GE Feeder Management Relay 750 User manual

750/760
Feeder Management Relay®
Instruction Manual
Firmware Rev: 5.X
Manual P/N: 1601-0044-AP (GEK-106293D)
Copyright © 2006 GE Multilin
GE Multilin
215 Anderson Avenue, Markham, Ontario
Canada L6E 1B3
Tel: [phone] Fax: [phone]
Internet: http://www.GEindustrial.com/multilin
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GE Industrial Systems
760 Feeder Management
®
818789A4.CDR
RELAY IN SERVICE
760 STATUS SYSTEM STATUS OUTPUT STATUS
BREAKER OPEN 1 TRIP
TRIP BREAKER CLOSED 2 CLOSE
ALARM RECLOSURE
ENABLED 3 AUXILIARY
PICKUP RECLOSURE
DISABLED 4 AUXILIARY
SETPOINT
GROUP 1
SETPOINT
GROUP 2
SETPOINT
GROUP 3
SETPOINT
GROUP 4
RECLOSURE
IN PROGRESS 5 AUXILIARY
RESET OPEN
NEXT
SETPOINT
MESSAGE
VALUE
ACTUAL
CLEAR
STORE
CLOSE
RECLOSURE
LOCKOUT 6 AUXILIARY
LOCAL 7 AUXILIARY
8
PROGRAM PORT
PROGRAM PORT
REMOTE
BREAKER
SELF-TEST
WARNING
789
456
12
0
3
HELP
.
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ISO9001:2000
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GE Multilin's Quality
Management System is
registered to ISO9001:2000
QMI # 005094
UL # A3775
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GE Multilin 750/760 Feeder Management Relay i
TABLE OF CONTENTS
1. GETTING STARTED 1.1 IMPORTANT PROCEDURES
1.1.1 Cautions and Warnings...................................................................................... 1-1
1.1.2 Manual Organization .......................................................................................... 1-1
1.1.3 Inspection Checklist ........................................................................................... 1-1
1.2 USING THE RELAY
1.2.1 Menu Navigation ................................................................................................ 1-2
1.2.2 Panel Keying Example ....................................................................................... 1-3
1.2.3 Changing Setpoints............................................................................................ 1-3
1.2.4 Application Example........................................................................................... 1-5
1.2.5 Commissioning................................................................................................... 1-8
2. INTRODUCTION 2.1 OVERVIEW
2.1.1 Description ......................................................................................................... 2-1
2.1.2 Theory of Operation ........................................................................................... 2-3
2.1.3 Ordering ............................................................................................................. 2-5
2.2 SPECIFICATIONS
2.2.1 Applicability ........................................................................................................ 2-6
2.2.2 Inputs ................................................................................................................. 2-6
2.2.3 Measured Parameters........................................................................................ 2-7
2.2.4 Protection Elements ........................................................................................... 2-7
2.2.5 Monitoring Elements .......................................................................................... 2-9
2.2.6 Control Elements.............................................................................................. 2-10
2.2.7 Outputs............................................................................................................. 2-11
2.2.8 Output Relays .................................................................................................. 2-11
2.2.9 CPU.................................................................................................................. 2-11
2.2.10 Physical............................................................................................................ 2-12
2.2.11 Testing ............................................................................................................. 2-12
2.2.12 Approvals ......................................................................................................... 2-12
3. INSTALLATION 3.1 MECHANICAL
3.1.1 Drawout Case .................................................................................................... 3-1
3.1.2 Installation .......................................................................................................... 3-2
3.1.3 Unit Withdrawal and Insertion ............................................................................ 3-3
3.1.4 Rear Terminal Layout......................................................................................... 3-5
3.2 ELECTRICAL
3.2.1 Typical Wiring..................................................................................................... 3-7
3.2.2 Phase Sequence and Transformer Polarity ....................................................... 3-8
3.2.3 Current Inputs .................................................................................................... 3-8
3.2.4 Voltage Inputs .................................................................................................. 3-11
3.2.5 Control Power .................................................................................................. 3-12
3.2.6 Trip/Close Coil Supervision.............................................................................. 3-12
3.2.7 Logic Inputs...................................................................................................... 3-14
3.2.8 Analog Input ..................................................................................................... 3-14
3.2.9 Analog Outputs ................................................................................................ 3-15
3.2.10 RS485 and RS422 Communications ............................................................... 3-16
3.2.11 RS232 Communications .................................................................................. 3-18
3.2.12 IRIG-B .............................................................................................................. 3-18
4. USER INTERFACES 4.1 FRONT PANEL INTERFACE
4.1.1 Description ......................................................................................................... 4-1
4.1.2 LED Status Indicators ........................................................................................ 4-2
4.1.3 Keypad Operation .............................................................................................. 4-3
4.1.4 Messages........................................................................................................... 4-4
4.2 750/760PC SOFTWARE INTERFACE
4.2.1 Description ......................................................................................................... 4-7
4.2.2 Requirements..................................................................................................... 4-7
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TABLE OF CONTENTS
4.2.3 Hardware Configuration......................................................................................4-7
4.2.4 Installation/Upgrade............................................................................................4-8
4.2.5 Startup and Communications Configuration .....................................................4-10
4.2.6 Using 750/760PC..............................................................................................4-11
4.2.7 Advanced 750/760PC Features........................................................................4-15
5. SETPOINTS 5.1 OVERVIEW
5.1.1 Setpoints Message Map .....................................................................................5-1
5.1.2 Setpoint Entry Methods ......................................................................................5-4
5.1.3 Setpoint Access Security ....................................................................................5-4
5.1.4 Common Setpoints .............................................................................................5-4
5.1.5 Logic Diagrams...................................................................................................5-6
5.2 S1 RELAY SETUP
5.2.1 Passcode ............................................................................................................5-7
5.2.2 Communications .................................................................................................5-7
5.2.3 Clock.................................................................................................................5-10
5.2.4 Event Recorder.................................................................................................5-10
5.2.5 Trace Memory...................................................................................................5-11
5.2.6 Data Logger ......................................................................................................5-12
5.2.7 Front Panel .......................................................................................................5-13
5.2.8 Default Messages .............................................................................................5-14
5.2.9 User Text Messages.........................................................................................5-14
5.2.10 Clear Data.........................................................................................................5-15
5.2.11 Installation.........................................................................................................5-15
5.3 S2 SYSTEM SETUP
5.3.1 Current Sensing................................................................................................5-16
5.3.2 Bus VT Sensing ................................................................................................5-16
5.3.3 Line VT Sensing ...............................................................................................5-17
5.3.4 Power System...................................................................................................5-17
5.3.5 FlexCurves™ ....................................................................................................5-18
5.4 S3 LOGIC INPUTS
5.4.1 Overview...........................................................................................................5-19
5.4.2 Logic Inputs Setup ............................................................................................5-19
5.4.3 Breaker Functions.............................................................................................5-21
5.4.4 Control Functions..............................................................................................5-22
5.4.5 User Inputs .......................................................................................................5-22
5.4.6 Block Functions ................................................................................................5-23
5.4.7 Block Overcurrent Functions ............................................................................5-24
5.4.8 Transfer Functions............................................................................................5-25
5.4.9 Reclose Functions (760 Only) ..........................................................................5-26
5.4.10 Miscellaneous Functions ..................................................................................5-26
5.5 S4 OUTPUT RELAYS
5.5.1 Relay Operation................................................................................................5-27
5.5.2 Trip Relay .........................................................................................................5-28
5.5.3 Close Relay ......................................................................................................5-29
5.5.4 Auxiliary Relays ................................................................................................5-30
5.5.5 Self-Test Warning Relay...................................................................................5-31
5.6 S5 PROTECTION
5.6.1 Overview...........................................................................................................5-32
5.6.2 Phase Current...................................................................................................5-36
5.6.3 Neutral Current .................................................................................................5-42
5.6.4 Ground Current.................................................................................................5-47
5.6.5 Sensitive Ground Current .................................................................................5-51
5.6.6 Negative Sequence ..........................................................................................5-58
5.6.7 Voltage..............................................................................................................5-63
5.6.8 Frequency.........................................................................................................5-68
5.6.9 Breaker Failure .................................................................................................5-71
5.6.10 Reverse Power (if Enabled)..............................................................................5-72
5.7 S6 MONITORING
5.7.1 Current Level ....................................................................................................5-73
5.7.2 Power Factor ....................................................................................................5-75
5.7.3 Fault Locator.....................................................................................................5-76
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TABLE OF CONTENTS
5.7.4 Demand............................................................................................................ 5-78
5.7.5 Analog Input ..................................................................................................... 5-83
5.7.6 Analog Outputs ................................................................................................ 5-86
5.7.7 Overfrequency.................................................................................................. 5-88
5.7.8 Equipment ........................................................................................................ 5-89
5.7.9 Pulse Output .................................................................................................... 5-95
5.8 S7 CONTROL
5.8.1 Setpoint Groups ............................................................................................... 5-96
5.8.2 Synchrocheck................................................................................................... 5-99
5.8.3 Manual Close Blocking................................................................................... 5-101
5.8.4 Cold Load Pickup Blocking ............................................................................ 5-103
5.8.5 Undervoltage Restoration .............................................................................. 5-105
5.8.6 Underfrequency Restoration .......................................................................... 5-106
5.8.7 Transfer.......................................................................................................... 5-107
5.8.8 Autoreclose (760 only) ................................................................................... 5-118
5.9 S8 TESTING
5.9.1 Output Relays ................................................................................................ 5-129
5.9.2 Pickup Test .................................................................................................... 5-130
5.9.3 Analog Outputs .............................................................................................. 5-130
5.9.4 Simulation ...................................................................................................... 5-131
5.9.5 Factory Service .............................................................................................. 5-134
6. ACTUAL VALUES 6.1 OVERVIEW
6.1.1 Actual Values Main Menu .................................................................................. 6-1
6.2 A1 STATUS
6.2.1 Virtual Inputs ...................................................................................................... 6-5
6.2.2 Hardware Inputs................................................................................................. 6-5
6.2.3 Last Trip Data..................................................................................................... 6-6
6.2.4 Fault Locations................................................................................................... 6-7
6.2.5 Clock .................................................................................................................. 6-7
6.2.6 Autoreclose (760 only) ....................................................................................... 6-7
6.3 A2 METERING
6.3.1 Metering Conventions ........................................................................................ 6-8
6.3.2 Current ............................................................................................................... 6-9
6.3.3 Voltage ............................................................................................................. 6-10
6.3.4 Frequency ........................................................................................................ 6-11
6.3.5 Synchronizing Voltage ..................................................................................... 6-11
6.3.6 Power ............................................................................................................... 6-11
6.3.7 Energy.............................................................................................................. 6-12
6.3.8 Demand............................................................................................................ 6-13
6.3.9 Analog Input ..................................................................................................... 6-14
6.4 A3 MAINTENANCE
6.4.1 Trip Counters ................................................................................................... 6-15
6.4.2 Arcing Current .................................................................................................. 6-15
6.5 A4 EVENT RECORDER
6.5.1 Event Records.................................................................................................. 6-16
6.5.2 Last Reset Date ............................................................................................... 6-18
6.6 A5 PRODUCT INFO
6.6.1 Technical Support ............................................................................................ 6-19
6.6.2 Revision Codes ................................................................................................ 6-19
6.6.3 Calibration Dates.............................................................................................. 6-19
7. COMMUNICATIONS 7.1 OVERVIEW
7.1.1 Protocols ............................................................................................................ 7-1
7.1.2 Physical Layer.................................................................................................... 7-1
7.2 MODBUS PROTOCOL
7.2.1 Description ......................................................................................................... 7-2
7.2.2 Data Link Layer .................................................................................................. 7-2
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TABLE OF CONTENTS
7.2.3 CRC-16 Algorithm...............................................................................................7-3
7.2.4 Message Timing .................................................................................................7-3
7.3 MODBUS OPERATIONS
7.3.1 Modbus Function Codes.....................................................................................7-4
7.3.2 Exception Responses .........................................................................................7-7
7.3.3 Clock Synchronization of Multiple Relays...........................................................7-8
7.3.4 Reading the Event Recorder ..............................................................................7-9
7.3.5 Reading Trace Memory ....................................................................................7-10
7.3.6 Reading the Data Logger..................................................................................7-11
7.3.7 Accessing Data via the User Map.....................................................................7-11
7.3.8 Memory Map Organization ...............................................................................7-12
7.4 MODBUS MEMORY MAP
7.4.1 Memory Map.....................................................................................................7-13
7.4.2 Data Formats ....................................................................................................7-40
7.5 DNP COMMUNICATIONS
7.5.1 Device Profile Document ..................................................................................7-49
7.5.2 DNP Implementation.........................................................................................7-51
7.5.3 DNP Point Lists.................................................................................................7-52
8. COMMISSIONING TESTS 8.1 OVERVIEW
8.1.1 Safety Precautions..............................................................................................8-1
8.1.2 Requirements .....................................................................................................8-1
8.1.3 Conventions........................................................................................................8-2
8.1.4 Test Equipment...................................................................................................8-2
8.1.5 Installation Checks..............................................................................................8-2
8.1.6 Wiring Diagrams .................................................................................................8-3
8.2 INPUTS/OUTPUTS
8.2.1 Logic/Virtual Inputs 1 to 14 .................................................................................8-4
8.2.2 Virtual Inputs 15 to 20.........................................................................................8-8
8.2.3 Output Relays .....................................................................................................8-9
8.3 METERING
8.3.1 Current Metering...............................................................................................8-10
8.3.2 Voltage Metering...............................................................................................8-10
8.3.3 Power Metering.................................................................................................8-12
8.3.4 Demand Metering .............................................................................................8-13
8.3.5 Analog Input Metering.......................................................................................8-15
8.4 PROTECTION SCHEMES
8.4.1 Setpoint Groups................................................................................................8-16
8.4.2 Phase Overcurrent............................................................................................8-16
8.4.3 Neutral Overcurrent ..........................................................................................8-20
8.4.4 Ground Overcurrent..........................................................................................8-23
8.4.5 Negative-Sequence Overcurrent and Voltage ..................................................8-24
8.4.6 Voltage..............................................................................................................8-25
8.4.7 Frequency.........................................................................................................8-29
8.4.8 Breaker Failure .................................................................................................8-31
8.4.9 Reverse Power .................................................................................................8-32
8.5 MONITORING
8.5.1 Current Monitoring ............................................................................................8-33
8.5.2 Fault Locator.....................................................................................................8-33
8.5.3 Demand Monitoring ..........................................................................................8-34
8.5.4 Analog Inputs....................................................................................................8-35
8.5.5 Overfrequency Monitoring ................................................................................8-35
8.5.6 Power Factor ....................................................................................................8-36
8.5.7 VT Failure .........................................................................................................8-36
8.5.8 Trip Coil Monitor ...............................................................................................8-37
8.5.9 Close Coil Monitor ............................................................................................8-37
8.5.10 Breaker Operation Failure ................................................................................8-37
8.5.11 Arcing Current...................................................................................................8-38
8.5.12 Analog Output Channels...................................................................................8-38
8.5.13 IRIG-B...............................................................................................................8-38
8.5.14 Pulse Output .....................................................................................................8-38
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TABLE OF CONTENTS
8.6 CONTROL SCHEMES
8.6.1 Setpoint Group Control .................................................................................... 8-39
8.6.2 Synchrocheck................................................................................................... 8-40
8.6.3 Manual Close Feature Blocking ....................................................................... 8-42
8.6.4 Cold Load Pickup Blocking .............................................................................. 8-43
8.6.5 Undervoltage Restoration ................................................................................ 8-44
8.6.6 Underfrequency Restoration ............................................................................ 8-46
8.6.7 Transfer Scheme.............................................................................................. 8-47
8.6.8 Autoreclose (760 only) ..................................................................................... 8-52
8.7 PLACING THE RELAY IN SERVICE
8.7.1 Description ....................................................................................................... 8-56
8.7.2 On-Load Testing .............................................................................................. 8-56
8.7.3 Dielectric Strength Testing ............................................................................... 8-57
A. APPENDIX A.1 RELAY MODS
A.1.1 Reverse Power...................................................................................................A-1
A.2 CONFORMITY
A.2.1 EU Declaration of Conformity.............................................................................A-3
A.3 WARRANTY
A.3.1 GE Multilin Warranty ..........................................................................................A-4
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vi 750/760 Feeder Management Relay GE Multilin
TABLE OF CONTENTS
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GE Multilin 750/760 Feeder Management Relay 1-1
1 GETTING STARTED 1.1 IMPORTANT PROCEDURES
1
1 GETTING STARTED 1.1IMPORTANT PROCEDURES
Please read this chapter to help guide you through the initial setup of your new relay.
1.1.1 CAUTIONS AND WARNINGS
Before attempting to install or use the relay, it is imperative that all WARNINGS and CAU-
TIONS in this manual are reviewed to help prevent personal injury, equipment damage, and/
or downtime.
1.1.2 MANUAL ORGANIZATION
Reading a lengthy instruction manual on a new product is not a task most people enjoy. To speed things up, this introduc-
tory chapter provides a step-by-step tutorial for a simple feeder application. Important wiring considerations and precau-
tions discussed in Chapter 3: Installation should be observed for reliable operation. Detailed information regarding
accuracy, output relay contact ratings, and so forth are detailed in Section 2.2: Specifications. 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 ÖØ DMND ÖPHASE A CURRENT ÖLAST PHASE A CURRENT DMND
This “path representation” shows how to navigate menus and sub-menus to get to a specific setpoint or value (in the exam-
ple above, LAST PHASE A CURRENT DMND). The forward arrows indicate entering a new sub-menu to arrive at a message;
the down arrows indicate scrolling through a sub-menu to arrive at a message. See 1.2.1: Menu Navigation on page 1–2 for
an example of how to navigate setpoints and actual values messages from the relay front panel.
1.1.3 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 Multilin Products CD (includes the 750/760PC software and manuals in PDF format)
• mounting screws
• registration card (attached as the last page of the manual)
• Fill out the registration form and mail it back to GE Multilin (include the serial number located on the rear nameplate).
• For product information, instruction manual updates, and the latest software updates, please visit the GE Multilin web-
site at www.GEindustrial.com/multilin.
If there is any noticeable physical damage, or any of the contents listed are missing, please contact GE
Multilin immediately.
GE MULTILIN CONTACT INFORMATION AND CALL CENTER FOR PRODUCT SUPPORT:
GE Multilin
215 Anderson Avenue
Markham, Ontario
Canada L6E 1B3
TELEPHONE: [phone] (North America only)
FAX: [phone]
E-MAIL: i[email protected]
HOME PAGE: http://www.GEindustrial.com/multilin
WARNING CAUTION
NOTE
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1-2 750/760 Feeder Management Relay GE Multilin
1.2 USING THE RELAY 1 GETTING STARTED
1
1.2USING THE RELAY 1.2.1 MENU NAVIGATION
The relay has five types of display messages: actual value, setpoint, diagnostic, flash, and help. Actual values are values
that are measured by the relay such as current and voltage. 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 Sec-
tions 5.1.1: Setpoints Message Map on page 5–1 and 6.1.1: Actual Values Main Menu on page 6–1, respectively.
1. Press the 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. Repeatedly pressing the key will scroll through all the available actual values page headers.
2. Press the key to display the header for the first setpoints page. The setpoint pages are numbered, have an 'S'
prefix for easy identification and have a name which gives a general idea of the settings available in that page. Repeat-
edly pressing the key will scroll through all the available setpoint page headers.
3. Press the key until the A2 METERING page appears. Now press the key and the first sub-page head-
ing for Page 2 of actual values appears. Pressing the and keys will scroll the display up and down
through the sub-page headers.
4. Press the key until the DMND sub-page heading appears. Press to display the messages in this sub-
page.
5. Note that all heading messages have the symbol preceding them and that only some sub-pages have a subsequent
second sub-page.
6. Press the key to display the actual values of this second sub-page. Actual values messages and setpoints
always have a colon separating the name of the value and the actual value or setpoint. This particular message dis-
plays the last Phase A current demand as measured by the relay. The menu path to this particular message is referred
to as A2 METERING ÖØ DMND ÖPHASE A CURRENT ÖLAST PHASE A CURRENT DMND. Messages are referred to in this
manner throughout the manual.
7. Press the key and the next actual value display message will appear. Pressing the and
keys will scroll the display up and down through all the actual value displays in this second sub-page.
8. Pressing the key reverses the process described above and returns the display to the previous level. Press the
key twice to return to the A2 METERING ÖØ DMND sub-page header.
 ACTUAL VALUES
 A1 STATUS
 SETPOINTS
 S1 RELAY SETUP
CURRENT
[ENTER] for more
DMND
[ENTER] for more
PHASE A CURRENT
[ENTER] for more
LAST PHASE A CURRENT
DMND: 0 A
MAX PHASE A CURRENT
DMND: 0 A
PHASE A CURRENT
[ENTER] for more
ACTUAL
ACTUAL
SETPOINT
SETPOINT
ACTUAL
MESSAGE
MESSAGE
MESSAGE
MESSAGE ENTER
ENTER
MESSAGE
MESSAGE
MESSAGE
ESCAPE
ESCAPE
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GE Multilin 750/760 Feeder Management Relay 1-3
1 GETTING STARTED 1.2 USING THE RELAY
1
1.2.2 PANEL KEYING EXAMPLE
The following figure gives a specific example of the keypad is used to navigate through the menu structure. Specific loca-
tions are referred to throughout this manual by using a path. The example shown in the figure gives the key presses
required to reach the point given by the path A3 MAINTENANCE ÖØ ARCING CURRENT ÖØ TOTAL ARCING CURRENT ∅B.
1.2.3 CHANGING SETPOINTS
a) INTRODUCTION
There are several classes of setpoints, each distinguished by the way their values are displayed and edited. Now that we
have become more familiar 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
access terminals (C10 and C11) on the back of the relay case. Attempts to enter a new setpoint without this electrical con-
nection will result in an error message.
b) THE HELP KEY
Pressing the 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.
c) NUMERICAL SETPOINTS
Each numerical setpoint has its own minimum, maximum, and step value associated with it. These parameters define what
is acceptable for the setpoint. Two methods of editing and storing a numerical setpoint value are available.
The 750/760 numeric keypad works the same as any electronic calculator. A number is entered one digit at a time with the
0 to 9 and decimal keys. The leftmost digit is entered first and the rightmost digit is entered last. Pressing the key
before the key returns the original value to the display.
The key increments the displayed value by the step value, up to a maximum allowed and then wraps around to the
minimum value. The key decrements the displayed value by the step value, down to a minimum value and then
wraps around to the maximum value.
1. Move to the S2 SYSTEM SETUP ÖØ BUS VT SENSING ÖØ NOMINAL VT SECONDARY VOLTAGE setpoint message.
2. Press the 6, 3, decimal, and 9 keys. The display message will change as shown.
 ACTUAL VALUES
 A1 STATUS
 ACTUAL VALUES
 A2 METERING
 ACTUAL VALUES
 A3 MAINTENANCE
TRIP COUNTERS
[ENTER] for more
ARCING CURRENT
[ENTER] for more
TOTAL ARCING CURRENT
φA: 0kA2- cycle
TOTAL ARCING CURRENT
φB: 0kA2- cycle
NOMINAL VT SECONDARY
VOLTAGE: 120.0 V
NOMINAL VT SECONDARY
VOLTAGE: 63.9 V
ACTUAL
ACTUAL
MESSAGE
MESSAGE ENTER
MESSAGE
HELP
ESCAPE
ENTER
VALUE
VALUE
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1-4 750/760 Feeder Management Relay GE Multilin
1.2 USING THE RELAY 1 GETTING STARTED
1
3. Until the key is pressed, editing changes are not registered by the relay. Therefore, press the key to store
the new value in memory. This flash message will momentarily appear as confirmation of the storing process. If 69.28
were entered, it would be automatically rounded to 69.3.
d) 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 and keys.
1. Move to the S2 SYSTEM SETUP ÖØ BUS VT SENSING ÖVT CONNECTION TYPE setpoint message.
2. Press the key until the "Delta" value is displayed as shown (in this manual, setpoint values are always shown
in double quotation marks).
3. Press the key to store this change into memory. As before, confirmation of this action will momentarily flash on
the display.
e) 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 individu-
ally, 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. Move to the S5 PROTECTION ÖØ PHASE CURRENT ÖPHASE TIME O/C 1 ÖØ PHASE TIME O/C 1 RELAYS (3-7) setpoint mes-
sage.
2. If an application requires the Phase TOC protection element to operate the 3 Auxiliary output relay, select this output
relay by pressing the 3 key.
3. Press the 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.
f) TEXT SETPOINTS
Text setpoints have data values which are fixed in length, but user defined in character. They may be 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 , , , and keys.
NEW SETPOINT
STORED
VT CONNECTION TYPE:
Wye
VT CONNECTION TYPE:
Delta
NEW SETPOINT
STORED
PHASE TIME O/C 1
RELAYS (3-7): -----
PHASE TIME O/C 1
RELAYS (3-7): 3----
NEW SETPOINT
STORED
ENTER ENTER
VALUE
VALUE
VALUE
ENTER
ENTER
ENTER VALUE
VALUE
ESCAPE
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GE Multilin 750/760 Feeder Management Relay 1-5
1 GETTING STARTED 1.2 USING THE RELAY
1
1. Move to message S3 LOGIC INPUTS ÖUSER INPUT A ÖUSER INPUT A NAME setpoint message. The name of this user
defined input is going to be changed in this section.
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 key and a solid cursor () will appear in the first character position.
3. Press the or key until the character "S" is displayed in the first position. Now press the 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 key repeatedly until the
cursor returns to the position of the error. Re-enter the character as required. Once complete, press the key to
remove the solid cursor and view the result.
1.2.4 APPLICATION EXAMPLE
a) DESCRIPTION
The 750 and 760 relays contain many features designed to accommodate a wide range of applications. This chapter is pro-
vided to guide you, the first time user, through a real-world application. The following step-by-step installation example, pro-
vides you with a quick and convenient way of becoming familiar with 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 set-
points are unaltered from their factory default values.
• Power System Data
System: 3Φ, 4 wire
Frequency: 60 Hz
Line Voltage: 13.8 kV
Maximum Current: 600 A
• Control System Requirements
All protection elements used are to trip the breaker.
Breaker position monitoring via 52b contact only.
Only current metering is required.
Contact Inputs: Remote open and close contacts from RTU. Remote/local selection from panel hand switch. Reset
from RTU. Alarm after 100 second delay from substation monitor
Contact Outputs: Trip and close to breaker control circuit (trip and close relays). Relay failure alarm to RTU (self-test
warning relay, no programming required). Alarm contact to RTU (setup in User Function for “Substation Monitor”)
No data communications to other equipment.
• Instrument Transformer Data
Bus VTs: 3 ×Wye connected, ratio = 14.4 kV:120 V
Phase CTs: 3 ×Wye connected, ratio = 600:5 A
• Phase Protection Settings
Time Overcurrent 1: Curve Shape = Moderately Inverse; Pickup = 840 A; Multiplier = 20.2
Instantaneous Overcurrent 1: Pickup = 840 A; Phases Required = Any Two; Delay = 0 seconds
Instantaneous Overcurrent 2: Pickup = 10100 A; Phases Required = Any Two; Delay = 0 seconds
USER INPUT A NAME:
User Input A
USER INPUT A NAME:
ser Input A
USER INPUT A NAME:
Substation Monitor
ENTER
VALUE
VALUE
ENTER
ENTER
ESCAPE
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1-6 750/760 Feeder Management Relay GE Multilin
1.2 USING THE RELAY 1 GETTING STARTED
1
• Neutral Protection Settings
Time Overcurrent 1: curve shape = Moderately Inverse; pickup = 120 A; multiplier = 10
Instantaneous Overcurrent 1: Pickup = 120 A; Delay = 0 seconds
Instantaneous Overcurrent 2: Pickup = 2000 A; Delay = 0 seconds
You should now be familiar with maneuvering through and editing setpoint messages. As such, we will now limit our discus-
sion to just the values that must be programmed, in order to meet the requirements of the example application. Any set-
points not explicitly mentioned should be left at the factory default value.
b) S2 SYSTEM SETPOINTS
The S2 setpoints page contains setpoints for entering the characteristics of the equipment on the feeder electrical system.
In our example, these characteristics are specified under POWER SYSTEM DATA and INSTRUMENT TRANSFORMER DATA.
From this information and the resulting calculations, program S2 setpoints as indicated.
For current transformers, make the following change in the S2 SYSTEM SETUP ÖCURRENT SENSING setpoints page:
PHASE CT PRIMARY: "600 A"
For voltage transformers, make the following changes in the S2 SYSTEM SETUP ÖØ BUS VT SENSING setpoints page:
VT CONNECTION TYPE: "Wye"
NOMINAL VT SECONDARY VOLTAGE: "66.4 V" (13.8kV ø-ø ≡7.97kV ø-N; 7.97kV / 120 = 66.4 V)
VT RATIO: "120:1" (14.4 kV VTpri / 120V VTsec)
Make the following change in the S2 SYSTEM SETUP ÖØ POWER SYSTEM setpoints page to reflect the power system:
NOMINAL FREQ: “60 Hz”
c) S3 LOGIC INPUTS SETPOINTS
The S3 setpoints page is for entering the characteristics of the logic inputs. In our example, these characteristics are spec-
ified under the Control System Requirements heading. Program S3 setpoints as indicated.
For breaker position monitoring, enter the following values in the S3 LOGIC INPUTS ÖLOGIC INPUTS SETUP setpoints page:
INPUT 2 NAME: "Brkr Position (52b)"
INPUT 2 ASSERTED LOGIC: "Contact Close"
then enter the following value in the S3 LOGIC INPUTS ÖØ BRKR FUNCTIONS setpoint page:
52B CONTACT: "Input 2"
For the Remote Open/Close and Reset RTU contacts, enter the following values in the S3 LOGIC INPUTS ÖLOGIC INPUTS
SETUP setpoints page:
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"
then enter the following values in the S3 LOGIC INPUTS ÖØ CONTROL FUNCTIONS setpoint page:
LOCAL MODE: "Input 3"
RESET: "Input 6"
REMOTE OPEN: "Input 4"
REMOTE CLOSE: "Input 5"
To setup an Alarm-after-Delay Input. make the following changes to the S3 LOGIC INPUTS ÖØ USER INPUT A setpoints page:
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GE Multilin 750/760 Feeder Management Relay 1-7
1 GETTING STARTED 1.2 USING THE RELAY
1
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"
d) S5 PROTECTION SETPOINTS
The S5 Protection setpoints page contains setpoints for entering protection element characteristics. In our example, these
characteristics are specified under PHASE CURRENT and NEUTRAL CURRENT. From this data and the resulting calculations,
program the S5 setpoints as indicated.
For the Phase Time Overcurrent 1 element, enter the following values in the S5 PROTECTION ÖPHASE CURRENT ÖØ PHASE
TIME OC 1 setpoints page:
PHASE TIME OC 1 FUNCTION: "Trip"
PHASE TIME OC 1 PICKUP: "1.40 x CT" (840 A pickup / 600 A CT 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 ÖPHASE CURRENT
ÖØ PHASE INST OC 1 setpoints page:
PHASE INST OC 1 FUNCTION: "Trip"
PHASE INST OC 1 PICKUP: "1.40 x CT" (840 A pickup / 600 A CT 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 ÖPHASE CURRENT
ÖØ PHASE INST OC 2 setpoints page:
PHASE INST OC 2 FUNCTION: "Trip"
PHASE INST OC 2 PICKUP: "16.83 x CT" (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 S5 PROTECTION ÖØ NEUTRAL CURRENT ÖØ
NEUTRAL TIME OC 1 setpoints page:
NEUTRAL TIME OC 1 FUNCTION: "Trip"
NEUTRAL TIME OC 1 PICKUP: "0.20 x CT" (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"
For the Neutral Instantaneous Overcurrent 1 element, enter the following values in the S5 PROTECTION ÖØ NEUTRAL CUR-
RENT ÖØ NEUTRAL INST OC 1 setpoints page:
NEUTRAL INST OC 1 FUNCTION: "Trip"
NEUTRAL INST OC 1 PICKUP: "0.20 x CT" (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 ÖØ NEUTRAL CUR-
RENT ÖØ NEUTRAL INST OC 2 setpoints page:
NEUTRAL INST OC 2 FUNCTION: "Trip"
NEUTRAL INST OC 2 PICKUP: "3.33 x CT" (2000 A pickup / 600 A primary)
NEUTRAL INST OC 2 DELAY: "0.00 s"
The Ground and Negative Sequence Overcurrent elements are disabled as follows:
S5 PROTECTION ÖØ GROUND CURRENT ÖGROUND TIME OC ÖGROUND TIME O/C FUNCTION: "Disabled"
S5 PROTECTION ÖØ GROUND CURRENT ÖØ GROUND INST OC ÖGROUND INST O/C FUNCTION: "Disabled"
S5 PROTECTION ÖØ NEGATIVE SEQUENCE ÖNEG SEQ TIME OC ÖNEG SEQ TIME OC FUNCTION: "Disabled"
S5 PROTECTION ÖØ NEGATIVE SEQUENCE ÖØ NEG SEQ INST OC ÖNEG SEQ INST O/C FUNCTION: "Disabled"
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1-8 750/760 Feeder Management Relay GE Multilin
1.2 USING THE RELAY 1 GETTING STARTED
1
e) 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 before it leaves the factory. This minor self-test warning, diagnostic message,
warns that the 750/760 has not been programmed for its intended application. 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:
Move to the S1 RELAY SETUP ÖØ INSTALLATION ÖØ 750 OPERATION setpoint message. To put the relay in the Ready state,
press the key until the READY message is displayed and press . Enter "Yes" at the ARE YOU SURE? prompt.
The Relay In Service LED Indicator will now turn on and the Relay Not Ready diagnostic message will disappear.
1.2.5 COMMISSIONING
Extensive commissioning tests are available in Chapter 8: Commissioning Tests. Commissioning tables for recording
required settings are available in Microsoft Excel format from the GE Multilin website at http://www.GEindustrial.com/multi-
lin. The website also contains additional technical papers and FAQs relevant to the 750/760 Feeder Management Relay.
SELF-TEST WARNING
Relay Not Ready
VALUE
ENTER
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GE Multilin 750/760 Feeder Management Relay 2-1
2 INTRODUCTION 2.1 OVERVIEW
2
2 INTRODUCTION 2.1OVERVIEW 2.1.1 DESCRIPTION
The 750/760 Feeder Management Relays are microprocessor-based units intended for the management and primary pro-
tection of distribution feeders, as well as for the management and backup protection of buses, transformers, and transmis-
sion 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
advanced features are disabled. These 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 interface, setpoints can be
entered with a PC running the 750/760PC software provided with the relay. Even with minimal computer knowledge, this
menu-driven software 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 features 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.
Figure 2–1: FUNCTIONAL BLOCK DIAGRAM
Trip Relay
Close Relay
5 Auxiliary Relays
Self-Test Warning Relay
8 Analog Outputs
Underfrequency Restoration
Undervoltage Restoration
Manual Close
Synchronism Check
Cold Load Pickup
Power Factor
Oscillograph
Arcing
Tripping
Demand
Data Logger
Event Recorder
1 x RS232
Modbus RTU
DNP 3.0
2 x RS485 OR
1 x RS422
Fault Locator
Transfer
Auto Reclose (760)
Overfrequency
Analog Input
VT Failure
OUTPUTS
CONTROL
MONITOR
COMMUNICATIONS
818840AD.dwg
VT
Fail
3+4
27
27
1+2
3
52
N
Calc.
V2
750/760
Feeder Management Relay¨
Line VT
Breaker
Trip
Close
25
46/50
67N
67P
51V
810
Control
Control
Phase A only
Bus VT
50
BF
:
:
SOURCE
1
50SG 51SG 67SG
Control
47
1+2
59
dcmA
Rate
3Vo
Calc.
59N
Calc.
3Io 2
I
Calc.
Level
50P
Supervision
Current
760 Only
79X
50P
Demand
55
1+2
Calc.
I2
Calc.
2
V
Calc.
Calc.
V1
Control
67G
51G
50G
46/51 46/67
Control
-Vo
Calc.
Zone
Coordination
1
I
GROUND
OPERATING CURRENT
SENSITIVE GROUND
OPERATING CURRENT
POLARIZING CURRENT*
ARE MUTUALLY EXCLUSIVE SINCE BOTH USE
* POLARIZING CURRENT AND GND CURRENT
THE SAME RELAY CT INPUT TERMINALS
Level
Coil Monitors Breaker Operation
1+2
81U 81
Decay
50P
1+2 1+2
51P
51N
1+2
1+2
50N
50N
Level
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2-2 750/760 Feeder Management Relay GE Multilin
2.1 OVERVIEW 2 INTRODUCTION
2
Figure 2–2: SUMMARY OF FEATURES
PROTECTION / CONTROL
Bus / Line Undervoltage
Negative Sequence Voltage
Phase/Neutral/Gnd/Neg Seq/Sens Gnd Inst O/C
Phase/Neutral/Gnd/Neg Seq/Sens Gnd Time O/C
Bus Overvoltage/Neutral Displacement
Phase/Neutral/Neg Seq/Sens Gnd/Gnd Directional Control
Bus Underfrequency/Rate of Change
Undervoltage Automatic Restoration
Underfrequency Automatic Restoration
Breaker Failure with Current Superv.
Bus Transfer
Programmable Logic Inputs
Multiple Setpoint Groups
ANSI
27
47
50
51
59
67
81
25
50
55
79
81
MONITORING / CONTROL
Synchrocheck
Phase/Neutral Current Level
Power Factor
Autoreclose (760 only)
Overfrequency
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
FEATUR60/50.AI
FEEDER
BUS
TRANSFORMER
LINE
Capacitor
Radial
Two-ended
Backup
Backup
Backup
Transfer
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GE Multilin 750/760 Feeder Management Relay 2-3
2 INTRODUCTION 2.1 OVERVIEW
2
2.1.2 THEORY OF OPERATION
Relay functions are controlled by two processors: a Motorola 68332 32-bit 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 WAVEFORM CAPTURE:
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 sig-
nals 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 750/760PC software for display and diagnostics.
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 dis-
carded 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 off-nominal frequencies. Also, sampling is synchronized to the Va-x voltage zero cross-
ing 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 with a DC Offset Filter and a Fast Fourier Transform (FFT) to yield pha-
sors 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 fol-
lowing diagram illustrates the signal processing performed on the AC current inputs:
PROCESSING OF AC CURRENT INPUTS:
The DC Offset Filter is an infinite impulse response (IIR) digital filter which removes the DC component from the asymmet-
rical current present at the moment a fault occurs. This is done for all current signals used for overcurrent protection; volt-
age 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 compo-
nents 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 debounced 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.
996709A1.CDR
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2-4 750/760 Feeder Management Relay GE Multilin
2.1 OVERVIEW 2 INTRODUCTION
2
Figure 2–3: HARDWARE BLOCK DIAGRAM
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