8-06-2_p741-743_tech-man

MiCOM P740

Numerical Busbar Protection

Technical Manual

P740/EN T/D11

Technical Manual P740/EN T/D11 Content MiCOM P740 Page 1/2

NUMERICAL BUSBAR PROTECTION MiCOM P740

CONTENTS

Safety Section

Introduction P740/EN IT/D11

Hardware Description P740/EN HW/D11

Functional Description P740/EN FT/D11

Application Notes P740/EN AP/D11

Technical Data P740/EN TD/D11

Installation P740/EN IN/D11

Commissioning & Maintenance P740/EN CM/D11

Problem Analysis P740/EN PR/D11

Connection diagrams P740/EN CO/D11

Relay Menu Database P740/EN GC/D11

Menu Content Tables P740/EN HI/D11

Version Compatibility P740/EN VC/D11

P740/EN T/D11 Technical Manual Content Page 2/2 MiCOM P740

BLANK PAGE

Introduction P740/EN IT/D11 MiCOM P740

INTRODUCTION

P740/EN IT/D11 Introduction MiCOM P740

Introduction P740/EN IT/D11 MiCOM P740 Page 1/18

CONTENTS

1. INTRODUCTION TO MiCOM 3

2. INTRODUCTION TO MiCOM GUIDES 4

3. USER INTERFACES AND MENU STRUCTURE 6

3.1 Introduction to the relay 6

3.1.1 Front panel 6

3.1.2 Relay rear panel 7

3.2 Introduction to the user interfaces and settings options 10

3.3 Menu structure 11

3.3.1 Central Unit settings 12

3.3.2 Peripheral Units settings 12

3.4 Password protection 13

3.5 Relay configuration 13

3.6 Front panel user interface (keypad and LCD) 14

3.6.1 Default display and menu time-out 15

3.6.2 Menu navigation and setting browsing 15

3.6.3 Password entry 15

3.6.4 Reading and clearing of alarm messages and fault records 16

3.6.5 Setting changes 16

3.7 Front communication port user interface 17

P740/EN IT/D11 Introduction Page 2/18 MiCOM P740


1. INTRODUCTION TO MiCOM

MiCOM is a comprehensive solution capable of meeting all electricity supply requirements. It comprises a range of components, systems and services from AREVA.

Central to the MiCOM concept is flexibility.

MiCOM provides the ability to define an application solution and, through extensive communication capabilities, to integrate it with your power supply control system.

The components within MiCOM are:

P range protection relays;

C range control products;

M range measurement products for accurate metering and monitoring;

S range versatile PC support and substation control packages.

MiCOM products include extensive facilities for recording information on the state and behaviour of the power system using disturbance and fault records. They can also provide measurements of the system at regular intervals to a control centre enabling remote monitoring and control to take place.

For up-to-date information on any MiCOM product, visit our website:

www.areva-td.com

http://www.alstom.com/


2. INTRODUCTION TO MiCOM GUIDES

The guides provide a functional and technical description of the MiCOM protection relay and a comprehensive set of instructions for the relays use and application.

The Technical Manual is composed as follows:

Technical Guide, includes information on the application of the relay and a technical description of its features. It is mainly intended for protection engineers concerned with the selection and application of the relay for the protection of the power system.

Operation Guide, contains information on the installation and commissioning of the relay, and also a section on fault finding. This volume is intended for site engineers who are responsible for the installation, commissioning and maintenance of the relay.

The chapter content within the Technical Manual is summarised below:

Technical Guide

Handling of Electronic Equipment

Safety Section

P740/EN IT Introduction

A guide to the different user interfaces of the protection relay describing how to start using the relay.

P740/EN AP Application Notes (includes a copy of publication P740/EN BR)

Comprehensive and detailed description of the features of the relay including both the protection and non-protection element of the P740 scheme including circuit breaker fail element. Description of the other functions such as event and disturbance recording, fault location, programmable scheme logic and specific topology. This chapter includes a description of the current transformer requirements (saturation detection) and how to apply the settings to the relay.

P740/EN HW Hardware Description

Overview of the operation of the relays hardware. This chapter includes information on the self-checking features and diagnostics of the relay.

P740/EN FT Functional Description

Overview of the operation of the relays software.

P740/EN TD Technical Data

Technical data including setting ranges, accuracy limits, recommended operating conditions, ratings and performance data. Compliance with technical standards is quoted where appropriate.


P740/EN IN Installation (includes a copy of publication P740/EN BR)

Recommendations on unpacking, handling, inspection and storage of the relay. A guide to the mechanical and electrical installation of the relay is provided incorporating earthing recommendations.

P740/EN CM Commissioning and Maintenance

Instructions on how to commission the relay, comprising checks on the calibration and functionality of the relay. A general maintenance policy for the relay is outlined.

P740/EN PR Problem Analysis:

P740/EN GC Configuration / Mapping:

Listing of all of the settings contained within the relay together with a brief description of each.

P740/EN CO External Connection Diagrams

All external wiring connections to the relay.

P740/EN HI HMI/User Interface (menu content tables)

P740/EN VC Version compatibility

Hardware / Software Version History and Compatibility

Repair Form


3. USER INTERFACES AND MENU STRUCTURE

The settings and functions of the MiCOM protection relay can be accessed both from the front panel keypad and LCD, and via the front and rear communication ports. Information on each of these methods is given in this section to describe how to get started using the relay.

3.1 Introduction to the relay

3.1.1 Front panel

The front panel of the relay is shown in Figure 1, with the hinged covers at the top and bottom of the relay shown open. Extra physical protection for the front panel can be provided by an optional transparent front cover. With the cover in place read only access to the user interface is possible. Removal of the cover does not compromise the environmental withstand capability of the product, but allows access to the relay settings. When full access to the relay keypad is required, for editing the settings, the transparent cover can be unclipped and removed when the top and bottom covers are open. If the lower cover is secured with a wire seal, this will need to be removed. Using the side flanges of the transparent cover, pull the bottom edge away from the relay front panel until it is clear of the seal tab. The cover can then be moved vertically down to release the two fixing lugs from their recesses in the front panel.

User programablefunction LEDs

TRIP

ALARM

OUT OF SERVICE

HEALTHY

= CLEAR

= READ

= ENTER

SER N o

DIAG N o

Zn

Vx

Vn

V

V

1/5 A 50/60 Hz

SK 1 SK 2

Serial N° and *, V RatingsI Top cover

FixedfunctionLEDs

Bottomcover

Battery compartment Front comms port Download/monitor port

Keypad

LCD

P0103ENa

FIGURE 1: RELAY FRONT VIEW (example for MiCOM P742 40 TE)


The front panel of the relay includes the following, as indicated in Figure 1:

• a 16-character by 2-line alphanumeric liquid crystal display (LCD).

a 7-key keypad comprising 4 arrow keys ( !, ", # and $ ), an enter key ( %), a clear key ( & ), and a read key ( ' ).

12 LEDs; 4 fixed function LEDs on the left hand side of the front panel and 8 programmable function LEDs on the right hand side.

Under the top hinged cover:

the relay serial number, and the relays current and voltage rating information*.

Under the bottom hinged cover:

battery compartment to hold the 1/2 AA size battery which is used for memory back-up for the real time clock, event, fault and disturbance records.

a 9-pin female D-type front port for communication with a PC locally to the relay (up to 15m distance) via an RS232 serial data connection.

a 25-pin female D-type port providing internal signal monitoring and high speed local downloading of software and language text via a parallel data connection.

The fixed function LEDs on the left hand side of the front panel are used to indicate the following conditions:

Trip (Red) indicates that the relay has issued a trip signal. It is reset when the associated fault record is cleared from the front display. (Alternatively the trip LED can be configured to be self-resetting)*.

Alarm (Yellow) flashes to indicate that the relay has registered an alarm. This may be triggered by a fault, event or maintenance record. The LED will flash until the alarms have been accepted (read), after which the LED will change to constant illumination, and will extinguish when the alarms have been cleared.

Out of service (Yellow) indicates that the relays protection is unavailable.

Healthy (Green) indicates that the relay is in correct working order, and should be on at all times. It will be extinguished if the relays self-test facilities indicate that there is an error with the relays hardware or software. The state of the healthy LED is reflected by the watchdog contact at the back of the relay.

3.1.2 Relay rear panel

The rear panel of the relay is shown in Figure 2. All current and voltage signals, digital logic input signals and output contacts are connected at the rear of the relay. Also connected at the rear is the twisted pair wiring for the rear RS485 communication port, the IRIG-B time synchronising input and the optical fibre rear communication port which are both optional.


COPROCESSOR BOARD(Connexion to CU via optical fibre)

COPROCESSOR BOARD(Connexion to CU via optical fibre)

POWER SUPPLYPOWER SUPPLY

ANALOG INPUT MODULEANALOG INPUT MODULE

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Figure 2a: P742 - Relay rear view 40TE case

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POWER SUPPLYPOWER SUPPLYANALOG INPUTANALOG INPUT

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HI

P3711ENa

COPROCESSOR BOARD(connexion to CU via optic fibre)

COPROCESSOR BOARD(connexion to CU via optic fibre)

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Figure 2b: P743 - Relay rear view 60 TE


1 TO 8 COMMUNICATION BOARDS

OPTIONAL IRIG-B BOARD

CO-PROCESSOR BOARD

POWER SUPPLY MODULE

A B C D E F G HJ K L

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P3712ENa

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LOGICAL OUTPUT CONTACT BOARD

LOGICAL INPUT CONTACT BOARD

Figure 2c: P741 - Relay rear view 80 TE

Refer to the wiring diagram in Connection Diagrams Chapter (P740/EN CO) for complete connection details.


3.2 Introduction to the user interfaces and settings options

The relay has three user interfaces:

• the front panel user interface via the LCD and keypad.

• the front port which supports Courier communication.

The measurement information and relay settings which can be accessed from the three interfaces are summarised in Table 1.

Keypad/LCD

Courier

Display & modification of all settings

Digital I/O signal status

Display/extraction of measurements

Display/extraction of fault records

Extraction of disturbance records

Programmable scheme logic settings

Reset of fault & alarm records

Clear event & fault records

Time synchronisation

Control commands

TABLE 1


3.3 Menu structure

The relays menu is arranged in a tabular structure. Each setting in the menu is referred to as a cell, and each cell in the menu may be accessed by reference to a row and column address. The settings are arranged so that each column contains related settings, for example all of the disturbance recorder settings are contained within the same column. As shown in Figure 3, the top row of each column contains the heading which describes the settings contained within that column. Movement between the columns of the menu can only be made at the column heading level. A complete list of all of the menu settings is given in Configuration / Mapping Chapter of the manual.

Columndata

settings

Column header

Control & support Group 1 Group 2 Group 3 Group 4

Up to 4 protection setting groups

System data View records Overcurrent Earth fault Earth fault Earth fault Earth faultOvercurrent Overcurrent Overcurrent

P0106ENa

FIGURE 3: Px40 SERIES - MENU STRUCTURE

The menu content tables for P740 are fully described in HMI/User Interface Chapter.

All of the settings in the menu fall into one of three categories: protection settings, disturbance recorder settings, or control and support (C&S) settings. One of two different methods is used to change a setting depending on which category the setting falls into. Control and support settings are stored and used by the relay immediately after they are entered. For either protection settings or disturbance recorder settings, the relay stores the new setting values in a temporary scratchpad. It activates all the new settings together, but only after it has been confirmed that the new settings are to be adopted. This technique is employed to provide extra security, and so that several setting changes that are made within a group of protection settings will all take effect at the same time.


3.3.1 Central Unit settings

The central Unit settings include the following items: • system data • view records • measurements (1 & 2) • topology • PU configuration & status • date & time • configuration • record control • disturbance recorder • measurement setup • commission tests • opto setup • protection element settings*

• busbar element • input labels • output labels

3.3.2 Peripheral Units settings

The central Unit settings include the following items: • system data • view records • measurements • topology • CB condition • CB control • date & time • configuration • CT & VT ratios • record control • disturbance recorder • measurement setup • commission tests • CB monitor • opto setup • protection element settings*

• busbar element • backup phase O/C • backup earth O/C • CB fail • supervision • input labels • output labels

* There are four groups of protection settings, with each group containing the same setting cells. One group of protection settings is selected as the active group, and is used by the protection elements.


3.4 Password protection

The menu structure contains three levels of access. The level of access that is enabled determines which of the relays settings can be changed and is controlled by entry of two different passwords. The levels of access are summarised in Table 2.

Access level Operations enabled

Level 0 No password required Read access to all settings, alarms, event records and fault records

Level 1 Password 1 or 2 As level 0 plus: Control commands, e.g. circuit breaker open/close. Reset of fault and alarm conditions. Reset LEDs. Clearing of event and fault records.

Level 2

As level 1 plus:

Password 2 required

All other settings.

TABLE 2

Each of the two passwords are 4 characters of upper case text. The factory default for both passwords is AAAA. Each password is user-changeable once it has been correctly entered. Entry of the password is achieved either by a prompt when a setting change is attempted, or by moving to the Password cell in the System data column of the menu. The level of access is independently enabled for each interface, that is to say if level 2 access is enabled for the rear communication port, the front panel access will remain at level 0 unless the relevant password is entered at the front panel. The access level enabled by the password entry will time-out independently for each interface after a period of inactivity and revert to the default level. If the passwords are lost an emergency password can be supplied - contact AREVA with the relays serial number. The current level of access enabled for an interface can be determined by examining the 'Access level' cell in the 'System data' column, the access level for the front panel User Interface (UI), can also be found as one of the default display options.

The relay is supplied with a default access level of 2, such that no password is required to change any of the relay settings. It is also possible to set the default menu access level to either level 0 or level1, preventing write access to the relay settings without the correct password. The default menu access level is set in the Password control cell which is found in the System data column of the menu (note that this setting can only be changed when level 2 access is enabled).

3.5 Relay configuration

The relay is a multi-function device which supports numerous different protection, control and communication features. In order to simplify the setting of the relay, there is a configuration settings column which can be used to enable or disable many of the functions of the relay. The settings associated with any function that is disabled are made invisible, i.e. they are not shown in the menu. To disable a function change the relevant cell in the Configuration column from Enabled to Disabled.


The configuration column controls which of the four protection settings groups is selected as active through the Active settings cell. A protection setting group can also be disabled in the configuration column, provided it is not the present active group. Similarly, a disabled setting group cannot be set as the active group.

The column also allows all of the setting values in one group of protection settings to be copied to another group.

To do this firstly set the Copy from cell to the protection setting group to be copied, then set the Copy to cell to the protection group where the copy is to be placed. The copied settings are initially placed in the temporary scratchpad, and will only be used by the relay following confirmation.

To restore the default values to the settings in any protection settings group, set the Restore defaults cell to the relevant group number. Alternatively it is possible to set the Restore defaults cell to All settings to restore the default values to all of the relays settings, not just the protection groups settings. The default settings will initially be placed in the scratchpad and will only be used by the relay after they have been confirmed. Note that restoring defaults to all settings includes the rear communication port settings, which may result in communication via the rear port being disrupted if the new (default) settings do not match those of the master station.

3.6 Front panel user interface (keypad and LCD)

When the keypad is exposed it provides full access to the menu options of the relay, with the information displayed on the LCD.

The !, ", # and $ keys which are used for menu navigation and setting value changes include an auto-repeat function that comes into operation if any of these keys are held continually pressed. This can be used to speed up both setting value changes and menu navigation; the longer the key is held depressed, the faster the rate of change or movement becomes.

Systemfrequency

Date and time

3-phase voltage

Alarm messages

Other default displays

Column 1System data

Column 2View records

Column nGroup 4

Overcurrent

Data 1.1Language

Data 2.1Last record

Data 1.2Password

Data 2.2Time and date

Data 1.nPasswordlevel 2

Data 2.nC - A voltage

Data n.n

I> char angle

Data n.2

I>1 directional

Data n.1

I>1 function

Other settingcells in

column 1


column 2


column n

Other column headings

Note:The C key will returnto column headerfrom any menu cell

C

C

C

P0105ENa

FIGURE 4: Px40 SERIES - FRONT PANEL USER INTERFACE


3.6.1 Default display and menu time-out

The front panel menu has a selectable default display. The relay will time-out and return to the default display and turn the LCD backlight off after 15 minutes of keypad inactivity. If this happens any setting changes which have not been confirmed will be lost and the original setting values maintained.

The contents of the default display can be selected from the following options: 3-phase and neutral current, 3-phase voltage, power, system frequency, date and time, relay description, or a user-defined plant reference*. The default display is selected with the Default display cell of the Measuret setup column. Also, from the default display the different default display options can be scrolled through using the !and " keys. However the menu selected default display will be restored following the menu time-out elapsing. Whenever there is an uncleared alarm present in the relay (e.g. fault record, protection alarm, control alarm etc.) the default display will be replaced by:

Alarms/Faults Present

Entry to the menu structure of the relay is made from the default display and is not affected if the display is showing the Alarms/Faults present message.

3.6.2 Menu navigation and setting browsing

The menu can be browsed using the four arrow keys, following the structure shown in Figure 4. Thus, starting at the default display the # key will display the first column heading. To select the required column heading use the !and " keys. The setting data contained in the column can then be viewed by using the $ and # keys. It is possible to return to the column header either by holding the [up arrow symbol] key down or by a single press of the clear key &. It is only possible to move across columns at the column heading level. To return to the default display press the # key or the clear key & from any of the column headings. It is not possible to go straight to the default display from within one of the column cells using the auto-repeat facility of the # key, as the auto-repeat will stop at the column heading. To move to the default display, the # key must be released and pressed again.

3.6.3 Password entry

When entry of a password is required the following prompt will appear:

Enter password **** Level 1

Note: The password required to edit the setting is the prompt as shown above

A flashing cursor will indicate which character field of the password may be changed. Press the # and $ keys to vary each character between A and Z. To move between the character fields of the password, use the ( and " keys. The password is confirmed by pressing the enter key %. The display will revert to Enter Password if an incorrect password is entered. At this point a message will be displayed indicating whether a correct password has been entered and if so what level of access has been unlocked. If this level is sufficient to edit the selected setting


then the display will return to the setting page to allow the edit to continue. If the correct level of password has not been entered then the password prompt page will be returned to. To escape from this prompt press the clear key &. Alternatively, the password can be entered using the Password cell of the System data column.

For the front panel user interface the password protected access will revert to the default access level after a keypad inactivity time-out of 15 minutes. It is possible to manually reset the password protection to the default level by moving to the Password menu cell in the System data column and pressing the clear key & instead of entering a password.

3.6.4 Reading and clearing of alarm messages and fault records

The presence of one or more alarm messages will be indicated by the default display and by the yellow alarm LED flashing. The alarm messages can either be self-resetting or latched, in which case they must be cleared manually. To view the alarm messages press the read key '. When all alarms have been viewed, but not cleared, the alarm LED will change from flashing to constant illumination and the latest fault record will be displayed (if there is one). To scroll through the pages of this use the ' key. When all pages of the fault record have been viewed, the following prompt will appear:

Press clear to reset alarms

To clear all alarm messages press &; to return to the alarms/faults present display and leave the alarms uncleared, press '. Depending on the password configuration settings, it may be necessary to enter a password before the alarm messages can be cleared (see section on password entry). When the alarms have been cleared the yellow alarm LED will extinguish, as will the red trip LED if it was illuminated following a trip.

Alternatively it is possible to accelerate the procedure, once the alarm viewer has been entered using the ' key, the & key can be pressed, this will move the display straight to the fault record. Pressing & again will move straight to the alarm reset prompt where pressing & once more will clear all alarms.

3.6.5 Setting changes

To change the value of a setting, first navigate the menu to display the relevant cell. To change the cell value press the enter key %, which will bring up a flashing cursor on the LCD to indicate that the value can be changed. This will only happen if the appropriate password has been entered, otherwise the prompt to enter a password will appear. The setting value can then be changed by pressing the or " keys. If the setting to be changed is a binary value or a text string, the required bit or character to be changed must first be selected using the !and " keys. When the desired new value has been reached it is confirmed as the new setting value by pressing %. Alternatively, the new value will be discarded either if the clear button & is pressed or if the menu time-out occurs.


For protection group settings and disturbance recorder settings, the changes must be confirmed before they are used by the relay. To do this, when all required changes have been entered, return to the column heading level and press the key. Prior to returning to the default display the following prompt will be given:

Update settings? Enter or clear

Pressing % will result in the new settings being adopted, pressing & will cause the relay to discard the newly entered values. It should be noted that, the setting values will also be discarded if the menu time out occurs before the setting changes have been confirmed. Control and support settings will be updated immediately after they are entered, without Update settings? prompt.

3.7 Front communication port user interface

The front communication port is provided by a 9-pin female D-type connector located under the bottom hinged cover. It provides RS232 serial data communication and is intended for use with a PC locally to the relay (up to 15m distance) as shown in Figure 5. This port supports the Courier communication protocol only. Courier is the communication language developed by AREVA to allow communication with its range of protection relays. The front port is particularly designed for use with the relay settings program MiCOM S1 which is a Windows 95/NT based software package.

SK2

MiCOM relay

Laptop

Serial communication port (COM 1 or COM 2)

Serial data connector (up to 15m)

25 pin download/monitor port

Battery9 pin

front comms port

P0107ENb

FIGURE 5: FRONT PORT CONNECTION

The relay is a Data Communication Equipment (DCE) device. Thus the pin connections of the relays 9-pin front port are as follows: Pin no. 2 Tx Transmit data Pin no. 3 Rx Receive data Pin no. 5 0V Zero volts common


None of the other pins are connected in the relay. The relay should be connected to the serial port of a PC, usually called COM1 or COM2. PCs are normally Data Terminal Equipment (DTE) devices which have a serial port pin connection as below (if in doubt check your PC manual):

25 Way 9 Way

Pin no. 3 2 Rx Receive data

Pin no. 2 3 Tx Transmit data

Pin no. 7 5 0V Zero volts common

For successful data communication, the Tx pin on the relay must be connected to the Rx pin on the PC, and the Rx pin on the relay must be connected to the Tx pin on the PC, as shown in Figure 6. Therefore, providing that the PC is a DTE with pin connections as given above, a straight through serial connector is required, i.e. one that connects pin 2 to pin 2, pin 3 to pin 3, and pin 5 to pin 5. Note that a common cause of difficulty with serial data communication is connecting Tx to Tx and Rx to Rx. This could happen if a cross-over serial connector is used, i.e. one that connects pin 2 to pin 3, and pin 3 to pin 2, or if the PC has the same pin configuration as the relay.

Pin 2 TxPin 3 RxPin 5 0V

Pin 2 TxPin 3 RxPin 5 0V

Serial data connectorDCE DTE

Note: PC connection shown assuming 9 Way serial port

MiCOM relay PC

P0108ENb

FIGURE 6: PC RELAY SIGNAL CONNECTION

Having made the physical connection from the relay to the PC, the PCs communication settings must be configured to match those of the relay. The relays communication settings for the front port are fixed as shown in the table below:

Protocol Courier

Baud rate 19,200 bits/s

Courier address 1

Message format 11 bit - 1 start bit, 8 data bits, 1 parity bit (even parity), 1 stop bit

The inactivity timer for the front port is set at 15 minutes. This controls how long the relay will maintain its level of password access on the front port. If no messages are received on the front port for 15 minutes then any password access level that has been enabled will be revoked.

Hardware Description P740/EN HW/D11 MiCOM P740

HARDWARE DESCRIPTION

P740/EN HW/D11 Hardware Description MiCOM P740

Hardware Description P740/EN HW/D11 MiCOM P740 Page 3/13

CONTENTS

1. HARDWARE OVERVIEW 5

1.1 Power supply module 5

1.2 Main board 5

1.3 Co-processor board 5

1.4 Internal Communication board 5

1.5 Input module 5

1.6 Input and output boards 6

1.7 IRIG-B board 6

2. HARDWARE MODULES 8

2.1 Main board 8

2.2 Co-processor board 8

2.3 Communication board 9

2.4 Internal communication buses 9

2.5 Input module (P742 and P743 only) 10

2.5.1 Transformer board 11

2.5.2 Input board 11

2.5.3 Universal opto isolated logic inputs 11

2.6 Power supply module (including output relays) 12

2.6.1 Power supply board (including RS485 communication interface (K Bus courier)) 12

2.6.2 Output relay board 13

2.6.3 Auxiliary power supply 13

2.7 IRIG-B board (P741 only) 13

2.8 Mechanical layout 13

P740/EN HW/D11 Hardware Description Page 4/13 MiCOM P740


1. HARDWARE OVERVIEW

The relay hardware is based on a modular design whereby the relay is made up of several modules which are drawn from a standard range. Some modules are essential while others are optional depending on the users requirements. The different modules that can be present in the relay are as follows:

1.1 Power supply module

The power supply module provides a power supply to all of the other modules in the relay, at three different voltage levels. The power supply board also provides the RS485 electrical connection (K-bus courier) for the rear communication port. This communication is used on P741, never on P742 or P743. On a second board the power supply module contains :

• relays which provide the output contacts (P742 and P743),

• an auxiliary power supply (P741). 1.2 Main board

The main board performs some functions for the relay (fixed and programmable scheme logic) and controls the operation of modules which are on its interconnection bus within the relay. The main board also contains and controls the user interfaces (LCD, LEDs, keypad and communication interfaces).

1.3 Co-processor board

In P742 and P743, the co-processor board controls the operation of I/O modules within the relay and manages the communication with the P741 relay. In P741, the co-processor board controls the communication boards and manages the communication with others P741 of the system (if present).

1.4 Internal Communication board

Only present within P741 relay. The communication board manages the communication with the P742 and P743 relays.

1.5 Input module

The input module is only present in P742 and P743 relays. The input module converts the information contained in the analogue and digital input signals into a format suitable for the co-processor board. The standard input module consists of two boards:

• a transformer board to provide electrical isolation

• a main input board which provides analogue to digital conversion and the isolated digital inputs.


1.6 Input and output boards

P741 P742 P743

Opto-inputs 8 x UNI(1) 16 x UNI(1) 24 x UNI(1)

Relay outputs 6 n/o and 2 c/o 6 n/o and 2 c/o 15 n/o and 6 c/o

(1) Universal voltage range opto inputs n/o normally open c/o change over

1.7 IRIG-B board

This board, which is optional, can be used where an IRIG-B signal is available to provide an accurate time reference for the relay. IRIG-B board can only be used in P741 relay and is controlled by the main board. All modules are connected by a parallel data and address bus which allows the processor board to send and receive information to and from the other modules as required. There is also a separate serial data bus for conveying sample data from the input module to the coprocessor. Following figures show the modules of the relay and the flow of information between them. There are two independant buses. Through the first bus, the main board controls the coprocessor board and the IRIG-B board (optional, only in P741). Through the second bus, the coprocessor board controls the input/output boards and input module in P742 and P743 relays, it controls the communication boards in P741 relay. So the coprocessor board is controlled by the first bus and controls the second bus. Functionnaly, electrically, mechanically both interconnection buses are very similar.


Universal

Opto

Board

Coprocessor

Board

Main board

Relay board

Relay

Power

Supply

n Communication

Boards

(n=1 to 8)

Auxiliary

Power Supply

(for Comm. Boards)

IRIG-B

Board

(Optional)

P3701ENa

Interconnexion buses


ENTER

READ

=

=

CLEAR

OUT OF SERVICE

HEALTHY

=

TRIP

ALARM

FIGURE 1: MiCOM P741 Architecture

Coprocessor

Board

Power

Supply

Relay

Board

P3702ENa



Universal

Opto

Board

P743

Only

P743

Only

P743

Only

Relay

Board

Relay

Board

ENTER

READ

=

=

CLEAR

OUT OF SERVICE

HEALTHY

=

TRIP

ALARM

Main Board

Universal

Opto

Board

Universal

Opto

Board

P743

Only

Input

Module

FIGURE 2: MiCOM P742 & P743 Architecture


2. HARDWARE MODULES

The relay is based on a modular hardware design where each module performs a separate function within the relay operation. This section describes the functional operation of the various hardware modules.

2.1 Main board

The main board is based around a TMS320C32 floating point, 32-bit digital signal processor (DSP) operating at a clock frequency of 20MHz. The processor board is located directly behind the relays front panel which allows the LCD and LEDs to be mounted on the processor board along with the front panel communication ports. These comprise the 9-pin D-connector for RS232 serial communications (e.g. using MiCOM S1 and Courier communications) and the 25-pin D-connector relay test port for parallel communication. All serial communication is handled using a two-channel 85C30 serial communications controller (SCC). The memory provided on the main processor board is split into two categories, volatile and non-volatile:

• The volatile memory is fast access (zero wait state) SRAM which is used for the storage and execution of the processor software, and data storage as required during the processors calculations.

• The non-volatile memory is sub-divided into 3 groups: 2MB of flash memory for non-volatile storage of software code and text together with default settings, 256kB of battery backed-up SRAM for the storage of disturbance, event, fault and maintenance record data and 32kB of E2PROM memory for the storage of configuration data, including the present setting values.

2.2 Co-processor board

The co-processor board is based around a TMS320VC5402 , 16-bit digital signal processor (DSP) operating at a clock frequency of 100MHz. The feature of the co-processor board are :

• 128 K * 16 bits high speed memory for external code execution.

• 128 K * 16 bits high speed memory for data storage.

• Interface with first interconnection bus from main board.

• 4 K * 16 bits double access memory for communication with main board.

• Interface with second interconnection bus towards peripheral boards.

• Serial communication interface on optical fiber with 4 full duplex channels. The communication uses a synchronous protocole with a date rate of 2.5 Mbit/s. On the co-processor board only 2 of the 4 optical channels are provided.

On board DC-DC converter which gives 3.3V chip power supply from the interconnection bus 22V rail.


After power on, the main board loads the software in coprocessor board via double access memory. When software starts, the microprocessor configures the board. After this, optical communication can begin. In P741 relay, coprocessor board controls 1 opto board, 1 relay board and up to 8 communication boards via its own interconnection bus. In P742 and P743 relays, coprocessor board controls opto boards and relay boards via its own interconnection bus. Coprocessor board provides the sample synchronisation to input module and receives the samples from input module.

2.3 Communication board

The communication board looks like the coprocessor board. The Differences are : • Four duplex optical channels are provided.

• The second interconnection bus is not provided. The communication board controls no board.

This board is only used within P741 relay. It performs the communication with the P742 and P743 relays. Up to 8 communication boards can be interfaced within P741 relay. So up to 32 P742 or P743 relays can be interfaced from a P741 relay.

2.4 Internal communication buses

The relay has two internal interconnection buses : • The first is controlled by the main board. Via its interconnection bus the main

board controls the coprocessor board (P741, P742 & P743) and the IRIG-B board (P741 only).

• The second is controlled by the coprocesseur board. Via its interconnection bus the coprocessor board controls relay boards (P741, P742 & P743), opto boards (P741, P742 & P743), input module (P742 & P743), communication boards (P741).

These two interconnection buses are very similar. Both are based on a 64-way ribbon cable. The main part of the buses is a parallel link with 6 address lines for board selection, 16 data lines and control lines. On the main controlled bus, main board drive address and control lines. On the coprocessor controlled bus, coprocessor board drive address and control lines. Other parts of the buses are :

• the sample serial link from input module to coprocessor board which loads analogue channel samples.

• power supply which are directly wired between the two interconnection buses.

• serial lines for rear RS485 communication which are also directly wired between the two interconnection buses. So in any way main board keeps control of the rear RS485 communication.


2.5 Input module (P742 and P743 only)

The input module provides the interface between the coprocessor board and the analogue and digital signals coming into the relay. The input module consist of two PCBs; the main input board and a transformer board. The P742 and P743 provide four current inputs (3 phases and neutral). P741 relay dont use this board.

CT CT

Buffer

16-bit

ADC

Serial

interface

Sample

control

16:1

Multiplexer

Up to 4 current inputs

8 digital inputs

Serial sample

data bus

Trigger from

processor board

Calibration

E2 PROM

Parallel bus

Up to 4

Up to 4

Up to 4

Diffn

to

single

Diffn

to

single

Low

pass

filter

Low

pass

filter

Noise Filter

Threshold

Bus Interface

FIGURE 3: Main Input Board


2.5.1 Transformer board

The transformer board holds up to four current transformers (CTs). The current inputs will accept either 1A or 5A nominal current (menu and wiring options). The transformers are used to step-down the currents to levels appropriate to the relays electronic circuitry and to provide effective isolation between the relay and the power system. The connection arrangements of the current transformer secondary provide differential input signals to the main input board to reduce noise.

2.5.2 Input board

The main input board is shown as a block diagram in Figure 3. It provides the circuitry for the digital input signals and the analogue-to-digital conversion for the analogue signals. Hence it takes the differential analogue signals from the CTs on the transformer board, converts these to digital samples and transmits the samples to the coprocessor board via the sample serial data bus. On the input board the analogue signals are passed through an anti-alias filter before being multiplexed into a single analogue-to-digital converter chip. The A D converter provides 16-bit resolution and a serial data stream output. The digital input signals are opto isolated on this board to prevent excessive voltages on these inputs causing damage to the relay's internal circuitry.

2.5.3 Universal opto isolated logic inputs

The P741, P742 and P743 relays are fitted with universal opto isolated logic inputs that can be programmed for the nominal battery voltage of the circuit of which they are a part. i.e. thereby allowing different voltages for different circuits e.g. signalling, tripping. They nominally provide a Logic 1 or ON value for Voltages ≥80% of the set voltage and a Logic 0 or OFF value for the voltages ≤60% of the set voltage. This lower value eliminates fleeting pickups that may occur during a battery earth fault, when stray capacitance may present up to 50% of battery voltage across an input. Each input also has selectable filtering which can be utilised. This allows use of a pre-set filter of ½ cycle which renders the input immune to induced noise on the wiring: although this method is secure it can be slow, particularly for inter-tripping. This can be improved by switching off the ½ cycle filter in which case one of the following methods to reduce ac noise should be considered. The first method is to use double pole switching on the input, the second is to use screened twisted cable on the input circuit.


2.6 Power supply module (including output relays)

The power supply module contains two PCBs, one for the power supply unit itself and the other for the output relays (P742 and P743) or for an auxiliary power supply (P741). The power supply board also contains the input and output hardware for the rear communication port which provides an RS485 communication interface (K-Bus Courier).

2.6.1 Power supply board (including RS485 communication interface (K Bus courier))

One of three different configurations of the power supply board can be fitted to the relay. This will be specified at the time of order and depends on the nature of the supply voltage that will be connected to the relay. The three options are shown in table 1 below.

Nominal dc range Nominal ac range

24 48V dc only

48 110V 30 100V rms

110 250V 100 240V rms

Table 1: Power supply options

The output from all versions of the power supply module are used to provide isolated power supply rails to all of the other modules within the relay. Three voltage levels are used within the relay, 5.1V for all of the digital circuits, 16V for the analogue electronics, e.g. on the input board, and 22V for driving the output relay coils and for coprocessor and communication boards 3.3V power supply (through on board DC-DC converter). All power supply voltages including the 0V ground line are distributed around the relay via the 64-way ribbon cables. One further voltage level is provided by the power supply board which is the field voltage of 48V. This is brought out to terminals on the back of the relay so that it can be used to drive the optically isolated digital inputs.

The two other functions provided by the power supply board are the RS485 communications interface and the watchdog contacts for the relay. The RS485 interface is used with the relays rear communication port to provide communication using K Bus Courier. The RS485 hardware supports half-duplex communication and provides optical isolation of the serial data being transmitted and received. All internal communication of data from the power supply board is conducted via the output relay board which is connected to the parallel bus. The watchdog facility provides two output relay contacts, one normally open and one normally closed which are driven by the coprocessor board. These are provided to give an indication that the relay is in a healthy state.


2.6.2 Output relay board

The output relay board holds eight relays, six with normally open contacts and two with changeover contacts. The relays are driven from the 22V power supply line. The relays state is written to or read from using the parallel data bus. In model P743, additional output contacts may be provided, through the use of up to two extra relay boards. In this case only 5 normally open contacts are used per board.

2.6.3 Auxiliary power supply

In P741 the power supply module contains main power supply and an auxiliary power supply. The auxiliary power supply adds power on 22 V rail for the up to 8 communication boards within the relay.

The three input voltage options are the same as for main supply. The relay board is provided as an alone board.

2.7 IRIG-B board (P741 only)

The IRIG-B board is an order option which can be fitted to provide an accurate timing reference for the relay. This can be used wherever an IRIG-B signal is available. The IRIG-B signal is connected to the board via a BNC connector on the back of the relay. The timing information is used to synchronise the relays internal real-time clock to an accuracy of 1ms. The internal clock is then used for the time tagging of the event, fault maintenance and disturbance records.

2.8 Mechanical layout

The case materials of the relay are constructed from pre-finished steel which has a conductive covering of aluminium and zinc. This provides good earthing at all joints giving a low impedance path to earth which is essential for performance in the presence of external noise. The boards and modules use a multi-point earthing strategy to improve the immunity to external noise and minimise the effect of circuit noise. Ground planes are used on boards to reduce impedance paths and spring clips are used to ground the module metalwork. Heavy duty terminal blocks are used at the rear of the relay for the current and voltage signal connections. Medium duty terminal blocks are used for the digital logic input signals, the output relay contacts, the power supply and the rear communication port. ST connectors are used for the optical communication. A BNC connector is used for the optional IRIG-B signal. 9-pin and 25-pin female D-connectors are used at the front of the relay for data communication.

Inside the relay the PCBs plug into the connector blocks at the rear, and can be removed from the front of the relay only. The connector blocks to the relays CT inputs are provided with internal shorting links inside the relay which will automatically short the current transformer circuits before they are broken when the board is removed. The front panel consists of a membrane keypad with tactile dome keys, an LCD and 12 LEDs mounted on an aluminium backing plate.

Functional Description P740/EN FT/D11 MiCOM P740

FUNCTIONAL DESCRIPTION

P740/EN FT/D11 FunctionalDescription MiCOM P740

Functional Description P740/EN FT/D11 MiCOM P740 Page 1/10

CONTENTS

1. SOFTWARE OVERVIEW 3

1.1 Real-time operating system 4

1.2 System services software 4

1.3 Platform software 4

1.4 Communication software 4

1.5 Protection & control software 4

2. RELAY SOFTWARE 5

2.1 Operating system 5

2.2 System services software 5

2.3 Communication software 5

2.4 Platform software 7

2.4.1 Record logging 7

2.4.2 Settings database 7

2.4.3 Database interface 7

2.5 Protection and control software 8

2.5.1 Overview - protection and control distribution 8

2.5.2 Topology software 8

2.5.3 Signal processing 8

2.5.4 Programmable scheme logic 9

2.5.5 Event and Fault Recording 10

2.5.6 Disturbance recorder 10

P740/EN FT/D11 Functional Description Page 2/10 MiCOM P740


1. SOFTWARE OVERVIEW

The busbar protection is a distributed system composed of two different software: the first one is used in central unit (P741) and the second one in peripheral units (P742 & P743). The whole of functions implemented in P740 relays can be split into five elements:

1. the operating system,

2. the system services software,

3. the platform software,

4. the communication software,

5. the protection and control software.

Control of interfaces to keypad,

LCD, LEDs, Front & Rear comm. ports

Data exchanged

between CU & PU:Sample data,

Logic inputs &

Outputs contacts

Measurements & event,

fault & disturbance records

Protection &

control settings

Protection & Control software

Platform software

Disturbance

recorder task

Programmable &

fixed scheme logic

Signal processing &

saturation detection

Protection

algorithms

Topology

algorithms

Front panel interface

(LCD & Keypad)

Local & remote

communications

interface - Courier

Event, Fault,

Disturbance,

Maintenance

record logging.

Settings

database

System services softwareCommunication software

Relay hardware

Curent samples

& signal quality ;

Trip order ;

Internal courrier com. ;

Date & time.

P3704ENa

FIGURE 1: Software Overview


1.1 Real-time operating system

As explain in the hardware overview, each relay contains one main board and one coprocessor board. These two boards use two different operating system:

• For main board software: a real time operating system is used to provide a framework for the different parts of the relays software to operate within. To this end the software is split into tasks. The real-time operating system is responsible for scheduling the processing of these tasks such that they are carried out in the time available and in the desired order of priority.

• For coprocessor board software: a sequencer manages all the functions implemented on the coprocessor board. Each function is executed at fixed frequency; consequently the CPU load of the coprocessor is fixed and independent of the networks frequency.

1.2 System services software

The system services software provides the low-level control of the relay hardware. For example, the system services software controls the boot of the relays software from the non-volatile flash EPROM memory at power-on, and provides driver software for the user interface via the LCD and keypad, and via the serial communication ports.

The system services software provides an interface layer between the control of the relays hardware and the rest of the relay software.

1.3 Platform software

The platform software deals with the management of the relay settings, the user interfaces and logging of event, alarm, fault and maintenance records. All of the relay settings are stored in a database within the relay which provides direct compatibility with Courier communications.

The platform software notifies the protection & control software of all setting changes and logs data as specified by the protection & control software.

1.4 Communication software

The communication software manages optical fibre communication between the central unit and the peripheral units. This includes the control of data exchanged transmitted and the synchronisation of peripheral units. With this object, the communication software interfaces with the sequencer used in coprocessors boards.

1.5 Protection & control software

The protection and control software performs the calculations for all of the protection algorithms for all the protections algorithms of the P740 relays. This includes digital signal processing such as saturation detection, Fourier filtering and ancillary tasks such as the measurements. The protection & control software interfaces with the platform software for settings changes and logging of records, and with the system services software for acquisition of sample data and access to output relays and digital opto-isolated inputs.


2. RELAY SOFTWARE

The relay software was introduced in the overview of the relay at the start of this chapter. The software can be considered to be made up of five sections:

• the operating system

• the system services software

• the communication software

• the platform software

• the protection & control software

This section describes in detail the latter two of these, the platform software and the protection & control software, which between them control the functional behaviour of the relay. Figure 2 shows the structure of the relay software.

2.1 Operating system

• Real-time operating system for main board: the real-time operating system is used to schedule the processing of the tasks to ensure that they are processed in the time available and in the desired order of priority. The operating system is also responsible in part for controlling the communication between the software tasks through the use of operating system messages.

• Sequencer for coprocessor and communication boards: the sequencer executed all functions at fixed frequency depending of the priority of the functions. The highest frequency, 2400Hz, is the frequency of sample acquisition, signal processing and trip decision. To start analog acquisition at the same time on all peripheral units, the sequencers of all peripheral units and central unit are synchronized and control the analog acquisition interfacing with system services software.

2.2 System services software

As shown in figure 3, the system services software provides the interface between the relays hardware and the higher-level functionality of the platform software and the protection & control software. For example, the system services software provides drivers for items such as the LCD display, the keypad and the remote communication ports, and controls the boot of the processor and downloading of the processor code into SRAM from non-volatile flash EPROM at power up.

2.3 Communication software

In accordance with sequencer used in coprocessor board, the communication software sends frames at fixed frequency equal to 2400Hz. Likewise the contents of the frames is independent of the frequency and of the status of the protections. The frames are split in fixed parts according to the priority of each application. For example trip order and current sample are respectively transmitted at 2400Hz and 1200Hz whereas the internal courier communication or date & time are exchange at low frequency.


PERIPHERAL UNIT

Coprocessor board

Saturation detection

algorithm

Signal processing & local confirmation

threshold for busbar protection

Fixed scheme

logic

Local Topology

Local and global

measurements

Main board

Event & fault

recording

Disturbance recorder

of peripheral unit

Overcurrent

protection

Logic of breaker

failure

Programmable

scheme logic

CENTRAL UNIT

Coprocessor &

communications boards

Sum of current for busbar protection

Fixed scheme

logic

Global

topology

Main board

Event & fault

recording

Disturbance recorder

of central unit

Programmable

scheme logic

OpticalFibre

PERIPHERAL UNIT

PERIPHERAL UNIT

PERIPHERAL UNIT

P3705ENa

FIGURE 2: MiCOM P740 system overview


2.4 Platform software

The platform software has three main functions:

• to control the logging of records that are generated by the protection software, including alarms and event, fault, and maintenance records.

• to store and maintain a database of all of the relays settings in non-volatile memory.

• to provide the internal interface between the settings database and each of the relays user interfaces, i.e. the front panel interface and the front and rear communication ports, using Courier communication protocol.

2.4.1 Record logging

The logging function is provided to store all alarms, events, faults and maintenance records. The records for all of these incidents are logged in battery backed-up SRAM in order to provide a non-volatile log of what has happened. The relay maintains four logs: one each for up to 32 alarms, 250 event records, 5 fault records and 5 maintenance records. The logs are maintained such that the oldest record is overwritten with the newest record. The logging function can be initiated from the protection software or the platform software is responsible for logging of a maintenance record in the event of a relay failure. This includes errors that have been detected by the platform software itself or error that are detected by either the system services or the protection software function.

2.4.2 Settings database

The settings database contains all of the settings and data for the relay, including the protection, disturbance recorder and control & support settings. The settings are maintained in non-volatile E2

PROM memory. The platform softwares management of the settings database includes the responsibility of ensuring that only one user interface modifies the settings of the database at any one time. This feature is employed to avoid conflict between different parts of the software during a setting change. For changes to protection settings and disturbance recorder settings, the platform software operates a scratchpad in SRAM memory. This allows a number of setting changes to be applied to the protection elements, disturbance recorder and saved in the database in E2

PROM. (See also Introduction Chapter on the user interface). If a setting change affects the protection & control task, the database advises it of the new values.

2.4.3 Database interface

The other function of the platform software is to implement the relays internal interface between the database and each of the relays user interfaces. The database of settings and measurements must be accessible from all of the relays user interfaces to allow read and modify operations. The platform software presents the data in the appropriate format for each user interface.


2.5 Protection and control software

The protection and control software is responsible for processing all of the protection elements and measurement functions of the relay. To achieve this it has to communicate with the system services software, the communication software and the platform software as well as organize its own operations. The protection software has the highest priority of any of the software tasks in the relay in order to provide the fastest possible protection response.

2.5.1 Overview - protection and control distribution

The figure 2 shows the parts of AREVA software and their allocation on the different boards of the peripheral and central units. The P740 relays contained two global protections, busbar protection and circuit breaker failure, and one local function, overcurrent protection. Overcurrent protection is implemented on peripheral unit and is totally independent of the central unit. On the contrary, busbar protection and circuit breaker failure are distributed between central unit and peripheral units. Local functions such as saturation detection algorithm, logic of circuit breaker failure and local confirmation threshold are performed on each peripheral unit. Sum of current, logic of differential protection and circuit breaker failure are processed on central unit.

2.5.2 Topology software

Topology algorithm determines dynamically the electric scheme of the substation from the auxiliary contact of circuit breaker and isolators. The results of local topology performed on peripheral unit are sending to central unit which determines global topology of the substation. At the end of process, central unit know the node of current and zone to trip according to the fault location.

2.5.3 Signal processing

The sampling frequency of analogue signal is fixed to 2400Hz apart from the electric network frequency. To ensure that the frequency is identical on each PU, analog acquisition is based on interruption signal from communication software. Central unit send frames on optical fibers in diffusion towards all peripheral units. So they received data at the same instant, this reception signal starts the acquisition of analog signal. The main signal processing algorithms are:

• Flux calculation and prediction algorithm to detect CT saturation

• Zero sequence supervision

• Detection of signal variation

• Local threshold to block busbar protection on external fault

All this information are transmitted to central unit with the sample of current, they represent signal quality. The sum of current is processed in central unit each 1200Hz but the signal processing is executed at 2400Hz on peripheral unit.


The protection and control calculates the Fourier components for the analogue signals. The Fourier components are calculated using a one-cycle, 48-sample Discrete Fourier Transform (DFT). The DFT is always calculated using the last cycle of samples from the 2-cycle buffer, i.e. the most recent data is used. The DFT used in this way extracts the power frequency fundamental component from the signal and produces the magnitude and phase angle of the fundamental in rectangular component format. The DFT provides an accurate measurement of the fundamental frequency component, and effective filtering of harmonic frequencies and noise. This performance is achieved in conjunction with the relay input module which provides hardware anti-alias filtering to attenuate frequencies above the half sample rate. The Fourier components of the input current signals are stored in memory so that they can be accessed by all of the protection elements algorithms. The samples from the input module are also used in an unprocessed form by the disturbance recorder for waveform recording and to calculate true rms values of current.

2.5.4 Programmable scheme logic

The purpose of the programmable scheme logic (PSL) is to allow the relay user to configure an individual protection scheme to suit their own particular application. This is achieved through the use of programmable logic gates and delay timers. The input to the PSL is any combination of the status of the digital input signals from the opto-isolators on the input board, the outputs of the protection elements, e.g. protection starts and trips, and the outputs of the fixed protection scheme logic. The fixed scheme logic provides the relays standard protection schemes. The PSL itself consists of software logic gates and timers. The logic gates can be programmed to perform a range of different logic functions and can accept any number of inputs. The timers are used either to create a programmable delay, and/or to condition the logic outputs, e.g. to create a pulse of fixed duration on the output regardless of the length of the pulse on the input. The outputs of the PSL are the LEDs on the front panel of the relay and the output contacts at the rear. The execution of the PSL logic is event driven; the logic is processed whenever any of its inputs change, for example as a result of a change in one of the digital input signals or a trip output from a protection element. Also, only the part of the PSL logic that is affected by the particular input change that has occurred is processed. This reduces the amount of processing time that is used by the PSL. The protection and control software updates the logic delay timers and checks for a change in the PSL input signals every time it runs. This system provides flexibility for the user to create their own scheme logic design. However, it also means that the PSL can be configured into a very complex system, and because of this setting of the PSL is implemented through the PC support MiCOM S1.


2.5.5 Event and Fault Recording

A change in any digital input signal or protection element output signal causes an event record to be created. When this happens, the protection and control task sends a message to the supervisor task to indicate that an event is available to be processed and writes the event data to a fast buffer in SRAM which is controlled by the supervisor task. When the supervisor task receives either an event or fault record message, it instructs the platform software to create the appropriate log in battery backed-up SRAM. The operation of the record logging to battery backed-up SRAM is slower than the supervisors buffer. This means that the protection software is not delayed waiting for the records to be logged by the platform software. However, in the rare case when a large number of records to be logged are created in a short period of time, it is possible that some will be lost if the supervisors buffer is full before the platform software is able to create a new log in battery backed-up SRAM. If this occurs then an event is logged to indicate this loss of information.

2.5.6 Disturbance recorder

The disturbance recorder operates as a separate task from the protection and control task. It can record the waveforms for up to 8 analogue channels and the values of up to 32 digital signals. For peripheral unit the recording time is user selectable up to a maximum of 10 seconds and for central unit the record duration is fixed to 600ms. The disturbance recorder is supplied with data by the protection and control task once per cycle. The disturbance recorder collates the data that it receives into the required length disturbance record. It attempts to limit the demands it places on memory space by saving the analogue data in compressed format whenever possible. This is done by detecting changes in the analogue input signals and compressing the recording of the waveform when it is in a steady-state condition. The compressed disturbance records can be decompressed by MiCOM S1 which can also store the data in COMTRADE format, thus allowing the use of other packages to view the recorded data.

Application Notes P740/EN AP/D11 MiCOM P740

APPLICATION NOTES

P740/EN AP/D11 Application Notes MiCOM P740

Application Notes P740/EN AP/D11 MiCOM P740 Page 1/103

CONTENTS

1. INTRODUCTION 5

1.1 Protection of Substation Busbars 5

1.2 P740 Scheme 5 1.2.1 Protection features 6

1.2.2 Non-Protection Features 7

2. APPLICATION OF INDIVIDUAL PROTECTION FUNCTIONS 8

2.1 Configuration Columns 8

2.2 Busbar Biased Current Differential Protection 11 2.2.1 Operating principle 11

2.2.2 Application of Kirchoffs law 11

2.3 Central Unit 13 2.3.1 Differential Protection Configuration 13

2.3.2 Bias Characteristic and Differential current setting 14

2.3.3 Scheme supervision by "check zone element 14

2.3.4 Sensitive earth fault element 15

2.3.5 Current Circuit Supervision 19

2.3.6 Threshold coherency. 19

2.3.7 Signal Quality 20

2.3.8 Tripping Criteria 21

2.4 Peripheral Unit 21 2.4.1 Busbar Elements 21

2.4.1.1 Busbar Protection Configuration 21

2.4.1.2 Busbar Trip Confirmation (87BB) or Central Breaker Fail Trip Confirmation (50BF) 22

2.4.2 Non-directional Phase Fault Overcurrent Protection 22

2.4.2.1 IDMT Characteristics 25

2.4.3 Non-Directional Earth Fault Overcurrent Protection 25

2.4.4 External Fault Detection by High-Set Overcurrent or Earth Fault Element 26

2.4.4.1 Application Example 26

2.4.5 Supervision 27

2.4.6 Zero Sequence Current (ΙO) Supervision. 28

P740/EN AP/D11 Application Notes Page 2/103 MiCOM P740

3. CIRCUIT BREAKER FAIL (CBF) 29

3.1 Distributed Tripping, Control and Indication Elements (Peripheral Units) 29

3.2 Circuit Breaker Fail Criteria 30 3.2.1 Current Criterion 30

3.2.2 Logic Criterion 30

3.2.2.1 Overcurrent Criterion 30

3.3 Processing A Circuit Breaker Failure Condition 30 3.3.1 Internally Initiated CBF i.e. Tripping from the Differential Element 87BB 32

3.3.1.1 Description of the Logic for Internally Initiated CBF 33

3.3.1.1.1 Initial Trip 33

3.3.1.1.2 Re-Trip after time tBF1 33

3.3.1.1.3 Back Trip after time tBF2 33

3.3.2 Externally Initiated 50BF 34

3.3.2.1 Local re-trip after time tBf3 35

3.3.2.2 General zone trip after time tBF4 35

3.3.3 Separate external 50BF protection to the busbar protection 35

4. CURRENT TRANSFORMERS 36

4.1 CT Mismatch 37 4.1.1 Adjusting the Scheme Base Ratio 37

4.2 CT Requirements 38 4.2.1 Notation 38

4.2.2 Feeders connected to sources of significant power (i.e. lines and generators) 39

4.2.3 Out of service feeders or those with low power contribution (low infeed) 39

4.2.4 CT Specification according to IEC 185, 44-6 and BS 3938 (British Standard) 39

4.2.5 Support of IEEE C Class CTs 41

4.3 CT Saturation detection 42

4.4 CT Location 45

5. CIRCUIT BREAKER FUNCTION 46

5.1 Circuit breaker state monitoring 46 5.1.1 Circuit Breaker State Monitoring Features 46

5.2 Circuit Breaker Control 47 5.3 Trip relays 49 5.4 Suggested Trip Circuit Supervision using psl editor 49


6. ISOLATION AND REDUCED FUNCTION MODE 52 6.1 Central processing unit (P741) 52 6.2 Peripheral Units (P742 and P743) 53 6.3 System operation under failed communications situation 57 6.4 Waiting Configuration 57

7. TOPOLOGY 58 7.1 Topology Configurator 58 7.2 Nodal Assignment 59 7.3 Topology Communication 59 7.4 Topology data 59 7.5 Topology processing 60 7.5.1 CTs on one side of bus coupler, CB closes before status acquisition. 60 7.5.2 CTs on both sides of bus coupler, CB closes before status acquisition. 61 7.5.3 CTs on one side of bus coupler, CB closed and fault evolves between CT and CB.62 7.5.4 CTs on both sides of coupler, CB closed and fault evolves between CT and CB. 64

8. PSL CONFIGURATION AND INTEGRATION 65 8.1 Factory default settings 65 8.1.1 Logic input mapping 65 8.1.2 Relay output mapping 66 8.1.3 Relay output conditioning 67 8.1.4 LED mapping 68 8.1.5 LED output conditioning 68 8.1.6 Fault recorder start mapping 68

9. COMMUNICATIONS BETWEEN PU AND CU 69 9.1 Communications link 69 9.2 Direct optical fibre link, 850nm multi-mode fibre 69 9.3 Optical budgets 70

10. UNDERTAKING A NUMERICAL DIFFERENTIAL BUSBAR PROTECTION PROJECT 71 10.1 General Substation information 71 10.2 Short Circuit Levels 71 10.3 Switchgear 71 10.4 Cubicle specifications 72 10.5 Substation Architecture 72

11. STANDARD CONFIGURATIONS 73

12. MEASUREMENTS 84 12.1 Measured currents 84 12.2 Sequence currents 84 12.3 Settings 84


12.3.1 Common Conventional Ratio (Ibp) 85

12.3.2 Default Display 85 12.3.3 Local Values 85 12.3.4 Remote Values 85

13. EVENT & FAULT RECORDS 86 13.1 Types of Event 89 13.1.1 Change of state of opto-isolated inputs 89 13.1.2 Change of state of one or more output relay contacts 89 13.1.3 Relay alarm conditions 90 13.1.3.1 Protection element starts and trips 90 13.1.3.2 General events 90 13.1.3.3 Fault records 91 13.1.3.4 Maintenance reports 91 13.1.3.5 Setting Changes 91 13.1.4 Resetting of event/fault records 91 13.1.5 Viewing event records via MiCOM S1 Support Software 92 13.1.6 Event Filtering 93

14. DISTURBANCE RECORDER 94

15. COMMISSIONING TEST MENU 97 15.1 Opto I/P status 98 15.2 Relay O/P status 98 15.3 Test Port status 99 15.4 LED status 99 15.5 Test mode 99 15.5.1 Test mode for PU 99 15.5.2 Test mode for CU 100 15.6 Test pattern 100 15.7 Contact test 100 15.8 Test LEDs 100 15.9 Busbar Monitoring (only in CU) 101 15.10 Busbar (BB) & Circuit Breaker Fail (CBF) Disable (only in CU) 101 15.11 Position Pattern (only in PU) 101 15.12 Position Test (only in PU) 101

16. MONITOR TOOL 102


1. INTRODUCTION

1.1 Protection of Substation Busbars

The busbars in a substation are possibly one of the most critical elements in a power system. If a fault is not cleared or isolated quickly, not only could substantial damage to the busbars and primary plant result, but also a substantial loss of supply to all consumers who depend upon the substation for their electricity. It is therefore essential that the protection associated with them provide reliable, fast and discriminative operation.

As with any power system the continuity of supply is of the utmost importance, however, faults that occur on substation busbars are rarely transient but more usually of a permanent nature. Circuit breakers should, therefore, be tripped and not subject to any auto-reclosure.

The busbar protection must also remain stable for faults that occur outside of the protected zone as these faults will usually be cleared by external protection devices. In the case of a circuit breaker failure, it may be necessary to open all of the adjacent circuit breakers, this can be achieved by issuing a backtrip to the busbar protection. Security and stability are key requirements of a busbar protection scheme. Should the busbar protection maloperate under such conditions substantial loss of supply could result unnecessarily.

Many different busbar configurations exist. A typical arrangement is a double busbar substation with a transfer bar. The positioning of the primary plant can also vary and also needs to be considered which in turn introduces endless variations, all of which have to be able to be accommodated within the busbar protection scheme.

Backup protection is also an important feature of any protection scheme. In the event of equipment failure, such as signalling equipment or switchgear for example it is necessary to provide alternative forms of fault clearance. It is desirable to provide backup protection, which can operate with minimum time delay and yet discriminate with other protection elsewhere on the system.

1.2 P740 Scheme

Using the latest numerical technology, MiCOM relays include devices designed for application to a wide range of power system plant such as motors, generators, busbars, feeders, overhead lines and cables.

Each relay in the range is designed around a common hardware and software platform in order to achieve a high degree of commonality between products. One such product is the P740 busbar protection scheme. The scheme has been designed to cater for the protection of a wide range of busbar configurations. The scheme comprises of three relays the Central Unit - P741, and the Peripheral Units P742 and P743. Which, together with the topology configurator software, allows flexibility for all configurations.

The P740 range also includes a comprehensive range of non-protection features to aid with power system analysis and fault analysis.


1.2.1 Protection features

There are three modules that make up the P740 scheme. The P741 is the Central Unit (CU), whilst the P742 and P743 are both variants of the Peripheral Unit (PU). The central unit co-ordinates the scheme, receiving signals from all the peripheral units associated with the protected busbar(s) and acting on these signals, initiating a buszone protection trip when necessary. One peripheral unit is associated with each CT location, usually one per incomer/feeder and one/two for each bus coupler/bus section depending of number of CT (1 or 2). The peripheral units acquire the analogue signals from the associated CT and the binary signals from the auxiliary contacts of the primary plant (CB and isolator(s)). The peripheral units also incorporate the main circuit breaker failure logic together with backup protection. The difference between the P742 and P743 is the amount of I/O that each can accommodate. The P743 allows for increased I/O, this is found to be particularly useful in double busbar applications. Especially where single pole breakers and a transfer bar are employed, in these applications the I/O requirements are large in comparison to those required for a single busbar application where a P742 may be more suitable.

The main features of the P740 scheme are summarised below:

− Current differential busbar protection Phase segregated biased differential protection (*) provides the main protection element for the scheme. This protection provides high-speed discriminative protection for all fault types

(Note: * Sometimes referred to as low impedance type)

− Sensitive differential earth fault protection provided for high impedance earthed systems and incorporates bias current control to guarantee stability under external faults

− Non-directional phase fault over current protection provides two stage backup protection

− Non-directional earth fault protection provides two stage backup protection

− Low Burden Allows the protection to be installed in series with other equipment on a common CT secondary

− Accommodates different CT classes , ratios and manufacturer

− Circuit breaker failure protection two stage breaker fail logic that can be initiated internally or externally.


1.2.2 Non-Protection Features

The non-protection features for the scheme are summarised below:

− Scheme can be centralised/distributed if space is not available to locate the busbar protection centrally it is possible to decentralise the scheme and locate the units within other protection cubicles.

− Local, zone and scheme measurements various measurements are available locally via the relay LCD or remotely via the serial communication link

− Event, fault and disturbance recording Comprehensive post fault analysis available via event lists, disturbance records and fault records which can be accessed locally via the relay LCD or remotely via the serial communication link (PU -> CU)

− Real time clock/time synchronisation Time synchronisation available via IRIG-B input (option in Central Unit)

− Four settings groups Independent remotely selectable setting groups to allow for customer specific applications

− CB and isolator state monitoring indication of the circuit breaker/isolator position via the auxiliary contacts, scheme acts accordingly should discrepancy conditions be detected

− CB control available locally via the HMI

− Commissioning test facilities

− Continuous self monitoring extensive self checking routines to ensure maximum reliability

− Communications supervision detects communication failure between units and enables remedial action to be taken e.g. switch to communication independent backup protection locally and disregard feeder at a zone level

− Graphical programmable scheme logic allowing user defined protection and control logic to be tailored to the specific application


2. APPLICATION OF INDIVIDUAL PROTECTION FUNCTIONS

The following sections detail the individual protection functions in addition to where and how they may be applied. Each section also provides an extract from the respective menu columns to demonstrate how the settings are actually applied to the relay.

Each relay in the P740 series has a Configuration column. As this affects all of the protection functions it is described in the following section.

2.1 Configuration Columns

The configuration column for the Central Unit is shown in the following table:-

MENU TEXT DEFAULT SETTING AVAILABLE SETTING

CONFIGURATION

Restore Defaults No Operation No Operation All Settings Setting Group 1 Setting Group 2 Setting Group 3 Setting Group 4

Setting Group Select via Menu Select via Menu Select via Optos

Active Settings Group 1 Group 1 Group 2 Group 3 Group 4

Save Changes No Operation No Operation Save Abort

Copy From Group 1 Group 1 Group 2 Group 3 Group 4

Copy to No Operation No Operation Group 1 Group 2 Group 3 Group 4

Setting Group 1 Enabled Enabled/Disabled

Setting Group 2 Disabled Enabled/Disabled



Diff Busbar Prot Enabled Enabled/Disabled

Optos Setup Visible Visible/Invisible

Input Labels Visible Visible/Invisible

Output Labels Visible Visible/Invisible



CONFIGURATION

Recorder Control Visible Visible/Invisible

Disturb Recorder Visible Visible/Invisible

Measure't Setup Visible Visible/Invisible

Comms Settings Visible Visible/Invisible

Commission Test Visible Visible/Invisible

Setting Values Primary Primary/Secondary

PU in service 0 PU7 to PU39 (0 = on) (1 = off)

PU connected 0 PU from address 7 to address 39

Table 1

In the central unit an additional configuration column PU Conf & Status is present to configure the hardware to the software topology.


PU CONF & STATUS

PU in service Listing the PUs in service. For example a topology scheme may define 12 PU: 5 PU for current phase and 7 PU for future. This would be set to 5.

PU connected This give a list of PUs connected and synchronized with the CU. After reboot the CU waits for the list of connected PUs to equal the PUs in service before enabling the busbar protection.

If there is a discrepancy the CU will not start and the scheme will be locked.

PU topo valid This gives a list of PUs with valid topology data. After rebooting the CU checks the topology configuration on all PUs and reports the result in this cell.

If there is a discrepancy the central unit will not start and the scheme will be locked.

Reset Circt Flt After a circuitry fault has been detected, the user must accept and clear the error, using the command from this cell.

Circuitry Fault List of zones blocked for circuitry fault

Circ Fault Phase Phase in circuitry fault

Table 2


The configuration column for the Peripheral Unit is shown in table 3 below:-


CONFIGURATION

Restore Defaults No Operation No Operation All Settings Setting Group 1 Setting Group 2 Setting Group 3 Setting Group 4

Setting Group Select via Menu Select via Menu Select via Optos

Active Settings Group 1 Group 1 Group 2 Group 3 Group 4

Save Changes No Operation No Operation Save Abort

Copy From Group 1 Group 1 Group 2 Group 3 Group 4

Copy to No Operation No Operation Group 1 Group 2 Group 3 Group 4

Setting Group 1 Enabled Enabled/Disabled




BB Trip Confirm Enabled Enabled/Disabled

Optos Setup Visible Visible/Invisible

Overcurrent Prot Disabled Enabled/Disabled

earth Fault Prot Disabled Enabled/Disabled

CB Fail & I> Enabled Enabled/Disabled

Input Labels Visible Visible/Invisible

Output Labels Visible Visible/Invisible

CT & VT Ratios Visible Visible/Invisible

Recorder Control Invisible Visible/Invisible

Disturb Recorder Invisible Visible/Invisible

Measure't Setup Invisible Visible/Invisible



CONFIGURATION

Commission Tests Invisible Visible/Invisible

Setting Values Secondary Primary/Secondary

Table 3

The aim of the configuration column is to allow general configuration from a single point in the menu. Items that are disabled or made invisible do not appear in the main relay menu.

2.2 Busbar Biased Current Differential Protection

The primary protection element of the P740 scheme is phase segregated biased current differential protection. The technique used is purely numerical and uses nodal analysis throughout the scheme, on a per zone and per scheme basis. The analysis is carried out in the central unit therefore communication between the central unit and all peripheral units is essential. This is achieved via a direct optical connection utilising a 2.5 Mbits/sec data rate.

2.2.1 Operating principle

The basic operating principle of the differential protection is based on the application of Kirchhoffs law. This compares the amount of current entering and leaving the protected zone. Under normal operation, the amount of current flowing into the area concerned is equal in to the amount of the current flowing out of the area. Therefore the currents cancel out. In contrast, when a fault occurs the differential current that arises is equal to the derived fault current.

xIi1

S1

xIi2

S2

xIi3

S3

xIo1

xIo2

xIo3

Io4x

xSΣIi ΣIo

xImport Export

Substation Simplified Scheme

Ii = | ΣIin |

Io = | ΣIon|

Ibias = Ii + Io

Idiff = Ii - Io

P3766ENa

Figure 1: Differential busbar protection principle

2.2.2 Application of Kirchoffs law

Several methods of summation can be used for a differential protection scheme:

− Vector sum

− Instantaneous sum


The algorithms applied in MiCOM P740 use the instantaneous sum method. This method has the advantage of cancelling the harmonic and DC components of external origin in the calculation and in particular under transformer inrush conditions.

The other advantage of using an instantaneous sum lies in the speed of decision, which in turn is dictated by the sampling frequency.

Differential currents may also be generated under external fault conditions due to CT error. To provide stability for through fault conditions the relay adopts a biasing technique, which effectively raises the setting of the relay in proportion to the through fault current thereby preventing relay maloperation.

The bias current is the scalar sum of the currents in the protected zone. Each of these calculations is done on a per phase basis for each node and then summated.

Figure 2 shows the characteristics of the P740 scheme phase differential element.

i (t)bias

I > 2D

i3 i4

i2i1

I > 1D

Is

Trip

Restrain

i (t)diff

i (t) =bias

i 1 i 2 i 3 i 4+ + + = i

Perce

ntage bias - k =

20to

90%

i (t) =diff i1 2 3 4+ i + i + i = i

P3721ENa

Figure 2: P740 Scheme Characteristic

The characteristic is determined from the following protection settings:

ID>2 High-set differential current threshold setting which controls the set slope of the bias characteristic (Is + k Ibias)

IS The origin of the bias characteristic slope

k Percentage bias setting (slope)

When an external fault condition causes CT saturation, a differential current is apparent and is equal to the current of the saturated CT. The measured differential current may be determined as an internal fault and initiate an unwanted trip of the bus bar. In order to avoid a risk of tripping under these circumstances, MiCOM P740 uses an ultra fast innovative algorithm based on the prediction of the next samples and the calculation of the image of the flux of the CT core. This signal-processing algorithm makes it possible to block a trip sample within a window of 3 samples. A settable timer Block Duration is used to block the differential element in case of CT saturation detection (settable from 0 to 2s, default value 150 ms).


2.3 Central Unit

2.3.1 Differential Protection Configuration

Following is a copy of the Differential Elements 87BB column on the relay menu, which is found in the central unit P741. All configuration settings applicable to this element are found in this column. A different configuration column is found in the P742 and P743. This is shown in section 2.4.1.

The differential element has independent settings for phase and earth (sensitive) faults, which are used for all zones. The check zone element uses only the minimum pick up level setting ID>2. Ibp is the common base current, refer to section 4.2.

MENU TEXT DEFAULT SETTING

MINIMUM MAXIMUM STEPSIZE

BUSBAR ELEMENTS - DIFF BUSBAR PROT -

Diff Phase Fault

Current Is 0.1*Ibp 0.02*Ibp 1*Ibp 0.01*Ibp

Phase slope k 40% 20% 90% 1%

ID>2 Current 1.2*Ibp 0.1*Ibp 4*Ibp 0.01*Ibp

ID>1 Current 0.05*Ibp 0.01*Ibp 0.5*Ibp 0.01*Ibp

ID>1 Alarm Timer

5s 0s 100s 0.1s

Diff Earth Fault

Diff Earth Fault Disabled Enabled/Disabled

IBiasPh>Cur. 2*Ibp 0.1*Ibp 10*Ibp 0.1*Ibp

Earth Cur. ISN 0.06*Ibp 0.02*Ibp 1*Ibp 0.01*Ibp

Earth Slope kN 20% 20% 90% 1%

IDN>2 Current 0.1*Ibp 0.03*Ibp 2*Ibp 0.05*Ibp

IDN>1 Current 0.05*Ibp 0.01*Ibp 0.5*Ibp 0.01*Ibp

IDN>1 Alarm Timer

5s 0s 100s 0.1s

Table 4 Busbar element configuration column for the Central Unit.

Note 1: Only values for Group 1 settings are shown. Identical columns/rows exist for setting groups 2, 3 and 4.

2: Ibp refer to Section 4.1.1 for more information.


2.3.2 Bias Characteristic and Differential current setting

The operation of the busbar differential protection is based on the application of an algorithm having a biased characteristic, (Figure 2) in which a comparison is made between the differential current and a bias or restraining current. A trip is only permitted if this differential current exceeds the set slope of the bias characteristic. This characteristic is intended to guarantee the stability of protection during external faults where the scheme has current transformers with differing characteristics, likely to provide differing performance.

The algorithm operands are as follows:

− Differential Current

idiff(t) = Σ i

− Bias or restraining current

ibias(t) = Σ i

− Origin of the bias characteristic

Is

− Slope of the bias characteristic

k

− Tripping permitted by bias element for:

idiff(t) > Is + k x ibias(t)

The main differential current element of MiCOM P740 will only be able to operate if the differential current reaches a threshold ID>2. In general, this setting will be adjusted above the highest normal full load current.

2.3.3 Scheme supervision by "check zone element

The use of a "check zone" element is based on the principle that in the event of a fault on one of the substation busbars, the differential current measured in the faulty zone will be equal to that measured in the entire scheme.

One of the most frequent causes of maloperation of differential busbar protection schemes is an error in the actual position of an isolator or CB in the substation to that replicated in the scheme (auxiliary contacts discrepancy). This would produce a differential current in one or more current nodes. However, if an element monitors only the currents "entering" and "leaving" the substation, the resultant will remain negligible in the absence of a fault, and the error will lie with the zones assumption of the plant position at this particular point in time.

For security, the P740 scheme will only trip a particular busbar zone if that zone differential element AND the check zone are in agreement to trip.

The principal advantage of this element is total insensitivity to topological discrepancies. Under such circumstances the "check zone" element will see two currents with equal amplitude but of opposite sign in adjacent zones.


The check zone is the sum of all the current nodes entering and leaving the sub-station (bus section, dead zone, blind spot).

Scheme differential current = sum of all differential current nodes:

idiff(t) CZ = Σ idiff

INCLUDEPICTUREMERGEFORMAT

P3723ENa

BB1 BB2

Z12

Z1

Z2

CZ= Idiff

Figure 3: Check Zone Element

Examples showing how the topology accommodates such conditions using the check zone are shown in section 7.4.

The Check Zone will operate if the sum of all differential current nodes is greater than ID>2.

2.3.4 Sensitive earth fault element

The sensitive earth fault element is included for high impedance earthed systems and has bias current control to guarantee stability under external faults or when there are significant errors in the measurement CTs. The element is usually disabled for effectively earthed systems with low impedance or solid earthing. The sensitive earth fault settings are shown in table 4 and are also repeated below.


MINIMUM MAXIMUM STEP SIZE

Earth Faults

Earth Fault Disabled Enabled/Disabled

IBiasPh> Cur. 2*Ibp 0.1*Ibp 10*Ibp 0.1*Ibp

Earth Cur. ISN 0.06*Ibp 0.02*Ibp 1*Ibp 0.01*Ibp

Earth slope kN 20% 20% 90% 1%

IDN>2 Current 0.1*Ibp 0.03*Ibp 2*Ibp 0.05*Ibp

IDN>1 Current 0.05*Ibp 0.01*Ibp 0.5*Ibp 0.01*Ibp

IDN>1 Alarm Timer

5s 0s 100s 0.1s

Table 5


The current control and blocking matrix is shown in Table 6.

There is a separate characteristic for the sensitive earth fault element. This is shown in Figure 4.

i (t)bias

I > 2D

i3 i4

i2i1

I > 1D

Is

Trip

Restrain

i (t)diff

i (t) =bias

i 1 i 2 i 3 i 4+ + + = i

Perce

ntage bias - k =

20to

90%

i (t) =diff i1 2 3 4+ i + i + i = i

P3721ENa


Figure 4: Sensitive earth fault characteristic

This element is automatically enabled/disabled via the load (flowing) current. The point at which the sensitive earth fault protection is enabled/disabled (IbiasPh>Cur.) is settable in the range 0.1 to 10 times Ibp, where Ibp is the scheme base current. This threshold is usually set to be equal to the minimum phase to phase short circuit current.

Under earth fault conditions the risk of CT saturation is minimal and therefore the slope of the characteristic can be set low, however, should the fault evolve to a phase fault, it is important that the normal characteristic be restored.

Table 6 shows the current control for the SEF element.

PROTECTION ELEMENT

Before fault detection

External single phase fault

Internal single phase fault

External phase to phase fault

Internal phase to phase fault

CURRENT CONTROL

ibias A > phase A bias current threshold ibias B > phase B bias current threshold ibias C > phase C bias current threshold

0 0 0

0 or 1 0 or 1 0 or 1

0 or 1 0 or 1 0 or 1

1 1 1

1 1 1

SEF blocking order : a + b+ c

0 0 or 1 0 or 1 1 1

IDN>1, ISN, (it is assumed that these

0 0 1 0 before saturation

0 or 1


PROTECTION ELEMENT

Before fault detection

External single phase fault

Internal single phase fault

External phase to phase fault

Internal phase to phase fault

thresholds are set less than the minimum earth fault current)

1 during saturation

IDN>2 (this threshold can be set greater or less than maximum earth fault current)

0 0 0 or 1 0 before saturation

1 during saturation

1

Table 6 Sensitive earth fault current control / blocking elements configuration column

Note: In the above table a 1 signifies that the setting has been exceeded in the case of thresholds and a 0 vice versa. A 1 in the SEF blocking order shows that the logic statement Ibias A and Ibias B and Ibias C is true and 0 shows that it is false. A 1 (or true condition) blocks/disables the SEF protection, as described below whilst a 0 (or false condition) keeps the SEF protection active/enabled.

It can be seen that for an internal phase to earth fault only the phase on which the fault has occurred will exceed the setting IbiasPh>Cur but a block will not be issued as PhA + PhB + PhC = 0. The IDN>1 and ISN settings will be exceeded and if appropriate evolve to issue a IDN>2 trip.

For an external phase fault the SEF will be disabled via blocking order.

It can be seen that for an internal phase to phase fault the bias current will be sufficient to enable the SEF blocking order. The SEF protection is then blocked and no trip issued from this element irrespective of SEF setting thresholds being exceeded. The main phase differential protection is then able to react to the fault and issue a trip accordingly.

For an external phase to phase fault the SEF will be disabled via the blocking order.

The sensitive differential earth fault protection is delayed by 20ms to prevent any maloperation during CT saturation condition.


2.3.5 Current Circuit Supervision

During normal operation the differential current in the scheme should be zero or negligible. Any anomaly is detected via a given threshold ID>1.

An unbiased Overcurrent element is used to supervise the current circuit. A differential current will result if the secondary circuit of a CT becomes open circuited; the amplitude of this current is proportional to the load current flowing in the circuit monitored by the faulty current circuit.

The setting is chosen to be as low as possible (minimum suggested setting is 3% of the base current Ibp) but also allow for standing differential current for example due to CT mismatch and varying magnetising current losses. 5 to 20% is a typical application range.

The element is typically time delayed for 5 seconds (set greater than the maximum clearance time). Instead the time delay allows the relevant protection element (which should be substantially faster) to clear the fault instead i.e. ID>2 in the case of an internal phase fault.

2.3.6 Threshold coherency.

The measuring elements have several level detectors for differential current. The protection reacts to any setting inconsistency in the detection of these levels in a specific order. The supervision threshold, ID>1 being the first threshold, with all the other thresholds above it needing confirmation by it. If the thresholds are not exceeded in the correct sequence then an error is detected and an alarm and, or, blocking signal is issued.

The differential element is blocked until the thresholds ID>1, IS and ID>2 are exceeded in the correct sequence.

0.01 0.02

0.5

1

0.1

4

ID>1

Is

ID>2

Settings as multiples of Ibp

Is ID>2

Ibp

P3767ENa

Figure 5: Threshold Coherency


The thresholds must be set so that:

(ID>1) ! (IS) ! (ID>2) and (IDN>1) ! (ISN) ! (IDN>2)

Table 7 below shows operation depending on the threshold coherency.

ID>1 IS + k.Ibias ID>2 Status Operation

0 0 0 Normal -

1 0 0 Circuitry fault Block and circuitry fault alarm after tCF

1 0 1 External fault or circuitry

fault

External fault with CT saturation or block circuitry fault alarm after tCF

1 1 0 Circuitry fault Block and circuitry fault alarm after tCF

1 1 1 Internal fault Trip

Table 7 Threshold Coherency Conditions

ID>1 IS + k.Ibias ID>2 Status

0 0 1 Incoherent setting



Table 8 Threshold Incoherent Setting

2.3.7 Signal Quality

An additional check is carried out to confirm that the signals used to determine the previous criteria are satisfactory.

This includes checking for CT saturation conditions (information from peripheral unit, refer to Section 4.3), that no plant discrepancies exist (via check zone as discussed earlier), and that a change (increase) in current flow has been detected by at least two peripheral units (∆I detection). The latter condition is used, as internal or external faults will cause a change in levels in at least two circuits whereas an CT fail only affect a single circuits levels (faulty CT).

When a trip is issued for a bus zone by the central unit a signal is sent to all peripheral units associated with the faulted bus zone. The peripheral units carry out a further local confirmation via local Overcurrent protection, I>BB or IN>BB, before allowing a trip to take place. This is covered in Section 2.4.1.2.


2.3.8 Tripping Criteria

Before a trip signal is issued five trip criteria at the top level, i.e. the Central Unit, and one at the local level, i.e. the Peripheral Units, must be met.

These criteria are:

− Top level (Central Unit)

− Bias characteristic and Differential current setting exceeded (Idiff> Is + k Ibias)

− Idiff > (ID>2)

− Check Zone Operation

− Setting Coherency: (ID>1) ! (IS) ! (ID>2) and (IDN>1) ! (ISN) ! (IDN>2)

− Signal quality (CT supervision, CT saturation, AD converter, etc)

− Local Level (Peripheral Unit)

− Local confirmation by an instantaneous Overcurrent element (enabled/disabled) (I>BB or IN>BB)

2.4 Peripheral Unit

2.4.1 Busbar Elements

2.4.1.1 Busbar Protection Configuration

Following is a copy of the Differential Elements 87BB column on the relay menu, which is found in the peripheral units P742 and P743. A different configuration column is found in the P741. This is shown in section 2.3.1. All configuration settings applicable to this element are found in this column.

Note: In is the CT nominal current.



BB Trip Confirm

I>BB Current Set 1.2*In 0.05*In 4*In 0.01*In

IN>BB Current 0.2*In 0.05*In 4*In 0.01*In

Table 9 Peripheral Unit differential protection elements configuration column.

The settings required for the local confirmation of a busbar trip are included in this column.

Note: Only values for Group 1 settings are shown. Identical columns/rows exist for setting groups 2, 3 and 4.


2.4.1.2 Busbar Trip Confirmation (87BB) or Central Breaker Fail Trip Confirmation (50BF)

The peripheral units can be enabled to control the trip command issue by the central unit (87BB or 50BF) if a local fault threshold, either phase or earth (i.e. I>BB or IN>BB), is exceeded.

This criterion provides additional scheme stability. Should the command proceed, and a trip be issued to the circuit breaker this element can confirm the evolution of a circuit breaker failure condition. If the element is still operated after a set time delay a breaker failure condition must exist.

2.4.2 Non-directional Phase Fault Overcurrent Protection

Non-directional Phase fault Overcurrent protection is provided as an alternative form of back-up protection. The P742 and P743 relays have two Overcurrent stages for backup protection. The first stage is selectable IDMT or definite time whilst the second stage is definite time only. The Overcurrent protection can be selectively enabled or disabled.

The Overcurrent elements will need to be co-ordinated with any other protection elements on the system, in order to provide discriminative fault clearance. The Overcurrent protection menu column is shown in Table 9. Note In is the CT nominal current.



BB TRIP CONFIRM

BACKUP OVERCURRENT

I>1 Function Disabled Disabled, DT, IEC S Inverse, IEC V Inverse, IEC E Inverse, UK LT Inverse, IEEE M Inverse, IEEE V Inverse, IEEE E Inverse, US Inverse, US ST Inverse

I>1 Current Set 3*In 0.1* In 32* In 0.01* In

I>1 Time Delay 1s 0s 100s 0.01s

I>1 TMS 1 0.025 1.2 0.025

I>1 Time Dial 7 0.5 15 0.1

I>1 Reset Char DT DT/Inverse

I>1tReset 0 0 100 0.1

I>2 Function Disabled Disabled/Blocking Busbar/High Set O/C/Both

I>2 Current Set 20* In 0.10* In 32* In 0.01* In

I>2 Time Delay 1s 0s 10s 0.01s

Table 10 Phase Fault Overcurrent Protection Configuration Column


For the IDMT characteristics the following options are available.

The IEC/UK IDMT curves conform to the following formula:

t TK

IsL= ×

−+(

( / ))

I α 1 EQEQ

The IEEE/US IDMT curves conform to the following formula:

tTD K

IsL= ×

−+

7 1(( / )

)I α

EQEQ

t = operation time

K = constant

Ι = measured current

Ιs = current threshold setting

α = constant

L = ANSI/IEEE constant (zero for IEC curves)

T = Time multiplier setting for IEC/UK curves

TD = Time multiplier setting for IEEE/US curves

Figure 6: IDMT Characteristic Curves


Figure 7: IEEE Characteristic Curves

IDMT characteristics

IDMT Curve description Standard K constant α constant L constant

Standard Inverse IEC 0.14 0.02 0

Very Inverse IEC 13.5 1 0

Extremely Inverse IEC 80 2 0

Long Time Inverse UK 120 1 0

Moderately Inverse IEEE 0.0515 0.02 0.114

Very Inverse IEEE 19.61 2 0.491

Extremely Inverse IEEE 28.2 2 0.1217

Inverse US-C08 5.95 2 0.18

Short Time Inverse US-C02 0.02394 0.02 0.01694

Table 11 IDMT Characteristics


2.4.2.1 IDMT Characteristics

Note that the IEEE and US curves are set differently to the IEC/UK curves, with regard to the time setting. A time multiplier setting (TMS) is used to adjust the operating time of the IEC curves, whereas a time dial setting is employed for the IEEE/US curves. Both the TMS and Time Dial settings act as multipliers on the basic characteristics but the scaling of the time dial is approximately 10 times that of the TMS, as shown in the previous menu. The menu is arranged such that if an IEC/UK curve is selected, the Ι> Time Dial cell is not visible and vice versa for the TMS setting.

2.4.3 Non-Directional Earth Fault Overcurrent Protection

The P742 and P743 relays include backup non-directional earth fault protection. The earth fault element has two stages of protection. The earth fault element needs to be co-ordinated with any other protection elements on the system, in order to provide discriminative fault clearance. The inverse time characteristics available for the earth fault protection, are the same as those for the Overcurrent element. The earth fault settings are shown below.

Note: Ιn is the CT nominal current.



OVERCURRENT

O/C EARTH FAULT

ΙN>1 Function Disabled Disabled, DT, IEC S Inverse, IEC V Inverse, IEC E Inverse, UK LT Inverse, IEEE M Inverse, IEEE V Inverse, IEEE E Inverse, US Inverse, US ST Inverse

ΙN>1 Current Set 0.3*Ιn 0.1*Ιn 32*Ιn 0.01*Ιn

ΙN>1 Time Delay 1s 0s 100s 0.01s

ΙN>1 TMS 1 0.025 1.2 0.025

ΙN>1 Time Dial 7 0.5 15 0.1

ΙN>1 Reset Char DT DT/Inverse

ΙN>1tReset 0 0 100 0.1

ΙN>2 Function Disabled Disabled/Blocking Busbar/High Set O/C/Both

ΙN>2 Current Set 20* Ιn 0.10*Ιn 32* Ιn 0.01* Ιn

ΙN>2 Time Delay 1s 0s 10s 0.01s

Table 12 Earth Fault Overcurrent Protection Configuration Column


2.4.4 External Fault Detection by High-Set Overcurrent or Earth Fault Element

There are feeders where, if the power is sufficiently low in relation to the maximum short circuit power of the busbar, it can be impossible to distinguish between an internal or external fault by measuring the current magnitude.

The feeders in question are mainly transformer feeders where the short circuit reactance poses significant limitations. Thus, knowing the feeders maximum possible contribution to the busbar fault current, it is easy to infer that exceeding this value will indicate an external fault. In certain cases it is just the presence of a current that will indicate an external fault.

Normally the P740 scheme may detect a fault, but a saturation condition is also detected before this is allowed. In this scenario saturation may not occur until after the scheme has eliminated a saturation condition and allowed a trip to be issued for the external fault.

An ultra high-speed detection is carried out by each of the peripheral units (P742 and P743) and can generate a blocking signal from the moment of the first sample at 0.42 ms.

This function can be activated independently for phase faults (Ι>2) and for earth faults (ΙN>2). A setting example for these thresholds is shown in Figure 8.

2.4.4.1 Application Example

3000/5A 3000/5A

3000/5A

1500/5AI>2 enabledIN>2 enabledI>2 enabledIN>2 enabled

I>2 enabledIN>2 enabledBlocking orderto 87BB element

150/5A25VA5P10

150/5A25VA5P10

ph-ph <300Aph-N 0A

TR11115/13,8K25 MVAX = 12%

ph-ph 30 000Aph-N 7 500A

TR12115/13,8K25 MVAX = 12%

Example of use of high speed detectorsI>2 and/or IN>2 to block the 87BB

element before CT saturation

P3770ENa

Figure 8: Transformer Feeder example

An example where this facility is required, where there is a high risk of CT saturation, is shown in the above example.

The problem, lies in the transformer feeder circuits TR11 and TR12 both 115/13.8kV, rated power 25 MVA with a reactance of 12%. Both feeders are equipped with 150/5 A CTs. (If rating is 25 MVA I=125A @115 kV). Maximum busbar short circuit current is 30kA phase to phase and 7.5kA phase to earth.


The contribution of each transformer feeder under internal fault conditions is as follows:-

1. Less than 300 A for phase to phase faults Would the contribution from the transformers be a maximum of 1045 A ie 1/X% x Ifull load

2. 0 A for phase to earth faults.

When an external fault occurs on one of the transformer feeders, the fault MVA will be the same as that for an internal fault but the feeder will be subjected to an excessively high Overcurrent condition as compared to normal load conditions at rated current.

In the example shown, under the external fault condition, the short-circuit phase to phase current is 200 times the primary rated current. (150 A x 200=30 kA). Taking into account the CT and initial flux estimated at 80% of that at full load, saturation will be detected at 10 times In, where In is the CT nominal current in this case in primary values (150 A x 10 = 1500 A)

With Ιsaturation = 1500 A and Ιshort-circuit = 30000 A = 20 x Ιsaturation.

If the assumption is taken that there is no remnant flux, saturation will be detected 1.4 ms after the appearance of the fault. At which time the current will have reached 0.4 times the maximum value i.e. 1200 A.

Data relating to transformer flux derived from typical magnetising characteristics.

Conclusion: An ultra fast Overcurrent detector in the P742 and P743 when used on HV/MV transformer feeders makes it possible to pre-empt CT saturation and establish an external fault condition. The setting used for this detection is Ι>2 for phase faults and ΙN>2 for earth faults. The detection of I>2 used a settable drop-off timer (Block Duration).

In this example a setting of 1305 A can be used for both phase and earth faults.

2.4.5 Supervision

Following is a copy of the SUPERVISION column on the relay menu, which is found in the peripheral units P742 and P743. All configuration settings applicable to this element are found in this column.

Note: In is the CT nominal current.



SUPERVISION ELEMENTS

ΙO Supervision

Error Factor KCE 0.40 0.01 1 0.01

Alarm Delay TCE 5 0 10 0.1

Table 13 Supervision Configuration Column


2.4.6 Zero Sequence Current (ΙO) Supervision.

The four current inputs to the peripheral units are used to verify that the calculated zero sequence current is within the correct range for CT supervision purposes. This then provides continuous supervision of the local current transformer and of the relay measurement chaining (CTs, ADC, etc).

The residual current 3Ιo is derived from the three phases Ιa + Ιb + Ιc and compared to the measured value of ΙN from the neutral CT input.

|3ΙO - ΙN |

During an earth fault the two values should be the same and the sum should therefore be equal to zero or below the threshold (CTS ΙN> Set) and the CT supervision alarm will not be issued.

If a CT becomes disconnected a difference between the derived and measured value will appear, i.e. a CT problem has been detected and after a user settable time delay (CTS Time delay) the alarm will be issued.

This calculation is then compared to a further criterion to verify and monitor CT connections and associated current circuits.

|3ΙO - ΙN |> 0.05 Ιn + KCE x (|Ιa| + |Ιb| + |Ιc| + |ΙN| )

(Where KCE is a calculation error coefficient and In is the nominal current) The calculation error coefficient in the above formula is set between 0.01 and 1 thereby allowing for small discrepancies and preventing false blocking of the differential elements whilst the constant value of 0.05 In provides stability under no load or low load conditions.

Main causes for alarms from zero sequence current calculations are:-

− Commissioning with load current detection of connection errors (input inverted/rated current incorrect)

− Maintenance with load current By pass of analogue input, when a separate neutral CT is made available.

− Failure of an analogue channel e.g. A/D converter failure

Once detected the alarm will be issued after a user settable time delay (Alarm Delay TCE).

Because the peripheral units sample at 2400Hz discrepancies between the measured and derived values are identified and responded to very quickly. If any anomalies arise for either of the above calculations the differential elements associated with the faulty peripheral unit are instantaneously blocked. The blocking signal remains in place for 10ms with an alarm signal sent after the time delay. The time delay is usually set above the time required to trip under fault conditions.


3. CIRCUIT BREAKER FAIL (CBF)

Following is a copy of the CB FAIL column on the relay menu, which is found in the peripheral units P742 and P743. The P740 scheme has integral CB fail protection within its logic but can also accept external initiation from other protection. All configuration settings applicable to this element are found in this column: -



CB FAIL

Control by I< I<; 52a or both

I< Current Set 0.05*In 0.05*In 1*In 0.01*In

I> Status Disabled Enabled/Disabled

I> Current Set 1.2*In 0.05*In 4*In 0.01*In

IN> Current Set 0.2*In 0.05*In 4*In 0.01*In

INTERNAL TRIP

CB Fail Timer 1 0.05 0 10 0.01

CB Fail Timer 2 0.2 0 10 0.01

EXTERNAL TRIP

CB Fail Timer 3 0.05 0 10 0.01

CB Fail Timer 4 0.2 0 10 0.01

Table 14 Circuit Breaker Fail Configuration Column

Note: CB Fail 2 Timer > CB Fail 1 Timer

and

CB Fail 4 Timer > CB Fail 3 Timer

The detailed logic of the circuit breaker failure element follows.

3.1 Distributed Tripping, Control and Indication Elements (Peripheral Units)

As the P740 scheme has been designed for use as either a centralised or distributed scheme, the hardware corresponds to one circuit breaker and can accommodate 1 or 2 trip coils:

− 1 main trip coil

− 1 back-up trip coil

Furthermore these can be either 3 single-phase trip coils or 1 three-phase trip coil. These can be combined for example 3 single-phase trip coils on the main system and 1 three-phase trip coil for the back-up system.


3.2 Circuit Breaker Fail Criteria

3.2.1 Current Criterion

The criterion normally used for the detection of an open circuit breaker pole is the disappearance of the current i.e. undercurrent element. This function is generally preferred above other elements due to the response time. In P740 this method of detection is utilised and has the threshold I<.

3.2.2 Logic Criterion

This criterion is based on checking the state of the circuit breaker auxiliary contacts. i.e. to see if the 52a contact is open for open circuit breaker conditions.

3.2.2.1 Overcurrent Criterion

One of the most common causes of busbar mal-tripping is error introduced in the back tripping of adjacent sections. To prevent such an error it is possible to condition the operation of 50BF protection only when there is presence of a significant current i.e. a short-circuit on the concerned feeder. This confirmation is provided by the I> threshold which is set by default at 1.2 times the nominal rated current of the CT and/or by the threshold setting of residual current IN> set by default to 0.2 times the rated current.

3.3 Processing A Circuit Breaker Failure Condition

Due to the nature of the busbar protection, the substation topology can manage the system under circuit breaker failure conditions (50BF).

There are several options for circuit breaker failure protection installations. Generally these depend on the substation construction and wiring:

− Internally initiated CBF i.e. Initiation from the differential element, 87BB, trip

− Externally initiated, for example by the feeder protection, but using the busbar protections integral 50BF protection to execute tripping procedure

− Separate 50BF protection to the busbar protection

The breaker failure logic uses fast acting undercurrent elements to provide the required current check. These elements reset within 15ms, thereby allowing the use of the P740 relay at all voltage levels.

Since the Overcurrent element within the peripheral units may also be used in blocking schemes to provide back-up protection, it is possible to reset the Overcurrent start signals after the breaker fail time delay has elapsed. This ensures that the upstream back-up protection can be maintained by removal of the blocking signal. This would also ensure that the possible risk of re-trip on re-closure of the circuit breaker is minimised.


52

aP

ha

se

A

I<

A

I<

B

I<

C

0

Tn1

0

Tn1

0

Tn1

& & &Ext

ern

altr

ipsi

gnalfr

om

peri

phera

lunit

(21

,8

7T,

etc

….)

Tp

A Tp

B Tp

C

0 0 0

0 0 0

TBF3

Retr

iptim

edela

y

IBIA IC

0

25

0m

s

I>

a

I>

b c

0

Tn2

0

Tn2

0

=1

IBIA IC

& & &

& & &

=1

=1

=1

=1

CB

FAIL

ALA

RM

CB

FAIL

ALA

RM

BB/F

FBusb

ar

Trip

on

feeder

fault

=1

=1

=1

TBF1

0&

TBF2-T

BF1

0&

0

25

0m

s

=1

&

52a

Ph

ase

B

52

aP

ha

se

C

Trip

sig

nalto

localC

BB

us

Couple

r

from

Busbar

pro

tection

3phases

Trip

(TpA

BC

)

IN>

N

0

Tn

2

Tn

2

IN

TBF3

TBF3

TBF3

=1

=1

TBF4

Back

trip

tim

edela

y

TBF4-

TBF3

TBF4-

TBF3

TBF4-

TBF3

Dead

pole

dete

ctio

n

I>

Fault

Dete

ctio

n

52a

Enable

I,IN

>Retr

ip&

back

trip

confirm

ation

I,IN

>Retr

ip&

back

trip

confirm

ation

TBF1

Back

trip

tim

edela

yT

BF2

Back

trip

tim

edela

y

Re

trip

Phase

AFeeder

Fault

Re

trip

Phase

BFeeder

Fault

Retr

ipPhase

CFeeder

Fault

Busb

ar2

Trip

on

Busb

ar1

Fault

Loca

lre

trip

on

Busb

ar

Fault

1 2 3 4 5 6 7

8 9 10

11

P3

73

8E

Na12

13

Figure 9: CB Fail Logic


P3739ENa

>1

>1

>1

DDB Ext. CB Fail

DDB O/C Protection

DDB Ext. 3ph Trip

DDB External Trip A

DDB External Trip B

DDB External Trip C

1

2

3

>1

>1

>1

DDB CB Aux. 3ph (52a)

DDB CB Aux. A (52a)

DDB CB Aux. B (52a)

DDB CB Aux. C (52a)

4

5

6

7Trip signal from CU

8

12

13

>1

DDB CBF Int Backtrip

DDB CBF Ext Backtrip

DDB Int Retrip 3ph

9

10

11

DDB Ext. Retrip ph A

DDB Ext. Retrip ph B

DDB Ext. Retrip ph C

DDB BF Trip RequestTrip signal towards CU

CB FailLogic

(See Fig 9)

Figure 9bis: CB Fail Logic (DDB Inputs & Outputs)

3.3.1 Internally Initiated CBF i.e. Tripping from the Differential Element 87BB

When a tripping order is generated by the busbar protection (87BB or 50BF) but not executed due to a circuit breaker failure condition, the following circuit breakers are required to be tripped instead:

− The remote end circuit breaker if the faulty circuit breaker is that of a feeder (line or transformer). This intertripping is optional (via PSL) and may not be required on feeders, which may be serviced automatically via the distance or other line protection.

− All the circuit breakers in the adjacent busbar zone if the faulty circuit breaker is that of a bus coupler or bus section.

The tripping order from the busbar protection is referenced as TpABC, it is always three-phase and initiates timers tBF1 and tBF2. The first timer is associated with the local re-trip function while the second timer is associated with the conveyance of the signal to the central unit for tripping of the adjacent zone in the cases of bus coupler/bus section circuit breaker failure.


3.3.1.1 Description of the Logic for Internally Initiated CBF

Local overcurrent element 87BB confirmation

I<Dead pole detection threshold

I> (note 2)

Local overcurrent element CBF confirmation

&

& &tBF1

tBF2-tBF1 &

BBx

LocalRetrip

LocalCircuitBreaker

TpABC: Tripping signal from 87BB

Note 1: Signal to CU for back-trip (including adjacent zone(s) if failed CB is bus section or bus coupler circuit breaker

Back trip(Note 1)

I>BB (note 2)

Trip signalfrom CU

Main busbar protection trip signal

Note 2: I>BB and I> could be enabled or disabled (scheme shown is with the 2 functions enhanced)

P3771ENa

Figure 10: CB Fail Element Logic Internally Initiated

3.3.1.1.1 Initial Trip

A trip signal is issued by the central unit and then confirmed by the local peripheral unit. If the threshold for the local Overcurrent protection setting for busbar protection (I>BB) is exceeded then the local circuit breaker trip coil is energised and subsequently the local circuit breaker is tripped.

3.3.1.1.2 Re-Trip after time tBF1

The peripheral units dead pole detection threshold (I<) and external protection initiation (I>) trigger the first breaker failure timer (tBF1). This signal in turn is passed through an AND gate with the signal from the local Overcurrent protection for busbar protection (I>BB) (if a circuit breaker failure condition has evolved this will still be present) and a re-trip command is issued. Re-trip output contacts should be assigned using the PSL editor (including in default PSL settings).

3.3.1.1.3 Back Trip after time tBF2

A signal from the first circuit breaker timer triggers the second breaker failure timer (tBF2). This in turn is passed through an AND gate with the signal from the local overcurrent protection for busbar protection (I>BB), if a circuit breaker failure condition has persisted this will still be present, and a general bus-zone trip signal issued via the central unit. In summary tBF1 is used for re-trip and tBF2 for general bus zone trip

Because the busbar protection scheme uses the system topology, during circuit breaker failure conditions, circuit breaker operations are executed according to on the current state of the system. It is therefore of paramount importance that should an internally initiated scheme be implemented, the circuit breaker tripping order, must be thoroughly defined within the scheme topology to guarantee correct scheme operation.


OtherProtection

P3758ENa

BB1

Trip Order (1)

PU

50BF

PU

50BF

CU 87BB

PU

50BF

CB

Failed

(2)

Main Trip

or Retrip

Back Trip

CB Fail signal (3) Back Trip Order (4)

BB2

Figure 11: Circuit Breaker Failure Logic

Z1

P3740ENa

PU

PU

PU

PU PU PU PU

PU PU

PU PU

PU PU

PU PU PU

Z2

Z3 Z4

Remote Substation

CBA

Fault in Z2 CB failed:

Back trip Z2 to Z1

and A

Z1

P3741ENa

PU

PU

PU

PU PU PU PU

PU PU

PU PU

PU PU

PU PU PU

Z2

Z3 Z4

Remote Substation

CBB

Fault in Z3 CB failed:

Back trip to remote end

and B

Figure 11bis: Examples

3.3.2 Externally Initiated 50BF

I<Dead pole detection threshold

I>Local oversurrent element CBF confirmation

& &tBF3

tBF4-tBF3 &

BBx

LocalRetrip(Note 2)

LocalCircuitBreaker

TpA, TpB or TpC: Tripping signal from external protection

Note 1: Signal to CU for back-trip (including adjacent zone(s) if failed CB is bus section or bus coupler circuit breakerNote 2: Optional, refer to section 3.3.2.1Note 3: I> could be enable or disable

Back trip(Note 1)

ExternalProtectionInitiation

P3772ENa

Figure 12: CB Fail Element Logic Externally Initiated


Taking into account the relationship between the busbar protection and the circuit breaker failure protection certain operators prefer an integrated solution where the breaker failure may be initiated by external protection but executed in the busbar scheme. Tripping is then worked out in the section or zone.

On an overhead line for example the external commands may be generated by the distance protection (21). Generally these commands are on a per phase basis and therefore the tripping commands must be to. In the diagrams these signals are labelled TpA, TpB, TpC (Tripping pole A, B or C).

The logic is similar to that for internally initiated CB fail protection but utilises tBf3 for re-trip and tBF4 for back-trip functions.

3.3.2.1 Local re-trip after time tBf3

This re-trip command can be applied via either the main or back up trip coil. It is possible to choose between the 3 following modes:

− Local re-trip activated/deactivated via PSL. The relay used for this function can use the same fixed logic for the busbar protection or other independent relays.

− A re-trip can be applied after a time tBF3. This is typically set at 50ms when a single phase trip and re-trip is used. This prevents loss of phase selectivity by allowing the main protection trip to execute via the main CB trip coil before re-trip command is executed by the back-up CB trip coil.

− Single or three phase re-trip is possible. If the feeder protection executes single-phase tripping, the three-phase re-trip must be carried out in time tBF3 and this must be adjusted to have a value higher than the normal operation time of the circuit breaker. Typical setting under this condition is 150ms.

3.3.2.2 General zone trip after time tBF4

When both the local trip and re-trip have failed, the countdown continues with a second timer adjusted to have a value of tBF4 - tBF3. The end of this time thus corresponds to total time tBF4, beyond which a persistent circuit breaker failure condition is declared.

Information is then relayed to the Central unit for routing to the other peripheral units, and the associated circuit breakers, in the adjacent zone(s) for a general three-phase back-trip.

3.3.3 Separate external 50BF protection to the busbar protection

This is the most common solution utilising conventional wiring. The 50BF relay is completely independent of all others. When a circuit breaker failure condition occurs the external protection trips all adjacent circuit breakers as defined in the separate scheme (DDB Ext. CB fail).

In view of the connection between the functions of the busbar protection and the circuit breaker failure protection some operators prefer one of the more integrated system solutions previously mentioned.


4. CURRENT TRANSFORMERS

Following is a copy of the CT ratio column in the peripheral unit menu. Only P742 and P743 units have the CT ratio menu as they are connected to the primary plant. All configuration settings specific to the current transformers can be found in this column:-



CT RATIO Note: Practical largest range 50/In to 5000/In in the same substation

Phase CT Primary 1000A 1A 30000A 1A

Phase CT Sec'y In 1A 1A 5A 4A

CT Class X 5P (IEC185) X (BS3938) TPX (IEC44-6) TPY (IEC44-6) TPZ (IEC44-6)

RBPh / RBN 1 0.5 10 0.1

Power Parameters

BRITISH STANDARD Knee voltage Vk

250/In 100/In 5000/In 10/In

IEC Rated Burden VA

25 5 100 1

IEC Rated Burden Ohm (calculated value)

25 / In2Ω 5 / In

2Ω 100 / In2Ω 1 / In

2Ω

IEC Rated short-circuit factor Kscc

10 10 50 5

Secondary RCT 0.5 0.1 50 0.1

Eff Burden Ohm 25 / In2Ω 1 / In

2Ω 200 / In2Ω 1 / In

2Ω

Eff Burden VA (calculated value)

25 0.1 200 0.01

Table 15 Peripheral Unit CT Configuration Column

It is important that the CT settings are entered in full as these are required to calculate additional parameters for use in the saturation detection algorithms that run within the peripheral units.


4.1 CT Mismatch

A P740 scheme can accommodate different CT ratios throughout the protected zone. This mismatch must, therefore, be accounted for by the scheme. This is achieved by using a base ratio to which the central unit converts all of the analogue values when undertaking scheme calculations.

The interface permits a range of 1 A to 30000 A. In practice the range 50 A to 5000 A is most common and should not be exceeded. In practice, a common base current of 1000 A is usually selected.

4.1.1 Adjusting the Scheme Base Ratio

As has been mentioned in Section 4.1 using a base current and adjusting all analogue values to this current when undertaking scheme calculations, i.e. differential current calculation, means that CT mismatch can be accommodated.

As scheme calculations are carried out in the central unit the setting for this base current is only found in this unit. To set the scheme base ratio the setting for the common base current, or common setting base, in the central unit must be adjusted in the Measurement Set-up menu column in the Central Unit.



Common conventional ratio

Ibp Current Set 1000 A 1 A 10000 A 1 A

Table 16 Scheme base current setting in CU

This current setting corresponds to primary values and can be set to between 1A and 10,000A. In practice a common base current of the highest primary nominal current of main CT is recommended, as this is easy to manipulate.

Changing the base current in this cell adjusts the base for the entire scheme and no further setting changes need to be carried out.

P.U. P.U. P.U.P.U.

C.U.

Available ibase

4000A / 3000A / 2000A / 1000A

3000/52000/5 1000/5 500/5

5/3 ibase 5/2 i

base5/1 i

base5/0.5 i

base

P3773ENa

Figure 13: Accommodating CT mismatch using the scheme base current


As can be seen in the above example all analogue values are converted to the base value via relevant ratio.

e.g. Ibp taken as 1000 A as recommended

− Feeder 1 equipped with the 3000/5 CT. All values need to be adjusted by 5/3 Ibp.

− Feeder 2 equipped with the 500/5 CT. All values need to be adjusted by 5/0.5 Ibp .

For a current of 1250 A

Feeder 1 Isecondary = (1250 x 5)/3000 = 2.083 A

Converted to base current

Icorrected = 2.083 x 3 x 1000/5 = 1250 A

Feeder 2 Isecondary = (1250 x 5)/500 = 12.5 A

Converted to base current

Icorrected = 12.5 x 0.5 x 1000/5 = 1250 A

This shows that even though the values obtained at the CT secondary are different, when the base current correction is applied the value is the same and therefore correct on a scheme basis.

These values are then used for all scheme calculations.

4.2 CT Requirements

4.2.1 Notation

IF max maximum fault current (same for all feeders)

IF max int maximum contribution from a feeder to an internal fault (depends on the feeder).

Inp CT primary rated current

In nominal secondary current (1A or 5A)

RCT CT secondary winding Resistance

RB Total external load resistance

Vk CT knee point voltage

SVA Nominal output in VA,

KSSC Short-circuit current coefficient (generally 20)

General recommendations for the specification of protection CTs use common rules of engineering which are not directly related to a particular protection.


4.2.2 Feeders connected to sources of significant power (i.e. lines and generators)

The primary rated current is specified above a 1/20th of the maximum contribution of the feeder to internal faults.

i.e. Inp = IF max int/20

e.g. A power line likely to import electricity at 20 kA gives rated primary current Inp as 1000 A.

This recommendation is used for the majority of line or transformer protection applications.

4.2.3 Out of service feeders or those with low power contribution (low infeed)

Because of CT construction, thermal behaviour, and electrodynamics the CT primary rated current cannot be as low as required compared to the maximum fault current. In the case of a CT with primary bushings and not wound there is not a precise limit but a practical one. The primary rated current could not be lower than the 1/200th of the maximum short-circuit current crossing the CT at the time of an external fault

i.e. Inp = IF max /200

This is possible using the fast overcurrent detection I>2 to distinguish between an internal or external fault in case of CT saturation below than 2 ms

e.g. For a sub station whose maximum short-circuit current would be 30 kA, the CTs on the least powerful feeders are to be specified for a rated primary current Inp = 150 A, even if the normal consumption of the feeder is much lower than this value (Sub-station transformer feeder)

4.2.4 CT Specification according to IEC 185, 44-6 and BS 3938 (British Standard)

1. Class X according to British Standard: Minimum knee point voltage for saturation

Vk min = 0.5 x secondary IF max x (RCT + RB)

The recommended specification makes it possible to guarantee a saturation time > 1.4 ms with a remnant flux of 80 % of maximum flux (class X or TPX). This provides a sufficient margin of security for CT saturation detection, which operates in less 2 ms.

2. Class 5P to IEC 185. Conversion of class X (BS) with the 5P equivalent (IEC)

3. Class TPX and TPY according to IEC 44-6. IEC defines a composite error as a percentage of a multiple of the rated current (IN) on a definite load SVA.

e.g. CT 1000/5 A 50VA 5P 20.


This definition indicates that the composite error must be lower than 5%, for a primary current of 20Inp when the external load is equal to 2 ohms (50VA to In). If secondary resistance, RCT, is known it is easy to calculate the magnetising EMF developed with the fault current (20In). Actually if the error is 5% (= 5A) with this EMF, the point of operation is beyond the knee point voltage for saturation. By convention one admits that the knee point voltage, Vk, is 80% of this value. For a conversion between a class 5P (IEC) and a class X (BS) CT one uses the relation:

Vk=0.8 X [(SVA x Kssc)/In + (RCT x Kscc x In) ]

SVA = (In x Vk/0.8 Kssc) RCT x In2

In particular cases, calculation could reveal values too low to correspond to industrial standards. In this case the minima will be: SVA min = 10 VA 5P 20 which corresponds to a knee point voltage of approximately Vkmin = 70 V at 5A or 350V at 1A. Class TPY would permit lower values of power, (demagnetisation air-gap). Taking into account the weak requirements of class X or TPX one can keep specifications common.

For accuracy, class X or class 5P current transformers (CTs) are strongly recommended. The knee point voltage of the CTs should comply with the minimum requirements of the formulae shown below.

Vk ≥ k (RCT + RB)

Where:

Vk = Required knee point voltage

k = Dimensioning factor

RCT = CT secondary resistance

RL = Circuit resistance from CT to relay

RB = Burden resistance

k is a constant depending on:

If = Maximum value of through fault current for stability (multiple of In)

X/R = Primary system X/R ratio

Thus the following expression can be derived.

Vk ≥ IF.(1+X/R).(RCT + RB)

The following CT requirement can be developed for the P740 scheme

Vk > 0.5 x (secondary If max) x (RCT + RB)

With RB = 2 RL


4.2.5 Support of IEEE C Class CTs

MiCOM Px40 series protection is compatible with ANSI/IEEE current transformers as specified in the IEEE C57.13 standard. The applicable class for protection is class C, which specifies a non air-gapped core. The CT design is identical to IEC class P, or British Standard class X, but the rating is specified differently. The following table allows C57.13 ratings to be translated into an IEC/BS knee point voltage

IEEE C57.13 C Classification (volts)

C50 C100 C200 C400 C800 CT Ratio RCT (ohm)

Vk Vk Vk Vk Vk

100/5 0.04 56.5 109 214 424 844

200/5 0.8 60.5 113 218 428 848

400/5 0.16 68.5 121 226 436 856

800/5 0.32 84.5 137 242 452 872

1000/5 0.4 92.5 145 250 460 880

1500/5 0.6 112.5 165 270 480 900

2000/5 0.8 132.5 185 290 500 920

3000/5 1.2 172.5 225 330 540 960

Table 17 IEC/BS Knee Point Voltage Vk offered by C class CTs

Assumptions:

1. For 5A CTs, the typical resistance is 0.002 ohms/secondary turn

2. IEC/BS knee is typically 5% higher than ANSI/IEEE knee

Given:

3. IEC/BS knee is specified as an internal EMF, whereas the C class voltage is specified at the CT output terminals. To convert from ANSI/IEEE to IEC/BS requires the voltage drop across the CTs secondary winding resistance to be added.

4. IEEE CTs are always rated at 5A secondary

5. The rated dynamic current output of a C class CT (Kssc) is always 20 x In

Vk = (C x 1.05) + (In. RCT. Kssc)

Where:

Vk = Equivalent IEC or BS knee point voltage

C = C Rating

In = 5A

RCT = CT secondary winding resistance

Kssc = 20 times


4.3 CT Saturation detection

Innovative methods are used to detect CT saturation in the P740. The values associated with the CT saturation algorithms are entered into the Peripheral Units CT ratio menu column shown in table 14 and are used to define the CTs characteristic. The algorithms for CT saturation detection are executed in the peripheral units.

The first algorithm to be examined is the detection of variation of current.

The PU calculates the derived current and compares it to the magnitude of the waveform. With 2400Hz sampling, maximum variation between 2 successive samples of sinusoidal current can not exceed 14% of the magnitude.

The magnitude of the current is the maximum value of the current measure during the last period with a minimum of 50% of nominal current. A variation is detected is derived current exceed 20% of this magnitude.

This instantaneous value is maintained 150ms for the first variation then 50ms for the next ones, as shown as figure 14.

Figure 14:


The second algorithm, by integration of the secondary current, presumes of maximum flux in the core.

The flux calculation starts when the first variation of current is detected, then if the calculated flux reached 20% of the maximum flux, a CT saturation is presumed as shown in figure 15.

Figure 15: Determination of Signal Quality in Peripheral Unit

CT saturation detection starts at the first variation of current detected and stop if there is no variation during 100ms. CT saturation is detected when there are a variation of current and a presumption of maximum flux detected, as shown figure 4. When CT saturation appears, blocking order is sent to CU to lock the relevant zones.


P3774ENa

Figure 16: Determination of Signal Quality in Peripheral Unit

Blocking of the differential protection via the high speed external fault element is discussed in Section 2.4.4.


4.4 CT Location

There are no restrictions imposed as to the location of current transformers within the system, however, when the topological model is created the position and orientation of the current transformers must be defined correctly to ensure the correct operation of the protection.

A suggested current transformer location is to position the current transformer for the busbar protection, line side of the circuit breaker whilst the line protection current transformers are positioned busbar side of the circuit breaker. This then covers the largest possible busbar zone providing an overlap with the line protection therefore eliminating any possible blind spots. This is shown in Figure 17.

P3775ENa

Figure 17: CT Location


5. CIRCUIT BREAKER FUNCTION

5.1 Circuit breaker state monitoring

An operator at a remote location requires a reliable indication of the state of the switchgear. Without an indication that each circuit breaker is either open or closed, the operator has insufficient information to decide on switching operations. The relay incorporates circuit breaker state monitoring, giving an indication of the position of the circuit breaker, or, if the state is unknown, an alarm is raised.

5.1.1 Circuit Breaker State Monitoring Features

MiCOM relays can be set to monitor normally open (52a) and normally closed (52b) auxiliary contacts of the circuit breaker. Under healthy conditions, these contacts will be in opposite states. Should both sets of contacts be open, this would indicate one of the following conditions:

− Auxiliary contacts / wiring defective

− Circuit Breaker (CB) is defective

− CB is in isolated position

Should both sets of contacts be closed, only one of the following two conditions would apply:

− Auxiliary contacts / wiring defective

− Circuit Breaker (CB) is defective

If any of the above conditions exist, an alarm will be issued after a 200ms time delay. A normally open / normally closed output contact can be assigned to this function via the programmable scheme logic (PSL). The time delay is set to avoid unwanted operation during normal switching duties.

In the PSL CB AUX could be used or not, following the four options:

− None

− Both 52A and 52B (2 optos)

− Both 52A and 52B (6 optos)

Where None is selected no CB status will be available. This will directly affect any function within the relay that requires this signal, for example CB control, Topology, etc. If both 52A and 52B are used then status information will be available and in addition a discrepancy alarm will be possible, according to the following table. 52A and 52B inputs are assigned to relay opto-isolated inputs via the PSL.


Auxiliary Contact Position CB State Detected Action

52A 52B

Open Closed Breaker Open Circuit breaker healthy

Closed Open Breaker Closed Circuit breaker healthy

Closed Closed CB Failure Alarm raised if the condition persists for greater than 200ms

Open Open State Unknown Alarm raised if the condition persists for greater than 200ms

5.2 Circuit Breaker Control

The relay includes the following options for control of a single circuit breaker:

− Local tripping and closing, via the relay menu

− Local tripping and closing, via relay opto-isolated inputs

It is recommended that separate relay output contacts are allocated for remote circuit breaker control and protection tripping. This enables the control outputs to be selected via a local/remote selector switch as shown below. Where this feature is not required the same output contact(s) can be used for both protection and remote tripping.

C lo s e

Tr ip0c lo se

Lo ca lR em o te

Trip

Pro tec tio ntr ip

R em o te co n tro ltr ip

R em o teco n tro lc lo se

+ ve

ve

Remote Control of Circuit Breaker


The following table is taken from the relay menu and shows the available settings and commands associated with circuit breaker control.

Menu text Default setting Setting range Step size

Min Max

CB CONTROL

Prot Trip Pulse 0.2s 0.05s 2s 0.01s

Trip Latched Disabled Enabled, Disabled

Reset Trip Latch No Yes, No

CB Control by Disabled Disabled, Local, Remote, Local+Remote, Opto, Opto+local, Opto+Remote, Opto+Rem+local

Man Close Pulse 0.5s 0.1s 10s 0.01s

Man Trip Pulse 0.5s 0.1s 5s 0.01s

Man Close Delay 10s 0.01s 600s 0.01s

A manual trip will be permitted provided that the circuit breaker is initially closed. Likewise, a close command can only be issued if the CB is initially open. To confirm these states it will be necessary to use the breaker 52A and/or 52B contacts via PSL. If no CB auxiliary contacts are available no CB control (manual or auto) will be possible.

Once a CB Close command is initiated the output contact can be set to operate following a user defined time delay (Man Close Delay). This would give personnel time to move away from the circuit breaker following the close command. This time delay will apply to all manual CB Close commands.

The length of the trip or close control pulse can be set via the Man Trip Pulse and Man Close Pulse settings respectively. These should be set long enough to ensure the breaker has completed its open or close cycle before the pulse has elapsed.

Note : The manual close commands for each user interface are found in the System Data column of the menu.

If an attempt to close the breaker is being made, and a protection trip signal is generated, the protection trip command overrides the close command.

If the CB fails to respond to the control command (indicated by no change in the state of CB Status inputs) a CB Fail Trip Control or CB Fail Close Control alarm will be generated after the relevant trip or close pulses have expired. These alarms can be viewed on the relay LCD display or can be assigned to operate output contacts for annunciation using the relays programmable scheme logic (PSL).


5.3 Trip relays

Relays 1, 2, and 3 of PU are used for tripping relays : busbar protection, overcurrent protection and back-trip breaker failure from CU. Even if relay 1, 2, and 3 are not used is PSL, there are closed if there is trip command from these functions. However these relays can be affected in PSL for additional functions (breaker-failure retrip for example).

The settings [CB CONTROL, Prot Trip Pulse] is parameter for Dwell timer used to assure a minimum tripping duration on relay 1, 2, and 3.

5.4 Suggested Trip Circuit Supervision using psl editor

The scheme shown in Figure 18 is designed to provide full H7 compliant trip circuit supervision.

The object of this arrangement is to ensure that all wiring in the trip circuit is monitored, regardless of circuit breaker state. Furthermore the open circuit or short circuit failure of any component in the supervision path would not cause a circuit breaker trip.

P3776ENa

Figure 18: Trip Circuit Supervision

As previously mentioned the resistors should be sized so that shorting of any one device will not lead to a trip:-

− With R1 and R2 in parallel and R3 shorted on CB operation if 52a and 52b overlap, current must be small

− With just R2 in circuit, current is typically 2mA

− With R3 + (R1 // R2) in circuit, current is typically 2mA

P3777ENa

Figure 19: Trip Circuit Supervision CB Closed


Figure 19 shows the trip circuit supervision current path with breaker closed. It can be seen that all the wires in the trip circuit, plus the trip coil are supervised.

P3778ENa

Figure 20: Trip Circuit Supervision CB Open

Figure 20 shows the trip circuit supervision current path with breaker open. It can be seen that all the wires in the trip circuit, plus the trip coil are supervised. This provides full pre-closing supervision

Suggested resistor values are shown in the table below.

Opto Voltage Range (DC)

Tested to meet Minimum Voltage (80% of lower DC voltage rating)

Resistor Values (ohms) Drain Current in circuit/ through trip coil

48/54 38.4 R1=R2=1.2K

R3=0.6K 2mA

110/125 88.0 R1=R2=2.5K

R3=1.2K 2mA

220/250 176.0 R1=R2=5K

R3=2.5K 2mA

Table 18 Trip circuit supervision resistor requirements

Due to the fact that under the circuit conditions shown, the effect of the trip coil inductance in the circuit causes the drop off voltage of the opto-input circuit output to become unstable at 24.1V. Therefore this circuit should only be employed for opto-input applications between 48 and 250V.

For guaranteed operation it is recommended that the opto-inputs be set to the voltage settings below:

Applied voltage (DC)

Relay Voltage Setting

48/54 24

110/125 48

220/250 110

Table 19 Trip circuit supervision opto input voltage settings


For correct operation of the trip circuit supervision the following logic must be implemented in the PSL:

Latching LED

Opto Input 52a

Any Trip Pick-Up400

0

Relay ContactPick-Up400

0

P3733ENa


Figure 21: PSL for Trip Circuit Supervision


6. ISOLATION AND REDUCED FUNCTION MODE

The scheme permits maintenance on the busbar and, or busbar protection whilst maintaining some form of protection if possible. Two levels in the Central Unit and two levels in the Peripheral Units allow this to be possible. A command to one or more of the affected units via the commissioning test menu will then force the scheme to a selected (reduced) operating mode. The levels are as follows.

6.1 Central processing unit (P741)

A central instruction for a reduced operation mode of the busbar protection on two levels can be applied selectively zone by zone.

− Busbar monitoring the busbar protection is monitored (87BB) only (i.e. trip inhibited, measurements enabled). All other protection remains in service and trips can still be issued for CBF conditions.

21-50BF ...

P3734ENa

PU CU

Trip orders for relevant C ’s by 50BF

Trip orders by 87BB blocked

B

Figure 22: Central Unit: Busbar monitoring

Additionally, all protection functions are disabled when the system is awaiting configuration downloads (topology is missing).


− Busbar & CBF disabled - both the busbar and circuit breaker fail conditions are monitored but all trips are inhibited.


21-50BF ...

P3735ENa

PU CU

No Trip orders

for relevant C ’s

(Trip by 50BF & 87BB blocked)

B

At least both

isolators or

CB closed

Figure 23: CU Busbar and Circuit Breaker Fail disabled

Under the condition shown in Figure 23, the circuit breaker is closed as is one of the busbar isolators thereby connecting the feeder to a busbar. However all I/O is disconnected and the protection is out of service. The peripheral unit still relays information regarding the analogue values to the central unit but as the i/o is effectively disconnected the scheme cannot respond to changes in plant position so the differential element is deactivated for that zone.

If this case is true for all feeders the protection is in busbar and circuit breaker fail disabled mode only (87BB) i.e. all trips inhibited, measurements enabled.

6.2 Peripheral Units (P742 and P743)

Three levels of command can be applied selectively to each peripheral unit.

− Normal operating conditions

− I/O disabled

− Out of Service

There also exists a forcing function, which makes it possible, via the front panel user interface, to modify the image of the switchgear positions of the associated bay. This acts as a tool for commissioning, which makes it possible to check CT orientation, as well as the LV wiring, by effectively modelling the primary plant positions without having to interfere with the control circuits, can be used in conjunction with the above operating modes.


Figure 24: PU I/O disabled

In the mode shown in Figure 24 all inputs to and tripping contacts (RL1, RL2, RL3) from the relay are effectively disconnected. The topology algorithm remembers the plant positions prior to switching to maintenance status. As the peripheral unit continues to monitor the analogue values the central unit will maintain a balanced condition with the remainder of the system still in normal operation. However, the local Overcurrent protection is still enabled and able to react to a fault condition by creating a CB fail condition and back tripping the zone(s).

Figure 25: PU Out of Service

In this mode the feeder is totally disconnected from the system. All I/O (tripping contact only) is disconnected and no information is passed back to the central unit for inclusion in zone calculations and hence the protection scheme. Hence the central unit can keep the zone elements in service as the contribution of this feeder will be zero. Whilst in this mode the peripheral unit can be tested locally for example secondary injections tests can be carried out.


Figure 26: Forcing plant position state

Under certain conditions it may be desirable to force the positions of the primary plant to enable scheme testing to be carried out, for example during commissioning. This can be done via the user interface.

In the first example the forced scheme theoretically connects the feeder to busbar 2, whilst in practice it is connected to busbar 1. Zone 1 will see a differential current equal to iload whilst zone 2 will see a differential current equal to +iload this will give a check zone (ΣΣ idiff ) equal to zero.

In the second example the forced scheme theoretically totally disconnects the feeder. An end zone or extra node, is created by the topology in order to fully replicate the scheme. This lies between the feeder CT and the circuit breaker. However, it must be remembered that in practice the feeder is still connected to busbar 1. Zone 1 will see a differential current equal to iload. This extra node will see a differential current equal to +iload and which when included in the check zone (ΣΣ idiff ) will give a result equal to zero.


Extra nodes (end zones) are covered in topology processing section 7.4.

87BB 50BF Local 50/51 I/O Tripping Meas

CU

BB Monitoring Monitored In service Not Applicable

Disabled only input

No 87BB trips

Enabled

BB & CBF disabled

Monitored Disabled Not Applicable

Disabled only input

No 87BB or 50BF

trips

Enabled

System configuration & download

Blocked Blocked Not Applicable

Disabled Disabled Disabled

PU

I/O disabled Enabled Enabled In service Inputs disabled

Only tripping

relays RL1, RL2, RL3 disabled

Disabled on this feeder. Enabled

for remainder of scheme



Out of Service Enabled (no contribution

from this feeder)

Enabled Out of service

(for feeder fault)

Inputs disabled

Only tripping

relays RL1, RL2, RL3 disabled





Forcing Enabled Enabled Cleared via 50BF backtrip.

Enabled

Part enabled.

Plant positions forced to req status





Table 20 Reduce function mode summary


6.3 System operation under failed communications situation

With each start or reboot of CU, all the zones are set to BB and CBF disabled mode as described above. They will remain in this mode until all peripheral units are recognised as being in service and synchronised. (PU CONF & STATUS/PU in service).

If a PU that was considered to be out of service but suddenly communicates with the CU, the CU automatically places all zones to a waiting system configuration mode while waiting for an input from the user to either assign the PU in service or disconnect additional PUs.

During operation, if the communication with a PU is broken, the zone connected to the CT of the non-communicating PU is temporarily suspended. If the communication is restored, the differential protection is restored for the zone. On the other hand, if the break in communications persists longer than permitted (ID>1 Alarm Timer), the zone protection is suspended.

For the reinstatement of the zone the user must intervene:

− If communication is restored the user must reset alarm by the same command to reset circuitry fault (PU CONF & STATUS -> Reset circuitry)

− If the failed feeder needs to be withdrawn from service in order to replace a faulty fibre the PU must be removed from the list of PUs in service.

On the PU, an alarm will indicate loss of communication with the CU.

On the CU, an alarm will indicate that one or more PUs are no longer synchronised.

In the PU CONF & STATUS column, it is possible to view the list of synchronised PU (PU connected) after having altered the list of PU in service (PU in service).

If at the time of the initial startup, the topology of the substation was implemented including futures (for example 15 PU including 6 extensions), it is possible to boot the system only activating the existing 9 PUs in the cell PU in service.

When the future 6 PUs are connected, it will be sufficient to connect them and indicate that they are now in service in the CU menu columns.

6.4 Waiting Configuration

Alarm Config error occurs when the configuration is incorrect:

− Topology download in relay does not correspond to this relay address (be careful to erase topology by sending a default setting file)

− For CU: check the coherency of threshold: ID>2 > IS > ID>1 and IDN>2 > ISN > IDN>1


7. TOPOLOGY

The topological analysis of the state of the sub-station in real time is one of the primary factors of the reliability of numerical differential busbar protection. Thus in the case of a power system fault, this analysis determines the sections of the substation concerned with the fault and only takes those sections out of service. The algorithms available for topological analysis make this level of discrimination possible and it is these algorithms that are utilized in the P740 scheme.

7.1 Topology Configurator

For the P740 scheme the system topology is determined by replication of the circuit, i.e. the connections between the various pieces of plant on the system, via a graphical interface. This topological replication is carried out from a single line diagram of the system, which is used to recreate the system using the topology configurator software. This is carried out by AREVA personnel at an authorised AREVA competence centre.

P740 Scheme Editor P740 Synoptic

The topology configurator uses standard symbols for creating the system model by simply dragging and dropping in the configurator screen.

Bar Link

Node

Current Transformer

Feeder

Circuit Breaker (CB) Isolator

Figure 27: Topology configurator objects

The switchgear/busbars are then labelled and assigned to relevant peripheral units.

When the topology has been fully defined it is compiled and then downloaded to each PU and the CU.


7.2 Nodal Assignment

Three files are created from the topological model. The first identifies each piece of primary plant such as circuit breakers, isolators, current transformer (CT), bus section and feeders. The second file identifies the connections between each piece of primary plant and the third calculates the topological nodal assignment thus making it possible to link to each peripheral unit with associated primary plant of the system.

Algorithms search to determine the electrical topology. These operate in real time in the hardware of the P740 scheme. They start with the information obtained regarding the state of the primary plant. A state table is created and associated with each device. According to the algorithm, this state table gathers the data related to the physical states of the primary plant taken by the unit.

The results of these algorithms are then subjects of a further algorithm, developed from operational research. This algorithm identifies commonality between nodes and merges nodes where appropriate. The new node includes all common nodes.

The principal characteristics of this algorithm mean that the scheme has the following benefits:-

− Adaptability to various sub-station configurations

− Permanent identification of current nodes

− Permanent identification of physical links for each zone

− Reference to the neighbouring circuit breakers for each point of the circuit

These algorithms offer flexibility to the operator not met in non-numeric conventional systems.

The global substation topology is updated every 33ms.

The above improve the overall function and discrimination of the protection scheme and therefore reliability of the network.

7.3 Topology Communication

The peripheral units relay the information regarding their associated topological model to the central unit. The central unit gathers the information from all attached peripheral units and calculates the topological scheme for these as well as carrying out the calculations for the system topology.

7.4 Topology data

Topology results are displayed in Central Unit and locally in Peripheral Units.

For the Central Unit, zones included in each current node are displayed in Topology 1 column and current transformer (or Peripheral Unit) included in each current node are displayed in Topology 2 column.

For the Peripheral Unit, link between current transformer and zones are displayed in Topology column.

Note: If the topology scheme is equipped with a transfer bus outside the protection zone, this link is never reported in Topology column because current transformer is connected to feeder.


7.5 Topology processing

The following scenarios demonstrate how the dynamic topology processing accommodates anomalies and discrepancies in the scheme.

7.5.1 CTs on one side of bus coupler, CB closes before status acquisition.

BB1 BB2ILOAD through CB

CB CLOSEDbut auxiliary

contact OPEN

I EN1diff

=-iload

Zone 1 Zone 2

Idiff Z1= 0 Idiff Z2= + Iload

EN 1

P3742ENa

Check Zone Idiff = Σidiff = idiff Z1 + idiff EN1 + idiff EN2 + idiff Z2 = 0

Figure 28: CTs on one side of bus coupler, CB closes before status acquisition

As the CB has closed but the status has not yet been refreshed the topology still believes the CB to be open.

Treating this as an open bus coupler circuit breaker the topology algorithm will have created an end node (EN1). This is located between the CT and the circuit breaker. This then fully replicates the scheme upto the open bus coupler CB on both sides. Note that in this example zone 2s limits now extend upto the circuit breaker.

If the circuit breaker was open no load current would flow through the circuit breaker and hence the extra node. The differential current in the two main zones would equal zero, as the current flowing into the zones would still equal the current flowing out, and the current measured in the extra node would also be equal to zero.

However, if the circuit breaker is actually closed, the load current will flow through the circuit breaker and the extra node. The differential current in main zone 1 will still equal zero, as the current flowing into the zone will still equal the current flowing out, but the current measured in the extra node and in main zone 2 will be equal in magnitude but opposite in sign. (±iload)

Zone 1 would not operate and when the check zone element is calculated, the differential currents seen in zone 2 and the extra node (idiffEN), which result from the discrepancy in the plant status, can be seen to be cancelled out.

Check zone Idiff = Σidiff = idiffZ1+ idiffEN1 + idiffZ2 = 0 + (-iload) + (+iload) = ∅

Again the system retains its stability for discrepancies in plant status.


7.5.2 CTs on both sides of bus coupler, CB closes before status acquisition.

BB1 BB2ILOAD through CB

CB CLOSEDbut auxiliary

contact OPEN

I EN1diff

=-iload

Zone 1 Zone 2

Idiff Z1= 0 Idiff Z2 = 0EN 1

P3743ENa

EN 2

I EN1diff

=+iload

Check Zone Idiff = Σidiff = idiff Z1 + idiff EN1 + idiff EN2 + idiff Z2 = 0

Figure 29: CTs on both sides of bus coupler, CB closes before status acquisition

As the CB has closed but the status has not yet been refreshed the topology still believes the CB to be open.

Treating this as an open bus coupler the topology algorithm will have created two end nodes (EN1 and EN2). These are located between the CTs and the circuit breaker. These then fully replicate the scheme upto the open bus coupler CB on both sides.

If the circuit breaker was open no load current would flow through the circuit breaker and hence the two extra nodes. The differential current in the two main zones would equal zero, as the current flowing into the zones would still equal the current flowing out, and the current measured in the extra nodes would also be equal to zero.

However, if the circuit breaker is actually closed, the load current will flow through the circuit breaker and hence the two extra nodes. The differential current in the two main zones will still equal zero, as the current flowing into the zone(s) will still equal the current flowing out, but the current measured in the extra nodes will be equal in magnitude but opposite in sign. (±iload)

The main zones would not operate and when the check zone element is calculated, the differential currents seen in the extra nodes (idiffEN), which result from the discrepancy in the plant status and which are taken into account for the check zone calculation, can be seen to be cancelled out.

Check zone Idiff = Σidiff = idiffZ1+ idiffEN1 + idiffEN2 + idiffZ2 =0 + (-iload) + (+iload) = ∅

Hence, the system retains its stability even when there are discrepancies in plant status.


7.5.3 CTs on one side of bus coupler, CB closed and fault evolves between CT and CB.

BB1 BB2Zone 1 Zone 2

Idiff Z1 = 0 Idiff Z2= ifault

P3744ENa

Figure 30: CTs on one side of bus coupler, CB closed and fault evolves between CB & CT

Treating this as a closed bus section circuit breaker the topology algorithm will have extended the limits of the main zones to the bus coupler CT. This then fully replicates the scheme.

Under normal operating conditions when the circuit breaker is closed load current would flow through the circuit breaker and differential current in the two main zones would equal zero, as the current flowing into the zones would still equal the current flowing out.

However, if a fault was to occur between the CT and the circuit breaker the current will flow from zone 1 into zone 2 which feeds the fault. The differential current in main zone 1 will still equal zero, as the current flowing into the zone will still equal the current flowing out, but the differential current measured in zone 2 will be equal to that of the fault current.

In this case zone 2 would operate as will the check zone element.

Check zone Idiff = Σidiff = idiffZ1 + idiffZ2 = 0 + ifault = ifault > (ID>2)


However, when zone 2 trips the fault will still be present. The topology then analyses the remainder of the system as follows.

BB1 BB2I EN1diff = ifaultZone 1 Zone 2

Idiff Z1= 0EN 1

P3745ENa

Figure 31: Zone 2 tripped, fault still present

Treating this as an open bus coupler circuit breaker as before the topology algorithm will have created an end node (EN1) which is located between the CT and the circuit breaker. This then fully replicates the scheme upto the open bus coupler CB. Remember that in this example zone 2s limit extended upto the circuit breaker but this zone has been tripped already.

As the topology algorithm updates scheme every 33ms this is the maximum time to the creation of the extra node after auxiliary contact change of state.

The circuit breaker is now open and current would flow through the CT and into the extra node to feed the fault. The differential current in the main zone would equal zero, as the current flowing into the zone is still equal to the current flowing out, whereas the current measured in the extra node will be equal to the fault current ifault.

Check zone Idiff = Σidiff = idiffZ1 + idiffEN = 0 + ifault = ifault

End zone Idiff = ifault

Hence, the system reacts to the continuing presence of the fault in the end zone and trips the zone 1 as the check zone Idiff > (ID>2) and the end zone Idiff > (ID>2).

In this example it can be seen that the opposite zone is tripped first but the dynamic topology reacts to the changed scheme and subsequently trips the adjacent main zone.


7.5.4 CTs on both sides of coupler, CB closed and fault evolves between CT and CB.

BB1 BB2Virtual Zone

= Z3Zone 1 Zone 2

Idiff Z1= 0 Idiff Z2= 0

P3746ENa

Figure 32: CTs both sides of bus coupler, CB closed fault evolves between CT & CB

Treating this as a closed bus section circuit breaker the topology algorithm will have created a virtual zone that surrounds the circuit breaker with the bus coupler CTs as its limits called zone 3 in the event report and measurements. This then fully replicates the scheme.

Under normal operating conditions when the circuit breaker is closed load current would flow through the circuit breaker and hence the virtual zone. The differential current in the two main zones would equal zero, as the current flowing into the zones would still equal the current flowing out. This is also the case for the virtual zone around the bus coupler.

However, if a fault was to occur in the virtual zone, current would flow into the virtual zone and feed the fault. The differential current in the two main zones will still equal zero, as the current flowing into the zone(s) will still equal the current flowing out, but the differential current measured in the virtual zone will be equal to that of the fault current.

The main zones would not operate but the virtual zone or zone 3, which surrounds the bus coupler and has limits at the bus coupler CTs would operate. When the check zone element is calculated, the differential current seen in the virtual zone or zone 3, which results from the presence of the fault in the dead zone, will confirm the presence of a fault and initiate a simultaneous trip of both main zones.

Check zone Idiff = Σidiff = idiffZ1+ idiffZ3 + idiffZ2 = ifault

Hence, the system reacts to a fault occurring between the CT and the CB simultaneously tripping both adjacent zones.

When required, the bus coupler can operate first for a fault in the virtual zone or zone 3 and then the faulty zone 1 will remain in service. For such operation a special topology scheme should be used.


8. PSL CONFIGURATION AND INTEGRATION

A standard PSL will be supplied, preloaded as with other relays in the MiCOM range.

The programmable scheme logic (PSL) is multi-functional and includes the following options:

− Enables the mapping of opto-isolated inputs, relay output contacts and the programmable LED's.

− Provides relay output conditioning (delay on pick-up/drop-off, dwell time, latching or self-reset).

− Fault Recorder start mapping, i.e. which internal signals initiate a fault record.

− Enables customer specific scheme logic to be generated through the use of the PSL editor inbuilt into the MiCOM S1 support software.

It is strongly recommended that due to the nature of busbar protection this PSL is not modified after factory testing, unless modifications are carried out by competent AREVA personnel. Further information regarding editing and the use of PSLs can be found in the MiCOM S1 user manual. Note that changes to these defaults can only be carried out using the PSL editor and not via the relay front plate.

The standard PSL is shown in Configuration/Mapping Chapter. The following section details the default settings of the PSL.

8.1 Factory default settings

8.1.1 Logic input mapping

P741 P742 P743

1 L1 Reset Lached L1 Reset Latches L2 Reset Latches

2 L2 Ext. Start Disturbance Recorder

L2 Reset Latches L2 Reset Latches

3 L3 Reset Circuitry Fault L3 Q1 closed L3 Q1 close

4 L4 Ext. Check Zone L4 Q1 open L4 Q1 open

5 L5 Not used L5 Q2 closed L5 Q2 closed

6 L6 Not used L6 Q2 open L6 Q2 open

7 L7 Not used L7 CB Aux 3ph (52a) L7 CB Aux 3ph (52a)

8 L8 Not used L8 CB Aux 3ph (52b) L8 CB Aux 3ph (52b)

9 L9 Q3 closed L9 Q3 closed

10 L10 Q3 open L10 Q3 open

11 L11 Not Used L11 Not Used

12 L12 Ext 3Ph Trip L12 Ext 3Ph Trip

13 L13 CB not available L13 CB not available

14 L14 Ext CB Fail L14 Ext CB Fail

15 L15 Man CB Close cmd L15 Man CB Close cmd

16 L 16 Not Used L 16 Not Used


P741 P742 P743

17 L17 Not Used

18 L18 Not Used

19 L19 Not Used

20 L20 Not Used

21 L21 Not Used

22 L22 Not Used

23 L23 Not Used

24 L24 Not Used

Table 21 Logic input mapping

8.1.2 Relay output mapping

P741 P742 P743

1 R1 Fault phase A R1 Main trip Phase A R1 Main trip Phase A

2 R2 Fault phase B R2 Main trip Phase B R2 Main trip Phase B

3 R3 Fault phase C R3 Main trip Phase C R3 Main trip Phase C

4 R4 Z1 trip R4 Local CB failed R4 Local CB failed

5 R5 Z2 trip R5 Local CB not available R5 Local CB not available

6 R6 Circuitry fault R6 CB fail 3ph retrip R6 CB fail 3ph retrip

7 R7 Z1 off R7 Trip + end fault R7 Trip + end fault

8 R8 Z2 off R8 CB & isolator supervision

R8 CB & isolator supervision

9 R9 Not Used

10 R10 Not Used

11 R11 Not Used

12 R12 Not Used

13 R13 Not Used

14 R14 Not Used

15 R15 Not Used

16 R16 Not Used

17 R17 Not Used

18 R18 Not Used

19 R19 Not Used

20 R20 Not Used

21 R21 Not Used

Table 22 Relay output mapping


8.1.3 Relay output conditioning

P741 P742 P743

1 Pick-Up 0ms Pick-Up 0ms Pick-Up 0ms








9 Not Used

10 Not Used

11 Not Used

12 Not Used

13 Not Used

14 Not Used

15 Not Used

16 Not Used

17 Not Used

18 Not Used

19 Not Used

20 Not Used

21 Not Used

Table 23 Relay output conditioning


8.1.4 LED mapping

P741 P742 P743

1 Fault Phase A Q1 Position Closed Q1 Position Closed

2 Fault Phase B Q2 Position Closed Q2 Position Closed

3 Fault Phase C Q3 Position Closed Q3 Position Closed

4 Trip 87BB Not Used Not Used

5 Trip 50BF Local CB not available Local CB not available

6 Circuitry Fault Trip 87BB Trip 87BB

7 Not used Dead Zone Signal Dead Zone Signal

8 Not used Not used Not used

Table 24 LED mapping

8.1.5 LED output conditioning

P741 P742 P743

1 Latched Not latched Not latched



4 Latched Not Used Not Used

5 Latched Not Latched Not Latched

6 Not latched Latched Latched

7 Not Used Latched Latched

8 Not Used Not Used Not Used

Table 25 LED output conditioning

8.1.6 Fault recorder start mapping

P741 P742 P743

Any Trip Any Trip Any Trip

Table 26 Fault recorder start mapping

Should a specific modification be required to the standard PSL, this should be specified at order and it will, where possible, be incorporated into the scheme build and tested accordingly.


9. COMMUNICATIONS BETWEEN PU AND CU

The P740 scheme can be either centralised in one cubicle or distributed in cubicles housing other protection depending on the availability of space. Either way the peripheral units still need to communicate with the central unit and vice versa. Each central unit has upto 8 communication boards each accommodating inputs from 4 peripheral units. Thus each central unit can accommodate up to 32 peripheral units.

9.1 Communications link

The following communication media is used for the communication channel within the P740 scheme. The data rate is 2.5 Mbits/sec.

9.2 Direct optical fibre link, 850nm multi-mode fibre

The units are connected directly using two 850nm multi-mode optical fibres for each signalling channel. Multi-mode fibre type 62.5/125µm is suitable and standard BFOC/2.5 type fibre optic connectors are used. These are commonly known as ST connectors (ST is a registered trademark of AT&T).

Figure 33: Module Interconnection

This is typically suitable for connection up to 1km.


9.3 Optical budgets

When using fibre optics as a method of communication the type of fibre used and the distance between devices needs to be considered. The following table shows the optical budgets of the communications interface.

Parameter 850nm Multi mode

Min. transmit output level (average power) -19.8dBm

Receiver sensitivity (average power)

-25.4dBm

Optical budget 5.6dB

Less safety margin (3dB) 2.6dB 3dB

Typical cable loss 2.6dB/km

Max. transmission distance 1km

Table 27 Optical Budget

The total optical budget is given by transmitter output level minus the receiver sensitivity and will indicate the total allowable losses that can be tolerated between devices. A safety margin of 3dB is also included in the above table. This allows for degradation of the fibre as a result of ageing and any losses in cable joints. The remainder of the losses will come from the fibre itself. The figures given are typical only and should only be used as a guide.


10. UNDERTAKING A NUMERICAL DIFFERENTIAL BUSBAR PROTECTION PROJECT

The substation construction will influence the protection scheme installed. It is advisable that a scheme evaluation is conducted as soon as possible, preferably at the same time as the definition of the equipment specification.

Only a few system parameters are required and it is vital that these are included.

10.1 General Substation information

− Number of independent zones

− Number of feeders, bus couplers, bus sections

− Positions of bus sections

− Positions of switchgear plant i.e. circuit breakers, isolators

− Positions of CTs

− Planned future extensions with circuit breaker, isolator and current transformer (CT)

10.2 Short Circuit Levels

− Maximum external fault current (phase to phase and phase to ground faults)

− Minimum internal fault current (phase to phase and phase to ground faults)

10.3 Switchgear

− Nominal CT ratio

− Highest nominal primary current (CT In Max)

− Lowest nominal primary current (CT In Min)

− CT Knee point voltage (Vk)

− CT secondary resistance (RCT)

− Length and cross section of the conductors between CT and peripheral unit. (In the absence of precise information, an estimate taken from the lowest CT ratio will suffice).

− Auxiliary contacts of disconnecting switches and tripping orders for circuit breaker failure (irrespective of the how the CB fail scheme is to be implemented i.e. internally or externally initiated).


10.4 Cubicle specifications

Cubicle specification is contract specific.

However, AREVA propose the following:

− Single cubicle: 800x800x2000

− Double cubicle: 1600x800x2000

− Model: Schroff type Proline

− Color: RAL 7032

10.5 Substation Architecture

Due to the flexibility of the differential busbar protection there is an infinite number of busbar configurations that can be accommodated via the topology. Each may have very different architecture and, therefore, vary in complexity.

You will find in the following pages example topologies of layouts most frequently encountered. For each example, the number of central units and peripheral units necessary to protect the busbars is specified.

Generally, the elements of the protection architecture will be identified in a similar manner to the principal parts of the sub-station e.g. by the letters A and B.

Note: A cubicle needs to be considered for a centralised solution whereas if the peripheral units are distributed and the scheme is distributed there is no requirement for a dedicated cubicle.

In both cases, and before any delivery, the topology will be thoroughly tested on appropriate test platforms.


11. STANDARD CONFIGURATIONS

The following information relates only to the more common standard schemes. For further information on the accommodation of other busbar configurations consult your AREVA representative.

P3782ENa

Figure 34: Single busbar application with bus section isolator

The above example shows a single busbar with a bus section isolator. It is split into two zones. There are n feeders connected to the busbar. This configuration requires 1 central unit and n + 1 peripheral units (the additional peripheral unit being for the bus section isolator). The type of peripheral unit used for each bay will depend on the i/o requirements of the bay in question.

P3783ENa

Figure 35: Single busbar application with bus section circuit breaker

The above example shows a single busbar with a bus section circuit breaker. It is split into two zones. There are n feeders connected to the busbar. The bus section circuit breaker has CTs on either side. This configuration requires 1 central unit and n + 2


peripheral units (the additional peripheral units being for the bus section CTs). The type of peripheral unit used for each bay will depend on the i/o requirements of the bay in question.

It is recommended that the CTs for feeder protection are sited such as to overlap with the CTs defining the limits of each busbar protection zone.

P3784ENa

Figure 36: Breaker and a half scheme

The above example shows a breaker and a half scheme. The recommended solution is to have two separate schemes. There are n feeders connected to each busbar. Each scheme will require 1 central unit and n peripheral units. An other solution is to use only one central unit and n peripheral units. The type of peripheral unit used for each bay will depend on the i/o requirements of the bay in question.

P3785ENa

Figure 37: Double busbar application with bus coupler

The above example shows a double busbar with a bus coupler. It is split into two zones. There are n feeders connected to the busbar. The bus coupler circuit breaker can have either a single CT (solution 1) on one side or CTs on both sides (solution 2).


This configuration requires 1 central unit and n + 1 peripheral units for solution 1 or n + 2 peripheral units for solution 2. (The additional peripheral units being for the bus coupler CTs). The type of peripheral unit used for each bay will depend on the i/o requirements of the bay in question.

P3786ENa

Figure 38: Traditional double busbar application with bus coupler and bus section

The above example shows a double busbar with both a bus section and a bus coupler. It is split into four zones. There are n feeders connected to the busbar. The bus coupler and bus section circuit breakers can have either a single CT (solution 1 and 2) on one side or CTs on both sides (solution 1a or 2a). This configuration requires 1 central unit and n plus the following number of peripheral units. The total number of peripheral units required allows for a peripheral unit for the bus section isolator on the upper bar.

Solution Solution A 1 CT on BC & 1 CT on BS

Solution B 2 CT on BC & 2 CT on BS

Solution C 1 CT on BC & 2 CT on BS

Solution D 2 CT on BC & 1 CT on BS

Solution 1 ! " ! "

Solution 1a " ! " !

Solution 2 ! " " !

Solution 2a " ! ! "

Number of peripheral units required

n + 3 n + 5 n + 4 n + 4

If a second bus coupler is added i.e. one bus coupler either side of the bus section

Using solution 1 for the 2nd coupler

! " ! "

Using solution 1a for the 2nd coupler

" ! " !







n + 4 n + 7 n + 5 n + 6

Table 28 Number of required PUs for figure 37

The number of additional peripheral units being dependant on the number of bus section/bus coupler CTs. The type of peripheral unit used for each bay will depend on the i/o requirements of the bay in question.

P3787ENa

Figure 39: Double busbar application with bus coupler and bus section with additional bus section isolators

The above example shows a double busbar with both a bus section and a bus coupler. The bus section also has additional bus section isolators and allows for bus section bypass. The scheme is split into four zones. There are n feeders connected to the busbar. The bus coupler and bus section circuit breakers can have either a single CT (solution 1 and 2) on one side or CTs on both sides (solution 1a or 2a). This configuration requires 1 central unit and n plus the following number of peripheral units. The total number of peripheral units required allow for a peripheral unit for the bus section isolators.





Solution 1 ! " ! "

Solution 1a " ! " !

Solution 2 ! " " !

Solution 2a " ! ! "


n + 3 n + 5 n + 4 n + 4








! " ! "


" ! " !


n + 4 n + 7 n + 5 n + 6



P3788ENa

Figure 40: Double busbar application with bus coupler and double bus section circuit breaker arrangement

The above example shows a double busbar with both a bus section and a bus coupler. There are circuit breakers on both the upper and lower bars. The scheme is split into four zones. There are n feeders connected to the busbar. The bus coupler and bus section circuit breakers can have either a single CT (solution 1 and 2) on one side or CTs on both sides (solution 1a or 2a). This configuration requires 1 central unit and n plus the following number of peripheral units. The total number of peripheral units required allows for a peripheral unit for the bus section isolator on the upper bar.


Solution Solution A 1 CT on BC & 1 CT on each BS

Solution B 2 CT on BC & 2 CT on each BS

Solution C 1 CT on BC & 2 CT on each BS

Solution D 2 CT on BC & 1 CT on each BS

Solution 1 ! " ! "

Solution 1a " ! " !

Solution 2 ! " " !

Solution 2a " ! ! "


n + 3 n + 6 n + 5 n + 4



! " ! "


" ! " !


n + 4 n + 8 n + 6 n + 6



P3789ENa

Figure 41: Double busbar application with a bus coupler. The transfer busbar is not included in the protection zone.

The above example shows a double busbar with a bus coupler and a transfer busbar. As the transfer busbar is not included in the protected zone it can be considered similarly to figure 37, but an additional peripheral unit must be included for the transfer bay.


It is split into two zones. There are n feeders connected to the busbar. The bus coupler circuit breaker can have either a single CT (solution 1) on one side or CTs on both sides (solution 2). This configuration requires 1 central unit and n + 2 peripheral units for solution 1 or n + 3 peripheral units for solution 2. (The additional peripheral units being for the bus coupler CTs and the transfer bay). The type of peripheral unit used for each bay will depend on the i/o requirements of the bay in question.

P3790ENa

Figure 42: Double busbar application with a bus coupler. The transfer busbar is included in the protection zone.

The above example shows a double busbar with a bus coupler and a transfer busbar. The transfer busbar is included in the protected zone. It can be considered similarly to figure 36, where an additional peripheral unit has been included for the transfer bay. The only difference being the positioning of the CTs and therefore the peripheral units.

Again it is split into two zones. With an additional zone for the transfer bay, there are n feeders connected to the busbar. The bus coupler circuit breaker can have either a single CT (solution 1) on one side or CTs on both sides (solution 2). This configuration requires 1 central unit and n + 2 peripheral units for solution 1 or n + 3 peripheral units for solution 2. (The additional peripheral units being for the bus coupler CTs and the transfer bay). The type of peripheral unit used for each bay will depend on the i/o requirements of the bay in question.


P3791ENa

Figure 43: Triple busbar application with bus coupler and bus section

The above example shows a triple busbar with both a bus section and a bus coupler. The bus section also has additional bus section isolators and allows for bus section bypass. The scheme is split into six zones. There are n feeders connected to the busbar. The bus coupler and bus section circuit breakers can have either a single CT (solution 1 and 2) on one side or CTs on both sides (solution 1a or 2a). This configuration requires 1 central unit and n plus the following number of peripheral units. The total number of peripheral units required allows for a peripheral unit for the bus section isolators.





Solution 1 ! " ! "

Solution 1a " ! " !

Solution 2 ! " " !

Solution 2a " ! ! "


n + 3 n + 5 n + 4 n + 4



! " ! "


" ! " !


n + 4 n + 7 n + 5 n + 6




P3792ENaINCLUDEPICTUREMERGEFORMAT

Figure 44: Double bus bar with two circuit breakers per feeder

The above example shows a double busbar with two circuit breakers on each feeder. The scheme is split into two zones. There are n feeders connected to the busbar. This configuration requires 1 central unit and 2n peripheral units. In each bay the two peripheral units will share the CT, but each circuit breaker will be assigned to a separate peripheral unit.

P3793ENa

Figure 45: Mesh Corner

The above example shows a mesh corner arrangement. The scheme is split into four zones. This configuration requires 1 central unit and 12 peripheral units.


P3794ENa

Figure 46: Six main bus for s/s CB bus-sections and CB by-pass

The above example shows a six busbar arrangement with both a bus section and a bus coupler. It is also possible to include bypass facilities. The scheme is split into six zones. There are n feeders connected to the busbar. The bus coupler, bus section and bypass circuit breakers can have either a single CT (solution 1, 2 and 3) on one side or CTs on both sides (solution 1A, 2A and 3A).

This configuration requires 1 central unit and n plus the following number of peripheral units.





Solution 1 ! " ! "

Solution 1a " ! " !

Solution 2 ! " " !

Solution 2a " ! ! "


n + 4 n + 8 n + 7 n + 5

If bypass facilities are to be included

Using solution 3 ! " ! "

Using solution 3a

" ! " !


n + 5 n + 10 n + 8 n + 8

If a second bus coupler is added i.e. one bus coupler either side of the bus section and no bypass facilities







! " ! "


" ! " !


n + 5 n + 10 n + 8 n + 7

If a second bus coupler is added i.e. one bus coupler either side of the bus section and bypass facilities are included

Using solution 3 ! " ! "

Using solution 3a

" ! " !


n + 6 n + 12 n + 9 n + 10




12. MEASUREMENTS

The relay produces a variety of both directly measured and calculated power system quantities. These measurement values are updated on a per second basis and are summarised below:

− Phase currents: IA, IB, IC, IN

− Sequence currents: I0, I1, I2

− Differential and Bias currents: Idiff A, B, C, N and Ibias A, B, C, N

− check zone differential currents: Idiff CZ A, B, C, N

There are also measured values from the protection functions, which are also displayed under the measurement columns of the menu; these are described in the section on the relevant protection function.

For the Central Unit both bias and differential current for all zones, including the check zone differential current are displayed in the Measurement columns in addition to relevant zone bias and differential currents.

For the Peripheral Unit phase currents, phase currents and sequence current values relating to the associated bay CT are displayed in the Measurement columns in addition to relevant zone bias and differential currents.

12.1 Measured currents

The relay produces phase current values. They are produced directly from the DFT (Discrete Fourier Transform) used by the relay protection functions and present both magnitude and phase angle measurement.

12.2 Sequence currents

Sequence quantities are produced by the relay from the measured Fourier values; these are displayed as magnitude values.

12.3 Settings

There are different set-up menus for the Central Unit P741 and the Peripheral Units P742 and P743. The following settings under the heading Measurement Set-up can be used to configure the relay measurement function in the P741.



Default Display Description Description/Plant Reference/Frequency/Access Level/3Ph + N Current/Date and Time

Common conventional ratio

Ibp Current Set 1,000A 1A 10,000A 1A

Table 33 Measurement Setup Column P741


The following settings under the heading Measurement Setup can be used to configure the relay measurement function in the P742/P743.



Default Display Description Description/Plant Reference/Frequency/Access Level/3Ph + N Current/Date and Time

Local Values Secondary Primary/Secondary

Remote Values Primary Primary/Secondary

Table 34 Measurement Setup Column P742/P743

12.3.1 Common Conventional Ratio (Ibp)

This was discussed in section 4.2. Changing the ratio in this cell adjusts the base ratio for the calculations over the entire scheme and no further setting changes need to be carried out.

This current corresponds to primary values, which can be set to between 1A and 10,000A. In practice, a common base current of 1,000A is usually selected.

12.3.2 Default Display

This setting can be used to select the default display from a range of options, note that it is also possible to view the other default displays whilst at the default level using the ! and " keys. However, once the 15 minute timeout elapses the default display will revert to that selected by this setting.

12.3.3 Local Values

This setting controls whether measured values via the front panel user interface and the front Courier port are displayed as primary or secondary quantities.

12.3.4 Remote Values

This setting controls whether measured values via the rear communication port are displayed as primary or secondary quantities.


13. EVENT & FAULT RECORDS

The relay records and time tags up to 250 events and stores them in non-volatile (battery backed up) memory. This enables the system operator to establish the sequence of events that occurred within the relay following a particular power system condition, switching sequence etc. When the available space is exhausted, the oldest event is automatically overwritten by the new one.

The real time clock within the relay provides the time tag to each event, to a resolution of 1ms.

The event records are available for viewing either via the front plate LCD or remotely, via the communications ports.

Local viewing on the LCD is achieved in the menu column entitled VIEW RECORDS. This column allows viewing of event, fault and maintenance records. Different columns exist in the Central unit and the Peripheral Unit. The column for the Central Unit is shown below in table 35. The column displayed in the Peripheral Units is shown in table 36.

VIEW RECORDS

LCD Text Description for CU

Last Record

Menu Cell Ref

Time & Date Time & Date Stamp for the event given by the internal Real Time Clock

Record Text Up to 32 Character description of the occurrence (refer to following sections)

Record Value Up to 32 bit binary flag or integer representative of the occurrence (refer to following sections)

Select Fault Setting range from 0 to 4. This selects the required fault record from the possible 5 that may be stored. A value of 0 corresponds to the latest fault and so on.

Active Group Active group when fault recorder starts

Faulted Phase Phase initiating fault recorder starts

Start Elements Note relevant for CU

Trip Elements Trip 87BB, Trip 87BB block, Trip 50BF, Trip 50BF block, Dead Zone signal, Manual trip zone.

Time Stamp Time and date of fault recorder start

Fault Alarms

System Frequency

Fault duration - if fault detected by differential protection => delay between first detection of differential current and disappearance of differential current

- if breaker failure order received from PU => delay between reception of order and disappearance

IA diff Differential current of faulted zone

IB diff Differential current of faulted zone


VIEW RECORDS

LCD Text Description for CU

IC diff Differential current of faulted zone

IN diff Differential current of faulted zone

IA bias Differential current of faulted zone

IB bias Bias current of faulted zone

IC bias Bias current of faulted zone

IN bias Bias current of faulted zone

IA CZ diff Differential current of check zone

IB CZ diff Differential current of check zone

IC CZ diff Differential current of check zone

IN CZ diff Differential current of check zone

Faulted Zone Zone where fault is detected

Select Report (Maint) Setting range from 0 to 4. This selects the required report from the possible 5 that may be stored. A value of 0 corresponds to the latest report and so on.

The following cells show all the fault flags, protection starts, protection trips, fault location, measurements etc. associated with the fault, i.e. the complete fault record.

Report Text (Maint) Up to 32 Character description of the occurrence (refer to following sections)

Type (Maint) These cells are numbers representative of the occurrence. They form a specific error code which should be quoted in any related correspondence to AREVA.

Data

Reset Indication Either Yes or No. This serves to reset the trip LED indications provided that the relevant protection element has reset.

Table 35 View Records Column for the Central Unit

VIEW RECORDS

LCD Text Description for PU

Last Record

Menu Cell Ref

Time & Date Time & Date Stamp for the event given by the internal Real Time Clock

Record Text Up to 32 Character description of the occurrence (refer to following sections)

Record Value Up to 32 bit binary flag or integer representative of the occurrence (refer to following sections)

Select Fault Setting range from 0 to 4. This selects the required fault


VIEW RECORDS

LCD Text Description for PU record from the possible 5 that may be stored. A value of 0 corresponds to the latest fault and so on.

Active Group Active group when fault recorder starts

Faulted Phase Phase initiating fault recorder starts

Start Elements Start I>1, Start I>2, Start I>2BB, Start I>BB, Start IN>1, Start IN>2, Start IN>2BB, Start IN>BB

Trip Elements Trip I>1, Trip I>2, Trip IN>1, Trip IN>2, Trip 87BB, Trip CBFail tBF1, Trip CBFail tBF2, Trip CBFail tBF3, Trip CBFail tBF4, Trip 50BF (CU), Manual Trip zone, Trip 87BB block

Time Stamp Time and date of fault recorder start

Fault Alarms

System Frequency

Relay Trip Time Delay between reception of signal and end of trip on PU

IA Feeder currents

IB Feeder currents

IC Feeder currents

IN Feeder currents

Select Report (Main) Setting range from 0 to 4. This selects the required report from the possible 5 that may be stored. A value of 0 corresponds to the latest report and so on.

The following cells show all the fault flags, protection starts, protection trips, fault location, measurements etc. associated with the fault, i.e. the complete fault record.

Report Text (Maint) Up to 32 Character description of the occurrence (refer to following sections)

Type (Maint) These cells are numbers representative of the occurrence. They form a specific error code which should be quoted in any related correspondence to AREVA.

Data

Reset Indication Either Yes or No. This serves to reset the trip LED indications provided that the relevant protection element has reset.

Table 36 View Records Column for the Peripheral Unit

Note: That a full list of all the event types and the meaning of their values is given in the Configuration/Mapping Chapter (P740/EN GC/A11).


13.1 Types of Event

An event may be a change of state of control input or output relay, an alarm condition, setting change etc. The following sections show the various items that constitute an event:-

13.1.1 Change of state of opto-isolated inputs

If one or more of the opto (logic) inputs has changed state since the last time that the protection algorithm ran, the new status is logged as an event. When this event is selected to be viewed on the LCD, three applicable cells will become visible as shown below;

Time & Date of Event

LOGIC INPUTS

Event Value 0101010101010101

The Event Value is an 8, 16 or 24 bit word showing the status of the opto inputs, where the least significant bit (extreme right) corresponds to opto input 1 etc. The same information is present if the event is extracted and viewed via PC.

13.1.2 Change of state of one or more output relay contacts

If one or more of the output relay contacts has changed state since the last time that the protection algorithm ran, then the new status is logged as an event. When this event is selected to be viewed on the LCD, three applicable cells will become visible as shown below;

Time & Date of Event

OUTPUT CONTACTS

Event Value 010101010101010101010

The Event Value is an 8, 16 or 21-bit word showing the status of the output contacts, where the least significant bit (extreme right) corresponds to output contact 1 etc. The same information is present if the event is extracted and viewed via PC.


13.1.3 Relay alarm conditions

Any alarm conditions generated by the relays will also be logged as individual events. The following table shows examples of some of the alarm conditions and how they appear in the event list:-

Resulting Event Alarm Condition

Event Text Event Value Battery Fail Battery Fail ON/OFF Number from 0 to 31 Field Voltage Fail Field V Fail ON/OFF Number from 0 to 31 Setting group via opto invalid

Setting Grp Invalid ON/OFF Number from 0 to 31

Protection Disabled Protn Disabled ON/OFF Number from 0 to 31 Frequency out of range Freq out of Range ON/OFF Number from 0 to 31 CB Trip Fail Protection CB Fail ON/OFF Number from 0 to 31

Table 37 Alarm Configuration Column

The previous table shows the abbreviated description that is given to the various alarm conditions and also a corresponding value between 0 and 31. This value is appended to each alarm event in a similar way as for the input and output events previously described. It is used by the event extraction software, such as MiCOM S1, to identify the alarm and is therefore invisible if the event is viewed on the LCD. Either ON or OFF is shown after the description to signify whether the particular condition has become operated or has reset.

13.1.3.1 Protection element starts and trips

Any operation of protection elements, (either a start or a trip condition), will be logged as an event record, consisting of a text string indicating the operated element and an event value. Again, this value is intended for use by the event extraction software, such as MiCOM S1, rather than for the user, and is therefore invisible when the event is viewed on the LCD.

13.1.3.2 General events

A number of events come under the heading of General Events - an example is shown below:-

Nature of Event Displayed text in event record Displayed value

Level 1 password modified, either from user interface, front or rear port

PW1 edited UI, F or R 0

Table 38

A complete list of the General Events is given in the Configuration/Mapping Chapter (P740/EN GC).


13.1.3.3 Fault records

Each time a fault record is generated, an event is also created. The event simply states that a fault record was generated, with a corresponding time stamp.

Note: That viewing of the actual fault record is carried out in the Select Fault cell further down the VIEW RECORDS column, which is selectable from up to 5 records. These records consist of fault flags, fault measurements etc. Also note that the time stamp given in the fault record itself will be more accurate than the corresponding stamp given in the event record as the event is logged some time after the actual fault record is generated.

13.1.3.4 Maintenance reports

Internal failures detected by the self-monitoring circuitry, such as watchdog failure, field voltage failure etc are logged into a maintenance report. The Maintenance Report holds up to 5 such events and is accessed from the Select Maint cell at the bottom of the VIEW RECORDS column.

Each entry consists of a self explanatory text string and a Type and Data cell, which are explained in the menu extract at the beginning of this section and in further detail in Configuration / Mapping Chapter (P740/EN GC).

Each time a Maintenance Report is generated, an event is also created. The event simply states that a report was generated, with a corresponding time stamp.

13.1.3.5 Setting Changes

Changes to any setting within the relay are logged as an event. Two examples are shown in the following table:-

Type of Setting Change Displayed Text in Event Record Displayed Value

Control/Support Setting C & S Changed 0

Group 1 Change Group 1 Changed 1

Table 39

Note: Control/Support settings are communications, measurement, CT/VT ratio settings etc, which are not duplicated within the four setting groups. When any of these settings are changed, the event record is created simultaneously. However, changes to protection or disturbance recorder settings will only generate an event once the settings have been confirmed at the setting trap.

13.1.4 Resetting of event/fault records

If it is required to delete either the event, fault or maintenance reports, this may be done from within the RECORD CONTROL column.


13.1.5 Viewing event records via MiCOM S1 Support Software

When the event records are extracted and viewed on a PC they look slightly different than when viewed on the LCD. The following shows an example of how various events appear when displayed using MiCOM S1:-

As can be seen, the first line gives the description and time stamp for the event, whilst the additional information that is displayed below may be collapsed via the +/- symbol.

For further information regarding events and their specific meaning, refer to Configuration / Mapping Chapter (P740/EN GC).


13.1.6 Event Filtering

It is possible to disable the reporting of events from any user interface that supports setting changes. The settings, which control the various types of events, are in the Record Control column.

The effect of setting each to disabled is as follows:

Alarm Event None of the occurrences that produce an alarm will result in an event being generated.

The presence of any alarms is still reported by the alarm LED flashing and the alarm bit being set in the communications status byte.

Alarms can still be read using the Read key on the relay front panel.

Relay O/P Event No event will be generated for any change in relay output state.

Opto Input Event

No event will be generated for any change in logic input state.

General Event No General Events will be generated.

Fault Rec Event No event will be generated for any fault that produces a fault record.

The fault records can still be viewed by operating the Select Maintsetting in column 0100.

Protection Event Any operation of protection elements will not be logged as an event.

Table 40

Note: That some occurrences will result in more than one type of event, e.g. a battery failure will produce an alarm event and a maintenance record event.

If the Protection Event setting is Enabled a further set of settings is revealed which allow the event generation by individual DDB signals to be enabled or disabled.


14. DISTURBANCE RECORDER

The integral disturbance recorder has an area of memory specifically set aside for record storage. The number of records that may be stored is dependent upon the selected recording duration but the relays typically have the capability of storing a minimum of 20 records in the PU and 8 records in the CU, duration depends on the unit, 1.2 seconds in the CU and 10.5 seconds in the PU. Disturbance records continue to be recorded until the available memory is exhausted, at which time the oldest record(s) are overwritten to make space for the newest one.

The recorder stores actual samples that are taken at a rate of 12 samples per cycle.

Minimum delay between 2 disturbance records (CU) is 5s.

Each disturbance record consists of eight analogue data channels and thirty-two digital data channels. Note that the relevant CT ratios for the analogue channels are also extracted to enable scaling to primary quantities).

The Disturbance recorder settings are different for the Central Unit and the Peripheral Units as shown in the configuration columns below.

Note: When a 5A CT is used it must be ensured that the CT ratio entered is ≥ 5:5 to ensure correct operation of the disturbance recorder.

The DISTURBANCE RECORDER menu column for the central unit is shown in table 41:-

MENU TEXT DEFAULT SETTING SETTING RANGE STEP SIZE

MIN MAX

DISTURB RECORDER

Duration 1.2s Fixed value

Trigger Position 50% 0 50% 17%

Trigger Mode Single Non settable

Analog Channel 1 IA diff

Analog Channel 2 IB diff

Analog Channel 3 IC diff

Analog Channel 4 IN diff

Analog Channel 5 IA bias

Analog Channel 6 IB bias

Analog Channel 7 IC bias

Analog Channel 8 IN bias

Digital Inputs 1 to 32 Relays 1 to 8 and Optos 1 to 8

Any of 8 O/P Contacts or Any of 8 Opto Inputs or Internal Digital Signals

Table 41 Disturbance Recorder Menu Column for the Central Unit


The DISTURBANCE RECORDER menu column for the peripheral unit is shown in table 42:-

MENU TEXT DEFAULT SETTING SETTING RANGE STEP SIZE

MIN MAX

DISTURB RECORDER

Duration 1.5 0.1s 10.5s 0.01s

Trigger Position 33.3% 0 100% 0.1%

Trigger Mode Single Single or Extended

Analog Channel 1 IA

Analog Channel 2 IB

Analog Channel 3 IC

Analog Channel 4 IN

Analog Channel 5 Not used




Digital Inputs 1 to 32 Relays 1 to 8 and Optos 1 to 16/24

Any of 8 or 21 O/P Contacts or Any of 16 or 24 Opto Inputs or Internal Digital Signals

Inputs 1 to 32 Trigger

No trigger except dedicated trip relay outputs which are set to trigger L/H

No trigger, Trigger L/H, Trigger H/L

Table 42 Disturbance Recorder Menu Column for the Peripheral Unit

Note: The available analogue and digital signals will differ between relay types and models and so the individual Courier database in Chapter Configuration/Mapping (P740/EN GC) should be referred to when determining default settings etc.

The pre and post fault recording times are set by a combination of the Duration and Trigger Position cells. Duration sets the overall recording time and the Trigger Position sets the trigger point as a percentage of the duration. For example, the default settings for the peripheral units show that the overall recording time is set to 1.5s with the trigger point being at 33.3% of this, giving 0.5s pre-fault and 1s post fault recording times.


If a further trigger occurs whilst a recording is taking place, the recorder will ignore the trigger if the Trigger Mode has been set to Single. However, if this has been set to Extended, the post trigger timer will be reset to zero, thereby extending the recording time.

As can be seen from the menu, each of the analogue channels is selectable from the available analogue inputs to the relay. The digital channels may be mapped to any of the opto isolated inputs or output contacts, in addition to a number of internal relay digital signals, such as protection starts, LEDs etc. The complete list of these signals may be found by viewing the available settings in the relay menu or via a setting file in MiCOM S1. Any of the digital channels may be selected to trigger the disturbance recorder on either a low to high or a high to low transition, via the Input Trigger cell. The default trigger settings are that any dedicated trip output contacts (e.g. relay 3) will trigger the recorder.

It is not possible to view the disturbance records locally via the LCD; they must be extracted using suitable software such as MiCOM S1.


15. COMMISSIONING TEST MENU

To help minimise the time required to test MiCOM relays the relay provides several test facilities under the COMMISSION TESTS menu heading. There are menu cells which allow the status of the opto-isolated inputs, output relay contacts, internal digital data bus (DDB) signals and user-programmable LEDs to be monitored. Additionally there are cells to test the operation of the output contacts and user-programmable LEDs.

The following table shows the commissioning test relay menu, including the available setting ranges and factory defaults:

Menu text Default setting Settings

COMMISSION TESTS

Opto I/P Status - -

Relay O/P Status - -

Test Port Status - -

LED Status - -

Monitor Bits 64 to 71 step 1 per bit 0 to 511 step 1

Test Mode Disabled Enabled/Disabled

Test Pattern All bits set to 0 0 = Not Operated 1 = Operated

Contact Test No Operation No Operation Apply Test Remove Test

Test LEDs No Operation No Operation Apply Test

87BB Monitoring All bits set to 0 Each bit represents 1 zone

0 = In Service 1 = Out of Service

87BB & 50BF disabled All bits set to 0 Each bit represents 1 zone

0 = In Service 1 = Out of Service

BB Trip Pattern All bits set to 0 0 = In Service 1 = Out of Service

BB Trip Command No Operation No Operation Apply Test

Table 43 Commissioning Tests Column for CU


Menu text Default setting Settings

COMMISSION TESTS

Opto I/P Status - -

Relay O/P Status - -

Test Port Status - -

LED Status - -

Monitor Bits 64 to 71 step 1 per bit 0 to 511 step 1

Test Mode Disabled Enabled/Disabled

Test Pattern All bits set to 0 0 = Not Operated 1 = Operated

Contact Test No Operation No Operation Apply Test Remove Test

Test LEDs No Operation No Operation Apply Test

Position Pattern 0 0 79 step 1

Position Test No operation No Operation Apply Test

Table 44 Commissioning Tests Column for PU

15.1 Opto I/P status

This menu cell displays the status of the relays opto-isolated inputs as a binary string, a 1 indicating an energised opto-isolated input and a 0 a de-energised one. If the cursor is moved along the binary numbers the corresponding label text will be displayed for each logic input.

It can be used during commissioning or routine testing to monitor the status of the opto-isolated inputs whilst they are sequentially energised with a suitable dc voltage.

15.2 Relay O/P status

This menu cell displays the status of the digital data bus (DDB) signals that result in energisation of the output relays as a binary string, a 1 indicating an operated state and 0 a non-operated state. If the cursor is moved along the binary numbers the corresponding label text will be displayed for each relay output.

The information displayed can be used during commissioning or routine testing to indicate the status of the output relays when the relay is in service. Additionally fault finding for output relay damage can be performed by comparing the status of the output contact under investigation with its associated bit.

Note: When the Test Mode cell is set to Enabled this cell will continue to indicate which contacts would operate if the relay was in-service, it does not show the actual status of the output relays.


15.3 Test Port status

This menu cell displays the status of the eight digital data bus (DDB) signals that have been allocated in the Monitor Bit cells. If the cursor is moved along the binary numbers the corresponding DDB signal text string will be displayed for each monitor bit.

By using this cell with suitable monitor bit settings, the state of the DDB signals can be displayed as various operating conditions or sequences are applied to the relay. Thus the programmable scheme logic can be tested.

As an alternative to using this cell, the optional monitor/download port test box can be plugged into the monitor/download port located behind the bottom access cover. Details of the monitor/download port test box can be found in section 6.11 of this chapter.

15.4 LED status

The LED Status cell is an eight bit binary string that indicates which of the user-programmable LEDs on the relay are illuminated when accessing the relay from a remote location, a 1 indicating a particular LED is lit and a 0 not lit.

THE MONITOR/DOWNLOAD PORT DOES NOT HAVE ELECTRICAL ISOLATED AGAINST INDUCED VOLTAGES ON THE COMMUNICATIONS CHANNEL. IT SHOULD THEREFORE ONLY BE USED FOR LOCAL COMMUNICATIONS.

15.5 Test mode

15.5.1 Test mode for PU

This cell is used to allow secondary injection testing to be performed on the relay, without operation of the trip command, or commissioning of other relays in the same bay as the PU, without mal-operation of the breaker failure protection. It also enables the user to directly test the output contacts and the effect of plant position via the application of controlled tests signals (forcing see Sections 15.11 and 15.12).

Two test modes are available:

− In the I/O disable mode, the busbar protection remains in service on the feeder but no trip is possible on local breaker (tripping contacts RL1, RL2, RL3 disabled). The topology algorithm uses last known position of the circuit breaker and isolator(s). Secondary injection cannot be carried out as it could invoke a differential protection trip command.

− In the Out of Service mode, the feeder must be physically disconnected from any zone. The busbar protection does not take into account this feeder and it is not possible to trip the breaker(tripping contacts RL1, RL2, RL3 disabled). The topology algorithm uses last known position of the circuit breaker and isolator(s). This mode allows secondary injection testing to be performed on the relay.

When a test mode is select, the relay is out of service causing an alarm condition to be recorded and the yellow Out of Service LED to illuminate. Once testing is complete the cell must be set back to Disabled to restore the relay back to service.


15.5.2 Test mode for CU

This cell is used to allow commissioning of busbar and general breaker failure protection. It also enables a facility to directly test the output contacts by applying menu controlled tests signals. During the test mode, opto inputs and outputs contacts remain in last known state before the test mode is selected.

To select test mode this cell should be set to Enabled which takes the relay out of service causing an alarm condition to be recorded and the yellow Out of Service LED to illuminate. Once testing is complete the cell must be set back to Disbled to restore the relay back to service.

WHEN THE TEST MODE CELL IS SET TO ENABLED, THE RELAY SCHEME LOGIC DOES NOT DRIVE THE OUTPUT RELAYS AND HENCE THE CU WILL NOT TRIP THE ASSOCIATED CIRCUIT BREAKER IF A BUSBAR FAULT OCCURS (COMMISSIONING MODE 1 AND 2).

HOWEVER, THE COMMUNICATIONS CHANNELS WITH REMOTE RELAYS REMAIN ACTIVE, WHICH, IF SUITABLE PRECAUTIONS ARE NOT TAKEN, COULD LEAD TO THE REMOTE ENDS TRIPPING WHEN CURRENT TRANSFORMERS ARE ISOLATED OR INJECTION TESTS ARE PERFORMED.

15.6 Test pattern

The Test Pattern cell is used to select the output relay contacts that will be tested when the Contact Test cell is set to Apply Test. The cell has a binary string with one bit for each user-configurable output contact which can be set to 1 to operate the output under test conditions and 0 to not operate it.

15.7 Contact test

When the Apply Test command in this cell is issued the contacts set for operation (set to 1) in the Test Pattern cell change state. After the test has been applied the command text on the LCD will change to No Operation and the contacts will remain in the Test State until reset issuing the Remove Test command. The command text on the LCD will again revert to No Operation after the Remove Test command has been issued.

Note: When the Test Mode cell is set to Enabled the Relay O/P Status cell does not show the current status of the output relays and hence can not be used to confirm operation of the output relays. Therefore it will be necessary to monitor the state of each contact in turn.

15.8 Test LEDs

When the Apply Test command in this cell is issued the eight user-programmable LEDs will illuminate for approximately 2 seconds before they extinguish and the command text on the LCD reverts to No Operation.


15.9 Busbar Monitoring (only in CU)

The BB monitoring cell is used to select the status of each zone. This cell has a binary string with one bit per zone which can be set to 1 to disable busbar protection and 0 to keep the zone in operating mode. When a zone is set to 1, the current sum calculation remains active for monitoring but a trip order cannot be generated by the busbar protection, only from the breaker failure protection. Zones can be in busbar monitoring when others zones remain active.

15.10 Busbar (BB) & Circuit Breaker Fail (CBF) Disable (only in CU)

The BB & CBF disable cell is used to select the status of each zone. This cell has a binary string with one bit per zone which can be set to 1 to disable busbar & breaker failure protection and 0 to maintain the zone in operating mode. When a zone is set to 1, the current sum calculation remains active for monitoring but trip orders cannot be sent by either the busbar protection or the breaker failure protection. Zones can be in ' BB & CBF disable ' when others zones remain active.

15.11 Position Pattern (only in PU)

The Position Pattern cell is used to force the position of the circuit breaker and isolator in the topology algorithm when the Position Test cell is set to Apply Test. This cell has a binary string with one bit per each isolator and one for circuit breaker. These can be set to 1 to simulate the closed position or 0 to simulate the open position.

15.12 Position Test (only in PU)

When the Apply test command in this cell is issued, the states set in the position pattern cell are sent to the topology algorithm. After the test has been applied the command text on the LCD will change to No operation and the topology does not change until the Remove Test command has been applied.


16. MONITOR TOOL

Software monitor of MiCOM S1 is designed for 8 zones substation. Consequently, if you open connection with P741 which protects 4 zones substation, there are error message to inform you that cells corresponding to topology and measurements of zone 5 to 8 can not be displayed.

You can use monitor tool even if this error message appears.

To remove error message, you have to remove cells in the default file :

• Open file celllist.txt with text editor (for example notepad). This file is located in directory Monitor in the path of MiCOM S1 install (default is c:\Programmes Files\AREVA\MiCOM S1\Monitor)

• Go to line [P741], referring to documentation Menu Database - P740/EN GC

• Remove addresses of cell that you dont want to display after the line /Measurement. For example, to remove cell [Topology 1, Current node 5], delete line 0405

• Save file

Later if you want to display new zone, do reverse operation.

Technical Data P740/EN TD/D11 MiCOM P740 Page 1/36

TECHNICAL DATA

P740/EN TD/D11 Technical Data Page 2/36 MiCOM P740

CONTENTS

1. REFERENCE CONDITIONS 3

2. PROTECTION FUNCTIONS 3

3. CONTROL 12

4. MEASUREMENTS AND RECORDING FACILITIES 13

5. POST FAULT ANALYSIS 14

6. PLANT SUPERVISION 16

7. LOCAL AND REMOTE COMMUNICATIONS 17

8. DIAGNOSTICS 18

9. RATINGS 19

10. CT REQUIREMENTS (P740 RANGE) 22

11. HIGH VOLTAGE WITHSTAND (P740 RANGE) 25

12. ELECTRICAL ENVIRONMENT 26

13. ATMOSPHERIC ENVIRONMENT 31

14. MECHANICAL ENVIRONMENT 32

15. INFLUENCING QUANTITIES 34

16. MISCELLANEOUS 35

17. EC EMC COMPLIANCE (P740 RANGE) 36

18. EC LVD COMPLIANCE (P740 RANGE) 36


1. REFERENCE CONDITIONS

The accuracy claims within this document are relevant for relays operating under the following reference conditions.

Quantity Reference conditions Test tolerance

General

Ambient temperature 20 °C ±2°C

Atmospheric pressure 86kPa to 106kPa -

Relative humidity 45 to 75 % -

Input energising quantity Reference conditions Test tolerance

Current Ιn ±5%

Voltage Vn ±5%

Frequency 50 or 60Hz ±0.5%

Auxiliary supply DC 24V, 48V or 110V AC 63.5V or 110V

±5%

Settings Reference value

Time Multiplier Setting 1.0

Time Dial 7

2. PROTECTION FUNCTIONS

The following functional claims are applicable to the P740 range of busbar differential relays.

Note however that not all the protection functions listed below are applicable to every relay.

2.1 Phase busbar differential protection

2.1.1 Phase current biased differential characteristic settings

Name Range Step Size

Ιs [0.02 - 1.0] x Ιbp 0.01 x Ιbp

ΙD>2 [0.1 4] x Ιbp 0.01x Ιbp

K 20 90% 1%

Characteristic shape determined by the following formula:

For Ιdiff greater than: ΙD>2

|Ιdiff| = k|Ιbias|+ ΙS


Idiff

Ibias

0perate

Restrain

I >2D

I >1D

IS

Percentagebias k

2.2 Earth fault busbar differential protection

2.2.1 Earth current biased differential characteristic settings


ΙSN [0.02 - 1.0] x Ιbp 0.01 x Ιbp

ΙDN>2 [0.03 2] x Ιbp 0.01x Ιbp

K 20 90% 1%

Characteristic shape determined by the following formula:

For Ιdiff greater than: ΙDN>2

|Ιdiff| = k|Ιbias|+ ΙSN

Idiff

Ibias

0perate

Restrain

I >2DN

I >1DN

ISN

Percentagebias k

Bias Current

Differential Current
Bias Current
Differential Current


2.3 Three Phase Overcurrent Protection

2.3.1 Setting ranges

Stage Range Step size

Phase element 1st Stage 0.1 32Ιn 0.01Ιn

" " 2nd Stage 0.1 32Ιn 0.01Ιn

2.3.2 Time delay settings

Each overcurrent element has an independent time setting and each time delay is capable of being blocked by an optically isolated input:

Element Time delay type

1st Stage Definite Time (DT) or IDMT

2nd Stage DT

Curve type Reset time delay

IEC / UK curves DT only

All other IDMT or DT

2.3.2.1 Inverse Time (IDMT) Characteristic

IDMT characteristics are selectable from a choice of four IEC/UK and five IEEE/US curves as shown in the table below.

The IEC/UK IDMT curves conform to the following formula:

( )

+×=

−α LK

Tt1IsI

The IEEE/US IDMT curves conform to the following formula:

( )

+×=

−α LK

7TD

t1IsI

Where: t = operation time K = constant Ι = measured current ΙS = current threshold setting α = constant L = ANSI/IEEE constant (zero for IEC/UK curves) T = Time Multiplier Setting for IEC/UK curves TD = Time Dial Setting for IEEE/US curves


IDMT Curve description Standard K Constant α Constant L Constant

Standard Inverse IEC 0.14 0.02 0

Very Inverse IEC 13.5 1 0

Extremely Inverse IEC 80 2 0

Long Time Inverse UK 120 1 0

Moderately Inverse IEEE 0.0515 0.02 0.114

Very Inverse IEEE 19.61 2 0.491

Extremely Inverse IEEE 28.2 2 0.1217

Inverse US-C08 5.95 2 0.18

Short Time Inverse US-C02 0.02394 0.02 0.01694

2.3.2.2 Time Multiplier Settings for IEC/UK curves


TMS 0.025 to 1.2 0.025

2.3.2.3 Time Dial Settings for IEEE/US curves


TD 0.5 to 15 0.1

2.3.2.4 Definite Time Characteristic

Element Range Step Size

All stages 0 to 100s 10ms

2.3.2.5 Reset Characteristics

For all IEC/UK curves, the reset characteristic is definite time only.

For all IEEE/US curves, the reset characteristic can be selected as either inverse curve or definite time.

The definite time can be set (as defined in IEC) to zero. Range 0 to 100 seconds in steps of 0.01 seconds.

The Inverse Reset characteristics are dependent upon the selected IEEE/US IDMT curve as shown in the table below.


All inverse reset curves conform to the following formula:

( )

−×

= αIsI1

tr7TD

tReset

Where: tReset = reset time tr = constant

Ι = measured current ΙS = current threshold setting α = constant TD = Time Dial Setting (Same setting as that employed by IDMT curve)

IEEE/US IDMT Curve description

Standard tr Constant α Constant

Moderately Inverse IEEE 4.85 2

Very Inverse IEEE 21.6 2

Extremely Inverse IEEE 29.1 2

Inverse US-C08 5.95 2

Short Time Inverse US-C02 2.261 2

Inverse Reset Characteristics

2.3.3 Accuracy

Pick-up Setting ±5%

Drop-off 0.95 x Setting ±5%

Minimum trip level of IDMT elements 1.05 x Setting ±5%

IDMT characteristic shape ±5% or 40ms whichever is greater (under reference conditions)*

IEEE reset ±5% or 40ms whichever is greater

DT operation ±2% or 50ms whichever is greater

DT reset Setting ±5%

Directional boundary accuracy (RCA ±90°) ±2° hysteresis 2°

Characteristic UK curves IEC 60255-3 1998

US curves IEEE C37.112 1996

* Reference conditions TMS=1, TD=7 and Ι> setting of 1A, accuracy operating range 2-20Ιs


2.3.4 IEC IDMT Curves

!

Curve 1 Standard Inverse

Curve 2 Very Inverse

Curve 3 Extremely Inverse

Curve 4 UK Long Time Inverse


2.3.5 ANSI/IEEE IDMT curves

"#$

%

&

&

'

(

Curve 5 IEEE Moderately inverse

Curve 6 IEEE Very inverse

Curve 7 IEEE Extremely inverse

Curve 8 US Inverse

Curve 9 US Short time inverse


2.4 Earth Fault Protection

2.4.1 Setting ranges

2.4.1.1 Earth Fault, Sensitive Earth Fault

Element Range Step Size

Earth Fault 1st Stage 0.1 - 32Ιn 0.01Ιn

" " 2nd Stage 0.1 - 32Ιn 0.01Ιn

2.4.2 EF time delay characteristics

The earth-fault measuring elements for EF and SEF are followed by an independently selectable time delay. These time delays are identical to those of the Phase Overcurrent time delay. The reset time delay is the same as the Phase overcurrent reset time.

2.4.3 Accuracy

2.4.3.1 Earth fault

Pick-up Setting ±5%

Drop-off >0.85 x Setting

Minimum trip level of IDMT elements 1.05 x Setting ±5%

IDMT characteristic shape ±5% or 40ms whichever is greater (under reference conditions)*

IEEE reset ±10% or 40ms whichever is greater

DT operation ±2% or 50ms whichever is greater

DT reset ±5% or 50ms whichever is greater

Repeatability 7.5%

* Reference conditions TMS=1, TD=7 and ΙN> setting of 1A, accuracy operating range 2-20Ιs

2.5 Transient Overreach and Overshoot

2.5.1 Accuracy

Additional tolerance due to increasing X/R ratios

±5% over the X/R ratio of 1 to 90

Overshoot of overcurrent elements <40ms


2.6 Programmable scheme logic

2.6.1 Level settings


Time delay t 0-14400000ms 1ms

2.6.2 Accuracy

Output conditioner timer Setting ±2% or 50ms whichever is greater

Dwell conditioner timer Setting ±2% or 50ms whichever is greater

Pulse conditioner timer Setting ±2% or 50ms whichever is greater


3. CONTROL

The following claims for Control Functions are applicable to the P740 range of busbar differential relays (model specific as detailed).

3.1 Display Control and Setting Groups


Settings Range Step size

Setting groups 1 - 4 1

3.1.2 Performance

Setting groups 4 independent setting groups including independent programmable scheme logic for each group.

3.2 Inhibit current differential protection

3.2.1 Performance

Current differential algorithm blocked by

Energising the opto input assigned to inhibit busbar differential protection

Compliant

Unhealthy communications link Compliant

Loss of power supply to any relay Compliant


4. MEASUREMENTS AND RECORDING FACILITIES

The following claims for Measurement & Recording facilities are applicable to the P740 range of busbar differential relays (model specific as detailed).

4.1 Measurements

Accuracy under reference conditions.

Measurand Range Accuracy

Phase current 0.05 to 3 Ιn ±1.0% of reading

Phase local current 0.05 to 3 Ιn ±1.0% of reading or ±(f-fn)/fn %

Phase remote current 0.05 to 3 Ιn ±1.0% of reading or ±(f-fn)/fn %

Phase differential current

0.05 to 3 Ιn ±5.0%

Bias current 0.05 to 3 Ιn ±5.0%

Frequency 45 to 65Hz ±1%

4.2 IRIG-B and Real Time Clock

4.2.1 Features

Real time 24 hour clock settable in hours, minutes and seconds

Calendar settable from January 1994 to December 2092

Clock and calendar maintained via battery after loss of auxiliary supply

Internal clock synchronisation using IRIG-B

4.2.2 Performance

Year 2000 Compliant

Real time clock accuracy < ±2 seconds / day

External clock synchronisation Conforms to IRIG standard 200-98, format B


5. POST FAULT ANALYSIS

The following claims for Post Fault Analysis Functions are applicable to the P740 range of busbar differential relays (model specific as detailed).

5.1 Fault Records

5.1.1 Features

Fault record generation on protection operation indicating

Time and date Setting group Start / trip element Faulted current magnitudes Remote, bias and differential currents Frequency Protection operating time

Alarm events generated on the following indications

Protection disabled/test mode CB alarms Frequency out of range Battery status Differential protection inhibited Configuration / reconfiguration error Field voltage fail Signal fail alarm differential fail alarm Setting groups

5.1.2 Performance

Fault record display indication and information Correct

Alarm events display indication and information Correct

Time and date stamping ±10ms of applied fault/event

Fault Clearance time ±2%

CB operating time ±10ms

Protection operating time ±2%


5.2 Disturbance Records


Settings (P742, P743) Range Step size

Duration 0.1 10.5s 10ms

Trigger position 0 100% 0.1%

4 analogue channels, 32 digital channels

Settings (P741) Range Step size

Duration 1.2 s (Fixed)

Trigger position 0 50% 16.67%

8 analogue channels, 32 digital channels

5.2.2 Accuracy

Waveshape Comparable with applied quantities

Magnitude and relative phases ±5% of applied quantities

Duration ±2%

Trigger position ±2% (minimum trigger 100ms)


6. PLANT SUPERVISION

The following claims for Plant Supervision Functions are applicable to the P740 range of Busbar differential relays (model specific as detailed).

6.1 CB State Monitoring Control, breaker fail and backtrip, breaker fail timer


Setting Range Step

Breaker fail timer 1 0 10s 0.01s

Breaker fail timer 2 0 10s 0.01s

6.1.2 Accuracy

Timers ±2% or 40ms whichever is greater

Reset <30ms


7. LOCAL AND REMOTE COMMUNICATIONS

The following claims for Local & Remote Communications are applicable to the P740 range of busbar differential relays (model specific as detailed).

7.1 Front Port

Setting

Protocol Courier

Message format IEC 60870-5 FT1.2

Baud rate 9 200 bits/s

7.2 Rear Port

Rear port settings Setting options Setting available for:

Physical links EIA(RS)485 or Fibre optic EIA(RS)485 only

Courier

Remote address 0 - 255 (step 1) Courier

Baud rate 64,000 bits/s Courier

Inactivity timer 1 - 30 minutes (step 1) All

7.2.1 Performance

Front and rear ports conforming to Courier communication protocol Compliant


8. DIAGNOSTICS

The following claims for Diagnostic Functions are applicable to the P740 range of Busbar differential relays

8.1 Features

Power up self checking with watchdog indication of healthy condition

Watchdog and front display indication of a hardware or software failure occurring during power up or during normal in service operation

8.2 Performance

Power up / continuous self checks Compliant

Watchdog operation Compliant

Co-processor failure detection Compliant

Time to power up < 11s


9. RATINGS

The following claims for Ratings are applicable to the P740 range of busbar differential relays (model specific as detailed).

9.1 Nominal ratings

9.1.1 Currents (All P740 range)

Ιn = 1A or 5A ac rms.

Separate terminals are provided for the 1A and 5A windings, with the neutral input of each winding sharing one terminal.

All current inputs will withstand the following, with any current function setting:

Withstand Duration

4 Ιn Continuous rating

4.5 Ιn 10 minutes

5 Ιn 5 minutes

6 Ιn 3 minutes

7 Ιn 2 minutes

30 Ιn 10 seconds

50 Ιn 3 seconds

100 Ιn 1 second

Pass Criteria Winding temperatures <105° C

Dielectric withstand and insulation resistance unimpaired

9.1.2 Auxiliary voltages P740 range

Three auxiliary power supply versions are available:

Nominal Ranges Operative dc range Operative ac range

24/54 V dc 19 - 65 V Not available

48/125 V dc (30/100 V ac rms.) ** 37 - 150 V 24 110 V

110/250 V dc (100/240 V ac rms.) ** 87 - 300 V 80 265 V

** rated for AC or DC operation.

Pass Criteria All functions operate as specified within the operative ranges

All power supplies operate continuously over their operative ranges, and environmental conditions


9.1.3 Universal Logic inputs (P740 range)

Battery Voltage (V dc) Logical off (V dc) Logical on (V dc)

24/27 <16.2 >19.2

30/34 <20.4 >24

48/54 <32.4 >38.4

110/125 <75 >88

220/250 <150 >176

9.1.4 Output contacts (P740 range)

Make & Carry 30A for 3s

Carry 250A for 30ms 10A continuous

Break DC: 50W resistive DC: 37.5W inductive (L/R = 40ms) AC: 1250VA AC: 1250 inductive (P.F. = 0.7)

Maxima: 10A and 300V

Loaded contact: 10,000 operation minimum

Unloaded contact: 100,000 operations minimum

Watchdog Contact

Break DC: 30W resistive DC: 15W inductive (L/R = 40ms) AC: 275VA inductive (P.F. = 0.7)

9.1.5 Field voltage (P740 range)

Rated field voltage output 48V dc

Rated field voltage current limit 112mA ±20%

Operating range 40V to 60V

Alarm voltage 35 V ±5%


9.2 Burdens

9.2.1 Current (P742 and P743)

Reference current (Ιn)

Phase <0.15VA at rated current

9.2.2 Auxiliary voltage

P740 range

Typical values

Type Case size Minimum*

P741

(8 Comms boards)

Size 16/80TE 37 to 41w

P742 Size 8/40TE 16W to 23 W

P743 Size 12/60TE 22W to 32 W

* no output contacts or optos energised

For each energised Opto powered from the Field Voltage or each energised Output Relay:

Each additional energised opto input

0.09W (24/27, 30/34, 48/54V)


0.12W (110/125V)


0.19W (220/250V)

Each additional energised output relay

0.13W

9.2.3 Optically isolated inputs

Peak current of opto inputs when energised is 3.5mA (0-300V)

Maximum input voltage 300V dc (any setting).


10. CT REQUIREMENTS (P740 RANGE)

10.1 Notation

IF max maximum fault current (same for all feeders)

IF max int maximum contribution from a feeder to an internal fault (depends on the feeder).

Inp CT primary rated current

In nominal secondary current (1A or 5A)

RCT CT secondary winding Resistance

RB Total external load resistance

Vk CT knee point voltage

SVA Nominal output in VA,

KSSC Short-circuit current coefficient (generally 20)

General recommendations for the specification of protection CTs use common rules of engineering which are not directly related to a particular protection.

10.2 CT Specification according to IEC 185, 44-6 and BS 3938 (British Standard)

1. Class x according to British Standard: Minimum knee point voltage for saturation

Vk min = 0.25 x secondary IF max x (RCT + RB)

The recommended specification makes it possible to guarantee a saturation time > 1.4 ms with a remnant flux of 80 % of maximum flux (class X or TPX). This provides a sufficient margin of security for CT saturation detection, which operates in less 1ms.

2. Class 5P to IEC 185. Conversion of class X (BS) with the 5P equivalent (IEC)

3. Class TPX and TPY according to IEC 44-6. IEC defines a composite error as a percentage of a multiple of the rated current (IN) on a definite load SVA.

e.g. CT 1000/5 A 50VA 5P 20.

This definition indicates that the composite error must be lower than 5%, for a primary current of 20Inp when the external load is equal to 2 ohms (50VA to IN). If secondary resistance, RCT, is known it is easy to calculate the magnetising EMF developed with the fault current (20IN). Actually if the error is 5% (= 5A) with this EMF, the point of operation is beyond the knee point voltage for saturation. By convention one admits that the knee point voltage, Vk, is 80% of this value. For a conversion between a class 5P (IEC) and a class X (BS) CT one uses the relation:

Vk=0.8 X [(SVA x Kssc)/In + (RCT x Kscc x In) ]

SVA = (In x Vk/0.8 Kssc) RCT x In ²

In particular cases, calculation could reveal values too low to correspond to industrial standards. In this case the minima will be: SVA min = 10 VA 5P 20 which corresponds to a knee point voltage of approximately Vkmin = 70 V at 5A or 350V at 1A. Class TPY would permit lower values of power, (demagnetisation air-gap). Taking into account the weak requirements of class X or TPX one can keep specifications common.


For accuracy, class X or class 5P current transformers (CTs) are strongly recommended. The knee point voltage of the CTs should comply with the minimum requirements of the formulae shown below.

Vk min ≥ 0.5 x (secondary If max) x (RCT + RB)

Where:

Vk = Required knee point voltage

RCT = CT secondary resistance

RB = Circuit impedance from CT to relay

If = Maximum value of through fault current for stability (multiple of In)

10.3 Support of IEEE C Class CTs

MiCOM Px40 series protection is compatible with ANSI/IEEE current transformers as specified in the IEEE C57.13 standard. The applicable class for protection is class C, which specifies a non air-gapped core. The CT design is identical to IEC class P, or British Standard class X, but the rating is specified differently. The following table allows C57.13 ratings to be translated into an IEC/BS knee point voltage:

IEEE C57.13 C Classification (volts)

CT Ratio RCT (ohm) 50 100 200 400 800

100/5 0.04 56.5 109 214 424 844

200/5 0.08 60.5 113 218 428 848

400/5 0.16 68.5 121 226 436 856

800/5 0.32 84.5 137 242 452 872

1000/5 0.4 92.5 145 250 460 880

1500/5 0.6 112.5 165 270 480 900

2000/5 0.8 132.5 185 290 500 920

3000/5 1.2 172.5 225 330 540 960

Table 1 IEC/BS Knee Point Voltage Vk offered by C class CTs


Assumptions:

4. For 5A CTs, the typical resistance is 0.002 ohms/secondary turn

5. IEC/BS knee is typically 5% higher than ANSI/IEEE knee

Given:

6. IEC/BS knee is specified as an internal EMF, whereas the C class voltage is specified at the CT output terminals. To convert from ANSI/IEEE to IEC/BS requires the voltage drop across the CTs secondary winding resistance to be added.

7. IEEE CTs are always rated at 5A secondary

8. The rated dynamic current output of a C class CT (Kssc) is always 20 x In

Vk = (C x 1.05) + (In. Rct. Kssc)

Where:

Vk = Equivalent IEC or BS knee point voltage

C = C Rating

In = 5A

Rct = CT secondary winding resistance

Kssc = 20


11. HIGH VOLTAGE WITHSTAND (P740 RANGE)

11.1 Dielectric withstand, impulse, insulation resistance and ANSI test requirements insulation test voltage

11.1.1 Impulse

IEC 60255-5:1977

5kV 1.2/50µs impulse, common and differential mode - input, power supply, & terminal block communications connections.

11.1.2 Dielectric withstand

IEC 60255-5:1977

2kV rms. for 1 minute between all terminals connected together and case earth.

2kV rms. for 1 minute between all terminals of independent circuits with terminals on each independent circuit connected together.

1kV rms. for 1 minute across watchdog contacts.

11.1.3 ANSI dielectric withstand

ANSI/IEEE C37.90. (1989) (Reaff. 1994)

1kV rms. for 1 minute across open contacts of the watchdog contacts.

1kV rms. for 1 minute across open contacts of changeover output contacts.

1.5kV rms. for 1 minute across normally open output contacts.

11.1.4 Insulation resistance

IEC 60255-5:1977

100 MΩ minimum.


12. ELECTRICAL ENVIRONMENT

12.1 Performance criteria

The following three classes of performance criteria are used within sections 12.2 to 12.12 (where applicable) to specify the performance of the MiCOM relay when subjected to the electrical interference. The performance criteria are based on the performance criteria specified in EN 50082-2:1995.

12.1.1 Class A

During the testing the relay shall not maloperate, upon completion of the testing the relay shall function as specified. A maloperation shall include a transient operation of the output contacts, operation of the watchdog contacts, reset of any of the relays microprocessors or an alarm indication.

The relay communications and IRIG-B signal must continue uncorrupted via the communications ports and IRIG-B port respectively during the test, however relay communications and the IRIG-B signal may be momentarily interrupted during the tests, provided that they recover with no external intervention.

12.1.2 Class B

During the testing the relay shall not maloperate, upon completion of the testing the relay shall function as specified. A maloperation shall include a transient operation of the output contacts, operation of the watchdog contacts, reset of any of the relays microprocessors or an alarm indication. A transitory operation of the output LEDs is acceptable provided no permanent false indications are recorded.

The relay communications and IRIG-B signal must continue uncorrupted via the communications ports and IRIG-B port respectively during the test, however relay communications and the IRIG-B signal may be momentarily interrupted during the tests, provided that they recover with no external intervention.

12.1.3 Class C

The relay shall power down and power up again in a controlled manner within 5 seconds. The output relays are permitted to change state during the test as long as they reset once the relay powers up.

Communications to relay may be suspended during the testing as long as communication recovers with no external intervention after the testing.

12.2 Auxiliary supply tests, dc interruption, etc.

12.2.1 DC voltage interruptions

P740 Range

IEC 60255-11:1979.

DC Auxiliary Supply Interruptions 2, 5, 10, 20ms. Performance criteria - Class A.

DC Auxiliary Supply Interruptions 50, 100, 200ms, 40s. Performance criteria - Class C.


12.2.2 DC voltage fluctuations

P740 range

IEC 60255-11:1979.

AC 100Hz ripple superimposed on DC max. and min. auxiliary supply at 12% of highest rated DC.

Performance criteria - Class A.

12.3 AC voltage dips and short interruptions

12.3.1 AC Voltage short interruptions

P740 range

IEC 61000-4-11:1994.

AC Auxiliary Supply Interruptions 2, 5, 10, 20ms. Performance criteria - Class A. AC Auxiliary Supply Interruptions 50, 100, 200ms, 1s, 40s. Performance criteria - Class C.

12.3.2 AC voltage dips

P740 range

IEC 61000-4-11:1994

AC Auxiliary Supply 100% Voltage Dips 2, 5, 10, 20ms. Performance criteria - Class A. AC Auxiliary Supply 100% Voltage Dips 50, 100, 200ms, 1s, 40s. Performance criteria - Class C.



12.4 High Frequency Disturbance IEC 60255-22-1:1988 Class III. (P740 range)

1MHz burst disturbance test.

2.5kV common mode.

Power supply, field voltage, CTs, VTs, opto inputs, output contacts, IRIG-B and terminal block communications connections.

1kV differential mode.

Power supply, field voltage, CTs, VTs, opto inputs and output contacts.

Performance criteria Class A.


12.5 Fast Transients (P740 range)

IEC 60255-22-4:1992 (EN 61000-4-4:1995), Class III and Class IV.

2kV 5kHz (Class III) and 4kV 2.5kHz (Class IV) direct coupling.

Power supply, field voltage, opto inputs, output contacts, CTs, VTs.

2kV 5kHz (Class III) and 4kV 2.5kHz (Class IV) capacitive clamp.

IRIG-B and terminal block communications connections.


12.6 Conducted / Radiated emissions (P740 range)

12.6.1 Conducted emissions

EN 55011:1998 Class A, EN 55022:1994 Class A.

0.15 - 0.5MHz, 79dBµV (quasi peak) 66dBµV (average).

0.5 - 30MHz, 73dBµV (quasi peak) 60dBµV (average).

12.6.2 Radiated emissions

EN 55011:1998 Class A, EN 55022:1994 Class A.

30 - 230MHz, 40dBµV/m at 10m measurement distance.

230 - 1000MHz, 47dBµV/m at 10m measurement distance.

12.7 Conducted / Radiated Immunity (P740 range)

12.7.1 Conducted immunity

EN 61000-4-6:1996 Level 3.

10V emf @ 1kHz 80% am, 150kHz to 80MHz. Spot tests at 27MHz, 68MHz.


12.7.2 Radiated immunity

IEC 60255-22-3:1989 Class III (EN 61000-4-3: 1997 Level 3).

10 V/m 80MHz - 1GHz @ 1kHz 80% am.

Spot tests at 80MHz, 160MHz, 450MHz, 900MHz.



12.7.3 Radiated immunity from digital radio telephones

ENV 50204:1995

10 V/m 900MHz ± 5 MHz and 1.89GHz ±5MHz, 200Hz rep. freq., 50% duty cycle pulse modulated.


12.8 Electrostatic Discharge (P740 range)

IEC 60255-22-2:1996 Class 3 & Class 4.

Class 4: 15kV air discharge. Class 3: 6kV contact discharge. Tests carried out both with and without cover fitted.


12.9 Surge Immunity (P740 range)

IEC 61000-4-5:1995 Level 4.

4kV common mode 12Ω source impedance, 2kV differential mode 2Ω source impedance.

Power supply, field voltage, CTs, VTs.

4kV common mode 42Ω source impedance, 2kV differential mode 42Ω source impedance.

Opto inputs, output contacts.

4kV common mode 2Ω source impedance applied to cable screen.

Terminal block communications connections and IRIG-B.

Performance criteria Class A under reference conditions.

12.10 Power Frequency Interference (P740 range)

NGTS* 2.13 Issue 3 April 1998, section 5.5.6.9.

500V rms. common mode. 250V rms. differential mode.

Voltage applied to all non-mains frequency inputs. Interference applied to all permanently connected communications circuits via the induced voltage method.


* National Grid Technical Specification


12.11 Surge Withstand Capability (SWC)

ANSI/IEEE C37.90.1 (1990) (Reaff. 1994)

Oscillatory SWC Test. 2.5kV 3kV, 1 - 1.5MHz - common and differential mode applied to all circuits except for IRIG-B and terminal block communications, which are tested common mode only via the cable screen.

Fast Transient SWC Tests

4 - 5kV crest voltage - common and differential mode - applied to all circuits except for IRIG-B and terminal block communications, which are tested common mode only via the cable screen.

Performance criteria Class A (see section 8.2).

12.12 Radiated Immunity

ANSI/IEEE C37.90.2 1995

35 V/m 25MHz - 1GHz, no modulation applied to all sides.

35 V/m 25MHz - 1GHz, 100% pulse modulated, front only.

Performance criteria Class A (see section 8.2).

12.13 Power Frequency Magnetic Field Immunity

IEC 61000-4-8:1994 Level 5.

100A/m field applied continuously in all planes for the EUT in a quiescent and tripping state

1000A/m field applied for 3s in all planes for the EUT in a quiescent and tripping state


13. ATMOSPHERIC ENVIRONMENT

13.1 Temperature

IEC 60068-2-1:1990/A2:1994 - Cold

IEC 60068-2-2:1974/A2:1994 - Dry heat

IEC 60255-6:1988.

Operating temperature range °C Storage temperature range °C

Cold Temperature

Dry heat Temperature

Cold Temperature

Dry heat Temperature

-25 55 -25 70

13.2 Humidity

IEC 60068-2-3:1969

Damp heat, steady state, 40° C ± 2° C and 93% relative humidity (RH) +2% -3%, duration 56 days.

IEC 60068-2-30:1980.

Damp heat cyclic, six (12 + 12 hour cycles) of 55°C ±2°C 93% ±3% RH and 25°C ±3°C 93% ±3% RH.

13.3 Enclosure protection

IEC 60529:1989.

IP52 Category 2.

IP5x Protected against dust, limited ingress permitted.

IPx2 Protected against vertically falling drops of water with the product in 4 fixed positions of 15° tilt with a flow rate of 3mm/minute for 2.5 minutes.


14. MECHANICAL ENVIRONMENT

14.1 Performance criteria

The following severity classes are used, where applicable, to specify the performance to specify the performance of the MiCOM relay, when subjected to mechanical testing.

14.1.1 Severity Classes

The following table details the Class and Typical Applications of the vibration, shock bump and seismic tests detailed previously

Class Typical Application

1 Measuring relays and protection equipment for normal use in power plants, substations and industrial plants and for normal transportation conditions

2 Measuring relays and protection equipment for which a very high security margin is required or where the vibration (shock and bump) (seismic shock) levels are very high, e.g. shipboard application and for severe transportation conditions.

14.1.2 Vibration (sinusoidal)

IEC 60255-21-1:1988

Cross over frequency - 58 to 60 Hz

Vibration Response

Severity Class Peak displacement below cross over frequency (mm)

Peak acceleration above cross over frequency (gn)

Number of sweeps in each axis

Frequency range (Hz)

2 0.075 1 1 10 150

Vibration Endurance

Severity Class Peak acceleration (gn)

Number of sweeps in each axis


2 2.0 20 10 150


14.1.3 Shock and bump

IEC 60255-21-2:1988

Type of test Severity Class

Peak acceleration (gn)

Duration of pulse (ms)

Number of Pulses in each direction

Shock response 2 10 11 3

Shock withstand 1 15 11 3

Bump 1 10 16 1000

14.1.4 Seismic

IEC 60255-21-3:1993

Cross over frequency - 8 to 9Hz

x = horizontal axis, y = vertical axis

Severity Class

Peak displacement below cross over frequency (mm)

Peak acceleration above cross over frequency (gn)

Number of sweep cycles in each axis


x y x y

2 7.5 3.5 2.0 1.0 1 1- 35


15. INFLUENCING QUANTITIES

15.1 Harmonics (P740 range)

Tolerances quoted are an additional tolerance with respect to measured accuracy without harmonics.

Harmonics applied 2nd 17th 10% harmonics

Measurements / filtered relay inputs Unaffected by harmonics

15.2 Frequency (P740 Range)

Operating frequency 45Hz 65Hz Affect

Overcurrent protection Unaffected by frequency

Earth fault protection Unaffected by frequency

Sensitive earth fault protection Unaffected by frequency

Disturbance recorder Unaffected by frequency

Differential protection Unaffected by frequency


16. MISCELLANEOUS

16.1 Analogue inputs, Logic inputs, Outputs relays (P740 range)

Relay 1A/5A dual rated CTs

Logic inputs

Output relays

Output LEDs

Test port

P741 0 8 8 8 TTL logic output



status displayed on LCD

status displayed on LCD

test pattern available on front user interface

DDB* signals mapped to front port for test purposes

*Digital Data Bus

16.2 Front user interface (P740 range)

All relay settings configurable from front user interface with the exception of programmable scheme logic.

Compliant

Back light inactivity timer 15 min. ±1min.

Two levels of password protection. Protection critical cells have high level password protection with other cells requiring a lower or no password

Compliant

Password protection removable Compliant

16.3 Battery life (P740 range)

Battery life (assuming relay energised for 90% of time) > 10 years

Low battery voltage, failure or absence of battery will be indicated Compliant

The relay is protected against incorrect insertion of battery Compliant

Removal of the battery with the relay energised will no affect records, events or real time clock

Compliant


16.4 Frequency tracking (P740 range)

Relay will frequency track over its entire operating range 45 65Hz

The relay will frequency track off any current inputs Compliant

The relay will frequency track down to the following

Levels: Current

Effect of harmonic None, relay tracks off fundamental frequency

16.5 K-Bus compatibility (P740 range)

Relay K-Bus interface compatible with other relays of different product families using K-Bus.

Compliant

Relay K-Bus port operates over 1km range with loading at either end of transmission line.

Compliant

17. EC EMC COMPLIANCE (P740 RANGE)

Compliance to the European Community Directive 89/336/EEC amended by 93/68/EEC is claimed via the Technical Construction File route.

The Competent Body has issued a Technical Certificate and a Declaration of Conformity has been completed.

The following Generic Standards used to establish conformity:

EN 50081-2:1994

EN 50082-2:1995.

18. EC LVD COMPLIANCE (P740 RANGE)

Compliance with European Community Directive on Low Voltage 73/23/EEC is demonstrated by reference to generic safety standards:

EN 61010-1:1993/A2: 1995

EN 60950:1992/A11 1997

Installation P740/EN IN/D11 MiCOM P740

INSTALLATION

P740/EN IN/D11 Installation MiCOM P740

Installation P740/EN IN/D11 MiCOM P740 Page 1/9

CONTENTS

1. RECEIPT OF RELAYS 2

2. HANDLING OF ELECTRONIC EQUIPMENT 2

3. STORAGE 3

4. UNPACKING 3

5. RELAY MOUNTING 4

5.1 Rack mounting 5

5.2 Panel mounting 6

6. RELAY WIRING 7

6.1 Medium and heavy duty terminal block connections 7

6.2 RS485 port (P741 only) 8

6.3 IRIG-B connections (P741 only) 8

6.4 RS232 port 8

6.5 Download/monitor port 8

6.6 Earth connection 9

P740/EN IN/D11 Installation Page 2/10 MiCOM P740

1. RECEIPT OF RELAYS

Protective relays, although generally of robust construction, require careful treatment prior to installation on site. Upon receipt, relays should be examined immediately to ensure no external damage has been sustained in transit. If damage has been sustained, a claim should be made to the transport contractor and AREVA T&D should be promptly notified.

Relays that are supplied unmounted and not intended for immediate installation should be returned to their protective polythene bags and delivery carton. Section 3 of this chapter gives more information about the storage of relays.

2. HANDLING OF ELECTRONIC EQUIPMENT

A persons normal movements can easily generate electrostatic potentials of several thousand volts. Discharge of these voltages into semiconductor devices when handling electronic circuits can cause serious damage which, although not always immediately apparent, will reduce the reliability of the circuit. This is particularly important to consider where the circuits use complementary metal oxide semiconductors (CMOS), as is the case with these relays.

The relays electronic circuits are protected from electrostatic discharge when housed in the case. Do not expose them to risk by removing the front panel or printed circuit boards unnecessarily.

Each printed circuit board incorporates the highest practicable protection for its semiconductor devices. However, if it becomes necessary to remove a printed circuit board, the following precautions should be taken to preserve the high reliability and long life for which the relay has been designed and manufactured.

1. Before removing a printed circuit board, ensure that you are at the same electrostatic potential as the equipment by touching the case.

2. Handle analogue input modules by the front panel, frame or edges of the circuit boards. Printed circuit boards should only be handled by their edges. Avoid touching the electronic components, printed circuit tracks or connectors.

3. Do not pass the module to another person without first ensuring you are both at the same electrostatic potential. Shaking hands achieves equipotential.

4. Place the module on an anti-static surface, or on a conducting surface which is at the same potential as yourself.

5. If it is necessary to store or transport printed circuit boards removed from the case, place them individually in electrically conducting anti-static bags.

In the unlikely event that you are making measurements on the internal electronic circuitry of a relay in service, it is preferable that you are earthed to the case with a conductive wrist strap. Wrist straps should have a resistance to ground between 500kΩ to 10MΩ. If a wrist strap is not available you should maintain regular contact with the case to prevent a build-up of electrostatic potential. Instrumentation which may be used for making measurements should also be earthed to the case whenever possible.

More information on safe working procedures for all electronic equipment can be found in BS EN 100015:Part 1:1992. It is strongly recommended that detailed investigations on electronic circuitry or modification work should be carried out in a special handling area such as described in the aforementioned British Standard document.


3. STORAGE

If relays are not to be installed immediately upon receipt, they should be stored in a place free from dust and moisture in their original cartons. Where de-humidifier bags have been included in the packing they should be retained. The action of the de-humidifier crystals will be impaired if the bag is exposed to ambient conditions and may be restored by gently heating the bag for about an hour prior to replacing it in the carton.

To prevent battery drain during transportation and storage a battery isolation strip is fitted during manufacture. With the lower access cover open, presence of the battery isolation strip can be checked by a red tab protruding from the positive side.

Care should be taken on subsequent unpacking that any dust which has collected on the carton does not fall inside. In locations of high humidity the carton and packing may become impregnated with moisture and the de-humidifier crystals will lose their efficiency.

Prior to installation, relays should be stored at a temperature of between 25ûC to +70ûC.

4. UNPACKING

Care must be taken when unpacking and installing the relays so that none of the parts are damaged and additional components are not accidentally left in the packing or lost.

Note: With the lower access cover open, the red tab of the battery isolation strip will be seen protruding from the positive side of the battery compartment. Do not remove this strip because it prevents battery drain during transportation and storage and will be removed as part of the commissioning tests.

Relays must only be handled by skilled persons.

The site should be well lit to facilitate inspection, clean, dry and reasonably free from dust and excessive vibration. This particularly applies to installations which are being carried out at the same time as construction work.


5. RELAY MOUNTING

MiCOM relays are dispatched either individually or as part of a panel/rack assembly.

Individual relays are normally supplied with an outline diagram showing the dimensions for panel cut-outs and hole centres. This information can also be found in the product publication.

Secondary front covers can also be supplied as an option item to prevent unauthorised changing of settings and alarm status. They are available in sizes 40TE (GN0037 001) and 60TE (GN0038 001). Note that the 60TE cover also fits the 80TE case size of the relay.

The design of the relay is such that the fixing holes in the mounting flanges are only accessible when the access covers are open and hidden from sight when the covers are closed.

If a P991 or MMLG test block is to be included, it is recommended that, when viewed from the front, it is positioned on the right-hand side of the relay (or relays) with which it is associated. This minimises the wiring between the relay and test block, and allows the correct test block to be easily identified during commissioning and maintenance tests.

FIGURE 1: LOCATION OF BATTERY ISOLATION STRIP

If it is necessary to test correct relay operation during the installation, the battery isolation strip can be removed but should be replaced if commissioning of the scheme is not imminent. This will prevent unnecessary battery drain during transportation to site and installation. The red tab of the isolation strip can be seen protruding from the positive side of the battery compartment when the lower access cover is open. To remove the isolation strip, pull the red tab whilst lightly pressing the battery to prevent it falling out of the compartment. When replacing the battery isolation strip, ensure that the strip is refitted as shown in Figure 1, ie. with the strip behind the battery with the red tab protruding.


5.1 Rack mounting

MiCOM relays may be rack mounted using single tier rack frames (our part number FX0121 001), as illustrated in Figure 2. These frames have been designed to have dimensions in accordance with IEC60297 and are supplied pre-assembled ready to use. On a standard 483mm (19) rack system this enables combinations of widths of case up to a total equivalent of size 80TE to be mounted side by side.

The two horizontal rails of the rack frame have holes drilled at approximately 26mm intervals and the relays are attached via their mounting flanges using M4 Taptite self-tapping screws with captive 3mm thick washers (also known as a SEMS unit). These fastenings are available in packs of 5 (our part number ZA0005 104).

Note: Conventional self-tapping screws, including those supplied for mounting MIDOS relays, have marginally larger heads which can damage the front cover moulding if used.

Once the tier is complete, the frames are fastened into the racks using mounting angles at each end of the tier.

P0147XXb

FIGURE 2: RACK MOUNTING OF RELAYS

Relays can be mechanically grouped into single tier (4U) or multi-tier arrangements by means of the rack frame. This enables schemes using products from the MiCOM and MiDOS product ranges to be pre-wired together prior to mounting.

Where the case size summation is less than 80TE on any tier, or space is to be left for installation of future relays, blanking plates may be used. These plates can also be used to mount ancillary components. Table 1 shows the sizes that can be ordered.

Further details on mounting MiDOS relays can be found in publication R7012, MiDOS Parts Catalogue and Assembly Instructions.


Case size summation Blanking plate part number

5TE GJ2128 001

10TE GJ2128 002

15TE GJ2128 003

20TE GJ2128 004

25TE GJ2128 005

30TE GJ2128 006

35TE GJ2128 007

40TE GJ2128 008

TABLE 1: BLANKING PLATES

5.2 Panel mounting

The relays can be flush mounted into panels using M4 SEMS Taptite self-tapping screws with captive 3mm thick washers (also known as a SEMS unit). These fastenings are available in packs of 5 (our part number ZA0005 104).

Note: Conventional self-tapping screws, including those supplied for mounting MIDOS relays, have marginally larger heads which can damage the front cover moulding if used.

Alternatively tapped holes can be used if the panel has a minimum thickness of 2.5mm.

For applications where relays need to be semi-projection or projection mounted, a range of collars are available.

Where several relays are to mounted in a single cut-out in the panel, it is advised that they are mechanically grouped together horizontally and/or vertically to form rigid assemblies prior to mounting in the panel.

Note: It is not advised that MiCOM relays are fastened using pop rivets as this will not allow the relay to be easily removed from the panel in the future if repair is necessary.

If it is required to mount a relay assembly on a panel complying to BS EN60529 IP52, it will be necessary to fit a metallic sealing strip between adjoining relays (Part no GN2044 001) and a sealing ring selected from Table 2 around the complete assembly.


Width Single tier Double tier

10TE GJ9018 002 GJ9018 018

15TE GJ9018 003 GJ9018 019

20TE GJ9018 004 GJ9018 020

25TE GJ9018 005 GJ9018 021

30TE GJ9018 006 GJ9018 022

35TE GJ9018 007 GJ9018 023

40TE GJ9018 008 GJ9018 024

45TE GJ9018 009 GJ9018 025

50TE GJ9018 010 GJ9018 026

55TE GJ9018 011 GJ9018 027

60TE GJ9018 012 GJ9018 028

65TE GJ9018 013 GJ9018 029

70TE GJ9018 014 GJ9018 030

75TE GJ9018 015 GJ9018 031

80TE GJ9018 016 GJ9018 032

TABLE 2: IP52 SEALING RINGS

Further details on mounting MiDOS relays can be found in publication R7012, MiDOS Parts Catalogue and Assembly Instructions.

6. RELAY WIRING

This section serves as a guide to selecting the appropriate cable and connector type for each terminal on the MiCOM relay.

6.1 Medium and heavy duty terminal block connections

Loose relays are supplied with sufficient M4 screws for making connections to the rear mounted terminal blocks using ring terminals, with a recommended maximum of two ring terminals per relay terminal.

If required, AREVA T&D can supply M4 90° crimp ring terminals in three different sizes depending on wire size (see Table 3). Each type is available in bags of 100.

Part number Wire size Insulation colour

ZB9124 901 0.25 1.65mm2 (22 16AWG) Red

ZB9124 900 1.04 2.63mm2 (16 14AWG) Blue

ZB9124 904 2.53 6.64mm2 (12 10AWG) Uninsulated*

TABLE 3: M4 90° CRIMP RING TERMINALS

* To maintain the terminal block insulation requirements for safety, an insulating sleeve should be fitted over the ring terminal after crimping.


The following minimum wire sizes are recommended:

Current Transformers 2.5mm2

Auxiliary Supply, Vx 1.5mm2

RS485 Port See separate section

Other circuits 1.0mm2

Due to the limitations of the ring terminal, the maximum wire size that can be used for any of the medium or heavy duty terminals is 6.0mm2 using ring terminals that are not pre-insulated. Where it required to only use pre-insulated ring terminals, the maximum wire size that can be used is reduced to 2.63mm2 per ring terminal. If a larger wire size is required, two wires should be used in parallel, each terminated in a separate ring terminal at the relay.

The wire used for all connections to the medium and heavy duty terminal blocks, except the RS485 port, should have a minimum voltage rating of 300Vrms.

It is recommended that the auxiliary supply wiring should be protected by a 16A high rupture capacity (HRC) fuse of type NIT or TIA. For safety reasons, current transformer circuits must never be fused. Other circuits should be appropriately fused to protect the wire used.

6.2 RS485 port (P741 only)

Connections to the RS485 port are made using ring terminals. It is recommended that a 2 core screened cable is used with a maximum total length of 1000m or 200nF total cable capacitance. A typical cable specification would be:

Each core: 16/0.2mm copper conductors

PVC insulated

Nominal conductor area: 0.5mm2 per core

Screen: Overall braid, PVC sheathed

6.3 IRIG-B connections (P741 only)

The IRIG-B input and BNC connector have a characteristic impedance of 50Ω. It is recommended that connections between the IRIG-B equipment and the relay are made using coaxial cable of type RG59LSF with a halogen free, fire retardant sheath.

6.4 RS232 port

Short term connections to the RS232 port, located behind the bottom access cover, can be made using a screened multi-core communication cable up to 15m long, or a total capacitance of 2500pF. The cable should be terminated at the relay end with a 9-way, metal shelled, D-type male plug.

6.5 Download/monitor port

Short term connections to the download/monitor port, located behind the bottom access cover, can be made using a screened 25-core communication cable up to 4m long. The cable should be terminated at the relay end with a 25-way, metal shelled, D-type male plug.


6.6 Earth connection

Every relay must be connected to the local earth bar using the M4 earth studs in the bottom left hand corner of the relay case. The minimum recommended wire size is 2.5mm2 and should have a ring terminal at the relay end. Due to the limitations of the ring terminal, the maximum wire size that can be used for any of the medium or heavy duty terminals is 6.0mm2 per wire. If a greater cross-sectional area is required, two parallel connected wires, each terminated in a separate ring terminal at the relay, or a metal earth bar could be used.

Note: To prevent any possibility of electrolytic action between brass or copper earth conductors and the rear panel of the relay, precautions should be taken to isolate them from one another. This could be achieved in a number of ways, including placing a nickel-plated or insulating washer between the conductor and the relay case, or using tinned ring terminals.

Before carrying out any work on the equipment, the user should be familiar with the contents of the Safety and Technical Data sections and the ratings on the equipment's rating label

Commissioning/Maintenance P740/EN CM/D11 MiCOM P740 Page 1/78

COMMISSIONING AND MAINTENANCE

P740/EN CM/D11 Commissioning/Maintenance Page 2/78 MiCOM P740


CONTENTS

1. INTRODUCTION 5

2. SETTING FAMILIARISATION 6

3. EQUIPMENT REQUIRED FOR COMMISSIONING 7

3.1. Minimum equipment required 7

3.2. Optional equipment 7

4. PRODUCT CHECKS 8

4.1. With the relay de-energised 8 4.1.1. Visual inspection 9

4.1.2. Current transformer shorting contacts 9

4.1.3. Insulation 11

4.1.4. External wiring 12

4.1.5. Watchdog contacts 12

4.1.6. Auxiliary supply 12

4.2. With the relay energised 13 4.2.1. Watchdog contacts 13

4.2.2. Date and time 13

4.2.3. Light Emitting Diodes (LEDs) 14

4.2.4. Field voltage supply 15

4.2.5. Input opto-isolators 15

4.2.6. Output relays 16

4.2.7. Current differential communications 17

4.2.8. Current inputs (P742, P743 only) 17

5. SETTING CHECKS 19

5.1. Apply application-specific settings 19

5.2. How to measure the Burden Resistance (RB) 20

5.3. Demonstrate Correct Relay Operation 20 5.3.1. Current Differential Bias Characteristic 22

5.3.2. Phase Overcurrent Protection (P742 and P743) 26

5.3.3. Breaker Failure Protection 28

5.4. Check Application Settings 30


6. END TO END TESTS 31

7. ON-LOAD CHECKS 31

8. FINAL CHECKS 32

9. MAINTENANCE 33

9.1. Maintenance period 33

9.2. Maintenance checks 33 9.2.1. Alarms 33

9.2.2. Opto-isolators 33

9.2.3. Output relays 33

9.2.4. Measurement accuracy 34

9.3. Method of repair 34 9.3.1. Replacing the complete relay 34

9.3.2. Replacing a PCB 36

9.4. Recalibration 50 9.4.1. P740 relay 50

9.5. Changing the relay battery 50 9.5.1. Instructions for replacing the battery. 50

9.5.2. Post modification tests 51

9.5.3. Battery disposal 51

9.6. Cleaning 51

10. COMMISSIONING TEST RECORD: 52

10.1. Peripheral Units: P742/P743 52

11. SETTING RECORD 60

11.1. Central Unit: P741 60

11.2. Peripheral Units: P742/P743 68


1. INTRODUCTION

The MiCOM P740 Busbar Differential Protection is fully numerical in their design, implementing all protection and non-protection functions in software. The relays employ a high degree of self-checking and, in the unlikely event of a failure, will give an alarm. As a result of this, the commissioning tests do not need to be as extensive as with non-numeric electronic or electromechanical relays.

To commission numeric relays, it is only necessary to verify that the hardware is functioning correctly and the application-specific software settings have been applied to the relay (PSL, topology, differential and breaker failure protection linked to the topology/PSL). It is considered unnecessary to test every function of the relay if the settings have been verified by one of the following methods:

- Extracting the settings applied to the relay using appropriate setting software (preferred method)

- Via the operator interface.

Unless previously agreed to the contrary, the customer will be responsible for determining the application-specific settings to be applied to the relay and for testing of any scheme logic applied by external wiring and/or configuration of the relays internal programmable scheme logic.

Blank commissioning test and setting records are provided at the end of this chapter for completion as required.

As the relays menu language is user-selectable, it is acceptable for the Commissioning Engineer to change it to allow accurate testing as long as the menu is restored to the customers preferred language on completion.

To simplify the specifying of menu cell locations in these Commissioning Instructions, they will be given in the form [courier reference: COLUMN HEADING, Cell Text]. For example, the cell for selecting the menu language (first cell under the column heading) is located in the System Data column (column 00) so it would be given as [SYSTEM DATA, Language].

Before carrying out any work on the equipment, the user should be familiar with the contents of the Safety and Technical Data sections and the ratings on the equipments rating label.


2. SETTING FAMILIARISATION

When commissioning a MiCOM P740 Busbar protection for the first time, sufficient time should be allowed to become familiar with the method by which the settings are applied.

The Introduction (P740/EN IT) contains a detailed description of the menu structure of P740 relays.

With the secondary front cover in place all keys except the ! key are accessible. All menu cells can be read. LEDs and alarms can be reset. However, no protection or configuration settings can be changed, or fault and event records cleared.

Removing the secondary front cover allows access to all keys so that settings can be changed, LEDs and alarms reset, and fault and event records cleared. However, menu cells that have access levels higher than the default level will require the appropriate password to be entered before changes can be made.

Alternatively, if a portable PC is available together with suitable setting software (such as MiCOM S1), the menu can be viewed a page at a time to display a full column of data and text. This PC software also allows settings to be entered more easily, saved to a file on disk for future reference or printed to produce a setting record. Refer to the PC software user manual for details. If the software is being used for the first time, allow sufficient time to become familiar with its operation.


3. EQUIPMENT REQUIRED FOR COMMISSIONING

3.1. Minimum equipment required

Overcurrent test set with interval timer

Multimeter with suitable ac current range, and ac and dc voltage ranges of 0 440V and 0 250V respectively

Continuity tester (if not included in multimeter)

Optical power meter with sensitivity 0 to 50dBm (to measure the optical signal level)

Note: Modern test equipment may contain many of the above features in one unit.

3.2. Optional equipment

Multi-finger test plug type P992 (if test block type P991 installed) or MMLB (if using MMLG blocks)

An electronic or brushless insulation tester with a dc output not exceeding 500V (for insulation resistance testing when required). This equipment will be required only if the dielectric test has been no done during the manufacturing process.

A portable PC, with appropriate software (this enables the rear communications port to be tested, if this is to be used, and will also save considerable time during commissioning).

A printer (for printing a setting record from the portable PC).


4. PRODUCT CHECKS

These product checks cover all aspects of the relay which should be checked to ensure that it has not been physically damaged prior to commissioning, is functioning correctly and all input quantity measurements are within the stated tolerances.

If the application-specific settings have been applied to the relay prior to commissioning, it is advisable to make a copy of the settings so as to allow their restoration later. This could be done by:

− Obtaining a setting file on a diskette from the customer (this requires a portable PC with appropriate setting software for transferring the settings from the PC to the relay)

− Extracting the settings from the relay itself (this again requires a portable PC with appropriate setting software)

− Manually creating a setting record. This could be done using a copy of the setting record located at the end of this chapter to record the settings as the relays menu is sequentially stepped through via the front panel user interface.

If password protection is enabled and the customer has changed password 2 that prevents unauthorised changes to some of the settings, either the revised password 2 should be provided, or the customer should restore the original password prior to commencement of testing.

Note: In the event that the password has been lost, a recovery password can be obtained from AREVA by quoting the serial number of the relay. The recovery password is unique to that relay and is unlikely to work on any other relay.

4.1. With the relay de-energised

The following group of tests should be carried out without the auxiliary supply being applied to the relay and with the trip circuit isolated.

The current and voltage transformer connections must be isolated from the relay for these checks. If a P991 test block is provided, the required isolation can easily be achieved by inserting test plug type P992 which effectively open-circuits all wiring routed through the test block.

Before inserting the test plug, reference should be made to the scheme (wiring) diagram to ensure that this will not potentially cause damage or a safety hazard. For example, the test block may be associated with protection current transformer circuits. It is essential that the sockets in the test plug which correspond to the current transformer secondary windings are linked before the test plug is inserted into the test block.


DANGER: Never open circuit the secondary circuit of a current transformer since the high voltage produced may be lethal and could damage insulation.

If a test block is not provided, the voltage transformer supply to the relay should be isolated by means of the panel links or connecting blocks. The line current transformers should be short-circuited and disconnected from the relay terminals. Where means of isolating the auxiliary supply and trip circuit (e.g. isolation links, fuses, MCB, etc.) are provided, these should be used. If this is not possible, the wiring to these circuits will have to be disconnected and the exposed ends suitably terminated to prevent them from being a safety hazard.

4.1.1. Visual inspection

Carefully examine the relay to see that no physical damage has occurred since installation.

The rating information given under the top access cover on the front of the relay should be checked to ensure it is correct for the particular installation.

Ensure that the case earthing connections, bottom left-hand corner at the rear of the relay case, are used to connect the relay to a local earth bar using an adequate conductor.

4.1.2. Current transformer shorting contacts

If required, the current transformer shorting contacts can be checked to ensure that they close when the heavy duty terminal block (block reference B for P742 and A for P743 in Figure 1and Figure 2) is disconnected from the current input PCB.

B

17

16

18

13

15

12

14

9

11

8

10

13 14

1716

15

18

1110 12

5

7

4

6

1

3

A

2

654

87 9

21 3

16

18

17 17

16

18

17

16

18

10

12

14

13

15

23

24

11

22

9

13

15

12

14

9

11

8

10

8

20

21

5

7

19 1

3

5

7

4

6

4

6

1

3

2 2

TX

13

15

12

14

9

11

8

10

RXCH2

5

7

4

6

1

3

2

TX

RXCH1

FC D E

Figure 1: Rear terminal blocks on P742


016

1817

17

15

24

13

10

7

1514

1211

1323

11

22

98

9

721

1

4

1932

65

5

20

3

A

1

14

16

1818 18

1617

1415

1716

1514

18

16

14

17

15

18

17

15

1716

1514

18 18

1617

1415

16

14

CH1

CH2

2

4

8

10

121213

1011

1312

1110

89

67

98

76

12

10

13

11

8

6

9

7

45

23

54

32

B

1

C

1

4

2

5

3

D

1

E

13

11

1312

1110

9

76

98

76

1213

1011

12

10

89

67

8

6

5

3

54

32

1

F

1

45

23

4

2

G

1

H

RX

TX

RX

TX

J

Figure 2 : Rear terminal blocks on P743

The heavy duty terminal block is fastened to the rear panel using four crosshead screws. These are located top and bottom between the first and second, and third and fourth, columns of terminals (see Figure 2).

Note: The use of a magnetic bladed screwdriver is recommended to minimise the risk of the screws being left in the terminal block or lost.

Pull the terminal block away from the rear of the case and check with a continuity tester that all the shorting switches being used are closed. Table 1 shows the terminals between which shorting contacts are fitted.

Shorting contact between terminals

P742 P743

Current input

1A common 5A 1A common 5A

ΙA B3 B2 B1 A3 A2 A1

ΙB B6 B5 B4 A6 A5 A4

ΙC B9 B8 B7 A9 A8 A7

ΙN B12 B11 B10 A12 A11 A10 Table 1: Current transformer shorting contact locations.


P0299ENa

Figure 3 :Location of securing screws for heavy duty terminal blocks.

4.1.3. Insulation

Insulation resistance tests are only necessary during commissioning if it is required for them to be done and they have not been performed during installation.

Isolate all wiring from the earth and test the insulation with an electronic or brushless insulation tester at a dc voltage not exceeding 500V. Terminals of the same circuits should be temporarily connected together.

The main groups of relay terminals are:

a) Current transformer circuits

b) Auxiliary voltage supply.

c) Field voltage output and opto-isolated control inputs.

d) Relay contacts.

e) Case earth.

The insulation resistance should be greater than 100MΩ at 500V.

On completion of the insulation resistance tests, ensure all external wiring is correctly reconnected to the relay.


4.1.4. External wiring

Check that the external wiring is correct to the relevant relay diagram or scheme diagram. The relay diagram number appears on the rating label under the top access cover on the front of the relay. The corresponding connection diagram will have been supplied with the AREVA order acknowledgement for the relay.

If a P991 test block is provided, the connections should be checked against the scheme (wiring) diagram. It is recommended that the supply connections are to the live side of the test block [coloured orange with the odd numbered terminals (1, 3, 5, 7 etc.). The auxiliary supply is normally routed via terminals 13 (supply positive) and 15 (supply negative), with terminals 14 and 16 connected to the relays positive and negative auxiliary supply terminals respectively. However, check the wiring against the schematic diagram for the installation to ensure compliance with the customers normal practice.

4.1.5. Watchdog contacts

Using a continuity tester, check that the watchdog contacts are in the states given in Table 2 for a de-energised relay.

Contact state Terminals

Relay de-energised Relay energised

L11 L12

E11 E12

H11 H12

(P741)

(P742)

(P743)

Closed Open

L13 L14

E13 E14

H13 H14

(P741)

(P742)

(P743)

Open Closed

Table 2: Watchdog contact status

4.1.6. Auxiliary supply

The P740 relay can be operated from either a dc only or an ac/dc auxiliary supply depending on the relays nominal supply rating. The incoming voltage must be within the operating range specified in Table 3.

Without energising the relay measure the auxiliary supply to ensure it is within the operating range.

Nominal supply rating DC [AC rms] DC operating range AC operating range

24 48V [] 19 to 65V -

48 110V [30 100V] 37 to 150V 24 to 110V

110 250V [100 240V] 87 to 300V 80 to 265V Table 3 Operational range of auxiliary supply Vx.


It should be noted that the P740 relay range can withstand an ac ripple of up to 12% of the upper rated voltage on the dc auxiliary supply.

Do not energise the relay or interface unit using the battery charger with the battery disconnected as this can irreparably damage the relays power supply circuitry.

Energise the relay only if the auxiliary supply is within the specified operating ranges. If a test block is provided, it may be necessary to link across the front of the test plug to connect the auxiliary supply to the relay.

4.2. With the relay energised

The following group of tests verify that the relay hardware and software is functioning correctly and should be carried out with the auxiliary supply applied to the relay.

The current and voltage transformer connections must remain isolated from the relay for these checks. The trip circuit should also remain isolated to prevent accidental operation of the associated circuit breaker.

4.2.1. Watchdog contacts

Using a continuity tester, check the watchdog contacts are in the states given in Table 2 for an energised relay.

4.2.2. Date and time

Before setting the date and time, ensure that the factory-fitted battery isolation strip, that prevents battery drain during transportation and storage, has been removed. With the lower access cover open, presence of the battery isolation strip can be checked by a red tab protruding from the positive side of the battery compartment. Whilst lightly pressing the battery, to prevent it from falling out of the battery compartment, pull the red tab to remove the isolation strip.

The date and time should now be set to the correct values. The method of setting will depend on whether accuracy is being maintained via the optional Inter-Range Instrumentation Group standard B (IRIG-B) port on the rear of the P741 relay.

4.2.2.1 With an IRIG-B signal for Central Unit (P741) only

If a satellite time clock signal conforming to IRIG-B is provided and the P741 relay has the optional IRIG-B port fitted, the satellite clock equipment should be energised.

To allow the relays time and date to be maintained from an external IRIG-B source cell [DATE and TIME, IRIG-B Sync] must be set to Enabled.

Ensure the relay is receiving the IRIG-B signal by checking that cell [DATE and TIME, IRIG-B Status] reads Active.

Once the IRIG-B signal is active, adjust the time offset of the universal co-ordinated time (satellite clock time) on the satellite clock equipment so that local time is displayed.

Check the time, date and month are correct in cell [DATE and TIME, Date/Time]. The IRIG-B signal does not contain the current year so it will need to be set manually in this cell.


In the event of the auxiliary supply failing, with a battery fitted in the compartment behind the bottom access cover, the time and date will be maintained. Therefore, when the auxiliary supply is restored, the time and date will be correct and not need to be set again.

To test this, remove the IRIG-B signal, then remove the auxiliary supply from the relay. Leave the relay de-energised for approximately 30 seconds. On re-energisation, the time in cell [DATE and TIME, Date/Time] should be correct.

Reconnect the IRIG-B signal.

The P741 will synchronise all peripheral units (P742/P743) every 10s and during the power on of the scheme.

4.2.2.2 Without an IRIG-B signal for Central Unit (P741) or Peripheral Unit (P742/P743)

If the time and date is not being maintained by an IRIG-B signal, ensure that cell [DATE and TIME, IRIG-B Sync] is set to Disabled.

Set the date and time to the correct local time and date using cell [DATE and TIME, Date/Time].

In the event of the auxiliary supply failing, with a battery fitted in the compartment behind the bottom access cover, the time and date will be maintained. Therefore when the auxiliary supply is restored the time and date will be correct and not need to be set again.

To test this, remove the auxiliary supply from the relay for approximately 30 seconds. On re-energisation, the time in cell [DATE and TIME, Date/Time] should be correct.

4.2.3. Light Emitting Diodes (LEDs)

On power up the green LED should have illuminated and stayed on indicating that the relay is healthy. The relay has non-volatile memory which remembers the state (on or off) of the alarm, trip and, if configured to latch, user-programmable LED indicators when the relay was last energised from an auxiliary supply. Therefore these indicators may also illuminate when the auxiliary supply is applied.

If any of these LEDs are on then they should be reset before proceeding with further testing. If the LEDs successfully reset (the LED goes out), there is no testing required for that LED because it is known to be operational.

Note: It is likely that alarms related to the communications channels will not reset at this stage.

4.2.3.1 Testing the alarm and out of service LEDs

The alarm and out of service LEDs can be tested using the COMMISSION TESTS menu column. Set cell [COMMISSION TESTS, Test Mode] to Contacts Blocked. Check that the out of service LED illuminates continuously and the alarm LED flashes.

It is not necessary to return cell [COMMISSION TESTS, Test Mode] to Disabled at this stage because the test mode will be required for later tests.


4.2.3.2 Testing the Trip LED

The trip LED can be tested by initiating a manual circuit breaker trip from the relay. However, the trip LED will operate during the setting checks performed later. Therefore no further testing of the trip LED is required at this stage. Please note that the CB control function does not exist in the Central Unit (P741) as only the Peripheral Unit (P742/P743) may trip/close the local circuit breakers.

4.2.3.3 Testing the user-programmable LEDS

To test the user-programmable LEDs set cell [COMMISSION TESTS, Test LEDs] to Apply Test. Check that all 8 LEDs on the right-hand side of the relay illuminate.

4.2.4. Field voltage supply

The relay generates a field voltage of nominally 48V dc that can be used to energise the opto-isolated inputs (alternatively the substation battery may be used).

Measure the field voltage across the terminals 7 and 9 on the terminal block given in Table 4. Check that the field voltage is within the range 40V to 60V when no load is connected and that the polarity is correct.

Repeat for terminals 8 and 10.

Terminals Supply rail

P741 P742 P743

+ve L7 & L8 E7 & E8 H7 & H8

ve L9 & L10 E9 & E10 H9 & H10

Table 4: Field voltage terminals

4.2.5. Input opto-isolators

This test checks that all the opto-isolated inputs on the relay are functioning correctly. The P741 relay has 8 opto-isolated inputs while the P742 relay has 16 opto-isolated inputs and P743 relays has 24 opto-isolated inputs.

The opto-isolated inputs should be energised one at a time, see external connection diagrams (P740/EN CO) for terminal numbers. Ensuring correct polarity, connect the field supply voltage to the appropriate terminals for the input being tested.


Note: The opto-isolated inputs may be energised from an external dc auxiliary supply (e.g. the station battery) in some installations. Check that this is not the case before connecting the field voltage otherwise damage to the relay may result.

The status of each opto-isolated input can be viewed using either cell [SYSTEM DATA, Opto I/P Status] or [COMMISSION TESTS, Opto I/P Status], a 1 indicating an energised input and a 0 indicating a de-energised input. When each opto-isolated input is energised one of the characters on the bottom line of the display will change to indicate the new state of the inputs.

4.2.6. Output relays

This test checks that all the output relays are functioning correctly. The P741 and P742 relays have 8 output relays while P743 relay has 21 output relays.

Note: For P743, the output boards are equipped with 8 output relays but only 7 are used on each board. See external Connection Diagrams Chapter (P740/EN CO) for terminal numbers.

Ensure that the relay is still in test mode by viewing cell [COMMISSION TESTS, Test Mode] to ensure that it is set to Blocked.

The output relays should be energised one at a time. To select output relay 1 for testing, set cell [COMMISSION TESTS, Test Pattern] as appropriate.

Connect a continuity tester across the terminals corresponding to output relay 1 as given in external connection diagram (P740/EN CO).

To operate the output relay set cell COMMISSION TESTS, Contact Test] to Apply Test. Operation will be confirmed by the continuity tester operating for a normally open contact and ceasing to operate for a normally closed contact. Measure the resistance of the contacts in the closed state.

Reset the output relay by setting cell [COMMISSION TESTS, Contact Test] to Remove Test.

Note: It should be ensured that thermal ratings of anything connected to the output relays during the contact test procedure is not exceeded by the associated output relay being operated for too long. It is therefore advised that the time between application and removal of contact test is kept to the minimum.

Repeat the test for relays 2 to 8 for P741 and P742 relays, 2 to 21 for P743 relay.

Return the relay to service by setting cell [COMMISSION TESTS, Test Mode] to Disabled.


4.2.7. Current differential communications

This test verifies that the P742 or P743 relays fibre optic communications ports used for communications to the P741 Central Unit, are operating correctly.

17

13

15

16

18

17

13

1415

9

11

7

9

1011

12

67

8

RX

RX

TX

15

13

1716

18

14

10

12

6

8

14

16

18

6

8

10

12

9

11

7

CH2

CH1

IRIG-B

RX

TX

K

CH1

CH2

CH4

CH3

CH4

CH3RX

TX

RX

RX

TX

RX

CH1

CH2RX

TX

RX

TX

RX

TX

RX

TX

TX

A

TX

B

RX

TX

CH4

CH3

RXCH4

CH3 RX

TX

RX

RX

TX

CH2

RX

TX

CH1

CH2 RX

TX

CH1 RX

TX

CH4

CH3 RX

TX

RXCH4

CH3 RX

TX

RX

CH2 RX

TX

CH1 RX

TX

CH2 RX

TX

CH1 RX

TX

CH4

CH3 RX

TX

RXCH4

CH3

RX

TX

RX

CH2 RX

TX

CH1 RX

TX

CH2

TX

RX

CH1

TX

RX

TX

C

TX

D

TX

E

TX

F

TX

G

TX

H

3

5

1

J

23

54

1

TX

2

4 4

23

5

1

L M N

Figure 4 : P741 Rear Terminal blocks and communication ports

When connecting or disconnecting optical fibres care should be taken not to look directly into the transmit port or end of the optical fibre.

From central unit, the cell [PU CONF & STATUS, PU connected] displayed the list of peripheral units connected to the central unit.

From peripheral unit, it is possible to check the communication with the central unit by disconnecting the optical fibre, an alarm Fibre Com Error should appear.

4.2.8. Current inputs (P742, P743 only)

This test verifies that the accuracy of current measurement is within the acceptable tolerances.

All relays will leave the factory set for operation at a system frequency of 50Hz. If operation at 60Hz is required then this must be set in cell [SYSTEM DATA, Frequency].

Apply current equal to the line current transformer secondary winding rating to each current transformer input of the corresponding rating in turn, see Table 1 or external connection diagram (P740/EN CO) for appropriate terminal numbers, checking its magnitude using a multimeter. The corresponding reading can then be checked in the relays MEASUREMENTS 1 column and value displayed recorded.

The measured current values displayed on the relay LCD or a portable PC connected to the front communication port will either be in primary or secondary Amperes. If cell [MEASURET SETUP, Local Values] is set to Primary, the values displayed should be equal to the applied current multiplied by the corresponding current transformer ratio set in the CT and VT RATIOS menu column (see SEQARABIC). If cell [MEASURET SETUP, Local Values] is set to Secondary, the value displayed should be equal to the applied current.

The measurement accuracy of the relay is ±5%. However, an additional allowance must be made for the accuracy of the test equipment being used.


Cell in MEASUREMENTS 1 column (02) Corresponding CT Ratio

(in CT and VT RATIOS column(0A) of menu)

[IA Magnitude] [IB Magnitude] [IC Magnitude] [IN Magnitude]

[Phase CT Primary]__ [Phase CT Secondary]

Table 5: CT ratio settings


5. SETTING CHECKS

The setting checks ensure that all of the application-specific relay settings (i.e. both the relays function and programmable scheme logic settings), for the particular installation, have been correctly applied to the relay.

Note: The trip circuit should remain isolated during these checks to prevent accidental operation of the associated circuit breaker.

5.1. Apply application-specific settings

There are two methods of applying the settings to the relay:

− Transferring them from a pre-prepared setting file to the relay using a portable PC running the appropriate software via the relays front EIA(RS)232 port, located under the bottom access cover. This method is preferred for transferring function settings as it is much faster and there is less margin for error. If programmable scheme logic other than the default settings with which the relay is supplied are to be used then this is the only way of changing the settings.

If a setting file has been created for the particular application and provided on a diskette, this will further reduce the commissioning time and should always be the case where application-specific programmable scheme logic is to be applied to the relay.

− Enter them manually via the relays operator interface. This method is not suitable for changing the programmable scheme logic.

Note: It is essential that where the installation needs application-specific Programmable Scheme Logic, that the appropriate .psl file is downloaded (sent) to the relay, for each and every setting group that will be used. If the user fails to download the required .psl file to any setting group that may be brought into service, then factory default PSL will still be resident. This may have severe operational and safety consequences.


5.2. How to measure the Burden Resistance (RB)

P3747ENb

V

A

A

B

C

N

CTA

CTB

CTC

Short-circuit of the secondarywinding of the current transformer

(HV site)

P992 or MMLGPU

IA

IB

IC

IN

Insertion of the test block to open current circuit

1. Short-circuit of the secondary winding of the 3 current transformers (see above).

2. Open the current circuit by inserting the test block

3. Connect the current test set in the test block (phase + neutral).

4. Inject a current (1A) and measure the voltage at the terminals of the resistor circuitry.

5. Calculate the burden resistance RB by using the following equation:

RB = Umeasured / Iinjected

Repeat the previous operation for each resistance :

RAN between boundary A and N

RBN between boundary B and N

RCN between boundary C and N

RAB between boundary A and B

Calculate the resistance RBA, RBB, RBC, and RBN, by using the following equation:

RBA = (RAB + RAN - RBN ) / 2

RBN = RAN - RBA

RBB = RAB - RBA

RBC = RCN - RBN


The highest value of the 3 phases (RBA, RBB, RBC) should be multiplicated by 1.25 (increase of 25% for a temperature at 75°) and set in the cell [CT/VT ratio, RB in ohm].

The highest value of the 3 phases (RBA, RBB, RBC) should be divided by the neutral resistance RBN and set in the cell [CT/VT ratio, RBPh / RBN].

1 RBph / RBN

P3900ENa

CTA

CTB

CTC

PU

IA

IB

IC

IN

2 RBPh / RBN = 3

P3901ENa

CTA

CTB

CTC

PU

IA

IB

IC

IN


5.3. Demonstrate Correct Relay Operation

Tests below have already demonstrated that the relay is within calibration, thus the purpose of these tests is as follows:

− To determine that the primary protection function of the relay, current differential, can trip according to the correct application settings.

− To verify correct setting of any backup phase overcurrent protection.

− To verify correct assignment of the inputs, relays and trip contacts, by monitoring the response to a selection of fault injections.

5.3.1. Current Differential Bias Characteristic

To avoid spurious operation of any Overcurrent, earth fault or breaker fail elements, these should be disabled for the duration of the differential element tests. This is done in the relays CONFIGURATION column. Ensure that cells, [Overcurrent Prot], [Earth Fault Prot] and [CB Fail & I<] are all set to Disabled. Make a note of which elements need to be re-enabled after testing.

5.3.1.1 Connect the test circuit

The following tests require a injection test set, able to feed the relays with two currents variable in phase and magnitude, connected as shown in Figure 5.

This method will be preferred for a centralised solution


A

A

P741Central

Unit

P742/3Peripheral

Unit 1

P742/3Peripheral

Unit 2

FO

FO

TestBox

I1

I2

P3748ENa

Figure 5: Connection for Bias Characteristic Testing Centralised Solution

As shown in figure 5bis, this method will be used for a distributed solution when only one peripheral unit is available.


AP741Central

Unit

P742/3Peripheral

Unit 1

FO TestBox

I2

P3749ENa

Figure 5bis: Connection for Bias Characteristic Testing Distributed Solution

A current I1 is injected into the A phase of the PU1 which is used as the bias current and another current I2 is injected into the A phase of the PU2 which is used as differential current.

Currents I1 and I2 are in anti-phase, i.e.: 180° out of phase and I2>I1

Idiff: I1+I2 = I2 - I1

Ibias: ∑I= I1+I2 = I1 + I2

k : Percentage bias, Characteristic limit: Idiff = IS + k Ibias

I2 I1 = IS + k (I1 + I2) with I2 = I1 + ∆I

∆I = IS + k (2 I1 + ∆I)

∆I (1 k) = IS + 2 k I1

∆I = (IS + 2 k I1 ) / (1 k)


1) If only one current is available, we will have I1 = 0

∆I = IS / (1 k)

i bias

I = I =diff 2

I

Is

i (t)diff

Slope k

P3750ENa

45°

A

I = I = I =bias diff 2

I

I = I =bias 2

I0

In this case, we increase I2 from 0 to A point until the differential element operates.

Note: ID>2 will be set below the A point during the test. ID>1 alarm timer will be set to 100s during the test.

To calculate and check the slope k, k = (I2-IS)/I2

2) If 2 currents are available:

i bias

I = I - Idiff 21

Is

i (t)diff

Slope k

P3759ENa

45°

A

I = I + Ibias 21

0

C

B

Ibias is fixed to a value greater than the A point. So Ibias = I1 + I2 = fixed value (Point B)

we set I1 = - I2 = Ibias / 2 so Idiff = 0

In this case, we increase I1 and decrease I2 from the same primary value ∆I (note that all PUs transmit the primary currents to central unit). When we reach the point C, the differential element should have to operate.

To calculate the slope k, k = [(I1 I2) IS] / (I1 + I2)

The differential current will increase twice the value ∆I.

Note: ID>2 will be set below the A point during the test. ID>1 alarm timer will be set to 100s during the test.


5.3.1.2 Slope

If a LED has been assigned in central or/and peripheral units to display the trip information, these may be used to indicate correct operation. If not, monitor option will need to be used see the next paragraph.

On P741 go Central Unit GROUP1-->BUSBAR PROTECT and set ID>1 Alarm timer to 100s

On P742/3 go to COMMISSION TESTS column in the menu, scroll down and change cells [Monitor Bit 1] to [BUSBAR_TRIPPING]. Doing so, cell [Test Port Status] will appropriately set or reset the bits that now represent BUSBAR_TRIPPING (with the rightmost bit representing Busbar Trip. From now on you should monitor the indication of [Test Port Status]. Make a note of which elements need to be re-enabled or re-set after testing.

Test of I D>2:

ID>1 Alarm Timer should be set to 100s during testing.

Inject a I2 current smaller than ID>2 and slowly increase I2 until tripping.

Test of the operating time of the differential element:

Inject a I2 current greater than twice ID>2 threshold and measure the operating time of the differential element.

Test of I D>1:

ID>1 Alarm Timer should be set to 100ms.

Inject a I2 current smaller than ID>1 and slowly increase I2 until circuit fault appears (LED Alarm of LED circuitry fault).

Test of I D>1 Alarm Timer:

ID>1 Alarm Timer should be set to 5s.

Inject a I2 current greater than twice the ID>1 threshold and check that the Circuitry Fault Alarm is coming in 5s.

Note: Same tests can be applied for the Differential Sensitive Earth Fault Protection. Note: the differential SEF is 20ms delayed and controlled by a settable threshold Ibias ph> to unblock/block the sensitive element depending of the restrain phase currents.


5.3.2. Phase Overcurrent Protection (P742 and P743)

If the overcurrent protection function is being used, both Ι>1 and I>2 elements should be tested.

To avoid spurious operation of any current differential, earth fault, breaker fail or CT supervision elements, these should be disabled for the duration of the overcurrent tests. This is done in the relays CONFIGURATION column. Make a note of which elements need to be re-enabled after testing.

5.3.2.1 Connect the test circuit

Determine which output relay has been selected to operate when an Ι>1 trip and an I>2 occur by viewing the relays programmable scheme logic.

The programmable scheme logic can only be changed using the appropriate software. If this software has not been available then the default output relay allocations will still be applicable.

If the trip outputs are phase-segregated (i.e. a different output relay allocated for each phase), the relay assigned for tripping on A phase faults should be used.

If stage 1 is not mapped directly to an output relay in the programmable scheme logic, output relay 1,2 or 3 could be used for the test as it operates for trip condition (phase A, B and C).

The associated terminal numbers can be found from the external connection diagram (Chapter P740/EN CO)SEQARABIC.

Connect the output relay so that its operation will trip the test set and stop the timer.

Connect the current output of the test set to the A phase current transformer input of the relay.

Ensure that the timer will start when the current is applied to the relay.


5.3.2.1.1 Perform the test

Ensure that the timer is reset.

Apply a current of twice the setting in cell [GROUP 1 OVERCURRENT, Ι>1 Current Set] to the relay and note the time displayed when the timer stops.

Check that the red trip LED has illuminated.

5.3.2.1.2 Check the operating time

Check that the operating time recorded by the timer is within the range shown in SEQARABIC

Note: Except for the definite time characteristic, the operating times given in SEQARABIC are for a time multiplier or time dial setting of 1. Therefore, to obtain the operating time at other time multiplier or time dial settings, the time given in SEQARABIC must be multiplied by the setting of cell [GROUP 1 OVERCURRENT, Ι>1 TMS] for IEC and UK characteristics or cell [GROUP 1 OVERCURRENT, Time Dial] for IEEE and US characteristics.

In addition, for definite time and inverse characteristics there is an additional delay of up to 0.02 second and 0.08 second respectively that may need to be added to the relays acceptable range of operating times.

For all characteristics, allowance must be made for the accuracy of the test equipment being used.

Characteristic Operating time at twice current setting and time multiplier/time dial setting of 1.0

Nominal (seconds) Range (seconds)

DT [: Ι>1 Time Delay] setting Setting ±2%

IEC S Inverse 10.03 9.53 10.53

IEC V Inverse 13.50 12.83 14.18

IEC E Inverse 26.67 24.67 28.67

UK LT Inverse 120.00 114.00 126.00

IEEE M Inverse 0.64 0.61 0.67

IEEE V Inverse 1.42 1.35 1.50

IEEE E Inverse 1.46 1.39 1.54

US Inverse 0.46 0.44 0.49

US ST Inverse 0.26 0.25 0.28 Table 6: Characteristic operating times for Ι>1

Re-perform the tests for the function I>2

Upon completion of the tests any current differential, overcurrent, earth fault, breaker fail or supervision elements which were disabled for testing purposes must have their original settings restored in the CONFIGURATION column.


5.3.3. Breaker Failure Protection

5.3.3.1 Separate external 50BF protection to the busbar protection

P3751ENa

PU4 PU5

PU3

PU1 PU2

CB Fail

External Fault

For example as shown in the above figure, we simulate a CB fail in feeder 1 (PU1). Therefore, we energise the opto input External CB Fail of the PU1 and we check that the central unit issue a tripping order to PU2 and PU3.

Note: If the I>BB or IN>BB are enabled in menu Busbar Trip Confirm in Peripheral Unit, the CB fail trip command issued by the Central Unit will be confirmed by a measured phase currents or neutral currents greater than I>BB (Phase) or IN>BB (Earth).

For example: PU2 and PU3 will operate only if the phase currents > I>BB else the local trip will be not confirmed.

The trip of the backup phase overcurrent or earth fault overcurrent protection initiates, as described above, the timers tBF3 and tBF4.

5.3.3.2 External initiation of BF Protection

Prote

ctiv

eRela

ys

P742/3Peripheral

Unit

Trip A, B, C

P3752ENa

Trip Command


To test the retrip:

As shown in the above figure, we initiate the opto inputs External Trip A,B,C and apply a current twice the I< threshold.

Check that the PU issue a retrip order after the settable time tBF3.

Note: If I> enabled is activated, then the retrip command will be controlled locally by a measured phase currents greater than I>.

To test the backtrip:

Do the same test as for retrip however apply a faulty current for more than tBF4 and check that the backtrip signal is sent to the CU.

Check that PU2 and PU3 connected to the bus-section 1 are tripped by the CU.

Note: If the I>BB or IN>BB are enabled in menu Busbar Trip Confirm in Peripheral Unit, the CB fail trip command issued by the Central Unit will be confirmed by a measured phase currents or neutral currents greater than I>BB (Phase) or IN>BB (Earth).

For example: PU2 and PU3 will operate only if the phase currents > I>BB else the local trip will be not confirmed.

CB unavailable:

P3753ENa

PU4 PU5

PU3

PU1 PU2

Zone 1 Zone 2

Apply an internal fault in zone 2 and energise the opto input of PU3 CB unavailable and check that both bus-section 1 tripped simultaneously.

Note: If the input CB unavailable is energised, the CB will be not tripped and is normally used only for bus-coupler.


5.3.3.3 Internal initiation Breaker Failure Protection

This Breaker failure Protection can be initiated only by a trip command issue by the Central Unit.

P3753ENa

PU4 PU5

PU3

PU1 PU2

Zone 1 Zone 2

Simulate a busbar fault on the bus-section 2.

Continue to apply fault current in the bus-coupler until the timer tBF1 elapsed.

Check that the retrip signal is given by PU3 and backtrip signal is sent after tBF2.

Check that the CU issued a trip command to both bus-sections (PU1, PU2 PU4 and PU5 should have operate).

5.4. Check Application Settings

The settings applied should be carefully checked against the required application-specific settings to ensure that they are correct, and have not been mistakenly altered during the injection test.

There are two methods of checking the settings:

− Extract the settings from the relay using a portable PC running the appropriate software via the front EIA(RS)232 port, located under the bottom access cover. Compare the settings transferred from the relay with the original written application-specific setting record. (For cases where the customer has only provided a printed copy of the required settings but a portable PC is available).

− Step through the settings using the relays operator interface and compare them with the original application-specific setting record.

Unless previously agreed to the contrary, the application-specific programmable scheme logic will not be checked as part of the commissioning tests.

Due to the versatility and possible complexity of the programmable scheme logic, it is beyond the scope of these commissioning instructions to detail suitable test procedures. Therefore, when programmable scheme logic tests must be performed, written tests which will satisfactorily demonstrate the correct operation of the application-specific scheme logic should be devised by the Engineer who created it. These should be provided to the Commissioning Engineer together with the diskette containing the programmable scheme logic setting file.


6. END TO END TESTS

Verify communications between Peripheral units (P742 or P743) and Central Unit (P741) Advisable for distributed scheme.

The following communication checks confirm that the optical power at the transmit and receive ports of the Peripheral Units and the Central Unit are within the recommended operating limits.

Measure and record the optical signal strength received by the Peripheral Unit (P742 or P743) by disconnecting the optical fibre from the Channel 1 receive port and connecting it to an optical power meter. The mean level should be in the range − 16.8 dBm to −25.4dBm. If the mean level is outside of this range check the size and type of fibre being used.

When connecting or disconnecting optical fibres care should be taken not to look directly into the transmit port or end of the optical fibre.

Measure and record the optical power of the Channel 1 transmit port using the optical power meter and length of optical fibre. The mean value should be in the range 16.8dBm to 22.8dBm.

Ensure that all transmit (Tx) and receive (Rx) optical fibres between Peripheral Unit and Central Unit are reconnected, ensuring correct placement.

Reset any alarm indications and check that no further communications failure alarms

are raised.

7. ON-LOAD CHECKS

The objectives of the on-load checks are to:

- confirm the external wiring to the current inputs is correct.

- ensure the on-load differential current is well below the relay setting.

However, these checks can only be carried out if there are no restrictions preventing the energisation of the plant being protected and the other P740 relays in the group have been commissioned.

Remove all test leads, temporary shorting leads, etc. and replace any external wiring that has been removed to allow testing.

If it has been necessary to disconnect any of the external wiring from the relay in order to perform any of the foregoing tests, it should be ensured that all connections are replaced in accordance with the relevant external connection or scheme diagram.

Confirm current transformer wiring:

Measure the current transformer secondary values for each input using a multimeter connected in series with the corresponding relay current input.

Check that the current transformer polarities are correct.

Ensure the current flowing in the neutral circuit of the current transformers is negligible.

Compare the values of the secondary phase currents with the relays measured values, which can be found in the MEASUREMENTS 1 menu column.


Note: Under normal load conditions the earth fault function will measure little, if any, current. It is therefore necessary to simulate a phase to neutral fault. This can be achieved by temporarily disconnecting one or two of the line current transformer connections to the relay and shorting the terminals of these current transformer secondary windings.

If cell [MEASURET SETUP, Local Values] is set to Secondary, the currents displayed on the LCD or a portable PC connected to the front EIA(RS)232 communication port of the relay should be equal to the applied secondary current. The values should be within 5% of the applied secondary currents. However, an additional allowance must be made for the accuracy of the test equipment being used.

If cell [MEASURET SETUP, Local Values] is set to Primary, the currents displayed on the relay should be equal to the applied secondary current multiplied by the corresponding current transformer ratio set in CT & VT RATIOS menu column (see SEQARABIC). Again the values should be within 5% of the expected value, plus an additional allowance for the accuracy of the test equipment being used.

Note: If a single dedicated current transformer is used for the earth fault function, it is not possible to check the relays measured values.

8. FINAL CHECKS

The tests are now complete.

Remove all test or temporary shorting leads, etc. If it has been necessary to disconnect any of the external wiring from the relay in order to perform the wiring verification tests, it should be ensured that all connections are replaced in accordance with the relevant external connection or scheme diagram.

Ensure that the relay has been restored to service by checking that cell [COMMISSION TESTS, Test Mode] is set to Disabled.

If the menu language has been changed to allow accurate testing it should be restored to the customers preferred language.

If a P991/MMLG test block is installed, remove the P992/MMLB test plug and replace the cover so that the protection is put into service.

Ensure that all event records, fault records, disturbance records, alarms and LEDs have been reset before leaving the relay.

If applicable, replace the secondary front cover on the relay.


9. MAINTENANCE

9.1. Maintenance period

It is recommended that products supplied by AREVA T&D Information receive periodic monitoring after installation. As with all products some deterioration with time is inevitable. In view of the critical nature of protective relays and their infrequent operation, it is desirable to confirm that they are operating correctly at regular intervals.

AREVA protective relays are designed for a life in excess of 20 years.

MiCOM P740 current differential relays are self-supervising and so require less maintenance than earlier designs of relay. Most problems will result in an alarm so that remedial action can be taken. However, some periodic tests should be done to ensure that the relay is functioning correctly and the external wiring is intact.

If a Preventative Maintenance Policy exists within the customers organisation then the recommended product checks should be included in the regular programme. Maintenance periods will depend on many factors, such as:

− operating environment

− accessibility of the site

− amount of available manpower

− importance of the installation in the power system

− consequences of failure

9.2. Maintenance checks

It is recommended that maintenance checks are performed locally (i.e. at the substation itself).

Before carrying out any work on the equipment, the user should be familiar with the contents of the Safety and Technical Data sections and the ratings on the equipments rating label.

9.2.1. Alarms

The alarm status LED should first be checked to identify if any alarm conditions exist. If so, press the read key ["] repeatedly to step through the alarms.

Clear the alarms to extinguish the LED.

9.2.2. Opto-isolators

The opto-isolated inputs can be checked to ensure that the relay responds to their energisation by repeating the commissioning test.

9.2.3. Output relays

The output relays can be checked to ensure that they operate by repeating the commissioning test.


9.2.4. Measurement accuracy

If the power system is energised, the values measured by the relay can be compared with known system values to check that they are in the approximate range that is expected. If they are then the analogue/digital conversion and calculations are being performed correctly by the relay.

Alternatively, the values measured by the relay can be checked against known values injected into the relay via the test block, if fitted, or injected directly into the relay terminals. These tests will prove the calibration accuracy is being maintained.

9.3. Method of repair

P741, P742, P743 relays

If the relay should develop a fault whilst in service, depending on the nature of the fault, the watchdog contacts will change state and an alarm condition will be flagged. Due to the extensive use of surface-mount components faulty PCBs should be replaced as it is not possible to perform repairs on damaged circuits. Thus either the complete relay or just the faulty PCB, identified by the in-built diagnostic software, can be replaced. Advice about identifying the faulty PCB can be found in the Problem Analysis.

The preferred method is to replace the complete relay as it ensures that the internal circuitry is protected against electrostatic discharge and physical damage at all times and overcomes the possibility of incompatibility between replacement PCBs. However, it may be difficult to remove an installed relay due to limited access in the back of the cubicle and rigidity of the scheme wiring.

Replacing PCBs can reduce transport costs but requires clean, dry conditions on site and higher skills from the person performing the repair. However, if the repair is not performed by an approved service centre, the warranty will be invalidated.

Before carrying out any work on the equipment, the user should be familiar with the contents of the Safety and Technical Data sections and the ratings on the equipments rating label. This should ensure that no damage is caused by incorrect handling of the electronic components.

9.3.1. Replacing the complete relay

The case and rear terminal blocks have been designed to facilitate removal of the complete relay should replacement or repair become necessary without having to disconnect the scheme wiring.


Before working at the rear of the relay, isolate all voltage and current supplies to the relay.

Note: The MiCOM range of relays have integral current transformer shorting switches which will close when the heavy duty terminal block is removed.

Disconnect the relay earth, IRIG-B (Central unit only) and fibre optic connections, as appropriate, from the rear of the relay.

Medium duty terminal blockHeavy duty terminal block

P0149ENa

Figure 6 : Location of securing screws for terminal block

Note: The use of a magnetic bladed screwdriver is recommended to minimise the risk of the screws being left in the terminal block or lost

Without exerting excessive force or damaging the scheme wiring, pull the terminal blocks away from their internal connectors.

Remove the screws used to fasten the relay to the panel, rack, etc. These are the screws with the larger diameter heads that are accessible when the access covers are fitted and open.

If the top and bottom access covers have been removed, do not remove the screws with the smaller diameter heads which are accessible. These screws secure the front panel to the relay.

Withdraw the relay carefully from the panel, rack, etc. because it will be heavy due to the internal transformers.

To reinstall the repaired or replacement relay, follow the above instructions in reverse, ensuring that each terminal block is relocated in the correct position and the case earth, IRIG-B (Central Unit only) and fibre optic connections are replaced. To facilitate easy identification of each terminal block, they are labelled alphabetically with A on the left hand side when viewed from the rear.

Once reinstallation is complete the relay should be recommissioned using the instructions in sections 1 to 8 inclusive of this chapter.


9.3.2. Replacing a PCB

If the relay fails to operate correctly refer to the Problem Analysis chapter, to help determine which PCB has become faulty.

To replace any of the relays PCBs it is necessary to first remove the front panel.

Before removing the front panel to replace a PCB the auxiliary supply must be removed. It is also strongly recommended that the voltage and current transformer connections and trip circuit are isolated.

Open the top and bottom access covers. With size 60TE/80TE cases the access covers have two hinge-assistance T-pieces which clear the front panel moulding when the access covers are opened by more than 90°, thus allowing their removal.

If fitted, remove the transparent secondary front cover. A description of how to do this is given in the Introduction.

By applying outward pressure to the middle of the access covers, they can be bowed sufficiently so as to disengage the hinge lug allowing the access cover to be removed. The screws that fasten the front panel to the case are now accessible.

The size 40TE case has four crosshead screws fastening the front panel to the case, one in each corner, in recessed holes. The size 60TE/80TE case has an additional two screws, one midway along each of the top and bottom edges of the front plate. Undo and remove the screws.

Do not remove the screws with the larger diameter heads which are accessible when the access covers are fitted and open. These screws hold the relay in its mounting (panel or cubicle).

When the screws have been removed, the complete front panel can be pulled forward and separated from the metal case.

Caution should be observed at this stage because the front panel is connected to the rest of the relay circuitry by a 64-way ribbon cable.

Additionally, from here on, the internal circuitry of the relay is exposed and not protected against electrostatic discharges, dust ingress, etc. Therefore ESD precautions and clean working conditions should be maintained at all times.

The ribbon cable is fastened to the front panel using an IDC connector; a socket on the cable itself and a plug with locking latches on the front panel. Gently push the two locking latches outwards which will eject the connector socket slightly. Remove the socket from the plug to disconnect the front panel.

The PCBs within the relay are now accessible. Figures 8, 9 and 10 show the PCB locations for the Central Unit (P741) in a size 80 TE case, and for Peripheral Units either in a size 40 TE case (P742) or in a size 60 TE case (P743).


Note: The numbers above the case outline identify the guide slot reference for each printed circuit board. Each printed circuit board has a label stating the corresponding guide slot number to ensure correct re-location after removal. To serve as a reminder of the slot numbering there is a label on the rear of the front panel metallic screen.

76

1 ON 3 4

SLO

T1

SLO

T2

1

SLO

T3

SLO

T4

2

SLO

T5

ENSURE SWITCH POSITIONS ON REF5 ARE POSITIONED AS SHOWN

ON

1

1

ON 1

ON 1

ON 1

ON 1

ON1

ON 1 ON

SLO

T6

SLO

T7

5

5

SLO

T8

SLO

T9

5 5

SLO

T1

0

SLO

T1

1

5 5

SLO

T1

2

SLO

T1

3

5 5

SLO

T1

4

01

1

P3754ENa

REF DESCRIPTION MATERIAL

1 Assy Power Supply ZN0021 *

2 Assy Power Supply 2070583 *

3 Assy Opto Input ZN0017 002

4 Assy Relay Output ZN0019 001

5 Assy Comms 2070273 001

6 Assy IRIG-B ZN0007 *

7 Assy Coprocessor 2070273 002

Figure 7: P741 PCB/module locations (viewed from front)


SLO

T4

ON

6

1

SLO

T1

SLO

T2

SLO

T3

SLO

T5

SLO

T6

0SER No.

1 1

1 3

6

2 29 23 24or

P3755ENa






23 Assy Standard Input Module GN0010 033

24 Input Module (Univ. Inputs only) GN0010 040

29 Assembly Sreen Plate GN0058 001



1 ON

FIT JUMPERS (REF 64) TO PL2 ON

PCB'S REF 2 AND 3 IN SLOT POSITIONS SHOWN.

SLO

T1

SLO

T3

SLO

T2

SLO

T4

SLO

T6

SLO

T5

SLO

T8

SLO

T7

SLO

T9

SLO

T10

01

1 1 1 1

SER No.

1 2 29

29

6

2 2 3 323 24or

P3756ENa






23 Assy Standard Input Module GN0010 033

24 Input Module (Univ. Inputs only) GN0010 040

29 Assembly Screen Plate GN0058 001


The 64-way ribbon cable to the front panel also provides the electrical connections between PCBs with the connections being via IDC connectors.

The slots inside the case to hold the PCBs securely in place each correspond to a rear terminal block. Looking from the front of the relay these terminal blocks are labelled from right to left.

Note: To ensure compatibility, always replace a faulty PCB with one of an identical part number.


9.3.2.1 Replacement of the main processor board

The main processor board is located in the front panel, not within the case as with all the other PCBs. Place the front panel with the user interface face-down and remove the six screws from the metallic screen, as shown in Figure 10. Remove the metal plate.

There are two further screws, one each side of the rear of the battery compartment recess, that hold the main processor PCB in position. Remove these screws.

The user interface keypad is connected to the main processor board via a flex-strip ribbon cable. Carefully disconnect the ribbon cable at the PCB-mounted connector as it could easily be damaged by excessive twisting.

The front panel can then be re-assembled with a replacement PCB using the reverse procedure. Ensure that the ribbon cable is reconnected to the main processor board and all eight screws are re-fitted.


P3007ENa

Figure 10:Front panel assembly

Refit the front panel using the reverse procedure to that given before. After refitting and closing the access covers on size 60TE/80TE cases, press at the location of the hinge-assistance T-pieces so that they click back into the front panel moulding.

After replacement of the main processor board, all the settings required for the application will need to be re-entered. Therefore, it is useful if an electronic copy of the application-specific settings is available on disk. Although this is not essential, it can reduce the time taken to re-enter the settings and hence the time the protection is out of service.

Once the relay has been reassembled after repair, it should be recommissioned in accordance with the instructions in sections 1 to 8 inclusive of this chapter.


9.3.2.2 Replacement of the IRIG-B board (Central Unit only)

Depending on the model number of the central unit (P741), the IRIG-B board may have connections for IRIG-B signals.

To replace a faulty board, disconnect all IRIG-B connections at the rear of the relay.

The board is secured in the case by two screws accessible from the rear of the relay, one at the top and another at the bottom, as shown in Figure 11. Remove these screws carefully as they are not captive in the rear panel of the relay.

Gently pull the IRIG-B board forward and out of the case.

To help identify that the correct board has been removed, Figure 12 illustrates the layout of the IRIG-B board with IRIG-B (ZN0007 001).

RX

RX

TX

15

13

17

14

16

18

6

8

10

12

9

11

7

CH2

CH1

IRIG-B

RX

TX

TX4

23

5

1

L M N

P3757ENaINCLUDEPICTUREMERGEFORMAT

Figure 11: Location of securing screws for IRIG-B board

P3009FRa

SERIAL No.

ZN0007 C

Figure 12: Typical IRIG-B board


Before fitting the replacement PCB check that the number on the round label adjacent to the front edge of the PCB matches the slot number into which it will be fitted. If the slot number is missing or incorrect write the correct slot number on the label.

The replacement PCB should be carefully slotted into the appropriate slot, ensuring that it is pushed fully back on to the rear terminal blocks and the securing screws are re-fitted.

Reconnect IRIG-B connection at the rear of the relay.

Refit the front panel using the reverse procedure to that given in section 9.3.1.2. After refitting and closing the access covers on size 60TE/80TE cases, press at the location of the hinge-assistance T-pieces so that they click back into the front panel moulding.



9.3.2.3 Replacement of the input module

The input module comprises of two boards fastened together, the transformer board and the input board.

The module is secured in the case by two screws on its right-hand side, accessible from the front of the relay, as shown in Figure 13. Remove these screws carefully as they are not captive in the front plate of the module.

Handle

Input module

Figure 13: Location of securing screws for input module

On the right-hand side of the analogue input module there is a small metal tab which brings out a handle. Grasping this handle firmly, pull the module forward, away from the rear terminal blocks. A reasonable amount of force will be required to achieve this due to the friction between the contacts of two terminal blocks, one medium duty and one heavy duty.

Note: Care should be taken when withdrawing the input module as it will suddenly come loose once the friction of the terminal blocks has been overcome. This is particularly important with unmounted relays as the metal case will need to be held firmly whilst the module is withdrawn.

Remove the module from the case, taking care as it is heavy because it contains all the relays input voltage and current transformers.

Before fitting the replacement module check that the number on the round label adjacent to the front edge of the PCB matches the slot number into which it will be fitted. If the slot number is missing or incorrect write the correct slot number on the label.

The replacement module can be slotted in using the reverse procedure, ensuring that it is pushed fully back on to the rear terminal blocks. To help confirm that the module has been inserted fully there is a V-shaped cut-out in the bottom plate of the case that should be fully visible. Re-fit the securing screws.


Note: The transformer and input boards within the module are calibrated together with the calibration data being stored on the input board. Therefore it is recommended that the complete module is replaced to avoid on-site recalibration having to be performed.

Refit the front panel using the reverse procedure to that given in section. After refitting and closing the access covers on size 60TE/80TE cases, press at the location of the hinge-assistance T-pieces so that they click back into the front panel moulding.


9.3.2.4 Replacement of the power supply board

The power supply board is fastened to a relay board to form the power supply module and is located on the extreme left-hand side of all MiCOM differential busbar relays.

Pull the power supply module forward, away from the rear terminal blocks and out of the case. A reasonable amount of force will be required to achieve this due to the friction between the contacts of the two medium duty terminal blocks.

The two boards are held together with push-fit nylon pillars and can be separated by pulling them apart. Care should be taken when separating the boards to avoid damaging the inter-board connectors located near the lower edge of the PCBs towards the front of the power supply module.

The power supply board is the one with two large electrolytic capacitors on it that protrude through the other board that forms the power supply module. To help identify that the correct board has been removed, Figure 14 illustrates the layout of the power supply board for all voltage ratings.

Before re-assembling the module with a replacement PCB check that the number on the round label adjacent to the front edge of the PCB matches the slot number into which it will be fitted. If the slot number is missing or incorrect write the correct slot number on the label.

Re-assemble the module with a replacement PCB ensuring the inter-board connectors are firmly pushed together and the four push-fit nylon pillars are securely located in their respective holes in each PCB.


ZN0001 DSK1

C8C18C29C28

C33

C32

L1

C25

C43

C14

C20 C19

C24

C7

C13

C12

C15

C2

C41

C42

C47

C5

C6

C4

C9

C35

C11

C38

C37

C36

C44

C40

C39

C31

C30

C23

C22

D6

C21

C1

C10

C46

C45

C16

C34

C17

D20

D24

D19

D26

D25

D22

R59

R58

R40

R15

R63

R62

R69

R68

R2

R45

R12

R11

R25

R9

R26

R13

R41

R20

R4

R7

R24

R52

R39

R8

R28 R27

R47

R31

R22

R14

R48

R81

R80

R79 R78

R42

R19

R1

R33 R32

R3

R70

R55 R54

R88

R36

R37

R38

R77

R76

R46

R10

R6

R49

R50R51

R5

R44

R43

R64

R65

R66

R18

R23

R67

R30

R56

R57

R89

R90

LK2 LK1

T2

T1

RD1

RD2

PL1

L2

IC2

D18

IC1

D17

D16

D15

D23

D1

D13

PC5

PC4

PC3

IC6

IC5

PC1

PC2

RL1

D9

D7D12D11

D21

E2

E1

D10

D3

D4

D2

D5

D8

TR5

TR4

TR8TR7

TR6

TR10

SERIAL No.

REF 1

TR1

D14

TR9

TR3

C3

C26

D27

D28IC3

IC4

R21

R29

R53

RD3

RD4

R16

R17

Figure 14: Typical power supply board for P742 & P743

2070584 B

P3761ENa

Figure 15bis: Additive power supply board for P741

Slot the power supply module back into the relay case, ensuring that it is pushed fully back on to the rear terminal blocks.

Refit the front panel using the reverse procedure to that given in section. After refitting and closing the access covers on size 60TE/80TE cases, press at the location of the hinge-assistance T-pieces so that they click back into the front panel moulding.



9.3.2.5 Replacement of the relay board in the power supply module

Remove and replace the relay board in the power supply module as described in above.

The relay board is the one with holes cut in it to allow the transformer and two large electrolytic capacitors of the power supply board to protrude through. To help identify that the correct board has been removed, Figure 15 illustrates the layout of the relay board.

Before re-assembling the module with a replacement relay board check that the number on the round label adjacent to the front edge of the PCB matches the slot number into which it will be fitted. If the slot number is missing or incorrect write the correct slot number on the label.

Ensure the setting of the link (located above IDC connector) on the replacement relay board is the same as the one being replaced before replacing the module in the relay case.


E2

SERIAL No.

ZN0019

F

P3762ENa

Figure 16: Typical relay board

Note: Only for P743, relay number 6 is not used.


9.3.2.6 Replacement of the opto and separate relay boards (P741, P742, & P743)

To remove either, gently pull the faulty PCB forward and out of the case.

If the relay board is being replaced, ensure the setting of the link (located above IDC connector) on the replacement relay board is the same as the one being replaced. To help identify that the correct board has been removed, Figure 16 and Figure 17 illustrate the layout of the relay and opto boards respectively.

Before fitting the replacement PCB check that the number on the round label adjacent to the front edge of the PCB matches the slot number into which it will be fitted. If the slot number is missing or incorrect write the correct slot number on the label.

The replacement PCB should be carefully slid into the appropriate slot, ensuring that it is pushed fully back on to the rear terminal blocks.

Refit the front panel using the reverse procedure to that given in section After refitting and closing the access covers on size 60TE/80TE cases, press at the location of the hinge-assistance T-pieces so that they click back into the front panel moulding.


E1

C1

SERIAL No.

1

ZN0017

E

P3760ENa Figure 17: Typical opto board


9.3.2.7 Replacement of the Coprocessor board

Before replacing a faulty Coprocessor board, disconnect fibre optic cable connections at the rear of the relay.


Using the small metal tab on the left hand side of the input module rotate handle used for extraction until it is in a horizontal orientation. This is necessary so that the two PCB connectors on the underside of the Coprocessor board PCB do not catch the handle as the PCB is extracted.

Gently pull the faulty Coprocessor board PCB forward and out of the case.

P3763ENa

Figure 18: Typical Coprocessor board

To help identify that the correct board has been replace, Figure 18 illustrates the layout of the Coprocessor board with dual fibre optic communications channels fitted. The Coprocessor board boards with a single communications channel (used in relays for two ended feeders where dual redundant communications channels are not required) use the same PCB layout but have less components fitted.

The replacement PCB should be carefully slid into the appropriate slot, ensuring that it is pushed fully back and the board securing screws are re-fitted.

Refit the fibre optic cable connections, ensuring that they are in the correct locations.




9.3.2.8 Replacement of the Comms board

Before replacing a faulty Comms board (Communication board between central and peripheral units), disconnect fibre optic cable connections at the rear of the relay.


Using the small metal tab on the left hand side of the input module rotate handle used for extraction until it is in a horizontal orientation. This is necessary so that the two PCB connectors on the underside of the Comms board PCB do not catch the handle as the PCB is extracted.

Gently pull the faulty Comms board PCB forward and out of the case.

P3764ENa

Figure 19: Typical Comms board

To help identify that the correct board has been removed, Figure 19 illustrates the layout of the Comms board with dual fibre optic communications channels fitted. The Comms board boards with a single communications channel (used in relays for two ended feeders where dual redundant communications channels are not required) use the same PCB layout but have less components fitted.

The replacement PCB should be carefully slid into the appropriate slot, ensuring that it is pushed fully back and the board securing screws are re-fitted.

Refit the fibre optic cable connections, ensuring that they are in the correct locations.




9.4. Recalibration

9.4.1. P740 relay

Recalibration is not required when a PCB is replaced unless it happens to be one of the boards in the input module, the replacement of either directly affects the calibration.

Although it is possible to carry out recalibration on site, this requires test equipment with suitable accuracy and a special calibration program to run on a PC. It is therefore recommended that the work is carried out by the manufacturer, or entrusted to an approved service centre.

9.5. Changing the relay battery

Each relay has a battery to maintain status data and the correct time when the auxiliary supply voltage fails. The data maintained includes event, fault and disturbance records and the thermal state at the time of failure.

This battery will periodically need changing, although an alarm will be given as part of the relays continuous self-monitoring in the event of a low battery condition.

If the battery-backed facilities are not required to be maintained during an interruption of the auxiliary supply, the steps below can be followed to remove the battery, but do not replace with a new battery.

Before carrying out any work on the equipment, the user should be familiar with the contents of the safety and technical data sections and the ratings on the equipment's rating label.

9.5.1. Instructions for replacing the battery.

Open the bottom access cover on the front of the relay.

Gently extract the battery from its socket. If necessary, use a small insulated screwdriver to prize the battery free.

Ensure that the metal terminals in the battery socket are free from corrosion, grease and dust.

The replacement battery should be removed from its packaging and placed into the battery holder, taking care to ensure that the polarity markings on the battery agree with those adjacent to the socket.

Note: Only use a type ½AA Lithium battery with a nominal voltage of 3.6V and safety approvals such as UL (Underwriters Laboratory), CSA (Canadian Standards Association) or VDE (Vereinigung Deutscher Elektrizitätswerke).

Ensure that the battery is securely held in its socket and that the battery terminals are making good contact with the metal terminals of the socket.

Close the bottom access cover.


9.5.2. Post modification tests

To ensure that the replacement battery will maintain the time and status data if the auxiliary supply fails, check cell [0806: DATE and TIME, Battery Status] reads Healthy.

Additionally, if further confirmation that the replacement battery is installed correctly is required, the commissioning test described in section 4.2.2, Date and Time, can be performed.

9.5.3. Battery disposal

The battery that has been removed should be disposed of in accordance with the disposal procedure for Lithium batteries in the country in which the relay is installed.

9.6. Cleaning

Before cleaning the equipment ensure that all ac and dc supplies, current transformer and voltage transformer connections are isolated to prevent any chance of an electric shock whilst cleaning.

The equipment may be cleaned using a lint-free cloth dampened with clean water. The use of detergents, solvents or abrasive cleaners is not recommended as they may damage the relays surface and leave a conductive residue.


10. COMMISSIONING TEST RECORD:

10.1. Peripheral Units: P742/P743

Date: Engineer:

Station: Circuit:

System Frequency:

Front Plate Information

Peripheral Unit Type P74_

Model number

Serial number

Rated current In

Auxiliary voltage Vx

Test Equipment Used

This section should be completed to allow future identification of protective devices that have been commissioned using equipment that is later found to be defective or incompatible but may not be detected during the commissioning procedure.

Overcurrent test set Model:

Serial No:

Optical power meter Model:

Serial No:

Insulation tester Model:

Serial No:

Setting software: Type:

Version:


*Delete as appropriate

Have all relevant safety instructions been followed?

Yes/No*

4 Product Checks

4.1 With the relay de-energised

4.1.1 Visual inspection

Relay damaged? Yes/No*

Rating information correct for installation? Yes/No*

Case earth installed? Yes/No*

4.1.2 Current transformer shorting contacts close? Yes/No/Not checked*

4.1.3 Insulation resistance >100MΩ at 500V dc Yes/No/Not tested*

4.1.4 External Wiring

Wiring checked against diagram? Yes/No*

Test block connections checked? Yes/No/na*

4.1.5 Watchdog Contacts (auxiliary supply off)

Terminals 11 and 12 Contact closed? Yes/No*

Contact resistance ____Ω/Not measured*

Terminals 13 and 14 Contact open? Yes/No*

4.1.6 Measured auxiliary supply ______V ac/dc*

4.2 With the relay energised

4.2.1 Watchdog Contacts (auxiliary supply on)

Terminals 11 and 12 Contact open? Yes/No*

Terminals 13 and 14 Contact closed? Yes/No*


4.2.2 Date and time

Clock set to local time? Yes/No*

Time maintained when auxiliary supply removed?

Yes/No*


4.2.3 Light emitting diodes

4.2.3.1 Alarm (yellow) LED working? Yes/No*

Out of service (yellow) LED working? Yes/No*

4.2.3.2 Trip (red) LED working? Yes/No*

4.2.3.3 All 8 programmable LEDs working? Yes/No*

4.2.4 Field supply voltage

Value measured between terminals 7 and 9 ______V dc

Value measured between terminals 8 and 10 ______V dc

4.2.5 Input opto-isolators

Opto input 2 working? Yes/No*







Opto input 9 working? Yes/No/na*








For P742 Opto input 17 working? Yes/No/na*







For P743 Opto input 24 working? Yes/No/na*


4.2.6 Output relays

Relay 1 Working? Yes/No*







Contact resistance (N/C) ____Ω/Not measured*

(N/O) ____Ω/Not measured*










For P742 Relay 8 Working? Yes/No/na*


Relay 9 Working? Yes/No/na*


Relay 10 Working? Yes/No/na*



Contac t resistance (N/C) ____Ω/Not measured*






























For P743 Relay 21 Working? Yes/No*




4.2.9 Current Inputs

Displayed Current Primary/Secondary*

Phase CT Ratio _______ /na*

Input CT Applied value Displayed value

ΙA _______A _______A

ΙB _______A _______A

ΙC _______A _______A

ΙN _______A _______A

5 Setting Checks

5.1 Application-specific function settings applied? Yes/No*

Application-specific programmable scheme logic settings applied?

Yes/No/na*

5.2.1.2 Current Differential lower slope pickup _________A

5.2.1.3 Current Differential upper slope pickup _________A

5.2.5 Protection function timing tested? Yes/No*

Applied current _________A

Expected operating time _________s

Measured operating time _________s

5.4 Application-specific function settings verified? Yes/No/na*

Application-specific programmable scheme logic tested?

Yes/No/na*

Signal strength received by P742/3

Channel 1 ______dBm/na*

Signal strength transmitted by 742/3

Channel 1 ______dBm/na*

Signal Strength within tolerance Yes/No/na*

Optical fibres reconnected?

Channel RX and TX Yes/No*

Alarms reset? Yes/No*


7 On-load Checks

Test wiring removed? Yes/No/na*

Disturbed customer wiring re-checked? Yes/No/na*

7.1 Confirm current transformer wiring

7.1.2 Current connections

CT wiring checked? Yes/No/na*

CT polarities correct? Yes/No*

Displayed current Primary/Secondary*

Phase CT ratio _______ /na*

Currents: Applied value Displayed value

ΙA _______A _______A

ΙB _______A _______A

ΙC _______A _______A

ΙN _______A/na* _______A/na*

7.3 Differential current checked? Yes/ No*

8 Final Checks

Test wiring removed? Yes/No/na*

Disturbed customer wiring re-checked? Yes/No/na*

Test mode disabled? Yes/No*

Circuit breaker operations counter reset? Yes/No/na*

Current counters reset? Yes/No/na*

Event records reset? Yes/No*

Fault records reset? Yes/No*

Disturbance records reset? Yes/No*

Alarms reset? Yes/No*

LEDs reset? Yes/No*

Secondary front cover replaced? Yes/No/na*


Commissioning Engineer Customer Witness

Date Date


11. SETTING RECORD

11.1. Central Unit: P741

Date: Engineer:

Station: Circuit:

System Frequency:


Central Unit type: P741

Model Number

Serial Number

Rated Current In

Auxiliary Voltage Vx


Setting Groups Used

Group 1 Yes/No*

Group 2 Yes/No*

Group 3 Yes/No*

Group 4 Yes/No*

800 SYSTEM DATA

0001 Language English/Francais/Deutsch/Espanol*

0004 Description

0005 Plant Reference

0006 Model Number

0008 Serial Number

0009 Frequency

000A Comms Level

000B Relay Address

0011 Software Ref.1

00D1 Password Control

00D2 Password Level 1



800 PU CONF & STATUS

0601 PU in service 0000 0000 0000 0000 0000 0000 0000 0000

32............................................................................................1

0602 PU Connected 0000 0000 0000 0000 0000 0000 0000 0000

32............................................................................................1

0603 PU Topo valid 0000 0000 0000 0000 0000 0000 0000 0000

32............................................................................................1

800 DATE AND TIME

0801 Date/Time

0806 Battery Status Dead/Healthy*

0807 Battery Alarm Disabled/Enabled*

800 CONFIGURATION

0902 Setting Group Select via Menu/Select via Optos*

0903 Active Settings Group 1/Group 2/Group 3/Group 4*

0907 Setting Group 1 Disabled/Enabled*



090A Setting Group 4 Disabled/Enabled*

0925 Input Labels Invisible/Visible*

0926 Output Labels Invisible/Visible*

0929 Recorder Control Invisible/Visible*

092A Disturb Recorder Invisible/Visible*

092B Measuret Setup Invisible/Visible*

092D Commission Tests Invisible/Visible*

092E Setting Values Primary/Secondary*


0C00 DISTURB RECORDER

0C01 Duration

0C02 Trigger Position

0C03 Trigger Mode Single/Extended*

0C04 Analog Channel 1






0C0A Analog Channel 7

0C0B Analog Channel 8

0C0C Digital Input 1

0C0E Digital Input 2

0C10 Digital Input 3





0C1A Digital Input 8


























0D00 MEASURET SETUP

0D01 Default Display 3Ph+N Current/ Date and Time/Description/Plant Reference/ Frequency/ Access Level*

0D02 Local Values Primary/Secondary*

0D03 Remote Values Primary/Secondary*

0D04 Ibp Base Cur Pri

0F00 COMMISSION TESTS

0F05 Monitor Bit 1

0F06 Monitor Bit 2

0F07 Monitor Bit 3

0F08 Monitor Bit 4

0F09 Monitor Bit 5

0F0A Monitor Bit 6

0F0B Monitor Bit 7

0F0C Monitor Bit 8

0F0D Test Mode Disabled/Test Mode/Blocked*

0F0E Test Pattern

800 OPTOS SETUP

1101 Global Level

1101 Opto Input 1

1102 Opto Input 2

1103 Opto Input 3

1104 Opto Input 4


1105 Opto Input 5

1106 Opto Input 6

1107 Opto Input 7

1108 Opto Input 8

1109 Opto Input 9

110A Opto Input 10

110B Opto Input 11

110C Opto Input 12

110D Opto Input 13

110E Opto Input 14

110F Opto Input 15

1111 Opto Input 16

1112 Opto Input 17

1113 Opto Input 18

1114 Opto Input 19

1115 Opto Input 20

1116 Opto Input 21

1117 Opto Input 22

1118 Opto Input 23

1119 Opto Input 24

GROUP 1 PROTECTION SETTINGS

For Group 2,3 or 4 the first address figure must be respectively: 5 and 6, 7and 8 or 9 and A

800 DIFF BUSBAR PROT

Group 1 Settings Group 1 Settings

Group 2 Settings

Group 3 Settings

Group 4 Settings

3002 Current Is

3003 Phase Slope k

3004 ID>2 Current

3005 ID>1 Current

3006 ID>1 Alarm Timer

3007 Diff. Earth Fault Enabled/ Disabled

3008 Ibias Ph> Cur.


3009 Earth Cur. IsN

300A Earth Slope kN

300B IDN>2 Current

300C IDN>1 Current

300D IDN>1 Alarm Tim

4A00 INPUT LABELS


Group 2 Settings

Group 3 Settings

Group 4 Settings

4A01 Opto Input 1

4A02 Opto Input 2

4A03 Opto Input 3

4A04 Opto Input 4

4A05 Opto Input 5

4A06 Opto Input 6

4A07 Opto Input 7

4A08 Opto Input 8

4A09 Opto Input 9

4A0A Opto Input 10

4A0B Opto Input 11

4A0C Opto Input 12

4A0D Opto Input 13

4A0E Opto Input 14

4A0F Opto Input 15

4A10 Opto Input 16

4A11 Opto Input 17

4A12 Opto Input 18

4A13 Opto Input 19

4A14 Opto Input 20

4A15 Opto Input 21

4A16 Opto Input 22

4A17 Opto Input 23

4A18 Opto Input 24


4B00 OUTPUT LABELS


Group 2 Settings

Group 3 Settings

Group 4 Settings

4B01 Relay 1

4B02 Relay 2

4B03 Relay 3

4B04 Relay 4

4B05 Relay 5

4B06 Relay 6

4B07 Relay 7

4B08 Relay 8

4B09 Relay 9

4B0A Relay 10

4B0B Relay 11

4B0C Relay 12

4B0D Relay 13

4B0E Relay 14

4B0F Relay 15

4B10 Relay 16

4B11 Relay 17

4B12 Relay 18

4B13 Relay 19

4B14 Relay 20

4B15 Relay 21

4B20 Virtual Relay 01










4B2A Virtual Relay 11



Group 2 Settings

Group 3 Settings

Group 4 Settings

4B2B Virtual Relay 12

4B2C Virtual Relay 13

4B2D Virtual Relay 14

4B2E Virtual Relay 15

4B2F Virtual Relay 16


Date Date


11.2. Peripheral Units: P742/P743

Date: Engineer:

Station: Circuit:

System Frequency:


Peripheral Unit type: P742/P743 *

Model Number

Serial Number

Rated Current In

Auxiliary Voltage Vx


Setting Groups Used

Group 1 Yes/No*

Group 2 Yes/No*

Group 3 Yes/No*

Group 4 Yes/No*

800 SYSTEM DATA

0001 Language English/Francais/Deutsch/Espanol*

0004 Description

0005 Plant Reference

0006 Model Number

0008 Serial Number

0009 Frequency

000A Comms Level

000B Relay Address

0011 Software Ref.1

00D1 Password Control




800 CB CONTROL

0702 Trip Latched

0703 Reset Trip Latch

0704 CB Control By

0705 Man. Close Pulse Time

0706 Man. Trip Pulse Time

0707 Man. Close Delay

800 DATE AND TIME

0804 IRIG-B Sync Disabled/Enabled*

0805 IRIG-B Status Inactive/Active*

0806 Battery Status Dead/Healthy*

0807 Battery Alarm Disabled/Enabled*

0900 CONFIGURATION

0902 Setting Group Select via Menu/Select via Optos*

0903 Active Settings Group 1/Group 2/Group 3/Group 4*




090A Setting Group 4 Disabled/Enabled*

0910 BusBar Prot. Disabled/Enabled*

0911 Optos Setup

0912 Backup Phase O/C Disabled/Enabled*

0913 Backup Earth O/C Disabled/Enabled*

0914 CB Fail Disabled/Enabled*

0925 Input Labels Invisible/Visible*

0926 Output Labels Invisible/Visible*

0928 CT & VT Ratios Invisible/Visible*

0929 Recorder Control Invisible/Visible*

092A Disturb Recorder Invisible/Visible*

092B Measuret Setup Invisible/Visible*

092D Commission Tests Invisible/Visible*

092E Setting Values Primary/Secondary*


0A00 CT AND VT RATIOS

0A07 Phase CT Primary

0A08 Phase CT Secondary

0A20 Transfo Class

0A24 Standard Input BS/IEC

0A25 Knee Voltage Vk BS

0A26 Rated Burden VA IEC

0A28 KSCC IEC

0A29 RCT Sec'y

0A2B Eff. Burden

0C00 DISTURB RECORDER

0C01 Duration

0C02 Trigger Position

0C03 Trigger Mode Single/Extended*






































0D00 MEASURET SETUP

0D01 Default Display 3Ph+N Current/ Date and Time/Description/Plant Reference/ Frequency/ Access Level*

0D02 Local Values Primary/Secondary*

0D03 Remote Values Primary/Secondary*

0F00 COMMISSION TESTS

0F05 Monitor Bit 1

0F06 Monitor Bit 2

0F07 Monitor Bit 3

0F08 Monitor Bit 4

0F09 Monitor Bit 5

0F0A Monitor Bit 6

0F0B Monitor Bit 7

0F0C Monitor Bit 8

0F0D Test Mode Disabled/Test Mode/Blocked*

0F0E Test Pattern


1100 OPTOS SETUP

1101 Global Level

1101 Opto Input 1

1102 Opto Input 2

1103 Opto Input 3

1104 Opto Input 4

1105 Opto Input 5

1106 Opto Input 6

1107 Opto Input 7

1108 Opto Input 8

1109 Opto Input 9

110A Opto Input 10

110B Opto Input 11

110C Opto Input 12

110D Opto Input 13

110E Opto Input 14

110F Opto Input 15

1111 Opto Input 16

1112 Opto Input 17

1113 Opto Input 18

1114 Opto Input 19

1115 Opto Input 20

1116 Opto Input 21

1117 Opto Input 22

1118 Opto Input 23

1119 Opto Input 24

GROUP 1 PROTECTION SETTINGS

For Group 2,3 or 4 the first address figure must be respectively: 5 and 6, 7and 8 or 9 and A


3000 BB TRIP CONFIRM


Group 2 Settings

Group 3 Settings

Group 4 Settings

3001 I>BB Current set

3002 IN<BB Current

3500 BACKUP O/C PHASE


Group 2 Settings

Group 3 Settings

Group 4 Settings

3501 Ι>1 Function

3502 Ι>1 Current Set

3503 Ι>1 Time Delay

3504 Ι>1 TMS

3505 Ι>1 Time Dial

3506 Ι>1 Reset Char

3507 Ι>1 tRESET

3508 Ι>2 Function

3509 Ι>2 Current Set

350A Ι>2 Time Delay

3800 O/C EARTH FAULT


Group 2 Settings

Group 3 Settings

Group 4 Settings

3801 ΙN>1 Function

3802 ΙN>1 Current Set

3803 ΙN>1 Time Delay

3804 ΙN>1 TMS

3805 ΙN>1 Time Dial

3806 ΙN>1 Reset Char

3807 ΙN>1 tRESET

3808 ΙN>2 Function

3809 ΙN>2 Current Set

380A ΙN>2 Time Delay


4500 CB FAIL & I<


Group 2 Settings

Group 3 Settings

Group 4 Settings

4501 Control By

4502 Ι< Current Set

4503 I> Status

4504 I> Current Set

4505 IN> Current Set

4507 CB Fail Timer 1

4508 CB Fail Timer 2

450A CB Fail Timer 3

450B CB Fail Timer 4

4600 SUPERVISION


Group 2 Settings

Group 3 Settings

Group 4 Settings

460E Error Factor Kce

460F Opto Input 2

4A00 INPUT LABELS


Group 2 Settings

Group 3 Settings

Group 4 Settings

4A01 Opto Input 1

4A02 Opto Input 2

4A03 Opto Input 3

4A04 Opto Input 4

4A05 Opto Input 5

4A06 Opto Input 6

4A07 Opto Input 7

4A08 Opto Input 8

4A09 Opto Input 9



Group 2 Settings

Group 3 Settings

Group 4 Settings

4A0A Opto Input 10

4A0B Opto Input 11

4A0C Opto Input 12

4A0D Opto Input 13

4A0E Opto Input 14

4A0F Opto Input 15

4A10 Opto Input 16

4A11 Opto Input 17

4A12 Opto Input 18

4A13 Opto Input 19

4A14 Opto Input 20

4A15 Opto Input 21

4A16 Opto Input 22

4A17 Opto Input 23

4A18 Opto Input 24

4B00 OUTPUT LABELS


Group 2 Settings

Group 3 Settings

Group 4 Settings

4B01 Relay 1

4B02 Relay 2

4B03 Relay 3

4B04 Relay 4

4B05 Relay 5

4B06 Relay 6

4B07 Relay 7

4B08 Relay 8

4B09 Relay 9

4B0A Relay 10

4B0B Relay 11

4B0C Relay 12

4B0D Relay 13

4B0E Relay 14

4B0F Relay 15



Group 2 Settings

Group 3 Settings

Group 4 Settings

4B10 Relay 16

4B11 Relay 17

4B12 Relay 18

4B13 Relay 19

4B14 Relay 20

4B15 Relay 21











4B2A Virtual Relay 11

4B2B Virtual Relay 12

4B2C Virtual Relay 13

4B2D Virtual Relay 14

4B2E Virtual Relay 15

4B2F Virtual Relay 16



Date Date

Problem Analysis P740/EN PR/D11 MiCOM P740 Page 1/14

PROBLEM ANALYSIS

P740/EN PR/D11 Problem Analysis Page 2/14 MiCOM P740


CONTENT

1. INTRODUCTION 4

2. INITIAL PROBLEM IDENTIFICATION 4

3. POWER UP ERRORS 5

4. ERROR MESSAGE/CODE ON POWER-UP 6

5. OUT OF SERVICE LED ILLUMINATED ON POWER UP 8

6. ERROR CODE DURING OPERATION 9

7. MIS-OPERATION OF THE RELAY DURING TESTING 10

8. ERROR CODES 12


1. INTRODUCTION

Before carrying out any work on the equipment, the user should be familiar with the contents of the safety and technical data sections and the ratings on the equipments rating label.

The purpose of this chapter of the service manual is to allow an error condition on the relay to be identified so that appropriate corrective action can be taken.

Should the relay have developed a fault, it should be possible in most cases to identify which relay module requires attention. The Commissioning and Maintenance chapter (P740/EN CM), advises on the recommended method of repair where faulty modules need replacing. It is not possible to perform an on-site repair to a faulted module.

In cases where a faulty relay/module is being returned to the manufacturer or one of their approved service centres, completed copy of the Repair Form located at the end of this manual should be included.

2. INITIAL PROBLEM IDENTIFICATION

Consult the table below to find the description that best matches the problem experienced, then consult the section referenced to perform a more detailed analysis of the problem.

Symptom Refer to

Relay fails to power up Section 3

Relay powers up but indicates error and halts during power-up sequence

Section 4

Relay powers up but Out of Service LED is illuminated Section 5

Relay reboots during normal operation Section 6

Error during normal operation Section 6

Misoperation of the relay during testing Section 7

Table 1: Problem Identification


3. POWER UP ERRORS

If the relay does not appear to power up then the following procedure can be used to determine whether the fault is in the external wiring, auxiliary fuse, power supply module of the relay or the relay front panel.

Test Check Action

1 Measure auxiliary voltage on terminals 1 and 2, verify voltage level and polarity against the rating label on front panel, under the top cover.

Terminal 1 is dc, 2 is +dc

If auxiliary voltage is present and correct, then proceed to test 2. Otherwise the wiring/fuses in auxiliary supply should be checked.

2 Do LEDs/ and LCD backlight illuminate on power up, also check the N/O watchdog contact for closing.

If they illuminate or the contact closes and no error code is displayed then error is probably in the main processor board (front panel)

If they do not illuminate and the contact does not close then proceed to test 3.

3 Check Field voltage output (nominally 48V DC)

If field voltage is not present then the fault is probably in the relay power supply module. Consult the Commissioning & Maintenance chapter (P740/EN CM) for a description of how to remove this module. The part number of this module can be checked to verify that the rating of the module conforms to the auxiliary rating printed on the relay front panel.

Table 2: Failure of Relay to power up


4. ERROR MESSAGE/CODE ON POWER-UP

During the power-up sequence of the relay self-testing is performed as indicated by the messages displayed on the LCD. If an error is detected by the relay during these self-tests then an error message will be displayed and the power-up sequence will be halted. If the error occurs when the relay application software is executing then a maintenance record will be created and the relay will reboot.

Test Check Action

1 Is an error message or code permanently displayed during power up.

If relay locks up and displays an error code permanently then proceed to test 2. If the relay prompts for input by the user proceed to test 4. If the relay reboots automatically then proceed to test 5.

2 Record displayed error, then remove and re-apply relay auxiliary supply.

Record whether the same error code is displayed when the relay is rebooted.

If no error code is displayed then contact the local service centre stating the error code and relay information.

If the same code is displayed proceed to test 3.

3 Error code Identification location.

Following text messages (in English) will be displayed if a fundamental problem is detected preventing the system from booting:

Refer to the Commissioning & Maintenance chapter (P740/EN CMxxx) for module

These messages indicate that a problem has been detected on the main processor board of the relay (located in the front panel), or in the Current Differential processor board (located within the case).

Bus Fail address lines

SRAM Fail - data lines

FLASH Fail format error

FLASH Fail checksum

Code Verify Fail

Other error codes relate to errors detected in hardware or software:

Refer to section 8 for a list of error codes.

4 Relay displays message for corrupt settings and prompts for restoration of defaults to the affected settings.

The power up tests have detected corrupted relay settings. It is possible to restore defaults to allow the power- up to be completed. It will then be necessary to re-apply the application- specific settings.


Test Check Action

5 Relay resets on completion of power up record error code displayed.

Error 0x0E080000, programmable scheme logic error due to excessive execution time. Restore default settings by performing a power up with ! and " keys depressed, confirm restoration of defaults at prompt using # key. If relay powers up successfully, check programmable logic for feedback paths.

Refer to section 8 for a list of error codes.

Table 3: Power-up self-test error


5. OUT OF SERVICE LED ILLUMINATED ON POWER UP

Test Check Action

1 Using the relay menu confirm whether the Commission Test/ Test Mode setting is Enabled.

If the setting is Enabled then disable the test mode and, verify that the Out of Service LED is extinguished.

Otherwise proceed to test 2.

2 Select and view the last maintenance record from the menu (in the View Records).

Check for H/W Verify Fail (this indicates a discrepancy between the relay model number and the hardware). Examine the Maint Data,(this indicates the causes of the failure using bit fields):

Bit Meaning

0 The application type field in the model number does not match the software ID

1 The application field in the model number does not match the software ID

2 The variant 1 field in the model number does not match the software ID

3 The variant 2 field in the model number does not match the software ID

4 The protocol field in the model number does not match the software ID

5 The language field in the model number does not match the software ID

Table 4: Out-of-service condition


6. ERROR CODE DURING OPERATION

The relay performs continuous self-checking. If an error is detected, then an error message will be displayed, a maintenance record will be logged and the relay will reset (after a 1.6 second delay). A permanent problem (for example due to a hardware fault) will generally be detected on the power up sequence, following which the relay will display an error code and halt. If the problem was transient in nature then the relay should re-boot correctly and continue in operation. The nature of the detected fault can be determined by examination of the maintenance record logged.

There are also two cases where a maintenance record will be logged due to a detected error where the relay will not reset. These are detection of a failure of either the field voltage or the lithium battery. In these cases the failure is indicated by an alarm message. However, the relay will continue to operate.

If the field voltage is detected to have failed (the voltage level has dropped below threshold), then a scheme logic signal is also set. This allows the scheme logic to be adapted in the case of this failure (for example if a blocking scheme is being used).

In the case of a battery failure it is possible to prevent the relay from issuing an alarm using the setting under the Date and Time section of the menu. This setting "Battery Alarm" can be set to 'Disabled' to allow the relay to be used without a battery, without an alarm message being displayed.


7. MIS-OPERATION OF THE RELAY DURING TESTING

7.1 Failure of output contacts

An apparent failure of the relay output contacts may be caused by the relay configuration and the following tests should be performed to identify the real cause of the failure. Note that the relay self-tests verify that the coil of the contact has been energised. An error will be displayed if there is a fault in the output relay board.

Test Check Action

1 Is the Out of Service LED illuminated.

Illumination of this LED may indicate that the relay is in test mode or that the protection has been disabled due to a hardware verify error (see Table 4)

2 Examine the Contact status in the Commissioning section of the menu.

If the relevant bits of the contact status are operated then proceed to test 4.

If not, proceed to test 3.

3 Verify by examination of the fault record, or by using the test port whether the protection element is operating correctly.

If the protection element does not operate, verify whether the test is being correctly applied.

If the protection element does operate, then it will be necessary to check the programmable logic to ensure that the mapping of the protection element to the contacts is correct. If the mapping of the protection has been correctly configured, then the contact may be at fault. This can be verified see test 4.

4 Using the Commissioning/Test mode function, apply a test pattern to the relevant relay output contacts and verify whether they operate (note the correct external connection diagram should be consulted).

A continuity tester can be used at the rear of the relay for this purpose.

If the output relay does operate then the problem must be in the external wiring to the relay. If the output relay does not operate this could indicate a failure of the output relay contacts (note that the self-tests verify that the relay coil is being energised). Ensure that the closed resistance is not too high for the continuity tester to detect.

Table 5: Failure of output contacts


7.2 Failure of opto-isolated inputs

The opto-isolated inputs are mapped onto the relay internal signals using the programmable scheme logic. If an input does not appear to be recognised by the relay scheme logic the Commission Tests/Opto Status menu option can be used to verify whether the problem is in the opto-isolated input itself or the mapping of its signal to the scheme logic functions. If the opto-isolated input does appear to be read correctly then it will be necessary to examine its mapping within the programmable logic.

If the opto-isolated input state is not being correctly read by the relay the applied signal should be tested. Verify the connections to the opto-isolated input using the correct wiring diagram. Next, using a voltmeter verify that >80% of the programmed nominal battery voltage threshold is present on the terminals of the opto-isolated input in the energised state. If the signal is being correctly applied to the relay then the failure may be on the input card itself. Depending on which opto-isolated input has failed this may require replacement of either the complete analogue input module (the board within this module cannot be individually replaced without re-calibration of the relay) or a separate opto board.

7.3 Incorrect analogue signals (P742 and P743)

If it is suspected that the analogue quantities being measured by the relay are not correct then the measurement function of the relay can be used to verify the nature of the problem. The measured values displayed by the relay should be compared with the actual magnitudes at the relay terminals. Verify that the correct terminals are being used (in particular the dual rated CT inputs) and that the CT ratios set on the relay are correct.


8. ERROR CODES

Error codes (as reported by the relay via the front panel or in the Maintenance Records) can offer a considerable amount of information about the source of the error.

The Hex Code is reported on the front user interface of the relay immediately prior to a reboot sequence. If this code could not be observed, use the Maintenance Records section of the View Records column to display the corresponding Decimal Code.

Hex Code Decimal Code Meaning

0x0C140001 202637313 The serial driver failed to initialise properly. Check the serial port hardware on the power supply board and the main processor board.

0x0C140002 202637314 The LCD driver failed to initialise properly. Check the LCD on the main processor board.

0x0C140003 202637315 The Flash memory driver failed to initialise properly. Check the Flash memory on the main processor board.

0x0C140004 202637316 The date and time driver failed to initialise properly. Check the real-time clock and battery-backed SRAM on the main processor board.

0x0C140008 202637320 The database failed to initialise properly. Check the EEPROM on the main processor board.

0x0C140009 202637321 The database took too long to commit a change. Check the EEPROM on the main processor board.

0x0C14000A

(P741 only)

202637322 The IRIG-B driver failed to initialise properly. Check the IRIG-B interface hardware on the IRIG-B board.

0x0C160010 202768400 The continuous self-checks have found an error in the RAM bus. Check the RAM on the main processor board.

0x0C160011 202768401 The continuous self-checks have found an error in the RAM block. Check the RAM on the main processor board.

0x0C160012 202768402 The continuous self-checks have found an error in the Flash EPROM checksum. Check the Flash EPROM on the main processor board, and then try downloading a new program.

0x0C160013 202768403 The continuous self-checks have found an error in the code comparison. Check the Flash EPROM on the main processor board, and then try downloading a new program.

0x0C160014 202768404 The continuous self-checks have found an error in the battery backed SRAM. Check the battery, then the RAM on the main processor board.


0x0C160015 202768405 The continuous self-checks have found an error in the EEPROM. Check the EEPROM on the main processor board.

0x0C1600A0 202768544 The continuous self-checks have found an error on the acquisition board. Check the input board.

0x0C170016 202833942 Secondary initialisation tests detected a fast watchdog failure. Check the on the main processor board.

0x0C170017 202833943 Secondary initialisation tests detected a battery backed SRAM failure. Check the battery backed SRAM on the main processor board.

0x0C170018 202833944 Secondary initialisation tests detected a bus reset test failure. Check the main processor board.

0x0C170019 202833945 Secondary initialisation tests detected a slow watchdog failure.

0x0E020000 235012096 Excessive number of gates in PSL. Restore defaults and download new PSL.

0x0E080000 235405312 PSL excessive execution time. Restore defaults and download new PSL.

Table 6: Error Codes

Other error codes relate to problems within the main processor board software. It will be necessary to contact AREVA T&D with details of the problem for a full analysis.

Connection Diagrams P740/EN CO/D11 MiCOM P740

Version dated : 08/03

CONNECTION DIAGRAMS

P740/EN CO/D11 Connection Diagrams MiCOM P740

Connection Diagrams P740/EN CO/D11 MiCOM P740 Page 1/12

CONTENTS

1. MiCOM P741 - CENTRAL UNIT 3

2. MiCOM P742 PERIPHERAL UNIT 6

3. MiCOM P743 PERIPHERAL UNIT 9

P740/EN CO/D11 Connection Diagrams Page 2/12 MiCOM P740


1. MiCOM P741 - CENTRAL UNIT

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SEC

ON

DA

RY

CO

VER

(WH

EN

FIT

TED

)

24

0.0

INC

L.

WIR

ING

SID

EVIE

W

15

7.5

MA

X.

TYPE

OF

FIB

RE

OPTIC

CO

NN

EC

TO

R:

ST

P3

71

3E

Na

CH

1

TX

RX

TX

CH

2RX

CH

3RX

CH

4

TX

TX

RX

EA

CH

TERM

INATIO

NA

CC

EPTS:-

ST

CO

NN

EC

TO

R/

MU

LTI-

MO

DE

FIB

RE

Connections

for

com

munic

ation

board

s

FIGURE 1: MiCOM P741 (80TE) Hardware description


1T

O8

CO

MM

UN

ICA

TIO

NB

OA

RD

S

OP

TIO

NA

LIR

IG-B

BO

AR

D

CO

-PR

OC

ES

SO

RB

OA

RD

PO

WE

RS

UP

PLY

MO

DU

LE

AB

CD

EF

GH

JK

L

MN

P3712E

Na

2 18

16

14

12

10864

17

15

131197531

2 18

16

14

12

10864

17

15

131197531

2 18

16

14

12

10864

17

15

131197531

CH

1

TX

RX

TX

CH

2RX

CH

3RX

CH

4RX

TX

TX

CH

1

TX

RX

TX

CH

2RX

CH

3RX

CH

4RX

TX

TX

CH

1

TX

RX

TX

CH

2RX

CH

3RX

CH

4RX

TX

TX

CH

1

TX

RX

TX

CH

2RX

CH

3RX

CH

4RX

TX

TX

CH

1

TX

RX

TX

CH

2RX

CH

3RX

CH

4RX

TX

TX

CH

1

TX

RX

TX

CH

2RX

CH

3RX

CH

4RX

TX

TX

CH

1

TX

RX

TX

CH

2RX

CH

3RX

CH

4RX

TX

TX

CH

1

TX

RX

TX

CH

2RX

CH

3RX

CH

4RX

TX

TX

CH

1

TX

RX

TX

CH

2RX

IRIG

-B

RX

TX

LO

GIC

AL

OU

TP

UT

CO

NTA

CT

BO

AR

D

LO

GIC

AL

INP

UT

CO

NTA

CT

BO

AR

D

FIGURE 2: MiCOM P741 (80TE) Rear View


PA

PER

RTS

PA

PER

RTS

CTS

0V

RX

TX

SERIA

L

PO

RT

8 974 6532

CO

NN

EC

TED

DATA

REA

DY

DATA

REA

DY

TO

-T7

DO

-D7

0V

RESET

EXTERN

AL

AC

KN

OW

LED

GE

DO

WN

LO

AD

CO

MM

AN

D

DATA

DO

WN

LO

AD

TEST/

17

20,2

1,2

3,2

4

11,1

2,1

5,1

3,

19,1

8,2

2,2

5

NO

T

1SK

1

14

2-9

16

10

1

L16

SC

N

L18

SK

2

L17

CO

MM

UN

ICATIO

NC

OM

MU

NIC

ATIO

N

FIB

RE

OPTIC

FIB

RE

OPTIC

CU

RR

DIF

F

Positio

nA

1to

4PU

*

CU

RR

DIF

F

Positio

nA

1to

4PU

*

RX2

TX2

RX1

TX1

RX4

TX4

RX3

RX3

TX3

RX2

TX2

TX1

RX1

RX4

TX4

RX3

TX3

RX2

TX2

TX1

RX1

RX4

TX4

RX3

TX3

RX2

TX2

TX1

RX1

RX4

TX4

RX3

TX3

RX2

TX2

TX1

RX1

RX4

TX4

RX3

TX3

RX2

TX2

TX1

RX1

RX4

TX4

RX3

TX3

RX2

TX2

TX1

RX1

RX4

TX4

RX3

TX3

RX2

TX2

TX1

RX1

RX4

TX4

RX3

TX3

CO

MM

UN

ICATIO

NC

OM

MU

NIC

ATIO

N

FIB

RE

OPTIC

FIB

RE

OPTIC

CU

RR

DIF

F

Positio

nC

9to

12

PU

*

CU

RR

DIF

F

Positio

nC

9to

12

PU

*

CO

MM

UN

ICATIO

NC

OM

MU

NIC

ATIO

N

FIB

RE

OPTIC

FIB

RE

OPTIC

CU

RR

DIF

F

Positio

nD

13

to1

6PU

*

CU

RR

DIF

F

Positio

nD

13

to1

6PU

*

CO

MM

UN

ICATIO

NC

OM

MU

NIC

ATIO

N

FIB

RE

OPTIC

FIB

RE

OPTIC

CU

RR

DIF

F

Positio

nE

17

to2

0PU

*

CU

RR

DIF

F

Positio

nE

17

to2

0PU

*

CO

MM

UN

ICATIO

NC

OM

MU

NIC

ATIO

N

FIB

RE

OPTIC

FIB

RE

OPTIC

CU

RR

DIF

F

Positio

nF

21

to2

4PU

*

CU

RR

DIF

F

Positio

nF

21

to2

4PU

*

CO

MM

UN

ICATIO

NC

OM

MU

NIC

ATIO

N

FIB

RE

OPTIC

FIB

RE

OPTIC

CU

RR

DIF

F

Positio

nG

25

to2

8PU

*

CU

RR

DIF

F

Positio

nG

25

to2

8PU

*

CO

MM

UN

ICATIO

NC

OM

MU

NIC

ATIO

N

FIB

RE

OPTIC

FIB

RE

OPTIC

CU

RR

DIF

F

Positio

nH

29

to3

2PU

*

CU

RR

DIF

F

Positio

nH

29

to3

2PU

*

CO

MM

UN

ICATIO

NC

OM

MU

NIC

ATIO

N

FIB

RE

OPTIC

FIB

RE

OPTIC

CU

RR

DIF

F

Positio

nB

5to

8PU

*

CU

RR

DIF

F

Positio

nB

5to

8PU

*+

OPTO

1O

PTO

1

OPTO

2O

PTO

2-+-

K5

K9

OPTO

5O

PTO

5

+-

K10

OPTO

3O

PTO

3

OPTO

4O

PTO

4

+-+-

K8

K7

K6

K15

OPTO

8O

PTO

8

+-

K16

OPTO

6O

PTO

6

OPTO

7O

PTO

7

+-+-

K14

K13

K12

K11

K4

K3

K1

K2 K17

K18

CO

NN

EC

TIO

N

CO

MM

ON

50

OH

MK

NC

CO

NN

EC

TO

R5

0O

HM

KN

CC

ON

NEC

TO

R

PIN

TERM

INA

L(P.C

.K.

TYPE)

PIN

TERM

INA

L(P.C

.K.

TYPE)

9-W

AY

&2

5-W

AY

FEM

ALE

D-T

YPE

SO

CK

ET

9-W

AY

&2

5-W

AY

FEM

ALE

D-T

YPE

SO

CK

ET

(K)

48V

DC

FIE

LD

48V

DC

FIE

LD

VO

LTA

GE

OU

TVO

LTA

GE

OU

T

--+++-

L10

L9

L8

L2

L7

L1

CA

SE

EA

RTH

*

AU

XSU

PPLY

AU

XSU

PPLY

AC

OR

DC

AC

OR

DC

Vx

MiC

OM

P7

41

(PA

RT)

MiC

OM

P7

41

(PA

RT)

MiC

OM

P7

41

(PA

RT)

MiC

OM

P7

41

(PA

RT)

+-

10P74101

1 2

Sht:

Next

Sht:

Drg

No:

Issue:

Revis

ion:

Date

:

Date

:

Nam

e:

Chkd:

DO

NO

TSC

ALE

DO

NO

TSC

ALE

CA

DD

ATA

1:1

DIM

EN

SIO

NS:

mm

CA

DD

ATA

1:1

DIM

EN

SIO

NS:

mm

Title

:

T&

DPro

tection

&C

ontr

ole

T&

DPro

tection

&C

ontr

ole

7/0

2/2

00

3

Lattes

BU

SB

AR

PR

OTEC

TIO

N

CEN

TR

AL

UN

ITP

741

WATC

HD

OG

WATC

HD

OG

L1

3L1

3

L1

4L1

4

L1

2

L1

1

CO

NTA

CT

CO

NTA

CT

CO

NTA

CT

*PU

:Peri

phera

lU

nit

J8

J7

J10

J9

J12

J11

J13

J16

J18

J17

J14

J15

J2

J5

J6

J4

J3

J1

RELAY

8RELAY

8

RELAY

7RELAY

7

RELAY

6RELAY

6

RELAY

5RELAY

5

RELAY

4RELAY

4

TRIP

ATRIP

A

TRIP

BTRIP

B

TRIP

CTRIP

C

FIGURE 3: MiCOM P741 (80TE) Wiring Description


2. MiCOM P742 PERIPHERAL UNIT

20

0.0

24

0.0

INC

L.

WIR

ING

30

.0

15

7.5

MA

X.

SEC

ON

DA

RY

CO

VER

(WH

EN

FIT

TED

)

8O

FF

HO

LES

3.4

10

.35

18

1.3

23

.31

55

.4

15

9.0

16

8.0

20

2.0

17

7.0

20

6.0

MiC

OM

4.5

EA

CH

TERM

INATIO

NA

CC

EPTS:-

2x

M4

RIN

GTERM

INA

LS

HEA

VY

DU

TY

FLU

SH

MO

UN

TIN

GPA

NEL

CU

T-O

UT

DETA

IL

TERM

INA

LBLO

CK

DETA

IL

AN

ALO

G&

I/O

BO

ARD

S

1

18

2

17

161

19

3 24

18

SID

EVIE

W

MO

UN

TIN

GSC

REW

S:

M4

x1

2SEM

UN

ITSTEEL

TH

REA

DFO

RM

ING

SC

REW

.

TERM

INA

LSC

REW

S:

M4

x6

STEEL

CO

MBIN

ATIO

NPA

NH

EA

DM

AC

HIN

ESC

REW

.

FRO

NT

VIE

W

MED

IUM

DU

TY

=E

NT

ER

HEA

LTH

Y

OU

TO

FSERVIC

E

ALA

RM

TRIP

==C

LE

AR

RE

AD

TYPE

OF

FIB

RE

OPTIC

CO

NN

EC

TO

R:

ST

4

P3714E

Na

CH

1

TX

RX

TX

CH

2RX

EA

CH

TERM

INATIO

NA

CC

EPTS:-

ST

CO

NN

EC

TO

R/

MU

LTI-

MO

DE

FIB

RE

TERM

INA

LBLO

CK

DETA

IL

CO

PRO

CESSO

RBO

ARD

FIGURE 4: MiCOM P742 (40TE) Hardware Description


CO

PR

OC

ES

SO

RB

OA

RD

(Co

nn

exio

nto

CU

via

op

tica

lfib

re)

CO

PR

OC

ES

SO

RB

OA

RD

(Co

nn

exio

nto

CU

via

op

tica

lfib

re)

PO

WE

RS

UP

PLY

PO

WE

RS

UP

PLY

AN

AL

OG

INP

UT

MO

DU

LE

AN

AL

OG

INP

UT

MO

DU

LE

16

LO

GIC

AL

INP

UT

S1

6L

OG

ICA

LIN

PU

TS

8LO

GIC

AL

OU

TPU

TS

8LO

GIC

AL

OU

TPU

TS

16

17

24

18

13

14

10

11

78

2322

1512

21

9

45

12

A

2019

63

BC

D

2

EF

18

17

15

12

1311

16

14

975

108

31

64

P3

71

0E

Na

18

17

15

12

1311

16

14

975

108

31

64

18

17

15

12

1311

16

14

975

108

31

64

18

17

15

12

1311

16

14

975

108

31

64

22

2

CH

1

TX

RX

TX

CH

2RX



PA

PER

RTS

PA

PER

RTS

CTS

0V

RX

TX

SERIA

L

PO

RT

PO

RT

8 974 6532

CO

NN

EC

TED

CO

NN

EC

TED

DATA

REA

DY

DATA

REA

DY

TO

-T7

DO

-D7

0V

RESET

EXTERN

AL

AC

KN

OW

LED

GE

DO

WN

LO

AD

DO

WN

LO

AD

CO

MM

AN

D

DATA

DO

WN

LO

AD

DO

WN

LO

AD

TEST/

17

20

,21

,23

,24

11

,12

,15

,13

,

19

,18

,22

,25

NO

T

1SK

1

14

2-9

16

10

1

E1

6

SC

N

E1

8

SK

2

E1

7

C9

OPTO

5O

PTO

5

+-

C1

0

+

OPTO

3O

PTO

3

OPTO

4O

PTO

4

+-+-

OPTO

1O

PTO

1

OPTO

2O

PTO

2-+-

C8

C7

C6

C5

C4

C3

C1

C2

A1

8

A1

6

A1

7

+

A1

5

A1

4

-+

A1

2

A1

3

+ --

A1

0

A1

1

+-

A7

A8

A9

+-

A6

A5

+-

C1

4

+

A4

A3

+-

A2

A1

-

C1

7

C1

8

+C

16

C1

5-+

C1

2

C1

3-+

C1

1-

CO

NN

EC

TIO

N

OPTO

16

OPTO

16

CO

MM

ON

OPTO

15

OPTO

15

OPTO

14

OPTO

14

OPTO

13

OPTO

13

OPTO

12

OPTO

12

OPTO

11

OPTO

11

OPTO

7O

PTO

7

OPTO

10

OPTO

10

OPTO

9O

PTO

9

CO

NN

EC

TIO

N

CO

MM

ON

OPTO

8O

PTO

8

OPTO

6O

PTO

6

48

VD

CFIE

LD

48

VD

CFIE

LD

VO

LTA

GE

OU

TVO

LTA

GE

OU

T

--+++-

E1

0

E9

E8

E2

E7

E1

CO

MM

UN

ICATIO

NC

OM

MU

NIC

ATIO

N

FIB

RE

OPTIC

FIB

RE

OPTIC

CU

RR

DIF

FC

URR

DIF

F

RX2

RX1

TX2

TX1

CA

SE

CA

SE

EA

RTH

DIR

EC

TIO

NO

FFO

RW

ARD

CU

RREN

TFLO

WD

IREC

TIO

NO

FFO

RW

ARD

CU

RREN

TFLO

W

NO

TE

2.

NO

TE

2.

CBA

S2

S1

P2

P1

NI

B1

2

B11

B1

0

B9

1A

5A

1A

B5

CI

B8B6

B7

BI

B4

B3

B2

5A

1A

5A

1A

PH

ASE

RO

TATIO

NPH

ASE

RO

TATIO

N

A

CB

IA

B1

5A

C.T

.SH

ORTIN

GLIN

KS

C.T

.SH

ORTIN

GLIN

KS

50

OH

MBN

CC

ON

NEC

TO

R5

0O

HM

BN

CC

ON

NEC

TO

R

PIN

TERM

INA

L(P.C

.B.

TYPE)

PIN

TERM

INA

L(P.C

.B.

TYPE)

9-W

AY

&2

5- W

AY

FEM

ALE

D-T

YPE

SO

CK

ET

9-W

AY

&2

5-W

AY

FEM

ALE

D-T

YPE

SO

CK

ET

(b)

NO

TES

1.

NO

TES

1. (a)

AN

SI3

1_7

2.

C.T

.C

ON

NEC

TIO

NS

ARE

SH

OW

N1

AC

ON

NEC

TED

AN

DA

RE

TYPIC

AL

ON

LY.

AN

SI3

1_7

2.

C.T

.C

ON

NEC

TIO

NS

ARE

SH

OW

N1

AC

ON

NEC

TED

AN

DA

RE

TYPIC

AL

ON

LY.

*

AU

XSU

PPLY

AU

XSU

PPLY

AC

OR

DC

AC

OR

DC

Vx

MiC

OM

P742

(PA

RT)

MiC

OM

P742

(PA

RT)

MiC

OM

P742

(PA

RT)

MiC

OM

P742

(PA

RT)

PO

WER

SU

PPLY

VERSIO

N2

4-4

8V

(NO

MIN

AL)D

.C.

ON

LY

PO

WER

SU

PPLY

VERSIO

N2

4-4

8V

(NO

MIN

AL)D

.C.O

NLY

*

OPERATIO

NO

FTH

EPRO

TEC

TIV

ERELAY.

OPERATIO

NO

FTH

EPRO

TEC

TIV

ERELAY.

3.

TH

ISRELAY

SH

OU

LD

BE

ASSIG

NED

TO

AN

YTRIP

TO

EN

SU

RE

CO

RREC

T3

.TH

ISRELAY

SH

OU

LD

BE

ASSIG

NED

TO

AN

YTRIP

TO

EN

SU

RE

CO

RREC

T

+-

4.

OPTO

INPU

TS

1&

2M

UST

BE

USED

FO

RSETTIN

GG

RO

UP

CH

AN

GES

4.

OPTO

INPU

TS

1&

2M

UST

BE

USED

FO

RSETTIN

GG

RO

UP

CH

AN

GES

IFTH

ISO

PTIO

NIS

SELEC

TED

INTH

ERELAY

MEN

U.

IFTH

ISO

PTIO

NIS

SELEC

TED

INTH

ERELAY

MEN

U.

10

P7

42

01

1 2

Sht:

Next

Sht:

Drg

No:

Issue:

Revis

ion:

Date

:

Date

:

Nam

e:

Chkd:

DO

NO

TSC

ALE

DO

NO

TSC

ALE

CA

DD

ATA

1:1

DIM

EN

SIO

NS:

mm

CA

DD

ATA

1:1

DIM

EN

SIO

NS:

mm

Title

:

T&

DPro

tection

&C

ontr

ole

T&

DPro

tection

&C

ontr

ole

7/02/2003

Lattes

BU

SBA

RPO

TEC

TIO

N

PERIP

HERA

LU

NIT

P7

42

D8

D7

D1

0

D9

D1

2

D1

1

D1

3

D1

6

D1

8

D1

7

D1

4

D1

5D

15

WATC

HD

OG

WATC

HD

OG

D2

D5

D6

D4

D3

E1

3

E1

4

D1

E1

2

E1

1

CO

NTA

CT

CO

NTA

CT

RELAY

8RELAY

8

RELAY

7RELAY

7

RELAY

6RELAY

6

RELAY

5RELAY

5

RELAY

4RELAY

4

TRIP

ATRIP

A

TRIP

BTRIP

B

TRIP

CTRIP

C



3. MiCOM P743 PERIPHERAL UNIT

TERM

INA

LSC

REW

S:

M4

x6

STEEL

CO

MBIN

ATIO

NPA

NH

EA

D

MO

UN

TIN

GSC

REW

S:

M4

x12

SEM

UN

ITSTEEL

TH

REA

DFO

RM

ING

SC

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Relay Menu Database P740/EN GC/D11 MiCOM P740

RELAY MENU DATABASE

P740/EN GC/D11 Relay Menu Database MiCOM P740

A Menu Database (COURIER)

B Digital Data Bus (DDB)

C Default Programmable Scheme Logic (PSL)

This version of P740/EN GC/C11 is specific to the following models

Model number

P741-------01-B

P742-------01-B

P743-------01-B

For other models / software versions, please contact AREVA T&D for the relevant information.


Relay Menu Database

This Chapter is split into several sections, these are as follows:

Menu Database for Courier, User Interface

Digital Data Bus (Internal Digital Signal)

Default Programmable Logic

1. MENU DATABASE

This database defines the structure of the relay menu for the Courier interface and the front panel user interface. This includes all the relay settings and measurements. Indexed strings for Courier and the user interface are cross referenced to the Menu Datatype Definition section (using a G Number). For all settable cells the setting limits and default value are also defined within this database.

2. INTERNAL DIGITAL SIGNALS (DDB)

This table defines all of the relay internal digital signals (opto inputs, output contacts and protection inputs and outputs). A relay may have up to 512 internal signals each reference by a numeric index as shown in this table. This numeric index is used to select a signal for the commissioning monitor port. It is also used to explicitly define protection events produced by the relay.

3. DEFAULT PROGRAMMABLE LOGIC

This section documents the default programmable logic for the various models of the relay is supply with the MiCOM S1 Scheme Logic Editor PC support software.

References

Introduction Chapter: User Interface operation and connections to relay

Courier User Guide R6512


A - MENU DATABASE

Relay Menu Database

MiCOM P740

P740/EN GC/C11

Page A-1

A - Menu database for Courier, User Interface (MiCOM P741 only)

Courier Text Courier Data Type LCD ref Data Default Setting Cell Type Min Max Step Password CommentCol Row Courier Level

00 00 SYSTEM DATA

1 Language Indexed String G19 English Setting 0 3 1 2

2 Password ASCII Password(4 bytes) G20 AAAA Setting 65 90 1 0

4 Description ASCII Text(16 bytes) MiCOM P741 Setting 32 163 1 2

5 Plant Reference ASCII Text(16 bytes) ALSTOM Setting 32 163 1 2

6 Model Number ASCII Text(32 bytes) Model Number Data Cortec Code 18 characters

8 Serial Number ASCII Text(7 bytes) Serial Number Data

9 Frequency Unsigned Integer(1 byte) 50 Setting 50 60 10 2

0A Comms Level Unsigned Integer(2 bytes) 2 Data

0B Relay Address Unsigned Integer(2 bytes) 1 Setting 1 6 1 2 Rear Courier Address available via LCDAddress=255 with default settings

0C Plant Status Binary Flags(16 bits) Data

0D Control Status Binary Flags(16 or 32 bits) Data

0E Active Group Unsigned Integer(2 bytes) G1 Data

11 Software Ref. 1 ASCII Text(16 characters) Data

20 Opto I/P Status Binary Flag(32 bits) DataIndexed String

21 Relay O/P Status Binary Flag(32 bits) DataIndexed String

22 Alarm Status Binary Flag(32 bits) DataIndexed String

D0 Access Level Unsigned Integer(2 bytes) G1 Data

D1 Password Control Unsigned Integer(2 bytes) G22 2 Setting 0 2 1 2

D2 Password Level 1 ASCII Password(4 characters) G20 AAAA Setting 65 90 1 1


01 00 VIEW RECORDS

1 Last Record Unsigned Integer(2) 0 Setting 0 249 1 0 Max value is oldest record

2 Menu Cell Ref Cell Reference N/A (From Record) Data Indicates type of eventSee Event sheet

3 Time & Date IEC870 Time & Date (From Record) Data

Courier Ref

Relay Menu Database

MiCOM P740

P740/EN GC/C11

Page A-2



Courier Ref

4 Record Text Ascii String(32) Data See Event sheet

5 Record Value Binary Flag(32)/UINT32 Data Note DTL depends on event typeSee Event sheet of Spreadsheet

6 Select Fault Unsigned Integer 0 Setting 0 4 1 0 Allows Fault Record to be selected

7 Active Group Unsigned Integer 0 Data

8 Faulted Phase Binary Flags (8 Bits) N/A GXX Data Started phases + tripped phases

9 Start Elements Binary Flags (32 Bits) N/A GXX Data Started elements

0A Trip Elements Binary Flags (32 Bits) N/A GXX Data Tripped elements 1

0C Time Stamp IEC870 Time & Date G12 Data

0D Fault Alarms Binary Flags (32 Bits) G87 Data Faullt Alarms/Warnings

0E System Frequency Courier Number (frequency) Data

0F Fault Duration Courier Number (time) Data

11 IA diff Courier Number (current) G24 Data

12 IB diff Courier Number (current) G24 Data

13 IC diff Courier Number (current) G24 Data

14 IN diff Courier Number (current) G24 Data

15 IA bias Courier Number (current) G24 Data

16 IB bias Courier Number (current) G24 Data

17 IC bias Courier Number (current) G24 Data

18 IN bias Courier Number (current) G24 Data

19 IA CZ diff Courier Number (current) G24 Data

1A IB CZ diff Courier Number (current) G24 Data

1B IC CZ diff Courier Number (current) G24 Data

1C IN CZ diff Courier Number (current) G24 Data

1D Faulted Zone Binary Flags (16 Bits) G212 Data

F0 Select Report Unsigned Integer Manual override to Setting 0 4 1 2 Allows Self Test Report to be selectedselect a fault record.

Relay Menu Database

MiCOM P740

P740/EN GC/C11

Page A-3



Courier Ref

F1 Report Text Ascii String(32) Data

F2 Type UINT32 Data

F3 Data UINT32 Data

FF Reset Indication Indexed String G11 No Command 0 1 1 1

02 00 MEASUREMENTS 1

1 IA Diff CZ Courier Number (current) G24 Data

2 IB Diff CZ Courier Number (current) G24 Data

3 IC Diff CZ Courier Number (current) G24 Data

4 IN Diff CZ Courier Number (current) G24 Data

03 00 MEASUREMENTS 2 Visibility depend of the number of the zone configured

1 Zx1: IA diff Courier Number (current) G24 Data

2 Zx1: IB diff Courier Number (current) G24 Data

3 Zx1: IC diff Courier Number (current) G24 Data

4 Zx1: IN diff Courier Number (current) G24 Data

5 Zx1: IA bias Courier Number (current) G24 Data

6 Zx1: IB bias Courier Number (current) G24 Data

7 Zx1: IC bias Courier Number (current) G24 Data

8 Zx1: IN bias Courier Number (current) G24 Data

,,,

79 Zx16: IA diff Courier Number (current) G24 Data Ligne = 8*Numzone - 7

7A Zx16: IB diff Courier Number (current) G24 Data

7B Zx16: IC diff Courier Number (current) G24 Data

7C Zx16: IN diff Courier Number (current) G24 Data

7D Zx16: IA bias Courier Number (current) G24 Data

7E Zx16: IB bias Courier Number (current) G24 Data

Relay Menu Database

MiCOM P740

P740/EN GC/C11

Page A-4



Courier Ref

7F Zx16: IC bias Courier Number (current) G24 Data

80 Zx16: IN bias Courier Number (current) G24 Data

04 00 TOPOLOGY 1

01 Current Node 01 Binary Flag (16 bits) G212 Data Visible if <> 0









0A Current Node 10 Binary Flag (16 bits) G212 Data Visible if <> 0

0B Current Node 11 Binary Flag (16 bits) G212 Data Visible if <> 0

0C Current Node 12 Binary Flag (16 bits) G212 Data Visible if <> 0

0D Current Node 13 Binary Flag (16 bits) G212 Data Visible if <> 0

0E Current Node 14 Binary Flag (16 bits) G212 Data Visible if <> 0

0F Current Node 15 Binary Flag (16 bits) G212 Data Visible if <> 0


05 00 TOPOLOGY 2






Relay Menu Database

MiCOM P740

P740/EN GC/C11

Page A-5



Courier Ref





0A Current Node 10 Binary Flag (32 bits) G217 Data Visible if <> 0

0B Current Node 11 Binary Flag (32 bits) G217 Data Visible if <> 0

0C Current Node 12 Binary Flag (32 bits) G217 Data Visible if <> 0

0D Current Node 13 Binary Flag (32 bits) G217 Data Visible if <> 0

0E Current Node 14 Binary Flag (32 bits) G217 Data Visible if <> 0

0F Current Node 15 Binary Flag (32 bits) G217 Data Visible if <> 0


06 00 PU CONF & STATUS

01 PU in service Binary Flags (32 Bits) G213 0 Setting 0 0xFFFFFFFF 1 1 PU declared in service

02 PU connected Binary Flags (32 Bits) G213 Data PU synchronised

03 PU topo valid Binary Flags (32 Bits) G213 Data PU with topology parameters valid

04 Reset Circt Flt Indexed String G11 No Command 0 1 1 2 Reset command after circuitry fault

05 CircuitryFfault Binary Flags (16 Bits) G212 Data Circuitry Fault by zone

06 Circ Fault Phase Binary Flags (4 Bits) GXX Data Circuitry Fault by phase

08 00 DATE AND TIME

1 Date/Time IEC870 Time & Date N/A G12 Setting 0

N/A Date Front Panel Menu only36892 ADU if 1/1/2001 possible

N/A Time Front Panel Menu only0.5

4 IRIG-B Sync Indexed String G37 Disabled Setting 0 1 1 2 Master CU : visibe if IRIG-B FittedSlave CU : 0804=0 (invisible)

5 IRIG-B Status ASCII String G17 Data Master CU : visible if 0804=1Slave CU : 0805=0 (invisible)

6 Battery Status Indexed String G59 Data

Relay Menu Database

MiCOM P740

P740/EN GC/C11

Page A-6



Courier Ref

7 Battery Alarm Indexed String G37 Enabled Setting 0 1 1 2

09 00 CONFIGURATION

1 Restore Defaults Indexed String G53 No Operation Command 0 5 1 2

2 Setting Group Indexed String G61 Select via Menu Setting 0 1 1 2

3 Active Settings Indexed String G90 Group 1 Setting 0 3 1 1

4 Save Changes Indexed String G62 No Operation Command 0 2 1 2

5 Copy From Indexed String G90 Group 1 Setting 0 3 1 2

6 Copy to Indexed String G98 No Operation Command 0 3 1 2

7 Setting Group 1 Indexed String G37 Enabled Setting 0 1 1 2

8 Setting Group 2 Indexed String G37 Disabled Setting 0 1 1 2


0A Setting Group 4 Indexed String G37 Disabled Setting 0 1 1 2

10 Diff Busbar Prot Indexed String G37 Enabled Setting 0 1 1 2

11 Optos Setup Indexed String G80 Visible Setting 0 1 1 2

25 Input Labels Indexed String G80 Visible Setting 0 1 1 1

26 Output Labels Indexed String G80 Visible Setting 0 1 1 1

29 Recorder Control Indexed String G80 Visible Setting 0 1 1 1

2A Disturb Recorder Indexed String G80 Visible Setting 0 1 1 1

2B Measure't Setup Indexed String G80 Visible Setting 0 1 1 1

2C Comms Settings Indexed String G80 Invisible Setting 0 1 1 1

2D Commission Tests Indexed String G80 Visible Setting 0 1 1 1

2E Setting Values Indexed String G54 Secondary Setting 0 1 1 1

0B 00 RECORD CONTROL

1 Clear Events Indexed String G11 No Command 0 1 1 1

2 Clear Faults Indexed String G11 No Command 0 1 1 1

Relay Menu Database

MiCOM P740

P740/EN GC/C11

Page A-7



Courier Ref

3 Clear Maint Indexed String G11 No Command 0 1 1 1

0C 00 DISTURB RECORDER

1 Duration Courier Number (time) G2 1.2 Setting 1.2 1.2 0 2 FIXED VALUE: 1.2sCell not modifiable

2 Trigger Position Courier Number (%) G2 50 Setting 0 50 1 2 Ffixed step: 200ms

3 Trigger Mode Indexed String G34 Single Setting 0 1 1 2 Function not available => cell not modifiable

4 Analog Channel 1 Indexed String G214 IA diff Setting 0 8 1 2 Function not available => cell not modifiable

5 Analog Channel 2 Indexed String G214 IB diff Setting 0 8 1 2 Function not available => cell not modifiable

6 Analog Channel 3 Indexed String G214 IC diff Setting 0 8 1 2 Function not available => cell not modifiable

7 Analog Channel 4 Indexed String G214 IN diff Setting 0 8 1 2 Function not available => cell not modifiable

8 Analog Channel 5 Indexed String G214 IA bias Setting 0 8 1 2 Function not available => cell not modifiable

9 Analog Channel 6 Indexed String G214 IB bias Setting 0 8 1 2 Function not available => cell not modifiable

0A Analog Channel 7 Indexed String G214 IC bias Setting 0 8 1 2 Function not available => cell not modifiable

0B Analog Channel 8 Indexed String G214 IN bias Setting 0 8 1 2 Function not available => cell not modifiable

0C Digital Input 1 Indexed String G32 Unused Setting 0 DDB Size 1 2

0D Digital Input 2 Indexed String G32 Unused Setting 0 DDB Size 1 2

0E Digital Input 3 Indexed String G32 Unused Setting 0 DDB Size 1 2

0F Digital Input 4 Indexed String G32 Unused Setting 0 DDB Size 1 2

10 Digital Input 5 Indexed String G32 Unused Setting 0 DDB Size 1 2








Relay Menu Database

MiCOM P740

P740/EN GC/C11

Page A-8



Courier Ref



1A Digital Input 15 Indexed String G32 Unused Setting 0 DDB Size 1 2

1B Digital Input 16 Indexed String G32 Unused Setting 0 DDB Size 1 2

1C Digital Input 17 Indexed String G32 Unused Setting 0 DDB Size 1 2

1D Digital Input 18 Indexed String G32 Unused Setting 0 DDB Size 1 2

1E Digital Input 19 Indexed String G32 Unused Setting 0 DDB Size 1 2

1F Digital Input 20 Indexed String G32 Unused Setting 0 DDB Size 1 2











2A Digital Input 31 Indexed String G32 Unused Setting 0 DDB Size 1 2

2B Digital Input 32 Indexed String G32 Unused Setting 0 DDB Size 1 2

2C Manual Trigger Indexed String G11 No Command 0 1 1 1

2D Zone To Record Binary Flags (16 Bits) G212 0 Setting 0 0x8000 1 2

0D 00 MEASURE'T SETUP

01 Default Display Indexed String G52 0 Setting 0 4 1 2 Aff; Total Zone …

2 Local Values Indexed String G54 Secondary Setting 0 1 1 2 Local Measurement Values

Relay Menu Database

MiCOM P740

P740/EN GC/C11

Page A-9



Courier Ref

3 Remote Values Indexed String G54 Primary Setting 0 1 1 2 Remote Measurement Values

04 Ibp Base Cur Pri Courier Number (Current) G1 1000 Setting 1 10000 1 2

0F 00 COMMISSION TESTS



3 Test Port Status Binary Flags(8 bits) DataIndexed String

4 LED Status Binary Flags(8 bits) 0-7 Data

5 Monitor Bit 1 Unsigned Integer Relay 1 Setting 0 511 1 1





0A Monitor Bit 6 Unsigned Integer Relay 6 Setting 0 511 1 1

0B Monitor Bit 7 Unsigned Integer Relay 7 Setting 0 511 1 1

0C Monitor Bit 8 Unsigned Integer Relay 8 Setting 0 511 1 1

0D Test Mode Indexed String G215 Disabled Setting 0 1 1 2

0E Test Pattern Binary Flags (21bits) G9 0 Setting 0 20 1 2Indexed String

0F Contact Test Indexed String G93 No Operation Command 0 2 1 2

10 Test LEDs Binary Flags (8bits) G94 No Operation Command 0 1 1 2Indexed String

12 87BB monitoring Binary Flags (16bits) G212 0xFFFF Setting 0 0xFFFF 1 2

13 87BB&50BF disabl Binary Flags (16bits) G212 0xFFFF Setting 0 0xFFFF 1 2

14 87BBTrip Pattern Binary Flags (16bits) G212 0 Setting 0 0xFFFF 1 2

15 87BB Trip Order Indexed String G94 No Operation Command 0 1 1 2

20 DDB 0-31 Binary Flag (32 bits) N/A Data RelayVisible by Courier

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Courier Ref

21 DDB 32-63 Binary Flag (32 bits) N/A Data OptoVisible by Courier

22 DDB 64-95 Binary Flag (32 bits) N/A DataVisible by Courier








2A DDB 320-351 Binary Flag (32 bits) N/A DataVisible by Courier

2B DDB 352-383 Binary Flag (32 bits) N/A DataVisible by Courier

2C DDB 384-415 Binary Flag (32 bits) N/A DataVisible by Courier

2D DDB 415-447 Binary Flag (32 bits) N/A DataVisible by Courier

2E DDB 448-479 Binary Flag (32 bits) N/A DataVisible by Courier

2F DDB 480-511 Binary Flag (32 bits) N/A Data

11 00 OPTOS SETUP

1 Global Nominal V Indexed String G200 2 Setting 0 5 1 2

02 Opto Input 1 Indexed String G201 2 Setting 0 4 1 2








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Courier Ref

GROUP 1PROTECTION SETTINGS

30 00 GROUP 1DIFF BUSBAR PROT

01 Diff Phase Fault (Sub-Heading)

02 Current Is Courier Number (Current) G2 0,1*Ibp Setting 0,02*Ibp 1*Ibp 0,01*Ibp 2

03 Phase Slope k Courier Number (%) G2 40 Setting 20 90 1 2

04 ID>2 Current Courier Number (Current) G2 1,2*Ibp Setting 0,1*Ibp 4*Ibp 0,01*Ibp 2

05 ID>1 Current Courier Number (Current) G2 0,05*Ibp Setting 0,01*Ibp 0,5*Ibp 0,01*Ibp 2

06 ID>1 Alarm Timer Courier Number (Time) G2 5 Setting 0.1 100 0.1 2

07 Diff Earth Fault Indexed String G37 Disabled Setting 0 1 1 2

08 IBiasPh> Cur. Courier Number (Current) G2 2*Ibp Setting 0,2*Ibp 10*Ibp 0,1*Ibp 2

09 Earth Cur. IsN Courier Number (Current) G2 0,1*Ibp Setting 0,02*Ibp 1*Ibp 0,01*Ibp 2

0A Earth Slope kN Courier Number (%) G2 20 Setting 20 90 1 2

0B IDN>2 Current Courier Number (Current) G2 0,1*Ibp Setting 0,05*Ibp 2*Ibp 0,05*Ibp 2

0C IDN>1 Current Courier Number (Current) G2 0,05*Ibp Setting 0,01*Ibp 0,5*Ibp 0,01*Ibp 2

0D IDN>1 Alarm Tim. Courier Number (Time) G2 5 Setting 0.1 100 0.1 2

DIFF BUSBAR PROT

4A 00 GROUP 1INPUT LABELS

1 Opto Input 1 ASCII Text (16 chars) Opto Label 01 Setting 32 39 1 2








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Courier Ref

4B 00 GROUP 1OUTPUT LABELS

1 Relay 1 ASCII Text (16 chars) Relay Label 01 Setting 0 7 1 2









50 00 Repeat of Group 1 columns/rows





C0 00 TOPO SETTINGS

01 Topology Size Unsigned integer Data

02 Topology Element 1 Binary Flag (32bits) Data



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P740/EN GC/C11

Page A-13

A - Menu database for Courier, User Interface (MiCOM P742 and P743 only)


00 00 SYSTEM DATA

1 Language Indexed String G19 English Setting 0 3 1 2

2 Password ASCII Password(4 bytes) G20 AAAA Setting 65 90 1 0

4 Description ASCII Text(16 bytes) MiCOM P742/P743 Setting 32 163 1 2

5 Plant Reference ASCII Text(16 bytes) ALSTOM Setting 32 163 1 2

6 Model Number ASCII Text(32 bytes) Model Number Data Cortec / 18 characters

8 Serial Number ASCII Text(7 bytes) Serial Number Data

9 Frequency Unsigned Integer(1 byte) 50 Setting 50 60 10 2

0A Comms Level Unsigned Integer(2 bytes) 2 Data

0B Relay Address Unsigned Integer(2 bytes) 7 Setting 7 102 1 2 Rear Courier Address available via LCD1 Address=255 with default settings

0C Plant Status Binary Flags(16 bits) Data

0D Control Status Binary Flags(16 or 32 bits) Data

0E Active Group Unsigned Integer(2 bytes) G1 Data

10 CB Trip/Close Indexed String(2) G55 No Operation Command 0 2 1 2 Visible to Rear Port(command Bks & isolators)

11 Software Ref. 1 ASCII Text(16 characters) Data

20 Opto I/P Status Binary Flag(32 bits) Data ADU extension 24 ou 32 bitsIndexed String


22 Alarm Status Binary Flag(32 bits) G96 DataIndexed String

D0 Access Level Unsigned Integer(2 bytes) G1 Data

D1 Password Control Unsigned Integer(2 bytes) G22 2 Setting 0 2 1 2



01 00 VIEW RECORDS

1 Last Record Unsigned Integer(2) G1 0 Setting 0 249 1 0 Max value is oldest record

2 Menu Cell Ref Cell Reference N/A G13 (From Record) Data Indicates type of event

Courier Ref

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Courier Ref

See Event sheet3 Time & Date IEC870 Time & Date G12 (From Record) Data

4 Record Text Ascii String(32) Data See Event sheet

5 Record Value Binary Flag(32)/UINT32 G27 Data Note DTL depends on event typeSee Event sheet of Spreadsheet

6 Select Fault Unsigned Integer G1 0 Setting 0 4 1 0 Allows Fault Record to be selected

7 Active Group Unsigned Integer G1 0 Data

8 Faulted Phase Binary Flags (8 Bits) N/A G16 Data Started phases + tripped phases

9 Start Elements Binary Flags (32 Bits) N/A GXX Data Started elements

0A Trip Elements Binary Flags (32 Bits) N/A GXX Data Tripped elements 1

0C Time Stamp IEC870 Time & Date G12 Data

0D Fault Alarms Binary Flags (32 Bits) G87 Data Faullt Alarms/Warnings

0E System Frequency Courier Number (frequency) G25 Data

10 Relay Trip Time Courier Number (time) G24 Data

11 IA Courier Number (current) G24 Data

12 IB Courier Number (current) G24 Data

13 IC Courier Number (current) G24 Data

14 IN Courier Number (current) G24 Data

15 VA Courier Number(voltage) G24 Data Build = Option Transfo Tension

16 VB Courier Number(voltage) G24 Data Build = Option Transfo Tension

17 VC Courier Number(voltage) G24 Data Build = Option Transfo Tension

18 VN Courier Number(voltage) G24 Data Build = Option Transfo Tension

F0 Select Report Unsigned Integer G27 Manual override to Setting 0 4 1 2 Allows Self Test Report to be selectedselect a fault record.

F1 Report Text Ascii String(32) Data

F2 Type UINT32 G27 Data

F3 Data UINT32 G27 Data

FF Reset Indication Indexed String G11 No Command 0 1 1 1

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Courier Ref

02 00 MEASUREMENTS 1

1 IA Magnitude Courier Number (current) G24 Data

2 IA Phase Angle Courier Number (angle) G30 Data

3 IB Magnitude Courier Number (current) G24 Data

4 IB Phase Angle Courier Number (angle) G30 Data

5 IC Magnitude Courier Number (current) G24 Data

6 IC Phase Angle Courier Number (angle) G30 Data

7 IN Magnitude Courier Number (current) G24 Data

8 IN Phase Angle Courier Number (angle) G30 Data

9 IN Derived Magn Courier Number (current) G24 Data

0A IN Derived Angle Courier Number (angle) G30 Data

0B I1 Magnitude Courier Number (current) G24 Data

0C I2 Magnitude Courier Number (current) G24 Data

0D I0 Magnitude Courier Number (current) G24 Data

04 00 TOPOLOGY

1 Link CT / zone Binary Flag(32 bits) G212 Data Zones connected to CTIndexed String Isolator and/or breaker closed

2 Zx1: IA diff Courier Number (Current) G24 Data x1=n° of zone connected to isolator 1IF xx=255, no zone connected

3 Zx1: IB diff Courier Number (Current) G24 Data

4 Zx1: IC diff Courier Number (Current) G24 Data

5 Zx1: IN diff Courier Number (Current) G24 Data

6 Zx1: IA bias Courier Number (Current) G24 Data

7 Zx1: IB bias Courier Number (Current) G24 Data

8 Zx1: IC bias Courier Number (Current) G24 Data

9 Zx1: IN bias Courier Number (Current) G24 Data

0A Zx2: IA diff Courier Number (Current) G24 Data x2=n° of zone connected to isolator 2

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P740/EN GC/C11

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Courier Ref

IF xx=255, no zone connected0B Zx2: IB diff Courier Number (Current) G24 Data

0C Zx2: IC diff Courier Number (Current) G24 Data

0D Zx2: IN diff Courier Number (Current) G24 Data

0E Zx2: IA bias Courier Number (Current) G24 Data

0F Zx2: IB bias Courier Number (Current) G24 Data



12 Zx3: IA diff Courier Number (Current) G24 Data x3=n° of zone connected to isolator 3IF xx=255, no zone connected

13 Zx3: IB diff Courier Number (Current) G24 Data

14 Zx3: IC diff Courier Number (Current) G24 Data

15 Zx3: IN diff Courier Number (Current) G24 Data

16 Zx3: IA bias Courier Number (Current) G24 Data

17 Zx3: IB bias Courier Number (Current) G24 Data



1A Zx4: IA diff Courier Number (Current) G24 Data x4=n° of zone connected to isolator 4IF xx=255, no zone connected

1B Zx4: IB diff Courier Number (Current) G24 Data

1C Zx4: IC diff Courier Number (Current) G24 Data

1D Zx4: IN diff Courier Number (Current) G24 Data

1E Zx4: IA bias Courier Number (Current) G24 Data

1F Zx4: IB bias Courier Number (Current) G24 Data



07 00 CB CONTROL

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Courier Ref

1 Prot Trip Pulse Courier Number (Time) G2 0.2 Setting 0.05 2 0.01 2 Protection trip pulse time

2 Trip Latched Indexed String G37 Disabled Setting 0 1 1 2 To hold relay closed after trip

3 Reset Trip Latch Indexed String G11 No Command 0 1 1 2 Cde to reset upholding

4 CB Control by Indexed String G99 Disabled Setting 0 7 1 2

5 Man Close Pulse Courier Number (Time) G2 0.5 Setting 0.1 5 0.1 2

6 Man Trip Pulse Courier Number (Time) G2 0.5 Setting 0.1 5 0.1 2

7 Man Close Delay Courier Number (Time) G2 10 Setting 0 60 1 2

08 00 DATE and TIME

1 Date/Time IEC870 Time & Date N/A G12 Setting 0

N/A Date Front Panel Menu only35807

N/A Time Front Panel Menu only0.5

6 Battery Status Indexed String G59 Data

7 Battery Alarm Indexed String G37 Enabled Setting 0 1 1 2

09 00 CONFIGURATION

1 Restore Defaults Indexed String G53 No Operation Command 0 5 1 2

2 Setting Group Indexed String G61 Select via Menu Setting 0 1 1 2

3 Active Settings Indexed String G90 Group 1 Setting 0 3 1 2

4 Save Changes Indexed String G62 No Operation Command 0 2 1 2

5 Copy From Indexed String G90 Group 1 Setting 0 3 1 2

6 Copy to Indexed String G98 No Operation Command 0 3 1 2

7 Setting Group 1 Indexed String G37 Enabled Setting 0 1 1 2



0A Setting Group 4 Indexed String G37 Disabled Setting 0 1 1 2

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P740/EN GC/C11

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Courier Ref

10 BB Trip Confirm Indexed String G37 Enabled Setting 0 1 1 2

11 Optos Setup Indexed String G80 Visible Setting 0 1 1 2

12 Overcurrent Prot Indexed String G37 Disabled Setting 0 1 1 2

13 Earth Fault Prot Indexed String G37 Disabled Setting 0 1 1 2

14 CB Fail & I< Indexed String G37 Disabled Setting 0 1 1 2

25 Input Labels Indexed String G80 Visible Setting 0 1 1 1

26 Output Labels Indexed String G80 Visible Setting 0 1 1 1

28 CT & VT Ratios Indexed String G80 Visible Setting 0 1 1 1

29 Recorder Control Indexed String G80 Visible Setting 0 1 1 1

2A Disturb Recorder Indexed String G80 Visible Setting 0 1 1 1

2B Measure't Setup Indexed String G80 Visible Setting 0 1 1 1

2D Commission Tests Indexed String G80 Visible Setting 0 1 1 2

2E Setting Values Indexed String G54 Secondary Setting 0 1 1 1

0A 00 CT AND VT RATIOS

07 Phase CT Primary Courier Number (Current) G35 1000 Setting 1 30000 1 2 I1=Phase CT secondary rating

08 Phase CT Sec'y Courier Number (Current) G2 1 Setting 1 5 4 2Label M4=0A07/0A08

20 CT Class Indexed String G205 X Setting 0 3 1 2 Label M17=(0A07/0A08)^2

21 RBPh / RBN Unsigned Integer G1 1 Setting 0.5 10 0.1 2

23 Power Parameters (Sub-Heading)

24 Standard Input Indexed String G206 British Setting 0 1 1 2 British->0 / IEC->1

25 Knee Voltage Vk Courier Number (Voltage) G2 250 Setting 20 5000 10 2 0A24=0 => British

26 Rated Burden VA Courier Number (VA) G1 25 Setting 5 200 5 0A24=1 => IEC

27 Rated Burden Ohm Courier Number(Ohms) G35 25 / I1^2 Data 5 / I1^2 200 / I1^2 5 / I1^2 2 0A24=1 => IECCalculated not modifiable

28 KSCC Unsigned Integer G1 10 Setting 10 50 5 0A24=1 => IEC

29 RCT Sec'y Courier Number(Ohms) G35 0.5 Setting 0.1 50 0.1 2

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Courier Ref

2B Eff. Burden Ohm Courier Number(Ohms) G35 25 / I1^2 Setting 0,1 / I1^2 200 / I1^2 0,01 / I1^2 2

2C Eff. Burden VA Courier Number (VA) G1 25 Data 0.1 200 0.01 Calculaled not modifiable

0B 00 RECORD CONTROL

1 Clear Events Indexed String G11 No Command 0 1 1 1

2 Clear Faults Indexed String G11 No Command 0 1 1 1

3 Clear Maint Indexed String G11 No Command 0 1 1 1

0C 00 DISTURB RECORDER

1 Duration Courier Number (time) 1.5 Setting 0.1 10.5 0.01 2

2 Trigger Position Courier Number (%) 33.3 Setting 0 100 0.1 2

3 Trigger Mode Indexed String G34 Single Setting 0 1 1 2

4 Analog Channel 1 Indexed String G31 IA Setting 0 8 1 2

5 Analog Channel 2 Indexed String G31 IB Setting 0 8 1 2

6 Analog Channel 3 Indexed String G31 IC Setting 0 8 1 2

7 Analog Channel 4 Indexed String G31 IN Setting 0 8 1 2

8 Analog Channel 5 Indexed String G31 Unused Setting 0 8 1 2 Build = Option Transfo Tension

9 Analog Channel 6 Indexed String G31 Unused Setting 0 8 1 2 Build = Option Transfo Tension

0A Analog Channel 7 Indexed String G31 Unused Setting 0 8 1 2 Build = Option Transfo Tension

0B Analog Channel 8 Indexed String G31 Unused Setting 0 8 1 2 Build = Option Transfo Tension

0C Digital Input 1 Indexed String G32 Unused Setting 0 DDB Size 1 2 DDB Size different for each model

0D Input 1 Trigger Indexed String G66 No Trigger Setting 0 2 1 2

0E Digital Input 2 Indexed String G32 Unused Setting 0 DDB Size 1 2 DDB Size different for each model

0F Input 2 Trigger Indexed String G66 No Trigger Setting 0 2 1 2

10 Digital Input 3 Indexed String G32 Unused Setting 0 DDB Size 1 2 DDB Size different for each model

11 Input 3 Trigger Indexed String G66 No Trigger Setting 0 2 1 2


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Courier Ref








1A Digital Input 8 Indexed String G32 Unused Setting 0 DDB Size 1 2 DDB Size different for each model

1B Input 8 Trigger Indexed String G66 No Trigger Setting 0 2 1 2

















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P740/EN GC/C11

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Courier Ref



























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Courier Ref







0D 00 MEASURE'T SETUP

1 Default Display Indexed String G52 0 Setting 0 4 1 2

2 Local Values Indexed String G54 Secondary Setting 0 1 1 2 Local Measurement Values

3 Remote Values Indexed String G54 Primary Setting 0 1 1 2 Remote Measurement Values

0F 00 COMMISSION TESTS



3 Test Port Status Binary Flags(8 bits) DataIndexed String

4 LED Status Binary Flags(8 bits) 0-7 Data






0A Monitor Bit 6 Unsigned Integer Relay 6 Setting 0 511 1 1

0B Monitor Bit 7 Unsigned Integer Relay 7 Setting 0 511 1 1

0C Monitor Bit 8 Unsigned Integer Relay 8 Setting 0 511 1 1

0D Test Mode Indexed String G215 Disabled Setting 0 1 1 2

0E Test Pattern Binary Flags (21bits) G9 0 Setting 0 20 1 2

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Courier Ref

Indexed String0F Contact Test Indexed String G94 No Operation Command 0 2 1 2

10 Test LEDs Binary Flags (8bits) G94 No Operation Command 0 1 1 2Indexed String

12 Position Pattern Binary Flags (7bits) G216 0 Setting 0 79 1 2 Forced Position for Isolators and Circuit Breaker

13 Position Test Indexed String G93 No Operation Command 0 2 1 2

20 DDB 0-31 Binary Flag (32 bits) N/A Data RelayVisible by Courier and Modbus

21 DDB element 32-63 Binary Flag (32 bits) N/A Data OptoVisible by Courier and Modbus

22 DDB element 64-95 Binary Flag (32 bits) N/A DataVisible by Courier and Modbus








2A DDB element 320-351 Binary Flag (32 bits) N/A DataVisible by Courier and Modbus

2B DDB element 352-383 Binary Flag (32 bits) N/A DataVisible by Courier and Modbus

2C DDB element 384-415 Binary Flag (32 bits) N/A DataVisible by Courier and Modbus

2D DDB element 415-447 Binary Flag (32 bits) N/A DataVisible by Courier and Modbus

2E DDB element 448-479 Binary Flag (32 bits) N/A DataVisible by Courier and Modbus

2F DDB element 480-511 Binary Flag (32 bits) N/A DataVisible by Courier and Modbus

11 00 OPTOS SETUP

1 Global Nominal V Indexed String G200 2 Setting 0 5 1 2



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Courier Ref







0A Opto Input 9 Indexed String G201 2 Setting 0 4 1 2

0B Opto Input 10 Indexed String G201 2 Setting 0 4 1 2

0C Opto Input 11 Indexed String G201 2 Setting 0 4 1 2

0D Opto Input 12 Indexed String G201 2 Setting 0 4 1 2

0E Opto Input 13 Indexed String G201 2 Setting 0 4 1 2

0F Opto Input 14 Indexed String G201 2 Setting 0 4 1 2











GROUP 1BUSBAR ELEMENT

30 00 GROUP 1BB TRIP CONFIRM

01 I>BB Current Set Courier Number (Current) G2 1,2*I1 Setting 0,05*I1 4*I1 0,01*I1 2

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Courier Ref

02 IN>BB Current Courier Number (Current) G2 0,2*I1 Setting 0,05*I1 4*I1 0,01*I1 2

BB TRIP CONFIRM

35 00 GROUP 1BACKUP OVERCURRENT

01 I>1 Function Indexed String G43 Disabled Setting 0 10 1 2

02 I>1 Current Set Courier Number (Current) G2 3*I1 Setting 0,10*I1 32*I1 0,01*I1 2

03 I>1 Time Delay Courier Number (Time) G2 1 Setting 0 100 0.01 2

04 I>1 TMS Courier Number (Time) G2 1 Setting 0.025 1.2 0.025 2 5 >= 3501 >=2

05 I>1 Time Dial Courier Number (Time) G2 7 Setting 0.5 15 0.1 2

06 I>1 Reset Char Indexed String G60 DT Setting 0 1 1 2

07 I>1 tReset Courier Number (Time) G2 0 Setting 0 100 0.1 2 5 >= 3501 >=1 OR (3506 = 0 AND 3501 >= 6)

08 I>2 Function Indexed String G209 Disabled Setting 0 3 1 2

09 I>2 Current Set Courier Number (Current) G2 20*I1 Setting 0,10*In 32*I1 0,01*I1 2

0A I>2 Time Delay Courier Number (Time) G2 1 Setting 0 100 0.01 2

OVERCURRENT

38 00 GROUP 1EARTH FAULT

01 IN>1 Function Indexed String G43 Disabled Setting 0 10 1 2

02 IN>1 Current Set Courier Number (Current) G2 0,3*I1 Setting 0,10*I1 32*I1 0,01*I1 2

03 IN>1 Time Delay Courier Number (Time) G2 1 Setting 0 100 0.01 2

04 IN>1 TMS Courier Number (Time) G2 1 Setting 0.025 1.2 0.025 2 5 >= 3801 >=2

05 IN>1 Time Dial Courier Number (Time) G2 7 Setting 0.5 15 0.1 2

06 IN>1 Reset Char Indexed String G60 DT Setting 0 1 1 2

07 IN>1 tReset Courier Number (Time) G2 0 Setting 0 100 0.1 2 5 >= 3801 >=1 OR (3806 = 0 AND 3801 >= 6)

08 IN>2 Function Indexed String G209 Disabled Setting 0 3 1 2

09 IN>2 Current Set Courier Number (Current) G2 20*I1 Setting 0,10*I1 32*I1 0,01*I1 2

0A IN>2 Time Delay Courier Number (Time) G2 1 Setting 0 100 0.01 2

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Courier Ref

EARTH FAULT

45 00 GROUP 1CB FAIL

01 Control by Indexed String G210 I< Setting 0 2 1 2 I<, 52a, I< & 52a

02 I< Current Set Courier Number (Current) G2 0,05*I1 Setting 0,05*I1 1*I1 0,01*I1 2

03 I> Status Indexed String G37 Disabled Setting 2

04 I> Current Set Courier Number (Current) G2 1,2*I1 Setting 0,05*I1 4*I1 0,01*I1 2 4503<>0 and 4501<>1

05 IN> Current Set Courier Number (Current) G2 0,2*I1 Setting 0,05*I1 4*I1 0,01*I1 2 4503<>0 and 4501<>1

06 INTERNAL TRIP (Sub Heading)

07 CB Fail Timer 1 Courier Number (Time) G2 0.05 Setting 0 10 0.01 2

08 CB Fail Timer 2 Courier Number (Time) G2 0.2 Setting 0 10 0.01 2 4508 > 4507

09 EXTERNAL TRIP (Sub Heading)

0A CB Fail Timer 3 Courier Number (Time) G2 0.05 Setting 0 10 0.01 2

0B CB Fail Timer 4 Courier Number (Time) G2 0.2 Setting 0 10 0.01 2 450B > 450A

CB FAIL

46 00 GROUP 1SUPERVISION

0D I0 SUPERVISION (Sub Heading)

0E Error Factor Kce Courier Number (%) G2 40 Setting 1 100 1 2

0F Alarm Delay Tce Courier Number (Time) G2 5 Setting 0.1 10 0.1 2

SUPERVISION

4A 00 GROUP 1 Product DependentINPUT LABELS

1 Opto Input 1 ASCII Text (16 chars) G3 Opto Label 01 Setting 32 55 1 21



4 Opto Input 4 ASCII Text (16 chars) G3 etc.. Setting 32 55 1 2

5 Opto Input 5 ASCII Text (16 chars) G3 Setting 32 55 1 2


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Courier Ref




0A Opto Input 10 ASCII Text (16 chars) G3 Setting 32 55 1 2

0B Opto Input 11 ASCII Text (16 chars) G3 Setting 32 55 1 2

0C Opto Input 12 ASCII Text (16 chars) G3 Setting 32 55 1 2

0D Opto Input 13 ASCII Text (16 chars) G3 Setting 32 55 1 2

0E Opto Input 14 ASCII Text (16 chars) G3 Setting 32 55 1 2

0F Opto Input 15 ASCII Text (16 chars) G3 Setting 32 55 1 2










INPUT LABELS

4B 00 GROUP 1 Product DependentOUTPUT LABELS

1 Relay 1 ASCII Text (16 chars) G3 Relay Label 01 Setting 0 23 1 2



4 Relay 4 ASCII Text (16 chars) G3 etc … Setting 0 23 1 2

5 Relay 5 ASCII Text (16 chars) G3 Setting 0 23 1 2

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Courier Ref





0A Relay 10 ASCII Text (16 chars) G3 Setting 0 23 1 2

0B Relay 11 ASCII Text (16 chars) G3 Setting 0 23 1 2

0C Relay 12 ASCII Text (16 chars) G3 Setting 0 23 1 2

0D Relay 13 ASCII Text (16 chars) G3 Setting 0 23 1 2

0E Relay 14 ASCII Text (16 chars) G3 Setting 0 23 1 2

0F Relay 15 ASCII Text (16 chars) G3 Setting 0 23 1 2







OUTPUT LABELSGROUP 2

PROTECTION SETTINGS50 00 Repeat of Group 1 columns/rows





C0 00 TOPO SETTINGS

01 Topology Size Unsigned integer Data


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Courier Ref

,,,

FB Topology Element 250 Binary Flag (32bits) Data


B - DIGITAL DATA BUS

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P740/EN GC/C11

Page B-1

B - Digital Data Bus (For P741 Only)

DDB N° Source Description English Text

0 Relay Relay Label 01 Output Label 01








32 Opto Opto Label 01 Opto Input 1








64 Led LED 1 Led 1

65 Led LED 2 Led 2

66 Led LED 3 Led 3

67 Led LED 4 Led 4

68 Led LED 5 Led 5

69 Led LED 6 Led 6

70 Led LED 7 Led 7

71 Led LED 8 Led 8

72 PSL (IN) SG Bit LSB LSB Setting Group

73 PSL (IN) SG Bit MSB MSB Setting Group

74 PSL (IN) Reset Circt Flt Reset Circuitry Fault

75 PSL (IN) Ext. Start DR Starting Disturbance Recorder

76 PSL (IN) Ext. CZ confirm. External CZ confirmation (0=confirmed)

77 PSL (IN) Reset Latches Reset Relays and Led latched in PSL

80 Virtual Relay Virtual Relay 01 Virtual Relays 01
















103 PSL (OUT) System Minor Syst Error Minor System Error

104 PSL (IN) Alarm User 1 Self Reset User Alarm 1








112 PSL (OUT) 87BB Protection Fault 87BB zone 16 Fault current in zone 16
















128 PSL (OUT) 87BB Protection Circt Flt zone 16 Circuitry fault in zone 16






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144 PSL (OUT) 87BB Protection Trp 87BB zone 16 Busbar trip in zone 16
















160 PSL (OUT) 50BF Protection Trp 50BF zone 16 Breaker failure trip (50BF) in zone 16
















176 PSL (OUT) Commissioning Test Man.Trip zone 16 Manual trip zone 16
















192 PSL (OUT) Commissioning Test Lck Lev.1 zone16 Commissioning mode 87BB monitoring in zone 16
















208 PSL (OUT) Commissioning Test Lck Lev.2 zone16 Commissioning mode 87BB & 50BF disabled in zone 16



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224 PSL (OUT) 87BB Protection Trip 87BB Busbar trip order (87BB)

225 PSL (OUT) 87BB Protection Trip 87BB block Busbar trip order blocked by commissioning mode

226 PSL (OUT) 87BB Protection Trip Manual zone Manual Trip Order

227 PSL (OUT) 50BF Protection Trip 50BF Breaker fail trip order (50BF)

228 PSL (OUT) 50BF Protection Trip 50BF block Breaker fail trip order blocked by commissioning mode

229 PSL (OUT) 87BB Protection Dead Zone Signal Fault in dead zone

230 PSL (OUT) 87BB Protection Fault phase A Fault current in phase A

231 PSL (OUT) 87BB Protection Fault phase B Fault current in phase B

232 PSL (OUT) 87BB Protection Fault phase C Fault current in phase C

233 PSL (OUT) 87BB Protection Earth fault Sensitive earth fault current

234 PSL (OUT) 87BB Protection Circuitry Fault Circuitry fault on 1 or several zones

235 PSL (OUT) Commissioning Test Alm Lck Level 1 Commissioning mode 87BB monitoring

236 PSL (OUT) Commissioning Test Alm Lck Level 2 Commissioning mode 87BB & 50BF disabled

237 PSL (OUT) Config. valid Valid configuration

238 PSL (OUT) Topology valid Topology file valid

240 PSL (OUT) Main System Er. Main system error

241 PSL (OUT) 1st CU main err. CU main error

242 PSL (OUT) 2nd CU main err. Remote CU main error

243 PSL (OUT) 87BB Protection Fault Check Zone Busbar fault detected by both CZ (internal & external)

244 PSL (OUT) 87BB Protection Circt Flt ph A Circuitry fault in phase A

245 PSL (OUT) 87BB Protection Circt Flt ph B Circuitry fault in phase B

246 PSL (OUT) 87BB Protection Circt Flt ph C Circuitry fault in phase C

247 PSL (OUT) 87BB Protection Circt Flt Earth Residual circuitry fault

256 PSL (OUT) System Err Chan A Com 1 PU communication error: com A board 1

257 PSL (OUT) System Err Chan B Com 1 PU communication error: com B board 1

258 PSL (OUT) System Err Chan C Com 1 PU communication error: com C board 1

259 PSL (OUT) System Err Chan D Com 1 PU communication error: com D board 1





























288 PSL (OUT) System PU Adr 38 error Error: several PU adresse 38









Relay Menu Database

MiCOM P740

P740/EN GC/C11

Page B-4


























321 PSL (OUT) System 1st CU minor er. CU minor error

322 PSL (OUT) System 2nd CU minor er. Remote CU minor error

323 PSL (OUT) System Minor Err COM1 Minor error in COM 1 board








332 PSL (OUT) System Operating Mode 1

333 PSL (OUT) System Operating Mode 2

334 PSL (OUT) Disturbance Recorder Pre-fault

335 PSL (OUT) Disturbance Recorder Post-fault

336 Virtual Opto Virtual Opto 01 Virtual Opto 01
















352 PSL (OUT) CommTest Enabled Commissionning Test enable

353 PSL (OUT) 87BB Enabled Busbar protection enable

354 PSL (OUT) 87BBN Enabled Busbar earth enable

355 PSL (OUT) Reset Circt Flt Reset after fault

356 PSL (OUT) Topo/Set Changed Change on topology or configuration

357 PSL (OUT) Manual Start DR Disturbance recorder - Manual start

358 PSL (OUT) PU Topo no valid Topology file error for one or several PU

359 PSL (OUT) Alarm Field Volt Alarm field voltage

360 PSL (OUT) Ext. CZ confirm. External CZ confirmation

367 PSL (OUT) General alarm General alarm

400 PSL Relay 01 Output relay 1 condition








408 PSL Relay 09 Reserved






Expert Only

Relay Menu Database

MiCOM P740

P740/EN GC/C11

Page B-5





















432 PSL LED Cond IN 1 Led 1 condition








440 Aux Timer Timer IN 1 Input timer 1








448 Aux Timer Timer OUT 1 Output timer 1







455 Aux Timer Timer OUT 8 Output timer 8456 FRT Fault_REC_TRIG Fault Recorder Trigger

Relay Menu Database

MiCOM P740

P740/EN GC/B11

Page B-6

B - Digital Data Bus (For P742 and P743 Only)

DDB No Source Description English Text

0 Relay Relay Label 01



3 Relay Relay Label 04 Relay 4




7 Relay Relay Label 08 Relay 8 - Setting P742













20 Relay Relay Label 21 Relay 21 - Setting P743
















47 Opto Opto Label 16 Opto Input 16 - Setting P742








55 Opto Opto Label 24 Opto Input 24 - Setting P743

64 Led LED 1 Led 1

65 Led LED 2 Led 2

66 Led LED 3 Led 3

67 Led LED 4 Led 4

68 Led LED 5 Led 5

69 Led LED 6 Led 6

70 Led LED 7 Led 7

71 Led LED 8 Led 8

72 PSL (IN) Isolator Position Q1 Open Isolator 1 - Auxiliary contact open

73 PSL (IN) Isolator Position Q1 Closed Isolator 1 - Auxiliary contact closed











84 PSL (IN) CB Fail Ext. 3 ph Trip Integrated breaker failure logic - 3 phase initialisation

85 PSL (IN) CB Fail External Trip A Integrated breaker failure logic - Initialisation Phase A

86 PSL (IN) CB Fail External Trip B Integrated breaker failure logic - Initialisation Phase B

87 PSL (IN) CB Fail External Trip C Integrated breaker failure logic - Initialisation Phase C

88 PSL (IN) CB Control Man.CB Close Cmd CB Closing order (used in topology processing)

89 PSL (IN) CB Control CB not available CB auxiliary Contact not available

90 PSL (IN) CB Control Ext. CB Fail External breaker failure logique, input to send backtrip order to CU

91 PSL (IN) CB Control CB Aux. 3ph(52a) CB Auxiliary contact open 3ph (52a)

92 PSL (IN) CB Control CB Aux. 3ph(52b) CB Auxiliary contact closed 3ph (52b)

93 PSL (IN) CB Control CB Aux. A (52a) CB Auxiliary contact open Phase A (52a)

94 PSL (IN) CB Control CB Aux. A (52b) CB Auxiliary contact closed Phase A (52b)

95 PSL (IN) CB Control CB Aux. B (52a) CB Auxiliary contact open Phase B (52a)

Relay 1 - Trip Phase A / Relay 2 - Phase B / Relay 3 - Phase C 87BB, 50BF(CU), I> and IN> trip are directly connected even they don't

appear in PSL

Relay Menu Database

MiCOM P740

P740/EN GC/B11

Page B-7



96 PSL (IN) CB Control CB Aux. B (52b) CB Auxiliary contact closed Phase B (52b)

97 PSL (IN) CB Control CB Aux. C (52a) CB Auxiliary contact open Phase C (52a)

98 PSL (IN) CB Control CB Aux. C (52b) CB Auxiliary contact closed Phase C (52b)

99 PSL (IN) Reset Lockout Reset trip relays 1, 2, 3

100 PSL (IN) SG Bit LSB LSB Setting Group

101 PSL (IN) SG Bit MSB MSB Setting Group

102 PSL (IN) Reset All values

103 PSL (IN) Reset Latches Reset relays and leds latched in PSL

104 PSL (IN) User Alarm 1 Self Reset User Alam 1







111 PSL (IN) Aux Volt Superv Auxiliary voltage supervision

112 Virtual relay Virtual Relay 01 Virtual Relay 1
















128 PSL (IN) Isolator Position Man.Close Q1 Cmd Isolator 1 - Closing order (used in topology processing)

129 PSL (IN) Isolator Position Man.Close Q2 Cmd Isolator 2 - Closing order(used in topology processing)





134 PSL (IN) CB Control Man. Close CB CB Control : manual closing order

135 PSL (IN) CB Control Man. Trip CB CB Control : manual opening order

136 PSL (OUT) CB Fail Ext. Retrip Ph A CBF Phase A external retrip (TBF3)

137 PSL (OUT) CB Fail Ext. Retrip Ph B CBF Phase B external retrip (TBF3)

138 PSL (OUT) CB Fail Ext. Retrip Ph C CBF Phase C external retrip (TBF3)

139 PSL (OUT) CB Fail Int retrip 3 ph CBF 3Ph internal retrip (TBF1)

140 PSL (OUT) CB Fail CBF Int Backtrip CBF backtrip - internal (TBF2)

141 PSL (OUT) CB Fail CBF ext Backtrip CBF backtrip - external (TBF4)

142 PSL (OUT) CB Fail CB Fail Alarm CB Fail Alarm (TBF1 + TBF2 + TBF3 + TBF4)

144 PSL (OUT) Phase Overcurrent I>1 Start A Overcurrent Start I>1 phase A

145 PSL (OUT) Phase Overcurrent I>1 Start B Overcurrent Start I>1 phase B

146 PSL (OUT) Phase Overcurrent I>1 Start C Overcurrent Start I>1 phase C

147 PSL (OUT) Earth Fault IN>1 Start Overcurrent Start I>1 phase N

148 PSL (OUT) Phase Overcurrent I>1 Trip Overcurrent Phase Trip 3Ph I>1

149 PSL (OUT) Earth Fault IN>1 Trip Overcurrent Earth Trip 3Ph I>1

150 PSL (OUT) Phase Overcurrent I>2 Start A Overcurrent Start I>2 phase A

151 PSL (OUT) Phase Overcurrent I>2 Start B Overcurrent Start I>2 phase B

152 PSL (OUT) Phase Overcurrent I>2 Start C Overcurrent Start I>2 phase C

153 PSL (OUT) Earth Fault IN>2 Start Overcurrent Start I>2 phase N

154 PSL (OUT) Phase Overcurrent I>2 Trip Overcurrent Phase Trip 3Ph I>2

155 PSL (OUT) Earth Fault IN>2 Trip Overcurrent Earth Trip 3Ph I>2

160 PSL (OUT) 87BB Protection Zone 16 Off Zone 16 in commissioning mode or circuitry fault
















176 PSL (OUT) 87BB Protection Trip Zone 16 Trip zone 16 from 87BB, 50BF or manual trip zone


Relay Menu Database

MiCOM P740

P740/EN GC/B11

Page B-8

















192 PSL (OUT) 87BB Protection I>BB Start A Overcurrent Ia>BB - Busbar Trip Confirmation

193 PSL (OUT) 87BB Protection I>BB Start B Overcurrent Ib>BB - Busbar Trip Confirmation

194 PSL (OUT) 87BB Protection I>BB Start C Overcurrent Ic>BB - Busbar Trip Confirmation

195 PSL (OUT) 87BB Protection IN>BB Start Overcurrent In>BB - Busbar Confirmation

196 PSL (OUT) 87BB Protection I>BB Block Ph A Overcurrent Ia>BB - Blocking Busbar on external fault

197 PSL (OUT) 87BB Protection I>BB Block Ph B Overcurrent Ib>BB - Blocking Busbar on external fault

198 PSL (OUT) 87BB Protection I>BB Block Ph C Overcurrent Ic>BB - Blocking Busbar on external fault

199 PSL (OUT) 87BB Protection IN>BB Block Overcurrent In>BB - Blocking Busbar on external fault

200 PSL (OUT) CT Saturation Saturation ph A Saturation Phase A

201 PSL (OUT) CT Saturation Saturation ph B Saturation Phase B

202 PSL (OUT) CT Saturation Saturation ph C Saturation Phase C

203 PSL (OUT) Monitoring Current Overflow Optical fibre current format > Max

204 PSL (OUT) CT Saturation Max Flux ph A Max flux presomption Phase A

205 PSL (OUT) CT Saturation Max Flux ph B Max flux presomption Phase B

206 PSL (OUT) CT Saturation Max Flux ph C Max flux presomption Phase C

207 PSL (OUT) Monitoring Alarm OffsetABCN Offset Analog board Phase A, B, C or N

208 PSL (OUT) CT Saturation Predict err ph A Variation error Phase A (from derived current)

209 PSL (OUT) CT Saturation Predict err ph B Variation error Phase B (from derived current)

210 PSL (OUT) CT Saturation Predict err ph C Variation error Phase C (from derived current)

212 PSL (OUT) Monitoring Sat ADC ph A ADC saturation Phase A

213 PSL (OUT) Monitoring Sat ADC ph B ADC saturation Phase B

214 PSL (OUT) Monitoring Sat ADC ph C ADC saturation Phase C

215 PSL (OUT) Monitoring Sat ADC Neutral ADC saturation Phase N

216 PSL (OUT) Monitoring Delta IA Variation Phase A

217 PSL (OUT) Monitoring Delta IB Variation Phase B

218 PSL (OUT) Monitoring Delta IC Variation Phase C

219 PSL (OUT) Monitoring Delta IN Variation Phase N

220 PSL (OUT) System Fibre Com Error PU/CU communication error

221 PSL (OUT) System PU Main Error PU main error

222 PSL (OUT) Monitoring Acq Error 3Io Sample acquisition error - 3*Io=In

223 PSL (OUT) Monitoring CT Fail Alarm 3*Io=In error with Tce timer

224 PSL (OUT) All Protection Internal TripTrip 3ph from 87BB, 50BF(CU), I>, IN> or manual zone trip (CU). Trip command directly apply to relay 1, 2, 3 without PSL

225 PSL (OUT) 87BB Protection Trip 87BB Busbar trip in one zone, not especially on this PU

226 PSL (OUT) 87BB Protection Trip 87BB Block Busbar trip blocked by commissioning mode

227 PSL (OUT) 50BF Protection Trip 50BF (CU) 50BF backtrip from CU in one zone, not especially on this PU

228 PSL (OUT) Commissioning Test Man.Trip zone Manual trip in one zone, not especially on this PU

229 PSL (OUT) 50BF Protection Dead Zone Fault Dead zone alarm

230 PSL (OUT) 50BF Protection Circuitry Fault Circuitry fault on dead zone

232 PSL (OUT) System Operating mode 1



235 PSL (OUT) System Config. valid Valid configuration

236 PSL (OUT) System Topology valid Topology file valid

237 PSL (OUT) System Topo/Set valid Configuration & Topology valid

256 PSL (OUT) Overcurrent Protection I> Any Trip Overcurrent Trip (phase or earth fault)

257 PSL (OUT) CB Control CBAvailabToTrip Circuit Breaker available to trip

258 PSL (OUT) 50BF Protection BF Trip Request Internal or external 50BF (backtrip order to CU)

264 PSL (OUT) Overcurrent Protection I> No Trip Overcurent trip - complement

265 PSL (OUT) CB Control CBNotAvailToTrip CB available to trip - complement

266 PSL (OUT) 50BF Protection BFTripNoRequest Internal or external 50BF - complement

273 PSL (OUT) CB Control Ctrl CB Trip Manual trip for local Circuit Breaker

274 PSL (OUT) CB Control Ctrl CB Close Manual closing for local Circuit Breaker

275 PSL (OUT) Commissioning Test PU OutOfService Commissioning Mode - PU out of service

276 PSL (OUT) Commissioning Test PU I/O Disabled Commissioning Mode - I/O disabled

279 PSL (OUT) CT Saturation Reset Flux for expert only280 PSL (OUT) CT Saturation Restart Flux for expert only281 PSL (OUT) Comm Test Enable Activation Commissionning Test282 PSL (OUT) I>BB Enabled Activation OC Busbar Confirmation283 PSL (OUT) Trip Rel Latched Activation latched trip relay284 PSL (OUT) I>2 Block BB ON Activation OC Busbar Blocking Phase285 PSL (OUT) IN>2 Block BB ON Activation OC Busbar Blocking Residual286 PSL (OUT) Reset Trip Relay Reset latched trip relay 1,2 and 3287 PSL (OUT) Topo/Set Changed Setting or topology change

for expert only

Relay Menu Database

MiCOM P740

P740/EN GC/B11

Page B-9



288 PSL (OUT) Isolator Position Q1 Closed Isolator 1 closed (used for topology processing)






300 PSL (OUT) CB Position CB Closed Cicuit breaer closed (used for topology processing)

301 PSL (OUT) CB Control CB Healthy Circuit Breaker 1 available (used for topology processing)

304 PSL (OUT) Isolator Position Q1 Status Forced Isolator 1 - Forced position






310 PSL (OUT) CB Position CB Status Forced Circuit Breaker 1 - Forced position

311 PSL (OUT) Commissioning Test Forced Mode ON Forced position enable

312 PSL (OUT) CB Control CB Aux. 52a Circuit Breaker open

313 PSL (OUT) CB Control CB Aux. 52b Circuit Breaker closed

314 PSL (OUT) CB Control CB Trip 3 ph Circuit Breaker trip 3 phases

315 PSL (OUT) CB Control CB Trip phase A Circuit Breaker trip phase A

316 PSL (OUT) CB Control CB Trip phase B Circuit Breaker trip phase B

317 PSL (OUT) CB Control CB Trip phase C Circuit Breaker trip phase C

318 PSL (OUT) Alarm Field Volt Alarm field voltage

319 PSL (OUT) General Alarm General alarm

320 PSL (OUT) CB Control CB Status Alarm CB status alarm - CB auxiliary contact supevision

321 PSL (OUT) CB Control Man CB Trip Fail CB control alarm - trip error

322 PSL (OUT) CB Control Man CB Cls Fail CB control alarm - closed error

323 PSL (OUT) CB Control Ctrl Cls in Prog Circuit Breaker closed in progress

324 PSL (OUT) CB Control Control Close Circuit Breaker closed control

325 PSL (OUT) CB Control Control Trip Circuit Breaker open control

326 PSL (OUT) All Protection Any Trip OR between DDB 136, 137, 138, 139, 224















































Relay Menu Database

MiCOM P740

P740/EN GC/B11

Page B-10












407 Aux Timer Timer OUT 8 Output timer 8408 FRT Fault_REC_TRIG Fault recorder trigger


C - DEFAULT PROGRAMMABLE SCHEME LOGIC (PSL)

Relay Menu Database P740/EN GC/D11 MiCOM P740 Page C-1

MiCOM P741 PROGRAMMABLE SCHEME LOGIC (01) FOR CENTRAL UNIT

DDB #032

Opto Label 01

DDB #077

Reset Latches

Input-Opto Couplers

DDB #033

Opto Label 02

DDB #075

Ext. Start DR

DDB #034

Opto Label 03

DDB #074

Reset Circt Flt

DDB #035

Opto Label 04

DDB #076

Ext. CZ confirm

DDB #456

FAULT_REC_TRIGDwell20

0

DDB #227

TRIP 50BF

DDB #229

Dead Zone signal

DDB #224

TRIP 87BB

P740/EN GC/D11 Relay Menu Database Page C-2 MiCOM P740


Pick-Up

0

0

Relay Label 01

DDB #000DDB #230

Fault phase A

Output Contact

Pick-Up

0

0

Relay Label 02

DDB #001DDB #231

Fault phase B

Pick-Up

0

0

Relay Label 03

DDB #002DDB #232

Fault phase C

DDB #159

Trp 87BB Zone 01

DDB #175

Trp 50BF Zone 01

DDB #191

Man. Trip Zone 01

Pick-Up

0

0

Relay Label 04

DDB #003

DDB #158

DDB #174

DDB #190

Pick-Up

0

0

Relay Label 05

DDB #004

Pick-Up

0

0

Relay Label 06

DDB #005DDB #234

Circuitry Fault

DDB #143

Crct Flt Zone 01

DDB #207

Lck Lev.1 Zone01

DDB #223

Pick-Up

0

0

Relay Label 07

DDB #006

Pick-Up

0

0

Relay Label 08

DDB #007

DDB #142

DDB #206

DDB #222

Trp 87BB Zone 02

Trp 50BF Zone 02

Man. Trip Zone 02

Lck Lev.2 Zone01

Crct Flt Zone 02

Lck Lev.1 Zone02

Lck Lev.2 Zone02



DDB #064Latching

Output_led_01

DDB #230

Fault phase A

Leds Front Panel

Circuitry Fault

Breaker Fail

Busbar Trip

Phase C

Phase B

Phase A

DDB #065Latching

Output_led_02

DDB #231

Fault phase B

DDB #066Latching

Output_led_03

DDB #232

Fault phase C

DDB #067Latching

Output_led_04

DDB #224

Trip 87BB

DDB #068Latching

Output_led_05

DDB #227

Trip 50BF

DDB #069Latching

Output_led_06

DDB #234

Circuitry Fault


MiCOM P742 & P743 PROGRAMMABLE SCHEME LOGIC (01) FOR PERIPHERAL UNITS

DDB #032

Opto Label 01

DDB #103

Reset Latches

Input-Opto Couplers

DDB #033

Opto Label 02

DDB #099

Reset Lockout

DDB #408

Fault_REC_TRIGDwell20

0

DDB #326

Any Trip

DDB #229

Dead Zone Fault

DDB #034

Opto Label 03

DDB #073

Q1 Closed

DDB #035

Opto Label 04

DDB #072

Q1 Open

DDB #036

Opto Label 05

DDB #075

Q2 Closed

DDB #037

Opto Label 06

DDB #074

Q2 Open

DDB #038

Opto Label 07

DDB #091

CB Aux. 3ph (52a)

DDB #039

Opto Label 08

DDB #092

DDB #040

Opto Label 09

DDB #077

Q3 Closed

DDB #041

Opto Label 10

DDB #076

Q3 Open

DDB #043

Opto Label 12

DDB #084

Ext. 3 ph Trip

DDB #044

Opto Label 13

DDB #089

CB not available

DDB #045

Opto Label 14

DDB #090

Ext. CB Fail

DDB #046

Opto Label 15

DDB #088

Man.CB Close Cmd

P3721ENa

CB Aux. 3ph (52b)



Output Contact

DDB #136

Ext. Retrip Ph A

Pick-Up0

0

Relay Label 04

DDB #003DDB #142

CB Fail Alarm

DDB #137

Pick-Up0

0

Relay Label 06

DDB #005

DDB #138

DDB #139

Int retrip 3 ph

Pick-Up0

0

Relay Label 05

DDB #004

DDB #044

Opto Label 13

DDB #224

Internal Trip

DDB #229

Dead Zone Fault

Pick-Up0

0

Relay Label 07

DDB #006

DDB #034

Opto Label 03

DDB #035

Opto Label 04

DDB #034

Opto Label 03

DDB #035

Opto Label 04

&Dwell

5000

0

Pick-Up0

0

Relay Label 08

DDB #007

DDB #036

Opto Label 05

DDB #037

Opto Label 06

DDB #036

Opto Label 05

DDB #037

Opto Label 06

&

DDB #040

Opto Label 09

DDB #041

Opto Label 10

DDB #040

Opto Label 09

DDB #041

Opto Label 10

&

Dwell5000

0

Dwell5000

0

DDB #104

User Alarm 1

Ext. Retrip Ph B

Ext. Retrip Ph C

DDB #320

CB Status Alarm



DDB #064Latching

Output_led_01

DDB #288

Q1 Closed

Leds Front Panel

Dead Zone

Breaker Fail

Busbar Trip

Isolator 3

Isolator 2

Isolator 1

DDB #065Latching

Output_led_02

DDB #290

Q2 Closed

DDB #066Latching

Output_led_03

DDB #292

Q3 Closed

DDB #068Latching

Output_led_05DDB #142

CB Fail Alarm

DDB #070Latching

Output_led_07

DDB #229

Dead Zone Fault

DDB #044

Opto Label 13

DDB #069Latching

Output_led_06DDB #224

Internal Trip

DDB #225

Trip 87BB&

Menu Content Tables P740/EN HI/D11 MiCOM P740

MENU CONTENT TABLES

Menu Content Tables

MiCOM P740

P740/EN HI/D11

Page 1

MiCOM P741 - Central Unit

SYSTEM DATA VIEW RECORDS MEASUREMENTS 1 MEASUREMENTS 2 TOPOLOGY 1 TOPOLOGY 2PU CONF &

STATUS

Language Last Record IA bias IA Diff CZ Zx1: IA diff Current Node 01 Current Node 01 PU in service Date/TimeEnglish 0 0 0 A 0 0 0 0

Password Menu Cell Ref IB bias IB Diff CZ Zx1: IB diff Current Node 02 Current Node 02 PU connected TimeAAAA (From Record) 0 0 A 0 0 0 0

Description Time & Date IC bias IC Diff CZ Zx1: IC diff Current Node 03 Current Node 03 PU topo valid IRIG-B SyncMiCOM P741 (From Record) 0 0 A 0 0 0 Disabled

Plant Reference Record Text IN bias IN Diff CZ Zx1: IN diff Reset Circt Flt IRIG-B StatusALSTOM 0 0 0 A 0 0

Serial Number Record Value IA CZ diff Zx1: IA bias Current Node 16 Current Node 16 CircuitryFfault Battery StatusSerial Number 0 0 0 0 0 0

Frequency Active Group IB CZ diff Zx1: IB bias Circ Fault Phase Battery Alarm50 0 0 0 Enabled

Relay Address Faulted Phase IC CZ diff Zx1: IC bias1 0 0 0

Plant Status Start Elements IN CZ diff Zx1: IN bias0 0 0

Control Status Trip Elements Faulted Zone Zx16: IA diff0 0 0

Active Group Time Stamp Select Report Zx16: IB diff0 0 0

Software Ref. 1 Fault Alarms Report Text Zx16: IC diff0 0 0

Opto I/P Status System Frequency Type Zx16: IA bias0 0 0

Relay O/P Status Fault Duration Data Zx16: IB bias0 0 0

Alarm Status IA diff Reset Indication Zx16: IC bias0 No 0

Access Level IB diff Zx16: IN bias0 0

Password Control Password Level 1 IC diff2 AAAA 0

Password Level 2 IN diffAAAA 0

DATE AND TIME

Menu Content Tables

MiCOM P740

P740/EN HI/D11

Page 2

MiCOM P741 - Central Unit

CONFIGURATION RECORD CONTROL DISTURB RECORDER COMMISSION TESTS

Restore Defaults Clear Events Duration Default Display Opto I/P Status Global nominal V Current Is Opto Input 1 Relay 1No Operation No 1.2 0 0 2 0,1*Ibp Opto Label 01 Relay Label 01

Setting Group Clear Faults Trigger Position Local Values Relay O/P Status Opto Input 1 Phase Slope k Opto Input 2 Relay 2Select via Menu No 50 Secondary 0 2 40 Opto Label 02 Relay Label 02

Active Settings Clear Maint Trigger Mode Remote Values Test Port Status Opto Input 2 ID>2 Current Opto Input 3 Relay 3Group 1 No Single Primary 0 2 1,2*Ibp mA Opto Label 03 Relay Label 03

Save Changes Analog Channel 1 Ibp Base Cur Pri LED Status Opto Input 3 ID>1 Current Opto Input 4 Relay 4No Operation IA diff 1000 0 2 0,05*Ibp mA Opto Label 04 Relay Label 04

Copy From Analog Channel 2 Monitor Bit 1 Opto Input 4 ID>1 Alarm Timer Opto Input 5 Relay 5Group 1 IB diff Relay 1 2 5 s Opto Label 05

Copy to Analog Channel 3 Opto Input 5 Diff Earth Fault Opto Input 6 Relay 6No Operation IC diff Monitor Bit 8 2 Enabled Opto Label 06 Relay Label 06

Relay 8Setting Group 1 Analog Channel 4 Opto Input 6 IBiasPh> Cur. Opto Input 7 Relay 7Enabled IN diff Test Mode 2 2*Ibp mA Opto Label 07 Relay Label 07

DisabledSetting Group 2 Analog Channel 5 Opto Input 7 Earth Cur. IsN Opto Input 8 Relay 8Disabled IA bias Test Pattern 2 0,1*Ibp mA Opto Label 08 Relay Label 08

0Setting Group 3 Analog Channel 6 Opto Input 8 Earth Slope kN Virtual Opto 1 Virtual Relay 1Disabled IB bias Contact Test 2 20 mA Virtual Opto 01 Virtual Relay 01

No OperationSetting Group 4 Analog Channel 7 IDN>2 Current Virtual Opto 2 Virtual Relay 2Disabled IC bias Test LEDs 0,1*Ibp mA Virtual Opto 02 Virtual Relay 02

No OperationDiff Busbar Prot Analog Channel 8 IDN>1 CurrentEnabled 0 87BB monitoring 0,05*Ibp mA

0xFFFFOptos Setup Digital Input 1 IDN>1 Alarm Tim. Virtual Opto 16 Virtual Relay 16Visible Unused 87BB&50BF disabl 5 s Virtual Opto 16 Virtual Relay 16

0xFFFFInput LabelsVisible Digital Input 32 87BBTrip Pattern

Unused 0Output LabelsVisible Manual Trigger 87BB Trip Order

No 0Recorder Control Comms SettingsVisible Invisible Zone To Record DDB 0-31

0 0Disturb Recorder Commission TestsVisible Visible

DDB 480-511Measure't Setup Setting Values 0Visible Secondary

OUTPUT LABELSGROUP 1

Relay Label 05

Idem GROUP 2,3 & 4

MEASURE'T SETUPOPTOSSETUP

INPUT LABELSGROUP 1

DIFF BUSBAR PROT GROUP 1

Menu Content Tables

MiCOM P740

P740/EN HI/D11

Page 3

MiCOM P742/3 - Peripheral Units

SYSTEM DATA VIEW RECORDS MEASUREMENTS 1 CB CONTROL DATE and TIME

Language Last Record IA Magnitude Link CT / zone Prot Trip Pulse DateEnglish 0 0 A 0 0.2 0

Password Menu Cell Ref IA Phase Angle Zx1: IA diff Trip Latched TimeAAAA (From Record) 0 A 0 Disabled 0

Description Time & Date IB Magnitude Zx1: IB diff Zx3: IA diff Reset Trip Latch Battery StatusMiCOM P742/P743 (From Record) 0 A 0 0 No 0

Plant Reference Record Text IB Phase Angle Zx1: IC diff Zx3: IB diff CB Control by Battery AlarmALSTOM 0 0 ° 0 0 Disabled Enabled

Model Number Record Value IC Magnitude Zx1: IN diff Zx3: IC diff Man Close PulseModel Number 0 0 A 0 0 0.5

Serial Number Select Fault IC Phase Angle Zx1: IA bias Zx3: IN diff Man Trip PulseSerial Number 0 0 ° 0 0 0.5

Frequency Active Group IN Magnitude Zx1: IB bias Zx3: IA bias Man Close Delay50 0 0 A 0 0 10

Relay Address Faulted Phase IN Phase Angle Zx1: IC bias Zx3: IB bias0 0 ° 0 0

Plant Status Start Elements IN Derived Magn Zx1: IN bias Zx3: IN bias0 0 A 0 0

Control Status Trip Elements IN Derived Angle Zx2: IA diff Zx4: IA diff0 0 ° 0 0

Active Group Time Stamp I1 Magnitude Zx2: IB diff Zx4: IB diff0 0 A 0 0

CB Trip/Close Fault Alarms I2 Magnitude Zx2: IC diff Zx4: IC diffNo Operation 0 0 A Group 1 0

Software Ref. 1 Alarm Status System Frequency Select Report I0 Magnitude Zx2: IN diff Zx4: IN diff0 0 0 A 0 0

Opto I/P Status Access Level Relay Trip Time Report Text Frequency Zx2: IA bias Zx4: IA bias2 0 0 0 Hz 0 0

Relay O/P Status Password Control IA Type Zx2: IB bias Zx4: IB bias0 2 0 0 0 0

Password Level 1 IB Data Zx2: IC bias Zx4: IC biasAAAA 0 0 0 0

Password Level 2 IC Reset Indication Zx2: IN bias Zx4: IN biasAAAA 0 No 0 0

TOPOLOGY

Menu Content Tables

MiCOM P740

P740/EN HI/D11

Page 4


CT AND VT RATIOS

Restore Defaults Phase CT Primary Clear Events Duration Default Display Opto I/P Status Global LevelNo Operation 1000 No 1.5 s 0 0 2

Setting Group Phase CT Sec'y Clear Faults Trigger Position Local Values Relay O/P Status Opto Input 1Select via Menu 1 No 33.3 Secondary 0 2

Active Settings CT Class Clear Maint Trigger Mode Remote Values Test Port Status Opto Input 2Group 1 X No Single Primary 0 0

Save Changes RBPh / RBN Analog Channel 1 LED StatusNo Operation 1 IA 0

Copy From Power Parameters Analog Channel 2 Monitor Bit 1 Opto Input 24Group 1 0 IB 2

Copy to Standard Input Analog Channel 3No Operation British IC

Setting Group 1 Knee Voltage Vk Analog Channel 4 Monitor Bit 8Enabled 250 IN Relay 8

Setting Group 2 Rated Burden VA Analog Channel 5 Test ModeDisabled 25 Unused Disabled

Setting Group 3 Rated Burden Ohm Analog Channel 6 Test PatternDisabled 25 / I1^2 Unused 0

Setting Group 4 KSCC Analog Channel 7 Contact TestDisabled 2 Unused No operation

BB Trip Confirm RCT Sec'y Analog Channel 8 Test LEDsEnabled 0.5 No Trigger No Operation

Optos Setup CT & VT Ratios Eff. Burden Ohm Digital Input 1 Position PatternVisible Visible 25 / I1^2 Unused 0

Overcurrent Prot Recorder Control Eff. Burden VA Input 1 Trigger Position TestDisabled Visible 25 No Trigger No Operation

Earth Fault Prot Disturb Recorder DDB 0-31Disabled Visible 0

CB Fail & I< Measure't Setup Digital Input 32Disabled Visible Unused

Input Labels Commission Tests Input 32 Trigger DDB element 480-511Visible Enabled No Trigger 0

Output Labels Setting ValuesVisible Secondary

Relay 1

CONFIGURATION RECORD CONTROL MEASUR'T SETUPDISTURB RECORDER OPTOS SETUPCOMMISSION TEST

Menu Content Tables

MiCOM P740

P740/EN HI/D11

Page 5


Idem GROUP 2,3 & 4

I>BB Current Set I>1 Function IN>1 Function Control by Opto Input 1 Relay 11,2*I1 Disabled Disabled I< Opto Label 01 Relay Label 01

IN>BB Current I>1 Current Set IN>1 Current Set I< Current Set Error Factor Kce Opto Input 2 Relay 20,2*I1 3*I1 3*I1 0,05*I1 40 Opto Label 02 Relay Label 02

I>1 Time Delay IN>1 Time Delay I> Status Alarm Delay Tce1 1 Disabled 5

I>1 TMS IN>1 TMS I> Current Set Opto Input 24 Relay 211 1 1,2*I1 Opto Input 24 Relay Label 21

I>1 Time Dial IN>1 Time Dial IN> Current Set Virtual Relay 017 7 0,2*I1 Virtual Relay 01

I>1 Reset Char IN>1 Reset CharDT DT

I>1 tReset IN>1 tReset CB Fail Timer 1 Virtual Relay 160 0 0.05 Virtual Relay 16

I>2 Function IN>2 Function CB Fail Timer 2Disabled Disabled 0.2

I>2 Current Set IN>2 Current Set20*I1 20*I1

I>2 Time Delay IN>2 Time Delay CB Fail Timer 31 1 0.05

CB Fail Timer 40.2

BACKUP OVERCURRENT

GROUP1

INPUT LABELS

GROUP1

OUTPUTS LABELS

GROUP1

EXTERNAL TRIP

I0 SUPERVISION

O/C EARTH FAULT GROUP1

CB FAIL GROUP1

SUPERVISION GROUP1

INTERNAL TRIP

BB TRIP CONFIRM GROUP1

Version Compatibility P740/EN VC/D11

MiCOM P740

VERSION COMPATIBILITY

P740/EN VC/D11 Version Compatibility

MiCOM P740

Version Com

patibility P740/EN

VC/D

11

MiC

OM

P740 Page 1/2

PSL Setting FilesMenu Text

Files00 02/2003 First release to Production V2.07

01 07/2003 Update of default settings in the four languages V2.07Refer to manual P740/EN xx/C11 for software version 01 and hardware version B

Refer to manual P740/EN xx/B11 for software version 00 and hardware version B

Relay type: P740

Backward CompatibilitySoftwareVersion

Date ofIssue

Full Description of Changes S1

Compatibility

P44x/EN VC/D11 Menu Content Tables

Page 2/2 MiCOM P441, P442 & P444

8-06-2_p741-743_tech-man

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