Program Settings), see Figure 3.1.
44
Figure 3.1: Enable folder view setting in Program Settings dialog
NOTE: It is possible to enable/ disable the folder view only when VAMPSET
is disconnected from the relay and there is no configuration file opened.
When folder view is enabled, folder buttons become visible in
VAMPSET, see Figure 3.2. Currently selected folder appears in bold.
Figure 3.2: Folder view buttons
V59/en M/A009
4 Introduction
4
4.1
V59/en M/A009
Introduction
The numerical device includes all the essential overcurrent and earthfault protection functions needed. Further, the device includes several programmable functions, such as thermal, trip circuit supervision and circuit breaker protection and communication protocols for various protection and communication situations.
Main features
• Fully digital signal handling with microprocessor technology, and high measuring accuracy on all the setting ranges due to an accurate A/D conversion technique.
• Complete set of function for the proper protection of lines
• 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 device to various substations and alarm systems due to flexible signal-grouping matrix in the device.
• Possibility to control objects (e.g. circuit-breakers, disconnectors) from relay HMI or SCADA/automation system
• Freely configurable large 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 relay HMI or by means of a PC based VAMPSET user interface.
• All events, indications, parameters and waveforms are in non-volatile memory.
• Easy configuration, parameterisation and reading of information via local HMI, or with a VAMPSET user interface.
• Easy connection to various automation systems due to several available communication protocols. Native IEC61850 implementation is available as option.
• Flexible communication option concept available to support different media requirements (serial interfaces, optical fibres,
Ethernet etc),
• Built-in, self-regulating ac/dc converter for auxiliary power supply from any source within the range from 40 to 265 Vdc or Vac. The alternative power supply is for 18 to 36 Vdc.
45
4.2 Principles of numerical protection techniques
4.2
4 Introduction
• Built-in disturbance recorder for evaluating all the analogue and digital signals.
Principles of numerical protection techniques
The device is fully designed 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 device is primarily based on an adapted Fast Fourier Transformation (FFT). In FFT the number of calculations (multiplications and additions), which are required to filter out the measuring quantities, remains reasonable.
By using synchronized sampling of the measured analog signals and a sample rate according to the 2 n series, the FFT technique leads to a solution, which can be realized with a 16 bit micro controller, without using a separate DSP (Digital Signal Processor).
The synchronized sampling means an even number of 2 n samples per period (e.g. 32 samples per a period). This means that the frequency must be measured and the number of the samples per period must be controlled accordingly so that the number of the samples per period remains constant if the frequency changes.
Therefore, some current has to be injected to the current input I
L1 adapt the network frequency for the device. However, if this is not to possible then the frequency must be parameterised to the device.
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.
Figure 4.1 shows a principle block diagram of a numerical device.
The main components are the energizing inputs, digital input elements, output relays, A/D converters and the micro controller including memory circuits. Further, a device contains a power supply unit and a human-machine interface (HMI).
Figure 4.2 shows the heart of the numerical technology. That is the
main block diagram for calculated functions.
Figure 4.3 shows a principle diagram of a single-phase overvoltage
function.
V59/en M/A009
46
4 Introduction
4.2 Principles of numerical protection techniques
Figure 4.1: Principle block diagram of the VAMP hardware
Figure 4.2: Block diagram of signal processing and protection software
V59/en M/A009
Figure 4.3: Block diagram of a basic protection function
47
5
5.1
5.2
5 Protection functions
Protection functions
Each protection stage can independently be enabled or disabled according to the requirements of the intended application.
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 Configuration and parameter setting.
General features of protection stages
Setting groups
Setting groups are controlled by using digital inputs, function keys or virtual inputs. When none of the assigned input/inputs is/are not active the active setting group is defined by parameter ‘SetGrp no control state’. When controlled input activates the corresponding setting group is activated as well. If multiple inputs are active at the same time the active setting group is defined by ‘SetGrp priority’. By using virtual I/O the active setting group can be controlled using the local panel display, any communication protocol or using the inbuilt programmable logic functions.
48
Example
Any digital input could be used to control setting groups but in this example DI1, DI2, DI3 and DI4 are chosen to control setting groups
1 to 4. This setting is done with a parameter “Set group x DI control” where x refers to the desired setting group.
V59/en M/A009
5 Protection functions
5.2 General features of protection stages
Figure 5.1: DI1, DI2, DI3, DI4 are configured to control Groups 1 to 4 respectively.
“SetGrp priority” is used to give a condition to a situation where two or more digital inputs, controlling setting groups, are active and at a same time . SetGrp priority could have vales “1 to 4” or “4 to 1”.
V59/en M/A009
Figure 5.2: SetGrp priority setting is located in the Valid Protection stages view.
Assuming that DI2 and DI3 are active at a same time and SetGrp priority is set to “1 to 4” setting group 2 will become active. In case
SetGrp priority is reversed i.e. it is set to “4 to 1” setting group 3 would be active.
Forcing start or trip condition for testing
The status of a protection stage can be one of the followings:
•
Ok = ‘-‘
The stage is idle and is measuring the analog quantity for the protection. No fault detected.
•
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.
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 more details about block
matrix, see Chapter 8.6 Blocking matrix.
49
5.2 General features of protection stages
5 Protection functions
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 device 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.
Force flag can be found in relays menu.
50
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
Blocking
Any protection function, except arc protection, can be blocked with
internal and external signals using the block matrix (Chapter 8.6
Blocking matrix). 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.
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.
V59/en M/A009
5 Protection functions
5.2 General features of protection stages
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.
RetardationTime
V59/en M/A009 t
FAULT
DELAY SETTING > t
FAULT
+ t
RET
TRIP CONTACTS t < 50 ms
RET
Figure 5.3: Definition for retardation time. If the delay setting would be slightly shorter, an unselective trip might occur (the dash line pulse).
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 5.3 shows an overvoltage 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 devices the retardation time is less than 50 ms.
Reset time (release time)
Figure 5.4 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 precise reset time depends on the fault size; after a big fault the reset time is longer. The reset time also depends on the specific protection stage.
51
5.2 General features of protection stages
5 Protection functions
The maximum reset time for each stage is specified in Chapter 12.3
Protection functions. For most stages it is less than 95 ms.
t
SET t
CB
TRIP CONTACTS t
RESET
Figure 5.4: Reset time is the time it takes the trip or start relay contacts to open after the fault has been cleared.
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.
Hysteresis_GT
PICK UP LEVEL
> PICK UP
Figure 5.5: Behaviour of a greater than comparator. For example in overvoltage stages the hysteresis (dead band) acts according this figure.
Hysteresis_LT
PICK UP LEVEL
< PICK UP
Figure 5.6: Behaviour of a less than comparator. For example in under-voltage and under frequency stages the hysteresis (dead band) acts according this figure.
52
V59/en M/A009
5 Protection functions
5.3
5.4
5.5
5.3 Application modes
Application modes
The application modes available are the feeder protection mode and the motor protection mode. In the feeder protection mode all current dependent protection functions are relative to nominal current I
N derived by CT ratios. The motor protection functions are unavailable in the feeder protection mode. In the motor protection mode all current dependent protection functions are relative to motor’s nominal current
I
MOT
. The motor protection mode enables motor protection functions.
All functions which are available in the feeder protection mode are also available in the motor protection mode. Default value of the application mode is the feeder protection mode.
The application mode can be changed with VAMPSET software or from CONF menu of the device. Changing the application mode requires configurator password.
Current protection function dependencies
The current based protection functions are relative to I
MODE
, which is dependent of the application mode. In the motor, protection mode all of the current based functions are relative to I
MOT protection mode to I
N with following exceptions.
and in the feeder
I
2
> (46), I
2
>> (47), I
ST
> (48), N> (66) are always dependent on I
MOT and they are only available when application mode is in the motor protection.
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.
V59/en M/A009
53
5.5 Overcurrent protection I> (50/51)
5 Protection functions
Figure 5.7: Block diagram of the three-phase overcurrent stage I>
54
Figure 5.8: Block diagram of the three-phase overcurrent stage I>> and I>>>
Three independent stages
There are three separately adjustable overcurrent stages: I>, I>> and I>>>. The first stage I> can be configured for definite time (DT) or inverse time operation characteristic (IDMT). The stages I>> and
I>>> have definite time operation characteristic. By using the definite delay type and setting the delay to its minimum, an instantaneous
(ANSI 50) operation is obtained.
shows a functional block diagram of the I>> and I>>> overcurrent stages 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 5.17 Inverse time operation. The device will
V59/en M/A009
5 Protection functions
5.5 Overcurrent protection I> (50/51)
show the currently used inverse delay curve graph on the local panel display.
Inverse time limitation
The maximum measured secondary current is 50 x I
N
. This limits the scope of inverse curves with high pick-up settings. See
Chapter 5.17 Inverse time operation for more information.
Cold load and inrush current handling
See Chapter 6.3 Cold load pick-up and inrush current detection.
Parameter
Status
TripTime
SCntr
TCntr
SetGrp
SGrpDI
Force
ILmax
Status
I>
I>
Curve
Setting groups
-
DIx
VIx
LEDx
VOx
Fx
Off
On
-
Value
Blocked
Start
Trip
1, 2, 3, 4
-
DT
IEC, IEEE,
IEEE2, RI, PrgN
There are four settings groups available for each stage. Switching between setting groups can be controlled by digital inputs, virtual
Table 5.1: Parameters of the overcurrent stage I> (50/51)
Unit Description
Current status of the stage
Note
-
-
F
F s
A
A xI
N
Estimated time to trip
Cumulative start counter
Cumulative trip counter
Active setting group
Digital signal to select the active setting group
None
Digital input
Virtual input
LED indicator signal
Virtual output
Function key
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.
The supervised value. Max. of IL1, IL2 and IL3
Current status of the stage
Pick-up value scaled to primary value
Pick-up setting
Delay curve family:
Definite time
Inverse time. See Chapter 5.17 Inverse time operation.
C
C
Set
Set
Set
Set
Set
V59/en M/A009
55
5.5 Overcurrent protection I> (50/51)
5 Protection functions
Parameter
Type t> k>
Dly20x
Dly4x
Dly2x
Dly1x
IncHarm
Delay curves
A, B, C, D, E
-
Value
DT
NI, VI, EI, LTI,
Parameters
Recorded values
LOG1
Type
Flt
Load
Edly
SetGrp
Unit
s s s s s
On/off xI
N xI
N
%
Description
Delay type
Definite time
Inverse time. See Chapter 5.17 Inverse time operation.
Definite operation time (for definite time only)
Inverse delay multiplier (for inverse time only)
Delay at 20xImode
Delay at 4xImode
Delay at 2xImode
Delay at 1xImode
Include Harmonics
Graphic delay curve picture (only local display)
User's constants for standard equations. Type=Parameters.
Chapter 5.17 Inverse time operation.
Date and time of trip
Fault type
Fault current
Pre-fault current
Elapsed delay time
Active set group during fault
Note
Set
Set
Set
Set
Set = An editable parameter (password needed). C = Can be cleared to zero. F = Editable when force flag is on.
For details of setting ranges, see Table 12.20.
Parameter
Status -
Value
Blocked
Start
Trip
Table 5.2: Parameters of the overcurrent stages I>>, I>>> (50/51)
Unit Description
Current status of the stage
SCntr
TCntr
SetGrp
SGrpDI
1, 2, 3, 4
Note
-
-
F
F
C
C
Set
Set
Force
ILmax
-
DIx
VIx
LEDx
VOx
Fx
Off
On
A
Cumulative start counter
Cumulative trip counter
Active setting group
Digital signal to select the active setting group
None
Digital input
Virtual input
LED indicator signal
Virtual output
Function key
Force flag for status forcing for test purposes. This is a common flag for all stages and output relays, too. Automatically reset by a
5-minute timeout.
The supervised value. Max. of IL1, IL2 and IL3
Set
56
V59/en M/A009
5 Protection functions
5.5 Overcurrent protection I> (50/51)
Parameter
I>>, I>>>
I>>, I>>> t>>, t>>>
IncHarm
Value Unit
A xI
N s
On/off
Description
Pick-up value scaled to primary value
Pick-up setting
Definite operation time.
Include Harmonics
Set = An editable parameter (password needed). C = Can be cleared to zero. F = Editable when force flag is on.
For details of setting ranges, see Table 12.21, Table 12.22.
Note
Set
Set
Set
Parameter
Type
3-N
1-2
2-3
3-1
1-2-3
Value
yyyy-mm-dd hh:mm:ss.ms
1-N
2-N
Flt
Load
EDly
SetGrp 1, 2, 3, 4
Recorded values of the latest eight faults
There is detailed information available of the eight latest faults: Time stamp, fault type, fault current, load current before the fault, elapsed delay and setting group.
Table 5.3: Recorded values of the overcurrent stages (8 latest faults) I>, I>>,
I>>> (50/51)
Unit Description
Time stamp of the recording, date
Time stamp, time of day
Fault type xI
N xI
N
%
Ground fault
Ground fault
Ground fault
Two phase fault
Two phase fault
Two phase fault
Three phase fault
Maximum fault current
1 s average phase currents before the fault
Elapsed time of the operating time setting. 100% = trip
Active setting group during fault
V59/en M/A009
57
5.5 Overcurrent protection I> (50/51)
5.5.1
5 Protection functions
Remote controlled overcurrent scaling
Pick-up setting of the three over current stages can also be controlled remotely. In this case only two scaling coefficients are possible:
100% (the scaling is inactive) and any configured value between
10% - 200% (the scaling is active). When scaling is enabled all settings of group one are copied to group two but the pick-up value of group two is changed according the given value (10-200%).
• This feature can be enabled/disabled via VAMPSET or by using the local panel. When using VAMPSET the scaling can be activated and adjusted in the “protection stage status 2” –menu.
When using the local panel similar settings can be found from the “prot” -menu.
• It is also possible to change the scaling factor remotely by using the modbus TCP –protocol. When changing the scaling factor remotely value of 1% is equal to 1. Check the correct modbus address for this application from the VAMPSET or from the communication parameter list.
58
Figure 5.9: Remote scaling example.
In the Figure 5.9 can be seen the affect of remote scaling. After
enabling group is changed from group one to group two and all settings from group one are copied to group two. The difference is that group two uses scaled pick-up settings.
NOTE: When remote scaling function is used, it replaces all the settings of
group 2. So this function cannot be used simultaneously with normal group change.
V59/en M/A009
5 Protection functions
5.6 Current unbalance stage I
2
/I
1
> (46)
5.6
Parameter
I2/I1> t>
Type
S_On
S_Off
T_On
T_Off
2
I
2
I
1
Current unbalance stage I
2
/I
1
> (46)
The purpose of the unbalance stage is to detect unbalanced load conditions, for example a broken conductor of a heavy loaded overhead line in case there is no earth fault. The operation of the unbalanced load function is based on the negative phase sequence component I
2 related to the positive phase sequence component I
This is calculated from the phase currents using the method of
1
.
symmetrical components. The function requires that the measuring inputs are connected correctly so that the rotation direction of the
phase currents are as in Chapter 11.11 Connection examples. The
unbalance protection has definite time operation characteristic.
I
1
= I
L1
+ aI
L2
+ a
2
I
L3
I
2
= I
L1
+ a
2
I
L2
+ aI
L3
a
= 1 ∠ 120 ° = −
1
2
+
j
2
3
, a phasor rotating constant
Value
2 – 70
1.0 – 600.0
DT
Table 5.4: Setting parameters of the current unbalanced stage I
2
/I
1
> (46)
Unit Default Description
% s
-
20
10.0
DT
Setting value, I2/I1
Definite operating time
The selection of time characteristics
INV
Enabled; Disabled
Enabled; Disabled
Enabled; Disabled
Enabled; Disabled
-
-
-
Enabled
Enabled
Enabled
Enabled
Start on event
Start off event
Trip on event
Trip off event
For details of setting ranges, see Table 12.24.
Measured value
Recorded values
Table 5.5: Measured and recorded values of the current unbalanced stage
I
2
/I
1
> (46)
Parameter Value Unit Description
% I2/I1
SCntr
TCntr
Flt
EDly
%
%
Relative negative sequence component
Cumulative start counter
Cumulative trip counter
Maximum I
2
/I
1 fault component
Elapsed time as compared to the set operating time; 100% = tripping
V59/en M/A009
59
5.7 Directional earth fault protection I
0φ
> (67N)
5.7
5 Protection functions
Directional earth fault protection I
0φ
>
(67N)
The directional earth fault protection is used in networks where a selective and sensitive earth fault protection is needed and in applications with varying network structure and length.
The device consists of versatile protection functions for earth fault protection in various network types.
The function is sensitive to the fundamental frequency component of the residual current and zero sequence voltage and the phase angle between them. The attenuation of the third harmonic is more than 60 dB. Whenever the size of I
0 between I
0 and U
0 and U
0 and the phase angle fulfils the pick-up criteria, the 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.
Polarization
The negative zero sequence voltage U
0 the angle reference for I
0
. The -U
0 is used for polarization i.e.
voltage is measured via energizing input U
0
.
• 3LN+U
0
: the zero sequence voltage is measured with voltage transformer(s) for example using a broken delta connection. The setting values are relative to the VT
0 in configuration.
secondary voltage defined
NOTE: The U
0 signal must be connected according the connection diagram
(Figure 11.8) in order to get a correct polarization.
Modes for different network types
The available modes are:
60
V59/en M/A009
5 Protection functions
5.7 Directional earth fault protection I
0φ
> (67N)
• ResCap
This mode consists of two sub modes, Res and Cap. A digital signal can be used to dynamically switch between these two sub modes. This feature can be used with compensated networks, when the Petersen coil is temporarily switched off.
Res
The stage is sensitive to the resistive component of the selected I
0 signal. This mode is used with compensated
networks (resonant grounding) and networks earthed with
a high resistance. Compensation is usually done with a
Petersen coil between the neutral point of the main transformer and earth. In this context "high resistance" means, that the fault current is limited to be less than the rated phase current. The trip area is a half plane as drawn
in Figure 5.11. The base angle is usually set to zero degrees.
Cap
The stage is sensitive to the capacitive component of the selected I
0 signal. This mode is used with unearthed
networks. The trip area is a half plane as drawn in
Figure 5.11. The base angle is usually set to zero degrees.
• Sector
This mode is used with networks earthed with a small
resistance. In this context "small" means, that a fault current
may be more than the rated phase currents. The trip area has a
shape of a sector as drawn in Figure 5.12. The base angle is
usually set to zero degrees or slightly on the lagging inductive side (i.e. negative angle).
• Undir
This mode makes the stage equal to the undirectional stage I
0
>.
The phase angle and U
0 amplitude setting are discarded. Only the amplitude of the selected I
0 input is supervised.
Input signal selection
Each stage can be connected to supervise any of the following inputs and signals:
• Input I
0 for all networks other than rigidly earthed.
• Calculated signal I
0Calc networks. I
0Calc
= I
L1
+ I for rigidly and low impedance earthed
L2
+ I
L3
= 3I
0
.
V59/en M/A009
61
5.7 Directional earth fault protection I
0φ
> (67N)
5 Protection functions
Intermittent earth fault detection
Short earth faults make the protection to start (to pick up), but will not cause a trip. (Here a short fault means one cycle or more. For shorter than 1 ms transient type of intermittent earth faults in compensated networks there is a dedicated stage I
0INT
> 67NI.) 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.
Two independent stages
There are two separately adjustable stages: I
0φ
> and I
0φ
>>. Both the stages can be configured for definite time delay (DT) or inverse time delay operation time.
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 both stages I
0φ
> and I
0φ
>>. The inverse
delay types are described in Chapter 5.17 Inverse time operation.
The device will show a scaleable graph of the configured delay on the local panel display.
Inverse time limitation
The maximum measured secondary residual current is 10 x I
0N and maximum measured phase current is 50 x I
N
. This limits the scope
Setting groups
There are four settings groups available for each stage. Switching between setting groups can be controlled by digital inputs, virtual
62
V59/en M/A009
5 Protection functions
5.7 Directional earth fault protection I
0φ
> (67N)
Figure 5.10: Block diagram of the directional earth fault stages I
0φ
>, I
0φ
>>
Figure 5.11: Operation characteristic of the directional earth fault protection in Res or Cap mode. Res mode can be used with compensated networks and Cap mode is used with ungrounded networks.
V59/en M/A009
63
5.7 Directional earth fault protection I
0φ
> (67N)
5 Protection functions
70
70
Force
Io
IoCalc
IoPeak
IoRes
IoCap
Ioφ>
64
Parameter
Status
TripTime
SCntr
TCntr
SetGrp
SGrpDI
Figure 5.12: Two example of operation characteristics of the directional earth fault stages in sector mode. The drawn I
0 phasor in both figures is inside the trip area. The angle offset and half sector size are user’s parameters.
-
DIx
VIx
LEDx
VOx
Fx
Off
On
-
Value
Table 5.6: Parameters of the directional earth fault stages I
0φ
>, I
0φ
>> (67N)
Unit Description Note
Current status of the stage -
Blocked -
Start
Trip
F
F
1, 2, 3, 4 s pu
Estimated time to trip
Cumulative start counter
Cumulative trip counter
Active setting group
Digital signal to select the active setting group
None
Digital input
Virtual input
LED indicator signal
Virtual output
Function key
Force flag for status forcing for test purposes. This is a common flag for all stages and output relays, too. Automatically reset by a 5-minute timeout.
The supervised value according the parameter "Input" below.
(I
0φ
> only)
Clr
Clr
Set
Set
Set pu pu
A
Resistive part of I
0
(only when "InUse"=Res)
Capacitive part of I
0
(only when "InUse"=Cap)
Pick-up value scaled to primary value
V59/en M/A009
5 Protection functions
5.7 Directional earth fault protection I
0φ
> (67N)
Parameter
Ioφ>
Uo>
Uo
Curve
Type
Value
-
DT
-
IEC, IEEE,
IEEE2, RI, PrgN
DT
NI, VI, EI, LTI,
Parameters
Unit
pu
%
%
Description
Pick-up setting relative to the parameter “Input” and the corresponding CT value
Pick-up setting for U
0
Measured U
0
Delay curve family:
Definite time
Inverse time. Chapter 5.17 Inverse time operation.
Delay type.
Definite time
Inverse time. Chapter 5.17 Inverse time operation.
Note
Set
Set
Set
Set t> k>
Mode
Offset
Sector
ChCtrl
InUse
Input
Intrmt
Dly20x
Dly4x
Dly2x
Dly1x
A, B, C, D, E
-
ResCap
Sector
Undir
Default = 88
Res
Cap
DIx
VIx
Res
Cap
Io
IoCalc
IoPeak s
°
±° s s s s s
Definite operation time (for definite time only)
Inverse delay multiplier (for inverse time only)
High impedance earthed nets
Low impedance earthed nets
Undirectional mode
Angle offset (MTA) for RecCap and Sector modes
Half sector size of the trip area on both sides of the offset angle
Res/Cap control in mode ResCap
Fixed to Resistive characteristic
Fixed to Capacitive characteristic
Controlled by digital input
Controlled by virtual input
Selected submode in mode ResCap.
Mode is not ResCap
Submode = resistive
Submode = capacitive
X1:7, 8, 9. See Chapter 11 Connections.
IL1 + IL2 + IL3
X1:7, 8, 9 peak mode (I
0φ
> only)
Intermittent time
Delay at 20xI
0N
Delay at 4xI
0N
Delay at 2xI
0N
Delay at 1xI
0N
User's constants for standard equations.
Type=Parameters. See Chapter 5.17 Inverse time operation.
Set = An editable parameter (password needed). C = Can be cleared to zero. F = Editable when force flag is on.
For details of setting ranges, see Table 12.27.
Set
Set
Set
Set
Set
Set
Set
Set
Set
V59/en M/A009
65
5.7 Directional earth fault protection I
0φ
> (67N)
Parameter
Flt
EDly
Angle
Uo
SetGrp
5 Protection functions
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.
Table 5.7: Recorded values of the directional earth fault stages (8 latest faults) I
0φ
>, I
0φ
>> (67N)
Value Unit Description
yyyy-mm-dd hh:mm:ss.ms
pu
Time stamp of the recording, date
Time stamp, time of day
Maximum earth fault current
°
1, 2, 3, 4
%
%
Resistive part of I
0
(only when "InUse"=Res)
Capacitive part of I
0
(only when "InUse"=Cap)
Elapsed time of the operating time setting. 100% = trip
Fault angle of I
0
-U
0
= 0°
Max. U
0 voltage during the fault
Active setting group during fault
66
V59/en M/A009
5 Protection functions
5.8
5.8 Earth fault protection I
0
> (50N/51N)
Earth fault protection I
0
> (50N/51N)
The undirectional earth fault protection is to detect 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 3I
0
. 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.
Figure 5.13: Block diagram of the earth fault stage I
0
>
V59/en M/A009
Figure 5.14: Block diagram of the earth fault stages I
0
>>, I
0
>>>, I
0
>>>>
Figure 5.13 shows a functional block diagram of the I
0
> earth overcurrent stage with definite time and inverse time operation time.
Figure 5.14 shows a functional block diagram of the I
0
>>, I
0
>>> and
I
0
>>>> earth fault stages with definite time operation delay.
67
5.8 Earth fault protection I
0
> (50N/51N)
68
5 Protection functions
Input signal selection
Each stage can be connected to supervise any of the following inputs and signals:
• Input I
0 for all networks other than rigidly earthed.
• Calculated signal I
0Calc networks. I
0Calc
= I
L1
+ I for rigidly and low impedance earthed
L2
+ I
L3
.
Intermittent earth fault detection
Short earth faults make the protection to start (to pick up), but will not cause a trip. (Here a short fault means one cycle or more. For shorter than 1 ms transient type of intermittent earth faults in compensated networks there is a dedicated stage I
0INT
> 67NI.) 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.
Four or six independent undirectional earth fault overcurrent stages
There are four separately adjustable earth fault stages: I
0
>, I
0
>>,
I
0
>>>, and I
0
>>>>. The first stage I
0
> 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.
Using the directional earth fault stages (Chapter 5.7 Directional earth fault protection I
> (67N)) in undirectional mode, two more stages
with inverse operation time delay are available for undirectional earth fault protection.
Inverse operation time (I
0
> 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 I
0
> stage. The inverse delay types are
described in Chapter 5.17 Inverse time operation. The device will
show a scaleable graph of the configured delay on the local panel display.
Inverse time limitation
The maximum measured secondary residual current is 10 x I
0N and maximum measured phase current is 50 x I
N
. This limits the scope
V59/en M/A009
5 Protection functions
5.8 Earth fault protection I
0
> (50N/51N)
Parameter
Status
TripTime
SCntr
TCntr
SetGrp
SGrpDI
Force
Io, IoCalc, IoPeak
Io>
Io>
Curve
Type t> k>
Input
Intrmt
V59/en M/A009
Setting groups
-
DIx
VIx
LEDx
VOx
Fx
Off
On
-
Value
There are four settings groups available for each stage. Switching between setting groups can be controlled by digital inputs, virtual
Table 5.8: Parameters of the undirectional earth fault stage I
0
> (50N/51N)
Unit Description Note
Current status of the stage -
Blocked
Start
Trip
-
F
F
1, 2, 3, 4
-
DT
-
IEC, IEEE,
IEEE2, RI, PrgN
DT
NI, VI, EI, LTI,
Parameters s pu
A pu
Estimated time to trip
Cumulative start counter
Cumulative trip counter
Active setting group
Digital signal to select the active setting group
None
Digital input
Virtual input
LED indicator signal
Virtual output
Function key
Force flag for status forcing for test purposes. This is a common flag for all stages and output relays, too. Automatically reset by a 5-minute timeout.
The supervised value according the parameter "Input" below.
Pick-up value scaled to primary value
Pick-up setting relative to the parameter "Input" and the corresponding CT value
Delay curve family:
Definite time
Inverse time. Chapter 5.17 Inverse time operation.
Delay type.
Definite time
Inverse time. Chapter 5.17 Inverse time operation.
Clr
Clr
Set
Set
Set
Set
Set
Set
Io
IoCalc
IoPeak s s
Definite operation time (for definite time only)
Inverse delay multiplier (for inverse time only)
X1:7, 8, 9. See Chapter 11 Connections.
IL1 + IL2 + IL3
X1:7, 8, 9. peak mode (I
0φ
> only).
Intermittent time
Set
Set
Set
Set
69
5.8 Earth fault protection I
0
> (50N/51N)
5 Protection functions
Parameter
Dly20x
Dly4x
Dly2x
Dly1x
A, B, C, D, E
Value Unit
s s s
Description
Delay at 20 x I
0N
Delay at 4 x I
0N
Delay at 2 x I
0N
Delay at 1 x I
0N
User’s constants for standard equations.
Type=Parameters. See Chapter 5.17 Inverse time operation.
Note
Set
Set = An editable parameter (password needed). C = Can be cleared to zero. F = Editable when force flag is on.
For details of setting ranges, see Table 12.25.
Parameter
Status
TripTime
SCntr
TCntr
SetGrp
SgrpDI
Force
Io
IoCalc
Io>>, Io>>>, Io>>>>
Io>>, Io>>>, Io>>>>
-
1, 2, 3, 4
-
Dix
Vix
LEDx
VOx
Fx
Off
On
-
Value
Table 5.9: Parameters of the undirectional earth fault stage I
0
>>, I
0
>>>, I
0
>>>>
(50N/51N)
Unit Description Note
Current status of the stage -
Blocked
Start
Trip
-
F
F s pu
Estimated time to trip
Cumulative start counter
Cumulative trip counter
Active setting group
Digital signal to select the active setting group
None
Digital input
Virtual input
LED indicator signal
Virtual output
Function key
Force flag for status forcing for test purposes. This is a common flag for all stages and output relays, too. Automatically reset by a 5-minute timeout.
The supervised value according the parameter “Input” below.
Clr
Clr
Set
Set
Set
A pu Set t>
Input Io
IoCalc s
Pick-up value scaled to primary value
Pick-up setting relative to the parameter "Input" and the corresponding CT value
Definite operation time (for definite time only)
X1:7, 8, 9. See Chapter 11 Connections.
IL1 + IL2 + IL3
Set
Set
Set = An editable parameter (password needed). C = Can be cleared to zero. F = Editable when force flag is on.
For details of setting ranges, see Table 12.26.
70
V59/en M/A009
5 Protection functions
Parameter
Flt
EDly
SetGrp
5.8.1
V59/en M/A009
5.8 Earth fault protection I
0
> (50N/51N)
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.
Table 5.10: Recorded values of the undirectional earth fault stages (8 latest faults) I
0
>>, I
0
>>>, I
0
>>>> (50N/51N)
Value Unit Description
yyyy-mm-dd hh:mm:ss.ms
1, 2, 3, 4 pu
%
Time stamp of the recording, date
Time stamp, time of day
Maximum earth fault current
Elapsed time of the operating time setting. 100% = trip
Active setting group during fault
Earth fault faulty phase detection algorithm
Phase recognition:
A zero sequence overcurrent has been detected.
Faulted phase/ phases are detected in 2 stage system.
1. Algorithm is using delta principle to detect the faulty phase/ phases.
2. Algorithm confirms the faulty phase with neutral current angle comparison to the suspected faulted phase.
Ideal grounded network:
When there is forward earth fault in phase L1, its current will increase creating calculated or measured zero sequence current in phase angle of 0 degrees. If there is reverse earth fault in phase L1, its current will degrease creating calculated or measured zero sequence current in phase angle of 180 degrees.
When there is forward earth fault in phase L2, its current will increase creating calculated or measured zero sequence current in phase angle of -120 degrees. If there is reverse earth fault in phase L2, its current will degrease creating calculated or measured zero sequence current in phase angle of 60 degrees.
When there is forward earth fault in phase L3, its current will increase creating calculated or measured zero sequence current in phase angle of 120 degrees. If there is reverse earth fault in phase L3 its current will degrease creating calculated or measured zero sequence current in phase angle of -60 degrees.
Implementation:
When faulty phase is recognized, it will be recorded in 50N protection fault log (also in event list and alarm screen). This faulted phase and direction recording function has a tick box for enabling/disabling in
71
5.8 Earth fault protection I
0
> (50N/51N)
72
5 Protection functions protection stage settings. For compensated network, this is not a
100% reliable algorithm because it depends on the network compensation degree. So for compensated networks this feature can be turned off so it will not cause confusion. For high impedance earthed networks, there will be drop down menu in both setting groups to choose between RES/CAP. RES is default and it is for earthed networks. When CAP is chosen, the Io angle will be corrected to inductive direction 90 degrees and after that faulty phase detection is made.
Possible outcomes and conditions for those detections:
• FWD L1
Phase L1 increases above the set limit and two other phases remain inside the set (delta) limit. Io current angle is +/- 60 degrees from L1 phase angle.
• FDW L2
Phase L2 increases above the set limit and two other phases remain inside the set (delta) limit. Io current angle is +/- 60 degrees from L2 phase angle.
• FDW L3
Phase L3 increases above the set limit and two other phases remain inside the set (delta) limit. Io current angle is +/- 60 degrees from L3 phase angle.
• FWD L1-L2
Phase L1 and L2 increase above the set limit and phase L3 remains inside the set (delta) limit. Io current angle is between
L1 and L2 phase angles.
• FWD L2-L3
Phase L2 and L3 increase above the set limit and phase L1 remains inside the set (delta) limit. Io current angle is between
L2 and L3 phase angles.
• FWD L3-L1
Phase L3 and L1 increase above the set limit and phase L2 remains inside the set (delta) limit. Io current angle is between
L3 and L3 phase angles.
• FWD L1-L2-L3
All three phase currents increase above the set delta limit.
• REV 1 (any one phase)
One phase decreases below the set delta limit and other two phases remain inside the delta limit.
• REV 2 (any two phase)
Two phases decrease below the set delta limit and third phase remains inside the delta limit.
• REV 3 (all three phases)
All three phase currents decrease below the set delta limit.
V59/en M/A009
5 Protection functions
5.8 Earth fault protection I
0
> (50N/51N)
Below are simulated different fault scenarios:
Figure 5.15: Phase L1 forward
Figure 5.16: Phase L2 forward
Figure 5.17: Phase L3 forward
V59/en M/A009
73
5.9 Zero sequence voltage protection U
0
> (59N)
5.9
5 Protection functions
Zero sequence voltage protection U
0
>
(59N)
The zero sequence voltage protection is used as unselective backup for earth faults and also for selective earth fault protections for motors having a unit transformer between the motor and the busbar.
This function is sensitive to the fundamental frequency component of the zero sequence voltage. The attenuation of the third harmonic is more than 60 dB. This is essential, because 3rd harmonics exist between the neutral point and earth also when there is no earth fault.
Whenever the measured 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.
Measuring the zero sequence voltage
The zero sequence voltage is either measured with three voltage transformers (e.g. broken delta connection), one voltage transformer between the motor's neutral point and earth or calculated from the measured phase-to-neutral voltages according to the selected voltage
measurement mode (see Chapter 7.7 Voltage measurement modes):
• U
0
: The zero sequence voltage is measured with voltage transformer(s) for example using a broken delta connection. The setting values are relative to the VT
0 in configuration.
secondary voltage defined
NOTE: The U
0 signal must be connected according the connection diagram
(Figure 11.8) in order to get a correct polarization.
Two independent stages
There are two separately adjustable stages: U
0
> and U
0
>>. Both stages can be configured for definite time (DT) operation characteristic.
The zero sequence voltage function comprises two separately adjustable zero sequence voltage stages (stage U
0
> and U
0
>>).
Setting groups
There are four settings groups available for both stages. Switching between setting groups can be controlled by digital inputs, virtual
V59/en M/A009
74
5 Protection functions
5.9 Zero sequence voltage protection U
0
> (59N)
Figure 5.18: Block diagram of the zero sequence voltage stages U
0
>, U
0
>>
Parameter
Status
SCntr
TCntr
SetGrp
SGrpDI
Force
Uo
Uo>, Uo>>
Blocked
Start
Trip
-
DIx
VIx
LEDx
VOx
Fx
Off
On
-
Value
Table 5.11: Parameters of the residual overvoltage stages U
0
>, U
0
>>
Unit Description Note
Current status of the stage -
1, 2, 3, 4
Cumulative start counter
Cumulative trip counter
Active setting group
Digital signal to select the active setting group
None
Digital input
Virtual input
LED indicator signal
Virtual output
Function key
Force flag for status forcing for test purposes. This is a common flag for all stages and output relays, too.
Automatically reset by a 5-minute timeout.
-
F
F
C
C
Set
Set
Set
%
The supervised value relative to Un/
% Set s
Pick-up value relative to Un/
Definite operation time.
Set t>, t>>
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 voltage, elapsed delay and setting group.
V59/en M/A009
75
5.9 Zero sequence voltage protection U
0
> (59N)
Parameter
Flt
EDly
SetGrp
5 Protection functions
Table 5.12: Recorded values of the residual overvoltage stages U
0
>, U
0
>>
Value Unit Description
yyyy-mm-dd hh:mm:ss.ms
Time stamp of the recording, date
Time stamp, time of day
%
%
Fault voltage relative to Un/
Elapsed time of the operating time setting. 100% = trip
1, 2, 3, 4 Active setting group during fault
76
V59/en M/A009
5 Protection functions
5.10
5.10 Thermal overload protection T> (49)
Thermal overload protection T> (49)
The thermal overload function protects cables against excessive heating.
Thermal model
The temperature is calculated using rms values of phase currents and a thermal model according IEC 60255-8. The rms values are calculated using harmonic components up to the 15th.
Trip time:
t
=
τ
⋅ ln
I
2
I
2
−
−
I
P
2
a
2
, ȫ unit: second
Alarm:
Trip:
a
=
k
⋅
k
Θ
⋅
I
N
⋅
alarm
(Alarm 60% = 0.6)
a
=
k
⋅
k
Θ
⋅
I
N
Release time:
Trip release:
t
=
τ
⋅
C
τ
⋅ ln
a
2
I
P
2
−
I
2
, ȫ unit: second
a
= 0 .
95 ×
k
×
I
N
Start release:
T =
= ln =
I =
Ip = k = kΘ =
I
N
=
C
τ
=
a
= 0 .
95 ×
k
×
I
N
×
alarm
(Alarm 60% = 0.6)
Operation time
Thermal time constant tau (Setting value)
Natural logarithm function
Measured rms phase current (the max. value of three phase currents)
Preload current,
I
P
=
θ
×
k
×
I
N
(If temperature rise is 120%(θ = 1.2). This parameter is the memory of the algorithm and corresponds to the actual temperature rise.
Overload factor (Maximum continuous current), i.e. service factor.(Setting value)
Ambient temperature factor (Permitted current due to tamb).
The rated current
Relay cooling time constant (Setting value)
V59/en M/A009
77
5.10 Thermal overload protection T> (49)
5 Protection functions
Time constant for cooling situation
If the feeder's fan is stopped, the cooling will be slower than with an active fan. Therefore there is a coefficient C
τ for thermal constant available to be used as cooling time constant, when current is less than 0.3 x I
N
.
Heat capacitance, service factor and ambient temperature
The trip level is determined by the maximum allowed continuous
I current I
MAX corresponding to the 100 % temperature rise Θ
TRIP the heat capacitance of the cable. I
MAX i.e.
depends of the given service factor k and ambient temperature Θ
MAX70
AMB according the following equation.
and settings I
MAX40 and
I
MAX
=
k
⋅
k
Θ
⋅
I
N
The value of ambient temperature compensation factor kΘ depends on the ambient temperature Θ
AMB and settings I
MAX40 and I
MAX70
See Figure 5.19. Ambient temperature is not in use when kΘ = 1.
.
This is true when
• I
MAX40 is 1.0
• Samb is “n/a” (no ambient temperature sensor)
• TAMB is +40 °C.
k
Q
1.2
AmbientTemperatureCompensation
1.0
I
MAX40
0.8
I
MAX70
0.6
10 20 30
40
50 60
70
80
Q
AMB
(°C)
Figure 5.19: Ambient temperature correction of the overload stage T>.
78
V59/en M/A009
5 Protection functions
5.10 Thermal overload protection T> (49)
Example of a behaviour of the thermal model
Figure 5.19 shows an example of the thermal model behaviour. In
this example = 30 minutes, k = 1.06 and kΘ = 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 0.85 x I
N 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 device 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.
V59/en M/A009
Figure 5.20: Example of the thermal model behaviour.
79
5.11 Magnetishing inrush I f2
> (68F2)
5 Protection functions
Parameter
Status
Time
SCntr
TCntr
Force
T
MaxRMS
Imax k>
Alarm tau ctau kTamb
Imax40
Imax70
Tamb
Samb
-
Value
Table 5.13: Parameters of the thermal overload stage T> (49)
Unit Description
Current status of the stage
Blocked
Start
Trip hh:mm:ss
Off
On n/a
ExtAI1 – 16
%
Arms
A xI
N
% min xtau xI
N
%I
N
%I
N
°C
Estimated time to trip
Cumulative start counter
Cumulative trip counter
Force flag for status forcing for test purposes.
This is a common flag for all stages and output relays, too. Automatically reset by a 5-minute timeout.
Calculated temperature rise. Trip limit is 100 %.
Measured current. Highest of the three phases.
k x I
N
. Current corresponding to the 100 % temperature rise.
Allowed overload (service factor)
Alarm level
Thermal time constant
Coefficient for cooling time constant. Default =
1.0
Ambient temperature corrected max. allowed continuous current
Allowed load at Tamb +40 °C. Default = 100 %.
Allowed load at Tamb +70 °C.
Ambient temperature. Editable Samb=n/a. Default
= +40 °C
Sensor for ambient temperature
No sensor in use for Tamb
External Analogue input 1 – 16
Set = An editable parameter (password needed). C = Can be cleared to zero. F = Editable when force flag is on.
For details of setting ranges, see Table 12.23.
Note
-
-
F
F
C
C
Set
F
Set
Set
Set
Set
Set
Set
Set
Set
5.11
Magnetishing inrush I
f2
> (68F2)
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.
V59/en M/A009
80
5 Protection functions
5.11 Magnetishing inrush I f2
> (68F2)
The trip delay of the stages to be blocked must be more than 60 ms to ensure a proper blocking.
2ndHarm
Im1
Im2
Im3
Block
MAX
> t s t r
& t
&
Start
Register event
Trip
&
Register event
Setting
2.Harm
Delay
Enable events
Figure 5.21: Block diagram of the magnetishing inrush stage.
Parameter
If2> t_f2
S_On
S_Off
T_On
T_Off
Value
10 – 100
0.05 – 300.0
Enabled; Disabled
Enabled; Disabled
Enabled; Disabled
Enabled; Disabled
Table 5.14: Setting parameters of magnetishing inrush blocking (68F2)
-
-
-
Unit
% s
-
Default
10
0.05
Enabled
Enabled
Enabled
Enabled
Description
Setting value If2/Ifund
Definite operating time
Start on event
Start off event
Trip on event
Trip off event
For details of setting ranges, see Table 12.29.
Parameter
Table 5.15: Measured and recorded values of magnetishing inrush blocking
(68F2)
Value Unit Description
Measured values IL1H2.
IL2H2.
IL3H2.
Recorded values Flt
EDly
%
%
%
%
%
2. harmonic of IL1, proportional to the fundamental value of
IL1
2. harmonic of IL2
2. harmonic of IL3
The max. fault value
Elapsed time as compared to the set operating time; 100%
= tripping
V59/en M/A009
81
5.12 Transformer over exicitation I f5
> (68F5)
5 Protection functions
5.12
Parameter
If5> t_f5
S_On
S_Off
T_On
T_Off
Table 5.16: Setting parameters of over exicitation blocking (68F5)
Value
10 – 100
0.05 – 300.0
Enabled; Disabled
Enabled; Disabled
Enabled; Disabled
Enabled; Disabled
Transformer over exicitation I
f5
> (68F5)
Overexiting for example a transformer creates odd harmonics. This over exicitation stage can be used detect overexcitation. This stage can also be used to block some other stages.
The ratio between the over exicitation 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 trip delay of the stages to be blocked must be more than 60 ms to ensure a proper blocking.
Unit
% s
-
-
-
-
Default
10
0.05
Enabled
Enabled
Enabled
Enabled
Description
Setting value If5/Ifund
Definite operating time
Start on event
Start off event
Trip on event
Trip off event
For details of setting ranges, see Table 12.30.
Parameter
Measured values IL1H5.
IL2H5.
IL3H5.
Recorded values Flt
EDly
Table 5.17: Measured and recorded values of over exicitation blocking (68F5)
Value Unit
%
%
%
%
%
Description
5. harmonic of IL1, proportional to the fundamental value of IL1
5. harmonic of IL2
5. harmonic of IL3
The max. fault value
Elapsed time as compared to the set operating time;
100% = tripping
82
V59/en M/A009
5 Protection functions
5.13 Circuit breaker failure protection CBFP (50BF)
5.13
Circuit breaker failure protection CBFP
(50BF)
Parameter
Status
SCntr
TCntr
Force
Cbrelay
1
2
-
Value
Blocked
Start
Trip
Off
On
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 device 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
device. See Chapter 8.5 Output matrix
Table 5.18: Parameters of the circuit breaker failure stage CBFP (50BF)
Unit Description
Current status of the stage
Note
s
Cumulative start counter
Cumulative trip counter
Force flag for status forcing for test purposes. This is a common flag for all stages and output relays, too.
Automatically reset by a 5-minute timeout.
The supervised output relay *) .
Relay T1
Relay T2
Definite operation time.
-
F
F
C
C
Set
Set
Set t>
Set = An editable parameter (password needed). C = Can be cleared to zero. F = Editable when force flag is on.
For details of setting ranges, see Table 12.28.
Recorded values of the latest eight faults
There are detailed information available of the eight latest faults:
Time stamp and elapsed delay.
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83
5.13 Circuit breaker failure protection CBFP (50BF)
Parameter
EDly
5 Protection functions
Table 5.19: Recorded values of the circuit breaker failure stage (8 latest faults) CBFP (50BF)
Unit Value
yyyy-mm-dd hh:mm:ss.ms
%
Description
Time stamp of the recording, date
Time stamp, time of day
Elapsed time of the operating time setting. 100% = trip
84
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5 Protection functions
5.14
5.14 Line differential protection LdI> (87L)
Line differential protection LdI> (87L)
VAMP 59 is a differential protection device mainly designed for sub-transmission overhead lines, medium voltage cables and transformers. Two line ends may lie within the protection zone.
Phase segregated protection is based on current (vector) differential.
Combination of both phase and magnitude differential is used to determine operation. The differential element takes a sampled version of the instantaneous current waveform as its local input and compares it with a corresponding current from the remote end. The signal is converted to magnitude and angle information for comparison. The threshold characteristics is biased for CT saturation as presented in
V59/en M/A009
Settings:
I
Pick-Up
= 20 – 50%
Start of slope1 = 0.5 – 1.0 x I
N
Slope1 = 0 – 100%
Start of slope2 = 1.0 – 3.0 x I
N
Slope2 = 50 – 200%
Figure 5.22: Tripping threshold characteristics
Bias current calculation is only used in protection stage LdI>. Bias current describes the average current flow in transformer. Bias and differential currents are calculated individually for each phase.
85
5.14 Line differential protection LdI> (87L)
5 Protection functions
Equation 5.1: Bias current
I b
=
I
RELAY
1
+
I
RELAY
2
2
Equation 5.2: Differential current
I d
=
I
RELAY
1 −
I
RELAY
2
86
Figure 5.23: Setting example
Example 1: Normal situation from relay 1 point of view
Relay1: measured phase current I
L1
= 1000A / 0°
Relay2: measured phase current I
L1
= 300A / -180°
CT scaling of relay1 is 1000A / 5A and nominal current is 1000A.
CT scaling of relay2 is 1000A / 1A and the nominal current is 300A.
Relay2 sends primary current measurement information to relay1.
Relay1 swaps the angle of received current by 180 degrees (relay2 phase current I
L1
= 300A / -180° ⇒ 300A / 0°).
In BIAS-calculation the measured current amplitude is divided by the nominal primary current of both ends (might be different like now).
Relay1: I
PRIMARY MEASURED
/ I
NOMINAL
= 1000A / 1000A = 1
Relay2: I
PRIMARY RECEIVED
/ I
NOMINAL REMOTE
= 300A / 300A = 1
I b
I d
1 + 1
= = 1 ×
I
N
2
= 1 ∠ 0 ° − 1 ∠ 0 ° = 0 ×
I
N
V59/en M/A009
5 Protection functions
5.14 Line differential protection LdI> (87L)
Example 2: Fault situation from relay 1 point of view
Relay1: measured phase current I
L1
= 2400A / -30°
Relay2: measured phase current I
L1
= 2100A / -45°
CT scaling of relay1 is 1000A / 5A and nominal current is 1000A.
CT scaling of relay2 is 1000A / 1A and the nominal current is 300A.
Relay2 sends primary current measurement information to relay1.
Relay1 swaps the angle of received current by 180 degrees (relay2 phase current I
L1
= 2100A / -45° ⇒ 2100A / 135°).
In BIAS-calculation the measured current amplitude is divided by the nominal primary current of both ends (might be different like now).
Relay1: I
PRIMARY MEASURED
/ I
NOMINAL
= 2400A / 1000A = 2.4
Relay2: I
PRIMARY RECEIVED
/ I
NOMINAL REMOTE
= 2100A / 300A = 7
I
I b d
=
=
2 .
4 + 7
= 4 .
7 ×
I
N
2
2 .
4 ∠ − 35 ° − 7 ∠ 135 ° = 9 .
37 ×
I
N
V59/en M/A009
Figure 5.24: Example BIAS and differential calculation
Data communication for differential current measurement is functioned via fibre-optic cables. Single-mode fibre provides communication up till 120 km with external communication modules.
Relay has special setting called “Line distance”. This setting compensates the time delay between the relay caused by the optic fiber. In case that the length of the fibre is 90 km the setting has to be 90km as well.
87
5.14 Line differential protection LdI> (87L)
5 Protection functions
Figure 5.25: CT wiring towards the line
The starting times of the phase currents calculation tasks in two relays are synchronized. Function will block tripping until the synchronization is achieved. The default communication speed is
64000 bps.
Serial remote port of the relay (RS-232) is used by line differential protection. The recommended solution for the communication channel is the supervised fibre optic wiring. With multimode fibre cables and
VSE001-GG fibre optic modems the communication distance can be up to 1 km. When using single mode fibre cables and third party converters the distance can be up to tens of kilometres.
88
Figure 5.26: Enabling line differential communication
Line differential protection has no operation delay. When the difference between phase currents has been greater than the threshold for two task cycles, the device will trip. Typical tripping time in fault situation is 35 ms.
In case of the communication channel failure the line differential protection is inactive.
Line differential trip signal as well as communication channel failure status are available as inputs in the output matrix and blocking matrix of the relay.
V59/en M/A009
5 Protection functions
5.14 Line differential protection LdI> (87L)
Figure 5.27: Communication failure
The communication channel between two line differential protection relays carries also binary signals in both directions: the status of LDP trip signals, and the remote trip command signal which is an output from the output logic matrix of the sending relay. Remote trip signal can be processed as an input in the output matrix and blocking matrix of the receiving relay. Up to 16 binary signals can be sent between the relays. Signals are updated every 10 ms. POC-signals are tied to line differential algorithm which is operating after every half cycle
(50Hz).
V59/en M/A009
Figure 5.28: Up to 16 event stamped binary signals
In VAMP 59 current comparison is based to nominal primary currents of both ends in this unit. In line or cable differential protection “nominal primary” value should be the same the “CT primary” value.
89
5.14 Line differential protection LdI> (87L)
5 Protection functions
When it comes to transformer protection it is normal that nominal current of the transformer differs of the CT nominal which is higher.
To ensure correct differential calculation it is important to know the nominal current of the other end as well.
When there is transformer on the line or the VAMP 59 is used mainly to transformer differential protection, it is possible to select correct connection group and whether the relay is on high voltage (HV) or low voltage side (LV).
90
Figure 5.29: CT – and transformer settings
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 own and remote side.
V59/en M/A009
5 Protection functions
5.14 Line differential protection LdI> (87L)
V59/en M/A009
Yy6
Yyn6
Yd1
YNd1
Yd5
YNd5
Yd7
YNd7
Yd11
YNd11
Dy1
Dyn1
Dy5
Transformator
Connection group
YNy0
YNyn0
Yy0
Yyn0
YNy6
YNyn6
Dyn5
Dy7
Dyn7
Dy11
Dyn11
Table 5.20: Zero current compensation in transformer applications
Yd5
Yd5
Yd7
Yd7
Yy6
Yy6
Yd1
Yd1
Yd11
Yd11
Dy1
Dy1
Dy5
ConnGrp
Yy0
Yy0
Yy0
Yy0
Yy6
Yy6
Dy5
Dy7
Dy7
Dy11
Dy11
OFF
OFF
OFF
ON
OFF
ON
OFF
ON
OFF
ON
OFF
OFF
OFF
Relay setting
Io cmps
ON
ON
OFF
OFF
ON
ON
OFF
OFF
OFF
OFF
OFF
OFF
ON
OFF
OFF
OFF
OFF
OFF
OFF
OFF
OFF
OFF
ON
OFF
I'o cmps
OFF
ON
OFF
ON
OFF
ON
ON
OFF
ON
OFF
ON
For details of setting ranges, see Table 12.17, Table 12.18, Table 12.19.
91
5.14 Line differential protection LdI> (87L)
5 Protection functions
Testing mode
Test mode for commissioning can be enabled from the protection stage also. When protection stage in test mode does not receive currents from the other relay, this way the tests can be carried out without interference from the other relay. In test mode, the relay still sends it’s measurements to the other relay. When test mode is activated, it is shown in the protection stage.
92
Figure 5.30: When VI1 was activated, “Operation mode” changed from normal to test.
The other end relay tripping should be blocked during testing. This can be achieved by sending block signal with POC-messages to the other side and activating blocking for differential protection from that signal.
Figure 5.31: Sending the Block signal
Figure 5.32: Receiving the Block signal in other relay
Figure 5.33: Using the block signal for differential protection blocking
V59/en M/A009
5 Protection functions
5.14 Line differential protection LdI> (87L)
Current transformer supervision
The current transformer supervision feature is used to detect failure of one or more of the phase current inputs to the relay. Failure of a phase CT or an open circuit of the interconnecting wiring can result in incorrect operation of any current operated element. Additionally, interruption in the current circuit causes dangerous CT secondary voltages being generated.
V59/en M/A009
Figure 5.34: Current transformer supervision settings
Differential CTS method uses the ratio between positive and negative sequence currents in both ends of the protected line to determine
CT failure. This algorithm relies on ANSI85 communication and is inbuilt to LdI> stage.
When this ratio is small (zero), one of four conditions is present:
• The system is unloaded – both I2 and I1 are zero
• The system is loaded but balanced – I2 is zero
• The system has three phase fault – I2 is zero
• There is 3-phase CT failure – Unlikely to happen
When the ratio in non-zero one of the two conditions is present:
• The system has an asymmetric fault – both I2 and I1 are non-zero
• There is a 1 or 2 phase CT fault – both I2 and I1 are non-zero
I2 to I1 ratio is calculated in both ends of the protected line. Both relays calculate their own ratio and other end ratio from the own measurements and via ANSI85 received measurements. With this information we can assume:
• If the ratio is non-zero in both ends we have real fault in the network and the CTS should not operate.
• If the ratio is non-zero only in one end there is a change of CT failure and CTS should operate.
A second criteria for CTS is to check whether the differential system is loaded or not. For this purpose the positive sequence current I1 is checked at both ends. If load current is detected only in one end, it is assumed that there is internal fault condition and CTS is prevented from operating, but if load current is detected at both line ends, CTS operation is permitted.
93
5.14 Line differential protection LdI> (87L)
5.14.1
5 Protection functions
There will be three modes of operation: Indication, restrain, block.
In indication mode CTS alarm is raised but no effect on tripping. In restrain mode alarm is raised and differential current settings are raised 100% which is theoretically the maximum amount of differential current what CT failure can produce in normal full load condition. In block mode alarm is raised and differential protection is inhibited to trip.
Differential CTS block mode is not recommended for following two reasons:
• If there is real fault during CT failure differential protection would not protected the line at all.
• Blocking protection could slow down operation time of differential protection due transients in beginning of fault in protected line.
Capacitive charging current
Major charging currents can be expected on cable or hybrid feeders.
The charging current of the cable will increase according the lengt of the circuit. The capacitive charging current leads the feeder load current and therefore is causing differential (phase and magnitude) to the protected feeder. Steady state difference in currents will have an impact on the minimum differential settings that may be used.
Equation 5.3: Capacitive charging current
l =
I
C
= f =
C =
U =
I
C
=
l
2
π
fCU
⋅ 10
− 3
Cable length (km)
Charging current (amperes)
Frequency
Cable capacitance ( µF / km)
Voltage to neutral (kV)
Example: 32km of certain 15kV cable:
I
C
= 32
km
⋅ 2 ⋅ 3 .
14 ⋅ 50
Hz
⋅ 0 .
23
µ
F km
⋅
15
kV
3
⋅ 10
− 3 will cause about 20A of constant charging current. In this case differential stage should be set above 20A.
94
V59/en M/A009
5 Protection functions
5.14 Line differential protection LdI> (87L)
5.14.2
Index
1 – 16
Figure 5.35: Behaviour of constant charging current
NOTE: When cable feeder is energized there will be significant transient
charging current. The frequency of this transient is above basic component and does not effect to the differential calculation.
ANSI 85 communication (POC –signals)
Total of 16 signals can be sent between two VAMP 59 line differential relays via ANSI 85 communication. Basically it means when relay is using 8 of the signals there is still 8 more signals left for the other end. Signal status is updated every 10 ms.
Table 5.21: List of POC –signals between the relays (ANSI 85 communication)
Description Signal Value On event Off event
0 – 1 on – off on – off User selectable name for the signal
(None as a default)
None
DI1 – n
VI1 – 4
VO1 – 6
Logic1 – 20
V59/en M/A009
95
5.14 Line differential protection LdI> (87L)
5 Protection functions
5.14.3
Figure 5.36: Selecting POC – signals
ANSI 85 communication has to be enabled between the relays to transfer POC –signals. This is done by activating “Enable instance
1”. When for example DI1 is selected as a signal it’s value remains
0 as long as DI1 is acticated. Activated signal in index 1 activates the POC1 of the other relay in output matrix. Signal is also visible in logic and other matrixes.
Communication status is “NoProtocol” when ANSI 85 is not selected to remote port in protocol configuration –menu, “Disable” when not activated and “OK” when instance 1 is enabled.
Frequency adaptation
96
Figure 5.37: Frequency adaptation mode has to be set as “Fixed” when line differential protection is used
The frequency adaptation mode should be set as fixed when using the line differential protection stages. Adapted frequency should be set to same as the frequency of the grid.
NOTE: Frequency protection stages cannot be used while frequency
adaptation mode is set as “Fixed”.
V59/en M/A009
5 Protection functions
5.14.4
5.14 Line differential protection LdI> (87L)
Second harmonic blocking
Figure 5.38: Second harmonic blocking can be enabled in the LdI menus
Second harmonic blocking might be needed when there is a transformer inside the protected line. Transformer can cause great magnetizing current to the side of incomer. Big through faults outside the protected zone might cause saturation to the CT and this might cause false tripping as well. Second harmonic blocking can be used to avoid this type of false trips.
V59/en M/A009
97
5.14 Line differential protection LdI> (87L)
5.14.5
Fifth harmonic blocking
5 Protection functions
Figure 5.39: Fifth harmonic blocking can be enabled in the LdI> and LdI>> menus.
Sudden load drop might cause overvoltage situation. Overvoltage causes over-excitation to the transformer. Transformer over-excitation is another possible cause of differential relay undesired operation.
The use of an additional fifth-harmonic restraint can prevent such operations. Transformer over-excitation causes about 20 – 50% of fifth harmonic component to the measured phase currents.
98
Figure 5.40: Harmonic content of transformer exciting current as a function of the applied voltage
5th harmonic blocking limit is set to 35% of the fundamental component as a default. This value can be used in most of the applications.
V59/en M/A009
5 Protection functions
5.15
5.15 Programmable stages (99)
Programmable stages (99)
For special applications the user can built own protection stages by selecting the supervised signal and the comparison mode.
The following parameters are available:
•
Priority
If operation times less than 80 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.
•
Coupling A
The name of the supervised signal in “>” and “<” modes (see table below). Also the name of the supervised signal 1 in “Diff” and “AbsDiff” modes.
•
Coupling B
The name of the supervised signal 2 in “Diff” and “AbsDiff” modes.
•
Compare condition
Compare mode. ‘>’ for over or ‘<’ for under comparison, “Diff” and “AbsDiff” for comparing Coupling A and Coupling B.
•
Pick-up
Limit of the stage. The available setting range and the unit depend on the selected signal.
•
Operation delay
Definite time operation delay
•
Hysteresis
Dead band (hysteresis)
•
No Compare limit for mode <
Only used with compare mode under (‘<’). This is the limit to start the comparison. Signal values under NoCmp are not regarded as fault.
V59/en M/A009
99
5.15 Programmable stages (99)
5 Protection functions
Parameter Value
Enable for Prg”n" Enaled
Disabled
Priority
Table 5.22: Available signals to be supervised by the programmable stages
IL1, IL2, IL3
IL1REM, IL2REM, IL3REM
Io
Uo
I1
I2 f
IoCalc
I2/I1
I2/In
T
IL
THDIL1
THDIL2
THDIL3
IL1RMS
IL2RMS
IL3RMS
ILmin, ILmax
Io1RMS
VAI1, VAI2, VAI3, VAI4, VAI5
Phase currents
Remote end phase currents
Residual current input
Zero sequence voltage
Frequency
Phasor sum I
L1
+ I
L2
+ I
L3
Positive sequence current
Negative sequence current
Relative negative sequence current
Negative sequence current in pu
Thermal status
Average (I
L1
+ I
L2
+ I
L3)
/ 3
Total harmonic distortion of I
L1
Total harmonic distortion of I
L2
Total harmonic distortion of I
L3
IL1 RMS for average sampling
IL2 RMS for average sampling
IL3 RMS for average sampling
Minimum and maximum of phase currents
RMS current of input Io
Virtual analog inputs 1, 2, 3, 4, 5 (GOOSE)
Eight independent stages
The device has eight independent programmable stages. Each programmable stage can be enabled or disabled to fit the intended application.
Setting groups
There are four settings groups available. Switching between setting groups can be controlled by digital inputs, virtual inputs (mimic display, communication, logic) and manually.
There are four identical stages available with independent setting parameters.
See Chapter 5.2 General features of protection stages for more
details.
Table 5.23: Parameters of the programmable stages PrgN (99)
Unit Description
Activation of the programmable stage
Note
Set ms Software task priority of the protected stage Set
100
V59/en M/A009
5 Protection functions
5.15 Programmable stages (99)
Parameter
Status -
Value
Blocked
Start
Trip
1, 2, 3, 4
Unit Description
Current status of the stage
SetGrp
SGrpDI
Force
-
DIx
VIx
LEDx
VOx
Fx
Off
On
Active setting group
Digital signal to select the active setting group
None
Digital input
Virtual input
LED indicator signal
Virtual output
Function key
Force flag for status forcing for test purposes. This is a common flag for all stages and output relays, too. Automatically reset by a 5-minute timeout.
cycletime of the selected protection signal Timebase for input value
Coupling
Value
Cmp
Pickup
Pickup t
Hyster
NoCmp
>
<
Diff
AbsDiff pu s
% pu
Selected protection signal
Current primary value of the selected protection signal
Mode of comparison
Over protection
Under protection
Difference
Absolut difference
Pick up value scaled to primary level
Pick up setting in pu
Definite operation time.
Dead band setting
Minimum value to start under comparison. (Mode='<')
Set = An editable parameter (password needed). C = Can be cleared to zero. F = Editable when force flag is on.
Set
Set
Set
Set
Note
-
-
F
F
Set
Set
Set
Set
Set
Set
Set
Parameter
Flt
EDly
SetGrp
Recorded values of the latest eight faults
There is detailed information available of the eight latest faults: Time stamp, fault value and elapsed delay.
Value
yyyy-mm-dd hh:mm:ss.ms
1, 2, 3, 4
Table 5.24: Recorded values of the programmable stages PrgN (99)
Unit
pu
%
Description
Time stamp of the recording, date
Time stamp, time of day
Fault value
Elapsed time of the operating time setting. 100% = trip
Active setting group during fault
V59/en M/A009
101
5.16 Arc fault protection (optional)
5 Protection functions
5.16
Arc fault protection (optional)
5.16.1
2S+BIO
Delayed light indication signal
Relay output matrix has a delayed light indication output signal
(Delayed Arc L>) available for building selective arc protection systems. Any light source combination and a delay can be configured starting from 0.01 s to 0.15 s. The resulting signal is available in the output matrix to be connected to BO, output relays etc.
Pick up scaling
Parameter
Status
LCntr
SCntr
TCntr
Force Off
On
-
ILmax
Io>
ArcI>
ArcIn
–
S1/S2
S1/BI
S2/BI
S1/S2/BI
Delayed light signal output
Ldly
The per unit (pu) values for pick up setting are based on the current transformer values.
ArcI>: 1 pu = 1 x I
N
= rated phase current CT value
ArcI
0
>: 1 pu = 1 x I
0N
= rated residual current CT value for input I
0
.
-
Value
Table 5.25: Parameters of arc protection stages ArcI>, ArcI
0
>
(50ARC/50NARC)
Unit Description
Current status of the stage
Note
-
Start
Trip
F
F
C
C pu
Light detected according ArcI
N
Light and overcurrent detected
Cumulative light indication counter. S1, S2 or BI.
Cumulative light indication counter for the selected inputs according parameter ArcI
N
Cumulative trip counter
Force flag for status forcing for test purposes. This is a common flag for all stages and output relays, too.
Automatically reset by a 5-minute timeout.
Value of the supervised signal
Stage ArcI>
Stage ArcI
0
>
Pick up setting xI
N
Light indication source selection
No sensor selected
Sensor in terminals 1 and 2
Sensor 1 and BI in use
Sensor 2 and BI in use
Sensor 1, 2 and BI in use
C
Set
Set
Set s Delay for delayed light output signal Set
V59/en M/A009
102
5 Protection functions
5.16 Arc fault protection (optional)
Parameter
LdlyCn
Value
–
S1/S2
S1/BI
S2/BI
S1/S2/BI
Unit Description
Light indication source selection
No sensor selected
Sensor in terminals 1 and 2
Sensor 1 and BI in use
Sensor 2 and BI in use
Sensor 1, 2 and BI in use
Set = An editable parameter (password needed). C = Can be cleared to zero. F = Editable when force flag is on.
For details of setting ranges, see Chapter 12.3.8 Arc fault protection (option).
Note
Set
Parameter
Type
Flt
Load
EDly
Recorded values of the latest eight faults
There is detailed information available of the eight latest faults: Time stamp, fault type, fault value, load current before the fault and elapsed delay.
Table 5.26: Recorded values of the arc protection stages
Value
yyyy-mm-dd hh:mm:ss.ms
Unit
pu pu pu
%
Description
Time stamp of the recording, date
Time stamp, time of day
Fault type value. Only for ArcI> stage.
Fault value
Pre fault current. Only for ArcI> stage.
Elapsed time of the operating time setting. 100% = trip
V59/en M/A009
103
5.16 Arc fault protection (optional)
5.16.2
104
5 Protection functions
3S+BIO
The arc option card is inserted in the upper option card slot in the back of the device. The card is fastened to the relay with two screws.
The optional arc protection card includes three arc sensor channels for light detection and fast overcurrent detection for combined phase currents and Io. The arc sensors are connected to the terminals 6 –
7, 8 9, and 10 – 11.
3
4
1
2
5
6-7
8-9
9-10
The arc information can be transmitted and/or received through digital input and output channels BIO. The output signal is 30 V dc when active. The input signal has to be 12 – 40 V dc to be activated.
Binary output +
Binary output GND
Binary input +
Binary input GND no connection
Arc sensor 1 (VA 1 DA)
Arc sensor 2 (VA 1 DA)
Arc sensor 3 (VA 1 DA)
When devices are connected together using binary channel the ground wires must also be connected.
The option card has two fast arc outputs: the binary output and direct control of relay T1. The behaviour of the arc protection is determined by the 3S+BIO output matrix that is described in more detail later in this chapter.
Binary input
The binary input (BI) on the arc option card can be used to get either light or current indication from another relay to build selective arc protection systems. The BI signal can also be routed to BO or T1 from 3S+BIO output matrix. BI is a dry input for signal from binary outputs of other VAMP relays or dedicated arc protection devices by VAMP.
Binary output
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 3S+BIO output matrix.
BO is an internally wetted 30 Vdc signal for BI of other VAMP relays or dedicated arc protection devices by VAMP.
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5 Protection functions
5.16 Arc fault protection (optional)
Pick up scaling for 3S+BIO arc current
The per unit (pu) values for pick up setting are based on the current transformer values.
ArcI>:
ArcI
0
>:
1 pu = 1xI
N
= rated phase current CT value
1 pu = 1xI
0N
I
0
.
= rated residual current CT value for input
The greyed current values indicate the corresponding actual current values after scaling factors from the “scaling”-menu have been applied.
3S+BIO output matrix
The functionality of the 3S+BIO option card is controlled mostly by
the card’s dedicated output matrix (Figure 5.41). All the connections
made in this matrix are a lot faster than the device’s normal output matrix connections and are handled separately from the relay’s other processes.
V59/en M/A009
Figure 5.41: 3S+BIO output matrix
In the matrix all inputs are on left hand side and can be connected to outputs on top of each column by placing dots to the matrix. It should be noted that “Output latch” isn’t a real input. Instead, a dot in that line indicates that the corresponding output is latched on activation.
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5.16 Arc fault protection (optional)
5 Protection functions
Arc events
There are number of events that can be set to trigger on changes in arc protection signals. For each signal there is separately selectable on and off event. Those events can be enabled or disabled from the
3S+BIO event matrix shown in Figure 5.42.
Figure 5.42: 3S+BIO event enabling
When triggered the event shows up normally in the device’s event buffer along with time stamp.
106
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5.17
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5.17 Inverse time operation
Inverse time operation
The inverse time operation - i.e. inverse definite 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 5.17.1 Standard inverse delays IEC,
• 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
• 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 5.17.3 Programmable inverse time curves.
Local panel graph
The device 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 20 x I
SET
, 4 x I
SET and 2 x I
SET are shown.
107
5.17 Inverse time operation
108
5 Protection functions
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.
2. There are errors in formula parameters A – E, and the device is not able to build the delay curve
3. There are errors in the programmable curve configuration and the device is not able to interpolate values between the given points.
Limitations
The maximum measured secondary phase current is 50 x I
N maximum directly measured earth fault current is 10 x I
0N and the for residual current input. The full scope of inverse delay curves goes up to 20 times the setting. At high setting the maximum measurement capability limits the scope of inverse curves according the following table.
Current input Maximum measured secondary current
I
L1
, I
L2
, I
L3 and I
0Calc
I
0
= 5 A
I
0
= 1 A
I
01
= 0.2 A
I
0
= 0.2 A
250 A
50 A
10 A
2 A
Maximum secondary scaled setting enabling inverse delay times up to full 20x setting
12.5 A
2.5 A
0.5 A
0.1 A
1. Example of limitation
CT = 750 / 5
CT
0
= 100 / 1 (cable CT is used for residual current)
The CT
0 is connected to a 1 A terminals of input I
0
.
For overcurrent stage I> the table above gives 12.5 A. Thus the maximum setting for I> stage giving full inverse delay range is
12.5 A / 5 A = 2.5 xI
N
= 1875 A
Primary
.
For earth fault stage I
0
> the table above gives 0.5 A. Thus the maximum setting for I
0
> stage giving full inverse delay range is
0.5 A / 1 A = 0.5 xI
0N
= 50 A
Primary
.
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5 Protection functions
5.17 Inverse time operation
5.17.1
LTI
LTEI
LTVI
MI
DT
NI
VI
EI
STI
STEI
RI
RXIDG
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 5.17 Inverse time operation 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. Chapter 5.17
Inverse time operation for more details.
Table 5.27: Available standard delay families and the available delay types within each family.
Delay type
DT
X
IEC
Curve family
IEEE IEEE2 RI
Definite time
Normal inverse
Very inverse
Extremely inverse
Long time inverse
Long time extremely inverse
Long time very inverse
Moderately inverse
Short time inverse
Short time extremely inverse
Old ASEA type
Old ASEA type
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
IEC inverse time operation
The operation time depends on the measured value and other
parameters according Equation 5.4. 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.
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5.17 Inverse time operation
5 Protection functions
t
=
Equation 5.4:
NI
EI
VI
LTI
k
I
I
PICKUP
A
B
− 1 t = Operation delay in seconds k = User’s multiplier
I = Measured value
I
PICKUP
= User’s pick up setting
A, B = Constants parameters according Table 5.28.
There are three different delay types according IEC 60255-3, Normal inverse (NI), Extremely inverse (EI), Very inverse (VI) and a VI extension. Additional there is a de facto standard Long time inverse
(LTI).
Delay type
Table 5.28: Constants for IEC inverse delay equation
Parameter
Normal inverse
Extremely inverse
Very inverse
Long time inverse
A
0.14
80
13.5
120
B
0.02
2
1
1
Example for Delay type "Normal inverse (NI)":
k = 0.50
I = 4 pu (constant current)
I
PICKUP
= 2 pu
A = 0.14
B = 0.02
t
=
0 .
50 ⋅ 0 .
14
4
2
0 .
02
− 1
= 5 .
0
The operation time in this example will be 5 seconds. The same
result can be read from Figure 5.43.
110
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5.17 Inverse time operation
Figure 5.43: IEC normal inverse delay.
Figure 5.44: IEC extremely inverse delay.
Figure 5.45: IEC very inverse delay.
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Figure 5.46: IEC long time inverse delay.
111
5.17 Inverse time operation
5 Protection functions
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 5.29. 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 5.5. 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.
t = Operation delay in seconds
Equation 5.5: t
=
k
I
A
I
PICKUP
C
− 1
+
B
LTI
LTVI
LTEI
MI
VI
EI
STI
STEI
I k = User’s multiplier
I = Measured value
PICKUP
= User’s pick up setting
A,B,C = Constant parameter according Table 5.29.
Delay type
Table 5.29: Constants for IEEE/ANSI inverse delay equation
Long time inverse
Long time very inverse
Long time extremely inverse
Moderately inverse
Very inverse
Extremely inverse
Short time inverse
Short time extremely inverse
A
0.086
28.55
64.07
0.0515
19.61
28.2
0.16758
1.281
Parameter
B
0.185
0.712
0.250
0.1140
0.491
0.1217
0.11858
0.005
0.02
2
2
0.02
C
0.02
2
2
2
112
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5.17 Inverse time operation
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
t
= 0 .
50 ⋅
0 .
0515
4
2
0 .
02
− 1
+ 0 .
1140
= 1 .
9
The operation time in this example will be 1.9 seconds. The same
result can be read from Figure 5.50.
Figure 5.47: ANSI/IEEE long time inverse delay Figure 5.48: ANSI/IEEE long time very inverse delay
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5.17 Inverse time operation
5 Protection functions
Figure 5.49: ANSI/IEEE long time extremely inverse delay
Figure 5.50: ANSI/IEEE moderately inverse delay
Figure 5.51: ANSI/IEEE short time inverse delay Figure 5.52: ANSI/IEEE short time extremely inverse delay
114
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5 Protection functions
5.17 Inverse time operation
MI
NI
VI
EI
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 5.6, which in VAMP relays 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 5.30. The old
electromechanical induction disc relays have inverse delay for both trip and release operations. However, in VAMP relays only the trip time is inverse the release time being constant.
The operation delay depends on the measured value and other
parameters according Equation 5.6. 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 5.6: t
=
k
A
+
I
B
I
PICKUP
−
C
D
+
I
I
PICKUP
−
C
2
E
+
I
I
PICKUP
−
C
3
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 5.30.
Delay type
Table 5.30: Constants for IEEE2 inverse delay equation
Parameter
Moderately inverse
Normally inverse
Very inverse
Extremely inverse
A
0.1735
0.0274
0.0615
0.0399
B
0.6791
2.2614
0.7989
0.2294
C
0.8
0.3
0.34
0.5
D
-0.08
-0.1899
-0.284
3.0094
E
0.1271
9.1272
4.0505
0.7222
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5.17 Inverse time operation
5 Protection functions
Example for Delay type "Moderately inverse (MI)":
k = 0.50
I = 4 pu
I
PICKUP
= 2 pu
A = 0.1735
B = 0.6791
C = 0.8
D = -0.08
E = 0.127
t
= 0 .
5 ⋅
0
.
1735 +
0 .
6791
4
2
− 0 .
8
+
4
2
− 0 .
08
− 0 .
8
2
+
4
2
0 .
−
127
0 .
8
3
= 0 .
38
The operation time in this example will be 0.38 seconds. The same
result can be read from Figure 5.53.
Figure 5.53: IEEE2 moderately inverse delay Figure 5.54: IEEE2 normal inverse delay
116
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5.17 Inverse time operation
Figure 5.55: IEEE2 very inverse delay
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Figure 5.56: IEEE2 extremely inverse delay
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 5.7 and
Equation 5.8. 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 5.7: RI Equation 5.8: RXIDG t
RI
=
k
0 .
339 −
0 .
236
I
I
PICKUP
t = Operation delay in seconds k = User’s multiplier
I = Measured value
I
PICKUP
= User’s pick up setting
t
RXIDG
I
= 5 .
8 − 1 .
35 ln
k I
PICKUP
117
5.17 Inverse time operation
5 Protection functions
Example for Delay type RI
k = 0.50
I = 4 pu
I
PICKUP
= 2 pu
t
RI
=
0 .
339
0 .
5
−
0 .
236
4
2
= 2 .
3
The operation time in this example will be 2.3 seconds. The same
result can be read from Figure 5.57.
Example for Delay type RXIDG
k = 0.50
I = 4 pu
I
PICKUP
= 2 pu
t
RXIDG
4
=
5 .
8
−
1 .
35 ln
0 .
5
⋅
2
=
3 .
9
The operation time in this example will be 3.9 seconds. The same
result can be read from Figure 5.58.
Figure 5.57: Inverse delay of type RI.
118
Figure 5.58: Inverse delay of type RXIDG.
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5 Protection functions
5.17.2
5.17.3
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5.17 Inverse time operation
Free parameterization 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
PICKUP
= 2 pu
A = 0.2078
B = 0.8630
C = 0.8000
D = - 0.4180
E = 0.1947
t
= 0 .
5 ⋅
0 .
2078 +
0 .
8630
4
2
− 0 .
8
+
−
4
2
0 .
4180
− 0 .
8
2
+
4
2
0 .
1947
− 0 .
8
3
= 0 .
37
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 5.17 Inverse time operation 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 5.17
Inverse time operation for more details.
Programmable inverse time curves
Only with VAMPSET, requires rebooting.
119
5.17 Inverse time operation
5 Protection functions
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 line
• line 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 lines (on the bottom) should be filled with [1.00 0.00s]
12
13
14
15
16
10
11
8
9
6
7
4
5
Point
1
2
3
Here is an example configuration of curve points:
Current I/I
PICKUP
1.00
2.00
5.00
10.00
20.00
40.00
1.00
1.00
1.00
1.00
1.00
1.00
1.00
1.00
1.00
1.00
Operation delay
10.00 s
6.50 s
4.00 s
3.00 s
2.00 s
1.00 s
0.00 s
0.00 s
0.00 s
0.00 s
0.00 s
0.00 s
0.00 s
0.00 s
0.00 s
0.00 s
Inverse time setting error signal
The inverse time setting error signal will be activated, if interpolation
with the given points fails. See Chapter 5.17 Inverse time operation
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 5.17
Inverse time operation for more details.
120
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6 Supporting functions
6
6.1
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Supporting functions
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.
As an example of information included with a typical event a programmable stage trip event is shown in the following table.
EVENT Description Local panel
Code: 01E02
I> trip on
2.7 x In
2007-01-31
08:35:13.413
Type: 1-N, 2-N, 3-N
Channel 1, event 2
Event text
Fault value
Date
Time
Fault type
Yes
Yes
Yes
Yes
Yes
Yes
Communication protocols
Yes
No
No
Yes
Yes
No
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 VAMPSET 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 interruptions, the latest event can be reread any number of times using another 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.
All events are stored in non-volatile memory.
Indication screen (popup screen) can also be enabled in this same menu when VAMPSET –setting tool is used. The oldest one 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 5ms, 10 ms or 20 ms resolution.
The absolute accuracy of all time stamps depends on the time
121
6.1 Event log
6 Supporting functions
Event buffer overflow
Parameter
Count
ClrEn
Value
The normal procedure is to poll events from the device all the time.
If this is not done then the event buffer could reach its limits. In such case the oldest event is deleted and the newest displayed with OVF code in HMI.
Table 6.1: Setting parameters for events
-
Description
Number of events
Clear event buffer
Note
Set
Order
Clear
Old-New
New-Old
Order of the event buffer for local display Set
FVSca
Display
PU
Pri
On
Scaling of event fault value
Per unit scaling
Primary scaling
Indication dispaly is enabled
No indication display
Set
Set
Alarms
FORMAT OF EVENTS ON THE LOCAL DISPLAY
Code: CHENN
Event description yyyy-mm-dd hh:mm:ss.nnn
Off
CH = event channel, NN=event code
Event channel and code in plain text
Date
(for available date formats, see Chapter 6.6 System clock and synchronization)
Time
122
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6 Supporting functions
6.2
6.2 Disturbance recorder
Disturbance recorder
The disturbance recorder can be used to record all the measured signals, that is, currents, voltage and the status information of digital inputs (DI) and digital outputs (DO).
The disturbance recorder can be used to record all the measured signals, that is, currents, and the status information of digital inputs
(DI) and digital outputs (DO).
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 also means that 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 12 (limited in wave form) and 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.
Channel
IL1, IL2, IL3
Io1, Io2
U12
U23
U31
V59/en M/A009
Table 6.2: Disturbance recorder waveform
Description
Phase current
Measured residual current
Line-to-line voltage
Line-to-line voltage
Line-to-line voltage
1LN
Yes
Yes
-
-
-
Available for waveform
Voltage measurement mode
1LL
Yes
Yes
Yes
(*
-
-
U
0
Yes
Yes
-
-
-
123
6.2 Disturbance recorder
Channel
THDIL1
THDIL2
THDIL3
THDUa
THDUb
THDUc
DI_2
Prms
Qrms
Srms
IL1RMS
IL2RMS
IL3RMS
IL1Rem
IL2Rem
IL3Rem
I1
I2
I2/I1
I2/Imode
U1
U2
U2/U1
IL
Uphase
Uline
DO
DI
TanFii
UL1
UL2
UL3
Uo f
P, Q, S
P.F.
CosFii
IoCalc
124
Description
Phase-to-neutral voltage
Phase-to-neutral voltage
Phase-to-neutral voltage
Zero sequence voltage
Frequency
Active, reactive, apparent power
Power factor cosφ
Phasor sum Io = (IL1+IL2+IL3)/3
Positive sequence current
Negative sequence current
Relative current unbalance
Current unbalance [xImode]
Positive sequence voltage
Negative sequence voltage
Relative voltage unbalance
Average (IL1 + IL2 + IL3)/3
Average (UL1 + UL2 + UL3) / 3
Average (U12 + U23 + U31) / 3
Digital outputs
Digital inputs tanφ
Total harmonic distortion of I
L1
Total harmonic distortion of I
L2
Total harmonic distortion of I
L3
Total harmonic distortion of Ua
Total harmonic distortion of Ub
Total harmonic distortion of Uc
Digital inputs 21 – 32
Active power rms value
Reactive power rms value
Apparent power rms value
IL1 RMS for average sampling
IL2 RMS for average sampling
IL3 RMS for average sampling
IL1 Remote current
IL2 Remote current
IL3 Remote current
6 Supporting functions
-
-
-
-
1LN
Yes
(*
-
-
-
-
Available for waveform
Voltage measurement mode
1LL
-
-
-
-
-
-
-
-
-
Yes
-
-
-
-
-
-
-
U
0
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Yes
Yes
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Yes
Yes
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Yes
Yes
-
-
-
V59/en M/A009
6 Supporting functions
6.2 Disturbance recorder
Table 6.3: Disturbance recorder parameters
Parameter
Mode
SR
Time
PreTrig
MaxLen
Value
Saturated
Overflow
32/cycle
16/cycle
8/cycle
1/10ms
1/20ms
1/200ms
1/1s
1/5s
1/10s
1/15s
1/30s
1/1min
Unit
s
% s
Description
Behavior in memory full situation:
No more recordings are accepted
The oldest recorder will be overwritten
Sample rate
Waveform
Waveform
Waveform
One cycle value *)
One cycle value
**)
Average
Average
Average
Average
Average
Average
Average
Recording length
Amount of recording data before the trig moment
Maximum time setting.
Status
ManTrig
ReadyRec
-
Run
Trig
FULL
-, Trig n/m
This value depends on sample rate, number and type of the selected channels and the configured recording length.
Status of recording
Not active
Waiting a triggering
Recording
Memory is full in saturated mode
Manual triggering 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.
Note
Set
Set
Set
Set
Set
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6.2 Disturbance recorder
6 Supporting functions
Parameter
AddCh
Value
IL1, IL2, IL3
Io
U12, U23, U31
UL1, UL2, UL3 f
Uo
CosFii
IoCalc
I1
I2
I2/I1
I2/In
IL
DI, DO
TanFii
THDIL1, THDIL2,
THDIL3
IL1RMS, IL2MRS,
IL3RMS
IL1Rem, IL2Rem,
IL3Rem
Starts
Trips
Delete recorder channel
ClrCh
(Ch)
-, Clear
Unit Description
Add one channel. Maximum simultaneous number of channels is 12.
Phase current
Measured residual current
Line-to-line voltage
Phase-to-neutral voltage
Zero sequence voltage
Frequency cosφ
Phasor sum Io = (IL1+IL2+IL3)/3
Positive sequence current
Negative sequence current
Relative current unbalance
Current unbalance [x I
N
]
Average (IL1 + IL2 + IL3) / 3
Digital inputs, Digital outputs tanφ
Total harmonic distortion of IL1, IL2 or IL3
IL1, IL2, IL3 RMS for average sampling
Remote currents
Protection stage start signals
Protection stage trip signals
Delete selected channel
Remove all channels
List of selected channels
Set = An editable parameter (password needed).
*) This is the fundamental frequency rms value of one cycle updated every 10 ms.
**) This is the fundamental frequency rms value of one cycle updated every 20 ms.
For details of setting ranges, see Table 12.34.
Note
Set
Set
6.2.1
Running virtual comtrade files
Virtual comtrade files can be run with VAMP relays with the v.10.74
software or a later version. Relay behaviour can be analysed by playing the recorder data over and over again in the relay memory.
126
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6 Supporting functions
6.2 Disturbance recorder
Steps of opening the VAMPSET setting tool:
1. Go to “Disturbance record” and select Open… (A).
2. Select the comtrade file from you hard disc or equivalent.
VAMPSET is now ready to read the recording.
3. The virtual measurement has to be enabled (B) in order to send record data to the relay (C).
4. Sending the file to the device’s memory takes a few seconds.
Initiate playback of the file by pressing the Go! button (D). The
“Change to control mode” button takes you back to the virtual measurement.
V59/en M/A009
NOTE: The sample rate of the comtrade file has to be 32/cycle (625 micro
seconds when 50 Hz is used). The channel names have to correspond to the channel names in VAMP relays: I
L1
, I
L2
, I
L3
, I
0
,
U
12
, U
23
, U
L1
, U
L2
, U
L3 and U
0
.
127
6.3 Cold load pick-up and inrush current detection
6.3
Cold load pick-up and inrush current detection
Cold load pick-up
A situation is regarded as cold load when all the three phase currents have been less than a given idle value and then at least one of the currents exceeds a given pick-up level within 80 ms. In such case the cold load detection signal is activated for a given time. This signal is available for output matrix and blocking matrix. Using virtual outputs of the output matrix setting group control is possible.
Application for cold load detection
Right after closing a circuit breaker a given amount of overload can be allowed for a given limited time to take care of concurrent thermostat controlled loads. Cold load pick-up function does this for example by selecting a more coarse setting group for over-current stage(s). It is also possible to use the cold load detection signal to block any set of protection stages for a given time.
Inrush current detection
Inrush current detection is quite similar with the cold load detection but it does also include a condition for second harmonic relative content of the currents. When all phase currents have been less than a given idle value and then at least one of them exceeds a given pick-up level within 80 ms and the ratio 2nd harmonic ratio to fundamental frequency, I f2
/I f1
, of at least one phase exceeds the given setting, the inrush detection signal is activated. This signal is available for output matrix and blocking matrix. Using virtual outputs of the output matrix setting group control is possible.
By setting the 2nd harmonic pickup parameter for I f2
/I f1 to zero, the inrush signal will behave equally with the cold load pick-up signal.
Application for inrush current detection
The inrush current of transformers usually exceeds the pick-up setting of sensitive overcurrent stages and contains a lot of even harmonics.
Right after closing a circuit breaker the pick-up and tripping of sensitive overcurrent stages can be avoided by selecting a more coarse setting group for the appropriate over-current stage with inrush detect signal. It is also possible to use the detection signal to block any set of protection stages for a given time.
NOTE: Inrush detection is based on FFT - calculation which recuires full
cycle of data for analyzing the harmonic content. Therefore when using inrush blocking function the cold load pick up starting conditions are used for activating the inrush blocking when the current rise is noticed. If in the signal is found a significant ratio of second harmonic
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6 Supporting functions
6 Supporting functions
6.3 Cold load pick-up and inrush current detection
component after 1st cycle the blocking is continued, otherwise 2nd harmonic based blocking signal is released. Inrush blocking is recommended to be used into time delayed overcurrent stages while non blocked instant overcurrent stage is set to 20 % higher than expected inrush current. By this scheme fast reaction time in short circuit faults during the energization can be achieved while time delayed stages are blocked by inrush function.
1
3
4
Pick-up
2
Idle
Cold load
1. No activation because the current has not been under the set
I
DLE current.
2. Current dropped under the I
DLE between the I
DLE current level but now it stays current and the pick-up current for over 80ms.
3. No activation because the phase two lasted longer than 80ms.
4. Now we have a cold load activation which lasts as long as the operation time was set or as long as the current stays above the pick-up setting.
Figure 6.1: Functionality of cold load / inrush current feature.
Parameter
ColdLd
Inrush
ILmax
Pickup
Idle
MaxTime
Idle
Pickup
Pickupf2
-
Value
Start
-
Trip
Start
Trip
80
Table 6.4: Parameters of the cold load & inrush detection function
Unit Description
Status of cold load detection:
Note
xImode xImode ms
%
A s
A
A
Cold load situation is active
Timeout
Status of inrush detection:
Inrush is detected
Timeout
The supervised value. Max. of IL1, IL2 and IL3
Primary scaled pick-up value
Primary scaled upper limit for idle current
Current limit setting for idle situation
Pick-up setting for minimum start current
Maximum transition time for start recognition
Pick-up value for relative amount of 2nd harmonic, I f2
/I f1
Set
Set
Set
Set
Set = An editable parameter (password needed).
For details of setting ranges, see Table 12.35.
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6.4 Current transformer supervision
6 Supporting functions
6.4
Current transformer supervision
Parameter
Imax>
Imin< t>
CT on
CT off
Measured value
Display
Recorded values
The relay supervise the external wiring between the relay terminals and current transformers (CT) and the CT themselves. Furthermore, this is a safety function as well, since an open secondary of a CT, causes dangerous voltages.
The CT supervisor function measures phase currents. If one of the three phase currents drops below I
MIN
< setting, while another phase current is exceeding the I
MAX
> setting, the function will issue an alarm after the operation delay has elapsed.
Table 6.5: Setting parameters of CT supervisor CTSV
Value
0.0 – 10.0
0.0 – 10.0
0.02 – 600.0
On; Off
On; Off
Unit
xIn xIn s
-
-
Default
2.0
0.2
0.10
On
On
Description
Upper setting for CT supervisor current scaled to primary value, calculated by relay
Lower setting for CT supervisor current scaled to primary value, calculated by relay
Operation delay
CT supervisor on event
CT supervisor off event
Table 6.6: Measured and recorded values of CT supervisor CTSV
Parameter Value Unit Description
ILmax
ILmin
Imax>, Imin<
Date
Time
Imax
Imin
-
A
A
A
-
A
A
Maximum of phase currents
Minimum of phase currents
Setting values as primary values
Date of CT supervision alarm
Time of CT supervision alarm
Maximum phase current
Minimum phase current
For details of setting ranges, see Table 12.36.
6.5
Circuit breaker condition monitoring
The relay has a condition monitoring function that supervises the wearing of the circuit-breaker. The condition monitoring can give alarm for the need of CB maintenance well before the CB condition is critical.
The CB wear function measures the breaking current of each CB pole separately and then estimates the wearing of the CB accordingly the permissible cycle diagram. The breaking current is registered when the trip relay supervised by the circuit breaker failure protection
"CBrelay".)
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6 Supporting functions
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6.5 Circuit breaker condition monitoring
Breaker curve and its approximation
The permissible cycle diagram is usually available in the
documentation of the CB manufacturer (Figure 6.2). The diagram
specifies the permissible number of cycles for every level of the breaking current. This diagram is parameterised to the condition monitoring function with maximum eight [current, cycles] points. See
Table 6.7. If less than eight points needed, the unused points are
set to [I
BIG capacity.
, 1], where I
BIG is more than the maximum breaking
If the CB wearing characteristics or part of it is a straight line on a log/log graph, the two end points are enough to define that part of the characteristics. This is because the relay is using logarithmic interpolation for any current values falling in between the given current points 2 – 8.
The points 4 – 8 are not needed for the CB in Figure 6.2. Thus they
are set to 100 kA and one operation in the table to be discarded by the algorithm.
100000
10000
1000
100
50
20
10
100 200 500 1000 10000
Breaked current (A)
100000
CBWEARcharacteristics
Figure 6.2: An example of a circuit breaker wearing characteristic graph.
5
6
7
3
4
1
2
8
Table 6.7: An example of circuit breaker wearing characteristics in a table format. The values are taken from the figure above. The table is edited with
VAMPSET under menu "BREAKER CURVE".
Point Interrupted current Number of permitted
100
100
100
100
(kA)
0 (mechanical age)
1.25 (rated current)
31.0 (maximum breaking current)
100
1
1
1
10000
10000
80
1
1
operations
131
6.5 Circuit breaker condition monitoring
132
6 Supporting functions
Setting alarm points
There are two alarm points available having two setting parameters each.
• Current
The first alarm can be set for example to nominal current of the
CB or any application typical current. The second alarm can be set for example according a typical fault current.
• Operations left alarm limit
An alarm is activated when there are less operation left at the given current level than this limit.
Any actual interrupted current will be logarithmically weighted for the two given alarm current levels and the number of operations left at the alarm points is decreased accordingly. When the "operations left" i.e. the number of remaining operations, goes under the given alarm limit, an alarm signal is issued to the output matrix. Also an event is generated depending on the event enabling.
Clearing "operations left" counters
After the breaker curve table is filled and the alarm currents are defined, the wearing function can be initialised by clearing the decreasing operation counters with parameter "Clear" (Clear oper.
left cntrs). After clearing the relay will show the maximum allowed operations for the defined alarm current levels.
Operation counters to monitor the wearing
The operations left can be read from the counters "Al1Ln" (Alarm 1) and "Al2Ln" (Alarm2). There are three values for both alarms, one for each phase. The smallest of three is supervised by the two alarm functions.
Logarithmic interpolation
The permitted number of operations for currents in between the defined points are logarithmically interpolated using equation
Equation 6.1:
C =
a
I n
C = permitted operations
I = interrupted current
a = constant according Equation 6.2
n = constant according Equation 6.3
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6 Supporting functions
V59/en M/A009
6.5 Circuit breaker condition monitoring
Equation 6.2: Equation 6.3: n
= ln
C k
C k
+
1 ln
I k
+
1
I k
ln =
C k
, C k+1
=
I k
, I k+1
=
a =
C k
I k
2 natural logarithm function
permitted operations. k = row 2 – 7 in Table 6.7.
corresponding current. k = row 2 – 7 in Table 6.7.
Example of the logarithmic interpolation
Alarm 2 current is set to 6 kA. What is the maximum number of
operations according Table 6.7.
The current 6 kA lies between points 2 and 3 in the table. That gives value for the index k. Using k = 2
C k
= 10000
C k+1
= 80
I k+1
= 31 kA
I k
= 1.25 kA
and the Equation 6.2 and Equation 6.3, the relay calculates
ln
10000
80
n
= ln
31000
1250
=
1 .
5038
a
= 10000 ⋅ 1250
1 .
5038
= 454 ⋅ 10
6
Using Equation 6.1 the relay gets the number of permitted operations
for current 6 kA.
C
=
454 ⋅ 10
6
6000
1 .
5038
= 945
Thus the maximum number of current breaking at 6 kA is 945. This
can be verified with the original breaker curve in Figure 6.2. Indeed,
the figure shows that at 6 kA the operation count is between 900 and 1000. A useful alarm level for operation-left, could be in this case for example 50 being about five per cent of the maximum.
133
6.5 Circuit breaker condition monitoring
6 Supporting functions
Example of operation counter decrementing when the CB is breaking a current
Alarm2 is set to 6 kA. CBFP is supervising trip relay T1 and trip signal of an overcurrent stage detecting a two phase fault is connected to this trip relay T1. The interrupted phase currents are 12.5 kA, 12.5
kA and 1.5 kA. How many are Alarm2 counters decremented?
Using Equation 6.1 and values n and a from the previous example,
the relay gets the number of permitted operation at 10 kA.
C
10
kA
=
454 ⋅ 10
6
12500
1 .
5038
= 313
At alarm level 2, 6 kA, the corresponding number of operations is calculated according
Equation 6.4:
∆ =
C
AlarmMax
C
∆
L
1
= ∆
L
2
=
945
313
= 3
Thus Alarm2 counters for phases L1 and L2 are decremented by 3.
In phase L1 the currents is less than the alarm limit current 6 kA. For such currents the decrement is one.
Δ
L3
= 1
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6 Supporting functions
6.5 Circuit breaker condition monitoring
-
Parameter
CBWEAR STATUS
Al1L1
Al1L2
Al1L3
Al2L1
Al2L2
Al2L3
Latest trip
Date time
IL1
IL2
IL3
CBWEAR SET
Alarm1
Current
Cycles
Alarm2
Current
Cycles
CBWEAR SET2
Al1On
Al1Off
Al2On
Al2Off
Clear
Table 6.8: Local panel parameters of CBWEAR function
Value
0.00 – 100.00
100000 – 1
0.00 – 100.00
100000 – 1
On ; Off
On ; Off
On ; Off
On ; Off
-; Clear
Set = An editable parameter (password needed).
The breaker curve table is edited with VAMPSET.
Unit
A
A
A kA kA
Description
Operations left for
- Alarm 1, phase L1
- Alarm 1, phase L2
- Alarm 1, phase L3
- Alarm 2, phase L1
- Alarm 2, phase L2
- Alarm 2, phase L3
Time stamp of the latest trip operation
Broken current of phase L1
Broken current of phase L2
Broken current of phase L3
Alarm1 current level
Alarm1 limit for operations left
Alarm2 current level
Alarm2 limit for operations left
'Alarm1 on' event enabling
'Alarm1 off' event enabling
'Alarm2 on' event enabling
'Alarm2 off' event enabling
Clearing of cycle counters
Set
Set
Set
Set
Set
Set
Set
Set
Set
Set
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6.6 System clock and synchronization
6.6
6 Supporting functions
System clock and synchronization
The internal clock of the relay is used to time stamp events and disturbance recordings.
The system clock should be externally synchronised to get comparable event time stamps for all the relays in the system.
The synchronizing is based on the difference of the internal time and the synchronising message or pulse. This deviation is filtered and the internal time is corrected softly towards a zero deviation.
Time zone offsets
Time zone offset (or bias) can be provided to adjust the local time for IED. The Offset can be set as a Positive (+) or Negative (-) value within a range of -15.00 to +15.00 hours and a resolution of 0.01/h.
Basically quarter hour resolution is enough.
Daylight saving time (DST)
IED provides automatic daylight saving adjustments when configured.
A daylight savings time (summer time) adjustment can be configured separately and in addition to a time zone offset.
136
Daylight time standards vary widely throughout the world. Traditional daylight/summer time is configured as one (1) hour positive bias.
The new US/Canada DST standard, adopted in the spring of 2007 is: one (1) hour positive bias, starting at 2:00am on the second
Sunday in March, and ending at 2:00am on the first Sunday in
November. In the European Union, daylight change times are defined relative to the UTC time of day instead of local time of day (as in
U.S.) European customers, please carefully find out local country rules for DST.
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6 Supporting functions
6.6 System clock and synchronization
The daylight saving rules for Finland are the IED defaults (24-hour clock):
- Daylight saving time start: Last Sunday of March at 03.00
- Daylight saving time end: Last Sunday of October at 04.00
V59/en M/A009
To ensure proper hands-free year-around operation, automatic daylight time adjustments must be configured using the “Enable
DST” and not with the time zone offset option.
Adapting auto adjust
During tens of hours of synchronizing the device will learn its average deviation and starts to make small corrections by itself. The target is that when the next synchronizing message is received, the deviation is already near zero. Parameters "AAIntv" and "AvDrft" will show the adapted correction time interval of this ±1 ms auto-adjust function.
Time drift correction without external sync
If any external synchronizing source is not available and the system clock has a known steady drift, it is possible to roughly correct the clock deviation by editing the parameters "AAIntv" and "AvDrft". The following equation can be used if the previous "AAIntv" value has been zero.
AAIntv
=
604 .
8
DriftInOne Week
If the auto-adjust interval "AAIntv" has not been zero, but further trimming is still needed, the following equation can be used to calculate a new auto-adjust interval.
AAIntv
NEW
=
1
AAIntv
PREVIOUS
1
+
DriftInOne Week
604 .
8
The term DriftInOneWeek/604.8 may be replaced with the relative drift multiplied by 1000, if some other period than one week has been
137
6.6 System clock and synchronization
6 Supporting functions used. For example if the drift has been 37 seconds in 14 days, the relative drift is 37*1000/(14*24*3600) = 0.0306 ms/s.
Example 1
If there has been no external sync and the relay's clock is leading sixty-one seconds a week and the parameter AAIntv has been zero, the parameters are set as
AvDrft
=
Lead
AAIntv
=
604 .
8
61
=
9 .
9
s
With these parameter values the system clock corrects itself with –1 ms every 9.9 seconds which equals –61.091 s/week.
Example 2
If there is no external sync and the relay's clock has been lagging five seconds in nine days and the AAIntv has been 9.9 s, leading, then the parameters are set as
AAIntv
NEW
=
1
9 .
9
−
1
5000
9 ⋅ 24 ⋅ 3600
= 10 .
6
AvDrft
=
Lead
When the internal time is roughly correct – deviation is less than four seconds – any synchronizing or auto-adjust will never turn the clock backwards. Instead, in case the clock is leading, it is softly slowed down to maintain causality.
138
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6 Supporting functions
6.6 System clock and synchronization
Parameter
Date
Time
Style
SyncDI
TZone
DST
SySrc
MsgCnt
Dev
SyOS
Internal
DI
SNTP
SpaBus
ModBus
ModBus TCP
ProfibusDP
IEC101
IEC103
DNP3
IRIG-B003
0 – 65535,
Value
y-d-m d.m.y
m/d/y
DI1, DI2
-15.00 – +15.00
*)
Table 6.9: System clock parameters
Unit Description
Current date
Current time
Date format
Year-Month-Day
Day.Month.Year
Month/Day/Year
DI not used for synchronizing
Minute pulse input
UTC time zone for SNTP synchronization.
No; Yes
Note: This is a decimal number. For example for state of Nepal the time zone 5:45 is given as 5.75
Daylight saving time for SNTP
Clock synchronisation source
No sync recognized since 200s
Digital input
Protocol sync
Protocol sync
Protocol sync
Protocol sync
Protocol sync
Protocol sync
Protocol sync
Protocol sync
IRIG timecode B003
****)
The number of received synchronisation messages or pulses
0 – etc.
±32767 ms
±10000.000
±1000
Lead; Lag
±125 s s ms
Latest time deviation between the system clock and the received synchronization
Synchronisation correction for any constant deviation in the synchronizing source
Adapted auto adjust interval for 1 ms correction
Adapted average clock drift sign
Filtered synchronisation deviation
Note
Set
Set
Set
***)
Set
Set
Set
AAIntv
AvDrft
FilDev
Set
Set
**)
**)
Set = An editable parameter (password needed).
*) A range of -11 h – +12 h would cover the whole Earth but because the International Date Line does not follow the 180° meridian, a more wide range is needed.
**) If external synchronization is used this parameter will be set automatically.
***) Set the DI delay to its minimum and the polarity such that the leading edge is the synchronizing edge.
****) Relay needs to be equipped with suitable hardware option module to receive IRIG-B clock synchronization signal.
(Chapter 14 Order information).
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139
6.6 System clock and synchronization
6 Supporting functions
Synchronisation with DI
Clock can be synchronized by reading minute pulses from digital inputs, virtual inputs or virtual outputs. Sync source is selected with
SyncDI setting. When rising edge is detected from the selected input,
system clock is adjusted to the nearest minute. Length of digital input pulse should be at least 50 ms. Delay of the selected digital input should be set to zero.
Synchronisation correction
If the sync source has a known offset delay, it can be compensated with SyOS setting. This is useful for compensating hardware delays or transfer delays of communication protocols. A positive value will compensate a lagging external sync and communication delays. A negative value will compensate any leading offset of the external synch source.
Sync source
When the device receives new sync message, the sync source display is updated. If no new sync messages are received within next 1.5 minutes, the device will change to internal sync mode.
Sync source: IRIG-B003
IRIG-B003 synchronization is supported with a dedicated communication option with either a two-pole or two pins in a D9 rear
connector (See Chapter 14 Order information).
IRIG-B003 input clock signal voltage level is TLL. The input clock signal originated in the GPS receiver must be taken to multiple relays trough an IRIG-B distribution module. This module acts as a centralized unit for a point-to-multiple point connection. Note: Daisy chain connection of IRIG-B signal inputs in multiple relays must be avoided.
140
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6 Supporting functions
6.6 System clock and synchronization
Antenna
GPS-Clock
IRIG-B signal from clock
IRIG-B
Distribution
Module
VAMP 321 Arc flash protection system z
VAMP 50 VAMP 300 VAMP 200
VAMP relay series with IRIG-B synchronization capability
Recommended wiring: shieled cable of twisted-pair or coaxial type with a maximum length of 10 meters.
The recommended cable must be shielded and either of coaxial or twisted pair type. Its length should not exceed a maximum of 10 meters.
Deviation
The time deviation means how much system clock time differs from sync source time. Time deviation is calculated after receiving new sync message. The filtered deviation means how much the system clock was really adjusted. Filtering takes care of small deviation in sync messages.
Auto-lag/lead
The device synchronizes to the sync source, meaning it starts automatically leading or lagging to stay in perfect sync with the master. The learning process takes few days.
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141
6.7 Running hour counter
6 Supporting functions
6.7
Running hour counter
Parameter
Runh
Runs
Starts
Status
DI
0 – 3599
0 – 65535
Stop
-
Run
-
DI1 – DIn,
VI1 – VIn,
LedA,
LedB,
LedC,
LedD,
LedE,
LedF,
LedG,
LedDR,
VO1 – VO6
This function calculates the total active time of the selected digital input, virtual I/O or output matrix output signal. The resolution is ten seconds.
Table 6.10: Running hour counter parameters
Value
0 – 876000
Unit
h
Description
Total active time, hours
Note
(Set) s
Note: The label text "Runh" can be edited with
VAMPSET.
Total active time, seconds
Activation counter
Current status of the selected digital signal
(Set)
(Set)
Started at
Stopped at
Set = An editable parameter (password needed).
(Set) = An informative value which can be edited as well.
Select the supervised signal
None
Physical inputs
Virtual inputs
Output matrix out signal LA
Output matrix out signal LB
Output matrix out signal LC
Output matrix out signal LD
Output matrix out signal LE
Output matrix out signal LF
Output matrix out signal LG
Output matrix out signal DR
Virtual outputs
Date and time of the last activation
Date and time of the last inactivation
Set
142
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6 Supporting functions
6.8
6.8 Timers
Timers
The VAMP protection platform includes four settable timers that can be used together with the user's programmable logic or to control setting groups and other applications that require actions based on calendar time. Each timer has its own settings. The selected on-time and off-time is set and then the activation of the timer can be set to be as daily or according the day of week (See the setting parameters for details). The timer outputs are available for logic functions and for the block and output matrix.
V59/en M/A009
Figure 6.3: Timer output sequence in different modes.
The user can force any timer, which is in use, on or off. The forcing is done by writing a new status value. No forcing flag is needed as in forcing i.e. the output relays.
The forced time is valid until the next forcing or until the next reversing timed act from the timer itself.
The status of each timer is stored in non-volatile memory when the auxiliary power is switched off. At start up, the status of each timer is recovered.
143
6.8 Timers
Parameter
TimerN
On
Off
Mode
6 Supporting functions
-
0
1 hh:mm:ss hh:mm:ss
-
Daily
Monday
Tuesday
Wednesday
Thursday
Friday
Saturday
Sunday
MTWTF
MTWTFS
SatSun
-
Value
Table 6.11: Setting parameters of timers
Description
Timer status
Not in use
Output is inactive
Output is active
Activation time of the timer
De-activation time of the timer
For each four timers there are 12 different modes available:
The timer is off and not running. The output is off i.e. 0 all the time.
The timer switches on and off once every day.
The timer switches on and off every Monday.
The timer switches on and off every Tuesday.
The timer switches on and off every Wednesday.
The timer switches on and off every Thursday.
The timer switches on and off every Friday.
The timer switches on and off every Saturday.
The timer switches on and off every Sunday.
The timer switches on and off every day except Saturdays and Sundays
The timer switches on and off every day except Sundays.
The timer switches on and off every Saturday and Sunday.
144
V59/en M/A009
6 Supporting functions
6.9 Combined overcurrent status
6.9
Parameter
IFltLas
LINE ALARM
AlrL1
AlrL2
AlrL3
OCs
LxAlarm
LxAlarmOff
OCAlarm
OCAlarmOff
IncFltEvnt
ClrDly
LINE FAULT
FltL1
FltL2
FltL3
OCt
V59/en M/A009
On / Off
-
On / Off
-
On / Off
-
On / Off
-
On
Off
0 – 65535
1
-
0
1
-
-
0
-
0
1
-
0
1
Combined overcurrent status
This function is collecting faults, fault types and registered fault currents of all enabled overcurrent stages.
Value
Combined over current status can be used as an indication of faults.
Combined o/c indicates the amplitude of the last occurred fault. Also a separate indication of the fault type is informed during the start and the trip. Active phases during the start and the trip are also activated in the output matrix. After the fault is switched off the active signals will release after the set delay “clearing delay“ has passed.
The combined o/c status referres to the following over current stages:
I>, I>>, I>>>.
Table 6.12: Line fault parameters
Unit
xImode
Description
Current of the latest overcurrent fault
Note
(Set) s
Start (=alarm) status for each phase.
0 = No start since alarm ClrDly
1 = Start is on
Combined overcurrent start status.
AlrL1 = AlrL2 = AlrL3 = 0
AlrL1 = 1 or AlrL2 = 1 or AlrL3 = 1
'On' Event enabling for AlrL1 – 3
Events are enabled / Events are disabled
'Off' Event enabling for AlrL1 – 3
Events are enabled / Events are disabled
'On' Event enabling for combined o/c starts
Events are enabled / Events are disabled
'Off' Event enabling for combined o/c starts
Events are enabled / Events are disabled
Disabling several start and trip events of the same fault
Several events are enabled
*)
Several events of an increasing fault is disabled
**)
Duration for active alarm status AlrL1, Alr2, AlrL3 and OCs
Set
Set
Set
Set
Set
Set
Fault (=trip) status for each phase.
0 = No fault since fault ClrDly
1 = Fault is on
Combined overcurrent trip status.
FltL1 = FltL2 = FltL3 = 0
FltL1 = 1 or FltL2 = 1 or FltL3 = 1
145
6.9 Combined overcurrent status
6 Supporting functions
Parameter
LxTrip
LxTripOff
OCTrip
OCTripOff
IncFltEvnt
Value
-
On / Off
-
On / Off
-
On / Off
-
On / Off
-
On
Off
0 – 65535
Unit Description
'On' Event enabling for FltL1 – 3
Events are enabled / Events are disabled
'Off' Event enabling for FltL1 – 3
Events are enabled / Events are disabled
'On' Event enabling for combined o/c trips
Events are enabled / Events are disabled
'Off' Event enabling for combined o/c starts
Events are enabled / Events are disabled
Disabling several events of the same fault
Several events are enabled
*)
Several events of an increasing fault is disabled
**)
Duration for active alarm status FltL1, Flt2, FltL3 and OCt
Note
Set
Set
Set
Set
Set
Set ClrDly s
Set = An editable parameter (password needed).
*) Used with IEC 60870-105-103 communication protocol. The alarm screen will show the latest if it's the biggest registered fault current, too. Not used with Spabus, because Spabus masters usually don't like to have unpaired On/Off events.
**) Used with SPA-bus protocol, because most SPA-bus masters do need an off-event for each corresponding on-event.
146
Figure 6.4: Combined o/c status.
The fault that can be seen in the Figure 6.4 was 3 times to nominal
and it started as an one phase fault L1-E. At the moment when one of the protection stages tripped the fault was already increased in to a two phase short circuit L1-L2. All signals those are stated as “1” are also activated in the output matrix. After the fault disappears the activated signals will release.
Combined over current status can be found from VAMPSET menu
“protection stage status 2”.
V59/en M/A009
6 Supporting functions
6.10
6.10.1
6.10 Self-supervision
Self-supervision
The functions of the microcontroller and the associated circuitry, as well as the program execution are supervised by means of a separate watchdog circuit. Besides supervising the relay, the watchdog circuit attempts to restart the micro controller in an inoperable situation. If the micro controller does not resart, the watchdog issues a self-supervision signal indicating a permanent internal condition.
When the watchdog circuit detects a permanent fault, it always blocks any control of other output relays (except for the self-supervision output relay). In addition, the internal supply voltages are supervised.
Should the auxiliary supply of the IED disappear, an indication is automatically given because the IED status inoperative (SF) output relay functions on a working current principle. This means that the
SF relay is energized when the auxiliary supply is on and the arc flash protection is healthy.
Diagnostics
The device runs self-diagnostic tests for hardware and software in boot sequence and also performs runtime checking.
Permanent inoperative state
If permanent inoperative state has been detected, the device releases
SF relay contact and status LED is set on. Local panel will also display a detected fault message. Permanet inoperative state is entered when the device is not able to handle main functions.
Temporal inoperative state
When self-diagnostic function detects a temporal inoperative state,
Selfdiag matrix signal is set and an event (E56) is generated. In case the inoperative state was only temporary, an off event is generated
(E57). Self diagnostic state can be reset via local HMI.
Diagnostic registers
There are four 16-bit diagnostic registers which are readable through remote protocols. The following table shows the meaning of each diagnostic register and their bits.
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147
6.10 Self-supervision
Register
SelfDiag1
SelfDiag3
SelfDiag4
6 Supporting functions
Bit
0 (LSB)
1
2
3
4
10
11
8
9
12
13
14
15 (MSB)
0 (LSB)
1
2
3
6
7
4
5
1
2
Code
T1
T2
T3
T4
A1
DAC
STACK
MemChk
BGTask
DI
Description
Potential output relay problem
Potential mA-output problem
Potential stack problem
Potential memory problem
Potential background task timeout
Potential input problem (Remove DI1, DI2)
Arc
SecPulse
RangeChk
CPULoad
+24V
-15V
ITemp
ADChk1
ADChk2
E2prom
ComBuff
OrderCode
Potential arc card problem
Potential hardware problem
DB: Setting outside range
Overload
Potential internal voltage problem
Internal temperature too high
Potential A/D converter problem
Potential A/D converter problem
Potential E2prom problem
Potential BUS: buffer problem
Potential order code problem
The code is displayed in self diagnostic events and on the diagnostic menu on local panel and VAMPSET.
148
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7 Measurement functions
7
7.1
Measurement functions
All the direct measurements are based on fundamental frequency values. Most protection functions are also based on the fundamental frequency values.
The figure shows a current waveform and the corresponding fundamental frequency component f1, second harmonic f2 and rms value in a special case, when the current deviates significantly from a pure sine wave.
5
0 rms f2 f1 f2/f1 (%)
Load = 0%
100
50
0
-5
IL2
-10
0.00
0.05
0.10
0.15
Time (s)
0.20
0.25
0.30
Figure 7.1: Example of various current values of a transformer inrush current
Measurement accuracy
Table 7.1: Phase current inputs I
L1
, I
L2
, I
L3
Measuring range 0.025 – 250 A
Inaccuracy: -
I ≤ 7.5 A ±0.5 % of value or ±15 mA
I > 7.5 A ±3 % of value
The specified frequency range is 45 Hz – 65 Hz.
Squelch limit:
Phase current inputs: 0.1% of I
NOM
(tolerance +/- 0.05%)
Residual current: 0.2% of I
0NOM
(tolerance +/- 0.05%)
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149
7.2 RMS values
7 Measurement functions
7.2
7.3
THD
=
i
15
∑
= 2
h i
2
h
1
Table 7.2: Residual current input I
0N
Measuring range
Inaccuracy: -
0.003 – 10 x I
0N
I ≤ 1.5 xI
N
±0.3 % of value or ±0.2 % of I
0N
I > 1.5 xI
N
±3 % of value
The rated input I
0N is 5A, 1 A or 0.2 A. It is specified in the order code of the relay.
The specified frequency range is 45 Hz – 65 Hz.
Table 7.3: THD and harmonics
Inaccuracy I, U > 0.1 PU
Update rate
±2 % units
Once a second
The specified frequency range is 45 Hz – 65 Hz.
RMS values
RMS currents
The device calculates the RMS value of each phase current. The minimum and the maximum of RMS values are recorded and stored
(see Chapter 7.5 Minimum and maximum values).
I
RMS
=
I f
1
2
+
I f
2
2
+ ...
+
I f
15
2
Harmonics and Total Harmonic
Distortion (THD)
The device calculates the THDs as a percentage of the currents and voltages values measured at the fundamental frequency. The device calculates the harmonics from the 2nd to the 15th of phase currents and voltages. (The 17th harmonic component will also be shown partly in the value of the 15th harmonic component. This is due to the nature of digital sampling.)
The harmonic distortion is calculated h
1
= h
2 – 15
=
Fundamental value
Harmonics
Example
h
1
= 100 A
, h
3
= 10 A,
THD
=
10
2
+
3
2
100
+
8
2
=
13 .
2 % h
7
= 3 A, h
11
= 8 A
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150
7 Measurement functions
7.4 Demand values
For reference the RMS value is
RMS
=
100
2
+
10
2
+
3
2
+
8
2
=
100 .
9
A
Another way to calculate THD is to use the RMS value as reference instead of the fundamental frequency value. In the example above the result would then be 13.0 %.
7.4
Demand values
The relay calculates average i.e. demand values of phase currents
I
L1
, I
L2
, I
L3 and remote currents I
L1Remote
, I
L2Remote
, I
L3Remote
.
Parameter Value
Time 10 – 30
Fundamental frequency values
IL1da
IL2da
IL3da
IL1daRem
IL2daRem
IL3daRem
The demand time is configurable from 10 minutes to 30 minutes with parameter "Demand time".
Table 7.4: Demand value parameters
Unit
min
Description
Demand time (averaging time)
Set
Set
A
A
A
A
A
A
Demand of phase current IL1
Demand of phase current IL2
Demand of phase current IL3
Demand of remote phase current IL1
Demand of remote phase current IL2
Demand of remote phase current IL3
Set = An editable parameter (password needed).
7.5
Min & Max measurement
IL1, IL2, IL3
IL1RMS, IL2RMS, IL3RMS
I
0
IL1Rem, IL2Rem, IL3Rem
Minimum and maximum values
Minimum and maximum values are registered with time stamps since the latest manual clearing or since the device has been restarted.
The available registered min & max values are listed in the following table.
Description
Phase current (fundamental frequency value)
Phase current, rms value
Residual current
Demand values of remote phase currents
The clearing parameter "ClrMax" is common for all these values.
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151
7.6 Maximum values of the last 31 days and 12 months
7 Measurement functions
Parameter
ClrMax
7.6
Measurement
IL1, IL2, IL3
Io
IL1Rem, IL2Rem,
IL3Rem
Parameter
Timebase
ResetDays
ResetMon
-
Value
Table 7.5: Parameters
Description
Reset all minimum and maximum values
-
Clear
Set = An editable parameter (password needed).
Set
Set
Maximum values of the last 31 days and
12 months
X
X x
Max
Maximum and minimum values of the last 31 days and the last twelve months are stored in the non-volatile memory of the relay.
Corresponding time stamps are stored for the last 31 days. The registered values are listed in the following table.
Min Description 31 days 12 months
Phase current (fundamental frequency value)
Residual current
Remote current
The value can be a one cycle value or an average based on the
"Timebase" parameter.
Table 7.6: Parameters of the day and month registers
Value Description
20 ms
200 ms
1 s
1 min demand
Parameter to select the type of the registered values
Collect min & max of one cycle values
*
Collect min & max of 200 ms average values
Collect min & max of 1 s average values
Collect min & max of 1 minute average values
Collect min & max of demand values (Chapter 7.4 Demand values)
Reset the 31 day registers
Reset the 12 month registers
Set
Set
Set
Set
Set = An editable parameter (password needed).
* This is the fundamental frequency rms value of one cycle updated every 20 ms.
152
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7 Measurement functions
7.7 Voltage measurement modes
7.7
Voltage measurement modes
The relay can be connected to zero-sequence voltage. The configuration parameter "Voltage measurement mode" must be set to "U
0
".
L1 L2 L3
10
11
"U
0
"
U
0
The device is connected to zero sequence voltage.
Directional ground fault protection is available.
(see Figure 7.2 and Figure 11.8).
Figure 7.2: Broken delta connection “U
0
”.
7.8
V59/en M/A009
Symmetric components
In a three phase system, the voltage or current phasors may be divided in symmetric components according C. L. Fortescue (1918).
The symmetric components are:
• Positive sequence 1
• Negative sequence 2
• Zero sequence 0
Symmetric components are calculated according the following equations:
S
S
S
1
0
2
=
1
3
1
1
1
1
a a
2
1
a
2
a
U
V
W
S
0
= zero sequence component
S
1
= positive sequence component
S
2
= negative sequence component
a
= 1 ∠ 120 ° = −
1
2
+
j
2
3
, a phasor rotating constant
U = phasor of phase L1 (phase current)
V = phasor of phase L2
W = phasor of phase L3
153
7.9 Primary secondary and per unit scaling
7 Measurement functions
7.9
Primary secondary and per unit scaling
Many measurement values are shown as primary values although the relay is connected to secondary signals. Some measurement values are shown as relative values - per unit or per cent. Almost all pick-up setting values are using relative scaling.
The scaling is done using the given CT in feeder mode. The following scaling equations are useful when doing secondary testing.
7.9.1
Current scaling
NOTE: The rated value of the device's current input, for example 5 A or 1A,
does not have any effect in the scaling equations, but it defines the measurement range and the maximum allowed continuous current.
secondary → primary primary → secondary
Primary and secondary scaling
Current scaling
I
PRI
=
I
SEC
⋅
CT
PRI
CT
SEC
I
SEC
=
I
PRI
⋅
CT
SEC
CT
PRI
For residual current to input I
CT
SEC
0 use the corresponding CT
PRI values. For ground fault stages using I
0Calc and signals use the phase current CT values for CT
PRI and CT
SEC
.
Examples:
1. Secondary to primary
CT = 500 / 5
Current to the relay's input is 4 A.
=> Primary current is I
PRI
= 4 x 500 / 5 = 400 A
2. Primary to secondary
CT = 500 / 5
The relay displays I
PRI
= 400 A
=> Injected current is I
SEC
= 400 x 5 / 500 = 4 A
154
V59/en M/A009
7 Measurement functions
7.9 Primary secondary and per unit scaling
secondary → per unit per unit → secondary
Per unit [pu] scaling
For phase currents
1 pu = 1 x I
MODE
= 100 %, where
I
MODE is the nominal value of the feeder.
For residual currents
1 pu = 1 x CT
SEC side.
for secondary side and 1 pu = 1 x CT
PRI for primary
Phase current scaling Residual current (3I
0
) scaling
I
PU
=
I
SEC
⋅
CT
SEC
CT
PRI
⋅
I
N
I
PU
=
I
SEC
CT
SEC
I
SEC
=
I
PU
⋅
CT
SEC
⋅
I
N
CT
PRI
I
SEC
=
I
PU
⋅
CT
SEC
Examples:
1. Secondary to per unit for phase currents excluding ArcI>
CT = 750/5
I
MODE
= 525 A
Current injected to the relay's inputs is 7 A.
I
Per unit current is I
PU
MODE
= 200 %
= 7 x 750 / (5 x 525) = 2.00 pu = 2.00 x
2. Per unit to secondary for phase currents excluding ArcI>
CT = 750 / 5
I
MODE
= 525 A
The relay setting is 2 x I
MODE
= 2 pu = 200 %.
Secondary current is I
SEC
= 2 x 5 x 525 / 750 = 7 A
3. Secondary to per unit for residual current
Input is I
0
.
CT
0
= 50 / 1
Current injected to the relay's input is 30 mA.
Per unit current is I
PU
= 0.03 / 1 = 0.03 pu = 3 %
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155
7.9 Primary secondary and per unit scaling
7 Measurement functions
7.9.2
secondary ->per unit per unit -> secondary
4. Per unit to secondary for residual current
Input is I
0
.
CT
0
= 50 / 1
The relay setting is 0.03 pu = 3 %.
Secondary current is I
SEC
= 0.03 x 1 = 30 mA
5. Secondary to per unit for residual current
Input is I
0Calc
.
CT = 750 / 5
Currents injected to the relay's I
L1 input is 0.5 A.
I
L2
= I
L3
= 0.
Per unit current is I
PU
= 0.5 / 5 = 0.1 pu = 10 %
6. Per unit to secondary for residual current
Input is I
0Calc
.
CT = 750 / 5
The relay setting is 0.1 pu = 10 %.
If I
L2
I
SEC
= I
L3
= 0, then secondary current to I
L1
= 0.1 x 5 = 0.5 A is
Voltage scaling
Per unit [pu] scaling of zero sequence voltage
Zero-sequence voltage (U
0
) scaling
Voltage measurement mode = "U
0
"
U
PU
=
U
SEC
U
0
SEC
U
SEC
=
U
PU
⋅
U
0
SEC
Examples:
1. Secondary to per unit. Voltage measurement mode is "U
0
".
U
0SEC
U
0
= 110 V (This is a configuration value corresponding to at full ground fault.)
Voltage connected to the device's input U
C is 22 V.
Per unit voltage is U
PU
= 22 / 110 = 0.20 pu = 20 %
156
V59/en M/A009
7 Measurement functions
7.10
7.10.1
7.10 Analogue output (option)
Analogue output (option)
A device with the mA option has one configurable analogue output.
The resolution of the analogue output is 10 bits resulting current steps less than 25 μA. The output current range is configurable allowing e.g. the following ranges: 0 – 20 mA and 4 – 20 mA. More exotic ranges like 0 – 5 mA or 10 – 2 mA can be configured freely as long as the boundary values are within 0 – 20 mA.
Available couplings to the analog output:
• IL1, IL2, IL3
• f
• IL
• Io, IoCalc
• Uo
mA scaling example
Example of configuration of scaling the transducer (mA) output.
Example of mA scaling for IL
Coupling = IL
Scaled minimum = 0 A
Scaled maximum = 300 mA
Analogue output minimum value = 0 mA
Analogue output maximum value = 20 mA
Analogue output
(mA)
20
16 mAScaling_1
12
8
4
300
IL
(A)
Figure 7.3: The average of the three phase currents. At 0 A the transducer ouput is 0 mA, at 300 A the output is 20 mA
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8 Control functions
8 Control functions
8.1
Output relays
The output relays are also called digital outputs. Any internal signal can be connected to the output relays using output matrix. An output
relay can be configured as latched or non-latched. See Chapter 8.5
Output matrix for more details.
The difference between trip contacts and signal contacts is the DC
breaking capacity. See Table 12.4 and Table 12.5 for details. The
contacts are SPST normal open type (NO), except signal relay A1 which has change over contact (SPDT).
Table 8.1: Parameters of output relays
Value
0
Unit Description
Status of trip output relay
Note
F
Parameter
T1 – T4
A1
SF
Force
1
0
1
0
1
On
Off
Status of alarm output relay
Status of the SF relay
In VAMPSET, it is called as "Service status output"
Force flag for output relay forcing for test purposes. This is a common flag for all output relays and detection stage status, too. Any forced relay(s) and this flag are automatically reset by a 5-minute timeout.
REMOTE PULSES
A1, T3, T4 0.00 – 99.98
or s Pulse length for direct output relay control via communications protocols.
99.99 s = Infinite. Release by writing "0" to the direct control parameter
99.99
NAMES for OUTPUT RELAYS (editable with VAMPSET only)
Description String of max. 32 characters Names for DO on VAMPSET screens.
Default is
"Trip relay n", n=1 – 4 or
"Signal relay n", n=1
F
F
Set
Set
Set
F = Editable when force flag is on. Set = An editable parameter (password needed).
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8 Control functions
8.2
8.2 Digital inputs
Digital inputs
There are two (2) digital inputs available for control purposes.
The polarity – normal open (NO) / normal closed (NC) – and a delay can be configured according the application. The signals are available for the output matrix, block matrix, user's programmable logic etc.
Selection in order code
1
2
3
Threshold voltage
24 V dc / 110 V ac
110 V dc / 220 V ac
220 V dc
The digital inputs need an external control voltage (ac or dc). The
voltage nominal activation level can be selected in Chapter 14 Order information.
When 110 or 220 V ac voltage is used to activate the digital Inputs,
the AC mode should be selected as shown in Figure 8.1
Figure 8.1: AC mode selection in VAMPSET
These inputs are ideal for transferring the status information of switching devices into the device.
Please note that it is possible to use two different control voltages for the inputs.
Label and description texts can be edited with VAMPSET according the application. Labels are the short parameter names used on the local panel and descriptions are the longer names used by
VAMPSET.
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8.2 Digital inputs
8 Control functions
Table 8.2: Parameters of digital inputs
Parameter
DI1, DI2
Value
0; 1
DI COUNTERS
DI1, DI2 0 – 65535
DELAYS FOR DIGITAL INPUTS
DI1, DI2 0.00 – 60.00
CONFIGURATION DI1 – DI6
Inverted no
Unit
s
Description
Status of digital input
Cumulative active edge counter
Definite delay for both on and off transitions
Indication display
On event yes no yes
On
Off
For normal open contacts (NO). Active edge is
0 -> 1
For normal closed contacts (NC). Active edge is 1 -> 0
No pop-up display
Indication display is activated at active DI edge
Active edge event enabled
Active edge event disabled
Off event On
Off
Inactive edge event enabled
Inactive edge event disabled
NAMES for DIGITAL INPUTS (editable with VAMPSET only)
Label
Description
String of max. 10 characters
String of max. 32 characters
Short name for DIs on the local display. Default is "DIn", n = 1 – 2
Long name for DIs. Default is "Digital input n", n = 1 – 2
Set = An editable parameter (password needed).
Note
(Set)
Set
Set
Set
Set
Set
Set
Set
160
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8 Control functions
8.3 Virtual inputs and outputs
8.3
Virtual inputs and outputs
There are virtual inputs and virtual outputs, which can in many places be used like their hardware equivalents, execpt that they are only located in the memory of the device. The virtual inputs acts like normal digital inputs. The state of the virtual input can be changed from display, communication bus and from VAMPSET. For example setting groups can be changed using virtual inputs.
Table 8.3: Parameters of virtual inputs
Parameter
VI1 – VI4
Value
0; 1
Unit Description
Status of virtual input
Events On; Off Event enabling
NAMES for VIRTUAL INPUTS (editable with VAMPSET only)
Label String of max. 10 characters Short name for VIs on the local display
Note
Set
Set
Description String of max. 32 characters
Default is "VIn", n = 1 – 4
Long name for VIs. Default is "Virtual input n", n = 1 – 4
Set
Set = An editable parameter (password needed).
The six virtual outputs do act like output relays, but there are no physical contacts. Virtual outputs are shown in the output matrix and the block matrix. Virtual outputs can be used with the user's programmable logic and to change the active setting group etc.
8.4
Function keys / F1 & F2
There are two independent function keys, F1 and F2, available in the device front panel. As default, these keys are programmed to toggle VI1 and VI2. It is possible to change F1 & F2 to toggle other
VIs or to act as object control.
8.5
Output matrix
By means of the output matrix, the output signals of the various protection stages, digital inputs, logic outputs and other internal signals can be connected to the output relays, virtual outputs, etc.
There are eight general purpose LED indicators – "A", "B", "C", "D",
"E", "F", "G" and "H" – available for customer-specific indications on the front panel.
Furthermore there are two LED indicators specified for keys F1 and
F2. In addition, the triggering of the disturbance recorder (DR) and virtual outputs are configurable in the output matrix.
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8.5 Output matrix
8 Control functions
Figure 8.2: Output matrix
An output relay or indicator LED can be configured as latched or non-latched. A non-latched relay follows the controlling signal. A latched relay remains activated although the controlling signal releases.
“Auto LED release” function is designed to indicate only the latest event. When Auto LED release is enabled “old” latched LED’s will release latch when new event occurs. This way only the latest event
LED’s are active. “ Auto LED release enable time” sets the time delay after the event deactivation latched LED is interpret as “old”. See an
Figure 8.3: Local panel configuration menu
162
Figure 8.4: Release output matrix latches
There is a common "release all latches" signal to release all the latched relays. This release signal resets all the latched output relays and indicators with CPU and FPGA control. The reset signal can be given via a digital input, via HMI or through communication. The selection of the input is done with the VAMPSET software under the
menu "Release output matrix latches". See an example in Figure 8.4.
NOTE: "Release all latches" signal clears and resets FPGA controlled
latches.
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8 Control functions
8.6
8.6 Blocking matrix
Blocking matrix
By means of a blocking matrix, the operation of any protection stage can be blocked. The blocking signal can originate from the digital inputs DI1 to DI2, or it can be a start or trip signal from a protection stage or an output signal from the user's programmable logic. In the
block matrix Figure 8.5 an active blocking is indicated with a black
dot ( ● ) in the crossing point of a blocking signal and the signal to be blocked.
Figure 8.5: Blocking matrix and output matrix
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8.7 Controllable objects
8 Control functions
8.7
Setting
Object state
Setting
DI for ‘obj open’
DI for ‘obj close’
DI for ‘obj ready’
Max ctrl pulse length
Completion timeout
Object control
Controllable objects
The object block matrix and logic functions can be used to configure interlocking for a safe controlling before the output pulse is issued.
The objects 1 – 6 are controllable while the objects 7 – 8 are only able to show the status.
Controlling is possible by the following ways:
• through the local HMI
• through a remote communication
• through a digital input
• through the function key
The connection of an object to specific output relays is done via an output matrix (object 1 – 6 open output, object 1 – 6 close output).
There is also an output signal “Object failed”, which is activated if the control of an object is not completed.
Object states
Each object has the following states:
Value
Undefined (00)
Open
Close
Undefined (11)
Description
Actual state of the object
Basic settings for controllable objects
Each controllable object has the following settings:
Value
None, any digital input, virtual input or virtual output
Description
Open information
Close information
Ready information
0.02 – 600 s
0.02 – 600 s
Open/Close
Pulse length for open and close commands
Timeout of ready indication
Direct object control
If changing states takes longer than the time defined by “Max ctrl pulse length” setting, object is inoperative and “Object failure” matrix signal is set. Also undefined-event is generated. “Completion timeout” is only used for the ready indication. If “DI for ‘obj ready’” is not set, completion timeout has no meaning.
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8 Control functions
8.7 Controllable objects
Setting
DI for ‘obj open’
DI for ‘obj close’
Object timeout
8.7.1
8.7.2
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Each controllable object has 2 control signals in matrix:
Output signal
Object x Open
Object x Close
Description
Open control signal for the object
Close control signal for the object
These signals send control pulse when an object is controlled by digital input, remote bus, auto-reclose etc.
Settings for read-only objects
Value
None, any digital input, virtual input or virtual output
Description
Open information
Close information
0.02 – 600 s Timeout for state changes
If changing states takes longer than the time defined by “Object timeout” setting, and “Object failure” matrix signal is set. Also undefined-event is generated.
Controlling with DI
Objects can be controlled with digital input, virtual input or virtual output. There are four settings for each controllable object:
Setting
DI for remote open / close control
DI for local open / close control
Active
In remote state
In local state
If the device is in local control state, the remote control inputs are ignored and vice versa. Object is controlled when a rising edge is detected from the selected input. Length of digital input pulse should be at least 60 ms.
Local/Remote selection
In Local mode, the output relays can be controlled via a local HMI, but they cannot be controlled via a remote serial communication interface.
In Remote mode, the output relays cannot be controlled via a local
HMI, but they can be controlled via a remote serial communication interface.
The selection of the Local/Remote mode is done by using a local
HMI, or via one selectable digital input. The digital input is normally used to change a whole station to a local or remote mode. The selection of the L/R digital input is done in the “Objects” menu of the
VAMPSET software.
NOTE: A password is not required for a remote control operation.
165
8.7 Controllable objects
8.7.3
Parameter
F1 – F2
VI1 – VI4
ObjCtrl
PrgFncs
8 Control functions
Controlling with F1 & F2
Objects can be controlled with F1 & F2.
As default these keys are programmed to toggle F1 and F2. It is possible to configure F1 & F2 to toggle VI1 – VI4 or act as object control. Selection of the F1 and F2 function is made with the
VAMPSET software under the FUNCTION BUTTONS menu.
Value
Table 8.4: Parameters of F1, F2
Unit Description Set
0
1
Function key toggles Virtual input 1 – 4 and Function button
1 – 2 between on (1) and off (0)
When Object conrol in chosen F1 and F2 can be linked in
OBJECTS to desired objects close/open command.
Set
Selected object and control is shown in VAMPSET software under the menu ”FUNCTION BUTTONS”. If no object with local control is selected ’-’ is shown. If multiple local controls are selected for one key ’?’ is shown.
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8.8
8.8 Auto-reclose function (79)
Auto-reclose function (79)
The VAMP protection relays include a sophisticated Auto-reclosing
(AR) function. The AR function is normally used in feeder protection relays that are protecting an overhead line. Most of the overhead line faults are temporary in nature. Even 85% can be cleared by using the AR function.
General
The basic idea is that normal protection functions will detect the fault.
Then the protection function will trigger the AR function. After tripping the circuit-breaker (CB), the AR function can reclose the CB.
Normally, the first reclose (or shot) is so short in time that consumers cannot notice anything. However, the fault is cleared and the feeder will continue in normal service.
Terminology
Even though the basic principle of AR is very simple; there are a lot of different timers and parameters that have to be set.
In VAMP relays, there are five shots. A shot consists of open time
(so called “dead” time) and close time (so called “burning” time or discrimination time). A high-speed shot means that the dead time is less than 1 s. The time-delayed shot means longer dead times up to 2-3 minutes.
There are four AR lines. A line means an initialization signal for AR.
Normally, start or trip signals of protection functions are used to initiate an AR-sequence. Each AR line has a priority. AR1 has the highest and AR4 has the lowest one. This means that if two lines are initiated at the same time, AR will follow only the highest priority line. A very typical configuration of the lines is that the instantaneous overcurrent stage will initiate the AR1 line, time-delayed overcurrent stage the AR2 line and earth-fault protection will use lines AR3 and
AR4.
For more information about auto-reclosing, please refer to our application note “Auto-reclosing function in VAMP protection relays”.
The auto-reclose (AR) matrix in the following Figure 8.6 describes
the start and trip signals forwarded to the auto-reclose function.
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8.8 Auto-reclose function (79)
8 Control functions
Shot 1
Critical
AR1
AR2
AR-matrix
Ready
(Wait for
AR-request)
In use
In use
Start delay
0...300 s
0...300 s
Dead time
0...300 s
Discrimination time
Reclaim time
0...300 s
0...300 s 0...300 s
Shot 2
Not in use
In use
0...300 s
0...300 s
Shot 3...5
168
Figure 8.6: Auto-reclose matrix
The AR matrix above defines which signals (the start and trip signals from protection stages or digital input) are forwarded to the auto-reclose function. In the AR function, the AR signals can be configured to initiate the reclose sequence. Each shot from 1 to 5 has its own enabled/disabled flag. If more than one AR signal activates at the same time, AR1 has highest priority and AR2 the lowest. Each AR signal has an independent start delay for the shot
1. If a higher priority AR signal activates during the start delay, the start delay setting will be changed to that of the highest priority AR signal.
After the start delay the circuit-breaker (CB) will be opened if it is closed. When the CB opens, a dead time timer is started. Each shot from 1 to 5 has its own dead time setting.
After the dead time the CB will be closed and a discrimination time timer is started. Each shot from 1 to 5 has its own discrimination time setting. If a critical signal is activated during the discrimination time, the AR function makes a final trip. The CB will then open and the
AR sequence is locked. Closing the CB manually clears the “locked” state.
After the discrimination time has elapsed, the reclaim time timer starts. If any AR signal is activated during the reclaim time or the discrimination time, the AR function moves to the next shot. The reclaim time setting is common for every shot.
If the reclaim time runs out, the auto-reclose sequence is successfully executed and the AR function moves to ready -state and waits for a new AR request in shot 1.
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8.8 Auto-reclose function (79)
A trip signal from the protection stage can be used as a backup.
Configure the start signal of the protection stage to initiate the AR function. If something fails in the AR function, the trip signal of the protection stage will open the CB. The delay setting for the protection stage should be longer than the AR start delay and discrimination time.
If a critical signal is used to interrupt an AR sequence, the discrimination time setting should be long enough for the critical stage, usually at least 100 ms.
Manual closing
When CB is closed manually with the local panel, remote bus, digital inputs etc, the reclaim-state is activated. Within the reclaim time all
AR requests are ignored. It is up to protection stages to take care of tripping. Trip signals of protection stages must be connected to a trip relay in the output matrix.
Manual opening
Manual CB open command during AR sequence will stop the sequence and leaves the CB open.
Reclaim time setting
• Use shot specific reclaim time: No
Reclaim time setting defines reclaim time between different shots during sequence and also reclaim time after manual closing.
• Use shot specific reclaim time: Yes
Reclaim time setting defines reclaim time only for manual control.
Reclaim time between different shots is defined by shot specific reclaim time settings.
Support for 2 circuit breakers
AR function can be configured to handle 2 controllable objects. Object
1 – 6 can be configured to CB1 and any other controllable object can be used as CB2. The object selection for CB2 is made with
Breaker 2 object setting. Switching between the two objects is done
with a digital input, virtual input, virtual output or by choosing Auto
CB selection. AR controls CB2 when the input defined by Input for
selecting CB2 setting is active (except when using auto CB selection
when operated CB 1 or 2 is that which was last in close state). Control is changed to another object only if the current object is not close.
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8 Control functions
Blocking of AR shots
Each AR shot can be blocked with a digital input, virtual input or virtual output. Blocking input is selected with Block setting. When selected input is active the shot is blocked. A blocked shot is treated like it doesn’t exist and AR sequence will jump over it. If the last shot in use is blocked, any AR request during reclaiming of the previous shot will cause final tripping.
Starting AR sequence
Each AR request has own separate starting delay counter. The one which starting delay has elapsed first will be selected. If more than one delay elapses at the same time, an AR request of the highest priority is selected. AR1 has the highest priority and AR4 has the lowest priority. First shot is selected according to the AR request.
Next AR opens the CB and starts counting dead time.
Starting sequence at shot 2 – 5 & skipping of AR shots
Each AR request line can be enabled to any combination of the 5 shots. For example making a sequence of Shot 2 and Shot 4 for
AR request 1 is done by enabling AR1 only for those two shots.
NOTE: If AR sequence is started at shot 2 – 5 the starting delay is taken
from the discrimination time setting of the previous shot. For example if Shot 3 is the first shot for AR2, the starting delay for this sequence is defined by Discrimination time of Shot 2 for AR2.
Critical AR request
Critical AR request stops the AR sequence and cause final tripping.
Critical request is ignored when AR sequence is not running and also when AR is reclaiming.
Critical request is accepted during dead time and discrimination time.
Shot active matrix signals
When starting delay has elapsed, active signal of the first shot is set.
If successful reclosing is executed at the end of the shot, the active signal will be reset after reclaim time. If reclosing was not successful or new fault appears during reclaim time, the active of the current shot is reset and active signal of the next shot is set (if there are any shots left before final trip).
AR running matrix signal
This signal indicates dead time. The signal is set after controlling CB open. When dead time ends, the signal is reset and CB is controlled close.
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8 Control functions
8.8 Auto-reclose function (79)
Parameter
ARena
ExtSync
AR_DI
AR2grp
ReclT
CB
CB1
CB2
AutoCBSel
CB2Sel
ARreq
ShotS
ARlock
CritAr
ARrun
FinTrp
ReqEnd
ShtEnd
CriEnd
ARUnl
ARStop
FTrEnd
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Final trip matrix signals
There are 5 final trip signals in the matrix, one for each AR request
(1 to 4 and 1 critical). When final trip is generated, one of these signals is set according to the AR request which caused the final tripping. The final trip signal will stay active for 0.5 seconds and then resets automatically.
DI to block AR setting
This setting is useful with an external synchro-check device. This setting only affects re-closing the CB. Re-closing can be blocked with a digital input, virtual input or virtual output. When the blocking input is active, CB won’t be closed until the blocking input becomes inactive again. When blocking becomes inactive the CB will be controlled close immediately.
Value
ARon; ARoff
None,
Table 8.5: Setting parameters of AR function
any digital input, virtual input or virtual output
None,
Unit
-
-
-
-
Default
ARon
Description
Enabling/disabling the autoreclose
The digital input for blocking CB close. This can be used for Synchrocheck.
The digital input for toggling the ARena parameter any digital input, virtual input or virtual output
ARon; ARoff
0.02 – 300.00
s
ARon
10.00
-
Obj1
Obj1
off
Enabling/disabling the autoreclose for group 2
Reclaim time setting. This is common for all the shots.
Breaker object in use
Breaker 1 object
Breaker 2 object
Enabling/disabling the auto CB selection
The digital input for selecting the CB2.
On; Off
On; Off
On; Off
On; Off
On; Off
On; Off
On; Off
Obj1 – Obj6
Obj1 – Obj6
Obj1 – Obj6
On; Off
None, any digital input, virtual input or virtual output
On; Off
On; Off
On; Off
On; Off
On; Off
-
-
-
-
-
-
-
-
-
-
-
-
Off
Off
Off
Off
Off
Off
Off
Off
Off
Off
Off
Off
AR request event
AR shot start event
AR locked event
AR critical signal event
AR running event
AR final trip event
AR end of request event
AR end of shot event
AR end of critical signal event
AR release event
AR stopped event
AR final trip ready event
171
8.8 Auto-reclose function (79)
AR1
AR2
AR3
AR4
Start1
Start2
Start3
Start4
Discr1
Discr2
Discr3
Discr4
Parameter
ARon
ARoff
CRITri
AR1Tri
AR2Tri
Shot settings
DeadT
Value
On; Off
On; Off
On; Off
On; Off
On; Off
0.02 – 300.00
On; Off
On; Off
On; Off
On; Off
0.02 – 300.00
0.02 – 300.00
0.02 – 300.00
0.02 – 300.00
0.02 – 300.00
0.02 – 300.00
0.02 – 300.00
0.02 – 300.00
8 Control functions
Unit
-
-
-
-
-
Default
Off
Off
On
On
On s s s s s s s s s
-
-
-
-
5.00
Off
Off
0.02
0.02
0.02
0.02
Off
Off
0.02
0.02
0.02
0.02
Description
AR enabled event
AR disabled event
AR critical final trip on event
AR AR1 final trip on event
AR AR2 final trip on event
The dead time setting for this shot. This is a common setting for all the AR lines in this shot
Indicates if this AR signal starts this shot
Indicates if this AR signal starts this shot
Indicates if this AR signal starts this shot
Indicates if this AR signal starts this shot
AR1 Start delay setting for this shot
AR2 Start delay setting for this shot
AR3 Start delay setting for this shot
AR4 Start delay setting for this shot
AR1 Discrimination time setting for this shot
AR2 Discrimination time setting for this shot
AR3 Discrimination time setting for this shot
AR4 Discrimination time setting for this shot
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8.8 Auto-reclose function (79)
Parameter
Measured or recorded values
Obj1
Table 8.6: Measured and recorded values of AR function
Value
UNDEFINED;
Unit
-
Description
Object 1 state
OPEN;
Status
Shot#
CLOSE;
OPEN_REQUEST;
CLOSE_REQUEST;
READY;
NOT_READY;
INFO_NOT_AVAILABLE;
FAIL
INIT;
RECLAIM_TIME;
READY;
WAIT_CB_OPEN;
WAIT_CB_CLOSE;
DISCRIMINATION_TIME;
LOCKED;
FINAL_TRIP;
CB_FAIL;
INHIBIT
1 – 5 -
AR-function state
ReclT -
The currently running shot
The currently running time (or last executed)
RECLAIMTIME;
STARTTIME;
DEADTIME;
DISCRIMINATIONTIME
SCntr
Fail
Shot1*
Shot2*
Shot3*
Shot4*
Shot5*
-
-
-
-
-
-
Total start counter
The counter for failed
AR shots
Shot1 start counter
Shot2 start counter
Shot3 start counter
Shot4 start counter
Shot5 start counter
* There are 5 counters available for each one of the two AR signals.
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8.8 Auto-reclose function (79)
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8 Control functions
I> setting
Current
Open command
CB
Close command
CB
CBclose state
CBopen state
Figure 8.7: Example sequence of two shots. After shot 2 the fault is cleared.
1. Current exceeds the I> setting; the start delay from shot 1 starts.
2. After the start delay, an OpenCB relay output closes.
3. A CB opens. The dead time from shot 1 starts, and the OpenCB relay output opens.
4. The dead time from shot 1 runs out; a CloseCB output relay closes.
5. The CB closes. The CloseCB output relay opens, and the discrimination time from shot 1 starts. The current is still over the
I> setting.
6. The discrimination time from the shot 1 runs out; the OpenCB relay output closes.
7. The CB opens. The dead time from shot 2 starts, and the
OpenCB relay output opens.
8. The dead time from shot 2 runs out; the CloseCB output relay closes.
9. The CB closes. The CloseCB output relay opens, and the discrimination time from shot 2 starts. The current is now under
I> setting.
10. Reclaim time starts. After the reclaim time the AR sequence is successfully executed. The AR function moves to wait for a new
AR request in shot 1.
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8 Control functions
8.9
8.9 Logic functions
Logic functions
Logic is made with VAMPSET setting tool. Consumed memory is dynamically shown on the configuration view in percentage. The first value indicates amount of used inputs, second amount of gates and third values shows amount of outputs consumed.
Figure 8.8: Logic can be found and modified in “logic” menu in VAMPSET setting tool
Percentages show used memory amount.
Inputs/Logical functions/Outputs- used. None of these is not allowed to exceed 100%. See guide below to learn basics of logic creation:
1
2
3
4
Figure 8.9: How to create logical nodes.
1. Press empty area to add a logic gate, confirm new function by pressing “Yes”.
2. Logic function is always "AND" -gate as a default.
3. While logic increases the capacity is increasing as well.
4. To joint logic functions, go on top of the output line of gate and hold down mouse left -> make the connection to other logic functions input.
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8.9 Logic functions
8 Control functions
1
5
4
3
2
6
Figure 8.10: Logic creation
1. Left click on top of any logic function to activate the “Select operation” view.
2. Edit properties button opens the “Function properties” window.
3. Generally it is possible to choose the type of logic function between and/or/counter/swing -gate.
4. When counter is selected, count setting may be set here.
5. Separate delay setting for logic activation and dis-activation.
6. Possible to invert the output of logic. Inverted logic output is marked with circle.
176
1
2
3
4
Figure 8.11: Logic creation
1. Select input signals can be done by pressing the following button or by clicking mouse left on top of the logic input line.
2. Select outputs can be done by pressing the following button or by clicking mouse left on top of the logic output line.
3. This deletes the logic function.
4. When logic is created and settings are written to the IED the unit requires a restart. After restarting the logic output is automatically assigned in output matrix as well.
NOTE: Whenever writing new logic to the IED the unit has to be restarted.
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9 Communication and protocols
9
9.1
Communication and protocols
Communication ports
The relay has one communication port. See Figure 9.1.
There is also one optional communication module slot in the rear panel.
CommunicationPorts50
COMMUNICATION PORTS
LOCAL
PORT
EXTENSION
PORT
REMOTE
PORT
ETHERNET
PORT
Communication option
Ethernet
D-
USB
RS-232
FRONT PANEL
2
1
3
4
D+
GND
Figure 9.1: Communication ports and connectors. The DSR signal from the front panel port selects the active connector for the RS232 local port.
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9.1 Communication ports
9.1.1
9.1.2
Parameter
Protocol
9.1.3
Parameter
Protocol
9.1.4
9 Communication and protocols
Local port (Front panel)
The relay has a USB-connector in the front panel
Protocol for the USB port
The front panel USB port is always using the command line protocol for VAMPSET regardless of the selected protocol for the rear panel local port.
Remote port
Value
Table 9.1: Parameters
Unit
None
ANSI-85
Description
Protocol selection for remote port
-
Communication for line differential protection
Note
Set
Extension port
Value
Table 9.2: Parameters
Unit
None
ExternalIO
Description
Protocol selection for extension port
-
Modbus RTU master for external I/Omodules (VIO12-xx)
Note
Set
Ethernet port
TCP port 1 st
INST and TCP port 2 nd
INST are ports for ethernet communication protocols. Ethernet communication protocols can be selected to these ports when such hardware option is installed. The parameters for these ports are set via local HMI or with VAMPSET in menus TCP port 1 st
INST and TCP port 2 nd
INST. Two different protocols can be used simultaneously on one physical interface (both protocols use the same IP address and MAC address but different
IP port).
Protocol configuration menu contains address and other related information for the ethernet port. TCP port 1st and 2nd instance include selection for the protocol, IP port settings and message/error/timeout counters. More information about the protocol configuration menu on table below.
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9 Communication and protocols
9.1 Communication ports
Parameter
Protocol
Port
IpAddr
NetMsk
Gatew
NTPSvr
KeepAlive
FTP server
FTP speed
FTP password
MAC address
VS Port
Msg#
Errors
Tout
EthSffEn
SniffPort
Value
Table 9.3: Main configuration parameters (local display), inbuilt Ethernet port
None
ModbusTCPs
IEC-101
IEC 61850
EtherNet/IP
DNP3 nnn n.n.n.n
n.n.n.n
default = 0.0.0.0
n.n.n.n
Unit Description
Protocol selection for the extension port
Command line interface for VAMPSET
Modbus TCP slave
IEC-101
IEC-61850 protocol
Ethernet/IP protocol
DNP/TCP
Ip port for protocol, default 102
Internet protocol address (set with
VAMPSET)
Net mask (set with VAMPSET)
Gateway IP address (set with VAMPSET)
Network time protocol server (set with
VAMPSET)
Note
Set
Set
Set
Set
Set
Set
0.0.0.0 = no SNTP
TCP keepalive interval
Enable FTP server
Maximum transmission speed for FTP
FTP password
Set 1)
Set
Set
Set nn on/off
4 Kb/s (default)
? (user) config (configurator)
001ADnnnnnnn nn
23 (default) nnn nnn nnn on/off
Port2
MAC address
IP port for Vampset
Message counter
Error counter
Timeout counter
Sniffer port enable
Sniffer port
Set
Set
Set = An editable parameter (password needed)
1) KeepAlive: The KeepAlive parameter sets in seconds the time between two keepalive packets are sent from the IED.
The setting range for this parameter is between zero (0) and 20 seconds; with the exception that zero (0) means actually
120 seconds (2 minutes). A keep alive’s packet purpose is for the VAMP IED to send a probe packet to a connected client for checking the status of the TCP-connection when no other packet is being sent e.g. client does not poll data from the
IED. If the keepalive packet is not acknowledged, the IED will close the TCP connection. Connection must be resumed on the client side.
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9.1 Communication ports
9 Communication and protocols
Parameter
Protocol
Port
Msg#
Errors
Tout
Value
None
ModbusTCPs
IEC 61850
EtherNet/IP
DNP3 nnn nnn nnn nnn
Table 9.4: TCP PORT 1st INST
Unit Description
Protocol selection for the extension port.
Command line interface for VAMPSET
Modbus TCP slave
IEC-61850 protocol
Ethernet/IP protocol
DNP/TCP
Ip port for protocol, default 502
Message counter
Error counter
Timeout counter
Table 9.5: CP PORT 2nd INST
Parameter
Ethernet port protocol
Value
(TCP PORT 2nd INST)
None
ModbusTCPs
IEC 61850
EtherNet/IP
Port
Msg#
Errors
Tout
DNP3 nnn nnn nnn nnn
Unit Description
Protocol selection for the extension port.
Command line interface for VAMPSET
Modbus TCP slave
IEC-61850 protocol
Ethernet/IP protocol
DNP/TCP
Ip port for protocol, default 502
Message counter
Error counter
Timeout counter
Set = An editable parameter (password needed).
Note
Set
Set
Note
Set
Set
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9 Communication and protocols
9.2
9.2.1
9.2 Communication protocols
Communication protocols
The protocols enable the transfer of the following type of data:
• events
• status information
• measurements
• control commands.
• clock synchronizing
PC communication
PC communication is using a VAMP specified command line interface. The VAMPSET program can communicate using the local
USB-port or using optional Ethernet interface.
For Ethernet configuration, see Chapter 9.1.4 Ethernet port.
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9.2 Communication protocols
9 Communication and protocols
9.2.2
Modbus TCP and Modbus RTU
Parameter
Addr
Value
1 – 247
These Modbus protocols are often used in power plants and in industrial applications. The difference between these two protocols is the media. Modbus TCP uses Ethernet and Modbus RTU uses asynchronous communication (RS-485, optic fibre, RS-232).
VAMPSET will show the list of all available data items for Modbus.
The Modbus communication is activated usually for remote port via
a menu selection with parameter "Protocol". See Figure 9.1.
For Ethernet interface configuration, see Chapter 9.1.4 Ethernet port.
Table 9.6: Parameters
Unit Description
Modbus address for the device.
Note
Set bps
Broadcast address 0 can be used for clock synchronizing.
Modbus TCP uses also the TCP port settings.
Communication speed for Modbus RTU Set bit/s
Parity
1200
2400
4800
9600
19200
None
Even
Odd
Set = An editable parameter (password needed)
Parity for Modbus RTU Set
182
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9 Communication and protocols
9.2 Communication protocols
9.2.3
DNP 3.0
Parameter
bit/s
Parity
SlvAddr
MstrAddr
LLTout
LLRetry
APLTout
CnfMode
DBISup
SyncMode
The relay supports communication using DNP 3.0 protocol. The following DNP 3.0 data types are supported:
• binary input
• binary input change
• double-bit input
• binary output
• analog input
• counters
Value
4800
Additional information can be obtained from the “DNP 3.0 Device
Profile Document” and “DNP 3.0 Parameters.pdf”. DNP 3.0
communication is activated via menu selection. RS-485 interface is often used but also RS-232 and fibre optic interfaces are possible.
Table 9.7: Parameters
Unit
bps
Description
Communication speed
Set
Set
9600 (default)
19200
38400
None (default)
Even
Odd
1 – 65519
Parity Set
Set An unique address for the device within the system
Address of master Set 1 – 65519
255 = default
0 – 65535
1 – 255
1 = default
0 – 65535
5000 = default
EvOnly (default); All
No (default); Yes
0 – 65535 ms ms s
Link layer confirmation timeout
Link layer retry count
Application layer confirmation timeout
Application layer confirmation mode
Double-bit input support
Clock synchronization request interval.
0 = only at boot
Set
Set
Set
Set
Set
Set
Set = An editable parameter (password needed)
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9.2 Communication protocols
9.2.4
9.2.5
9 Communication and protocols
External I/O (Modbus RTU master)
External Modbus I/O devices can be connected to the relay using
IEC 61850
IEC 61850 protocol is available with the optional communication module. IEC 61850 protocol can be used to read / write static data from the relay to receive events and to receive / send GOOSE messages to other relays.
IEC 61850 server interface is capable of
• Configurable data model: selection of logical nodes corresponding to active application functions
• Configurable pre-defined data sets
• Supported dynamic data sets created by clients
• Supported reporting function with buffered and unbuffered Report
Control Blocks
• Sending analogue values over GOOSE
• Supported control modes:
direct with normal security
direct with enhanced security
select before operation with normal security
select before operation with enhanced security
• Supported horizontal communication with GOOSE: configurable
GOOSE publisher data sets, configurable filters for GOOSE subscriber inputs, GOOSE inputs available in the application logic matrix
Additional information can be obtained from the separate documents
“IEC 61850 conformance statement.pdf”, “IEC 61850 Protocol data.pdf” and “Configuration of IEC 61850 interface.pdf”.
184
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9 Communication and protocols
9.2 Communication protocols
9.2.6
EtherNet/IP
The device supports communication using EtherNet/IP protocol which is a part of CIP (Common Industrial Protocol) family. EtherNet/IP protocol is available with the optional inbuilt Ethernet port. The protocol can be used to read / write data from the device using request / response communication or via cyclic messages transporting data assigned to assemblies (sets of data).
For more detailed information and parameter lists for EtherNet/IP, refer to a separate application note “Application Note
EtherNet/IP.pdf”.
For the complete data model of EtherNet/IP, refer to the document
“Application Note DeviceNet and EtherNetIP Data Model.pdf”.
9.2.7
Parameter
Enable FTP server
FTP password
FTP max speed
FTP server
The FTP server is available on VAMP IEDs equipped with an inbuilt or optional Ethernet card.
The server enables downloading of the following files from an IED:
• Disturbance recordings.
• The MasterICD and MasterICDEd2 files.
The MasterICD and MasterICDEd2 files are VAMP-specific reference files that can be used for offline IEC61850 configuration.
Value
Yes
The inbuilt FTP client in Microsoft Windows or any other compatible
FTP client may be used to download files from the device.
Unit Description
Enable or disable the FTP server.
Note
Set
No
Max 33 characters
1 – 10 KB/s
Required to access the FTP server with an FTP client. Default is “config”. The user name is always “vamp”.
Set
The maximum speed at which the FTP server will transfer data.
Set
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185
9.2 Communication protocols
9.2.8
9 Communication and protocols
DeviceNet
The device supports communication using DeviceNet protocol which is a part of CIP (Common Industrial Protocol) family. DeviceNet protocol is available with the optional external VSE009 module. The protocol can be used to read / write data from the device using request / response communication or via cyclic messages transporting data assigned to assemblies (sets of data).
For more detailed information about DeviceNet, refer to a separate application note “Application Note DeviceNet.pdf”.
For the complete data model of DeviceNet, refer to the document
“Application Note DeviceNet and EtherNetIP Data Model.pdf”.
186
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10 Application
10
10.1
Application
VAMP 59 can be used for protection of medium voltage networks with grounded or low-resistance grounded neutral point. The relay has the required functions to be applied as a backup relay in high voltage networks or to a transformer differential relay.
The relays provide circuit-breaker control functionality, additional primary switching devices (earthing switches and disconnector switches) can also be controlled from the relay HMI or the control or
SCADA/automation system. Programmable logic functionality is also implemented in the relay for various applications e.g interlockings schemes. For details about the functionality in the relays, see
Line protection and auto-reclosing
Master Slave
Figure 10.1: Line differential protection and auto-reclosing
1. Fault is disconnected by line differential protection. LdI starts auto-reclosing.
2. Only master does the reclosing, slave waits for permission to close breaker. I> checks if there is still fault. Line differential protection has to be blocked.
3. After successful reclosing slave is permitted to close the breaker.
Slave receives POC-signal from master in 10 ms after successful reclosing. Line differential protection is no longer blocked.
4. Finally the station is energized.
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187
10.2 Trip circuit supervision
10.2
10.2.1
10 Application
Trip circuit supervision
Trip circuit supervision is used to ensure that the wiring from the protective device to a circuit-breaker is in order. This circuit is unused most of the time, but when a protection device detects a fault in the network, it is too late to notice that the circuit-breaker cannot be tripped because of a broken trip circuitry.
Also the closing circuit can be supervised, using the same principle.
Trip circuit supervision with one digital input
The benefits of this scheme is that only one digital inputs is needed and no extra wiring from the relay to the circuit breaker (CB) is needed. Also supervising a 24 Vdc trip circuit is possible.
The drawback is that an external resistor is needed to supervise the trip circuit on both CB positions. If supervising during the closed position only is enough, the resistor is not needed.
• The digital input is connected parallel with the trip contacts
• The digital input is configured as Normal Closed (NC).
• The digital input delay is configured longer than maximum fault time to inhibit any superfluous trip circuit fault alarm when the trip contact is closed.
• The digital input is connected to a relay in the output matrix giving out any trip circuit alarm.
• The trip relay should be configured as non-latched. Otherwise, a superfluous trip circuit fault alarm will follow after the trip contact operates, and the relay remains closed because of latching.
• By utilizing an auxiliary contact of the CB for the external resistor, also the auxiliary contact in the trip circuit can be supervised.
188
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10 Application
10.2 Trip circuit supervision
V59/en M/A009
52b 52a
TCS1DIclosed_1
Figure 10.2: Trip circuit supervision using a single digital input and an external resistor
R. The circuit-breaker is in the closed position. The supervised circuitry in this CB position is double-lined. The digital input is in active state when the trip circuit is complete.
NOTE: The need for the external resistor R depends on the application and
circuit breaker manufacturer's specifications.
189
10.2 Trip circuit supervision
10 Application
190
52a
TCS1DIclosed_2
Figure 10.3: Alternative connection without using circuit breaker 52b auxiliary contacts.
Trip circuit supervision using a single digital input and an external resistor R. The circuit-breaker is in the closed position. The supervised circuitry in this CB position is double-lined. The digital input is in active state when the trip circuit is complete.
V59/en M/A009
10 Application
10.2 Trip circuit supervision
V59/en M/A009
52b 52a
TCS1DIopen_1
Figure 10.4: Trip circuit supervision using a single digital input, when the circuit breaker is in open position.
191
10.2 Trip circuit supervision
10 Application
52a
TCS1DIopen_2
Figure 10.5: Alternative connection without using circuit breaker 52b auxiliary contacts.
Trip circuit supervision using a single digital input, when the circuit breaker is in open position.
Figure 10.6: An example of digital input DI1 configuration for trip circuit supervision with one digital input.
192
Figure 10.7: An example of output matrix configuration for trip circuit supervision with one digital input.
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10 Application
V59/en M/A009
10.2 Trip circuit supervision
Example of dimensioning the external resistor R:
U
AUX
U
DI
=
I
DI
=
= 110 Vdc - 20 % + 10%, Auxiliary voltage with tolerance
18 Vdc, Threshold voltage of the digital input
3 mA, Typical current needed to activate the digital input including a 1 mA safety margin.
P
COIL
=
U
U
R
MIN
MAX
COIL
=
=
=
50 W, Rated power of the open coil of the circuit breaker. If this value is not known, 0 Ω can be used for the R
COIL
.
U
AUX
- 20 % = 88 V
U
AUX
+ 10 % = 121 V
U
2
AUX
/ P
COIL
= 242 Ω.
The external resistance value is calculated using Equation 10.1.
Equation 10.1:
R
=
U
MIN
−
U
DI
−
I
DI
⋅
R
Coil
I
DI
R = (88 – 18 – 0.003 x 242)/0.003 = 23.1 kΩ
(In practice the coil resistance has no effect.)
By selecting the next smaller standard size we get 22 kΩ.
The power rating for the external resistor is estimated using
Equation 10.2 and Equation 10.3. The Equation 10.2 is for the CB
open situation including a 100 % safety margin to limit the maximum temperature of the resistor.
Equation 10.2:
P
= 2 ⋅
I
2
DI
⋅
R
P = 2 x 0.003
2 x 22000 = 0.40 W
Select the next bigger standard size, for example 0.5 W.
When the trip contacts are still closed and the CB is already open,
the resistor has to withstand much higher power (Equation 10.3) for
this short time.
Equation 10.3:
P
=
U
2
MAX
R
P = 121
2
/ 22000 = 0.67 W
193
10.2 Trip circuit supervision
10.2.2
10 Application
A 0.5 W resistor will be enough for this short time peak power, too.
However, if the trip relay is closed for longer time than a few seconds, a 1 W resistor should be used.
Trip circuit supervision with two digital inputs
The benefits of this scheme is that no external resistor is needed.
The drawbacks are, that two digital inputs from two separate groups are needed and two extra wires from the relay to the CB compartment is needed. Additionally the minimum allowed auxiliary voltage is 48
Vdc, which is more than twice the threshold voltage of the dry digital input, because when the CB is in open position, the two digital inputs are in series.
• The first digital input is connected parallel with the auxiliary contact of the open coil of the circuit breaker.
• Another auxiliary contact is connected in series with the circuitry of the first digital input. This makes it possible to supervise also the auxiliary contact in the trip circuit.
• The second digital input is connected in parallel with the trip contacts.
• Both inputs are configured as normal closed (NC).
• The user’s programmable logic is used to combine the digital input signals with an AND port. The delay is configured longer than maximum fault time to inhibit any superfluous trip circuit fault alarm when the trip contact is closed.
• The output from the logic is connected to a relay in the output matrix giving out any trip circuit alarm.
• Both digital inputs must have their own common potential.
Using the other digital inputs in the same group as the upper DI
in the Figure 10.8 is not possible in most applications. Using the
other digital inputs in the same group as the lower DI in the
Figure 10.8 is limited, because the whole group will be tied to
the auxiliary voltage V
AUX
.
194
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10 Application
10.2 Trip circuit supervision
V59/en M/A009
52b 52a
Figure 10.8: Trip circuit supervision with two digital inputs. The CB is closed. The supervised circuitry in this CB position is double-lined. The digital input is in active state when the trip circuit is complete.
195
10.2 Trip circuit supervision
10 Application
52b 52a
196
Figure 10.9: Trip circuit supervision with two digital inputs. The CB is in the open position. The two digital inputs are now in series.
Figure 10.10: An example of digital input configuration for trip circuit supervision with two dry digital inputs DI1 and DI2.
V59/en M/A009
10 Application
10.2 Trip circuit supervision
Figure 10.11: An example of logic configuration for trip circuit supervision with two dry digital inputs DI1 and DI2.
Figure 10.12: An example of output matrix configuration for trip circuit supervision with two digital inputs.
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197
11
11.1
11 Connections
Connections
Rear panel
X1
6
7
4
5
1
2
3
8
9
10
11
X2
1
2
Figure 11.1: Connections on the rear panel
2
1
4
3
6
5
8
7
X3
20
7
6
9
8
13
12
11
10
3
2
5
4
1
19
18
17
16
15
14
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198
11 Connections
Terminal X1
7
8
5
6
3
4
1
2
9
10
11
Terminal X2
1
2
8
9
6
7
2
3
4
5
No
1
10
11
Symbol
IL1(S1)
IL1(S2)
IL2(S1)
IL2(S2)
IL3(S1)
IL3(S2)
Io1
Io1/5A
Io1/1A
Uo
Uo
No
1
2
Symbol
U
AUX
U
AUX
11.1 Rear panel
Description
Phase current L1 (S1)
Phase current L1 (S2)
Phase current L2 (S1)
Phase current L2 (S2)
Phase current L3 (S1)
Phase current L3 (S2)
Residual current Io1 common for 1 A and 5 A (S1)
Residual current Io1 5A (S2)
Residual current Io1 1A (S2)
Zero sequence voltage Uo (Da)
Zero sequence voltage Uo (Da)
Description
Auxiliary voltage
Auxiliary voltage
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199
11.2 Auxiliary voltage
Terminal X3
20
19
18
17
16
15
4
3
6
5
2
1
10
9
8
7
14
13
12
11
11 Connections
5
4
7
6
9
8
11
10
3
2
1
15
14
13
12
No
20
19
18
17
16
T4
T4
A1 NC
A1 NO
A1 COM
DI2 +
DI2 -
DI1 +
T2
T2
T3
T3
Symbol
SF NO
SF NC
SF COM
T1
T1
DI1 mA out mA out +
Description
Internal fault relay, common connector
Internal fault relay, normal open connector
Internal fault relay, normal closed connector
Trip relay 1
Trip relay 1
Trip relay 2
Trip relay 2
Trip relay 3
Trip relay 3
Trip relay 4
Trip relay 4
Alarm relay 1, common connector
Alarm relay 1, normal open connector
Alarm relay 1, normal closed connector
Digital inputs
Digital inputs
Digital inputs
Digital inputs
Analogue output
Analogue output
11.2
Auxiliary voltage
The external auxiliary voltage U
AUX
(40 – 265 V ac or V dc, or optionally 18 – 36V dc) for the relay is connected to the pins X2: 1
– 2.
NOTE: When optional 18 – 36 Vdc power module is used the polarity is as
follows: X2:1 positive (+), X2:2 negative (-).
200
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11 Connections
11.3
11.4
11.4.1
11.3 Output relays
Output relays
The relay is equipped with 5 configurable output relays, and a separate output relay for the self-supervision system.
• Trip relays T1 – T4 (terminals X3: 10-17)
• Alarm relay A1 (terminals X3: 7-9)
• Self-supervision system output relay IF (terminals X3: 18-20)
Serial communication connection
The device can be equipped with optional communication module.
The physical location of the module is the lower option card slot at the back of the relay. The modules can be installed in the field (when power is first turned off).
There are three “logical communication ports” available in the relay:
REMOTE, LOCAL and EXTENSION. Depending on the module type one or more of these ports are physically available at the external connectors.
Front panel USB connector
2
3
1
4
Figure 11.2: Pin numbering of the front panel USB type B connector
Pin
1
2
3
4
Shell
Signal name
VBUS
D-
D+
GND
Shield
V59/en M/A009
201
11.4 Serial communication connection
11 Connections
11.4.2
Type
VCM 232+00
VCM 232+IR
VCM 232+FI
VCM 232+I62
VCM 232+L6
Pin assignments of the optional communication interface cards
The communication card types and their pin assignments are introduced in the following table.
Signal levels Connectors Pin usage Order code, Name Communication ports
LA REMOTE RS-232 D-connector 2 = TX_REM
RS-232 interface 3 = RX_REM
7 = GND
2-pole screw connector
9 = +12V
1= Data
2= GND
LB
RS-232 interface with timesyncronisation input
LC
CLOCK SYNC
(IRIG-B )
TTL
EXTENSION Light
RS-232 interface with RTD fiber optic interface
LE
RTD protocol must be selected for the port
Ethernet Ethernet 10Mbps
RS-232 interface with IEC 61850 interface
Snap-in connector
RJ-45
LG
RS-232 interface with IEC 61850
Ethernet fibre interface
Ethernet Light 100Mbps LC-connector
1=Transmit+
2=Transmit-
3=Receive+
4=Reserved
5=Reserved
6=Receive-
7=Reserved
8=Reserved
TX=Lower LC-connector
RX=Upper LC-connector
202
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11 Connections
11.5
11.5 Input/output card B = 4 x DI + 1 x DI/DO
Input/output card B = 4 x DI + 1 x DI/DO
The digital input/output option “B = 4 x DI + 1 x DI/DO" enables four more digital inputs and one optional digital input / output contact.
This card enables use of digital inputs DI3 – DI7. In case DI7 is not used as digital input then it can be used as additional output T5, but not simultaneously.
NOTE: Pay special attention when using DI7 (terminals numbers X6:1 –
X6:2) as digital input use. Never configure, operate or control T5 output if DI7 is used as an imput. Should the control of T5 happen the output contact will short-circuit DI7 and will lead to equipment damage and loss of data.
For this block information, please see Figure 11.5.
When this option card is installed to slot X6, the CARD INFO view indicates value “4DI + 1DO” for parameter “I/O card” in HMI and
VAMPSET. In case arc sensor card is chosen for slot X6 then this
I/O card cannot be used.
Digital inputs of the device can operate in three different voltage areas. It is also possible to select whether ac or dc –voltage is used.
Digital input threshold of the device is selected in the ordering code when the relay(s) are being ordered.
When 110 or 220 V ac voltage is used to activate the digital Inputs, the AC mode should be selected as shown in the screenshot below:
11.6
V59/en M/A009
Figure 11.3: AC mode selection in VAMPSET
Arc protection card C = Arc (2 x Arc sensor + BIO)
NOTE: When this option card is installed, the parameter "I/O" has value
"VOM Arc+BI". Please check the Chapter 14 Order information.
The optional arc protection card includes two arc sensor channels.
The arc sensors are connected to terminals X6: 5 – 6 and 7 – 8.
The arc information can be transmitted and/or received through digital input and output channels. This is a 48 V dc signal.
The arc option card is inserted in the upper option card slot in the back of the unit.
203
11.7 Arc protection card D = Advanced arc (3 x Arc sensor + BIO)
11.7
11 Connections
For this block information, please see Figure 11.6.
The arc information can be transmitted and/or received through digital input and output channels BIO. The output signal is 48 V dc when active. The input signal has to be 18 – 48 V dc to be activated.
The GND must be connected together between the GND of the connected devices.
The binary output of the arc option card may be activated by one or both of the connected arc sensors, or by the binary input. The connection between the inputs and the output is selectable via the output matrix of the device. The binary output can be connected to an arc binary input of another VAMP protection relay or arc protection system.
Arc protection card D = Advanced arc (3 x Arc sensor + BIO)
NOTE: When this option card is installed, the parameter "I/O" has value
"3S+1BI+1BO". Please check the Chapter 14 Order information.
The optional arc protection card includes two arc sensor channels.
The arc sensors are connected to terminals X6: 6 – 7, 8 – 9 and 10
– 11.
The arc information can be transmitted and/or received through digital input and output channels. This is a 48 V dc signal.
The arc option card is inserted in the upper option card slot in the back of the unit.
For this block information, please see Figure 11.7.
The arc information can be transmitted and/or received through digital input and output channels BIO. The output signal is 48 V dc when active. The input signal has to be 18 – 48 V dc to be activated.
The GND must be connected together between the GND of the connected devices.
The binary output of the arc option card may be activated by one or both of the connected arc sensors, or by the binary input. The connection between the inputs and the output is selectable via the output matrix of the device. The binary output can be connected to an arc binary input of another VAMP protection relay or arc protection system.
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204
11 Connections
11.8 External option modules
11.8
11.8.1
External option modules
Third-party external input / output modules
The device supports also external input / output modules used to extend the number of digital/analog inputs and outputs.
The following types of devices are supported:
• Analog input modules (RTD)
• Analog output modules (mA-output)
• Binary input/output modules
EXTENSION port is primarily designed for I/O modules. The relay must have a communication option card with EXTENSION port.
Depending of the option card I/O devices may require an adapter to be able to connect to the port (i.e. VSE004).
NOTE: If External I/O protocol is not selected to any communication port,
VAMPSET doesn’t display the menus required for configuring the
I/O devices. After changing EXTENSION port protocol to External
I/O, restart the relay and read all settings with VAMPSET.
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205
11.8 External option modules
11 Connections
Range
External analog inputs configuration (VAMPSET only)
X: -32000 – 32000
Y: -1000 – 1000
-
Description
Communication read errors
Scaling
Y2
Scaled value
-
X2
-
Y1
Modbus value
Scaled value
-
X1
-
Offset
Modbus value
Point 2
Point 1
-
Subtracted from Modbus value, before running XY scaling
-
Modbus register type
-
-32000 – 32000
-
InputR or HoldingR
-
-
1 – 9999
-
-
-
1 – 247
-
-
C, F, K, mA, Ohm or V/A
-
Modbus register for the measurement
-
-
Modbus address of the I/O device
-
On / Off
-
-
Unit selection
-
Active value
Enabling for measurement
206
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11 Connections
11.8 External option modules
-
Range
0 – 10000
-
-21x107 – +21x107
-
-
-
- / Alarm
Alarms for external analog inputs
-
Description
Hysteresis for alarm limits
-
Alarm >>
-
Limit setting
Alarm >
-
Active state
-
-
-
Limit setting
-
-21x107 – +21x107
-
-
-
- / Alarm
-
-
1 – 9999
-
1 – 247
On / Off
-
-
Active state
-
-
Active value
-
Modbus register for the measurement
-
-
Modbus address of the I/O device
-
Enabling for measurement
Analog input alarms have also matrix signals, “Ext. Aix Alarm1” and
“Ext. Aix Alarm2”.
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207
11.8 External option modules
11 Connections
Range
1 – 16
-
-
CoilS, InputS,
InputR or HoldingR
-
-
-
1 – 9999
External digital inputs configuration (VAMPSET only)
-
Description
-
Communication read errors
-
-
-
Bit number of Modbus register value
-
-
Modbus register type
-
1 – 247
-
-
0 / 1
-
On / Off
-
-
Modbus register for the measurement
-
-
-
-
-
Modbus address of the I/O device
Active state
-
Enabling for measurement
208
V59/en M/A009
11 Connections
11.8 External option modules
-
Range
-
-
1 – 9999
-
-
1 – 247
-
-
0 / 1
External digital outputs configuration (VAMPSET only)
-
Description
-
Communication errors
-
-
-
-
Modbus register for the measurement
-
-
-
-
-
-
-
-
Modbus address of the I/O device
-
Output state
-
Enabling for measurement
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209
11.8 External option modules
11 Connections
Range
External analog outputs configuration (VAMPSET only)
-32768 – +32767
(0 – 65535)
-
InputR or HoldingR
-
1 – 9999
-
1 – 247
0 – 42x108,
-21x108 – +21x108
-
-
-21x107 – +21x107
-
Description
Communication errors
-
-
Modbus value corresponding Linked Val. Max
-
-
Modbus value corresponding Linked Val. Min
-
-
Modbus register type
-
-
-
Modbus register for the output
-
-
Modbus address of the I/O device
-
-
Maximum limit for lined value, corresponding to “Modbus Max”
-
-
Minimum limit for lined value, corresponding to “Modbus Min”
-
-
Link selection
-
-
Minimum & maximum output values
On / Off
-
Active value
-
Enabling for measurement
210
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11 Connections
11.9 Block optional diagram
11.9
X2:1
X2:2
~
X1:1
X1:2
IL1
X1:3
X1:4
IL2
X1:5
X1:6
IL3
X1:7
X1:8
I
0
5A
1A
X1:9
X1:10
X1:11
U
0
*
I/O extension module
X6:1
X6:2
X6:3
X6:4
X6:5
X6:6
Arc option or
DI/DO module
X6:7
X6:8
Block optional diagram
VAMP 59
Protection functions
87L
Ldl>
Ldl>>
67N
I
0φ
>
I
0φ
>>
50/51
3I>
3I>>
3I>>>
59N
U
0
>
U
0
>>
46
I
2
>
49
T >
50N/51N
I
0
>, I
02
>
I
0
>>, I
02
>>
68F2
I f2
>
68F5
I f5
>
50ARC
ArcI>
50NARC
ArcI
0
>
Autorecloser matrix
79
Auto Reclose
Blocking and output matrix
X3:3 DI1 -
X3:4 DI1+
X3:5 DI2 -
X3:6 DI2+
DI
Front
Comm. option
Remote
T2
T3
T4
A1
X3:17
X3:16
X3:15
X3:14
X3:13
X3:12
X3:11
X3:10
X3:7
X3:9
X3:8
SF
X3:18
X3:19 mA out option
X3:20
X3:1 AO+
X3:2 AO -
mA
*
order option
I
0
1A
0.2A
V59/en M/A009
Figure 11.4: Block diagram of overcurrent and earthfault protection relay VAMP 59.
211
11.10 Block diagrams of optional modules
11.10
11 Connections
Block diagrams of optional modules
B = 4 x DI + 1 x DI/DO
X6:1 +DI7 / T5
X6:2 -DI7 / T5
X6:3 DI3
X6:4 COMM
X6:5 DI4
X6:6 DI5
X6:7 COMM
X6:8 DI6
Figure 11.5: Block diagram of optional module “B = Digital I/O; 4 x DI + 1 x DI/DO”
C = 2 x Arc sensor + BIO
A rc option
X6:1 BO+
X6:2 BO-
X6:3 BI+
X6:4 BI-
X6:5 L1 +
X6:6 L1 -
X6:7 L2+
X6:8 L2-
BI/ O
L>
Figure 11.6: Block diagram of optional arc protection card C = Arc (2 x Arc sensor
+ BIO)
212
V59/en M/A009
11 Connections
11.10 Block diagrams of optional modules
D = 3 x Arc sensor + BIO
Arc option
X6:1
X6:2
X6:3
X6:4
X6:5
BO1+
BO1-
BI1+
BI1n/a
BI/O
X6:6
X6:7
X6:8
X6:9
X6:10
X6:11
S1
S1
S2
S2
S3
S3
L>
Figure 11.7: Block diagram of advanced optional arc protection card D = Advanced
Arc (3 x Arc sensor + BIO)
V59/en M/A009
213
11.11 Connection examples
Connection examples 11.11
L1
L2
L3
+ dn da
X2:1
X2:2
~
U
0
X1:1
X1:2
X1:3
X1:4
X1:5
X1:6
IL1
IL2
IL3
X1:7
X1:8
X1:9
I
0 5A
1A
X1:10
X1:11 U
0
/U
L1
/U
12
*
I/O extension module
X6:1
X6:2
X6:3
X6:4
X6:5
X6:6
X6:7
X6:8
Arc option or
DI / DO module
X3:3 DI1 -
X3:4 DI1 +
X3:5 DI2 -
X3:6 DI2 +
DI
11 Connections
1
-
Front
Comm. option
Remote
-
0
T2
T3
T4
A1
X3:17
X3:16
X3:15
X3:14
X3:13
X3:12
X3:11
X3:10
X3:7
X3:9
X3:8
+
+
SF
X3:18
X3:19 mA out option
X3:20
X3:1 AO+
X3:2 AO-
mA
Figure 11.8: Block diagram of overcurrent and earthfault protection relay VAMP 59.
214
V59/en M/A009
12 Technical data
12
12.1
V59/en M/A009
Technical data
Connections
Table 12.1: Measuring circuits
Phase current inputs
-
Rated phase current
- Current measuring range
-
- Thermal withstand
-
- Burden
- Impedance
I
0 input (5 A)
Rated residual current
-
-
- Current measuring range
- Thermal withstand
- Burden
- Impedance
I
0 input (1 A)
Rated residual current
-
-
- Current measuring range
- Thermal withstand
- Burden
- Impedance
I
0 input (0.2 A)
Rated residual current
-
-
- Current measuring range
- Thermal withstand
- Burden
- Impedance
5 A (configurable for CT secondaries 1 – 10 A)
0.05 – 250 A
20 A (continuously)
100 A (for 10 s)
500 A (for 1 s)
0.075 VA
-
0.003 Ohm
5 A (configurable for CT secondaries 0.1 – 10 A)
0.015 – 50 A
20 A (continuously)
100 A (for 10 s)
500 A (for 1 s)
0.075 VA
-
0.003 Ohm
1 A (configurable for CT secondaries 0.1 – 10.0 A)
0.003 – 10 A
4 A (continuously)
20 A (for 10 s)
100 A (for 1 s)
0.02 VA
-
0.02 Ohm
0.2 A (configurable for CT secondaries 0.1 – 10.0 A)
0.0006 – 2 A
0.8 A (continuously)
4 A (for 10 s)
20 A (for 1 s)
0.02 VA
0.02 Ohm
215
12.1 Connections
12 Technical data
Frequency
Rated frequency f
N
Measuring range
-
45 – 65 Hz (protection operates accurately)
16 – 95 Hz
< 44Hz / > 66Hz (other protection is not steady except frequency protection)
Table 12.2: Auxiliary voltage
Rated voltage U
AUX
Start-up peak (DC)
24 V (Type B)
-
110 V (Type A)
220 V (Type A)
Power consumption
Max. permitted interruption time
Terminal block:
- Phoenix MVSTBW or equivalent
Type A (standard)
40 – 265 V ac/dc
Type B (option)
18 – 36 V dc
Note! Polarity
X2:1= positive (+)
X2:2= negative (-)
-
25 A with time constant of 1000 µs
15 A with time constant of 500 µs
25 A with time constant of 750 µs
< 15 W (normal conditions)
< 25 W (output relays activated)
< 50 ms (110 V dc)
Maximum wire dimension:
2.5 mm
2
(13 – 14 AWG)
Table 12.3: Digital inputs internal operating voltage
Number of inputs
Voltage withstand
External operating voltage, threshold
2
265 V ac/dc
1: 24 – 230 V ac/dc (max. 265 V ac/dc)
2: 110 – 230 V ac/dc (max. 265 V ac/dc)
Typical switching threshold
Current drain
Activation time dc/ac
Reset time dc/ac
Terminal block:
- MSTB2.5 – 5.08
3: 220 – 230 V ac/dc (max. 265 V ac/dc)
1: 12 V dc
2: 75 V dc
3: 155 V dc approx. 3 mA
< 11 ms / < 15 ms
< 11 ms / < 15 ms
Maximum wire dimension:
2.5 mm
2
(13 – 14 AWG)
NOTE: set dc/ac mode according to the used voltage in VAMPSET.
216
V59/en M/A009
12 Technical data
12.1 Connections
Table 12.4: Trip contact, Tx
Number of contacts
Rated voltage
Continuous carry
Make and carry, 0.5 s
Make and carry, 3s
4 making contacts (relays T1, T2, T3, T4)
250 V ac/dc
5 A
30 A
15 A
Breaking capacity, DC (L/R=40ms) at 48 V dc: at 110 V dc: at 220 V dc:
Contact material
Terminal block:
- MSTB2.5 - 5.08
1.15 A
0.5 A
0.25 A
AgNi 90/10
Wire dimension:
Maximum 2.5 mm
2
(13 – 14 AWG)
Minimum 1.5 mm
2
(15 – 16 AWG)
Table 12.5: Signal contacts
Number of contacts:
Rated voltage
Continuous carry
Breaking capacity, DC (L/R=40ms) at 48 V dc: at 110 V dc: at 220 V dc:
2 change-over contacts (relays A1 and SF)
250 V ac/dc
5 A
1 A
0.3 A
0.15 A
Contact material
Terminal block
- MSTB2.5 - 5.08
AgNi 0.15 gold plated
Wire dimension
Maximum 2.5 mm
2
(13 – 14 AWG)
Minimum 1.5 mm
2
(15 – 16 AWG)
Table 12.6: Local serial communication port
Number of ports 1 on front
Electrical connection
Data transfer rate
USB
2 400 – 187 500 kb/s
V59/en M/A009
217
12.1 Connections
Table 12.7: Remote control connection (option)
Number of ports
Electrical connection
1 option slot on rear panel
RS 232
Protocols
Glass fibre connection
Ethernet 10 Base-T
IEC 60870-5-101
IEC 60870-5-101 TCP
DNP 3.0
DNP 3.0 TCP
IEC 61850
Ethernet IP
ANSI 85 (RS 232)
Table 12.8: Analogue output connection (option)
Number of analogue mA output channels
Maximum output current
Minimum output current
Exception output current
Resolution
Current step
Inaccuracy
Response time
1
-
1 – 20 mA, step 1 mA
0 – 19 mA, step 1 mA
0 – 20.50 mA, step 25 µA
10 bit
< 25 µA
±80 µA
- normal mode
- fast mode
Burden
< 400 ms
< 50 ms
< 600 Ω
Table 12.9: Ethernet fiber interface
Type
Connector
Multimode
LC for single FO Ethernet
Physical layer
Maximum cable distance
Optical wavelength
Cable core / cladding size
ST for double FO Ethernet
100 Base-Fx
2 km
1300 nm
50/125 or 62.5/125 μm
12 Technical data
218
V59/en M/A009
12 Technical data
12.2 Test and environmental conditions
12.2
Test and environmental conditions
Test
Emission
- Conducted
- Emitted
Immunity
- 1Mhz damped oscillatory wave
- Static discharge (ESD)
- Emitted HF field
- Fast transients (EFT)
- Surge
Table 12.10: Disturbance tests
Standard & Test class / level
EN 61000-6-4 / IEC 60255-26
EN 61000-6-2 / IEC 60255-26
IEC 60255-22-1
Test value
EN 55011, Class A / IEC 60255-25 0.01 – 30 MHz
EN 55011, Class A / IEC 60255-25 / CISPR 11 30 – 1000 MHz
±2.5kVp CM, ±1.0kVp DM
EN 61000-4-2 Level 4 / IEC 60255-22-2 Class
4
EN 61000-4-3 Level 3 / IEC 60255-22-3
±8 kV contact, ±15 kV air
EN 61000-4-5 Level 3 / IEC 60255-22-5
80 - 2700 MHz, 10 V/m
EN 61000-4-4 Level 4 / 3 / IEC 60255-22-4 Class
A
4 kV / Signal ports 2.0 kV , 5/50 ns,
5 kHz
2 kV, 1.2/50 µs, CM
- Conducted HF field
- Power-frequency magnetic field
- Pulse magnetic field
- Voltage dips
- Voltage short interruptions
- Voltage alternative component
EN 61000-4-6 Level 3 / IEC 60255-22-6
EN 61000-4-8
EN 61000-4-9 Level 5
EN 61000-4-29 / IEC 60255-11
EN 61000-4-11
EN 61000-4-17 / IEC 60255-11
1 kV, 1.2/50 µs, DM
0.15 - 80 MHz, 10 Vemf
300A/m (continuous), 1000A/m 1-
3s
1000A/m, 1.2/50 µs
30%/1s, 60%/0.1s, 100%/0.01s
30%/10ms, 100%/10ms,
60%/100ms, 95%/5000ms
12% of operating voltage (DC) /
10min
Test
- Impulse voltage withstand
- Dielectric test
Table 12.11: Electrical safety tests
Standard & Test class / level
EN 60255-5, Class III
EN 60255-5, Class III
Test value
5 kV, 1.2/50 ms, 0.5 J
1 kV, 1.2/50 ms, 0.5 J Communication
2 kV, 50 Hz
0.5 kV, 50 Hz Communication
- Insulation resistance
- Protective bonding resistance
- Power supply burden
EN 60255-5
EN 60255-27
IEC 60255-1
Table 12.12: Mechanical tests
Standard & Test class / level Test
Device in operation
- Vibrations
- Shocks
Test value
IEC 60255-21-1, Class II / IEC 60068-2-6, Fc 1Gn, 10Hz – 150 HZ
IEC 60255-21-2, Class II / IEC 60068-2-27, Ea 10Gn/11ms
Device de-energized
- Vibrations
- Shocks
- Bump
V59/en M/A009
IEC 60255-21-1, Class II / IEC 60068-2-6, Fc 2Gn, 10Hz – 150 HZ
IEC 60255-21-2, Class II / IEC 60068-2-27, Ea 30Gn/11ms
IEC 60255-21-2, Class II / IEC 60068-2-27, Ea 20Gn/16ms
219
12.2 Test and environmental conditions
12 Technical data
Test
Device in operation
- Dry heat
- Cold
- Damp heat, cyclic
- Damp heat, static
Table 12.13: Environmental tests
Standard & Test class / level
EN / IEC 60068-2-2, Bd
EN / IEC 60068-2-1, Ad
EN / IEC 60068-2-30, Db
EN / IEC 60068-2-78, Cab
Flowing mixed gas corrosion test, method 2
IEC 60068-2-60, Ke
Flowing mixed gas corrosion test, method 4
IEC 60068-2-60, Ke
Test value
Device in storage
- Dry heat
- Cold
EN / IEC 60068-2-2, Bb
EN / IEC 60068-2-1, Ab
Ambient temperature, in-service
Ambient temperature, storage
Relative air humidity
Maximum operating altitude
Table 12.14: Environmental conditions
-40 – 65°C (-40 – 149°F)
-40 – 70°C (-40 – 158°F)
< 95%, no condensation allowed
2000 m (6561.68 ft)
Degree of protection (IEC 60529)
Dimensions (w x h x d):
Material
Weight
Colour code
Table 12.15: Casing
IP54 front panel, IP 20 rear panel
130 x 170 x 210 mm / 5.12 x 6.69 x 8.27 in
1 mm (0.039 in) steel plate
2.0 kg (4.415 lb)
RAL 7032 (Casing) / RAL 7035 (Back plate)
Dimensions (W x H x D)
Weight (Terminal, Package and
Manual)
Table 12.16: Package
230 x 215 x 175 mm / 9.06 x 8.46 x 6.89 in
3.0 kg (6.623 lb)
75°C (167°F)
-40°C (-40°F)
•
•
65°C (149°F)
-40°C (-40°F)
• From 25°C (77°F) to 55°C
(131°F)
From 93% RH to 98% RH
Testing duration: 6 days
•
•
•
40°C (104°F)
93% RH
Testing duration: 10 days
25°C (77°F), 75% RH,
10 ppb H
2
S, 200 ppb NO
2
,
10 ppb CL
2
25°C (77°F), 75% RH,
10 ppb H
2
S, 200 ppb NO
2
,
10 ppb CL
2
, 200 ppb SO
2
220
V59/en M/A009
12 Technical data
12.3 Protection functions
12.3
12.3.1
Protection functions
*) EI = Extremely Inverse, NI = Normal Inverse, VI = Very Inverse, LTI = Long Time Inverse,
MI= Moderately Inverse
**) This is the instantaneous time i.e. the minimum total operational time including the fault detection time and operation time of the trip contacts.
Differential protection
Table 12.17: Line differential protection LdI> (87L)
I
Pick-Up
Start of slope 1
Slope 1
Start of slope 2
Slope 2
Second harmonic blocking
20 – 50 %
0.5 – 1.0 x I
N
0 – 100 %
1.0 – 3.0 x I
N
50 – 200 %
5 – 30 % I
N
(step 1%)
Fifth harmonic blocking
Reset time
20 – 50 % I
N
(step 1%)
< 95 ms
Reset ratio: 0.95
Inaccuracy:
- 2nd harmonic blocking
- 5th harmonic blocking
- Starting
- Operating time (3.5 x I
SET
)
±1% - unit
±1% - unit
±5% of set value or 0.05 x IN when currents are > 200 mA typically 35 ms
NOTE:
The amplitude of second harmonic content has to be at least 2% of the nominal of CT. If the nominal current is 5 A, the 100 Hz component needs to exceed 100 mA.
Table 12.18: Differential overcurrent stage Ldl>> (87L)
Setting range
Second harmonic blocking
1.2 – 20.0 x I
N
(step 0.1)
5 – 30 % I
N
(step 1%)
Fifth harmonic blocking
Inaccuracy: -
20 – 50 % I
N
(step 1%)
- 2nd harmonic blocking
- 5th harmonic blocking
- Starting
- Operating time (3.5 x I
SET
)
±1% - unit
±1% - unit
±5% of the set value typically 35 ms
V59/en M/A009
221
12.3 Protection functions
12.3.2
12 Technical data
Table 12.19: Transformer settings (scaling menu)
Connection group None (no transformer)
Transformer side
Transformer grounding:
- I
0 compensation
- I’
0 compensation
Yy0, Yy6, Yd1, Yd5, Yd7, Yd11, Dy1, Dy5,
Dy7, Dy11, Dd0 and Dd6
HV (relay located on high voltage side)
-
LV (relay located on low voltage side) enabled or disabled depending whether starpoint is grounded or not
Non-directional current protection
Table 12.20: Overcurrent stage I> (50/51)
Pick-up value
Definite time function:
0.10 – 5.00 x I
N
(step 0.01)
DT
**
- Operating time 0.04 – 300.00 s (step 0.01 s)
IDMT function:
- Delay curve family
- Curve type
- Time multiplier k
Start time
Reset time
Retardation time
Reset ratio:
Transient over-reach, any τ
Inaccuracy:
- Starting
- Operating time at definite time function
- Operating time at IDMT function
(DT), IEC, IEEE, RI Prg
EI, VI, NI, LTI, MI…, depends on the family
*
0.05 – 20.0, except
0.50 – 20.0 for RXIDG, IEEE and IEEE2
Typically 30 ms
<95 ms
< 50 ms
0.97
< 10 %
±3% of the set value or 5 mA secondary
±1% or ±25 ms
±5% or at least ±25 ms
**
222
V59/en M/A009
12 Technical data
12.3 Protection functions
Table 12.21: Overcurrent stage I>> (50/51)
Pick-up value
Definite time function:
0.10 – 20.00 x I
N
(step 0.01)
DT
**
Operating time
Start time
Reset time
Retardation time
Reset ratio:
Transient over-reach, any τ
Inaccuracy:
- Starting
- Operation time
0.04 – 1800.00 s (step 0.01 s)
Typically 30 ms
<95 ms
< 50 ms
-
0.97
< 10 %
±3% of the set value or 5 mA secondary
±1% or ±25 ms
Table 12.22: Overcurrent stages I>>> (50/51)
Pick-up value
Definite time function:
0.10 – 40.00 x I
N
(step 0.01)
DT
**
Operating time
Instant operation time:
I
M
/ I
SET ratio > 1.5
I
M
/ I
SET ratio 1.03 – 1.5
Start time
Reset time
Retardation time
Reset ratio:
-
0.03 – 300.00 s (step 0.01 s)
<30 ms
< 50 ms
Typically 20 ms
<95 ms
< 50 ms
0.97
Inaccuracy:
- Starting ±3% of the set value or 5 mA secondary
- Operation time DT (I
M
/I
SET ratio > 1.5) ±1% or ±15 ms
- Operation time DT (I
M
/I
SET ratio 1.03 – 1.5) ±1% or ±25 ms
Table 12.23: Thermal overload stage T> (49)
Maximum continuous current:
Alarm setting range:
Time constant Tau:
Cooling time coefficient:
Max. overload at +40°C
Max. overload at +70°C
Ambient temperature
Resetting ratio (Start & trip)
Accuracy:
0.1 – 2.40 x I
N
(step 0.01)
60 – 99 % (step 1%)
2 – 180 min (step 1)
1.0 – 10.0 x Tau (step 0.1)
70 – 120 %I
MODE
(step 1)
50 – 100 %I
MODE
(step 1)
-55 – 125°C (step 1°)
-
0.95
- Operating time ±5% or ±1 s
V59/en M/A009
223
12.3 Protection functions
12 Technical data
Table 12.24: Current unbalance stage I
2
/I
1
> (46)
Settings: -
- Setting range I
2
/ I
1
>
Definite time function:
- Operating time
Start time
Reset time
Reset ratio:
Inaccuracy:
- Starting
- Operate time
-
2 – 70% (step 1%)
-
1.0 – 600.0 s (step 0.1 s)
Typically 300 ms
< 450 ms
0.95
±1% - unit
±5% or ±200 ms
Table 12.25: Earth fault stage I
0
> (50N/51N)
Input signal I
0
(input X1:7 – 8 or input X1:7 – 9)
Pick-up value
Definite time function:
I
0Calc
(= I
L1
+ I
L2
+ I
L3
)
0.005 – 8.00 pu (when I
0
) (step 0.001)
0.05 – 20.0 pu (when I
0Calc
)
DT
**
- Operating time 0.04
** – 300.00 s (step 0.01 s)
IDMT function:
- Delay curve family
- Curve type
- Time multiplier k
Start time
Reset time
Reset ratio:
Inaccuracy:
- Starting
(DT), IEC, IEEE, RI Prg
EI, VI, NI, LTI, MI..., depends on the family
*
0.05 – 20.0, except
0.50 – 20.0 for RXIDG, IEEE and IEEE2
Typically 30 ms
<95 ms
0.95
- Starting (Peak mode)
- Operating time at definite time function
- Operating time at IDMT function
±2% of the set value or ±0.3% of the rated value
±5% of the set value or ±2% of the rated value (Sine wave <65 Hz)
±1% or ±25 ms
±5% or at least ±25 ms **
224
V59/en M/A009
12 Technical data
12.3 Protection functions
Table 12.26: Earth fault stages I
0
>>, I
0
>>>, I
0
>>>> (50N/51N)
Input signal I
0
(input X1:7 – 8 or input X1:7 – 9)
Pick-up value
Definite time function:
I
0Calc
(= I
L1
+ I
L2
+ I
L3
)
0.01 – 8.00 pu (When I
0
) (step 0.01)
-
0.05 – 20.0 pu (When I
0Calc
) (step 0.01)
- Operating time
Start time
Reset time
Reset ratio:
0.04
**
– 300.00 s (step 0.01 s)
Typically 30 ms
<95 ms
0.95
Inaccuracy:
- Starting
- Starting (Peak mode)
- Operate time
±2% of the set value or ±0.3% of the rated value
±5% of the set value or ±2% of the rated value (Sine wave <65 Hz)
±1% or ±25 ms
V59/en M/A009
225
12.3 Protection functions
12.3.3
12.3.4
226
12 Technical data
Directional current protection
Table 12.27: Directional earth fault stages I
0φ
>, I
0φ
>> (67N)
Pick-up value 0.005 – 20.00 x I
0N than I
0Calc
)
(up to 8.00 for inputs other
Start voltage
Input signal
1 – 50 %U
0N
(step 1%)
I
0
(input X1:7 – 8 or X1:7 – 9)
Mode
Base angle setting range
Operation angle
Definite time function: -
I
0Calc
(= I
L1
+ I
L2
+ I
L3
)
Non-directional/Sector/ResCap
-180° – 179°
±88°
- Operating time 0.10
**
– 300.00 s (step 0.02 s)
IDMT function:
- Delay curve family
- Curve type
- Time multiplier k
(DT), IEC, IEEE, RI Prg
EI, VI, NI, LTI, MI…, depends on the family
*
0.05 – 20.0, except
0.50 – 20.0 for RI, IEEE and IEEE2
Start time
Reset time
Reset ratio:
Reset ratio (angle)
Typically 60 ms
<95 ms
0.95
2°
Inaccuracy:
- Starting U
0
& I
0
(rated value In= 1 – 5A) ±3% of the set value or ±0.3% of the rated value
- Starting U
0
& I
0
(Peak Mode when, rated value I
0n
= 1 – 10A)
±5% of the set value or ±2% of the rated value
(Sine wave <65 Hz)
- Starting U
0
& I
0
(I
0Calc
) ±3% of the set value or ±0.5% of the rated value
- Angle ±2° when U> 1V and I
0
> 5% of I
0N or > 50 mA
- Operate time at definite time function
- Operate time at IDMT function else ±20°
±1% or ±30 ms
±5% or at least ±30 ms **
Circuit-breaker failure protection CBFP (50BF)
Table 12.28: Circuit-breaker failure protection CBFP (50BF)
Relay to be supervised
Definite time function: -
T1, T2, T3 and T4
- Operating time
Inaccuracy -
0.1
**
– 10.0 s (step 0.1 s)
- Operating time ±100 ms
V59/en M/A009
12 Technical data
12.3 Protection functions
12.3.5
12.3.6
Magnetising inrush 68F2
Table 12.29: Magnetising inrush 68F2
Settings: -
- Pick-up value
- Operating time
Inaccuracy:
- Starting
10 – 100 % (step 1%)
-
0.03 – 300.00 s (step 0.01 s)
±1% - unit
NOTE:
The amplitude of second harmonic content has to be at least 2% of the nominal of CT. If the moninal current is 5 A, the 100 Hz component needs to exceed 100 mA.
Over exicitation 68F5
Table 12.30: Over exicitation 68F5
Settings:
- Setting range over exicitation
- Operating time
Inaccuracy:
- Starting
-
10 – 100 % (step 1%)
-
0.03 – 300.00 s (step 0.01 s)
±2%- unit
NOTE:
The amplitude of fifth harmonic content has to be at least 2% of the nominal of
CT. If the moninal current is 5 A, the 250 Hz component needs to exceed 100 mA.
V59/en M/A009
227
12.3 Protection functions
12 Technical data
12.3.7
Digital input / output card (option)
Table 12.31: Digital input / output card (option)
Number of digital inputs 4 (5)
External operating voltage Voltage selectable in order code (same as
DI nominal voltage for the relay):
Current drain, when active
Number of digital outputs
Voltage withstand
Continuous carry
Make and carry 0.5 s
Make and carry 3 s
Breaking capacity. DC ( L/R = 40 ms) at 48 V dc: at 110 V dc: at 220 V dc:
Terminal block
Phoenix MVSTBW or equivalent
5 A
30 A
-
15 A
1: 24 dc/ac (max 265 V)*
2: 110 dc/ac (max 265 V)*
3: 220 dc/ac (max 265 V)*
Approx. 3 mA
(1)
265 V dc/ac
1.0 A
0.44 A
0.22 A
Maximum wire dimension:
2.5 mm2 (13 – 14 awg)
* set dc/ac mode according to the used voltage in VAMPSET.
NOTE:
Approximately 2 mA of current is going trough the T5 (X6:1 & X6:2) circuit even when used as a digital output. This has to be noticed when T5 is used with certain type of applications (if 2 mA is enough to control for example a breaker).
When DI/DO-option cards are ordered separately the threshold has to be modified
manually on field according the description in the manual (see Chapter 11.5
Input/output card B = 4 x DI + 1 x DI/DO).
228
V59/en M/A009
12 Technical data
12.3.8
12.3 Protection functions
Arc fault protection (option)
1. 2S+BIO
The operation of the arc protection depends on the setting value of the ArcI> and ArcI
0
> current limits.
The arc current limits cannot be set, unless the relay is provided with the optional arc protection card.
Table 12.32: Arc protection stage ArcI> (50ARC), ArcI
0
> (50NARC)
Pick-up value 0.5 – 10.0 x I
N
Arc sensor connection: S1, S2, S1/S2, BI, S1/BI, S2/BI, S1/S2/BI
- Operating time (Light only) 13 ms
- Operating time (4 x I
SET
+ light)
- Operating time (BIN)
- Operating time (Delayed Arc L>)
- BO operating time
Reset time
Reset time (Delayed ARC L)
Reset time (BO)
Reset ratio:
Inaccuracy:
- Starting
- Operating time
- Delayed ARC light
17ms
10 ms
0.01 – 0.15 s
< 3 ms
<95 ms
<120 ms
-
< 85 ms
0.90
10% of the set value
±5 ms
±10 ms
2. 3S+BIO
The operation of the arc protection depends on the setting value of the I>int and I
0
>int current limits.
The arc current limits cannot be set, unless the relay is provided with the optional arc protection card.
Table 12.33: Advanced arc protection stage
Pick-up value
Arc sensor connection:
0.5 – 10.0 x I
N for I>
0.1 – 5.0 x I
N for I
0
>
S1, S2, S3, BI, GOOSE
- Operating time
Inaccuracy:
- Under nominal current
- Over nominal current
-
7 ms
2.5% of nominal
2.5% of measurement
V59/en M/A009
229
12.4 Supporting functions
12.4
12 Technical data
Supporting functions
**) This is the instantaneous time i.e. the minimum total operational time including the fault detection time and operation time of the trip contacts.
Table 12.34: Disturbance recorder (DR)
Mode of recording Saturated / Overflow
Sample rate:
- Waveform recording
- Trend curve recording
Recording time (one record)
Pre-trigger rate
Number of selected channels
32/cycle, 16/cycle, 8/cycle
10, 20, 200 ms
1, 5, 10, 15, 30 s
1 min
0.1 s – 12 000 min (According recorder setting)
0 – 100%
0 – 12
The recording time and the number of records depend on the time setting and the number of selected channels.
Table 12.35: Inrush current detection
Cold load settings: -
- Idle current
- Pickup current
- Maximum time
Inrush settings:
0.01 – 0.50 x I
N
0.30 – 10.00 x I
N
-
0.01
** – 300.00 s (step 0.01 s)
- Pickup for 2nd harmonic 0 – 99 %
Table 12.36: Current transformer supervision
I
MAX
> setting
I
MIN
< setting
Definite time function:
0.00 – 10.00 x I
N
(step 0.01)
0.00 – 10.00 x I
N
(step 0.01)
DT
- Operating time
Reset time
Reset ratio I
MAX
>
Reset ratio I
MIN
<
Inaccuracy:
- Activation
- Operating time at definite time function
0.04 – 600.00 s (step 0.02 s)
< 60 ms
0.97
-
1.03
±3% of the set value
±1% or ±30 ms
V59/en M/A009
230
13 Mounting
13 Mounting
PANEL MOUNTING VAMP 50 SERIES mm in
158
6.22
128
5.04
137
5.39
Vamp 50 series
OK
F1 F2
171
6.73
1
213
8.39
Vamp 5
0 serie s
OK
F1
F2
139
5.47
3
9.5
0.37
9.0
0.35
120
4.72
82
3.23
9.0
0.35
5.0
0.2
2
1.0-1
- 0
0
.39
>
20
0.79
80
3.15
Vamp
50 seri es
OK
F1
F2
186
7.32
Vamp 5
0 serie s
OK
F1
F2
Vamp 5
0 serie s
OK
F1
F2
V59/en M/A009
231
232
VAMP 50 SERIES (DEFAULT SIZE) WALL MOUNTING FRAME TYPE V50WAF
V50WAF
1
1a
1c
Vamp 5
2
OK
F1
F2
13 Mounting
1b mm in
2
32
1.26
185
7.28
121
4.76
32
1.26
120
4.72
OK
F1
F2
3
4
OK
F1
F2
OK
F1
F2
V59/en M/A009
14 Order information
14 Order information
When ordering, please state:
• Type designation:
• Quantity:
• Options (see respective ordering code):
V59
- Line Differential Protection Relay
Relay type
= Default
Phase current inputs [A]
3
= 1A / 5A
Earth-fault current input [A]
A
= 1A / 5A
B
= 0.2A /1A
Nominal Supply Voltage [V]
A
= Power A 48 - 230 V (40.. 265Vac/dc)
B
= Power B 24 V (18.. 36Vdc)
mA output option
A
= None
B
= mA output
DI nominal voltage
1
= 24 VDC / 110 VAC
2
= 110 VDC / 220VAC
3
= 220 VDC
Optional I/O extension modules
A
= None (***
B
= 4xDI + 1xDI/DO
C
= Arc (2 x Arc sensor + BIO)
D
= Advanced arc (3 x Arc sensor + BIO)
Optional communication module 1
A
= None
L
= RS-232 remote port inteface and support for module 2
M
= RS-232 remote port interface with IRIG B and extension port and support for module 2
Optional communication module 2
A
= None
B
= IRIG-B time syncronisation input (*
C
= RTD interface (Glass fibre) (*
E
= RJ-45 10Mbps ethernet interface inc. IEC 61850 (*
G
= LC 100Mbps ethernet fibre interface inc. IEC 61850 (*
Note:
(* Option available only with communication module 1: L and M
Note: (* Option available only with communication module 1: L and
M
V59/en M/A009
233
14 Order information
Accessories
Order code
VSE001GG
3P032
3P033
3P034
3P035
3P036
VX063
3P014
VX048
3P022
VX062
VX052-3
VX044
VIO 12 AA
VIO 12 AC
VIO 12 AD
VA 1 DA-6
VA 1 DA-20
V50WAF
Description
Fibre optic Interface Module (glass - glass)
WESTERMO ODW-720-F1
WESTERMO SLC20 (1310 nm)
WESTERMO SLC40 (1310 nm)
WESTERMO SLC80 (1550 nm)
WESTERMO SLC120 (1550 nm)
RS232 converter cable for WESTERMO ODW-720-F1
MOXA TCF-90
RS232 converter cable for MOXA TCF-90
MOXA TCF-142-S-ST
RS232 converter cable for MOXA TCF-142-S-ST
USB programming cable (VAMPSET)
Interface cable to VIO 12 (RTD module)
RTD Module, 12pcs RTD inputs, Optical Tx Communication (24-230
Vac/dc)
RTD/mA Module, 12pcs RTD inputs, PTC, mA inputs/outputs, RS232,
RS485 and Optical Tx/Rx Communication (24 Vdc)
RTD/mA Module, 12pcs RTD inputs, PTC, mA inputs/outputs, RS232,
RS485 and Optical Tx/Rx Communication (48-230 Vac/dc)
Arc sensor
Arc sensor
V50 wall assembly frame
Note
Max. distance 1 km
(Base module)
Max. distance 20 km
Max. distance 40 km
Max. distance 80 km
Max. distance 120km
Cable length 3m
Max. distance 40 km
Cable length 3m
Max. distance 40 km
Cable length 3m
Cable length 3m
Cable length 2 m
Cable length 6 m
Cable length 20 m
234
V59/en M/A009
15 Firmware revision
15
10.xx
10.97
10.106
10.108
10.116
10.118
10.122
Firmware revision
Maximum rated power increased to 400000 kVA from 200000 kVA
Support for two instances of TCP protocols on Ethernet port
Virtual output events added
Ethernet/IP: mapping extensions (ExtDOs, ExtAOs and ExtAIs alarms)
“get/set” added to communication ports’ protocol lists
VTZsecondary VTysecondary added to scaling menu
Phasor diagrams added for synchrocheck
First version for VAMP 59
Autoreclose:
• when two CB's are used and both closed, AR is blocked
• start counter is not increased after manual CB close
2nd harmonic blocking stage added
5th harmonic blocking stage added
Intermediate transformer parameters added to HMI
LdI>> hysteresis changed from 5% to 3%
GOOSE supervision signals added
Automatic LED latch release added
Disturbance recorder full event added
Use of recorder memory in percents added
Various additions to IEC 61850
IP and other TCP parameters are able to change without reboot
Logic output numbering is not changed when changes are made in the logic
NOTE! Vampset version 2.2.97 required
Enable sending of analog data in GOOSE message
Day light saving (DST) rules added for system clock
HMI changes:
• Order of the first displays changed, 1.measurement, 2. mimic, 3. title
•
•
•
•
• timeout does not apply if the first 3 displays are active
Stages renamed:
I f2
> = MAGNETISING INRUSH 68F2
I f5
> = OVER EXCITATION 68F5
P< = DIRECTIONAL POWER 32
P<< = DIRECTIONAL POWER 32
V59/en M/A009
235
Customer Care Centre
http://www.schneider-electric.com/CCC
Schneider Electric
35 rue Joseph Monier
92506 Rueil-Malmaison
FRANCE
Phone: +33 (0) 1 41 29 70 00
Fax: +33 (0) 1 41 29 71 00 www.schneider-electric.com/vamp-protection
Publication version: V59/en M/A009
Publishing: Schneider Electric
02/2017
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