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GE Industrial Systems
750/760
Feeder Management Relay
INSTRUCTION MANUAL
Software Revision: 7.0x
Manual P/N: 1601-0120-A5
Manual Order Code: GEK-106471D
Copyright © 2005 GE Multilin
GE Multilin
215 Anderson Avenue, Markham, Ontario
Canada L6E 1B3
Tel: (905) 294-6222 Fax: (905) 201-2098
Internet: http://www.GEmultilin.com
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GE Multilin's Quality
Management System is
registered to ISO9001:2000
QMI # 005094
UL # A3775
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Tabl
e of Contents
Table of Contents
GETTING STARTED Important Procedures
Cautions and Warnings...................................................................................................................... 1-1
Inspection Checklist............................................................................................................................ 1-1
Manual Organization ..........................................................................................................................1-2
Using the Relay
Menu Navigation ................................................................................................................................1-2
Panel Keying Example........................................................................................................................ 1-5
Changing Setpoints
Introduction ......................................................................................................................................... 1-5
The HELP Key......................................................................................................................................1-6
Numerical Setpoints........................................................................................................................... 1-6
Enumeration Setpoints....................................................................................................................... 1-7
Output Relay Setpoints ....................................................................................................................1-10
Text Setpoints ................................................................................................................................... 1-11
Application Example
Description ........................................................................................................................................ 1-11
S2 System Setpoints ........................................................................................................................ 1-19
S3 Logic Inputs Setpoints ................................................................................................................ 1-20
S5 Protection Setpoints....................................................................................................................1-21
Installation ......................................................................................................................................... 1-22
Commissioning
Feeder Management Relay
750/760
INTRODUCTION Overview
Description .......................................................................................................................................... 2-1
Theory of Operation
Description .......................................................................................................................................... 2-3
Current and Voltage Waveform Capture .......................................................................................... 2-3
Frequency Tracking ............................................................................................................................ 2-4
Phasors, Transients, and Harmonics................................................................................................. 2-4
Processing of AC Current Inputs .......................................................................................................2-4
Protection Elements............................................................................................................................ 2-4
Logic Inputs......................................................................................................................................... 2-4
Ordering
Order Codes ........................................................................................................................................ 2-6
Example Order Codes.........................................................................................................................2-6
Accessories..........................................................................................................................................2-6
Specifications
Applicability.........................................................................................................................................2-7
Inputs ................................................................................................................................................... 2-7
Measured Parameters ........................................................................................................................ 2-8
Protection Elements............................................................................................................................ 2-8
Monitoring Elements ........................................................................................................................ 2-10
Control Elements ..............................................................................................................................2-11
Outputs .............................................................................................................................................. 2-12
Output Relays.................................................................................................................................... 2-12
CPU .................................................................................................................................................... 2-12
Physical.............................................................................................................................................. 2-13
Testing ............................................................................................................................................... 2-13
Approvals .......................................................................................................................................... 2-14
INSTALLATION Mechanical Installation
GE Multilin
Drawout Case......................................................................................................................................3-1
Installation ........................................................................................................................................... 3-2
Unit Withdrawal and Insertion........................................................................................................... 3-3
Ethernet Connection ........................................................................................................................... 3-4
Rear Terminal Layout ......................................................................................................................... 3-5
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Feeder Management Relay
Electrical Installation
Phase Sequence and Transformer Polarity.......................................................................................3-8
Current Inputs ......................................................................................................................................3-8
Ground and Sensitive Ground CT Inputs ..........................................................................................3-8
Restricted Earth Fault Inputs ..............................................................................................................3-9
Zero Sequence CT Installation..........................................................................................................3-10
Voltage Inputs....................................................................................................................................3-10
Control Power ....................................................................................................................................3-11
Trip/Close Coil Supervision..............................................................................................................3-12
Logic Inputs........................................................................................................................................3-13
Analog Input.......................................................................................................................................3-13
Analog Outputs..................................................................................................................................3-13
Serial Communications.....................................................................................................................3-14
RS232 Communications....................................................................................................................3-16
IRIG-B..................................................................................................................................................3-17
INTERFACES Front Panel Interface
Description ...........................................................................................................................................4-1
Display..................................................................................................................................................4-1
LED Indicators
Description ...........................................................................................................................................4-1
750/760 Status LED Indicators............................................................................................................4-2
System Status LED Indicators ............................................................................................................4-3
Output Status LED Indicators .............................................................................................................4-4
Relay Messages
Keypad Operation................................................................................................................................4-5
Diagnostic Messages ..........................................................................................................................4-6
Self-Test Warnings..............................................................................................................................4-6
Flash Messages ...................................................................................................................................4-8
EnerVista 750/760 setup Software Interface
Overview ............................................................................................................................................4-10
Hardware............................................................................................................................................4-10
Installing the EnerVista 750/760 setup Software.............................................................................4-12
Connecting EnerVista 750/760 setup to the Relay
Configuring Serial Communications................................................................................................4-14
Using the Quick Connect Feature.....................................................................................................4-15
Configuring Ethernet Communications...........................................................................................4-16
Connecting to the Relay....................................................................................................................4-17
Working with Setpoints and Setpoint Files
Engaging a Device.............................................................................................................................4-18
Entering Setpoints.............................................................................................................................4-18
File Support........................................................................................................................................4-19
Using Setpoints Files.........................................................................................................................4-19
Upgrading Relay Firmware
Description .........................................................................................................................................4-24
Saving Setpoints To A File ...............................................................................................................4-24
Loading New Firmware.....................................................................................................................4-24
Advanced EnerVista 750/760 setup Features
Triggered Events ...............................................................................................................................4-25
Waveform Capture (Trace Memory)................................................................................................4-26
Data Logger........................................................................................................................................4-29
Event Recorder ..................................................................................................................................4-29
Modbus User Map.............................................................................................................................4-30
Viewing Actual Values ......................................................................................................................4-30
Using EnerVista Viewpoint with the 750/760
Plug and Play Example .....................................................................................................................4-31
Table of Contents750/760
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Page 5
Table of Contents
SETPOINTS Overview
Setpoints Main Menu ......................................................................................................................... 5-1
Setpoint Entry Methods .....................................................................................................................5-4
Setpoint Access Security.................................................................................................................... 5-5
Common Setpoints............................................................................................................................. 5-5
Logic Diagrams ................................................................................................................................... 5-6
S1 Relay Setup
Passcode.............................................................................................................................................. 5-7
Communications................................................................................................................................. 5-8
Clock...................................................................................................................................................5-10
Event Recorder.................................................................................................................................. 5-11
Trace Memory................................................................................................................................... 5-11
Data Logger....................................................................................................................................... 5-12
Front Panel ........................................................................................................................................ 5-13
Default Messages..............................................................................................................................5-14
User Text Messages .........................................................................................................................5-15
Clear Data .......................................................................................................................................... 5-15
Installation ......................................................................................................................................... 5-16
Mod 008 Upgrade ............................................................................................................................. 5-16
S2 System Setup
Current Sensing ................................................................................................................................5-17
Bus VT Sensing................................................................................................................................. 5-17
Line VT Sensing ................................................................................................................................ 5-18
Power System ................................................................................................................................... 5-18
FlexCurves™ ..................................................................................................................................... 5-18
S3 Logic Inputs
Overview............................................................................................................................................5-19
Logic Inputs Setup............................................................................................................................ 5-20
Breaker Functions ............................................................................................................................. 5-21
Control Functions.............................................................................................................................. 5-22
User Inputs ........................................................................................................................................ 5-23
Block Functions................................................................................................................................. 5-24
Block Overcurrent ............................................................................................................................. 5-25
Transfer Functions............................................................................................................................ 5-26
Reclose (760 Only) ............................................................................................................................ 5-27
Miscellaneous ................................................................................................................................... 5-27
S4 Output Relays
Relay Operation ................................................................................................................................ 5-27
Trip Relay...........................................................................................................................................5-29
Close Relay........................................................................................................................................5-30
Auxiliary Relays ................................................................................................................................ 5-31
Self-Test Warning Relay................................................................................................................... 5-32
S5 Protection
Overview............................................................................................................................................5-32
Time Overcurrent Curve Characteristics.........................................................................................5-33
Phase Current.................................................................................................................................... 5-37
Neutral Current ................................................................................................................................. 5-43
Ground Current................................................................................................................................. 5-48
Sensitive Ground .............................................................................................................................. 5-52
Negative Sequence........................................................................................................................... 5-59
Voltage............................................................................................................................................... 5-64
Frequency.......................................................................................................................................... 5-69
Breaker Failure .................................................................................................................................. 5-72
Reverse Power .................................................................................................................................. 5-73
S6 Monitoring
Current Level..................................................................................................................................... 5-74
Power Factor ..................................................................................................................................... 5-75
Fault Locator...................................................................................................................................... 5-77
Demand ............................................................................................................................................. 5-79
Analog Input...................................................................................................................................... 5-84
Analog Outputs................................................................................................................................. 5-87
Overfrequency...................................................................................................................................5-89
Feeder Management Relay
750/760
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Feeder Management Relay
Equipment..........................................................................................................................................5-90
Pulse Output ......................................................................................................................................5-96
S7 Control
Setpoint Groups ................................................................................................................................5-97
Synchrocheck...................................................................................................................................5-100
Manual Close Blocking....................................................................................................................5-102
Cold Load Pickup.............................................................................................................................5-104
Undervoltage Restoration...............................................................................................................5-106
Underfrequency Restore.................................................................................................................5-107
Transfer Scheme .............................................................................................................................5-108
Autoreclose (760 only) ....................................................................................................................5-122
S8 Testing
Output Relays ..................................................................................................................................5-133
Pickup Test.......................................................................................................................................5-134
Analog Outputs................................................................................................................................5-134
Simulation........................................................................................................................................5-135
Factory Service ................................................................................................................................5-138
ACTUAL VALUES Overview
Actual Values Main Menu...................................................................................................................6-1
A1 Status
Virtual Inputs........................................................................................................................................6-5
Hardware Inputs ..................................................................................................................................6-5
Last Trip Data.......................................................................................................................................6-6
Fault Locations.....................................................................................................................................6-6
Clock .....................................................................................................................................................6-7
Autoreclose (760 only) ........................................................................................................................6-7
A2 Metering
Metering Conventions.........................................................................................................................6-7
Current..................................................................................................................................................6-9
Voltage ...............................................................................................................................................6-10
Frequency...........................................................................................................................................6-11
Synchronizing Voltage ......................................................................................................................6-11
Power..................................................................................................................................................6-12
Energy ................................................................................................................................................6-13
Demand ..............................................................................................................................................6-13
Analog Input.......................................................................................................................................6-14
A3 Maintenance
Trip Counters .....................................................................................................................................6-15
Arcing Current....................................................................................................................................6-15
A4 Event Recorder
Event Records....................................................................................................................................6-16
Last Reset Date ..................................................................................................................................6-19
A5 Product Info
Technical Support .............................................................................................................................6-19
Revision Codes ..................................................................................................................................6-19
Calibration Dates ...............................................................................................................................6-20
Table of Contents750/760
COMMISSIONING Overview
Safety Precautions...............................................................................................................................7-1
Requirements.......................................................................................................................................7-1
Conventions .........................................................................................................................................7-2
Test Equipment....................................................................................................................................7-2
Installation Checks...............................................................................................................................7-3
Wiring Diagrams..................................................................................................................................7-3
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Feeder Management Relay
750/760
Inputs/Outputs
Logic / Virtual Inputs 1 to 14 .............................................................................................................. 7-5
Virtual Inputs 15 to 20....................................................................................................................... 7-11
Output Relays.................................................................................................................................... 7-11
Metering
Current Metering............................................................................................................................... 7-11
Voltage Metering .............................................................................................................................. 7-12
Power Metering................................................................................................................................. 7-14
Demand Metering............................................................................................................................. 7-15
Analog Input Metering......................................................................................................................7-17
Protection Schemes
Setpoint Groups................................................................................................................................ 7-17
Phase Overcurrent ............................................................................................................................ 7-18
Neutral Overcurrent.......................................................................................................................... 7-23
Ground Overcurrent ......................................................................................................................... 7-26
Negative-Sequence Overcurrent and Voltage................................................................................ 7-27
Voltage............................................................................................................................................... 7-28
Frequency.......................................................................................................................................... 7-33
Breaker Failure .................................................................................................................................. 7-35
Reverse Power .................................................................................................................................. 7-36
Monitoring
Current Monitoring ........................................................................................................................... 7-36
Fault Locator...................................................................................................................................... 7-37
Demand Monitoring ......................................................................................................................... 7-38
Analog Inputs .................................................................................................................................... 7-39
Overfrequency Monitoring............................................................................................................... 7-40
Power Factor ..................................................................................................................................... 7-40
VT Failure...........................................................................................................................................7-40
Trip Coil Monitor............................................................................................................................... 7-41
Close Coil Monitor ............................................................................................................................ 7-41
Breaker Operation Failure................................................................................................................ 7-41
Arcing Current................................................................................................................................... 7-42
Analog Output Channels.................................................................................................................. 7-42
IRIG-B.................................................................................................................................................7-42
Pulse Output...................................................................................................................................... 7-42
Control Schemes
Setpoint Group Control.................................................................................................................... 7-42
Synchrocheck.................................................................................................................................... 7-44
Manual Close Feature Blocking .......................................................................................................7-47
Cold Load Pickup Blocking............................................................................................................... 7-48
Undervoltage Restoration................................................................................................................ 7-49
Underfrequency Restoration............................................................................................................ 7-52
Transfer Scheme............................................................................................................................... 7-53
Autoreclose (760 only)...................................................................................................................... 7-59
Placing the Relay In Service
Description ........................................................................................................................................ 7-63
On-Load Testing................................................................................................................................ 7-64
Dielectric Strength Testing............................................................................................................... 7-65
APPENDIX Relay Mods
Conformity
Revision History
GE Multilin Device Warranty
GE Multilin
Reverse Power .................................................................................................................................... 8-1
EU Declaration of Conformity............................................................................................................ 8-3
Release Dates......................................................................................................................................8-4
Release Notes......................................................................................................................................8-4
Warranty Statement ........................................................................................................................... 8-5
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Feeder Management Relay
INDEX
Table of Contents750/760
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Page 9
Important Procedures
Feeder Management Relay
750/760
1 Getting Started
Important Procedures
Cautions and Warnings Please read this chapter to guide you through the initial setup of your new relay.
Before attempting to install or use the relay, it is
imperative that all WARNINGS and CAUTIONS in this
CAUTIONWARNING
manual are reviewed to help prevent personal injury,
equipment damage, and/or downtime.
Getting Started
Inspection Checklist • Open the relay packaging and inspect the unit for physical damage.
• View the rear nameplate and verify that the correct model has been ordered.
• Ensure that the following items are included:
– Instruction Manual
– GE EnerVista CD (includes software and relay documentation)
– mounting screws
• For product information, instruction manual updates, and the latest software
updates, please visit the GE Multilin website at http://www.GEmultilin.com
If there is any noticeable physical damage, or any of the contents listed are
missing, please contact GE Multilin immediately.
NOTE
GE Multilin contact information and call center for produc t su pport :
GE Multilin
215 Anderson Avenue
Markham, Ontario
Canada L6E 1B3
Telephone: (905) 294-6222, toll-free 1-800-547-8629 (North America only)
Fax: (905) 201-2098
E-mail: multilin.tech@ge.com
Home Page: http://www.GEmultilin.com
.
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1–1
Page 10
Getting Started
Using the Relay750/760
Feeder Management Relay
Manual Organization Reading a lengthy instruction manual on a new product is not a task most people
enjoy. To speed things up, this introductory chapter provides a step-by-step tutorial
for a simple feeder application. Important wiring considerations and precautions
discussed in Electrical Installation on page 3–7 should be observed for reliable
operation. Detailed information regarding accuracy, output relay contact ratings,
and so forth are detailed in Specifications on page 2–7. The remainder of this
manual should be read and kept for reference to ensure maximum benefit from the
750 and 760. For further information, please consult your local sales representative
or the factory. Comments about new features or modifications for your specific
requirements are welcome and encouraged.
Setpoints and actual values are indicated as follows in the manual:
A2 METERING ZV DEMAND Z PHASE A CURRENT Z LAST PHASE A CURRENT DEMAND
This ‘path representation’ illustrates the location of an specific actual value or
setpoint with regards to its previous menus and sub-menus. In the example above,
the
LAST PHASE A CURRENT DEMAND actual value is shown to be a item in the Phase A
Current sub-menu, which itself is an item in the Demand menu, which is an item of
actual values page A2 Metering).
Sub-menu levels are entered by pressing the MESSAGE X key. When inside a submenu, the W MESSAGE key returns to the previous sub-menu. The MESSAGE T and
MESSAGE S keys are used to scroll through the settings in a sub-menu. The display
indicates which keys can be used at any given point. A summary of the menu
structure for setpoints and actual values can be found on pages 5–1 and 6–1,
respectively.
Using the Relay
Menu Navigation The relay has three types of display messages: actual values, setpoints, and target
messages.
Setpoints are programmable settings entered by the user. These types of
messages are located within a menu structure that groups the information into
categories. Navigating the menu structure is described below. A summary of the
menu structure for setpoints and actual values can be found in Setpoints Main Menu
on page 5–1 and Actual Values Main Menu on page 6–1, respectively.
Actual values include the following information:
1. The status of logic inputs (both virtual and hardware), last trip information,
fault location, and relay date and time.
2. Metering values measured by the relay, such as current, voltage, frequency,
power, energy, demand, and analog inputs.
3. Maintenance data. This is useful statistical information that may be used for
preventive maintenance. It includes trip counters and accumulated arcing
current.
4. Event recorder downloading tool.
5. Product information including model number, firmware version, additional
product information, and calibration dates.
6. Oscillography and data logger downloading tool.
7. A list of active conditions.
Alarms, trip conditions, diagnostics, and system flash messages are grouped under
Target messages.
Pressing the MENU key accesses the header of each the three main menus (for
setpoints, actual values, and target messages), displayed as follows:
1–2
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Using the Relay
Feeder Management Relay
750/760
SETPOINTS [Z]
ACTUAL VALUES [Z]
TARGET MESSAGES [Z]
1. Press the MENU key to display the header for the setpoints menu, then press the
MESSAGE
X key to display the header of the first setpoints page. The setpoint
pages are numbered, have an ‘S’ prefix for easy identification, and have a name
which provides a general idea of the settings available in that page. Press the
MESSAGE T and MESSAGE S keys to scroll through all the available setpoint page
headers.
SETPOINTS [Z]
S1 RELAY SETUP
Getting Started
Press the MESSAGE
X key to enter the corresponding page. Press the MESSAGE T
and MESSAGE S keys to scroll through the page headers until the required
message is reached. The end of a page is indicated by the message
PAGE Sn
, where n represents the number of the setpoints page.
END OF
2. Press the MENU key to display the header for the actual values menu, then press
the MESSAGE
X key to display the header for the first actual values page. The
actual values pages are numbered, have an ‘A’ prefix for easy identification and
have a name which gives a general idea of the information available in that
page. Pressing the MESSAGE T and MESSAGE S keys will scroll through all the
available actual values page headers.
ACTUAL VALUES [Z]
A1 STATUS
Press the MESSAGE
X key to enter the corresponding page. Press the MESSAGE T
and MESSAGE S keys to scroll through the page headers until the required
message is reached. The end of a page is indicated by the message
PAGE An
3. Select the actual values menu and press the MESSAGE
page. Press the MESSAGE T or MESSAGE S keys until the
, where n represents the number of the actual values page.
X key to enter the first
A2 METERING page
END OF
appears.
ACTUAL VALUES [Z]
A2 METERING
4. Press the MESSAGE
X key to display the first sub-page heading for Page 2 of
actual values.
CURRENT [Z]
5. Press the MESSAGE T key until the
GE Multilin
Press the MESSAGE T and MESSAGE S keys to scroll the display up and down
through the sub-page headers. Pressing the
W MESSAGE key at any sub-page
heading will return the display to the heading of the corresponding setpoint or
actual value page, and pressing it again will return the display to the actual
values main menu header.
DEMAND sub-page heading appears. At this
point, press the MESSAGE
DEMAND [Z]
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X key display the messages in this sub-page.
1–3
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Feeder Management Relay
Using the Relay750/760
If instead you press the MESSAGE S key, the display will return to the previous
sub-page heading; in this case,
ENERGY [Z]
Getting Started
6. When the symbols and
sub-pages are available and can be accessed by pressing the MESSAGE
Pressing MESSAGE
X while at the Demand sub-page heading displays the
[Z] appear on the top line, it indicates that additional
X key.
following:
PHASE A [Z]
CURRENT
Pressing the
7. Press the MESSAGE
W MESSAGE key returns to the Demand sub-page heading.
X key to display the actual values of this second sub-page.
Actual values messages and setpoints always have a col on separating the name
of the value and the actual value or setpoint. This particular message displays
the last Phase A current demand as measured by the relay.
LAST PHASE A CURRENT
DEMAND: 0 A
The menu path to this value is shown as
CURRENT Z LAST PHASE A CURRENT DEMAND. Setpoints and actual values messages
A2 METERING ZV DEMAND Z PHASE A
are referred to in this manner throughout the manual.
To summarize the above example, the
CURRENT Z LAST PHASE A CURRENT DEMAND path representation describes the
A2 METERING ZV DEMAND Z PHASE A
following key-press sequence: press the MENU key until the actual values menu
header is displayed, then press the MESSAGE
METERING
to display the
PHASE A CURRENT message, followed by MESSAGE X one last time to display the
LAST PHASE A CURRENT DEMAND actual value.
message is displayed, then press the MESSAGE X and MESSAGE T keys
DEMAND message, then press the MESSAGE X key to reach the
X and MESSAGE T keys until the A2
8. Press the MESSAGE T key to display the next actual value message. Pressing the
MESSAGE T or MESSAGE S keys scrolls the display through all the actual value
displays in this second sub-page.
MAX PHASE A CURRENT
DEMAND: 0 A
9. Pressing the
the display to the previous level.
10. Press the
header.
1–4
W MESSAGE key reverses the process described above and returns
PHASE A [Z]
CURRENT
W MESSAGE key twice to return to the A2 METERING ZV DEMAND sub-page
DEMAND [Z]
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Changing Setpoints
Feeder Management Relay
750/760
Panel Keying Example The following figure gives a specific example of how the keypad is used to navigate
through the menu structure. Specific locations are referred to throughout this
manual by using a ‘path representation’. The exam ple shown in the figure gives the
key presses required to read the total arcing current in phase B denoted by the path
A3 MAINTENANCE ZV ARCING CURRENT ZV TOTAL ARCING CURRENT ∅B.
Press the menu key until the relay displays the actual values page.
ACTUAL VALUES [Z]
Press the MESSAGE key
ACTUAL VALUES [Z]
A1 STATUS
Press the MESSAGE key
ACTUAL VALUES [Z]
A2 METERING
Press the MESSAGE key
ACTUAL VALUES [Z]
A3 MAINTENANCE
MESSAGE
MESSAGE
TRIP COUNTER [Z]
ARCING CURRENT [Z]
MESSAGE
MESSAGE
TOTAL ARCING CURRENT
φA: 0kA
TOTAL ARCING CURRENT
φB: 0kA
2
- cycle
2
- cycle
Getting Started
Changing Setpoints
Introduction There are several classes of setpoints, each distinguished by the way their values
are displayed and edited.
The relay's menu is arranged in a tree structure. Each setting in the menu is
referred to as a setpoint, and each setpoint in the menu may be accessed as
described in the previous section.
The settings are arranged in pages with each page containing related settings; for
example, all the Phase Time Overcurrent 1 settings are contained within the same
page. As previously explained, the top menu page of each setting group describes
the settings contained within that page. Pressing the MESSAGE keys allows the user to
move between these top menus. A complete editable setpoint chart is available as
NOTE
an Excel spreadsheet from the GE Multilin website at http://www.GEmultilin.com
All of the 750/760 settings fall into one of following categories: device settings,
system settings, logic input settings, output relay settings, monitoring settings,
control settings, and testing settings.
IMPORTANT NOTE: Settings are stored and used by the relay immediately
after they are entered. As such, caution must be exercised when entering
settings while the relay is in service. Modifying or storing protection
settings is not recommended when the relay is in service, since any
incompatibility or lack of coordination with other previously saved settings
may cause unwanted operations.
Now that we have become more fami liar with maneuvering through messages, we
can learn how to edit the values used by all setpoint classes.
Hardware and passcode security features are designed to provide protection against
unauthorized setpoint changes. Since we will be programming new setpoints using
the front panel keys, a hardware jumper must be installed across the setpoint
.
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Page 14
Getting Started
Changing Setpoints750/760
Feeder Management Relay
access terminals (C10 and C11) on the back of the relay case. Attempts to enter a
new setpoint without this electrical connection will result in an error message.
The jumper does not restrict setpoint access via serial communications. The relay
has a programmable passcode setpoint, which may be used to disallow setpoint
changes from both the front panel and the serial communications ports. This
passcode consists of up to eight (8) alphanumeric characters.
The factory default passcode is “0”. When this specific value is programmed into the
relay it has the effect of removing all setpoint modification restrictions. Therefore,
only the setpoint access jumper can be used to restrict setpoi nt a cce s s via the fr ont
panel and there are no restrictions via the communications ports.
When the passcode is programmed to any other value, setpoint access is restricted
for the front panel and all communications ports. Access is not permitted until the
passcode is entered via the keypad or is programmed into a specific register (via
communications). Note that enabling setpoint access on one interface does not
automatically enable access for any of the other interfaces (i.e., the passcode must
be explicitly set in the relay via the interface from which access is desired).
A front panel command can disable setpoint access once all modifications are
complete. For the communications ports, writing an invalid passcode into the
register previously used to enable setpoint access disables access. In addition,
setpoint access is automatically disabled on an interface if no activity is detected for
thirty minutes.
The EnerVista 750/760 setup software incorporates a facility for programming the
relay's passcode as well as enabling and disabling setpoint access. For example,
when an attempt is made to modify a setpoint but access is restricted, the software
will prompt the user to enter the passcode and send it to the relay before the
setpoint is actually written to the relay. If a SCADA system is used for relay
programming, it is the programmer’s responsibility to incorporate appropriate
security for the application.
The HELP Key Pressing the HELP key displays context-sensitive information about setpoints such as
the range of values and the method of changing the setpoint. Help messages will
automatically scroll through all messages currently appropriate.
Numerical Setpoints Each numerical setpoint has its own minimum, maximum, and step value. These
parameters define the acceptable setpoint value range. Two methods of editing and
storing a numerical setpoint value are available.
The first method uses the 750/760 numeric keypad in the same way as any
electronic calculator. A number is entered one digit at a time with the 0 to 9 and
decimal keys. The left-most digit is entered first and the right-most digit is entered
last. Pressing ESCAPE before the ENTER key returns the original value to the display.
The second method uses the VA L U E S key to increment the displayed value by the
step value, up to a maximum allowed and then wr aps around to the minimum v alue.
Likewise, the VA L U E T key decrements the displayed value by the step va lue, down to
a minimum value and then wraps around to the maximum value.
For example:
1. Select the
setpoint message.
2. Press the 6, 3, decimal, and 9 keys. The display message will change as shown.
S2 SYSTEM SETUP ZV BUS VT SENSING Z NOMINAL VT SECONDARY VOLTAGE
NOMINAL VT SECONDARY
VOLTAGE: 120.0 V
NOMINAL VT SECONDARY
VOLTAGE: 63.9 V
3. Until the ENTER key is pressed, editing changes are not registered by the relay.
Therefore, press the ENTER key to store the new value in memory. This flash
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Changing Setpoints
Feeder Management Relay
750/760
message will momentarily appear as confirmation of the storing process. If
69.28 were entered, it would be automatically rounded to 69.3.
NEW SETPOINT
STORED
Enumeration Setpoints Enumeration setpoints have data values which are part of a set whose members are
explicitly defined by a name. A set is comprised of two or more members.
Enumeration values are changed using the VA L U E ke ys.
For example:
1. Move to the
message.
VT CONNECTION TYPE:
Wye
2. Press the VA L U E S key until the “Delta” value is displayed as shown (in this
manual, setpoint values are always shown in double quotation marks).
VT CONNECTION TYPE:
Delta
3. Press the ENTER key to store this change into memory. As before, confirmation of
this action will momentarily flash on the display.
The example shown in the following figures illustrates the key presses required to
enter system parameters such as the phase CT primary rating, ground CT primary
rating, bus VT connection type, secondary voltage, and VT ratio.
The following values will be entered:
Phase CT primary rating: 650 A
Ground CT primary rating: 100 A
Bus VT connection type: Delta
Secondary voltage: 1 15 V
VT Ratio: 14400 / 115 = 125.2
To set the phase CT primary rating, modify the
Z PHASE CT PRIMARY setpoint as shown below.
Press the MENU key until the relay displays the setpoints menu header.
S2 SYSTEM SETUP ZV BUS VT SENSING Z VT CONNECTION TYPE setp oint
NEW SETPOINT
STORED
S2 SYSTEM SETUP Z CURRENT SENSING
Getting Started
SETPOINTS [Z]
Press
MESSAGE X
SETPOINTS [Z]
S1 RELAY SETUP
Press
MESSAGE T
SETPOINTS [Z]
S2 SYSTEM SETUP
To set the ground CT primary rating, modify the
ZV GROUND CT PRIMARY setpoint as shown below.
GE Multilin
Press
MESSAGE X
Press the
enter the value directly via the numeric keypad.
CURRENT [Z]
SENSING
MESSAGE X
VA L U E keys unt il 650 A is displayed, or
Press the
ENTER key to store the
S2 SYSTEM SETUP Z CURRENT SENSING
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Press
setpoint.
PHASE CT PRIMARY:
1000 A
PHASE CT PRIMARY:
650 A
NEW SETPOINT
STORED
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Getting Started
Feeder Management Relay
SETPOINTS [Z]
Press
MESSAGE X
SETPOINTS [Z]
S1 RELAY SETUP
Press
MESSAGE T
SETPOINTS [Z]
S2 SYSTEM SETUP
Changing Setpoints750/760
Press the MENU key until the relay displays the setpoints menu header.
Press
MESSAGE X
Press the
enter the value directly via the numeric keypad.
CURRENT [Z]
SENSING
Press
MESSAGE X
Press
MESSAGE T
VA L U E keys unt il 100 A is displayed, or
Press the
ENTER key to store the
setpoint.
PHASE CT PRIMARY:
1000 A
GND CT PRIMARY:
50 A
GND CT PRIMARY:
100 A
NEW SETPOINT
STORED
To set the ground bus VT connection type, modify the
SENSING Z VT CONNECTION TYPE setpoint as shown below.
Press the MENU key until the relay displays the setpoints menu header.
Press MENU
SETPOINTS [Z]
Press
MESSAGE X
SETPOINTS [Z]
S1 RELAY SETUP
Press
MESSAGE T
SETPOINTS [Z]
S2 SYSTEM SETUP
To set the secondary voltage, modify the
NOMINAL VT SECONDARY VOLTAGE setpoint as shown below.
Press
MESSAGE X
Press
MESSAGE T
Press the
CURRENT [Z]
SENSING
BUS VT SENSING [Z] Press
MESSAGE X
VA L U E keys until the value of “Delta”
appears on the display.
Press the
ENTER key to store the
setpoint.
S2 SYSTEM SETUP ZV BUS VT SENSING ZV
S2 SYSTEM SETUP ZV BUS VT
VT CONNECTION TYPE:
Wye
VT CONNECTION TYPE:
Delta
NEW SETPOINT
STORED
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Changing Setpoints
SETPOINTS [Z]
Press
SETPOINTS [Z]
S1 RELAY SETUP
Press
SETPOINTS [Z]
S2 SYSTEM SETUP
Press MENU
MESSAGE X
MESSAGE T
Feeder Management Relay
Press the MENU key until the relay displays the setpoints menu header.
Press
MESSAGE X
Press
MESSAGE T
Press the
enter the value directly via the numeric keypad.
CURRENT [Z]
SENSING
BUS VT SENSING [Z] Press
MESSAGE X
Press
MESSAGE T
VA L U E keys until 115.0 V is displayed, or
Press the
ENTER key to store the
setpoint.
VT CONNECTION TYPE:
Wye
NOMINAL VT SECONDARY
VOLTAGE: 120.0 V
NOMINAL VT SECONDARY
VOLTAGE: 115.0 V
NEW SETPOINT
STORED
750/760
Getting Started
To set the VT ratio, modify the
setpoint as shown below.
Press the MENU key until the relay displays the setpoints menu header.
Press MENU
SETPOINTS [Z]
Press
MESSAGE X
SETPOINTS [Z]
S1 RELAY SETUP
MESSAGE T
Press
SETPOINTS [Z]
S2 SYSTEM SETUP
S2 SYSTEM SETUP ZV BUS VT SENSING ZV VT RATIO
Press
MESSAGE X
Press
MESSAGE T
CURRENT [Z]
SENSING
BUS VT SENSING [Z] Press
MESSAGE X
MESSAGE T
MESSAGE T
Press the
enter the value directly via the numeric keypad.
VA L U E keys until 125.2:1 is displayed, or
Press the
ENTER key to store the
Press
Press
setpoint.
VT CONNECTION TYPE:
Wye
NOMINAL VT SECONDARY
VOLTAGE: 120.0 V
VT RATIO:
120.0:1
VT RATIO:
125.2:1
NEW SETPOINT
STORED
If an entered setpoint value is out of range, the relay displays the following
message:
GE Multilin
OUT-OF RANGE –
VALUE NOT STORED
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Getting Started
Feeder Management Relay
Changing Setpoints750/760
To have access to information on maximum, minimum, step value, and information
on technical support, press the HELP key. For the previous example, pressing the HELP
key during setpoint entry displays the corresponding minimum, maximum and step
values for the displayed setpoint, as well as contact information if further assistance
is required.
For example, the help screens for the
PHASE CT PRIMARY:
1000 A
Press
Press
Press
Press
Press
Press
Press
Press
HELP
HELP
HELP
HELP
HELP
HELP
HELP
HELP
MIN: 1
MAX: 5000
IN STEPS OF:
1
PRESS [0]-[9] OR
[VALUE ST] TO EDIT
PRESS [ENTER] TO
STORE NEW VALUE
FOR FURTHER HELP
REFER TO MANUAL
INTERNET ADDRESS
www.GEmultilin.com
TECH SUPPORT
Tel: (905) 294-6222
TECH SUPPORT
Fax: (905) 201-2098
PHASE CT PRIMARY setpoint are shown below:
Output Relay Setpoints Each output relay setpoint has the Auxiliary Output Relays 3 to 7 associated with it.
Each can be toggled on or off individually, so that any combination of relays can be
activated upon detection of the initiating condition. Output relay configuration type
values are changed by using the 3 to 7 keys. Each key toggles the display between
the corresponding number and a hyphen.
1. Select the
TIME O/C 1 RELAYS (3-7) setpoint message.
2. If an application requires the Phase TOC protection element to operate the
Auxiliary Output 3 relay, select this output relay by pressing the ‘3’ key.
3. Press the ENTER key to store this change into memory. As before, confirmation of
this action will momentarily flash on the display.
The output relay setpoint values are represented by a 1-row, 5-column matrix.
For example, a value of “3---7” activates Auxiliary Relays 3 and 7, while a value
of “34567” activates all five auxiliary relays.
S5 PROTECTION Z PHASE CURRENT Z PHASE TIME OVERCURRENT 1 ZV PHASE
PHASE TIME O/C 1
RELAYS (3-7): -----
PHASE TIME O/C 1
RELAYS (3-7): 3----
NEW SETPOINT
STORED
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Application Example
Text Setpoints Text setpoints accept user-defined character strings as values. They may be
Feeder Management Relay
750/760
comprised of upper case letters, lower case letters, numerals, and a selection of
special characters. The editing and storing of a text value is accomplished with the
use of the ENTER, VA L U E , and ESCAPE keys.
For example:
1. Move to message
message. The name of this user defined input will be changed in this example
from the generic “User Input A” to something more descriptive.
USER INPUT A NAME:
User Input A
2. If an application is to be using the relay as a substation monitor, it is more
informative to rename this input ‘Substation Monitor’. Press the ENTER key and a
solid cursor () will appear in the first character position.
USER INPUT A NAME:
ser Input A
3. Press the VA L U E keys until the character “S” is displayed in the first position. Now
press the ENTER key to store the character and advance the cursor to the next
position. Change the second character to a “u” in the same manner. Continue
entering characters in this way until all characters the text “Substation Monitor”
are entered. Note that a space is selected like a character. If a character is
entered incorrectly, press the ENTER key repeatedly until the cursor returns to
the position of the error. Re-enter the character as required. Once complete,
press the MESSAGE X key to remove the solid cursor and view the result. Once a
character is entered by pressing the ENTER key, it is automatically saved in flash
memory as a new setpoint.
USER INPUT A NAME:
Substation Monitor
S3 LOGIC INPUTS ZV USER INPUT A Z USER INPUT A NAME setpoint
Getting Started
Application Example
Description The 750 and 760 relays contain many features designed to accommodate a wide
range of applications. This chapter is provided to guide you, the first time user,
through a real-world application. The following step-by-step installation example,
provides you with a quick and convenient way of becoming familiar with the relay.
The following example is only one of many possible applications of the 750/760
relay. Important points to keep in mind before developing settings for any
multifunction numerical relay like the 750/760 are as follows:
• Gather system data, including, but not limited to:
– CT primary and secondary ratings for all CTs used to feed the relay
– VT primary and secondary ratings for both the bus and line VTs
– System frequency
– System phase sequence
• Define the protection elemen ts that will be enabled. Prepare a list of protection
functions including the following information. By default, all the protection functions must be assumed Disabled:
– pickup parameter
– operating curve (if applicable)
– time dial or multiplier
– any additional intentional time delay
– directionality (if applicable)
• Define how many output contacts will be energized in response to a given pro-
tection function. Note that the 750/760 relay can be programmed to trip and, at
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Getting Started
Application Example750/760
Feeder Management Relay
the same time, to energize one, a combination, or all five auxiliary relays during
the process.
• Define if the output relays will be set as fail-safe type.
• Define if the 750/760 will be used to close the breaker. If that will be the case,
gather information on the conditions that will be used to verify synchronism.
• Define if the relay will be used to monitor the status of the breaker. It is strongly
recommended that the 750/760 always be programmed to monitor breaker status by means of a digital input connected to the one of the 750/760 logic inputs.
Use an auxiliary contact from the breaker either a normally open contact, 52a,
which is normally in open position when the breaker is open, or a normally
closed contact, 52b, which is in closed position when the breaker is open. A
combination of both can also be utilized, adding the capability for monitoring
pole discrepancy, an indication of a potential mechanical problem within the
main contact mechanism of the breaker.
• If the relay will be used to respond to logic inputs, prepare a list including:
– logic input name
– condition by which the logic input would be considered asserted
– function that the logic input will initiate within the 750/760.
• If the relay will be used to perform Monitoring functions and act upon certain
conditions, gather information such as:
– minimum and maximum values
– alarm and trip values
– time delays
– demand method to be used
– breaker timings
• It is important to familiarize yourself with the relay control functions before setting up the relay. Some control functions such as the Transfer scheme, which
takes automatic control of the auxiliary outputs, or the autorecloser that uses
the auxiliary outputs for specific pre-defined functions, can have an unwanted
effects in the performance of other functions within the relay.
To start, simply power on the unit, and follow the instructions in this tutorial. The
example assumes the following system characteristics. It also assumes that relay
setpoints are unaltered from their factory default values.
Refer to the following figures for schematics related to this application example.
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Application Example
Feeder Management Relay
750/760
Getting Started
FIGURE 1–1: Typical Three-Line Diagram
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Getting Started
Application Example750/760
Feeder Management Relay
FIGURE 1–2: Typical Connection Diagram
1–14
RS485 SERIAL NETWORK
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Page 23
Application Example
Feeder Management Relay
750/760
Getting Started
FIGURE 1–3: Typical Control Diagram
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Getting Started
Application Example750/760
Feeder Management Relay
FIGURE 1–4: Typical Breaker Control Diagram
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Application Example
Feeder Management Relay
750/760
Getting Started
FIGURE 1–5: Typical Relay Control Diagram
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Getting Started
Feeder Management Relay
Application Example750/760
• Power System Data
a) System: 3
b) Frequency: 60 Hz
c) Line-to-line voltage: 13.8 kV
d) Maximum current: 600 A
The above data will be used to set the relay system parameters.
• Control System Requirements
a) All protection elements used are to trip the breaker.
b) Breaker position monitoring via 52b contact only.
c) Only current metering is required.
d) Contact Inputs: Remote open and close contacts from RTU.
e) Remote/local selection from panel hand switch. Reset from RTU.
f) Alarm after 100 second delay from substation monitor. This is normally used
to signal the remote center when someone has gained access to the substation.
g) Contact Outputs:
– Trip and close to breaker control circuit (trip and close relays).
– Relay failure alarm to RTU (self-test warning, no programming req’d).
– Alarm contact to RTU (setup in User Function for “Substation Monitor”)
– No data communications to other equipment.
The above data will be used to set the output relays to achieve breaker control
and to set digital inputs for breaker status, remote operations, remote status,
and alarm indication. The example assumes that the communications between
the station and the master control center will be done by the RTU. Alarms,
status indication, and breaker commands will be hard-wired from the relay to
the RTU. Please note that, similar information could be exchanged between the
RTU and the relay via an RS485 or RS422 serial link using Modbus R TU protocol.
Refer to GE Publication GEK-106473: 750/760 Communications Guide for
additional information.
• Instrument Transformer Data
a) Bus VTs: 2 × Delta connected, ratio = 14.4 kV:120 V
b) Phase CTs: 3 × Wye connected, ratio = 600:5 A
The above data will be used to set the relay system parameters, such as CT and
VT connections, VT secondary voltage, and CT and VT primary to secondary
ratios.
•Phase Protection Settings
a) Time Overcurrent 1 (51P1): Curve Shape = Moderately Inverse; Pickup =
840 A; Multiplier = 20.2
b) Instantaneous Overcurrent 1 (50P1): Pickup = 840 A; Phases Required =
Any Two; Delay = 0 s
c) Instantaneous Overcurrent 2 (50P2): Pickup = 10100 A; Phases Required =
Any Two; Delay = 0 s
• Neutral Protection Settings
a) Time Overcurrent 1 (function 51N1):
– Curve shape = Moderately Inverse
– Pickup = 120 A
– Multiplier = 10
b) Instantaneous Overcurrent 1 (function 50N1):
– Pickup = 120 A
– Phases required = Any two
– Delay = 0 seconds
Φ, 4 wire
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Application Example
Feeder Management Relay
c) Instantaneous Overcurrent 2 (function 50N2):
– Pickup = 2000 A
– Phases required = Any two
– Delay = 0 seconds
The above data will be used to configure the relay protection. In this example,
the relay will be used for Phase and Neut r al Overcurrent protection only; t hat is,
functions 51P1, 50P1, 50P2, 51N1, 50N1, and 50N2.
In this manual, Neutral Overcurrent is to the residual current, calculated from
the currents measured at the phase CT inputs: terminals G7-H7 for phase A,
G8-H8 for phase B and G9-H9 for phase C. Since it is a calculated value, it
cannot be used to generate oscillography. Ground Overcurrent refers to the
current measured at terminals G10-H10, or at terminals G3-H3 for Sensitive
Ground Overcurrent, when the relay is fitted to measure sensitive ground
current.
You should now be familiar with maneuvering through and editing setpoints. As
such, we will now limit our discussion to just the values that must be programmed,
in order to meet the requirements of the example application. Any setpoints not
explicitly mentioned should be left at the factory default value.
S2 System Setpoints The S2 setpoints page contains setpoints for entering the characteristics of the
equipment on the feeder electrical syst em. I n our ex ample, these c har acteris tics are
specified under the Power System Data and Instrument Transformer Data headings
in the previous sub-section. From this information and the resulting calculations,
program the page S2 setpoints as indicated.
For current transformers, make the following change in the
CURRENT SENSING setpoints page:
PHASE CT PRIMARY: “600 A”
Since the example does not contemplate a ground CT, the setpoints for
PRIMARY, and SENSTV GND CT can be left unchanged. For additional information refer
to Current Sensing on page 5–17.
For voltage transformers, make the following changes in the
BUS VT SENSING setpoints page:
VT CONNECTION TYPE: “Delta”
NOMINAL VT SECONDARY VOLTAGE: “115.0 V”
(for a 138 kV system, 13.8 kV / 120 = 115 V)
VT RATIO: “120:1” (14.4 kV VT
primary
/ 120 V VT
secondary
For the case where Bus VTs are connected in Wye, the system settings are:
VT CONNECTION TYPE: “Wye”
NOMINAL VT SECONDARY VOLTAGE: “66.4 V” (the phase-to-neutral voltage must be
entered. For a 13.8 kV system, we have 13.8kV ø-ø
7.97kV / 120 = 66.4 V)
VT RATIO: “120:1” (14.4 kV VT
primary
/ 120V VT
secondary
For additional information, refer to Bus VT Sensing on page 5–17.
The 750/760 was designed to display primary system values. Current and voltage
measurements are performed at secondary levels, which the relay transforms to
primary values using CT and VT ratios, as well as nominal secondary values.
Configuring the relay for current measurement is simple and it only requires setting
the CT ratios. CT inputs can be 1 A or 5 A and must be specified when the relay is
purchased. There is additional flexibility with regards to the VT inputs, as nominal
values are not required before the relay is ordered; therefore, more settings are
needed to prepare the relay for voltage measurements.
Make the following change in the
S2 SYSTEM SETUP ZV POWER SYSTEM setpoints page
to reflect the power system:
NOMINAL FREQ: “60 Hz”
For additional information, refer to Power System on page 5–18.
S2 SYSTEM SETUP Z
S2 SYSTEM SETUP ZV
)
≡ 7.97kV ø-N; therefore,
)
750/760
Getting Started
GND CT
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Feeder Management Relay
Application Example750/760
Getting Started
S3 Logic Inputs
Setpoints
The S3 setpoints page is for entering the characteristics of the logic inputs. In our
example, these characteristics are specified under the Control System Requirements
heading. Program the S3 setpoints as indicated.
To properly configure the relay to respond to digital inputs, they need to be defined
as follows:
1. The digital inputs should be re-named. Changing the default names to meaningful names is strongly recommended so they can be easily identified in the LCD
and in event reports.
2. The asserted logic must be identified. Refer to S3 Logic Inputs on page 5–19 for
additional information.
3. The functionality of the logic inputs must be defined. Note that a logic input can
be utilized for more then one application.
If step 3 is not done, the relay will not perform any function, even if the logic input
is defined and the asserted logic is met. The last two steps use the following
setpoints pages:
•
S3 LOGIC INPUTS ZV BREAKER FUNCTIONS for breaker status.
•
S3 LOGIC INPUTS ZV CONTROL FUNCTIONS for local/remote operations, cold load
pick up, and setpoint group changes.
•
S3 LOGIC INPUTS ZV USER INPUTS to energize output relays adding time delay.
•
S3 LOGIC INPUTS ZV BLOCK FUNCTION to block protection functions other than
overcurrent functions
•
S3 LOGIC INPUTS ZV BLOCK OC FUNCTIONS to block overcurrent functions.
•
S3 LOGIC INPUTS ZV TRANSFER FUNCTIONS to set inputs that will work with the
automatic transfer scheme.
•
S3 LOGIC INPUTS ZV RECLOSER FUNCTIONS (760 relay only) to set inputs to work
with the autorecloser functions.
•
S3 LOGIC INPUTS ZV MISC FUNCTIONS to trigger oscillography, fault simulation, and
start demand intervals.
For breaker position monitoring, enter the following values in the
LOGIC INPUTS SETUP page:
INPUT 2 NAME: “Brkr Position (52b)”
INPUT 2 ASSERTED LOGIC: “Contact Close”
Then, to define the functionality of the logic input, enter the following value in the
LOGIC INPUTS ZV BREAKER FUNCTIONS setpoint page:
52B CONTACT: “Input 2”
S3 LOGIC INPUTS Z
S3
For the Remote Open/Close and Reset RTU contacts, enter the following values in
the
S3 LOGIC INPUTS Z LOGIC INPUTS SETUP setpoints page to define the logic inputs.
Using the MESSAGE T key, find the appropriate logic name message and then define
the logic input asserted logic to complete the logic input definition as follows:
INPUT 3 NAME: “Local Mode”
INPUT 3 ASSERTED LOGIC: “Contact Close”
INPUT 4 NAME: “Remote Open”
INPUT 4 ASSERTED LOGIC: “Contact Close”
INPUT 5 NAME: “Remote Close”
INPUT 5 ASSERTED LOGIC: “Contact Close”
INPUT 6 NAME: “Reset”
INPUT 6 ASSERTED LOGIC: “Contact Close”
Once the Logic Input definitions are completed, it is necessary to define their
functionality by entering the following values in the
FUNCTIONS setpoint page. Using the MESSAGE T key, locate the appropriate logic
S3 LOGIC INPUTS ZV CONTROL
function and select the corresponding logic input to perform the function.
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Application Example
750/760
Feeder Management Relay
LOCAL MODE: “Input 3”
RESET: “Input 6”
REMOTE OPEN: “Input 4”
REMOTE CLOSE: “Input 5”
If, for example, the same logic input would be needed to perform the functionality of
Close and Reset, then the following should have been entered:
RESET: “Input 5”
REMOTE CLOSE: “Input 5”
To setup an Alarm-after-Delay input, make the following changes to the
INPUTS ZV USER INPUT A setpoints page. Press the MESSAGE T key after each setpoint
S3 LOGIC
is completed to move to the next message.
USER INPUT A NAME: “Substation Monitor”
USER INPUT A SOURCE: “Input 1”
USER INPUT A FUNCTION: “Alarm”
USER INPUT A RELAYS (3-7): “3----”
USER INPUT A DELAY: “100.00 s”
S5 Protection Setpoints The S5 Protection setpoints page contains setpoints for entering protection element
characteristics. In our example, these characteristics are specified under the
PROTECTION Z PHASE CURRENT and S5 PROTECTION Z NEUTRAL CURRENT headings. From
this data and the resulting calculations, program the page S5 setpoints as indicated.
When setting the relay for the first time, other setpoints not listed in this example
will be left disabled.
For the Phase Time Overcurrent 1 element, enter the following values in the
PROTECTION Z PHASE CURRENT Z PHASE TIME OVERCURRENT 1 page. Press the MESSAGE T
key after each setpoint is completed to move to the next message.
PHASE TIME OC 1 FUNCTION: “Trip”
PHASE TIME OC 1 PICKUP: “1.40 x CT” (calculated as 840 A pickup / 600 A primary)
PHASE TIME OC 1 CURVE: “Mod Inverse”
PHASE TIME OC 1 MULTIPLIER: “20.20”
PHASE TIME OC 1 RESET: “Instantaneous”
For the Phase Instantaneous Overcurrent 1 element, enter the following values in
the
S5 PROTECTION Z PHASE CURRENT ZV PHASE INST OVERCURRENT 1 setpoints page.
Press the MESSAGE T key after each setpoint is completed to move to the next
message.
PHASE INST OC 1 FUNCTION: “Trip”
PHASE INST OC 1 PICKUP: “1.40 x CT” (calculated as 840 A pickup / 600 A primary)
PHASE INST OC 1 DELAY: “0.00 s”
PHASES REQUIRED FOR OPERATION: “Any Two”
For the Phase Instantaneous Overcurrent 2 element, enter the following values in
the
S5 PROTECTION Z PHASE CURRENT ZV PHASE INST OVERCURRENT 2 setpoints page.
Press the MESSAGE T key after each setpoint is completed to move to the next
message.
PHASE INST OC 2 FUNCTION: “Trip”
PHASE INST OC 2 PICKUP: “16.83 x CT” (from 10100 A pickup / 600 A primary)
PHASE INST OC 2 DELAY: “0.00 s”
PHASES REQUIRED FOR OPERATION: “Any Two”
For the Neutral Time Overcurrent 1 element, enter the following values in the
PROTECTION ZV NEUTRAL CURRENT Z NEUTRAL TIME OVERCURRENT 1 page. Press the
MESSAGE T key after each setpoint is completed to move to the next message.
NEUTRAL TIME OC 1 FUNCTION: “Trip”
NEUTRAL TIME OC 1 PICKUP: “0.20 x CT” (from 120 A pickup / 600 A primary)
NEUTRAL TIME OC 1 CURVE: “Mod Inverse”
NEUTRAL TIME OC 1 MULTIPLIER: “10.00”
NEUTRAL TIME OC 1 RESET: “Instantaneous”
Getting Started
S5
S5
S5
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Getting Started
Feeder Management Relay
Commissioning750/760
For the Neutral Instantaneous Overcurrent 1 element, enter the following values in
the
S5 PROTECTION ZV NEUTRAL CURRENT ZV NEUTRAL INST OVERCURRENT 1 setpoints
page. Press the MESSAGE T key after ea ch se tp oint is co mp lete d t o move to th e nex t
message.
NEUTRAL INST OC 1 FUNCTION: “Trip”
NEUTRAL INST OC 1 PICKUP: “0.20 x CT” (from 120 A pickup / 600 A primary)
NEUTRAL INST OC 1 DELAY: “0.00 s”
For the Neutral Instantaneous Overcurrent 2 element, enter the following values in
the
S5 PROTECTION ZV NEUTRAL CURRENT ZV NEUTRAL INST OVERCURRENT 2 setpoints
page. Press the MESSAGE T key after ea ch se tp oint is co mp lete d t o move to th e nex t
message.
NEUTRAL INST OC 2 FUNCTION: “Trip”
NEUTRAL INST OC 2 PICKUP: “3.33 x CT” (from 2000 A pickup / 600 A primary)
NEUTRAL INST OC 2 DELAY: “0.00 s”
The Ground Overcurrent element is disabled by entering the following values in the
S5 PROTECTION ZV GROUND CURRENT ZV GROUND TIME OVERCURRENT setpoints page:
GROUND TIME O/C FUNCTION: “Disabled”
GROUND INST O/C FUNCTION: “Disabled”
The Negative Sequence Overcurrent elements is disabled by entering the following
value s in the
NEG SEQ TIME OVERCURRENT Z NEG SEQ TIME OC FUNCTION: “Disabled”
NEG SEQ INST OVERCURRENT Z NEG SEQ INST OC FUNCTION: “Disabled”
S5 PROTECTION ZV NEGATIVE SEQUENCE setpoints page:
Installation Now that programming for the sample application is complete, the relay should be
put in the Ready state. Note that the relay is defaulted to the Not Ready state when
it leaves the factory. A minor self-test warning message informs the user that the
750/760 has not yet been programmed. If this warning is ignored, protection is
active and will be using factory default setpoints. The Relay In Service LED Indicator
will be on.
The following message indicates that the relay is in the Not Ready state:
SELF-TEST WARNING
Relay Not Ready
Move to the
put the relay in the Ready state, press the VA L U E S key until the
displayed and press ENTER. Enter “Yes” at the
Service LED Indicator will now turn on and the
Ready
S1 RELAY SETUP ZV INSTALLATION Z 750 OPERATION setpoint message. To
READY message is
ARE YOU SURE? prompt. The Relay In
SELF TEST WARNING: Relay Not
diagnostic message will disappear.
Commissioning
Extensive commissioning tests are available in Chapter 7: Commissioning.
Commissioning tables for recording required settings are available in Microsoft Excel
format from the GE Multilin website at http://www.GEmultilin.com
contains additional technical papers and FAQs relevant to the 750/760 Feeder
Management Relay.
. The website also
1–22
http://www.GEmultilin.com
GE Multilin
Page 31
Overview
Feeder Management Relay
750/760
2 Introduction
Introduction
Overview
Description The 750/760 Feeder Management Relays are microprocessor-based units intended
for the management and primary protection of distribution feeders, as well as for
the management and backup protection of buses, transformers, and transmission
lines. The 760 relay is particularly suited to overhead feeders, where automatic
reclosing is normally applied.
Each relay provides protection, control, and monitoring functions with both local and
remote human interfaces. They also display the present trip/alarm conditions, and
most of the more than 35 measured system parameters. Recording of past trip,
alarm or control events, maximum demand levels, and energy consumption is also
performed.
These relays contain many innovative features. To meet diverse utility standards
and industry requirements, these features have the flexibility to be programmed to
meet specific user needs. This flexibility will naturally make a piece of equipment
difficult to learn. To aid new users in getting basic protection operating quickly,
setpoints are set to typical default values and adv anced featur es are di sabled. T hese
settings can be reprogrammed at any time.
Programming can be accomplished with the front panel keys and display. Due to the
numerous settings, this manual method can be somewhat laborious. To simplify
programming and provide a more intuitive in terface, setpoints can be entered with a
PC running the EnerVista 750/760 Setup software provided with the relay. Even with
minimal computer knowledge, this menu-driven softw are provides easy access to all
front panel functions. Actual values and setpoints can be displayed, altered, stored,
and printed. If settings are stored in a setpoint file, they can be downloaded at any
time to the front panel program port of the relay via a computer cable connected to
the serial port of any personal computer.
A summary of the available functions and a single-line diagram of protection and
control features is shown below. For a complete understanding of each feature
operation, refer to Chapter 5: Setpoints. The logic diagrams include a reference to
every setpoint related to a feature and show all logic signals passed between
individual features. Information related to the selection of settings for each setpoint
is also provided.
GE Multilin
http://www.GEmultilin.com
2–1
Page 32
Feeder Management Relay
Overview750/760
Introduction
PROTECTION / CONTROL
ANSI
Bus / Line Undervoltage
27
Negative Sequence Voltage
47
Phase/Neutral/Gnd/Neg Seq/Sens Gnd Inst O/C
50
Phase/Neutral/Gnd/Neg Seq/Sens Gnd Time O/C
51
Bus Overvoltage/Neutral Displacement
59
Phase/Neutral/Neg Seq/Sens Gnd/Gnd Directional Control
67
Bus Underfrequency/Rate of Change
81
Undervoltage Automatic Restoration
Underfrequency Automatic Restoration
Breaker Failure with Current Superv.
Bus Transfer
Programmable Logic Inputs
Multiple Setpoint Groups
MONITORING / CONTROL
Synchrocheck
25
Phase/Neutral Current Level
50
Power Factor
55
Autoreclose (760 only)
79
Overfrequency
81
Breaker Open/Close
Manual Close Feature Blocking
Cold Load Pickup Feature Blocking
Breaker Operation Failure
Trip/Close Circuit Failure
Total Breaker Arcing Current
VT Failure
Demand (A, MW, Mvar, MVA)
Analog Input
Event Recording
Analog Output
Fault Locator
Trip Counter
FIGURE 2–1: Summary of Features
Capacitor
FEEDER
Radial
Two-ended
BUS
Transfer
Backup
Backup
Backup
TRANSFORMER
LINE
826712A1.CDR
2–2
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GE Multilin
Page 33
Theory of Operation
Feeder Management Relay
750/760
SOURCE
Bus VT
Breaker
Line VT
47
Calc.
V2
Calc.
-Vo
OUTPUTS
Trip Relay
Close Relay
5 Auxiliary Relays
Self-Test Warning Relay
8 Analog Outputs
CONTROL
Synchronism Check
Cold Load Pickup
Manual Close
Undervoltage Restoration
Underfrequency Restoration
Transfer
Auto Reclose (760)
MONITOR
Power Factor
Demand
Tripping
Arcing
Fault Locator
Analog Input
Overfrequency
VT Failure
Event Recorder
Oscillograph
Data Logger
COMMUNICATIONS
1 x RS232
2 x RS485 OR
1 x RS422
Modbus RTU
DNP 3.0
Introduction
N
dcmA
:
:
Trip
52
Close
1
3
Level
Coil Monitors
Calc.
3Io
1+2
Rate
27
Calc.
1+2
Breaker Operation
27
3+4
50
I
BF
2
OPERATING CURRENT
SENSITIVE GROUND
OPERATING CURRENT
59
50P
Level
GROUND
Feeder Management Relay
25
55
50P
Demand
1+2
50N
Level
Calc.
V
Calc.
V
46/50
50N
1+2
50G
50SG
Calc.
2
1
I
1
Control
Control
Control
81U
1+2
750/760
81
810
Decay
Phase A only
VT
Fail
Current
Supervision
Zone
Coordination
Calc.
79X
I
2
760 Only
46/51
51N
1+2
51G
51SG
46/67
67N
67G
67SG
50P
1+2
Calc.
3Vo
59N
Control
51V
51P
1+2
POLARIZING CURRENT*
¨
67P
Description Relay functions are controlled by two processors: a Motorola 68332 32-bit
Current and Voltage
Waveform Capture
Control
* POLARIZING CURRENT AND GND CURRENT
ARE MUTUALLY EXCLUSIVE SINCE BOTH USE
THE SAME RELAY CT INPUT TERMINALS
818840AD.dwg
FIGURE 2–2: Functional Block Diagram
Theory of Operation
microprocessor measures all analog signals and logic inputs, outputs all analog
signals, and controls all output relays; an Intel 80C186 16-bit microprocessor reads
all user input including communications, and outputs to the faceplate display and
LEDs. The processors pass information to each other via an RS485 serial
communications channel. The remainder of this section describes the algorithms
and operations that are critical to protection elements.
Current and voltage transformers (CTs and VTs) are used to scale-down the
incoming current and voltage signals from the source instrument transformers. The
current and voltage signals are then passed through a 400 Hz low pass anti-aliasing
filter. All signals are then simultaneously captured by sample and hold buffers to
ensure there are no phase shifts. The signals are converted to digital values by a
12-bit A/D converter before finally being passed on to the 68332 CPU for analysis.
Both current and voltage are sampled sixteen times per power frequency cycle with
frequency tracking control. These ‘raw’ samples are calibrated in software and then
placed into the waveform capture buffer thus emulating a fault recorder. The
waveforms can be retrieved from the relay via the EnerVista 750/760 Setup
software for display and diagnostics.
GE Multilin
http://www.GEmultilin.com
2–3
Page 34
Introduction
Theory of Operation750/760
Feeder Management Relay
Frequency Tracking Frequency measurement is done by measuring the time between zero crossings of
the Bus VT A and Line VT voltage inputs. Both signals are passed through a 72 Hz
low pass filter to prevent false zero crossings. Frequency readings are discarded if
the rate of change between two successive cycles is greater than 10 Hz/second. This
prevents momentary false frequency readings due to noise, phase reversals, or
faults.
Frequency tracking utilizes the measured frequency to set the sampling rate for
current and voltage which results in better accuracy for the FFT algorithm for offnominal frequencies. Also, sampling is synchronized to the Va-x voltage zero
crossing which results in better co-ordination for multiple 750/760 relays on the
same bus. If a stable frequency signal is not available then the sampling rate
defaults to the nominal system frequency.
Phasors, Transients,
and Harmonics
Current waveforms are processed once every cycle wi th a DC Offset Filter and a Fast
Fourier Transform (FFT) to yield phasors at the fundamental power system
frequency. The resulting phasors have fault current transients and all harmonics
removed. This results in an overcurrent relay that is extremely secure and reliable
and one that will not overreach. The following diagram illustrates the signal
processing performed on the AC current inputs:
996709A1.CDR
Processing of AC
Current Inputs
The DC Offset Filter is an infinite impulse response (IIR) digital filter which removes
the DC component from the asymmetrical current present at the moment a fault
occurs. This is done for all current signals used for overcurrent protection; voltage
signals bypass the DC Offset Filter. The filter results in no overreach of the
overcurrent protection; unfortunately, the filter also causes slower overcurrent
response times (0 to 50 ms) for faults marginally over the pickup level.
The Fast Fourier Transform (FFT) uses exactly one cycle of samples to calculate a
phasor quantity which represents the signal at the fundamental frequency only; all
harmonic components are removed. Further explanation of the FFT is beyond the
scope of this discussion but can be found in any text on signal analysis. All
subsequent calculations (e.g. RMS, power, demand, etc.) are based upon the
current and voltage phasors so the resulting values do not have any harmonic
components either.
Protection Elements All protection elements are processed once every cycle to determine if a pickup has
occurred or a timer has expired. The protection elements use RMS current/voltage
based on the magnitude of the phasor; hence, protection is impervious to both
harmonics and DC transients. Timing is not affected by system frequency.
Logic Inputs Contact inputs are de-bounced to eliminate false operations due to noise. The inputs
must be in the same state for three consecutive readings spaced evenly over one
power frequency cycle before a new state is recognized.
2–4
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GE Multilin
Page 35
Theory of Operation
Feeder Management Relay
750/760
Introduction
FIGURE 2–3: Hardware Block Diagram
GE Multilin
http://www.GEmultilin.com
2–5
Page 36
Introduction
Feeder Management Relay
Order Codes The relay model number will be indicated on the side of the drawout unit. This
Base Unit
Phase Current
Inputs
Zero-Sequence
Current Inputs
Sensitive Ground
Current Input
Control
Power
Analog
Outputs
Breaker
Closed LED
Display/Ethernet
Environmental Protection
Ordering
identification label can be interpreted with the following order code.
TABLE 2–1: 750/760 Order Codes
750– * – * – * – * – * – * – * – *
760– * – * – * – * – * – * – * – *
750 ||||||||
760 ||||||||
P1 | | | | | | |
P5 | | | | | | |
G1 ||||||
G5 ||||||
S1 | | | | |
S5 | | | | |
|
|
LO
|
|
HI
|
A1 | | |
A5 | | |
A10 | | |
A20 | | |
|
|
|
|
|
|
|
|
R
|
|
G
|
B |
E |
T
750 Feeder Management Relay
760 Feeder Management Relay
750 relay
760 relay with autoreclose
1 A phase current inputs
5 A phase current inputs
1 A zero-sequence current inputs
5 A zero-sequence current inputs
1 A sensitive ground current input
5 A sensitive ground current input
25 to 60 V DC;
|
20 to 48 V AC at 48 to 62 Hz
|
88 to 300 V DC;
|
70 to 265 V AC at 48 to 62 Hz
|
Eight (8) 0 to 1 mA analog outputs
Eight (8) 0 to 5 mA analog outputs
Eight (8) 0 to 10 mA analog outputs
Eight (8) 4 to 20 mA analog outputs
Red LED for Breaker Closed
|
indicator
|
Green LED for Breaker Closed
|
indicator
|
Basic display
Enhanced display
Enhanced display with Ethernet
|
Harsh (Chemical) Environment
H
Conformal Coating
Ordering750/760
Example Order Codes 1. The 750-P1-G1-S1-LO-A10-R-B specifies a 750 Feeder Management Relay with
1 A phase, zero-sequence, and sensitive ground current Inputs, low control
power, eight 0 to 10 mA analog outputs, a red LED for the Breaker Closed
indicator, and a basic display.
2. The 760-P5-G5-S5-HI-A20-G-T specifies a 760 Feeder Management Relay with
autoreclose, 5 A phase, zero-sequence, and sensitive ground current inputs,
high control power, eight 4 to 20 mA analog outputs, a green LED for the
Breaker Closed indicator, and enhanced display with Ethernet (10Base-T).
Accessories • DEMO: Metal carry case in which the 750/760 can be mounted
• SR19-1 or SR19-2 PANEL: Single or double cutout 19-inch panels
• RS-232/485: RS232 to RS485 converter box for harsh industrial environments
• 1A and 5A PHASE CTs: 50, 75, 100, 150, 200, 250, 300, 350, 400, 500,
600, 750, and 1000 CT ratios
3
• SR -inch COLLAR: For shallow switchgear, the collar reduces the depth of
• SR 3-inch COLLAR: For shallow switchgear, the collar reduces the depth of the
2–6
--- -
1
8
the relay by 1 3/8 inches
relay by 3 inches.
http://www.GEmultilin.com
GE Multilin
Page 37
Specifications 750/760
Feeder Management Relay
Specifications
Applicability APPLICABILITY
Systems: 3 or 4 wire, 600 kV maximum
Frequency: 25 to 60 Hz nominal
5000 A maximum
(frequency tracking allows
operation from 16 to 65 Hz)
Inputs CONTROL POWER
Options: LO/HI (specify with order)
LO range: 20 to 60 V DC
HI range: 88 to 300 V DC
Power: 25 VA nominal, 35 VA max.
Total loss of voltage ride through time
(0% control power): 16.7 ms
PHASE CURRENT
Source CT: 1 to 50000 A primary,
Relay input: 1 A or 5 A (specify with order)
Burden: < 0.2 VA at 1 or 5 A
Conversion range: 0.01 to 20 × CT
Accuracy: at < 2 × CT: ±0.5% of 2 × CT
Overload withstand: 1 second at 80 × rated
Calculated neutral current errors:
GROUND CURRENT
Source CT: 1 to 50000 A primary,
Relay input: 1 A or 5 A (specify with order)
Burden: < 0.2 VA at 1 or 5 A
Conversion range: 0.01 to 20 × CT
Accuracy: at < 2 × CT: ±0.5% of 2 × CT
Overload withstand: 1 second at 80 × rated
SENSITIVE GROUND CURRENT
Source CT: 1 to 50000 A primary,
Relay input: 1 A or 5 A (specify with order)
Burden: < 0.2 VA at 1 or 5 A
Conversion range: Low end: 0.005 × CT
Accuracy: at < 0.1 × CT: ±0.2% of 1 × CT
Overload withstand: 1 second at 80 × rated
20 to 48 V AC at 48 to 62 Hz
70 to 265 V AC at 48 to 62 Hz
1 or 5 A secondary
(fundamental frequency only)
at ≥ 2 × CT: ±1% of 20 × CT
current; continuous at 3 ×
rated current
3 × phase inputs
1 or 5 A secondary
(fundamental frequency only)
≥ 2 × CT: ±1% of 20 × CT
at
current; continuous at 3 ×
rated current
1 or 5 A secondary
Maximum: 500 A primary
(fundamental frequency only)
at ≥ 0.1 × CT: ±1% of 1 × CT
current; continuous at 3 ×
rated current
BUS AND LINE VOLTAGE
Source VT: 0.12 to 600 kV / 50 to 240 V
Source VT ratio: 1 to 5000 in steps of 0.1
Relay input: 50 to 240 V phase-neutral
Burden: < 0.025 VA at 120 V
or > 576 KW
Maximum continuous: 273 V phase-neutral
(full-scale) at fundamental
frequency only
Accuracy (0 to 40°C): ±0.25% of full scale
(11 to 130 V); ±0.8% of full
scale (130 to 273 V). For open
delta, the calculated phase has
errors 2 times those shown.
LOGIC INPUTS
Inputs: 14 contact and / or virtual
inputs, 6 virtual only
(functions assigned to logic
inputs)
Dry contacts: 1000 Ω maximum ON
resistance (32 V DC at 2 mA
provided by relay)
Wet contacts: 30 to 300 V DC at 2.0 mA
(external DC voltage only)
ANALOG INPUT
Current Input: 0 to 1 mA, 0 to 5 mA, 0 to 10
mA, 0 to 20 mA, or 4 to 20 mA
(programmable)
Input impedance: 375 Ω ± 10%
Conversion range: 0 to 21 mA
Accuracy: ±1% of full scale
TRIP & CLOSE COIL MONITORING
Acceptable voltage range: 20 to 250 V DC
Trickle current: 2 to 5 mA
IRIG-B
Amplitude modulated: 2.5 to 6 Vpk-pk at 3:1
signal ratio
DC shift: TTL
Input impedance: 20 kΩ ±10%
Error: ±1.0 ms
Introduction
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Page 38
Introduction
750/760
Specifications
Feeder Management Relay
Measured Parameters In the following specifications, accuracies are based on less than 2 × CT and
50 to 130 V inputs. The full-scale is defined as follows: Full Scale = 2 × CT at
NOTE
1 × VT
Full Scale
The harmonic components of current and voltage are removed from the input
voltage and current parameters, so all relay measurements based on these
quantities respond to the fundamental component only. To minimize errors, the A/D
process utilizes a sampling rate that is automatically adjusted to be 16 samples per
power frequency cycle when a measurable voltage is available. To prevent
overreaching of overcurrent elements, a digital filter removes the transient DC
component of currents.
CURRENT
Phasors: Phase A RMS current
% of load-to-trip accuracy: ±0.5% of full-
Phase B RMS current
Phase C RMS current
scale
VOLTAGE
Phasors: Phase A-N (A-B) voltage
Accuracy: ±0.25% of full scale
Phase B-N (B-C) voltage
Phase C-N (C-A) voltage
FREQUENCY
Measured: A-N (A-B) bus and line voltage
Range: 16 to 65 Hz
Accuracy: ±0.02 Hz
SYMMETRICAL COMPONENTS
Current level accuracy: ±1.5% of full scale
Voltage level accuracy: ±0.75% of full scale
Current and voltage angle accuracy: ±2°
3Φ POWER FACTOR
Range: 0.00 Lag to 1.00 to 0.00 Lead
Accuracy: ±0.02
3Φ REAL POWER
Range: –3000.0 to 3000.0 MW
Accuracy: ±1% of full scale
3Φ REACTIVE POWER
Range: –3000.0 to 3000.0 Mvar
Accuracy: ±1% of full scale
(see note above)
× .
3
3Φ APPARENT POWER
Range: –3000.0 to 3000.0 MVA
Accuracy: ±1% of full scale (see note
above)
WATT-HOURS
Range: –2.1 × 108 to 2.1 × 108 MWh
Accuracy: ±2% of full scale (see note
above) per hour
VAR-HOURS
Range: –2.1 × 108 to 2.1 × 108 Mvarh
Accuracy: ±2% of full scale (see note
above) per hour
DEMAND RANGE
Phase A/B/C current: 0 to 65535 A
3Φ real power: –3000.0 to 3000.0 MW
3Φ reactive power: –3000.0 to 3000.0 Mvar
3Φ apparent power: –3000.0 to 3000.0 MVA
DEMAND MEASUREMENT
Thermal exponential, 90% response time
(programmed):
5, 10, 15, 20, 30, or 60 min.
Block interval / rolling demand, time interval
(programmed):
5, 10, 15, 20, 30, or 60 min.
Accuracy: ±2% of full scale
(see note above)
Protection Elements PHASE / NEUTRAL / GROUND /
NEGATIVE SEQUENCE TIME OVERCURRENT
Pickup level: 0.05 to 20.00 × CT in steps of
Dropout level: 97 to 98% of pickup
Curves: ANSI Extremely/Very/
Curve multiplier: 0 to 100. 00 in steps of 0.01
Reset type: Instantaneous/Linear
Level accuracy: per current input
Timing accuracy: ±3% of trip time or ±40
2–8
0.01
Moderately/Normally Inverse,
Definite Time (0.1 s base
curve), IEC Curve A/B/C and
Short, FlexCurve™ A/B
(programmable curves), IAC
Extreme/Very/Inverse/Short
(I
is 3 × input error)
2
ms (whichever is greater) at
≥ 1.03 × PU
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SENSITIVE GROUND TIME OVERCURRENT
Pickup level: 0.005 to 1.000 × CT in steps of
0.001
Dropout level: 97 to 98% of Pickup
Curves: ANSI Extremely/Very/
Moderately/Normally Inverse,
Definite Time (0.1 s base
curve), IEC Curve A/B/C and
Short, FlexCurve™ A/B
(programmable curves), IAC
Extreme/Very/Inverse/Short
Curve multiplier: 0 to 100.00 in steps of 0.01
Reset type: Instantaneous/Linear
Level accuracy: per sensitive ground current
input
Timing accuracy: ±3% of trip time or ±40
ms (whichever is greater) at
≥ 1.03 × PU
GE Multilin
Page 39
Specifications 750/760
Feeder Management Relay
VOLTAGE RESTRAINED PHASE TIME
OVERCURRENT
Pickup adjustment: Modifies pickup from
0.10 to 0.90 × VT nominal in a
fixed line relationship
PHASE / NEUTRAL / GROUND /
NEGATIVE SEQUENCE INSTANTANEOUS OVERCURRENT
Pickup level: 0.05 to 20.00 × CT in steps of
Dropout level: 97 to 98% of pickup
Time delay: 0 to 600.00 s in steps of 0.01
Level accuracy: per phase / neutral / ground
Timing accuracy at 0 ms time delay (no
Timing accuracy at non-zero time delay:
Phases: Any one, any two, or all three
0.01
current input (I2 is 3 × phase
input error)
intentional delay): 50 ms max.
for relay contacts, 45 ms max.
for solid-state output
delay accuracy = 0 to 20 ms
(programmable) phases must
operate for output (not for I2)
SENSITIVE GROUND INSTANTANEOUS OVERCURRENT
Pickup level: 0.005 to 1.000 × CT in steps of
Dropout level: 97 to 98% of pickup
Time delay: 0 to 600.00 s in steps of 0.01
Level accuracy: per sensitive ground current
Timing accuracy at 0 ms time delay (no
Timing accuracy at non-zero time delay:
0.001
input
intentional delay): 50 ms max.
for relay contacts, 45 ms max.
for solid-state output
delay accuracy = 0 to 20 ms
PHASE DIRECTIONAL
Relay Connection: 90° (quadrature)
Polarizing Voltage: Vbc (phase A); Vca
MTA: 0 to 359° in steps of 1
Angle Accuracy: ±2°
Operation Delay: 25 to 40 ms
(phase B); Vab (phase C)
NEUTRAL DIRECTIONAL
Polarized by voltage, current, or both
voltage and current. For voltage ele-
NOTE
ment polarizing, the source VTs must
be connected in Wye.
Polarizing voltage: –Vo
Polarizing current: Ig
MTA: 0 to 359° in steps of 1
Angle accuracy: ±2°
Operation delay: 25 to 40 ms
GROUND / SENSITIVE GROUND
DIRECTIONAL
Polarized by voltage, current, or both
voltage and current. For voltage ele-
NOTE
ment polarizing, the source VTs must
be connected in Wye.
Polarizing voltage: –Vo
Polarizing current: Ig
MTA: 0 to 359° in steps of 1
Angle accuracy: ±2°
Operation delay: 25 to 40 ms
BUS / LINE UNDERVOLTAGE
Minimum voltage: > programmable
Pickup level: 0 to 1.25 × VT in steps of 0.01
Dropout level: 102 to 103% of pickup
Curve: Definite Time or Inverse Time
Time delay: 0 to 6000.0 s in steps of 0.1
Phases: Any one, any two, or all three
Level accuracy: per voltage input
Timing accuracy: ±100 ms
threshold from 0.00 to 1.25 ×
VT in steps of 0.01
(programmable) phases must
operate for output (Bus
Undervoltage only)
OVERVOLTAGE
Pickup level: 0 to 1.25 × VT in steps of 0.01
Dropout level: 97 to 98% of pickup
Time delay: 0.0 to 6000.0 s in steps of 0.1
Phases: Any one, any two, or all three
Level accuracy: per voltage input
Timing accuracy: ±100 ms
(Definite Time)
(programmable) phases must
operate for output
NEGATIVE SEQUENCE VOLTAGE
Pickup level: 0 to 1.25 × VT in steps of 0.01
Dropout level: 97 to 98% of pickup
Time delay: 0 to 6000.0 s in steps of 0.1
Level accuracy: 3 × voltage input error
Timing accuracy: ±100 ms
(Definite Time / Inverse Time)
UNDERFREQUENCY
Minimum voltage: 0 to 1.25 × VT in steps of
Pickup level: 20 to 65 Hz in steps of 0.01
Dropout level: Pickup + 0.03 Hz
Time delay: 0 to 600.00 s in steps of 0.01
Level accuracy: ±0.02 Hz
Timing accuracy:±25 ms at 60 Hz;
0.01 in Phase A
(Definite Time)
±30 ms at 50 Hz
BREAKER FAILURE
Pickup level: 0.05 to 20.0 × CT in steps of
Dropout level: 97 to 98% of pickup
Time delay: 0.03 to 1.00 s in steps of 0.01
Timing accuracy: ±20 ms error
Level accuracy: per CT input
0.01
Introduction
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Page 40
750/760
Feeder Management Relay
Specifications
Introduction
NEUTRAL DISPLACEMENT
Pickup level: 0.00 to 1.25 × VT in steps of
0.01
Dropout level: 97 to 98% of pickup
Curves: ANSI Extremely/Very/
Moderately/Normally Inverse,
Definite Time (0.1 s base
curve), IEC Curve A/B/C and
Short, FlexCurve™ A/B
(programmable curves), IAC
Extreme/Very/Inverse/Short
Curve multiplier: 0 to 100. 00 in steps of 0.01
Reset type: Instantaneous/Linear
Level accuracy: 3 × voltage input error
Timing accuracy: ±50 ms
Monitoring Elements PHASE/NEUTRAL CURRENT
Pickup level: 0.05 to 20.00 × CT in steps of
0.01
Dropout level: 97 to 98% of pickup
Time delay: 0 to 60000 s in steps of 1
(Definite Time)
Level accuracy: per current input
Timing accuracy: ±100 ms
POWER FACTOR
Required voltage: >30% of nominal in all
phases
Pickup level: 0.50 lag to 0.50 lead in steps
of 0.01
Dropout level: 0.50 lag to 0.50 lead in steps
of 0.01
Time delay: 0 to 60000 s in steps of 1
(Definite Time)
Level accuracy: ±0.02
Timing accuracy: ±100 ms
ANALOG INPUT THRESHOLD
Pickup level: 0 to 6553 5 units in steps of 1
Dropout level: 2 to 20% of Pickup
(programmable, under/over)
Time delay: 0 to 60000 s in steps of 1
Level accuracy: ±1%
Timing accuracy: ±100 ms
ANALOG INPUT RATE
Pickup level: –1000 to 1000 units/hour in
steps of 0.1
Dropout level: 97 to 98% of Pickup
Time delay: 0 to 60000.0 s in steps of 1
Level accuracy: ±1%
Timing accuracy: ±100 ms
OVERFREQUENCY
Required voltage: >30% of nominal, phase A
Pickup level: 20.01 to 65.00 Hz in steps of
0.01
Dropout level: Pickup – 0.03 Hz
Time delay: 0.0 to 6000.0 s in steps of 0.1
Level accuracy: ±0.02 Hz
Timing accuracy:±34 ms at 60 Hz;
±40 ms at 50 Hz
REVERSE POWER (IF ENABLED)
Pickup level: 0.015 to 0.600 × rated power
Dropout level: 94 to 95% of pickup
Reset time: less than 100 ms
Level accuracy: see 3Φ Real Power metering
Time delay: 0.0 to 6000.0 s in steps of 0.1
Timing accuracy: ±200 ms (includes Reverse
Power pickup time)
FAULT LOCATOR
Range: –327 to 327 km (or miles)
Memory: stores 10 most recent faults
0 to 65534 ohms
DATA LOGGER
Channels: 8 channels; same parameters
Sample rate: per cycle / per second / per
Trigger source: pickup/trip/dropout, control/
Trigger position: 0 to 100%
Storage: 2 to 16 events with 2048 to
as for analog outputs available
minute / every 5, 10, 15, 20,
30, or 60 minutes
alarm event, logic input,
manual command, or
continuous
256 samples of data
respectively (4096 if
continuous)
TRIP COUNTERS
Accumulates all ground, sensitive ground,
neutral, negative sequence, and phase
overcurrent trips.
DEMAND
Demand accuracies are based on less
than 2 × CT and 50 to 130 V inputs.
NOTE
Measured values: Phase A/B/C current (A),
Measurement type:
Thermal Exponential, 90% response time
Block Interval / Rolling Demand, time
Block Interval with Start Demand Interval
Amps pickup level: 10 to 10000 in steps of 1
MW pkp level: 0.1 to 3000.0 in steps of 0.1
Mvar pkp level: 0.1 to 3000.0 in steps of 0.1
MVA pkp level: 0.1 to 3000.0 in steps of 0.1
Level accuracy: ±2%
3Φ real power (MW), 3Φ
reactive power (Mvar), 3Φ
apparent power (MVA)
(programmed):
5, 10, 15, 20, 30, or 60 min.
interval (programmed):
5, 10, 15, 20, 30, or 60 min.
Logic Input pulses
2–10
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Page 41
Specifications 750/760
Feeder Management Relay
VT FAILURE
Programmable to inhibit dependent features.
BREAKER FAILURE TO OPERATE
Time delay: 30 to 1000 ms in steps of 10
Timing accuracy: 0 to 20 ms error
ACCUMULATED ARCING CURRENT
Pickup level: 1 to 50000 kA2-cycles in steps
of 1
Start delay: 0 to 100 ms in steps of 1
TRIP / CLOSE COIL MONITORS
Detect open trip and close circuits.
PULSED OUTPUT
Pulsed output is 1 second on time and one
second off time after the programmed
interval.
LAST TRIP DATA
Records cause of most recent trip, 4 RMS
currents, and 3 RMS voltages with a 1 ms
time stamp.
Control Elements SYNCHROCHECK
Voltage difference: 0.01 to 100.00 kV in
steps of 0.01
Phase difference: 0 to 100° in steps of 1
Frequency difference: 0.00 to 5.00 Hz in
steps of 0.01
Bypass permissives:
DB & DL
(dead bus and dead line)
LL & DB
(live line and dead bus)
DL & LB
(dead line and live bus)
DL | DB
(dead line or dead bus)
DL X DB
(either dead line or dead bus)
SETPOINT GROUPS
Number of groups: 4
Accessibility: Can be changed from logic
input or through
communications
Included features: TOC Curves, Phase TOC
and IOC, Neutral TOC and IOC,
Ground TOC and IOC, Negative
Sequence OC and Voltage,
Phase Directional, Ground
Directional, Overvoltage,
Undervoltage,
Underfrequency, Breaker
Failure
WAVEFORM CAPTURE
Channels: 4 currents, 3 voltages, 14 logic
input states and 8 output
relays
Sample rate: 16 per cycle
T rigger source: Element pickup/trip/dropout,
control/alarm event, logic
input or manual command
Trigger position: 0 to 100%
Storage: 2 to 16 events with 4096 to
512 samples of data
respectively
EVENT RECORDER
Number of events: 512
Content: event cause, 3 phase current
phasors, 1 ground current
phasor, sensitive ground
current phasors, 3 voltage
phasors, system frequency,
synchronizing voltage,
synchronizing frequency, and
analog input level with a 1 ms
time stamp.
UNDERVOLTAGE RESTORATION
Initiated by: Trip from Undervoltage 1 to 4
Minimum voltage level: 0.00 to 1.25 × VT in
steps of 0.01
Time delay: 0 to 10000 s in steps of 1
Incomplete seq. time: 1 to 10000 min. in
steps of 1
Phases: Any one, any two, or all three
(programmable) phases must
operate for output
Level accuracy: per voltage input
Timing accuracy: ±100 ms
UNDERFREQUENCY RESTORATION
Initiated by: Trip from Underfrequency 1/2
Minimum voltage level: 0.00 to 1.25 × VT in
steps of 0.01
Minimum freq. level: 20.00 to 65.00 Hz in
steps of 0.01
Time delay: 0 to 10000 s in steps of 1
Incomplete seq. time: 1 to 10000 min. in
steps of 1
Level accuracy: Per voltage and frequency
input
Timing accuracy: ±100 ms
MANUAL CLOSE BLOCKING
Operated by: manual close command.
Programmability: Block IOC for a selected
period. raise TOC pickup for a
selected period.
COLD LOAD PICKUP BLOCKING
Operated by: logic input command or
automatically
Programmability: Block IOC for a selected
period; raise TOC pickup for a
selected period.
Introduction
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2–11
Page 42
750/760
Feeder Management Relay
Specifications
Introduction
TRANSFER SCHEME
Applicability: Used for double-bus system
with two normally-closed
incoming and one normallyopen bus tie circuit breaker.
Closing: Automatic closing of the bus
tie breaker after a loss of one
source, with bus decayed
voltage permissive.
Trip: Trips a pre-selected breaker
after the third breaker is
manually closed (prevent
parallel operation).
Outputs ANALOG OUTPUTS
Type: Active
Outputs: 8 Channels; specify one of the
following output ranges when
ordering:
Ranges: 0 to 1 mA, 0 to 5 mA, 0 to 10
mA, 4 to 20 mA
Max. load: 12 kΩ for 0 to 1 mA output,
2.4 kΩ for 0 to 5 mA output,
1.2 kΩ for 0 to 10 mA output,
600 Ω for 4 to 20 mA output
Isolation: Fully isolated
Accuracy: ±1% of full scale
Response: 100% indication in less than 6
power system cycles (100 ms
at 60 Hz)
AUTORECLOSE (760 ONLY)
Reclose attempts: Up to four (4) before
lockout.
Blocking: Each reclose shot can block
IOC and raise TOC Pickup.
Adjustability: Current supervision can adjust
the maximum number of shots
to be attempted.
SOLID STATE TRIP
Make & carry: 15 A at 250 V DC for 500 ms
Output Relays Relay contacts must be considered unsafe to touch when the 750/
WARNING
CONFIGURATION
Number: 8
Type: Form A: Trip (1) and Close (2)
Contacts: silver alloy
Durability: 100 000 operations (at 1800
FORM A CONTACT RATINGS
Applicability: Trip and Close Relays (relays 1
Make: 30 A (per ANSI/IEEE C37.90)
Carry: 20 A continuous
Break (DC): 300 W resistive,
Break (AC): 5000 VA resistive
CPU CO MMUNICATIONS
Baud rate: 300 to 19200 baud
Parity: programmable
Protocol: Modbus RTU or DNP 3.0
Ethernet: 10Base-T RJ45 connector
760 is energized! If the output relay contacts are required for low
voltage accessible applications, it is the customer’s responsibility to
ensure proper insulation levels.
FORM C CONTACT RATINGS
Relays
Form C: Auxiliary Relays 3 to 7
and Self-Test Warning Relay 8
operations/hour) at rated load
and 2)
150 W inductive (L/R = 40 ms)
5000 VA inductive (PF = 0.4)
Applicability: Auxiliary Relays 3 to 7; Self-
Make: 30 A (per ANSI/IEEE C37.90)
Carry: 10 A for 15 seconds
Break (DC): 150 W resistive,
Break (AC): 1250 VA resistive
Test Warning Relay (relay 8)
5 A continuous
90 W inductive (L/R = 40 ms)
500 VA inductive (PF = 0.4)
EEPROM
100000 program/erase cycles max.
CLOCK
Resolution: 1 ms
Modbus TCP/IP
Version 2.0 / IEEE 802.3
Accuracy with IRIG-B:±1 ms
Accuracy without IRIG-B: ±1 minute/month
Supercap backup life: 45 days when control
power is off
2–12
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Page 43
Specifications 750/760
Feeder Management Relay
Physical TEMPERATURE
Operating range: –40°C to +60°C
Ambient storage: –40°C to +80°C
Ambient shipping –40°C to +80°C
At temperatures below –20°C, the
LCD contrast may become impaired.
NOTE
ENVIRONMENTAL
Humidity: up to 90% non-condensing
Pollution degree: 2
IP Rating: 40-X
Te s t i n g TYPE TES TING
The table below lists the 750/760 type tests:
Standard Test Name Level
EIA 485 RS485 Communications Test 32 units at 4000 ft.
IEC 60068-2-30 Relative Humidity Cyclic 55°C at 95% RH
IEC 60068-2-38 Composite Temperature/Humidity 65/–10°C at 93% RH
IEC 60255-5 Dielectric Strength 2300 V AC
IEC 60255-5 Insulation Resistance >100 MΩ / 500 V AC / 10 s
IEC 60255-21-1 Sinusoidal Vibration 2 g
IEC 60255-21-2 Shock and Bump 5 g / 10 g / 15 g
IEC 60255-21-3 Seismic 6 g
IEC 60255-22-1 Damped Oscillatory Burst, 1 MHz 2.5 kV / 1 kV
IEC 60255-22-2 Electrostatic Discharge: Air and Direct 15 kV / 8 kV
IEC 60255-22-3 Radiated RF Immunity 10 V/m
IEC 60255-22-4 Electrical Fast Transient / Burst Immunity 4 kV
IEC 60255-22-5 Surge Immunity 4 kV / 2 kV
IEC 60255-22-6 Conducted RF Immunity, 150 kHz to 80 MHz 10 V/m
IEC 60255-25 Radiated RF Emission Group 1 Class A
IEC 60255-25 Conducted RF Emission Group 1 Class A
IEC 60529 Ingress of Solid Objects and Water (IP) IP40 (front), IP20 (back)
IEC 61000-4-8 Power Frequency Magnetic Field Immunity 30 A/m
IEC 61000-4-9 Pulse Magnetic Field Immunity 1000 A/m
IEC 61000-4-11 Voltage Dip; Voltage Interruption 0%, 40%, 100%
IEEE C37.90.1 Fast Transient SWC ±4 kV
IEEE C37.90.1 Oscillatory Transient SWC ±2.5 kV
IEEE C37.90.3 Electrostatic Discharge: Air and Direct ±15 kV / ±8 kV
CASE
Type: Fully drawout unit (automatic
CT shorts)
Approvals: Meets CE drawout
specifications
Seal: Seal provision
Door: Dust tight door
Mounting: Panel or 19" rack mount
Weight: 7.9 kg (case and relay)
9.4 kg (shipping weight)
Introduction
GE Multilin
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2–13
Page 44
750/760
Feeder Management Relay
Specifications
Introduction
SIMULATION
Programmable pre-fault, fault, and post-fault
parameters simulation modes. Simulation of
circuit breaker and selection of whether or
not to operate outputs relays.
Approvals APPROVALS
ACA: Tick mark
CE: Conforms to IEC 1010-1 / EN
EN: EN 50623
FCC: Part 15; RF Emissions for
IEC: IEC 1010-1
ISO: GE Multilin’s Quality
UL: UL listed for the USA and
Specifications subject to change without notice.
PRODUCTION TESTS
Thermal cycling: Operational test at ambient,
reducing to –40°C and then
increasing to 60°C
Dielectric strength: On CT inputs, VT inputs,
Control Power inputs, Switch
inputs, Coil Supervision
outputs, and Relay outputs
(2 kV AC for 1 minute) to
Safety Ground.
RF Emissions for Australia
50082-2
EMC - CE for Europe
North America
LVD - CE for Europe
Management System is
registered to ISO9001:2000
QMI # 005094
UL #A3775
Canada, E83849
NOTE
It is recommended that all relays must be powered up once per year,
for one hour continuously, to avoid deterioration of electrolytic
NOTE
capacitors and subsequent relay failure.
2–14
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Page 45
Mechanical Installation
Feeder Management Relay
750/760
3 Installation
Mechanical Installation
Drawout Case The 750/760 is packaged in the standard SR series arrangement which consists of a
drawout relay and a companion case. The case provides mechanical protection for
the drawout portion and is used to make permanent electrical connections to
external equipment. Where required, case connectors are fitted with mechanisms,
such as automatic CT shorting, to allow the safe removal of the relay from an
energized panel. There are no electronic components in the case.
FIGURE 3–1: Case Dimensions
To prevent unauthorized removal of the drawout relay, a wire lead seal can be
installed through the slot in the middle of the locking latch. With this seal in place,
the relay cannot be removed. Even though a passcode or setpoint access jumper
can be used to prevent entry of setpoints and still allow monitoring of actual values,
access to the front panel controls may still need to be restricted. As such, a separate
seal can be installed on the outside of the door to prevent it from being opened.
Installation
GE Multilin
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3–1
Page 46
Feeder Management Relay
Installation
Mechanical Installation750/760
DRAWOUT
CASE SEAL
FIGURE 3–2: Drawout Case Seal
Installation The 750/760 can be mounted alone or adjacent to another SR-series unit on a
standard 19-inch rack panel. Panel cutout dimensions for both conditions shown
below. When planning the location of your panel cutout, ensure provision is made
for the front door to swing open without interference to or from adjacent equipment.
FIGURE 3–3: Single and Double Unit Panel Cutouts
Before mounting the relay in the supporting panel, remove the unit from the case.
From the front of the panel, slide the empty case into the cutout. To ensure the front
bezel is flush with the panel, apply pressure to the bezel’s front while bending the
retaining tabs 90°. These tabs are located on the sides and bottom of the case and
appear as shown in the illustration. After bending all tabs, the case will be securely
mounted so that its relay can be inserted. The unit is now ready for panel wiring.
FIGURE 3–4: Mounting Tabs
3–2
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Page 47
Mechanical Installation
Feeder Management Relay
750/760
Unit Withdrawal and
Insertion
CAUTION
TURN OFF CONTROL POWER BEFORE DRAWING OUT OR REINSERTING THE RELAY TO PREVENT MALOPERATION!
CAUTION
If an attempt is made to install a relay i nto a non-mat ching ca se, th e c ase’s
configuration pin will prevent full insertion. Applying a strong force in this
instance will result in damage to the relay and case.
If using an ethernet connection, refer to Ethernet Connection on page 3–4 before
starting the following procedure.
To remove the unit from the case:
1. Open the door by pulling from the top or bottom of its right side. It will rotate to
the left about its hinges.
2. Press upward on the locking latch, which is located below the handle, and hold
in its raised position. The tip of a small screwdriver may prove helpful in this
operation.
FIGURE 3–5: Press Latch Up and Pull Handle
3. With the latch raised, pull the center of the handle outward. Once disengaged,
continue rotating the handle up to the stop position.
Installation
FIGURE 3–6: Rotating Handle to Stop Position
4. When the stop position is reached, the locking mechanism will release. The
FIGURE 3–7: Sliding the Unit out of the Case
GE Multilin
relay will now slide out of the case when pulled from its handle. To free the
relay, it may sometimes be necessary to adjust the handle position slightly.
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3–3
Page 48
Feeder Management Relay
Installation
Ethernet Connection If using the 750/760 with the Ethernet 10Base-T option, ensure that the network
NOTE
CAUTION
Mechanical Installation750/760
To insert the unit into the case:
1. Ensure that the model number on the left side of the relay matches the
requirements of the installation.
2. Raise the locking handle to the highest position.
3. Hold the unit immediately in front of the case and align the rolling guide pins
(near the hinges of the relay’s handle) with the case’s guide slots.
4. Slide the unit into the case until the guide pins on the unit have engaged the
guide slots on either side of the case.
5. Once fully inserted, grasp the handle from its center and rotate it down from the
raised position towards the bottom of the relay.
6. Once the unit is fully inserted the latch will be heard to click, locking the handle
in the final position. The unit is mechanically held in the case by the handle’s
rolling pins, which cannot be fully lowered to the locked position until the
electrical connections are completely mated.
No special ventilation requirements need to be observed during the
installation of the unit. The unit does not require cleaning.
cable is disconnected from the rear RJ45 connector before removing the unit from
the case. This prevents any damage to the connector.
The unit may also be removed from the case with the network cable connector still
attached to the rear RJ45 connector, provided that there is at least 16" of network
cable available when removing the unit from the case. This extra length allows the
network cable to be disconnected from the RJ45 connector from the front of the
switchgear panel. Once disconnected, the cable can be left hanging safely outside
the case for re-inserting the unit back into the case.
The unit may then be re-inserted by first connecting the network cable to the units'
rear RJ45 connector (see step 3 of Unit Withdrawal and Insertion on page 3–3).
Ensure that the network cable does not get caught inside the case while
sliding in the unit. This may interfere with proper insertion to the case
terminal blocks and damage the cable.
FIGURE 3–8: Ethernet Cable Connection
3–4
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Page 49
Mechanical Installation
Feeder Management Relay
750/760
Rear Terminal Layout A broad range of applications are available for the 750/760 relays. As such, it is not
possible to present typical connections for all possible schemes. The information in
this section will cover the important aspects of interconnections, in the general
areas of instrument transformer inputs, other inputs, outputs, communications and
grounding. The figure below shows the rear terminal layout of the 750/760.
Relay contacts must be considered unsafe to touch when system is
WARNING
WARNING
energized! If the customer requires the relay contacts for low voltage
accessible applications, it is their responsibi li ty to ensure proper insulation
levels!
HAZARD may result if the product is not used for its intended purposes.
Installation
FIGURE 3–9: Rear Terminal Layout
The rear terminal assignments are indicated on the following table.
GE Multilin
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3–5
Page 50
Feeder Management Relay
Installation
Mechanical Installation750/760
TABLE 3–1: Rear Terminal Assignments
TERMINAL DESCRIPTION TERMINAL DESCRIPTION
ANALOG INPUT / OUTPUTS OUTPUT RELAYS
A1 ANALOG INPUT + E1 SOLID STATE TRIP OUT +
A2 ANALOG INPUT - E2 1 TRIP RELAY NO
A3 SHIELD (GROUND) E3 2 CLOSE RELAY NO
A4 ANALOG OUTPUT - E4 3 AUXILIARY RELAY NO
A5 ANALOG OUTPUT 1 + E5 3 AUXILIARY RELAY NC
A6 ANALOG OUTPUT 2 + E6 4 AUXILIARY RELAY NC
A7 ANALOG OUTPUT 3 + E7 5 AUXILIARY RELAY NC
A8 ANALOG OUTPUT 4 + E8 5 AUXILIARY RELAY NO
A9 ANALOG OUTPUT 5 + E9 6 AUXILIARY RELAY NC
A10 ANALOG OUTPUT 6 + E10 7 AUXILIARY RELAY NC
A11 ANALOG OUTPUT 7 + E11 7 AUXILIARY RELAY NO
A12 ANALOG OUTPUT 8 + E12 8 SELF-TEST WARNING RELAY NC
COMMUNICATION OUTPUT RELAYS
B1 COM1 RS485 + F1 SOLID STATE TRIP OUT B2 COM1 RS485 - F2 1 TRIP RELAY COM
B3 COM1 RS485 COM F3 2 CLOSE RELAY COM
B4 COM1 RS422 TX + F4 3 AUXILIARY RELAY COM
B5 COM1 RS422 TX - F5 4 AUXILIARY RELA Y NO
B6 COM2 RS485 + F6 4 AUXILIARY RELAY COM
B7 COM2 RS485 - F7 5 AUXILIARY RELA Y COM
B8 COM2 RS485 COM F8 6 AUXILIARY RELAY NO
B9 SHIELD (GROUND) F9 6 AUXILIARY RELAY COM
B10 IRIG-B + F10 7 AUXILIARY RELAY COM
B11 IRIG-B – F11 8 SELF-TEST WARNING RELAY NO
B12 RESERVED F12 8 SELF-TEST WARNG RELAY COM
LOGIC INPUTS CT and VT INPUTS / GROUND
C1 LOGIC INPUT 1 G1 COIL MONITOR 1 +
C2 LOGIC INPUT 2 G2 COIL MONITOR 2 +
C3 LOGIC INPUT 3 G3 SENSITIVE GROUND CT ■
C4 LOGIC INPUT 4 G4 SYNCHRO VT ■ (LINE)
C5 LOGIC INPUT 5 G5 PHASE A VT ■ (BUS)
C6 LOGIC INPUT 6 G6 PHASE C VT ■ (BUS)
C7 LOGIC INPUT 7 G7 PHASE A CT ■
C8 RESERVED G8 PHASE B CT ■
C9 RESERVED G9 PHASE C CT ■
C10 SETPOINT ACCESS – G10 GROUND CT ■
C11 SETPOINT ACCESS + G11 FILTER GROUND
C12 +32 VDC G12 SAFETY GROUND
LOGIC INPUTS CT and VT INPUTS / POWER
D1 LOGIC INPUT 8 H1 COIL MONITOR 1 D2 LOGIC INPUT 9 H2 COIL MONITOR 2 D3 LOGIC INPUT 10 H3 SENSITIVE GROUND CT
D4 LOGIC INPUT 11 H4 SYNCHRO VT (LINE)
D5 LOGIC INPUT 12 H5 PHASE B VT ■ (BUS)
D6 LOGIC INPUT 13 H6 PHASE VT NEUTRAL (BUS)
D7 LOGIC INPUT 14 H7 PHASE A CT
D8 RESERVED H8 PHASE B CT
D9 RESERVED H9 PHASE C CT
D10 RESERVED H10 GROUND CT
D11 RESERVED H11 CONTROL POWER –
D12 DC NEGATIVE H12 CONTROL POWER +
3–6
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Electrical Installation
Feeder Management Relay
750/760
Electrical Installation
Installation
FIGURE 3–10: Typical Wiring Diagram
GE Multilin
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3–7
Page 52
Feeder Management Relay
Electrical Installation750/760
Phase Sequence and
Transformer Polarity
Installation
Ground and Sensitive
For the correct operation of many relay features, the instrument transformer
polarities shown above in the Typical Wiring Diagram on page 3–7 must be followed.
Note the solid square markings shown with all instrument transformer connections.
When the connections adhere to this drawing, the arrow shows the direction of
power flow for positive watts and the positive direction of lagging vars. The phase
sequence is user programmable to be either ABC or ACB rotation.
Current Inputs The 750/760 relays have five (5) channels for AC current inputs, each with an
isolating transformer and an automatic shorting mechanism that acts when the
relay is withdrawn from its case. There are no internal ground connections on the
current inputs. Current transformers with 1 to 50000 A primaries may be used.
Verify that the relay’s nominal input current of 1 A or 5 A matches the
CAUTION
CAUTION
Ground CT Inputs
NOTE
NOTE
secondary rating of the connected CTs. Unmatched CTs may result in
equipment damage or inadequate protection.
IMPORTANT: The phase and ground current inputs will correctly measure
to 20 times the current input’s nominal rating. Time overcurrent curves
become horizontal lines for currents above the 20 × CT rating. This
becomes apparent if the pickup level is set above the nominal CT rating.
There are two dedicated ground inputs referred throughout this manual as the
Ground Current and the Sensitive Ground Current inputs. Before making ground
connections, consider that the relay automatically calculates the neutral (residual)
current from the sum of the three phase current phasors. The following figures show
three possible ground connections using the ground current input (Terminals G10
and H10) and three possible sensitive ground connections using the sensitive
ground current input (Terminals G3 and H3).
The ground input (Terminals G10 and H10) is used in conjunction with a Zero
Sequence CT as source, or in the neutral of wye-connected source CTs. The ground
current input can be used to polarize both the neutral and sensitive ground
directional elements. When using the residual connection set the
setpoint to a value equal to the PHASE CT PRIMARY setpoint.
The sensitive ground current input is intended for use either with a CT in a source
neutral of a high-impedance grounded system, or on ungrounded systems. On
ungrounded systems it is connected residually with the phase current inputs. In this
case, the
the
to a Zero Sequence CT for increased sensitivity and accuracy when physically
possible in the system.
Units that do not have the Sensitive Ground input (such as older units which have
been upgraded with new firmware) use the G3 and H3 terminals as the polarizing
input. The G10 and H10 terminals are used for the Ground input. These connections
will be shown on the terminal assignment label on the back of the relay’s case.
The Sensitive Ground input (G3 and H3 terminals) must on ly be used on systems
where the maximum ground current does not exceed 500 A.
SENSTV GND CT PRIMARY setpoint should be programmed to a value equal to
PHASE CT PRIMARY setpoint. The sensitive ground current input can be connected
GROUND CT PRIMARY
3–8
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Electrical Installation
Feeder Management Relay
750/760
Installation
FIGURE 3–11: Ground Inputs
FIGURE 3–12: Sensitive Ground Inputs
Restricted Earth Fault
Inputs
Restricted Earth Fault protection is often applied to transformers having grounded
wye windings to provide sensitive ground fault detection for faults near the
transformer neutral. The Sensitive Ground input (Terminals G3 and H3) can be
used.
NOTE
GE Multilin
Although the 750/760 is designed for feeder protection, it can provide
Restricted Earth Fault protection on transformers that do not have dedicated
protection. To use the 750/760 for this type of protection, a stabilizing
resistor and possibly a non-linear resistor will be required. For more details
see page 5–56.
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Feeder Management Relay
Electrical Installation750/760
Installation
Zero Sequence CT
Installation
FIGURE 3–13: Restricted Earth Fault Inputs
The various CT connections and the exact placement of a Zero Sequence CT, so that
ground fault current will be detected, are shown in the figure below. Twisted pair
cabling on the Zero Sequence CT is recommended.
FIGURE 3–14: Zero Sequence (Core Balance) CT Installation
Voltage Inputs The 750/760 relays have four channels for AC voltage inputs, each with an isolating
transformer. Voltage transformers up to a maximum 5000:1 ratio may be used. The
nominal secondary voltage must be in the 50 to 240 V range.
The three phase inputs are designated as the “bus voltage”. The Bus VT connections
most commonly used, wye and delta (or open delta), are shown in the typical wiring
diagram. Be aware that these voltage channels are internally connected as wye.
This is why the jumper between the phase B terminal and the Vcom terminal must
be installed with a delta connection.
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Electrical Installation
NOTE
Feeder Management Relay
750/760
FIGURE 3–15: Line VT Connections
If Delta VTs are used, the zero sequence voltage (V
polarizing voltage (–V
) will be zero. Also, with this Delta VT connection, the phase-
0
) and neutral/sensitive ground
0
neutral voltage cannot be measured and will not be displayed.
The single phase input is designated as the “line voltage”. The line VT input channel,
used for the synchrocheck feature, can be connected for phase-neutr al voltages V
V
, or Vcn; or for phase-phase voltages Vab or Vcb as shown below.
bn
an
Installation
,
Control Power Control power supplied to the relay must match the installed power
supply range. If the applied voltage does not match, damage to the
CAUTION
unit may occur. All grounds MUST be connected for normal operation
regardless of control power supply type.
The label found on the left side of the relay specifies its order code or model
number. The installed power supply’s operating range will be one of the following.
LO: 20 to 60 V DC or 20 to 48 V AC
HI: 88 to 300 V DC or 70 to 265 V AC
The relay should be connected directly to the ground bus, using the
CAUTION
shortest practical path. A tinned copper, braided, shielding and bonding
cable should be used. As a minimum, 96 strands of number 34 AWG should
be used. Belden catalog number 8660 is suitable.
FIGURE 3–16: Control Power Connection
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Feeder Management Relay
Electrical Installation750/760
Trip/Close Coil Super-
Installation
vision
Supervision of a breaker trip coil requires the relay supervision circuit to be wired in
parallel with the Trip contact. Likewise, supervision of the close coil requires the
supervision circuit to be wired in parallel with the Close contact. Each connection
places an impedance across the associated contact, which allows a small trickle
current to flow through the related trip and close coil supervision circuitry. For
external supply voltages in the 30 to 250 V DC range, this current draw will be
between 2 to 5 mA. If either the trip or close coil supervision circuitry ceases to
detect this trickle current, the appropriate failure will be declared by the relay.
When the
to be monitored when the breaker is closed and a close circuit to be monitored when
the breaker is open.
Circuit breakers equipped with standard control circuits have a 52a auxiliary contact
which only allows tripping of the breaker when it is closed. In this breaker state, the
52a contact is closed and a trickle current will flow through the trip circuitry. When
the breaker is open, the 52a auxiliary contact is also open and no trickle current will
flow. When the breaker position monitoring inputs detect an open breaker, the trip
coil supervision monitoring function will be disabled.
BRKR STATE BYPASS setpoint is “Disabled”, the logic only allows a trip circuit
FIGURE 3–17: Trip/Close Coil Supervision
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750/760
In a similar manner, the 52b auxiliary contact only allows closing of the breaker
when it is open. In this breaker state, the 52b contact is shorted and a trickle
current will flow through the breaker’s close circuitry. When the breaker is closed,
the 52b auxiliary contact is open and no trickle current will flow. When the breaker
position monitoring inputs detect a closed breaker, the close coil supervision
monitoring function will be disabled.
When the
BRKR STATE BYPASS setpoint is “Enabled”, the trip and close coil supervision
circuits can be arranged to monitor the trip and close circuits continuously,
unaffected by breaker state. This application requires that an alternate path around
the 52a or 52b contacts in series with the operating coils be provided, with
modifications to the standard wiring as shown FIGURE 3–17: Trip/Close Coil
Supervision on page 3–12. With these connections, trickle current can flow at all
times. If access to the breaker coil is available, as shown in drawing A above,
continuous coil monitoring regardless of breaker state is possible without using a
resistor to bypass the 52a/b contact.
A high speed solid state (SCR) output is also provided. This output is intended for
applications where it is required to key a communications channel.
Logic Inputs External contacts can be connected to the relay’s fourteen (14) logic inputs. As
shown, these contacts can be either dry or wet. It is also possible to use a
combination of both contact types.
Ensure correct polarity on logic input connections and do not connect any
CAUTION
logic input circuits to ground or else relay hardware may be damaged.
A dry contact has one side connected to Terminal C12. This is the +32 V DC voltage
rail. The other side of the dry contact is connected to the required logic input
terminal. When a dry contact closes, a current of approximately 2 mA will flow
through the associated circuit.
A wet contact has one side connected to the positive terminal of an external DC
power supply. The other side of this contact is connected to the required logic input
terminal. In addition, the negative side of the external source must be connected to
the relay’s DC negative rail at Terminal D12. The maximum external source voltage
for this arrangement is 300 V DC.
Dry Contact Connection
+32VDC
Logic Input 1
32VDC
DC Negative D12
C12
D12
Wet Contact Connection
750/760 RELAY750/760 RELAY
+32VDC
Logic Input 1
32VDC
DC Negative
C12
C1C1
30 to 300 V DC
LOGICIN.CDR
FIGURE 3–18: Dry and Wet Contact Connections
Installation
Analog Input Terminals A1 (+) and A2 (–) are provided for the input of a current signal from a
wide variety of transducer outputs - refer to technical specifications for complete
listing. This current signal can represent any external quantity, such as transformer
winding temperature, bus voltage, battery voltage, station service voltage, or
transformer tap position. Be sure to observe polarity mark ings for correc t operation.
Both terminals are clamped to within 36 V of ground with surge protection. As such,
common mode voltages should not exceed this limit. Shielded wire, with only one
end of the shield grounded, is recommended to minimize noise effects.
Analog Outputs The 750/760 relays provide eight (8) analog output channels whose full scale range
was specified at the time of ordering. Refer to Outputs on page 2–12 for the
specifications and Ordering on page 2–6 for the complete listing.
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Feeder Management Relay
Installation
Electrical Installation750/760
Each analog output channel can be programmed to represent one of the parameters
measured by the relay. For details, see Analog Outputs on page 5–87.
As shown in the Typical Wiring Diagram, the analog output signals originate from
Terminals A5 to A12 and share A4 as a common return. Output signals are internally
isolated and allow connection to devices which sit at a different ground potential.
Each analog output terminal is clamped to within 36 V of ground. To minimize the
affect of noise, external connections should be made with shielded cable and only
one end of the shield should be grounded.
If a voltage output is required, a burden resistor must be co nnected at the input of
the external measuring device. Ignoring the input impedance, we have
V
MAX
FULL SCALE
----------------------------------=
I
MAX
5 V
----------------------- - 5 kΩ===
0.001 A
R
LOAD
If a 5V full scale output is required with a 0 to 1 mA output channel:
V
FULL SCALE
R
LOAD
For a 0 to 5 mA channel this resistor would be 1 kW and for a 4 to 20 mA channel
this resistor would be 250 Ω. The Analog Output connection diagram is shown
below.
----------------------------------
I
(EQ 3.1)
(EQ 3.2)
FIGURE 3–19: Analog Output Connection
Serial Communications The 750/760 relays provide the user with two rear communication ports which may
be used simultaneously. Both support a subset of the AEG Modicon Modbus protocol
as well as the Harris Distributed Network Protocol (DNP) as discussed in GE
Publication GEK-106473: 750/760 Communications Guide. Through the use of these
ports, continuous monitoring and control from a remote computer , SCADA system or
PLC is possible.
The first port, COM1, can be used in a two wire RS485 mode or a four wire RS422
mode, but will not operate in both modes at the same time. In the RS485 mode,
data transmission and reception are accomplished over a single twisted pair with
transmit and receive data alternating over the same two wires. These wires should
be connected to the terminals marked RS485. The RS422 mode uses the COM1
terminals designated as RS485 for receive lines, and the COM1 terminals designated
as RS422 for transmit lines. The second port, COM2, is intended for the two wire
RS485 mode only.
The RS485 port is disabled when the Ethernet option is ordered.
To minimize errors from noise, the use of shielded twisted-pair wire is
recommended. Correct polarity should also be observed. For instance, SR type
relays must be connected with all B1 terminals (labeled COM1 RS485+) connected
together, and all B2 terminals (labeled COM 1 RS485–) connected together. Terminal
B3 (COM1 RS485 COM) should be connected to the common wire inside the shield.
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750/760
To avoid loop currents, the shield should be grou nded at one point only. Each relay
should also be daisy-chained to the next one in the link. A maximum of 32 devices
can be connected in this manner without exceeding driver capability. For larger
systems, additional serial channels must be added. It is also possible to use
commercially available repeaters to add more than 32 relays on a single channel.
Star or stub connections should be avoided entirely.
Lightning strikes and ground surge currents can cause large momentary voltage
differences between remote ends of the communication link. For this reason, surge
protection devices are internally provided at both communication ports. An isolated
power supply with an opto-coupled data interface also acts to reduce noise coupling.
To ensure maximum reliability, all equipment should have similar transient
protection devices installed.
Installation
GE Multilin
FIGURE 3–20: RS485 Wiring Diagram
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Feeder Management Relay
Installation
Electrical Installation750/760
FIGURE 3–21: RS422 Wiring Diagram
RS232 Communications The 9-pin RS232 serial port located on the front panel is used in conjunction with
the EnerVista 750/760 Setup software for programming setpoints and upgrading
relay firmware. A standard 9-pin RS232 cable is used to connect the relay to a
personal computer as shown below. When downloading new firmware, ensure
the relay address is set to 1 and the baud rate is set to 9600.
FIGURE 3–22: RS232 Connection
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Electrical Installation
GE MULTILIN
SR FAMILY
IRIG-B(-)
RECEIVER
TO OTHER DEVICES
RG58/59 COAXIAL CABLE
GPS SATELLITE SYSTEM
GPS CONNECTION
OPTIONAL
IRIG-B(+)
B10
B11
+
–
818838A7.CDR
IRIG-B
TIMECODE
GENERATOR
(DC SHIFT OR
AMPLITUDE MODULATED
SIGNAL CAN BE USED)
IRIG-B IRIG-B is a standard time code format that allows time stamping of events to be
Feeder Management Relay
750/760
synchronized among connected devices within 1 millisecond. The IRIG time code
formats are serial, width-modulated codes which can be either DC level shift or
amplitude modulated (AM) form. Third party equipment is available for generating
the IRIG-B signal; this equipment may use a GPS satellite system to obtain the time
reference so that devices at different geographic locations can al so be synchroni zed.
Installation
FIGURE 3–23: IRIG-B Connection
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Electrical Installation750/760
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Front Panel Interface
Description The front panel provides local operator interface with a liquid crystal display, LED
Feeder Management Relay
750/760
4 Interfaces
Front Panel Interface
status indicators, control keys, and program port. The display and status indicators
update alarm and status information automatically. The control keys are used to
select the appropriate message for entering setpoints or displaying measured
values. The RS232 program port is also provided for connection with a computer
running the EnerVista 750/760 Setup software.
Interfaces
Display The 40-character liquid crystal display (LCD) allows visibility under varied lighting
conditions. When the keypad and display are not being used, system information is
displayed by scrolling through a maximum of 30 user-defined default messages.
These default messages appear only after a user-defined period of inactivity.
Pressing any key during default message scrolling returns the display to the last
message shown before the default messages appeared. Any trip, alarm, or start
block is displayed immediately, automatically overriding the default messages.
LED Indicators
Description The front panel indicators are grouped into three columns. The 750/760 Status
column indicates the state of the relay; the System Status column indicates the
state of the breaker and the system; and the Output Status column indicates the
state of the output relays. These LED indicators can be tested by and holding the
HELP key for about one second when no trips or alarms are active. As shown below,
the color of each indicator conveys its importance.
G = Green: General Condition
A = Amber: Alert Condition
R = Red: Serious Alarm or Important Status
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Feeder Management Relay
LED Indicators750/760
Interfaces
750/760 Status LED
Indicators
NOTE
FIGURE 4–1: 750/760 Front Panel
• RELAY IN SERVICE: This indicator will be on continuously if the relay is
functioning normally and no major self-test errors have been detected. During
operation the relay continuously performs various self tests and if a major selftest fails, the indicator will be turned off, all output relays will be de-energized,
and the Self-Test Warning LED will be turned on. This indicates a complete loss
of protection. See the self-test warning section later in this chapter.
• TRIP: This indicator flashes when the relay detects a trip condition and
operates the Trip Relay to open the breaker. After the initiating fault has been
cleared, this LED can be turned off with a reset.
• ALARM: While the relay is detecting an alarm condition, this indicator will flash.
Even if latched output relays are programmed to operate with the alarm, the
indicator will automatically turn off if the alarm condition clears. Such output
relays will remain in the operated state until a reset is performed.
Latched Alarm: This relay flashes while the relay is detecting an alarm
condition. After the condition clears, the indicator remains illuminated and can
be turned off with a reset.
• PICKUP: For the purpose of testing and calibration verification, this indicator
will light steady when any protection feature has its pickup threshold exceeded.
Eventually, if the fault condition persists, a trip will be issued by the relay. If the
measured parameter drops below its pickup level, the indicator will turn off.
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LED Indicators
Feeder Management Relay
750/760
• SETPOINT GROUP 1 to 4: These indicators are flashing if the corresponding
group is selected for editing and/or display; they are continuously on if the
corresponding group is providing settings for the protection elements.
System Status LED
Indicators
NOTE
• BREAKER OPEN: When the breaker is open, this indicator will be on
continuously.
• BREAKER CLOSED: When the breaker is closed, this indicator will be on
continuously.
Breaker status indication is based on the breaker 52a and 52b contacts. With
both contacts wired to the relay , the closed status is determined by a closed 52a
contact and the open status is determined by a closed 52b contact. If both 52a
and 52b contacts are open, due to a breaker being racked out of the switchgear,
both the Breaker Open and Breaker Closed LED Indicators will be off.
With a single 52a contact, it is impossible to distinguish between a breaker open
state and a racked out breaker. In both situations, the 52a contact will be open.
With a single 52b contact, you cannot distinguish between a breaker closed
state and a racked out breaker. Likewise, the 52b contact will be open for both
situations. To clarify this ambiguity, the breaker connected function should be
programmed to an additional logic input. When this additional input is closed, a
single 52a or 52b contact will show both breaker states. When the breaker is
racked out, this additional breaker connected input should be open. In this case,
both breaker status indicators will be off.
The Open and Closed Status Indicator colors are interchangeable at the
time of placing a 750/760 order.
Interfaces
• RECLOSURE ENABLED (760 only): This indicator will be on continuously
when autoreclosure is allowed to operate as programmed. This is when the
autoreclose function setpoint is enabled, and if used, the block reclosure logic
input is not asserted. Otherwise, this indicator will be off. Note that this
indicator will always be in the opposite state of the Reclosure Disabled LED
Indicator.
• RECLOSURE DISABLED (760 only): This indicator will be on continuously
when autoreclosure is not allowed to operate as programmed. This is when the
autoreclose function setpoint is disabled, or if used, the block reclosure logic
input is asserted. Otherwise, this indicator will be off. Note that this indicator
will always be in the opposite state of the Reclosure Enabled LED.
• RECLOSURE IN PROGRESS (760 only): If a trip initiates a reclosing
sequence, this indicator will go on continuously during each of the programmed
dead times.
• RECLOSURE LOCKOUT (760 only): If the programmed reclose sequence has
progressed to a final lockout condition, this indicator will be on continuously.
Lockout can be cleared by performing a reset.
• LOCAL: This indicator turns on if the local mode function has been assigned a
logic input which is asserted. In local mode, the front panel OPEN and CLOSE keys
operate while the Remote Open and Remote Close logic input functions will not
operate. As well, the communication open and close commands have no effect.
Breaker operations performed by 750/760 outputs in response to logic inputs
energized with contacts from a local control switch are considered as remote
operations. When the 750/760 is in local mode, the local panel is the relay
faceplate; everything else is considered remote, even the control switch that
might be installed in the same switchgear compartment. It is important not to
confuse this with the concept of Station Local/Remote Mode, in which case the
same Control Switch is considered local.
• MESSAGE: Under normal conditions, the default messages selected during
setpoint programming are displayed. If any alarm or trip condition is gener ated,
a diagnostic message overrides the displayed message and this indicator
flashes. If there is more than one condition present, MESSAGE T can be used to
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Feeder Management Relay
LED Indicators750/760
scroll through the messages. Pressing any other key return to the normally
displayed messages. While viewing normally displayed messages, the Message
LED continues to flash if any diagnostic message is active. To return to the
diagnostic messages from the normally displayed messages, press the MENU key
until the following message is displayed:
TARGET MESSAGES [Z]
Now, press the MESSAGE X key followed by the message T key to scroll through
the messages. Note that diagnostic messages for alarms disappear with the
condition while diagnostic messages for trips remain until cleared by a reset.
Interfaces
Output Status LED
Indicators
The 750/760 has eight (8) output relays: the 1 Trip, 2 Close, and 8 Self-Test
Warning relays have fixed operation while the 3 to 7 Auxiliary relays are
configurable. Regardless of the mode of operation, the corresponding front panel
indicator turns on while the output relay is signaling. If the non-operated state of an
output relay is programmed as de-energized, the corresponding indicator will be on
when the normally open contacts are closed. If the non-operated state of an output
relay is programmed as energized, the corresponding indicator will be on when the
normally open contacts are open.
• 1 TRIP: A trip sequence can be initiated by a protection element, a logic input
element, a remote open command, a serial open command, or a front panel
open command. When started, the Trip LED turns on briefly while the Trip Relay
is energized. After the auxiliary breaker contacts indicate that the breaker has
opened, the Trip Relay and indicator stop operating. If both 52a and 52b
auxiliary contacts are not installed, the Trip Relay and indicator will deenergize 100 ms after the trip condition clears, or after two seconds.
• 2 CLOSE: A close sequence can be initiated by a 760 reclosure or a remote,
serial, or front panel close command. When started, the Close LED turns on
briefly while the Close Relay energizes. After the auxiliary breaker contacts
indicate that the breaker has closed, the Close Relay and indicator stop
operating. If both 52a and 52b auxiliary contacts are not installed, the
Close Relay and indicator operate for 200 ms.
• 3 to 7 AUXILIARY: These relays are intended for customer specific
requirements that can be initiated by any protection element or function whose
RELAYS (3-7) setpoint has “3”, “4”, “5”, “6”, or “7” selected. The Auxiliary LEDs (3
to 7) will turn on while the corresponding relays are operating.
• 8 SELF-TES T WARNING: During normal operation, this indicator is off with
the fail-safe Self-Test Warning Relay energized. If any abnormal condition is
detected during self monitoring (such as a hardware failure) the indicator turns
on and the relay de-energizes. If control power is lost or the relay is drawn out
of its case, the Self-Test Warning Relay signals loss of protection by deenergizing, but the LED indicator remains off. Since there are no shorting
contacts across the Self-Test Warning Relay, both the normally open and
normally closed contacts are open when the unit is drawn out.
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Relay Messages
Feeder Management Relay
Relay Messages
Keypad Operation The 750/760 display messages are organized into Main Menus, Pages, and Sub-
pages. There are three main menus labeled Setpoints, Actual Values, and Target
Messages.
Pressing the MENU key followed by the MESSAGE T key scrolls through the three Main
Menu headers, which appear in sequence as follows:
SETPOINTS [Z]
ACTUAL VALUES [Z]
TARGET MESSAGES [Z]
Pressing the MESSAGE X key or the ENTER key from these Main Menu pages will display
the corresponding menu Page. Use the MESSAGE S and MESSAGE T keys to scroll
through the Page headers.
When the display shows
display the page headers of programmable parameters (referred to as setpoints in
the manual). When the display shows
the ENTER key displays the page headers of measured parameters (referred to as
actual values in the manual). When the display shows
the MESSAGE X key or the ENTER key displays the page headers of event messages or
alarm conditions.
Each page is broken down further into logical sub-pages of messages. The
MESSAGE S and MESSAGE T keys are used to navigate through the sub-pages. A
summary of the setpoints and actual values pages can be found in the Chapters 5:
Setpoints and 6: Actual Values, respectively.
The ENTER key is dual purpose. It is used to enter the sub-pages and to store altered
setpoint values into memory to complete the change. The MESSAGE X key can also be
used to enter sub-pages but not to store altered setpoints.
The ESCAPE key is also dual purpose. It is used to exit the sub-pages and to cancel a
setpoint change. The MESSAGE W key can also be used to exit sub-pages and to
cancel setpoint changes.
The VA L U E keys are used to scroll through the possible choices of an enumerated
setpoint. They also decrement and increment numerical setpoints. Numerical
setpoints may also be entered through the numeric keypad.
The HELP key may be pressed at any time to display a list of context sensitive help
messages. Continue to press the HELP key to display all the help messages and
return to the original display.
The RESET key resets any latched conditions that are not presently active. This
includes resetting latched output relays, latched Trip LEDs, breaker operation
failure, and trip / close coil failures. The 760 Autoreclose Scheme is also reset with
the shot counter being returned to zero and the lockout condition being cleared.
The MESSAGE S and MESSAGE T keys scroll through any active conditions in the relay.
Diagnostic messages are displayed indicating the state of protection and monitoring
elements that are picked up, operating, or latched. When the Message LED is on
there are messages to be viewed with the MENU key by selecting target messages as
described earlier.
SETPOINTS, pressing the MESSAGE X key or t he ENTER ke y w il l
ACTUAL VALUES, pressing the MESSAGE X key or
TARGET MESSAGES, pressing
750/760
Interfaces
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Relay Messages750/760
Feeder Management Relay
Pressing the OPEN key will attempt to open the breaker connected to the Trip Relay
by closing the contact. Likewise, the CLOSE key will attempt to close the breaker
connected to the Close Relay by closing the contact. The OPEN and CLOSE keys only
operate when the relay is in local mode; local mode can be enabled with a user
programmed logic input.
Diagnostic Messages Diagnostic messages are automatically displayed for any active conditions in the
relay such as trips, alarms, or asserted logic inputs. These messages provide a
summary of the present state of the relay. The Message LED flashes when there are
diagnostic messages available; press the MENU key until the relay displays
MESSAGES, then press the MESSAGE X key, followed by the MESSAGE T key, to scroll
through the messages. The following shows the format of the various diagnostic
messages.
TARGET
Interfaces
PICKUP: <F>
< Cause >
TRIP: <F>
< Cause >
ALARM: <F>
< Cause >
SELF-TEST WARNING:
< Cause >
These messages show any elements that are presently
picked up.
These messages indicate that an element has tripped.
The message remains in the diagnostic queue until the
relay is reset.
These messages show any elements that are presently
operating and have been programmed to have an alarm
function. When an element is programmed to Latched
Alarm, this message remains in the diagnostic queue
after the alarm condition clears until the relay is reset.
These messages show any self-test warnings.
Self-Test Warnings The relay performs self diagnostics at initialization (after power up), and
continuously as a background task to ensure that every testable unit of the
hardware and software is alive and functioning correctly . There are two types of selftest warnings indicating either a minor or major problem. Minor problems indicate a
problem with the relay that does not compromise protection of the power system.
Major problems indicate a very serious problem with the relay which comprises all
aspects of relay operation.
Self-Test Warnings may indicate a serious problem with the relay
WARNING
hardware!
Upon detection of either a minor or major problem, the relay will:
• De-energize the Self-Test Warning Relay.
• Indicate the failure in the diagnostic message queu e.
• Record the failure in the Even t Recorder.
Upon detection of a major problem, the relay will (if possible) also:
• Turn off the Relay In Service LED.
• Inhibit operation of all output relays.
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750/760
TABLE 4–1: Self-Test Warnings
Error Severity Description
A/D Virtual Ground Major This warning is caused by a failure of the analog to
Analog Output
+32V
Clock Not Set Minor Occurs if the clock has not been set.
Dry Contact +32V Minor Caused by the loss of the +32 V DC power supply
EEPROM Corrupt Major Caused by detection of corrupted location(s) in the
Factory Service Major This warning occurs when the relay is in factory
FLASH Corrupt Major This warning is caused by detection of a corrupted
Force Analog Out Minor Occurs when the
Force Relays Minor Occurs when the
Internal RS485 Minor Caused by a failure of the internal RS485
Internal Temp Minor Caused by the detection of unacceptably low (less
IRIG-B Failure Minor Caused when IRIG-B time synchronization has been
Not Calibrated Minor This warning occurs when the relay has not been
Pickup Test Minor Occurs when the
Prototype Software Minor Occurs when prototype software has been loaded into
Relay Not Ready Minor This warning occurs when the
RTC Crystal Minor This warning is caused by a failure of the Real Time
Simulation Mode Minor This warning occurs when the simulation feature of
Minor Caused by the loss of the +32 V DC power supply
digital converter. The integrity of system input
measurements is affected by this failure.
used to power analog outputs. Analog output currents
are affected by this failure.
used to power dry contacts of logic inputs. Logic
inputs using internal power are affected by this
failure.
relay data memory which cannot be self-corrected.
Any function of the relay i s suscepti ble to malfun ction
from this failure.
service mode.
location in the program memory as determined by a
CRC error checking code. Any function of the relay is
susceptible to malfunction from this failure.
“Enabled”.
setpoint is "Enabled".
communication link. Attempts to read actual values or
write setpoints will produce unpredictable results.
than –40°C) or high (greater than +85°C)
temperatures detected inside the unit.
enabled but the signal cannot be decoded.
factory calibrated.
"Enabled".
the relay.
setpoint not been set to “Ready”.
Clock circuit. The ability of the relay to maintain the
current date and time is lost.
the relay is active.
FORCE A/O FUNCTION setpoint is
FORCE OUTPUT RELAYS FUNCTION
PICKUP TEST FUNCTION setpoint is
750/760 OPERATION
Interfaces
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Relay Messages750/760
Feeder Management Relay
Flash Messages Flash messages are warning, error, or general information messages displayed in
response to certain key presses. The length of time these messages remain
displayed can be programmed in
TIME. The factory default flash message time is 4 seconds.
S1 RELAY SETUP ZV FRONT PANEL ZV FLASH MESSAGE
Interfaces
ADJUSTED VALUE
HAS BEEN STORED
COMMAND IS BEING
EXECUTED
DEFAULT MESSAGE
HAS BEEN ADDED
DEFAULT MESSAGE
HAS BEEN REMOVED
ENTER PASSCODE
IS INVALID
ENTRY MISMATCH CODE NOT STORED
This flash message is displayed in response to the ENTER
key, while on a setpoint message with a numerical value.
The edited value had to be adjusted to the nearest
multiple of the step value before it was stored.
This flash message is displayed in response to executing
a command message. Entering "Yes" at a command will
display the message
ARE YOU SURE?. Entering "Yes"
again will perform the requested command and display
this flash message.
This flash message is displayed in response to pressing
the decimal key, followed by the ENTER key twice, on any
message in
S1 RELAY SETUP ZV DEFAULT MESSAGES.
This message is displayed in response to pressing the
decimal key, followed by the ENTER key twice, on any
selected default message in
MESSAGES.
S1 RELAY SETUP ZV DEFAULT
This flash message is displayed in response to an
incorrectly entered passcode when attempting to enable
or disable setpoint access.
This message is displayed while changing the password
with the
S1 RELAY SETUP Z PASSCODE ZV CHANGE PASSCODE
setpoint. If the passcode entered at the PLEASE RE-
ENTER A NEW PASSCODE
one entered
PLEASE ENTER A NEW PASSCODE prompt,
prompt is different from the
the relay dumps the new passcode and display this
message
INVALID KEY: MUST
BE IN LOCAL MODE
NEW PASSCODE
STORED
NEW SETPOINT
STORED
NO CONDITIONS ARE
CURRENTLY ACTIVE
OUT OF RANGE VALUE NOT STORED
This flash message is displayed in response to pressing
the OPEN or close keys while the relay is in Remote Mode.
The relay must be put into Local Mode in order for these
keys to be operational.
This message is displayed in response to changing the
programmed passcode from the
PASSCODE ZV CHANGE PASSCODE setpoint. The directions
S1 RELAY SETUP Z
to change the passcode were followed correctly and the
new passcode was stored as entered.
This flash message is displayed in response to the ENTER
key while on any setpoint message. The edited value was
stored as entered.
This flash message is displayed in response to the
MESSAGE X key when the relay is displaying
MESSAGES and the Message LED is off. There are no
TARGET
active conditions to display in the diagnostic message
queue.
This flash message is displayed in response to the ENTER
key while on a setpoint message or numerical value. The
edited value was either less than the minimum or greater
than the maximum acceptable values for the edited
setpoint and as a result was not stored.
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Relay Messages
Feeder Management Relay
750/760
PLEASE ENTER A
NON-ZERO PASSCODE
PRESS [ENTER] TO
ADD AS DEFAULT
PRESS [ENTER] TO
BEGIN TEXT EDIT
PRESS [ENTER] TO
REMOVE MESSAGE
PRESSED KEY
IS INVALID HERE
RESETTING LATCHED
CONDITIONS
This flash message is displayed while changing the
passcode with the
PASSCODE setpoint. An attempt was made to change the
S1 RELAY SETUP Z PASSCODE ZV CHANGE
passcode to “0” when it was already “0”.
This flash message is displayed for 5 seconds in respons e
to pressing the decimal key, followed by the ENTER key
while displaying any setpoint or actual value message
except those in
S1 RELAY SETUP ZV DEFAULT MESSAGES.
Pressing the ENTER key again while this message is
displayed adds the setpoint or actual value message to
the default list.
This message is d isplayed in response to the VA L U E keys
while on a setpoint message with a text entry value. The
ENTER key must be pressed to begin editing.
This flash message is displayed for 5 seconds in respons e
to pressing the decimal key, followed by the ENTER key
while displaying one of the selected default messages in
the subgroup
S1 RELAY SETUP ZV DEFAULT MESSAGES.
Pressing the ENTER key again while this message is
displayed removes the default message from the list.
This flash message is displayed in response to any
pressed key that has no meaning in the current context.
This flash messag e is displayed in response t o the RESET
key. All active latched conditions (trips, alarms, or
latched relays) for which the activating condition is no
longer present will be cleared.
Interfaces
SETPOINT ACCESS
DENIED (PASSCODE)
SETPOINT ACCESS
DENIED (SWITCH)
SETPOINT ACCESS
IS NOT ALLOWED
SETPOINT ACCESS
IS NOW RESTRICTED
This flash message is displayed in response to the ENTER
key while on any setpoint message. Setpoint access is
restricted because the programmed passcode has not
been entered to allow access.
This flash message is displayed in response to the ENTER
key while on any setpoint message. Setpoint access is
restricted because the setpoint access terminals have not
been connected.
This flash message is displayed in response to correctly
entering the programmed passcode at the
S1 RELAY SETUP
Z PASS CODE ZV ALLOW ACCESS TO SETPOINTS setpoint. The
command to allow access to setpoints has been
successfully executed and setpoints can be changed and
entered.
This flash message is displayed in response to entering
the correct programmed passcode at the
S1 RELAY SETUP
Z PASSCODE ZV RESTRICT ACCESS TO SETPOINTS setpoint.
The command to restrict access to setpoints has been
successfully executed and setpoints cannot be changed.
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Overview The EnerVista 750/760 Setup software provides a graphical user interface (GUI) as
EnerVista 750/760 Setup Software Interface750/760
EnerVista 750/760 Setup Software Interface
one of two human interfaces to a 750/760 device. The alternate human interface is
implemented via the device's faceplate keypad and display (see the first section in
this chapter).
The EnerVista 750/760 Setup software provides a single facility to configure,
monitor, maintain, and trouble-shoot the operation of relay functions, connected
over serial communication net works. It c an be used wh ile disconnected (i.e. off -lin e)
or connected (i.e. on-line) to a 750/760 device. In off-line mode, settings files can
be created for eventual downloading to the device. In on-line mode, you can
communicate with the device in real-time.
This no-charge software, provided with every 750/760 relay, can be run from any
computer supporting Microsoft Windows
summary of the basic EnerVista 750/760 Setup software interface features. The
EnerVista 750/760 Setup Help File provides details for getting started and using the
software interface.
With the EnerVista 750/760 Setup running on your PC, it is possible to:
• Program and modify setpoints
• Load/save setpoint files from/to disk
• Read actual values and monitor status
• Perform waveform capture and log data
• Plot, print, and view trending graphs of selected actual values
• Download and playback waveforms
• Get help on any topic
®
95 or higher. This chapter provides a
Hardware Communications from the EnerVista 750/760 Setup to the 750/760 can be
accomplished three ways: RS232, RS485, and Ethernet communications. The
following figures below illustrate typical connections for RS232, RS485, and
Ethernet communications.
FIGURE 4–2: Communications using the Front RS232 Port
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NOTE
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750/760
FIGURE 4–3: Communications using Rear RS485 Port
RS485 COM2 is disabled when the Ethernet option is ordered.
Interfaces
FIGURE 4–4: Communications using Rear Ethernet Port
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996711A1.CDR
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EnerVista 750/760 Setup Software Interface750/760
Interfaces
Installing the EnerVista
750/760 Setup Software
The following minimum requirements must be met for the EnerVista 750/760 Setup
software to operate on your computer.
• Pentium class or higher processor (Pentium II 300 MHz or better recommended)
• Microsoft Windows 95, 98, 98SE, ME, NT 4.0 (SP4 or higher), 2000, XP
• 64 MB of RAM (256 MB recommended)
• Minimum of 50 MB hard disk space (200 MB recommended)
After ensuring these minimum requirements, us e the following procedure to install
the EnerVista 750/760 Setup software from the enclosed GE EnerVista CD.
1. Insert the GE EnerVista CD into your CD-ROM drive.
2. Click the Install Now button and follow the installation instructions to install
the no-charge EnerVista software on the local PC.
3. When installation is complete, start the EnerVista Launchpad application.
4. Click the IED Setup section of the Launch Pad window.
5. In the EnerVista Launch Pad window, click the Install Software button and
select the “750 Feeder Management Relay” or “760 Feeder Management Relay”
from the Install Software window as shown below. Select the “Web” option to
ensure the most recent software release, or select “CD” if you do not have a
web connection, then click the Check Now button to list software items for the
750/760.
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EnerVista 750/760 Setup Software Interface
6. Select the EnerVista 750/760 Setup software and release notes (if desired) from
the list and click the Download Now button to obtain the installation program.
Feeder Management Relay
750/760
7. EnerVista Launchpad will obtain the installation program from the Web or CD.
Once the download is complete, double-click the installation program to install
the EnerVista 750/760 Setup software.
8. The program will request the user to create a backup 3.5" floppy-disk set. If this
is desired, click on the Start Copying button; otherwise, click on the
CONTINUE WITH 750/760 INSTALLATION button.
9. Select the complete path, including the new directory name, where the
EnerVista 750/760 Setup software will be installed.
10. Click on Next to begin the installation. The files will be installed in the directory
indicated and the installation program will automatically create icons and add
EnerVista 750/760 Setup software to the Windows start menu.
11. Click Finish to end the installation. The 750/760 device will be added to the list
of installed IEDs in the EnerVista Launchpad window, as shown below.
Interfaces
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Connecting EnerVista 750/760 Setup to the Relay750/760
Connecting EnerVista 750/760 Setup to the Relay
Interfaces
Configuring Serial
Communications
Before starting, verify that the serial cable is properly connected to either the RS232
port on the front panel of the device (for RS232 communications) or to the RS485
terminals on the back of the device (for RS485 communications). See Hardware on
page 4–10 for connection details.
This example demonstrates an RS232 connection. For RS485 communications, the
GE Multilin F485 converter will be required. Refer to the F485 manual for additional
details. To configure the relay for Ethernet communications, see Configuring
Ethernet Communications on page 4–16.
1. Install and start the latest version of the EnerVista 750/760 Setup software
(available from the GE EnerVista CD). See the previous section for the
installation procedure.
2. Click on the Device Setup button to open the Device Setup window and click
the Add Site button to define a new site.
3. Enter the desired site name in the Site Name field. If desired, a short
description of site can also be entered along with the display order of devices
defined for the site. In this example, we will use “Substation 1” as the site
name. Click the OK button when complete.
4. The new site will appear in the upper-left list in the EnerVista 750/760 Setup
window.
5. Click the Add Device button to define the new d evice.
6. Enter the desired name in the Device Name field and a description (optional)
of the site.
7. Select “Serial” from the Interface drop-down list. This will display a number of
interface parameters that must be entered for proper RS232 functionality.
• Enter the slave address and COM port values (from the
COMMUNICATIONS ZV PORT SETUP menu) in the Slave Address and COM Port
fields.
• Enter the physical communications parameters (baud rate and p arity settings)
in their respective fields.
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Connecting EnerVista 750/760 Setup to the Relay
8. Click the Read Order Code button to connect to the 750/760 device and
upload the order code. If an communications error occurs, ensure that the 750/
760 serial communications values entered in the previous step correspond to
the relay setting values.
9. Click OK when the relay order code has been received. The new device will be
added to the Site List window (or Online window) located in the top left corner
of the main EnerVista 750/760 Setup window.
The 750/760 Site Device has now been configured for serial communications.
Proceed to Connecting to the Relay on page 4–17 to begin communications.
Feeder Management Relay
750/760
Using the Quick
Connect Feature
The Quick Connect button can be used to establish a fast connection through the
front panel RS232 port of a 750/760 relay. The following window will appear when
the Quick Connect button is pressed:
As indicated by the window, the Quick Connect feature quickly connects the
EnerVista 750/760 Setup software to a 750/760 front port with the following
settings: 9600 baud, no parity , 8 bits, 1 stop bit. Select the PC communications port
connected to the relay and press the Connect button.
The EnerVista 750/760 Setup software will display a window indicating the status of
communications with the relay. When connected, a new Site called “Quick Connect”
will appear in the Site List window. The properties of this new site cannot be
changed.
Interfaces
The 750/760 Site Device has now been configured via the Quick Connect feature for
serial communications. Proceed to Connecting to the Relay on page 4–17 to begin
communications.
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NOTE
Connecting EnerVista 750/760 Setup to the Relay750/760
Interfaces
Configuring Ethernet
Communications
Before starting, verify that the Ethernet cable is properly connected to the RJ-45
Ethernet port.
1. Install and start the latest version of the EnerVista 750/760 Setup software
(available from the GE EnerVista CD). See the previous section for the
installation procedure.
2. Click on the Device Setup button to open the Device Setup window and click
the Add Site button to define a new site.
3. Enter the desired site name in the Site Name field. If desired, a short
description of site can also be entered along with the display order of devices
defined for the site. In this example, we will use “Substation 2” as the site
name. Click the OK button when complete.
4. The new site will appear in the upper-left list.
5. Click the Add Device button to define the new d evice.
6. Enter the desired name in the Device Name field and a description (optional).
7. Select “Ethernet” from the Interface drop-down list. This will display a number
of interface parameters that must be entered for proper Ethernet functionality.
• Enter the IP address, slave address, and Modbus port values assigned to
8. Click the Read Order Code button to connect to the 750/760 and upload the
order code. If an communications error occurs, ensure that the Ethernet
communications values correspond to the relay setting values.
9. Click OK when the relay order code has been received. The new device will be
added to the Site List window (or Online window) located in the top left corner
of the main EnerVista 750/760 Setup window.
The 750/760 Site Device has now been configured for Ethernet communications.
Proceed to the following section to begin communications.
To ensure optimal response from the relay, the typical connection timeout should be
set as indicated in the following table:
TCP/IP sessions Timeout setting
up to 2 2 seconds
up to 4 3 seconds
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the 750/760 relay (from the
WORK CONFIGURATION menu).
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S1 RELAY SETUP ZV COMMUNICATIONS ZV NET-
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Connecting EnerVista 750/760 Setup to the Relay
-
Expand the Site List by double
clicking or by selecting the [+] box
Communications Status Indicator
Green = OK, Red = No Comms
Feeder Management Relay
750/760
Connecting to the
Relay
Now that the communications parameters have been properly configured, the user
can easily communicate with the relay.
1. Expand the Site list by double clicki ng on the site name or click ing on the «+»
box to list the available devices for the given site (for example, in the
“Substation 1” site shown below).
2. Desired device trees can be expanded by clicking the «+» box. The following list
of headers is shown for each device:
• Device Definitions
• Settings
• Actual Values
•Commands
• Communications
3. Expand the Settings > Relay Setup list item and double click on Front Panel to
open the Front Panel settings window as shown below:
Interfaces
FIGURE 4–5: Main Window After Connection
4. The Front Panel settings window will open with a corresponding status indicator
5. If the status indica tor is red, verify that th e serial or Ethernet cable is properly
The Front Panel settings can now be edited, printed, or changed according to user
specifications. Other setpoint and commands windows can be displayed and edited
in a similar manner. Actual values windows are also available for display. These
windows can be locked, arranged, and resized at will.
Refer to the EnerVista 750/760 Setup Help File for additional information
about the using the software.
NOTE
GE Multilin
on the lower left of the EnerVista 750/760 Setup window.
connected to the relay, and that the relay has been properly configured for
communications (steps described earlier).
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Working with Setpoints and Setpoint Files750/760
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Working with Setpoints and Setpoint Files
Engaging a Device The EnerVista 750/760 Setup software may be used in on-line mode (relay
connected) to directly communicate with a 750/760 relay. Communicating relays
are organized and grouped by communication interfaces and into sites. Sites may
contain any number of relays selected from the SR or UR product series.
Entering Setpoints The System Setup page will be used as an example to illustrate the entering of
setpoints. In this example, we will be changing the current sensing setpoints.
1. Establish communications with the relay.
1. Select the Setpoint > System Setup menu item. This can be selected from
the device setpoint tree or the main window menu bar.
2. Select the
This will display three arrows: two to increment/decrement the value and
another to launch the numerical calculator.
PHASE CT PRIMARY setpoint by clicking anywhere in the parameter box.
Interfaces
3. Clicking the arrow at the end of the box displays a numerical keypad interface
that allows the user to enter a value within the setpoint range displayed near
the top of the keypad:
Click Accept to exit from the keypad and keep the new value. Click on Cancel
to exit from the keypad and retain the old value.
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Working with Setpoints and Setpoint Files
4. For setpoints requiring non-numerical pre-set values (e.g. BUS VT CONNECTION
TYPE above), clicking anywhere within the setpoint value box displays a drop-
down selection menu arrow. Select the desired value from this list.
5. For setpoints requiring an alphanumeric text string (e.g. message scratchpad
messages), the value may be entered directly within the setpoint value box.
6. In the Setpoint / System Setup dialog box, click on Store to save the values
into the 750/760. Click OK to accept any changes and exit the window. Click
Cancel to retain previous values and exit.
Feeder Management Relay
750/760
File Support Opening any EnerVista 750/760 Setup file will automatically launch the application
or provide focus to the already opened application. If the file is a settings file (has a
‘750’ or ‘760’ extension) which had been removed from the Settings List tree menu,
it will be added back to the Settings List tree.
New files will be automatically added to the tree, which is sorted alphabetically with
respect to settings file names.
Using Setpoints Files a) Overview
The EnerVista 750/760 Setup software interface supports three ways of handling
changes to relay settings:
•In off-line mode (relay disconnected) to create or edit relay settings files for
later download to communicating relays.
• Directly modifying relay settings while connected to a communicating relay,
then saving the settings when complete.
• Creating/editing settings files while connected to a communicating relay, then
saving them to the relay when complete.
Settings files are organized on the basis of file names assigned by the user. A
settings file contains data pertaining to the following types of relay settings:
• Device Definition
•Product Setup
•System Setup
• Grouped Elements
• Control Elements
• Inputs/Outputs
•Testing
Factory default values are supplied and can be restored after any changes.
The EnerVista 750/760 Setup display relay setpoints with the same hierarchy as the
front panel display. For specific details on setpoints, refer to Chapter 5.
Interfaces
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Working with Setpoints and Setpoint Files750/760
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b) Downloading and Saving Setpoints Files
Setpoints must be saved to a file on the local PC before performing any firmware
upgrades. Saving setpoints is also highly recommended before making any setpoint
changes or creating new setpoint files.
The EnerVista 750/760 Setup window, setpoint files are acc essed in the Settings List
control bar window or the Files Window. Use the following procedure to download
and save setpoint files to a local PC.
1. Ensure that the site and corresponding device(s) have been properly defined
and configured as shown in Connecting EnerVista 750/760 setup to the Relay on
page 4–14.
2. Select the desired device from the site list.
3. Select the File > Read Settings from Device menu item to obtain settings
information from the device.
4. After a few seconds of data retrieval, the software will request the name and
destination path of the setpoint file. The corresponding file extension will be
automatically assigned. Press Save to complete the process. A new entry will
be added to the tree, in the File pane, showing path and file name for the
setpoint file.
c) Adding Setpoints Files to the Environment
The EnerVista 750/760 Setup software provides the capability to review and
manage a large group of setpoint files. Use the following procedure to add a new or
existing file to the list.
1. In the files pane, right-click on ‘Files’ and select the Add Existing Setting File
item as shown:
2. The Open dialog box will appear, prompting the user to select a previously
saved setpoint file. As for any other MS Windows
file to be added then click Open. The new file and complete path will be added
to the file list.
d) Creating a New Setpoint File
The EnerVista 750/760 Setup software allows the user to create new setpoint files
independent of a connected device. These can be uploaded to a relay at a later date.
The following procedure illustrates how to create new setpoint files.
1. In the File pane, right click on ‘File’ and select the New Settings File item. The
EnerVista 750/760 Setup software displays the following box will appear,
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®
application, browse for the
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Working with Setpoints and Setpoint Files
allowing for the configuration of the setpoint file for the correct firmware
version. It is important to define the correct firmware version to ensure that
setpoints not available in a particular version are not downloaded into the relay.
2. Select the Device Type, Hardware Revision, and Firmware Version for the new
setpoint file.
3. For future reference, enter some useful information in the Description box to
facilitate the identification of the device and the purpose of the file.
4. To select a file name and path for the new file, click the button beside the Enter
File Name box.
5. Select the file name and path to store the file, or select any displayed file name
to update an existing file. All 750/760 setpoint files should have the extension
‘750’ or ‘760’ (for example, ‘feeder1.750’).
6. Click Save and OK to complete the process. Once this step is completed, the
new file, with a complete path, will be added to the EnerVista 750/760 Setup
software environment.
Feeder Management Relay
750/760
Interfaces
e) Upgrading Setpoint Files to a New Revision
It is often necessary to upgrade the revision code for a previously sav ed setpoi nt file
after the 750/760 firmware has been upgraded (for example, this is required for
firmware upgrades). This is illustrated in the following procedure.
1. Establish communications with the 750/760 relay.
2. Select the Actual > A5 Product Info menu item and record the Software
Revision identifier of the relay firmware.
3. Load the setpoint file to be upgraded into the EnerVista 750/760 Setup
environment as described in Adding Setpoints Files to the Environment on page
4–20.
4. In the File pane, select the saved setpoint file.
5. From the main window menu bar, select the File > Properties menu item and
note the File Version of the setpoint file. If this version (e.g. 5.00 shown
below) is different than the Software Revision code noted in step 2, select a
New File Version that matches the Software Revision code from the pull-down
menu.
For example, if the firmware revision is 27K700A4.000 (software revision 7.00)
and the current setpoint file revision is 5.00, change the setpoint file revision to
“7.0X”.
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Working with Setpoints and Setpoint Files750/760
Interfaces
Enter any special comments
about the setpoint file here.
Select the desired setpoint version
from this menu. The 6.0x indicates
versions 6.00, 6.01, 6.02, etc.
6. When complete, click Convert to convert the setpoint file to the desired revision.
A dialog box will request confirmation. See Loading Setpoints from a File on
page 4–23 for instructions on loading this setpoint file into the 750/760.
f) Printing Setpoints and Actual Values
The EnerVista 750/760 Setup software allows the user to print partial or complete
lists of setpoints and actual values. Use the following procedure to print a list of
setpoints:
1. Select a previously saved setpoints file in the File pane or establish
communications with a 750/760 device.
2. From the main window, select the File > Print Settings menu item.
3. The Print/Export Options dialog box will appear. Select Settings in the upper
section and select either Include All Features (for a complete list) or Include
Only Enabled Features (for a list of only those features which are currently
used) in the filtering section and click OK.
4. The process for File > Print Preview Settings is identical to the steps above.
Setpoints lists can be printed in the same manner by right clicking on the desired
file (in the file list) or device (in the device list) and selecting the Print Device
Information or Print Settings File options.
A complete list of actual values can also be printed from a connected device with the
following procedure:
1. Establish communications with the desired 750/760 device.
2. From the main window, select the File > Print Settings menu item.
3. The Print/Export Options dialog box will appear. Select Actual Values in the
upper section and select either Include All Features (for a complete list) or
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Include Only Enabled Features (for a list of only those features which are
currently used) in the filtering section and click OK.
Actual values lists can be printed in the same manner by right clicking on the
desired device (in the device list) and selecting the Print Device Information
option.
g) Loading Setpoints from a File
An error message will occur when attempting to download a setpoint file
WARNING
with a revision number that does not match the relay firmware. If the
firmware has been upgraded since saving the setpoint file, see Upgrading
Setpoint Files to a New Revision on page 4–21 for instructions on changing the
revision number of a setpoint file.
The following procedure illustrates how to load setpoints from a file. Before loading
a setpoints file, it must first be added to the EnerVista 750/760 Setup environment
as described in Adding Setpoints Files to the Environment on page 4–20.
1. Select the previously saved setpoints file from the File pane of the EnerVista
750/760 Setup software main window.
2. Select the File > Properties menu item and verify that the corresponding file
is fully compatible with the hardware and firmware version of the target relay. If
the versions are not identical, see Upgrading Setpoint Files to a New Revision on
page 4–21 for details on changing the setpoints file version.
3. Right-click on the selected file and select the Write Settings to Device item.
4. Select the target relay from the list of devices shown and click Send. If there is
an incompatibility, an error of following type will occur:
Feeder Management Relay
750/760
Interfaces
5. If there are no incompatibilities between the target device and th e settings file,
the data will be transferred to the relay. An indication of the percentage
completed will be shown in the bottom of the main window.
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Description To upgrade the 750/760 firmware, follow the procedures listed in this section. Upon
NOTE
Upgrading Relay Firmware750/760
Upgrading Relay Firmware
successful completion of this procedure, the 750/760 will have new firmware
installed with the original setpoints.
The latest firmware files are available from the GE Multilin website at http://
www.GEmultilin.com.
Units with bootware versions earlier than 3.00 must be set to a baud rate of 9600
with a Slave Address of 1 before downloading new firmware. The bootware version
can be checked in the
actual value.
A5 PRODUCT INFO ZV REVISION CODES ZV BOOTWARE REVISION
Interfaces
Saving Setpoints To A
File
Before upgrading firmware, it is very important to save the current 750/760 settings
to a file on your PC. After the firmware has been upgraded, it will be necessary to
load this file back into the 750/760.
Refer to Downloading and Saving Setpoints Files on page 4–20 for details on saving
relay setpoints to a file.
Loading New Firmware Loading new firmware into the 750/760 flash memory is accomplished as follows:
1. Connect the relay to the local PC and save the setpoints to a file as shown in
Downloading and Saving Setpoints Files on page 4–20.
2. Select the Communications > Update Firmware menu item.
3. The following warning message will appear. Select Yes to proceed or No the
cancel the process. Do not proceed unless you have saved the current
setpoints.
4. The EnerVista 750/760 Setup software will request the new firmware file.
Locate the firmware file to load into the 750/760. The firmware filename has the
following format:
5. The 750/760PC software automatically lists all filenames beginning with ‘27’.
Select the appropriate file and click OK to continue. This will be the Analog
Board file.
6. A second file request will be prompted. This will be for the Control Board file.
Both analog and control board files must have the same firmware
versions.
NOTE
7. The software will prompt with another Upload Firmware Warning window. This
will be the final chance to cancel the firmware upgrade before the flash memory
is erased. Click Yes to continue or No to cancel the upgrade.
4–24
27 K700 A4 . 000
http://www.GEmultilin.com
Modification Number (000 = none)
A4 = Analog Board file; C4 = Control Board file
Firmware Version
Required 750/760 hardware
Product code (27 = 750)
GE Multilin
Page 87
Advanced EnerVista 750/760 Setup Features
8. The EnerVista 750/760 Setup software now prepares the 750/760 to receive the
new firmware file. The 750/760 will display a message indicating that it is in
Upload Mode. While the file is being loaded into the 750/760, a status box
appears showing how much of the new firmware file has been transferred and
how much is remaining, as well as the upgrade status. The entire transfer
process takes approximately five minutes.
9. The EnerVista 750/760 Setup software will notify the user when the 750/760
has finished loading the file. Carefully read any displayed messages and click
OK to return the main screen.
Cycling power to the relay is recommended after a firmware upgrade.
Feeder Management Relay
750/760
NOTE
After successfully updating the 750/760 firmware, the relay will not be in service
and will require setpoint programming. To communicate with the relay, the following
settings will have to me manually programmed.
MODBUS COMMUNICATION ADDRESS
BAUD RATE
PARITY (if applicable)
When communications is established, the saved setpoints must be reloaded back
into the relay. See Loading Setpoints from a File on page 4–23 for details.
Modbus addresses assigned to firmware modules, features, settings, and
corresponding data items (i.e. default values, min/max values, data type, and item
size) may change slightly from version to version of firmware.
The addresses are rearranged when new features are added or ex istin g features are
enhanced or modified. The
upgrading/downgrading the firmware is a resettable, self-test message intended to
inform users that the Modbus addresses have changed with the upgraded firmware.
This message does not signal any problems when appearing after firmware
upgrades.
EEPROM DATA ERROR message displayed after
Advanced EnerVista 750/760 Setup Features
Triggered Events While the in te r fa c e is in e ith er o n- lin e or off-line mode, data generated by triggered
specified parameters can be viewed and analyzed via one of the following features:
• Event Recorder: The event recorder captures contextual data associated with
the last 512 events, listed in chronological order from most recent to the oldest.
• Oscillography: The oscillography waveform traces and digital states provide a
visual display of power system and relay operation data captured during specific
triggered events.
Interfaces
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Feeder Management Relay
Advanced EnerVista 750/760 Setup Features750/760
Interfaces
Waveform Capture
(Trace Memory)
The EnerVista 750/760 Setup software can be used to capture waveforms (or view
trace memory) from the 750/760 relay at the instance of a trip. A maximum of 512
cycles can be captured and the trigger point can be adjusted to anywhere within the
set cycles. A maximum of 16 waveforms can be buffered (stored) with the buffer/
cycle trade-off.
The following waveforms can be captured:
• Phase A, B, and C currents (I
• Ground and Sensitive ground currents (I
• Phase A-N, B-N, and C-N voltages (V
• Digital data for output relays and contact input states.
1. With EnerVista 750/760 Setup running and communications established, select
the Actual > Waveform Capture menu item to open the waveform capture
setup window:
, Ib, and Ic)
a
a
and Isg)
g
, Vb, and Vc)
Number of available files
Files to be saved or viewed
Click on Trigger Waveform to trigger a waveform capture.
The waveform file numbering starts with the number zero in the 750/760;
therefore, the maximum trigger number will always be one less then the total
number triggers available.
2. Click on the Save to File button to save the selected waveform to the local PC.
A new window will appear requesting for file name and path.
The file is saved as a COMTRADE File, with the extension ‘CFG’. In addition to
the COMTRADE file, two other files are saved. One is a CSV (comma delimited
values) file, which can be viewed and manipulated with compatible third-party
software. The other file is a DAT File, required by the COMTRADE file for proper
display of waveforms.
To view a previously saved COMTRADE File, click the Open button and select
the corresponding COMTRADE File.
Save waveform to a file
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Page 89
Advanced EnerVista 750/760 Setup Features
3. To view the captured waveforms, click the Launch Viewer button. A detailed
Waveform Capture window will appear as shown below:
Feeder Management Relay
750/760
TRIGGER TIME &DATE
Display the time & date of the
Trigger
VECTOR DISPLAY SELECT
Click here to open a new graph
to display vectors
CURSOR LINE POSITION
Indicate the cursor line position
in time with respect to the
trigger time
DELTA
Indicates time difference
between the two cursor lines
Interfaces
Display graph values
at the corresponding
cursor line. Cursor
lines are identified by
their colors.
FILE NAME
Indicates the
file name and
complete path
(if saved)
CURSOR
LINES
To move lines locate the mouse pointer
over the cursor line then click and drag
the cursor to the new location.
TRIGGER LINE
Indicates the
point in time for
the trigger
FIGURE 4–6: Waveform Capture Window Attributes
4. The red vertical line indicates the trigger point of the relay.
5. The date and time of the trip is displayed at the top left corner of the window. To
match the captured waveform with the event that triggered it, make note of the
time and date shown in the graph. Then, find the event that matches the same
time and date in the event recorde r. The event record will provide additional
information on the cause and the system conditions at the time of the event.
Additional information on how to download and save events is shown in Event
Recorder on page 4–29.
6. From the window main menu bar, press the Preference button to open the
Comtrade Setup page to change the graph attributes.
Preference button
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Page 90
Interfaces
Advanced EnerVista 750/760 Setup Features750/760
Feeder Management Relay
7. The following window will appear:
Change the Color of each graph as desired, and select other options as
required, by checking the appropriate boxes. Click OK to store these graph
attributes, and to close the window.
8. The Waveform Capture window will reappear with the selected graph attributes
available for use.
9. To view a vector graph of the quantities contained in the waveform capture,
press the Vector display button (see FIGURE 4–6: Waveform Capture Window
Attributes on page 4–27) to display the following window:
10. Use the graph attribute utility described in step 7 to change the vector colors.
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Page 91
Advanced EnerVista 750/760 Setup Features
EVENT LISTING
Lists the last 512 events
with the most recent
displayed at top of list.
EVENT SELECT BUTTONS
Click the All button to select
all events; click the None
button to clear all selections.
CLEAR EVENTS
Click the Clear
Events button to
clear the event list
from memory.
SAVE EVENTS
Click the Save Events
button to save the event
record to the PC as a
CSV file.
EVENT DATA
System information as
measured by the relay
at the instant of the
event occurrence.
DEVICE ID
The events shown here
correspond to this device.
EVENT NUMBER
The event data information
is related to the event number
shown here.
Data Logger The data logger feature is used to sample and record up to eight actual values at an
interval that is defined by the user. Refer to Event Recorder on page 5–11 for
additional details. The Data Logger window behaves in the same manner as the
Waveform Capture described above.
Event Recorder The 750/760 event recorder can be viewed through the EnerVista 750/760 Setup
software. The event recorder stores generator and system information each time an
event occurs (e.g. breaker failure). A maximum of 512 events can be stored, where
E512 is the most recent event and E001 is the oldest event. E001 is overwritten
whenever a new event occurs. Refer to Event Records on page 6–16 for additional
information on the event recorder.
Use the following procedure to view the event recorder with EnerVista 750/760
Setup:
1. With EnerVista 750/760 Setup running and communications established, select
the Actual > A4 Event Recorder item from the main menu. This displays the
Event Recorder window indicating the list of recorded events, with the most
current event displayed first.
Feeder Management Relay
750/760
Interfaces
GE Multilin
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4–29
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Advanced EnerVista 750/760 Setup Features750/760
Feeder Management Relay
2. T o view detailed information f or a given ev ent and the sys tem information at the
moment of the event occurrence, change the event number on the Select
Event box.
Modbus User Map The EnerVista 750/760 Setup software provides a means to program the 750/760
User Map (Modbus addresses 0180h to 01F7h). Refer to GE Publication GEK106473: 750/760 Communications Guide for additional information on the User
Map.
1. Select a connected device in EnerVista 750/760 Setup.
2. Select the Setpoint > User Map menu item to open the following window.
Interfaces
This window allows the desired addresses to be written to User Map locations.
The User Map values that correspond to these addresses are then displayed.
Viewing Actual Values You can view real-time relay data such as input/output status and measured
parameters. From the main window menu bar, selecting Actual Values opens a
window with tabs, each tab containing data in accordance to the following list:
• Status: Virtual Inputs, Hardware Inputs, Last Trip Data, Fault Locations, and
Autoreclose (760 Only)
• Metering: Current, Voltage, Frequency, Synchrocheck Voltage, Power, Energy,
Demand, and Analog Inputs
• Maintenance: Trip Counters and Arcing Current
• Product Information: Revision Codes and Calibration Dates
Selecting an actual values window also opens the actual values tree from the
corresponding device in the site list and highlights the current location in the
hierarchy.
For complete details on actual values, refer to Chapter 6.
To view a separate window for each group of actual values, select the desired item
from the tree, and double click with the left mouse button. Each group will be
opened on a separate tab. The windows can be re-arranged to maximize data
viewing as shown in the following figure (showing actual current, voltage, and
power values tiled in the same window):
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Page 93
Using EnerVista Viewpoint with the 750/760
Feeder Management Relay
750/760
FIGURE 4–7: Actual Values Display
Using EnerVista Viewpoint with the 750/760
Plug and Play Example EnerVista Viewpoint is an optional software package that puts critical 750/760
information onto any PC with plug-and-play simplicity. EnerVista Viewpoint connects
instantly to the 750/760 via serial, ethernet or modem and automatically generates
detailed overview, metering, power, demand, energy and analysis screens.
Installing EnerVista Launchpad (see previous section) allows the user to install a
fifteen-day trial version of EnerVista Viewpoint. After the fifteen day trial period you
will need to purchase a license to continue using EnerVista Viewpoint. Information
on license pricing can be found at http://www.EnerVista.com
1. Install the EnerVista Viewpoint software from the GE EnerVista CD.
2. Ensure that the 750/760 device has been properly configured for either serial or
Ethernet communications (see previous sections for details).
3. Click the Viewpoint window in EnerVista to log into EnerVista Viewpoint. At this
point, you will be required to provide a login and password if you have not
already done so.
.
Interfaces
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Interfaces
Using EnerVista Viewpoint with the 750/760750/760
Feeder Management Relay
FIGURE 4–8: EnerVista Viewpoint Main Window
4. Click the Device Setup button to open the Device Setup window, then click the
Add Site button to define a new site.
5. Enter the desired site name in the Site Name field. If desired, a short
description of site can also be entered along with the display order of devices
defined for the site. Click the OK button when complete. The new site will
appear in the upper-left list in the EnerVista 750/760 Setup window.
6. Click the Add Device button to define the new d evice.
7. Enter the desired name in the Device Name field and a description (optional)
of the site.
8. Select the appropriate communications interface (Ethernet or Serial) and fill in
the required information for the 750/760. See Connecting EnerVista 750/760
setup to the Relay on page 4–14 for details.
FIGURE 4–9: Device Setup Screen (Example)
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Using EnerVista Viewpoint with the 750/760
9. Click the Read Order Code button to connect to the 750/760 device and
upload the order code. If an communications error occurs, ensure that
communications values entered in the previous step correspond to the relay
setting values.
10. Click OK when complete.
11. From the EnerVista main window, select the IED Dashboard item to open the
Plug and Play IED dashboard. An icon for the 750/760 will be shown.
Feeder Management Relay
750/760
FIGURE 4–10: ‘Plug and Play’ Dashboard
12. Click the Dashboard button below the 750/760 icon to view the device
information. We hav e now successfully accessed ou r 750/760 through EnerVista
Viewpoint.
Interfaces
GE Multilin
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Page 96
Feeder Management Relay
Using EnerVista Viewpoint with the 750/760750/760
Interfaces
FIGURE 4–11: EnerVista Plug and Play Screens
For additional information on EnerVista viewpoint, please visit the EnerVista website
at http://www.EnerVista.com
4–34
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GE Multilin
Page 97
Overview
Feeder Management Relay
750/760
5 Setpoints
Overview
Setpoints Main Menu The 750/760 has a considerable number of programmable setpoints which makes it
extremely flexible. The setpoints have been grouped into a number of pages and
sub-pages as shown below. Each page of setpoints (e.g.
section which describes in detail all the setpoints found on that page.
S2 SYSTEM SETUP) has a
SETPOINTS [Z]
S1 RELAY SETUP
MESSAGE
MESSAGE
MESSAGE
MESSAGE
MESSAGE
MESSAGE
MESSAGE
MESSAGE
MESSAGE
MESSAGE
PASSCODE [Z]
COMMUNICATIONS [Z]
CLOCK [Z]
EVENT RECORDER [Z]
TRACE MEMORY [Z]
DATA LOGGER [Z]
FRONT PANEL [Z]
DEFAULT [Z]
MESSAGES
USER TEXT [Z]
MESSAGES
CLEAR DATA [Z]
INSTALLATION [Z]
See page 5–7.
See page 5–8.
Setpoints
See page 5–10.
See page 5–11.
See page 5–11.
See page 5–12.
See page 5–13.
See page 5–14.
See page 5–15.
See page 5–15.
See page 5–16.
GE Multilin
MESSAGE
MESSAGE
MOD 008 [Z]
UPGRADE
END OF PAGE S1
http://www.GEmultilin.com
See page 5–16.
5–1
Page 98
Feeder Management Relay
Overview750/760
MESSAGE
SETPOINTS [Z]
S2 SYSTEM SETUP
MESSAGE
MESSAGE
MESSAGE
MESSAGE
MESSAGE
MESSAGE
MESSAGE
SETPOINTS [Z]
S3 LOGIC INPUTS
MESSAGE
MESSAGE
CURRENT [Z]
SENSING
BUS VT [Z]
SENSING
LINE VT [Z]
SENSING
POWER SYSTEM [Z]
FLEXCURVE A [Z]
FLEXCURVE B [Z]
END OF PAGE S2
LOGIC INPUTS [Z]
SETUP
BREAKER [Z]
FUNCTIONS
CONTROL [Z]
FUNCTIONS
See page 5–17.
See page 5–17.
See page 5–18.
See page 5–18.
See page 5–18.
See page 5–18.
See page 5–20.
See page 5–21.
See page 5–22.
Setpoints
MESSAGE
MESSAGE
MESSAGE
MESSAGE
MESSAGE
MESSAGE
MESSAGE
MESSAGE
SETPOINTS [Z]
S4 OUTPUT RELAYS
MESSAGE
MESSAGE
USER INPUTS [Z]
BLOCK [Z]
FUNCTIONS
BLOCK OC [Z]
FUNCTIONS
TRANSFER [Z]
FUNCTIONS
RECLOSE [Z]
FUNCTIONS
MISC [Z]
FUNCTIONS
END OF PAGE S3
1 TRIP RELAY [Z]
2 CLOSE RELAY [Z]
3 AUXILIARY [Z]
See page 5–23.
See page 5–24.
See page 5–25.
See page 5–26.
See page 5–27.
See page 5–27.
See page 5–29.
See page 5–30.
See page 5–31.
5–2
MESSAGE
4 AUXILIARY [Z]
http://www.GEmultilin.com
See page 5–31.
GE Multilin
Page 99
Overview
Feeder Management Relay
750/760
MESSAGE
MESSAGE
MESSAGE
MESSAGE
MESSAGE
SETPOINTS [Z]
S5 PROTECTION
MESSAGE
MESSAGE
MESSAGE
MESSAGE
MESSAGE
5 AUXILIARY [Z]
6 AUXILIARY [Z]
7 AUXILIARY [Z]
END OF PAGE S4
PHASE [Z]
CURRENT
NEUTRAL [Z]
CURRENT
GROUND [Z]
CURRENT
SENSTV GND [Z]
CURRENT
NEGATIVE [Z]
SEQUENCE
VOLTAGE [Z]
See page 5–31.
See page 5–31.
See page 5–31.
See page 5–37.
See page 5–43.
See page 5–48.
See page 5–52.
See page 5–59.
See page 5–64.
MESSAGE
SETPOINTS
S6 MONITORING
MESSAGE
MESSAGE
MESSAGE
MESSAGE
MESSAGE
MESSAGE
MESSAGE
MESSAGE
MESSAGE
FREQUENCY [Z]
BREAKER [Z]
FAILURE
REVERSE [Z]
POWER
END OF PAGE S5
CURRENT LEVEL [Z]
POWER FACTOR [Z]
FAULT LOCATOR [Z]
DEMAND [Z]
ANALOG INPUT [Z]
ANALOG OUTPUTS [Z]
See page 5–69.
See page 5–72.
See page 5–73.
See page 5–74.
See page 5–75.
See page 5–77.
See page 5–79.
See page 5–84.
See page 5–87.
Setpoints
GE Multilin
MESSAGE
MESSAGE
OVERFREQUENCY [Z]
EQUIPMENT [Z]
http://www.GEmultilin.com
See page 5–89.
See page 5–90.
5–3
Page 100
Feeder Management Relay
Overview750/760
MESSAGE
SETPOINTS
S7 CONTROL
MESSAGE
MESSAGE
MESSAGE
MESSAGE
MESSAGE
MESSAGE
MESSAGE
MESSAGE
MESSAGE
PULSED OUTPUT [Z]
END OF PAGE S6
SETPOINT [Z]
GROUPS
SYNCHROCHECK [Z]
MANUAL CLOSE [Z]
COLD LOAD [Z]
PICKUP
UNDERVOLTAGE [Z]
RESTORATION
UNDERFREQUENCY [Z]
RESTORATION
TRANSFER [Z]
AUTORECLOSE [Z]
See page 5–96.
See page 5–97.
See page 5–100.
See page 5–102.
See page 5–104.
See page 5–106.
See page 5–107.
See page 5–108.
See page 5–122.
Setpoints
Setpoint Entry Methods Prior to placing the relay in operation, setpoints defining system characteristics,
MESSAGE
MESSAGE
SETPOINTS
S8 TESTING
MESSAGE
MESSAGE
MESSAGE
MESSAGE
END OF PAGE S7
OUTPUT RELAYS [Z]
PICKUP TEST [Z]
ANALOG OUTPUTS [Z]
SIMULATION [Z]
END OF PAGE S8
See page 5–133.
See page 5–134.
See page 5–134.
See page 5–135.
inputs, relay outputs, and protection settings must be entered, via one of the
following methods:
• Front panel, using the keys and display.
• Front program port, and a portable computer running the EnerVista 750/760
Setup software supplied with the relay.
• Rear RS485/RS422 COM1 port or RS485 COM2 port and a SCADA system
running user-written software.
Any of these methods can be used to enter the same information. A computer,
however, makes entry much easier. Files can be stored and downloaded for fast,
error free entry when a computer is used. To facilitate this process, the GE EnerVista
CD with the EnerVista 750/760 Setup software is supplied with the relay.
5–4
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