489 Generator Management Relay
Digital Energy
Multilin
489 Generator Management
Relay
Instruction Manual
Firmware Revision: 4.0X
Manual Part Number: 1601-0150-AE
Manual Order Code: GEK-106494N
Copyright © 2010 GE Multilin
GE Multilin
Tel: (905) 294-6222 Fax: (905) 201-2098
Internet: http://www.GEindustrial.com/multilin
*1601-0150-AE*
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ISO9001:2000
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Canada L6E 1B3
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GIS ERE
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215 Anderson Avenue, Markham, Ontario
U LT I L
GE Multilin's Quality Management
System is registered to
ISO9001:2000
QMI # 005094
UL # A3775
© 2010 GE Multilin Incorporated. All rights reserved.
GE Multilin 489 Generator Management Relay instruction manual for revision 4.0x.
489 Generator Management Relay, is a registered trademark of GE Multilin Inc.
The contents of this manual are the property of GE Multilin Inc. This documentation is
furnished on license and may not be reproduced in whole or in part without the permission
of GE Multilin. The content of this manual is for informational use only and is subject to
change without notice.
Part numbers contained in this manual are subject to change without notice, and should
therefore be verified by GE Multilin before ordering.
Part number: 1601-0150-AE (June 2010)
TOC
TABLE OF CONTENTS
Table of Contents
1: GETTING STARTED
IMPORTANT PROCEDURES .......................................................................................................... 1-1
CAUTIONS AND WARNINGS ............................................................................................... 1-1
INSPECTION CHECKLIST ...................................................................................................... 1-1
MANUAL ORGANIZATION ................................................................................................... 1-2
USING THE RELAY ............................................................................................................................ 1-3
MENU NAVIGATION ............................................................................................................. 1-3
PANEL KEYING EXAMPLE .................................................................................................... 1-7
CHANGING SETPOINTS ................................................................................................................. 1-9
INTRODUCTION ..................................................................................................................... 1-9
THE HELP KEY .................................................................................................................... 1-10
NUMERICAL SETPOINTS ...................................................................................................... 1-10
ENUMERATION SETPOINTS ................................................................................................. 1-11
OUTPUT RELAY SETPOINTS ................................................................................................ 1-14
TEXT SETPOINTS .................................................................................................................. 1-15
INSTALLATION ................................................................................................................................... 1-16
PLACING THE RELAY IN SERVICE ....................................................................................... 1-16
TESTING ................................................................................................................................ 1-16
2: INTRODUCTION
OVERVIEW ........................................................................................................................................... 2-1
DESCRIPTION ........................................................................................................................ 2-1
ORDERING ............................................................................................................................ 2-4
OTHER ACCESSORIES .......................................................................................................... 2-5
SPECIFICATIONS ............................................................................................................................... 2-6
INPUTS .................................................................................................................................. 2-6
OUTPUTS ............................................................................................................................... 2-7
PROTECTION ......................................................................................................................... 2-8
DIGITAL INPUTS ................................................................................................................... 2-11
MONITORING ........................................................................................................................ 2-12
POWER SUPPLY ................................................................................................................... 2-13
COMMUNICATIONS .............................................................................................................. 2-14
TESTING ................................................................................................................................ 2-14
APPROVALS ........................................................................................................................... 2-15
PHYSICAL .............................................................................................................................. 2-15
ENVIRONMENTAL ................................................................................................................. 2-16
LONG-TERM STORAGE ........................................................................................................ 2-17
3: INSTALLATION
MECHANICAL INSTALLATION ..................................................................................................... 3-1
DESCRIPTION ........................................................................................................................ 3-1
PRODUCT IDENTIFICATION .................................................................................................. 3-2
INSTALLATION ....................................................................................................................... 3-3
UNIT WITHDRAWAL AND INSERTION ................................................................................ 3-4
ETHERNET CONNECTION .................................................................................................... 3-6
TERMINAL LOCATIONS ........................................................................................................ 3-7
ELECTRICAL INSTALLATION ......................................................................................................... 3-9
TYPICAL WIRING .................................................................................................................. 3-9
GENERAL WIRING CONSIDERATIONS ................................................................................ 3-10
CONTROL POWER ................................................................................................................ 3-10
CURRENT INPUTS ................................................................................................................. 3-11
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
TOC–I
TABLE OF CONTENTS
VOLTAGE INPUTS ................................................................................................................. 3-14
DIGITAL INPUTS ................................................................................................................... 3-14
ANALOG INPUTS .................................................................................................................. 3-14
ANALOG OUTPUTS .............................................................................................................. 3-15
RTD SENSOR CONNECTIONS ............................................................................................ 3-15
OUTPUT RELAYS .................................................................................................................. 3-16
IRIG-B .................................................................................................................................. 3-17
RS485 PORTS ..................................................................................................................... 3-17
DIELECTRIC STRENGTH ....................................................................................................... 3-18
4: INTERFACES
FACEPLATE INTERFACE ................................................................................................................. 4-1
DISPLAY ................................................................................................................................. 4-1
LED INDICATORS ................................................................................................................. 4-1
RS232 PROGRAM PORT .................................................................................................... 4-3
KEYPAD ................................................................................................................................. 4-3
SETPOINT ENTRY .................................................................................................................. 4-6
DIAGNOSTIC MESSAGES ..................................................................................................... 4-8
SELF-TEST WARNINGS ....................................................................................................... 4-8
FLASH MESSAGES ................................................................................................................ 4-9
ENERVISTA SOFTWARE INTERFACE ......................................................................................... 4-10
OVERVIEW ............................................................................................................................ 4-10
HARDWARE ........................................................................................................................... 4-10
INSTALLING THE ENERVISTA 489 SETUP SOFTWARE .................................................... 4-12
CONNECTING ENERVISTA 489 SETUP TO THE RELAY ...................................................... 4-15
CONFIGURING SERIAL COMMUNICATIONS ....................................................................... 4-15
USING THE QUICK CONNECT FEATURE ............................................................................ 4-16
CONFIGURING ETHERNET COMMUNICATIONS ................................................................. 4-17
CONNECTING TO THE RELAY .............................................................................................. 4-19
WORKING WITH SETPOINTS AND SETPOINT FILES ........................................................... 4-21
ENGAGING A DEVICE ........................................................................................................... 4-21
ENTERING SETPOINTS ......................................................................................................... 4-21
USING SETPOINT FILES ....................................................................................................... 4-23
UPGRADING RELAY FIRMWARE ................................................................................................. 4-30
DESCRIPTION ........................................................................................................................ 4-30
SAVING SETPOINTS TO A FILE ............................................................................................ 4-30
LOADING NEW FIRMWARE ................................................................................................. 4-30
ADVANCED ENERVISTA 489 SETUP FEATURES ................................................................... 4-33
TRIGGERED EVENTS ............................................................................................................. 4-33
WAVEFORM CAPTURE (TRACE MEMORY) ......................................................................... 4-33
PHASORS .............................................................................................................................. 4-35
TRENDING (DATA LOGGER) ................................................................................................ 4-37
EVENT RECORDER ................................................................................................................ 4-40
MODBUS USER MAP ........................................................................................................... 4-41
VIEWING ACTUAL VALUES .................................................................................................. 4-41
USING ENERVISTA VIEWPOINT WITH THE 489 ................................................................... 4-44
PLUG AND PLAY EXAMPLE ................................................................................................. 4-44
5: SETPOINTS
OVERVIEW ........................................................................................................................................... 5-1
SETPOINT MESSAGE MAP ................................................................................................... 5-1
TRIPS / ALARMS/ CONTROL FEATURES ............................................................................ 5-6
RELAY ASSIGNMENT PRACTICES ........................................................................................ 5-7
DUAL SETPOINTS ................................................................................................................. 5-8
TOC–II
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
TOC
TABLE OF CONTENTS
COMMISSIONING .................................................................................................................. 5-8
S1 489 SETUP .................................................................................................................................... 5-9
PASSCODE ............................................................................................................................ 5-9
PREFERENCES ....................................................................................................................... 5-10
COMMUNICATIONS .............................................................................................................. 5-12
REAL TIME CLOCK ............................................................................................................... 5-13
DEFAULT MESSAGES ........................................................................................................... 5-14
MESSAGE SCRATCHPAD ...................................................................................................... 5-15
CLEAR DATA ......................................................................................................................... 5-16
S2 SYSTEM SETUP ............................................................................................................................ 5-18
CURRENT SENSING .............................................................................................................. 5-18
VOLTAGE SENSING .............................................................................................................. 5-18
GENERATOR PARAMETERS .................................................................................................. 5-19
SERIAL START/STOP INITIATION ........................................................................................ 5-20
S3 DIGITAL INPUTS .......................................................................................................................... 5-21
DESCRIPTION ........................................................................................................................ 5-21
BREAKER STATUS ................................................................................................................ 5-21
GENERAL INPUT A TO G ..................................................................................................... 5-22
REMOTE RESET .................................................................................................................... 5-23
TEST INPUT ........................................................................................................................... 5-23
THERMAL RESET .................................................................................................................. 5-23
DUAL SETPOINTS ................................................................................................................. 5-24
SEQUENTIAL TRIP ................................................................................................................ 5-25
FIELD-BREAKER ................................................................................................................... 5-26
TACHOMETER ....................................................................................................................... 5-26
WAVEFORM CAPTURE ......................................................................................................... 5-27
GROUND SWITCH STATUS ................................................................................................. 5-27
S4 OUTPUT RELAYS ......................................................................................................................... 5-28
DESCRIPTION ........................................................................................................................ 5-28
RELAY RESET MODE ............................................................................................................ 5-28
S5 CURRENT ELEMENTS ............................................................................................................... 5-29
INVERSE TIME OVERCURRENT CURVE CHARACTERISTICS .............................................. 5-29
OVERCURRENT ALARM ........................................................................................................ 5-33
OFFLINE OVERCURRENT ..................................................................................................... 5-33
INADVERTENT ENERGIZATION ............................................................................................ 5-34
PHASE OVERCURRENT ........................................................................................................ 5-35
NEGATIVE SEQUENCE ......................................................................................................... 5-36
GROUND OVERCURRENT .................................................................................................... 5-38
PHASE DIFFERENTIAL .......................................................................................................... 5-39
GROUND DIRECTIONAL ....................................................................................................... 5-40
HIGH-SET PHASE OC ......................................................................................................... 5-42
S6 VOLTAGE ELEMENTS ................................................................................................................ 5-43
UNDERVOLTAGE ................................................................................................................... 5-43
OVERVOLTAGE ...................................................................................................................... 5-44
VOLTS/HERTZ ...................................................................................................................... 5-45
PHASE REVERSAL ................................................................................................................. 5-48
UNDERFREQUENCY .............................................................................................................. 5-49
OVERFREQUENCY ................................................................................................................. 5-50
NEUTRAL OVERVOLTAGE .................................................................................................... 5-51
NEUTRAL UNDERVOLTAGE ................................................................................................. 5-53
LOSS OF EXCITATION .......................................................................................................... 5-55
DISTANCE ELEMENT ............................................................................................................ 5-56
S7 POWER ELEMENTS .................................................................................................................... 5-60
POWER MEASUREMENT CONVENTIONS ........................................................................... 5-60
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
TOC–III
TABLE OF CONTENTS
REACTIVE POWER ................................................................................................................ 5-61
REVERSE POWER ................................................................................................................. 5-62
LOW FORWARD POWER ..................................................................................................... 5-63
S8 RTD TEMPERATURE ................................................................................................................... 5-64
RTD TYPES ........................................................................................................................... 5-64
RTDS 1 TO 6 ....................................................................................................................... 5-65
RTDS 7 TO 10 ..................................................................................................................... 5-66
RTD 11 ................................................................................................................................ 5-67
RTD 12 ................................................................................................................................ 5-67
OPEN RTD SENSOR ............................................................................................................ 5-68
RTD SHORT/LOW TEMP .................................................................................................... 5-69
S9 THERMAL MODEL ...................................................................................................................... 5-70
489 THERMAL MODEL ....................................................................................................... 5-70
MODEL SETUP ...................................................................................................................... 5-71
THERMAL ELEMENTS ........................................................................................................... 5-89
S10 MONITORING ............................................................................................................................ 5-90
TRIP COUNTER ..................................................................................................................... 5-90
BREAKER FAILURE ............................................................................................................... 5-90
TRIP COIL MONITOR ............................................................................................................ 5-91
VT FUSE FAILURE ................................................................................................................ 5-92
DEMAND ............................................................................................................................... 5-93
PULSE OUTPUT .................................................................................................................... 5-94
RUNNING HOUR SETUP ...................................................................................................... 5-95
S11 ANALOG INPUTS/OUTPUTS ................................................................................................ 5-96
ANALOG OUTPUTS 1 TO 4 ................................................................................................. 5-96
ANALOG INPUTS 1 TO 4 ..................................................................................................... 5-98
S12 TESTING ....................................................................................................................................... 5-100
SIMULATION MODE ............................................................................................................. 5-100
PRE-FAULT SETUP ............................................................................................................... 5-101
FAULT SETUP ........................................................................................................................ 5-102
TEST OUTPUT RELAYS ......................................................................................................... 5-102
TEST ANALOG OUTPUT ....................................................................................................... 5-103
COMM PORT MONITOR ....................................................................................................... 5-104
FACTORY SERVICE ................................................................................................................ 5-104
6: ACTUAL VALUES
TOC–IV
OVERVIEW ........................................................................................................................................... 6-1
ACTUAL VALUES MAIN MENU ........................................................................................... 6-1
DESCRIPTION ........................................................................................................................ 6-3
A1 STATUS ........................................................................................................................................... 6-4
NETWORK STATUS ............................................................................................................... 6-4
GENERATOR STATUS ........................................................................................................... 6-4
LAST TRIP DATA ................................................................................................................... 6-5
ALARM STATUS .................................................................................................................... 6-6
TRIP PICKUPS ....................................................................................................................... 6-9
ALARM PICKUPS ................................................................................................................... 6-12
DIGITAL INPUTS ................................................................................................................... 6-15
REAL TIME CLOCK ............................................................................................................... 6-15
A2 METERING DATA ........................................................................................................................ 6-16
CURRENT METERING ........................................................................................................... 6-16
VOLTAGE METERING ........................................................................................................... 6-17
POWER METERING .............................................................................................................. 6-18
TEMPERATURE ...................................................................................................................... 6-19
DEMAND METERING ............................................................................................................ 6-20
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
TOC
TABLE OF CONTENTS
ANALOG INPUTS .................................................................................................................. 6-20
SPEED .................................................................................................................................... 6-21
A3 LEARNED DATA .......................................................................................................................... 6-22
PARAMETER AVERAGES ....................................................................................................... 6-22
RTD MAXIMUMS ................................................................................................................. 6-22
ANALOG INPUT MIN/MAX ................................................................................................. 6-23
A4 MAINTENANCE ........................................................................................................................... 6-25
TRIP COUNTERS ................................................................................................................... 6-25
GENERAL COUNTERS .......................................................................................................... 6-27
TIMERS .................................................................................................................................. 6-27
A5 EVENT RECORDER ..................................................................................................................... 6-28
EVENT RECORDER ............................................................................................................... 6-28
A6 PRODUCT INFORMATION ...................................................................................................... 6-31
489 MODEL INFO ............................................................................................................... 6-31
CALIBRATION INFO .............................................................................................................. 6-31
DIAGNOSTICS .................................................................................................................................... 6-32
DIAGNOSTIC MESSAGES ..................................................................................................... 6-32
FLASH MESSAGES ................................................................................................................ 6-33
7: TESTING
TEST SETUP ......................................................................................................................................... 7-1
DESCRIPTION ........................................................................................................................ 7-1
HARDWARE FUNCTIONAL TESTS .............................................................................................. 7-4
OUTPUT CURRENT ACCURACY .......................................................................................... 7-4
PHASE VOLTAGE INPUT ACCURACY .................................................................................. 7-4
GROUND (1 A), NEUTRAL, AND DIFFERENTIAL CURRENT ACCURACY ......................... 7-5
NEUTRAL VOLTAGE (FUNDAMENTAL) ACCURACY ........................................................... 7-6
NEGATIVE SEQUENCE CURRENT ACCURACY ................................................................... 7-6
RTD ACCURACY .................................................................................................................. 7-7
DIGITAL INPUTS AND TRIP COIL SUPERVISION ................................................................ 7-9
ANALOG INPUTS AND OUTPUTS ........................................................................................ 7-9
OUTPUT RELAYS .................................................................................................................. 7-11
ADDITIONAL FUNCTIONAL TESTS ............................................................................................. 7-12
OVERLOAD CURVE ACCURACY .......................................................................................... 7-12
POWER MEASUREMENT TEST ............................................................................................ 7-13
REACTIVE POWER ACCURACY ............................................................................................ 7-13
VOLTAGE PHASE REVERSAL ACCURACY ........................................................................... 7-14
INJECTION TEST SETUP #2 ................................................................................................ 7-15
GE MULTILIN 50:0.025 GROUND ACCURACY ............................................................... 7-15
NEUTRAL VOLTAGE (3RD HARMONIC) ACCURACY ......................................................... 7-16
PHASE DIFFERENTIAL TRIP ACCURACY ............................................................................. 7-16
INJECTION TEST SETUP #3 ................................................................................................ 7-19
VOLTAGE RESTRAINED OVERCURRENT ACCURACY ......................................................... 7-20
DISTANCE ELEMENT ACCURACY ........................................................................................ 7-21
APPENDIX
STATOR GROUND FAULT .............................................................................................................. A-1
DESCRIPTION ........................................................................................................................ A-1
NEUTRAL OVERVOLTAGE ELEMENT ................................................................................... A-2
GROUND OVERCURRENT ELEMENT ................................................................................... A-3
GROUND DIRECTIONAL ELEMENT ..................................................................................... A-4
THIRD HARMONIC VOLTAGE ELEMENT ............................................................................. A-6
REFERENCES ......................................................................................................................... A-7
STATOR DIFFERENTIAL PROTECTION SPECIAL APPLICATION ...................................... A-8
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
TOC–V
TABLE OF CONTENTS
BACKGROUND ...................................................................................................................... A-8
STATOR DIFFERENTIAL LOGIC ............................................................................................ A-9
CURRENT TRANSFORMERS .......................................................................................................... A-11
GROUND FAULT CTS FOR 50:0.025 A CT .................................................................... A-11
GROUND FAULT CTS FOR 5 A SECONDARY CT ............................................................. A-13
PHASE CTS ........................................................................................................................... A-13
TIME OVERCURRENT CURVES .................................................................................................... A-15
ANSI CURVES ...................................................................................................................... A-15
DEFINITE TIME CURVES ...................................................................................................... A-19
IAC CURVES ......................................................................................................................... A-20
IEC CURVES ......................................................................................................................... A-24
REVISION HISTORY .......................................................................................................................... A-27
CHANGE NOTES ................................................................................................................... A-27
CHANGES TO THE 489 MANUAL ...................................................................................... A-27
EU DECLARATION OF CONFORMITY ........................................................................................ A-31
EU DECLARATION OF CONFORMITY ................................................................................ A-31
WARRANTY ......................................................................................................................................... A-32
GE MULTILIN WARRANTY .................................................................................................. A-32
TOC–VI
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
Digital Energy
Multilin
489 Generator Management Relay
Chapter 1: Getting Started
Getting Started
1.1
Important Procedures
1.1.1
Cautions and Warnings
Please read this chapter to guide you through the initial setup of your new relay.
WARNING
1.1.2
Before attempting to install or use the relay, it is imperative that all
WARNINGS and CAUTIONS in this manual are reviewed to help
prevent personal injury, equipment damage, and/or downtime.
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
•
Note
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.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
1–1
CHAPTER 1: GETTING STARTED
1.1.3
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 guidelines for basic relay usability.
Important wiring considerations and precautions discussed in Electrical Installation on
page 3–9 should be observed for reliable operation. Detailed information regarding
accuracy, output relay contact ratings, and so forth are detailed in Specifications on page
2–6. The remainder of this manual should be read and kept for reference to ensure
maximum benefit from the 489 Generator Management Relay. 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:
A4 MAINTENANCE ZV TRIP COUNTERS Z TOTAL NUMBER OF TRIPS
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 TOTAL NUMBER
OF TRIPS actual value is shown to be an item in the TRIP COUNTERS sub-menu, which itself
is an item in the A4 MAINTENANCE menu, which is an item of ACTUAL VALUES.
Sub-menu levels are entered by pressing the MESSAGE X or ENTER key. When inside a
submenu, the W MESSAGE or ESCAPE 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.
1–2
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 1: GETTING STARTED
1.2
Using the Relay
1.2.1
Menu Navigation
The relay has three types of display messages: actual value, setpoint, and target
messages. A summary of the menu structure for setpoints and actual values can be found
at the beginning of chapters 5 and 6, respectively.
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.
Actual values include the following information:
1.
2.
Generator and System Status:
a.
Generator status either online, offline, or tripped.
b.
The status of digital inputs.
c.
Last trip information, including values such as cause of last trip, time and date of
trip, pre-trip temperature measurements, pre-trip analog inputs values, and pretrip instantaneous values of power system quantities.
d.
Active alarms.
e.
Relay date and time.
Metering Data:
a.
Instantaneous current measurements including phase, neutral, and ground currents.
3.
b.
Instantaneous phase to phase and phase to ground voltages (depending on the
VT connections), average voltage, and system frequency.
c.
Power quantities including apparent, real and reactive power.
d.
Current and power demand including peak values.
e.
Analog inputs.
f.
Generator speed.
g.
System phasors.
h.
RTD temperatures.
Learned Data:
a.
Average magnitudes of generator load, negative-sequence current, and phasephase voltage.
4.
b.
RTD learned data, which includes the maximum temperature measured by each
of the twelve (12) RTDs.
c.
Minimum and maximum values of analog inputs.
Maintenance data. This is useful statistical information that may be used for
preventive maintenance. It includes:
a.
Trip counters
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
1–3
CHAPTER 1: GETTING STARTED
b.
General counters such as number of breaker operations and number of thermal
resets.
c.
Generator hours online timer.
5.
Event recorder downloading tool.
6.
Product information including model number, firmware version, additional product
information, and calibration dates.
7.
Oscillography and data logger downloading tool.
Alarm, trip conditions, diagnostics, and system flash messages are grouped under Target
Messages.
Z Press the MENU key to access the header of each menu, which will
be displayed in the following sequence:
„
SETPOINTS
[Z]
„
ACTUAL VALUES
[Z]
„
TARGET MESSAGES [Z]
To access setpoints,
Z press the MENU key until the display shows the header of the
setpoints menu.
Z Press the MESSAGE X or ENTER 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 provides a general idea of the
settings available in that page.
Z Press the MESSAGE T and MESSAGE S keys to scroll through all the
available setpoint page headers.
Setpoint page headers look as follows:
„
SETPOINTS
S1 489 SETUP
[Z]
To enter a given setpoints page,
Z Press the MESSAGE X or ENTER key.
Z Press the MESSAGE T or MESSAGE S keys to scroll through subpage headers until the required message is reached.
The end of a page is indicated by the message END OF PAGE. The
beginning of a page is indicated by the message TOP OF PAGE.
To access actual values,
1–4
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 1: GETTING STARTED
Z Press the MENU key until the display shows the header of the actual
values menu.
Z Press the MESSAGE X or ENTER 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.
Z Press the MESSAGE T or MESSAGE S keys to scroll through all the
available actual values page headers.
Actual values page headers look as follows:
„
ACTUAL VALUES
A1 STATUS
[Z]
To enter a given actual values page,
Z Press the MESSAGE X or ENTER key.
Z Press the MESSAGE T or MESSAGE S keys to scroll through subpage headers until the required message is reached.
The end of a page is indicated by the message END OF PAGE. The
beginning of a page is indicated by the message TOP OF PAGE.
Similarly, to access additional sub-pages,
Z Press the MESSAGE X or ENTER key to enter the first sub-page,
Z Press the MESSAGE T or MESSAGE S keys to scroll through the
available sub-pages, until the desired message is reached.
The process is identical for both setpoints and actual values.
The following procedure illustrates the key sequence to access the Current Demand actual
values.
Z Press the MENU key until you reach the actual values main menu.
„
ACTUAL VALUES
[Z]
Z Press MESSAGE X or ENTER key to enter the first actual values
page.
Z Press the MESSAGE T or MESSAGE S key to scroll through pages,
until the A2 METERING DATA page appears.
„
ACTUAL VALUES
[Z]
A2 METERING DATA
Z Press the MESSAGE X or ENTER key to display the first sub-page
heading for the Metering Data actual values page:
„
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CURRENT
METERING
[Z]
1–5
CHAPTER 1: GETTING STARTED
Pressing the MESSAGE T or MESSAGE S keys will scroll the display up and down
through the sub-page headers. Pressing the W MESSAGE or ESCAPE key at any subpage 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 main menu
header.
Z Press the MESSAGE T key until the DEMAND METERING sub-page
heading appears.
„
DEMAND
METERING
[Z]
At this point, pressing MESSAGE X or ENTER key will display the messages under this
sub-page. If instead you press the MESSAGE S key, it will return to the previous subpage heading. In this case,
„
TEMPERATURE
[Z]
When the symbols „ and [Z] appear on the top line, it indicates that additional subpages are available and can be accessed by pressing the MESSAGE X or ENTER key.
Z Press the MESSAGE X or ENTER while at the Demand Metering subpage heading to display the following:
CURRENT
DEMAND:
0 Amps
Z Press W MESSAGE key to return to the Demand Metering sub-page
heading.
Z Press the MESSAGE T key to display the next actual value of this
sub-page.
Actual values and setpoints messages always have a colon
separating the name of the value and the actual value or setpoint.
This particular message displays the current demand as measured
by the relay.
The menu path to the value shown above is indicated as A2 METERING DATA ZV DEMAND
METERING Z CURRENT DEMAND. Setpoints and actual values messages are referred to in
this manner throughout the manual.
For example, the A4 MAINTENANCE Z TRIP COUNTERS Z TOTAL NUMBER OF TRIPS path
representation describes the following key-press sequence:
Z Press the MENU key until the actual value header appears on the
display.
„
ACTUAL VALUES
[Z]
Z Press MESSAGE X or the ENTER key, and then MESSAGE T key until
the A4 MAINTENANCE message is displayed.
„
1–6
ACTUAL VALUES
A4 MAINTENANCE
[Z]
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 1: GETTING STARTED
Z Press the MESSAGE X or ENTER key to display TRIP COUNTERS
message.
„
TRIP
COUNTERS
[Z]
Z Press the MESSAGE X or ENTER key to reach the TOTAL NUMBER OF
TRIPS message and the corresponding actual value.
TOTAL NUMBER OF
TRIPS:
0
Z Press the MESSAGE T key to display the next actual value message
as shown below:
DIGITAL INPUT
TRIPS:
0
Z Press the MESSAGE T or MESSAGE S keys to scroll the display up
and down through all the actual value displays in this corresponding
sub-page.
Z Press the W MESSAGE key to reverse the process described above
and return the display to the previous level.
„
TRIP
COUNTERS
[Z]
Z Press the W MESSAGE key twice to return to the A4 MAINTENANCE
page header.
„
1.2.2
ACTUAL VALUES
A4 MAINTENANCE
[Z]
Panel Keying Example
The following figure provides a graphical 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 example shown in the figure gives the key presses
required to read the average negative-sequence current denoted by the path A3 LEARNED
DATA Z PARAMETER AVERAGES ZV AVERAGE NEG. SEQ. CURRENT.
Z Press the menu key until the relay displays the actual values page.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
1–7
CHAPTER 1: GETTING STARTED
„
ACTUAL VALUES
Press the MESSAGE
„
ACTUAL VALUES
A1 STATUS
Press the MESSAGE
„
or ENTER key
[Z]
key
ACTUAL VALUES
[Z]
A2 METERING DATA
Press the MESSAGE
„
[Z]
key
ACTUAL VALUES
[Z]
MESSAGE
A3 LEARNED DATA
„
PARAMETER
AVERAGES
[Z]
MESSAGE
MESSAGE
1–8
AVERAGE GENERATOR
LOAD: 100% FLA
AVERAGE NEG. SEQ.
CURRENT:
0% FLA
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 1: GETTING STARTED
1.3
Changing Setpoints
1.3.1
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 Overcurrent 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.
All of the 489 settings fall into one of following categories: device settings, system settings,
digital input settings, output relay settings, current element settings, voltage element
settings, power element settings, RTD temperature settings, thermal model settings,
monitoring settings, analog input/output settings, and testing settings.
Note
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 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
(C1 and C2) 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 setpoint access via the front 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).
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
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CHAPTER 1: GETTING STARTED
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 489 Setup software incorporates a facility for programming the relay
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.
1.3.2
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.
1.3.3
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 489 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 VALUE S key to increment the displayed value by the step
value, up to a maximum allowed value. Likewise, the VALUE T key decrements the
displayed value by the step value, down to a minimum value. For example:
Z Select the S1 489 SETUP ZV PREFERENCES ZV DEFAULT MESSAGE
TIMEOUT setpoint message.
DEFAULT MESSAGE
TIMEOUT: 300 s
Z Press the 1, 2, and 0 keys. The display message will change as
shown.
DEFAULT MESSAGE
TIMEOUT: 120 s
Until the ENTER key is pressed, editing changes are not registered by the relay.
Therefore,
1–10
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 1: GETTING STARTED
Z Press the ENTER key to store the new value in memory.
The following message will momentarily appear as confirmation of
the storing process.
NEW SETPOINT HAS
BEEN STORED
1.3.4
Enumeration Setpoints
The example shown in the following figures illustrates the keypress sequences 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: 600 A
Ground CT type: 1 A secondary
Ground CT ratio: 200:1
Neutral Voltage Transformer: None
Voltage Transformer Connection Type: Open Delta
VT Ratio: 115:1
To set the phase CT primary rating, modify the S2 SYSTEM SETUP Z CURRENT SENSING Z
PHASE CT PRIMARY setpoint as shown below.
Z Press the MENU key until the relay displays the setpoints menu
header.
„
SETPOINTS
[Z]
Press MESSAGE X or ENTER
„
SETPOINTS
S1 489 SETUP
[Z]
Press MESSAGE T
„
SETPOINTS
[Z] Press
„ CURRENT
[Z] Press
PHASE CT PRIMARY:
MESSAGE X
MESSAGE X ------------S2 SYSTEM SETUP
SENSING
or ENTER
or ENTER
Press the VALUE keys until 600 A is displayed, PHASE CT PRIMARY:
or enter the value directly via the numeric 600 A
keypad.
Press the ENTER key to store the setpoint.
NEW SETPOINT HAS
BEEN STORED
To select the Ground CT type, modify the S2 SYSTEM SETUP Z CURRENT SENSING ZV GROUND
CT setpoint as shown below.
Z Press the MENU key until the relay displays the setpoints menu
header.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
1–11
CHAPTER 1: GETTING STARTED
„
SETPOINTS
[Z]
Press MESSAGE X or ENTER
„
SETPOINTS
S1 489 SETUP
[Z]
Press MESSAGE T
„
SETPOINTS
[Z] Press
„ CURRENT
MESSAGE X
S2 SYSTEM SETUP
SENSING
or ENTER
[Z] Press
MESSAGE X
or ENTER
Press
PHASE CT PRIMARY:
600 A
GROUND CT:
MESSAGE T 50:0.025
Press the VALUE keys until GROUND CT:
“1 A Secondary” is displayed. 1 A Secondary
Press the ENTER key to store the setpoint.
1–12
NEW SETPOINT HAS
BEEN STORED
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 1: GETTING STARTED
To set the ground CT ratio, modify the S2 SYSTEM SETUP Z CURRENT SENSING ZV GROUND
CT RATIO setpoint as shown below.
Z Press the MENU key until the relay displays the setpoints menu
header.
„
SETPOINTS
[Z]
Press MESSAGE X or ENTER
„
SETPOINTS
S1 489 SETUP
[Z]
Press MESSAGE T
„
SETPOINTS
[Z] Press
„ CURRENT
MESSAGE X
S2 SYSTEM SETUP
SENSING
or ENTER
[Z] Press
MESSAGE X
or ENTER
PHASE CT PRIMARY:
600 A
Press
GROUND CT:
Press
GROUND CT RATIO:
MESSAGE T 1 A Secondary
MESSAGE T 100: 1
Press the VALUE keys until 200: 1 is displayed, GROUND CT RATIO:
or enter the value directly via the numeric 200: 1
keypad.
Press the ENTER key to store the setpoint.
NEW SETPOINT HAS
BEEN STORED
To set the VT connection type and ratings, modify the S2 SYSTEM SETUP ZV VOLTAGE
SENSING ZV VT CONNECTION TYPE and the S2 SYSTEM SETUP ZV VOLTAGE SENSING ZV
VOLTAGE TRANSFORMER RATIO setpoints as shown below.
Z Press the MENU key until the relay displays the setpoints menu
header.
„
SETPOINTS
[Z]
Press MESSAGE X or ENTER
„
SETPOINTS
S1 489 SETUP
[Z]
Press MESSAGE T
„
SETPOINTS
[Z] Press
„ CURRENT
MESSAGE X
S2 SYSTEM SETUP
SENSING
or ENTER
Press
MESSAGE T
„
VOLTAGE
SENSING
[Z]
[Z] Press
VT CONNECTION TYPE:
MESSAGE X None
or ENTER
Press the VALUE keys until VT CONNECTION TYPE:
“Open Delta” is displayed. Open Delta
Press the ENTER key to store the setpoint.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
NEW SETPOINT HAS
BEEN STORED
1–13
CHAPTER 1: GETTING STARTED
Press
VOLTAGE TRANSFORMER
MESSAGE T RATIO: 5.00: 1
Press the VALUE keys until 115.00 : 1 is VOLTAGE TRANSFORMER
displayed, or enter the value directly via the RATIO: 115.0: 1
numeric keypad.
Press the ENTER key to store the setpoint.
NEW SETPOINT HAS
BEEN STORED
If an entered setpoint value is out of range, the relay displays a message with the following
format:
OUT-OF-RANGE! ENTER:
1-300:1 by 0.01:1
“1-300:1” indicates the range and “0.01:1” indicates the
step value
In this case, 1 is the minimum setpoint value, 300 is the maximum, and 0.01 is the step
value. To have access to information on maximum, minimum, and step value, press the
HELP key.
1.3.5
Output Relay Setpoints
The output relays 1 Trip and 5 Alarm can be associated to auxiliary relays 2 to 4. Each can
be selected individually, or in combination, in response to customer specific requirements.
These relays are initiated through the ASSIGN ALARM RELAYS or ASSIGN TRIP RELAYS
setpoints specific to a protection element or function.
Z Select the S6 VOLTAGE ELEMENTS Z UNDERVOLTAGE ZV ASSIGN TRIP
RELAYS (1-4) setpoint message.
ASSIGN TRIP
RELAYS (1-4): 1--If an application requires the undervoltage protection element to trip the 3 Auxiliary
relay,
Z Select this output relay by pressing the “3” key; pressing the “3” key
again disables the 3 Auxiliary relay.
Enable/disable relays 1, 3, and 4 in the same manner until the
desired combination appear in the display.
ASSIGN TRIP
RELAYS (1-4): --3Z Press the ENTER key to store this change into memory.
As before, confirmation of this action will momentarily flash on the
display.
NEW SETPOINT HAS
BEEN STORED
1–14
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 1: GETTING STARTED
1.3.6
Text Setpoints
Text setpoints have data values, which are fixed in length, but user defined in character.
They may be comprised of uppercase letters, lowercase letters, numerals, and a selection
of special characters. The editing and storing of a text value is accomplished with the use
of the decimal [.], VALUE, and ENTER keys.
For example:
Z Move to the S3 DIGITAL INPUTS Z GENERAL INPUT A ZV INPUT NAME
message:
INPUT NAME:
Input A
The name of this user-defined input will be changed in this example from the generic
“Input A” to something more descriptive.
If an application is to be using the relay as a station monitor, it is more informative to
rename this input “Stn. Monitor”.
Z Press the decimal [.] key to enter the text editing mode. The first
character will appear underlined as follows:
INPUT NAME:
Input A
Z Press the VALUE keys until the character “S” is displayed in the first
position.
Z Press the decimal [.] key to store the character and advance the
cursor to the next position.
Z Change the second character to a “t” in the same manner.
Z Continue entering characters in this way until all characters of the
text “Stn. Monitor” are entered.
Note that a space is selected like a character. If a character is
entered incorrectly, press the decimal [.] key repeatedly until the
cursor returns to the position of the error. Re-enter the character as
required.
Z Once complete, press the ENTER 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.
INPUT NAME:
Stn. Monitor
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
1–15
CHAPTER 1: GETTING STARTED
1.4
Installation
1.4.1
Placing the Relay in Service
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 489 Generator Management Relay has not yet
been programmed. If this warning is ignored, protection will be active using factory default
setpoints and the Relay In Service LED Indicator will be on.
1.4.2
Testing
Extensive commissioning tests are available in Chapter 7. Tables for recording required
settings are available in Microsoft Excel format from the GE Multilin website at http://
www.GEmultilin.com. The website also contains additional technical papers and FAQs
relevant to the 489 Generator Management Relay.
1–16
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
Digital Energy
Multilin
489 Generator Management Relay
Chapter 2: Introduction
Introduction
2.1
Overview
2.1.1
Description
The 489 Generator Management Relay is a microprocessor-based relay designed for the
protection and management of synchronous and induction generators. The 489 is
equipped with 6 output relays for trips and alarms. Generator protection, fault diagnostics,
power metering, and RTU functions are integrated into one economical drawout package.
The single line diagram illustrates the 489 functionality using ANSI (American National
Standards Institute) device numbers.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
2–1
CHAPTER 2: INTRODUCTION
Synch
ronou
s
Induc
tion
489
12
21
24
27
50/27
32
38
39
40
40Q
46
47
49
50
50BF
50
50/51GN
51V
59
59GN/27TN
60FL
67
76
81
86
87G
52
27
47
overspeed
distance
volts/hertz
undervoltage
inadvertent generator energization
reverse power/low forward power
bearing overtemperature (RTD)
bearing vibration (analog inputs)
loss of excitation (impedance)
loss of field (reactive power)
2
negative sequence overcurrent (I 2 t)
voltage phase reversal
stator thermal (RTD/thermal model)
high-set phase overcurrent
breaker failure detection
offline overcurrent
ground overcurrent
voltage restrained phase overcurrent
overvoltage
100% stator ground
VT fuse failure
ground directional
Trip Coil
Supervision
59
810
40
81U
24
21
38
41
GENERATOR
12
49
39
32
40Q
50/27
51V
60FL
76
46
Output
relays
49
86
Output
relays
6
50BF
50
87G
RS232
RS485
67 50/51GN RS485
overexcitation (analog input)
overfrequency/underfrequency
electrical lockout
percentage differential
sequential tripping logic
trip coil supervision
generator running hours alarm
59GN
27TN
+
+
-
4
4
Analog
outputs
Analog
inputs
808783E8.CDR
FIGURE 2–1: Single Line Diagram
Fault diagnostics are provided through pretrip data, event record, waveform capture, and
statistics. Prior to issuing a trip, the 489 takes a snapshot of the measured parameters and
stores them in a record with the cause of the trip. This pre-trip data may be viewed using
the NEXT key before the trip is reset, or by accessing the last trip data in actual values
page 1. The event recorder stores a maximum of 256 time and date stamped events
including the pre-trip data. Every time a trip occurs, the 489 stores a 16 cycle trace for all
measured AC quantities. Trip counters record the number of occurrences of each type of
trip. Minimum and maximum values for RTDs and analog inputs are also recorded. These
features allow the operator to pinpoint a problem quickly and with certainty.
A complete list protection features is shown below:
2–2
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 2: INTRODUCTION
Table 2–1: Trip and Alarm Protection Features
Trip Protection
Seven (7) Assignable Digital Inputs:
General Input, Sequential Trip (low
forward power or reverse power), FieldBreaker discrepancy, and Tachometer
Note
Alarm Protection
7 assignable digital inputs: general input
and tachometer
Overload
Negative Sequence
Offline Overcurrent (protection during
startup)
Ground Overcurrent
Inadvertent Energization
Ground Directional
Phase Overcurrent with Voltage Restraint
Undervoltage
Negative-Sequence Overcurrent
Overvoltage
Ground Overcurrent
Volts Per Hertz
Percentage Phase Differential
Underfrequency
Ground Directional
Overfrequency
High-Set Phase Overcurrent
Neutral Overvoltage (Fundamental)
Undervoltage
Neutral Undervoltage (3rd Harmonic)
Overvoltage
Reactive Power (kvar)
Volts Per Hertz
Reverse Power
Voltage Phase Reversal
Low Forward Power
Underfrequency (two step)
RTD: Stator, Bearing, Ambient, Other
Overfrequency (two step)
Short/Low RTD
Neutral Overvoltage (Fundamental)
Open RTD
Neutral Undervoltage (3rd Harmonic)
Thermal Overload
Loss of Excitation (2 impedance circles)
Trip Counter
Distance Element (2 zones of protection)
Breaker Failure
Reactive Power (kvar) for loss of field
Trip Coil Monitor
Reverse Power for anti-motoring
VT Fuse Failure
Low Forward Power
Demand: Current, MW, Mvar, MVA
RTDs: Stator, Bearing, Ambient, Other
Generator Running Hours
Thermal Overload
Analog Inputs 1 to 4
Analog Inputs 1 to 4
Service (Self-Test Failure)
Electrical Lockout
IRIG-B Failure
The following protection elements require neutral-end current inputs.
• Distance Element
• Offline Overcurrent
• Phase Differential
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
2–3
CHAPTER 2: INTRODUCTION
Power metering is a standard feature in the 489. The table below outlines the metered
parameters available to the operator through the front panel and communications ports.
The 489 is equipped with three independent communications ports. The front panel RS232
port may be used for setpoint programming, local interrogation or control, and firmware
upgrades. The computer RS485 port may be connected to a PLC, DCS, or PC based
interface software. The auxiliary RS485 port may be used for redundancy or simultaneous
interrogation and/or control from a second PLC, DCS, or PC program. There are also four
4 to 20 mA transducer outputs that may be assigned to any measured parameter. The
range of these outputs is scalable. Additional features are outlined below.
Table 2–2: Metering and Additional Features
Metering
Additional Features
Voltage (phasors)
Drawout Case (maintenance and testing)
Current (phasors) and Amps Demand
Breaker Failure
Real Power, MW Demand, MWh
Trip Coil Supervision
Apparent Power and MVA demand
VT Fuse Failure
MW, Mvar, and ±MVarh demand
Simulation
Frequency
Flash Memory for easy firmware
upgrades
Power Factor
RTD
Speed in RPM with a Key Phasor Input
User-Programmable Analog Inputs
2.1.2
Ordering
All features of the 489 are standard, there are no options. The phase CT secondaries,
control power, and analog output range must be specified at the time of order. There are
two ground CT inputs: one for a 50:0.025 CT and one for a ground CT with a 1 A secondary
(may also accommodate a 5 A secondary). The VT inputs accommodate VTs in either a
delta or wye configuration. The output relays are always non-failsafe with the exception of
the service relay. The EnerVista 489 Setup software is provided with each unit. A metal
demo case may be ordered for demonstration or testing purposes.
2–4
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 2: INTRODUCTION
Table 2–3: 489 Order Codes
489 –
Base unit
489
Phase current inputs
*
|
P1
P5
–
*
|
|
|
LO
Control power
HI
Analog outputs
Display
–
*
|
|
|
|
|
|
|
A1
A20
–
*
–
|
|
|
|
|
|
|
|
|
|
E
T
Harsh environment
*
|
|
|
|
|
|
|
|
|
|
|
|
H
489 Generator Management Relay
1 A phase CT secondaries
5 A phase CT secondaries
20 to 60 V DC;
20 to 48 V AC at 48 to 62 Hz
90 to 300 V DC;
70 to 265 V AC at 48 to 62 Hz
0 to 1 mA analog outputs
4 to 20 mA analog outputs
Basic display
Enhanced display, larger LCD
Enhanced with Ethernet (10Base-T)
Harsh (chemical) environment conformal
coating
For example, the 489-P1-LO-A20-E code specifies a 489 Generator Management Relay
with 1 A CT inputs, 20 to 60 V DC or 20 to 48 V AC control voltage, 4 to 20 mA analog
outputs, and an enhanced display.
2.1.3
Other Accessories
Additional 489 accessories are listed below.
• EnerVista 489 Setup software: no-charge software provided with the 489
• SR 19-1 PANEL: single cutout for 19” panel
• SR 19-2 PANEL: double cutout for 19” panel
• SCI MODULE: RS232 to RS485 converter box, designed for harsh industrial
environments
• Phase CT: 50, 75, 100, 150, 200, 250, 300, 350, 400, 500, 600, 750, 1000 phase CT
primaries
• HGF3, HGF5, HGF8: For sensitive ground detection on high resistance grounded
systems
• 489 1 3/8-inch Collar: For shallow switchgear, reduces the depth of the relay by 1
3/8 inches
• 489 3-inch Collar: For shallow switchgear, reduces the depth of the relay by 3
inches
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
2–5
CHAPTER 2: INTRODUCTION
2.2
Specifications
2.2.1
Inputs
ANALOG CURRENT INPUTS
Inputs:
0 to 1 mA, 0 to 20 mA, 4 to 20mA (setpoint)
Input impedance:
226 Ω ±10%
Conversion range:
0 to 20 mA
Accuracy:
±1% of full scale
Type:
Passive
Analog input supply:
+24 V DC at 100 mA max.
Sampling Interval:
50 ms
ANALOG INPUTS FREQUENCY TRACKING
Frequency tracking:
Va for wye, Vab for open delta; 6 V minimum, 10 Hz/s
DIGITAL INPUTS
Inputs:
External switch:
9 opto-isolated inputs
dry contact < 400 Ω, or open collector NPN transistor from
sensor. 6 mA sinking from internal 4K pull-up at 24 V DC with
Vce < 4 V DC
24 V DC at 20 mA max.
489 sensor supply:
GROUND CURRENT INPUT
CT primary:
CT secondary:
Conversion range:
10 to 10000 A (1 A / 5 A CTs)
1 A / 5 A or 50:0.025 (HGF CTs)
0.02 to 20 × CT for 1A/5A CTs
0.0 to 100 A primary for 50:0.025 CTs (HGF)
±0.1 A at < 10 A
±1.0 A at ≥ 10 to 100 A
at < 2 × CT: ±0.5% of 2 × CT
at ≥ 2 × CT: ±1% of 20 × CT
50:0.025 CT accuracy:
1 A / 5 A CT accuracy:
GROUND CT BURDEN
Ground CT
Input
Burden
Ω
VA
1A
1A/5A
50:0.025 HGF
0.024
0.024
5A
0.605
0.024
20 A
9.809
0.024
0.025 A
0.057
90.7
0.1 A
0.634
90.7
0.5 A
18.9
75.6
GROUND CT CURRENT WITHSTAND (SECONDARY)
Ground CT
Withstand Time
1 sec.
2 sec.
continuo
us
1A/5A
80 × CT
40 × CT
3 × CT
50:0.025 HGF
N/A
N/A
150 mA
NEUTRAL VOLTAGE INPUT
VT ratio:
VT secondary:
Conversion range:
2–6
1.00 to 240.00:1 in steps of 0.01
100 V AC (full-scale)
0.005 to 1.00 × Full Scale
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 2: INTRODUCTION
Accuracy:
Max. continuous:
Fundamental:+/-0.5% of Full Scale
3rd Harmonic at >3V secondary: +/-5% of reading
3rd Harmonic at < 3V secondary: +/- 0.15% of full scale
280 V AC
OUTPUT AND NEUTRAL END CURRENT INPUTS
CT primary:
CT secondary:
Conversion range:
Accuracy:
Burden:
CT withstand:
10 to 50000 A
1 A or 5 A (specify with order)
0.02 to 20 × CT
at < 2 × CT: ±0.5% of 2 × CT
at ≥ 2 × CT: ±1% of 20 × CT
Less than 0.2 VA at rated load
1 s at 80 × rated current
2 s at 40 × rated current
continuous at 3 × rated current
PHASE VOLTAGE INPUTS
VT ratio:
VT secondary:
Conversion range:
Accuracy:
Max. continuous:
Burden:
1.00 to 300.00:1 in steps of 0.01
200 V AC (full-scale)
0.02 to 1.00 × full-scale
±0.5% of full-scale
280 V AC
> 500 KΩ
RTD INPUTS
RTDs (3-wire type):
RTD sensing current:
Isolation:
Range:
Accuracy:
Lead resistance:
NO sensor:
Short/low alarm:
100 Ω Platinum (DIN.43760)
100 Ω Nickel, 120 Ω Nickel,
10 Ω Copper
5 mA
36 Vpk (isolated with analog inputs and outputs)
–50 to +250°C
±2°C/±4°F for Pt and Ni
±5°C/±9°F for Cu
25 Ω max. per lead (Pt and Ni types); 3 Ω max. per lead (Cu type)
>1 kΩ
<–50°C
IRIG-B
Amplitude Modulated:
DC shift:
Input impedance:
2.2.2
2.5 to 6.0 Vpk-pk at 3:1 signal ratio
TTL
50 kΩ ±10%
Outputs
ANALOG CURRENT OUTPUT
Type:
Range:
Accuracy:
4 to 20 mA max. load:
0 to 1 mA max. load:
Isolation:
4 assignable outputs:
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
Active
4 to 20mA, 0 to 1 mA
(must be specified with order)
±1% of full scale
1.2 kΩ
10 kΩ
36 Vpk (isolated with RTDs and analog inputs)
phase A, B, C output current, three-phase average current,
negative sequence current, generator load, hottest stator RTD,
hottest bearing RTD, RTDs 1 to 12, voltage (AB, BC, and CA),
2–7
CHAPTER 2: INTRODUCTION
average phase-phase voltage, volts/hertz, frequency, third
harmonic neutral voltage, power (3-phase Mvar, MW, and MVA),
power factor, analog inputs 1 to 4, tachometer, thermal
capacity used, demand (I, Mvar, MW, and MVA), torque
PULSE OUTPUT
Parameters:
Interval:
Pulse width:
+ kwh, +kvarh, –kvarh
1 to 50000 in steps of 1
200 to 1000 ms in steps of 1
RELAYS
Relay contacts must be considered unsafe to touch when the relay 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.
Configuration:
Contact material:
Operate time:
Make/carry:
6 electromechanical Form-C relays
silver alloy
10 ms
30 A for 0.2 s,
10 A continuous (for 100000 operations)
Maximum ratings for 100000 operations:
Voltage
Break
30 V
DC Resistive
DC inductive
L/R = 40 ms
AC Resistive
AC Inductive PF
= 0.4
2.2.3
10 A
Max. Load
300 W
125 V
0.5 A
62.5 W
250 V
0.3 A
75 W
30 V
5A
150 W
125 V
0.25 A
31.3 W
250 V
0.15 A
37.5 W
120 V
10 A
2770 VA
250 V
10 A
2770 VA
120 V
4A
480 VA
250 V
3A
750 VA
Protection
PHASE DISTANCE (IMPEDANCE)
Characteristics:
Reach (secondary Ω):
Reach accuracy:
Characteristic angle:
Time delay:
Timing accuracy:
Number of zones:
offset mho
0.1 to 500.0 Ω in steps of 0.1
±5%
50 to 85° in steps of 1
0.15 to 150.0 s in steps of 0.1
±50 ms or ±0.5% of total time
2
GROUND DIRECTIONAL
Pickup level:
Time delay:
Pickup accuracy:
Timing accuracy:
Elements:
0.05 to 20.00 × CT in steps of 0.01
0.1 to 120.0 s in steps of 0.1
as per phase current inputs
±100 ms or ±0.5% of total time
Trip and Alarm
GROUND OVERCURRENT
Pickup level:
Curve shapes:
2–8
0.05 to 20.00 × CT in steps of 0.01
ANSI, IEC, IAC, Flexcurve, Definite Time
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 2: INTRODUCTION
Time delay:
Pickup accuracy:
Timing accuracy:
Elements:
0.00 to 100.00 s in steps of 0.01
as per ground current input
+50 ms at 50/60 Hz or ±0.5% total time
Trip
HIGH-SET PHASE OVERCURRENT
Pickup level:
Time delay:
Pickup accuracy:
Timing accuracy:
Elements:
0.15 to 20.00 × CT in steps of 0.01
0.00 to 100.00 s in steps of 0.01
as per phase current inputs
±50 ms at 50/60 Hz or ±0.5% total time
Trip
INADVERTENT ENERGIZATION
Arming signal:
Pickup level:
Time delay:
Pickup accuracy:
Timing accuracy:
Elements:
undervoltage and/or offline from breaker status
0.05 to 3.00 × CT in steps of 0.01 of any one phase
no intentional delay
as per phase current inputs
+50 ms at 50/60 Hz
Trip
LOSS OF EXCITATION (IMPEDANCE)
Pickup level:
Time delay:
Pickup accuracy:
Timing accuracy:
Elements:
2.5 to 300.0 Ω secondary in steps of 0.1 with adjustable
impedance offset 1.0 to 300.0 Ω secondary in steps of 0.1
0.1 to 10.0 s in steps of 0.1
as per voltage and phase current inputs
±100 ms or ±0.5% of total time
Trip (2 zones using impedance circles)
NEGATIVE SEQUENCE OVERCURRENT
Pickup level:
Curve shapes:
Time delay:
Pickup accuracy:
Timing accuracy:
Elements:
3 to 100% FLA in steps of 1
I22t trip defined by k, definite time alarm
0.1 to 100.0 s in steps of 0.1
as per phase current inputs
±100ms or ± 0.5% of total time
Trip and Alarm
NEUTRAL OVERVOLTAGE (FUNDAMENTAL)
Pickup level:
Time delay:
Pickup accuracy:
Timing accuracy:
Elements:
2.0 to 100.0 V secondary in steps of 0.01
0.1 to 120.0 s in steps of 0.1
as per neutral voltage input
±100 ms or ±0.5% of total time
Trip and Alarm
NEUTRAL UNDERVOLTAGE
(3RD HARMONIC)
Blocking signals:
Pickup level:
Time delay:
Pickup accuracy:
Timing accuracy:
Elements:
low power and low voltage if open delta
0.5 to 20.0 V secondary in steps of 0.01 if open delta VT;
adaptive if wye VT
5 to 120 s in steps of 1
as per Neutral Voltage Input
±3.0 s
Trip and Alarm
OFFLINE OVERCURRENT
Pickup level:
Time delay:
Pickup accuracy:
Timing accuracy:
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
0.05 to 1.00 × CT in steps of 0.01 of any one phase
3 to 99 cycles in steps of 1
as per phase current inputs
+50ms at 50/60 Hz
2–9
CHAPTER 2: INTRODUCTION
Elements:
Trip
OTHER FEATURES
Serial Start/Stop Initiation, Remote Reset (configurable digital input), Test Input
(configurable digital input), Thermal Reset (configurable digital
input), Dual Setpoints, Pre-Trip Data, Event Recorder, Waveform
Memory, Fault Simulation, VT Failure, Trip Counter, Breaker
Failure, Trip Coil Monitor, Generator Running Hours Alarm, IRIGB Failure Alarm
OVERCURRENT ALARM
Pickup level:
Time delay:
Pickup accuracy:
Timing accuracy:
Elements:
0.10 to 1.50 × FLA in steps of 0.01 (average phase current)
0.1 to 250.0 s in steps of 0.1
as per phase current inputs
±100 ms or ±0.5% of total time
Alarm
OVERFREQUENCY
Required voltage:
Block from online:
Pickup level:
Curve shapes:
Time delay:
Pickup accuracy:
Timing accuracy:
Elements:
0.50 to 0.99 × rated voltage in Phase A
0 to 5 sec. in steps of 1
25.01 to 70.00 in steps of 0.01
1 level alarm, 2 level trip definite time
0.1 to 5000.0 s in steps of 0.1
±0.02 Hz
±150 ms or ±1% of total time at 50Hz and 60Hz; ±300 ms or 2%
of total time at 25Hz
Trip and Alarm
OVERLOAD / STALL PROTECTION / THERMAL MODEL
Overload curves:
Curve biasing:
Overload pickup:
Pickup accuracy:
Timing accuracy:
Elements:
15 Standard Overload Curves, Custom Curve, and Voltage
Dependent Custom Curve (all curves time out against average
phase current)
Phase Unbalance, Hot/Cold Curve Ratio, Stator RTD, Online
Cooling Rate, Offline Cooling Rate, Line Voltage
1.01 to 1.25
as per phase current inputs
±100 ms or ±2% of total time
Trip and Alarm
OVERVOLTAGE
Pickup level:
Curve shapes:
Time Delay:
Pickup accuracy:
Timing accuracy:
Elements:
1.01 to 1.50 × rated V in steps of 0.01
Inverse Time, definite time alarm
0.2 to 120.0 s in steps of 0.1
as per Voltage Inputs
±100 ms or ±0.5% of total time
Trip and Alarm
PHASE DIFFERENTIAL
Pickup level:
Curve shape:
Time delay:
Pickup accuracy:
Timing accuracy:
Elements:
0.05 to 1.00 × CT in steps of 0.01
Dual Slope
0 to 100 cycles in steps of 1
as per phase current inputs
+50 ms at 50/60 Hz or ±0.5% total time
Trip
PHASE OVERCURRENT
Voltage restraint:
Pickup level:
2–10
programmable fixed characteristic
0.15 to 20.00 × CT in steps of 0.01 of any one phase
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 2: INTRODUCTION
Curve shapes:
Time delay:
Pickup accuracy:
Timing accuracy:
Elements:
ANSI, IEC, IAC, FlexCurve, Definite Time
0.000 to 100.000 s in steps of 0.001
as per phase current inputs
+50 ms at 50/60 Hz or ±0.5% total time
Trip
RTDS 1 TO 12
Pickup:
Pickup hysteresis:
Time delay:
Elements:
1 to 250°C in steps of 1
2°C
3 sec.
Trip and Alarm
UNDERFREQUENCY
Required voltage:
Block from online:
Pickup level:
Curve shapes:
Time delay:
Pickup accuracy:
Timing accuracy:
Elements:
0.50 to 0.99 × rated voltage in Phase A
0 to 5 sec. in steps of 1
20.00 to 60.00 in steps of 0.01
1 level alarm, two level trip definite time
0.1 to 5000.0 sec. in steps of 0.1
±0.02 Hz
±150 ms or ±1% of total time at 50Hz and 60Hz; ±300 ms or 2%
of total time at 25Hz
Trip and Alarm
UNDERVOLTAGE
Pickup level:
Curve shapes:
Time Delay:
Pickup accuracy:
Timing accuracy:
Elements:
0.50 to 0.99 × rated V in steps of 0.01
Inverse Time, definite time alarm
0.2 to 120.0 s in steps of 0.1
as per voltage inputs
±100 ms or ±0.5% of total time
Trip and Alarm
VOLTAGE PHASE REVERSAL
Configuration:
Timing accuracy:
Elements:
ABC or ACB phase rotation
200 to 400 ms
Trip
VOLTS PER HERTZ
Pickup level:
Curve shapes:
Time delay:
Pickup accuracy:
Timing accuracy:
Elements:
2.2.4
1.00 to 1.99 × nominal in steps of 0.01
Inverse Time, definite time alarm
0.1 to 120.0 s in steps of 0.1
as per voltage inputs
±100 ms at ≥ 1.2 × Pickup
±300 ms at < 1.2 × Pickup
Trip and Alarm
Digital Inputs
FIELD BREAKER DISCREPANCY
Configurable:
Time delay:
Timing accuracy:
Elements:
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
assignable to Digital Inputs 1 to 7
0.1 to 500.0 s in steps of 0.1
±100 ms or ±0.5% of total time
Trip
2–11
CHAPTER 2: INTRODUCTION
GENERAL INPUT A TO G
Configurable:
Time delay:
Block from online:
Timing accuracy:
Elements:
ssignable Digital Inputs 1 to 7
0.1 to 5000.0 s in steps of 0.1
0 to 5000 s in steps of 1
±100 ms or ±0.5% of total time
Trip, Alarm, and Control
SEQUENTIAL TRIP
Configurable:
Pickup level:
Time delay:
Pickup accuracy:
Timing accuracy:
Elements:
assignable to Digital Inputs 1 to 7
0.02 to 0.99 × rated MW in steps of 0.01, Low Forward Power /
Reverse Power
0.2 to 120.0 s in steps of 0.1
see power metering
±100 ms or ±0.5% of total time
Trip
TACHOMETER
Configurable:
RPM measurement:
Duty cycle of pulse:
Pickup level:
Time delay:
Timing accuracy:
Elements:
2.2.5
assignable to Digital Inputs 4 to 7
0 to 7200 RPM
>10%
101 to 175 × rated speed in steps of 1
1 to 250 s in steps of 1
±0.5 s or ±0.5% of total time
Trip and Alarm
Monitoring
DEMAND METERING
Metered values:
Measurement type:
Demand interval:
Update rate:
Elements:
maximum phase current,
3 phase real power,
3 phase apparent power,
3 phase reactive power
rolling demand
5 to 90 min. in steps of 1
1 minute
Alarm
ENERGY METERING
Description:
Range:
Timing accuracy:
Update Rate:
continuous total of +watthours and ±varhours
0.000 to 4000000.000 Mvarh
±0.5%
50 ms
LOW FORWARD POWER
Block from online:
Pickup level:
Time delay:
Pickup accuracy:
Timing accuracy:
Elements:
2–12
0 to 15000 s in steps of 1
0.02 to 0.99 × rated MW
0.2 to 120.0 s in steps of 0.1
see power metering
±100 ms or ±0.5% of total time
Trip and Alarm
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 2: INTRODUCTION
POWER METERING
Range:
-2000.000 to 2000.000 MW,
–2000.000 to 2000.000 Mvar,
0 to 2000.000 MVA
Accuracy at Iavg < 2 × CT: ±1% of 3 × 2 × CT × VTratio × VTfull-scale
Accuracy at Iavg > 2 × CT: ±1.5% of 3 × 20 × CT × VTratio × VTfull-scale
REACTIVE POWER
Block from online:
Pickup level:
Time delay:
Pickup accuracy:
Timing accuracy:
Elements:
0 to 5000 s in steps of 1
0.02 to 1.50 × rated Mvar
(positive and negative)
0.2 to 120.0 s in steps of 0.1
see power metering
±100ms or ±0.5% of total time
Trip and Alarm
REVERSE POWER
Block from online:
Pickup level:
Time delay:
Pickup accuracy:
Timing accuracy:
Elements:
0 to 5000 s in steps of 1
0.02 to 0.99 × rated MW
0.2 to 120.0 s in steps of 0.1
see power metering
±100 ms or ±0.5% of total time
Trip and Alarm
TRIP COIL SUPERVISION
Applicable voltage:
Trickle current:
2.2.6
20 to 300 V DC/AC
2 to 5 mA
Power Supply
CONTROL POWER
Options:
LO range:
LO / HI (specify with order)
20 to 60 V DC
20 to 48 V AC at 48 to 62 Hz
HI range:
90 to 300 V DC
70 to 265 V AC at 48 to 62 Hz
Power:
45 VA (max.), 25 VA typical
Total loss of voltage ride through time (0% control power): 16.7 ms
It is recommended that the 489 be powered up at least once per year to prevent
deterioration of electrolytic capacitors in the power supply.
FUSE
Current rating:
Type:
Model:
2.5 A
5x20mm HRC SLO-BLO Littelfuse
215-02.5
An external fuse must be used if the supply voltage exceeds 250 V
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
2–13
CHAPTER 2: INTRODUCTION
2.2.7
Communications
COMMUNICATIONS PORTS
RS232 port:
RS485 ports:
RS485 baud rates:
RS232 baud rate:
Parity:
Protocol:
2.2.8
1, front panel, non-isolated
2, isolated together at 36 Vpk
300, 1200, 2400, 4800, 9600, 19200
9600
None, Odd, Even
Modbus® RTU / half duplex, DNP 3.0
Testing
PRODUCTION TESTS
Thermal cycling:
Dielectric strength:
Operational test at ambient, reducing to –40°C and then
increasing to 60°C
1.9 kV AC for 1 second or 1.6 kV AC for one minute, per UL 508.
DO NOT CONNECT FILTER GROUND TO SAFETY GROUND DURING ANY PRODUCTION TESTS!
TYPE TESTING
The table below lists the 489 type tests:
2–14
Test
Reference Standard
Test Level
Dielectric voltage
withstand
EN60255-5
2.3KV
Impulse voltage withstand
EN60255-5
5KV
Insulation resistance
EN60255-5
500Vdc
Damped Oscillatory
IEC61000-4-18IEC60255-22-1
2.5KV CM, 1KV DM
Electrostatic Discharge
EN61000-4-2/IEC60255-22-2
Level 4
RF immunity
EN61000-4-3/IEC60255-22-3
Level 3
Fast Transient Disturbance
EN61000-4-4/IEC60255-22-4
Class A and B
Surge Immunity
EN61000-4-5/IEC60255-22-5
Level 3 & 4
Conducted RF Immunity
EN61000-4-6/IEC60255-22-6
Level 3
Radiated & Conducted
Emissions
CISPR11 /CISPR22/ IEC60255-25
Class A
Sinusoidal Vibration
IEC60255-21-1
Class 1
Power magnetic Immunity
IEC61000-4-8
Level 4
Voltage Dip & interruption
IEC61000-4-11
0, 40, 70% dips, 250/
300 cycle interrupts
Ingress Protection
IEC60529
IP40 front , IP10A Back
Environmental (Cold)
IEC60068-2-1
-40C 16 hrs
Environmental (Dry heat)
IEC60068-2-2
85C 16hrs
Relative Humidity Cyclic
IEC60068-2-30
6day variant 2
EFT
IEEE/ANSI C37.90.1
4KV, 2.5Khz
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 2: INTRODUCTION
Test
Reference Standard
Test Level
Damped Oscillation
IEEE/ANSI C37.90.1
2.5KV, 1.0Mhz
ESD
IEEE/ANSIC37.90.3
8KV CD/ 15KV AD
UL508
e83849 NKCR
UL C22.2-14
e83849 NKCR7
UL1053
e83849 NKCR
Safety
2.2.9
Approvals
CE compliance
North America
Applicable Council Directive
According to
Low voltage directive
EN60255-5/EN60255-27
EMC Directive
EN50263
cULus
UL508
UL1053
C22.2.No 14
ISO
Manufactured under a registered ISO9001
quality program
2.2.10 Physical
CASE
Drawout:
Seal:
Door:
Mounting:
IP Class:
Fully drawout (automatic CT shorts)
Seal provision
Dust tight door
Panel or 19" rack mount
IP10A
PACKAGING
Shipping box:
Shipping weight:
12” × 11” × 10” (W × H × D)
30.5cm × 27.9cm × 25.4cm
17 lbs / 7.7 kg max.
TERMINALS
Low voltage (A, B, C, D terminals): 12 AWG max
High voltage (E, F, G, H terminals): #8 ring lug, 10 AWG wire standard
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
2–15
CHAPTER 2: INTRODUCTION
2.2.11 Environmental
Ambient temperatures:
Note
2–16
Storage/Shipping:
-40C to 85C
Operating:
-40C to 60C
Humidity:
Operating up to 95% (non condensing) @ 55C (As per
IEC60068-2-30 Variant 2, 6days)
Altitude:
2000m (max)
Pollution Degree:
II
Overvoltage Category:
II
Ingress protection:
IP40 Front , IP10A back
At temperatures less than –20°C, the LCD contrast may be impaired.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 2: INTRODUCTION
2.2.12 Long-term Storage
LONG-TERM STORAGE
Environment:
Correct storage:
Note
In addition to the above environmental considerations, the
relay should be stored in an environment that is dry, corrosivefree, and not in direct sunlight.
Prevents premature component failures caused by
environmental factors such as moisture or corrosive gases.
Exposure to high humidity or corrosive environments will
prematurely degrade the electronic components in any
electronic device regardless of its use or manufacturer, unless
specific precautions, such as those mentioned in the
Environmental section above, are taken.
It is recommended that all relays be powered up once per year, for one hour continuously,
to avoid deterioration of electrolytic capacitors and subsequent relay failure.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
2–17
CHAPTER 2: INTRODUCTION
2–18
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
Digital Energy
Multilin
489 Generator Management Relay
Chapter 3: Installation
Installation
3.1
Mechanical Installation
3.1.1
Description
The 489 is packaged in the standard GE Multilin SR-series arrangement, which consists of
a drawout unit and a companion fixed case. The case provides mechanical protection to
the unit, and is used to make permanent connections to all external equipment. The only
electrical components mounted in the case are those required to connect the unit to the
external wiring. Connections in the case are fitted with mechanisms required to allow the
safe removal of the relay unit from an energized panel, such as automatic CT shorting. The
unit is mechanically held in the case by pins on the locking handle, which cannot be fully
lowered to the locked position until the electrical connections are completely mated. Any
489 can be installed in any 489 case, except for custom manufactured units that are
clearly identified as such on both case and unit, and are equipped with an index pin keying
mechanism to prevent incorrect pairings.
No special ventilation requirements need to be observed during the installation of the unit,
but the unit should be wiped clean with a damp cloth.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
3–1
CHAPTER 3: INSTALLATION
FIGURE 3–1: 489 Dimensions
To prevent unauthorized removal of the drawout unit, a wire lead seal can be installed in
the slot provided on the handle as shown below. With this seal in place, the drawout unit
cannot be removed. A passcode or setpoint access jumper can be used to prevent entry of
setpoints but still allow monitoring of actual values. If access to the front panel controls
must be restricted, a separate seal can be installed on the outside of the cover to prevent it
from being opened.
Seal location
FIGURE 3–2: Drawout Unit Seal
Hazard may result if the product is not used for its intended purpose.
3.1.2
Product Identification
Each 489 unit and case are equipped with a permanent label. This label is installed on the
left side (when facing the front of the relay) of both unit and case. The case label details
which units can be installed.
The case label details the model number, manufacture date, and special notes.
The unit label details the model number, type, serial number, file number, manufacture
date, phase current inputs, special notes, overvoltage category, insulation voltage,
pollution degree, control power, and output contact rating.
3–2
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 3: INSTALLATION
FIGURE 3–3: Product Case and Unit Labels
3.1.3
Installation
The 489 case, alone or adjacent to another SR-series unit, can be installed in a standard
19-inch rack panel (see 489 Dimensions on page 3–2). Provision must be made for the front
door to swing open without interference to, or from, adjacent equipment. The 489 unit is
normally mounted in its case when shipped from the factory and should be removed
before mounting the case in the supporting panel. Unit withdrawal is described in the next
section.
After the mounting hole in the panel has been prepared, slide the 489 case into the panel
from the front. Applying firm pressure on the front to ensure the front bezel fits snugly
against the front of the panel, bend out the pair of retaining tabs (to a horizontal position)
from each side of the case, as shown below. The case is now securely mounted, ready for
panel wiring.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
3–3
CHAPTER 3: INSTALLATION
808704A1.CDR
FIGURE 3–4: Bend Up Mounting Tabs
3.1.4
Unit Withdrawal and Insertion
TURN OFF CONTROL POWER BEFORE DRAWING OUT OR RE-INSERTING THE RELAY TO
PREVENT MALOPERATION!
If an attempt is made to install a unit into a non-matching case, the mechanical key
will prevent full insertion of the unit. Do not apply strong force in the following step or
damage may result.
To remove the unit from the case:
Z Open the cover by pulling the upper or lower corner of the right side,
which will rotate about the hinges on the left.
Z Release the locking latch, located below the locking handle, by
pressing upward on the latch with the tip of a screwdriver.
FIGURE 3–5: Press Latch to Disengage Handle
3–4
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 3: INSTALLATION
Z Grasp the locking handle in the center and pull firmly, rotating the
handle up from the bottom of the unit until movement ceases.
FIGURE 3–6: Rotate Handle to Stop Position
Once the handle is released from the locking mechanism, the unit can freely slide
out of the case when pulled by the handle. It may sometimes be necessary to
adjust the handle position slightly to free the unit.
FIGURE 3–7: Slide Unit out of Case
To insert the unit into the case:
Z Raise the locking handle to the highest position.
Z Hold the unit immediately in front of the case and align the rolling
guide pins (near the hinges of the locking handle) to the guide slots
on either side of the case.
Z Slide the unit into the case until the guide pins on the unit have
engaged the guide slots on either side of the case.
Z Grasp the locking handle from the center and press down firmly,
rotating the handle from the raised position toward the bottom of
the unit.
When the unit is fully inserted, the latch will be heard to click, locking the handle in
the final position.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
3–5
CHAPTER 3: INSTALLATION
3.1.5
Ethernet Connection
If using the 489 with the Ethernet 10Base-T option, ensure that the network 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 inches 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 be re-inserted by first connecting the network cable to the rear RJ45
connector of the 489 (see step 3 of Unit Withdrawal and Insertion on page 3–4).
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
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
The RS485 COM2 port is disabled if the Ethernet option is ordered.
3–6
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 3: INSTALLATION
3.1.6
Terminal Locations
FIGURE 3–9: Terminal Layout
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
3–7
CHAPTER 3: INSTALLATION
Table 3–1: 489 Terminal List
Terminal
A01
3–8
Description
RTD #1 Hot
Terminal
D21
Description
Assignable Switch 6
A02
RTD #1 Compensation
D22
Assignable Switch 7
A03
RTD Return
D23
Switch Common
A04
RTD #2 Compensation
D24
Switch +24 V DC
A05
RTD #2 Hot
D25
Computer RS485 +
A06
RTD #3 Hot
D26
Computer RS485 –
A07
RTD #3 Compensation
D27
Computer RS485 Common
A08
RTD Return
E01
1 Trip NC
1 Trip NO
A09
RTD #4 Compensation
E02
A10
RTD #4 Hot
E03
2 Auxiliary Common
A11
RTD #5 Hot
E04
3 Auxiliary NC
A12
RTD #5 Compensation
E05
3 Auxiliary NO
A13
RTD Return
E06
4 Auxiliary Common
A14
RTD #6 Compensation
E07
5 Alarm NC
A15
RTD #6 Hot
E08
5 Alarm NO
A16
Analog Output Common –
E09
6 Service Common
A17
Analog Output 1 +
E10
Neutral VT Common
A18
Analog Output 2 +
E11
Coil Supervision +
A19
Analog Output 3 +
E12
IRIG-B +
A20
Analog Output 4 +
F01
1 Trip Common
A21
Analog Shield
F02
2 Auxiliary NO
A22
Analog Input 24 V DC Supply +
F03
2 Auxiliary NC
A23
Analog Input 1 +
F04
3 Auxiliary Common
A24
Analog Input 2 +
F05
4 Auxiliary NO
A25
Analog Input 3 +
F06
4 Auxiliary NC
A26
Analog Input 4 +
F07
5 Alarm Common
A27
Analog Input Common –
F08
6 Service NO
B01
RTD Shield
F09
6 Service NC
B02
Auxiliary RS485 +
F10
Neutral VT +
B03
Auxiliary RS485 –
F11
Coil Supervision –
B04
Auxiliary RS485 Common
F12
IRIG-B –
C01
Access +
G01
Phase VT Common
C02
Access –
G02
Phase A VT •
C03
Breaker Status +
G03
Neutral Phase A CT •
C04
Breaker Status –
G04
Neutral Phase B CT •
D01
RTD #7 Hot
G05
Neutral Phase C CT •
D02
RTD #7 Compensation
G06
Output Phase A CT •
D03
RTD Return
G07
Output Phase B CT •
D04
RTD #8 Compensation
G08
Output Phase C CT •
D05
RTD #8 Hot
G09
1A Ground CT •
D06
RTD #9 Hot
G10
HGF Ground CT •
D07
RTD #9 Compensation
G11
Filter Ground
D08
RTD Return
G12
Safety Ground
D09
RTD #10 Compensation
H01
Phase B VT •
D10
RTD #10 Hot
H02
Phase C VT •
D11
RTD #11 Hot
H03
Neutral Phase A CT
D12
RTD #11 Compensation
H04
Neutral Phase B CT
D13
RTD Return
H05
Neutral Phase C CT
D14
RTD #12 Compensation
H06
Output Phase A CT
D15
RTD #12 Hot
H07
Output Phase B CT
D16
Assignable Switch 1
H08
Output Phase C CT
D17
Assignable Switch 2
H09
1A Ground CT
D18
Assignable Switch 3
H10
HGF Ground CT
D19
Assignable Switch 4
H11
Control Power –
D20
Assignable Switch 5
H12
Control Power +
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 3: INSTALLATION
3.2
Electrical Installation
3.2.1
Typical Wiring
FIGURE 3–10: Typical Wiring Diagram
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
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CHAPTER 3: INSTALLATION
3.2.2
General Wiring Considerations
A broad range of applications are available to the user and 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. See Terminal Layout on
page 3–7 and 489 Terminal List on page 3–8 for terminal arrangement, and Typical Wiring
Diagram on page 3–9 for typical connections.
FIGURE 3–11: Typical Wiring (Detail)
3.2.3
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 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 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.
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489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
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Ensure applied control voltage and rated voltage on drawout case terminal label match.
For example, the HI power supply will work with any DC voltage from 90 to 300 V, or AC
voltage from 70 to 265 V. The internal fuse may blow if the applied voltage exceeds this
range.
Extensive filtering and transient protection are built into the 489 to ensure proper
operation in harsh industrial environments. Transient energy must be conducted back to
the source through the filter ground terminal. A separate safety ground terminal is
provided for hi-pot testing.
FIGURE 3–12: Control Power Connection
3.2.4
Current Inputs
Phase Current
The 489 has six phase current transformer inputs (three output side and three neutral end),
each with an isolating transformer. There are no internal ground connections on the CT
inputs. Each phase CT circuit is shorted by automatic mechanisms on the 489 case if the
unit is withdrawn. The phase CTs should be chosen such that the FLA is no less than 50% of
the rated phase CT primary. Ideally, the phase CT primary should be chosen such that the
FLA is 100% of the phase CT primary or slightly less. This will ensure maximum accuracy
for the current measurements. The maximum phase CT primary current is 50000 A.
The 489 will measure correctly up to 20 times the phase current nominal rating. Since the
conversion range is large, 1 A or 5 A CT secondaries must be specified at the time of order
such that the appropriate interposing CT may be installed in the unit. CTs chosen must be
capable of driving the 489 phase CT burden (see SPECIFICATIONS for ratings).
Verify that the 489 nominal phase current of 1 A or 5 A matches the secondary rating
and connections of the connected CTs. Unmatched CTs may result in equipment
damage or inadequate protection. Polarity of the phase CTs is critical for phase
differential, negative sequence, power measurement, and residual ground current
detection (if used).
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
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CHAPTER 3: INSTALLATION
Ground Current
The 489 has a dual primary isolating transformer for ground CT connections. There are no
internal ground connections on the ground current inputs. The ground CT circuits are
shorted by automatic mechanisms on the case if the unit is withdrawn. The 1 A tap is used
for 1 A or 5 A secondary CTs in either core balance or residual ground configurations. If the
1 A tap is used, the 489 measures up to 20 A secondary with a maximum ground CT ratio
of 10000:1. The ground CT must be capable of driving the ground CT burden.
The HGF ground CT input is designed for sensitive ground current detection on high
resistance grounded systems where the GE Multilin HGF core balance CT (50:0.025) is used.
In applications such as mines, where earth leakage current must be measured for
personnel safety, primary ground current as low as 0.25 A may be detected with the GE
Multilin HGF CT. Only one ground CT input tap should be used on a given unit.
The HGF CT has a rating of 50:0.025. However if the HGF CT is used in conjunction with the
489, the relay assumes a fixed ratio of 5:0.0025. Therefore, the pickup level in primary
amps will be Pickup × CT, where CT is equal to 5.
Note
Only one ground input should be wired. The other input should be unconnected.
FIGURE 3–13: Residual Ground CT Connection
DO NOT INJECT OVER THE RATED CURRENT TO HGF TERMINAL (0.25 to 25 A PRIMARY).
The exact placement of a zero sequence CT to detect ground fault current is shown below.
If the core balance CT is placed over shielded cable, capacitive coupling of phase current
into the cable shield may be detected as ground current unless the shield wire is also
passed through the CT window. Twisted pair cabling on the zero sequence CT is
recommended.
3–12
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
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FIGURE 3–14: Core Balance Ground CT Installation – Unshielded Cable
FIGURE 3–15: Core Balance Ground CT Installation – Shielded Cable
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
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CHAPTER 3: INSTALLATION
3.2.5
Voltage Inputs
The 489 has four voltage transformer inputs, three for generator terminal voltage and one
for neutral voltage. There are no internal fuses or ground connections on the voltage
inputs. The maximum phase VT ratio is 300.00:1 and the maximum neutral VT ratio is
240.00:1. The two possible VT connections for generator terminal voltage measurement
are open delta or wye (see Typical Wiring Diagram on page 3–9). The voltage channels are
connected in wye internally, which means that the jumper shown on the delta-source
connection of the Typical Wiring Diagram, between the phase B input and the 489 neutral
terminal, must be installed for open delta VTs.
Polarity of the generator terminal VTs is critical for correct power measurement and
voltage phase reversal operation.
3.2.6
Digital Inputs
There are 9 digital inputs that are designed for dry contact connections only. Two of the
digital inputs, Access and Breaker Status have their own common terminal, the balance of
the digital inputs share one common terminal (see Typical Wiring Diagram on page 3–9).
In addition, the +24 V DC switch supply is brought out for control power of an inductive or
capacitive proximity probe. The NPN transistor output could be taken to one of the
assignable digital inputs configured as a counter or tachometer. Refer to the Specifications
section of this manual for maximum current draw from the +24 V DC switch supply.
DO NOT INJECT VOLTAGES TO DIGITAL INPUTS. DRY CONTACT CONNECTIONS ONLY.
3.2.7
Analog Inputs
Terminals are provided on the 489 for the input of four 0 to 1 mA, 0 to 20 mA, or 4 to 20 mA
current signals (field programmable). This current signal can be used to monitor any
external quantity such as: vibration, pressure, field current, etc. The four inputs share one
common return. Polarity of these inputs must be observed for proper operation The analog
input circuitry is isolated as a group with the Analog Output circuitry and the RTD circuitry.
Only one ground reference should be used for the three circuits. Transorbs limit this
isolation to ±36 V with respect to the 489 safety ground.
In addition, the +24 V DC analog input supply is brought out for control power of loop
powered transducers. Refer to the Specifications section of this manual for maximum
current draw from this supply.
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489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 3: INSTALLATION
FIGURE 3–16: Loop Powered Transducer Connection
3.2.8
Analog Outputs
The 489 provides four analog output channels, which when ordered, provide a full-scale
range of either 0 to 1 mA (into a maximum 10 kΩ impedance), or 4 to 20 mA (into a
maximum 1.2K Ω impedance). Each channel can be configured to provide full-scale output
sensitivity for any range of any measured parameter.
As shown in the Typical Wiring Diagram on page 3–9, these outputs share one common
return. The polarity of these outputs must be observed for proper operation. Shielded cable
should be used, with only one end of the shield grounded, to minimize noise effects.
The analog output circuitry is isolated as a group with the Analog Input circuitry and the
RTD circuitry. Only one ground reference should be used for the three circuits. Transorbs
limit this isolation to ±36 V with respect to the 489 safety ground.
If a voltage output is required, a burden resistor must be connected at the input of the
SCADA measuring device. Ignoring the input impedance of the input:
V FULL-SCALE
R LOAD = ----------------------------I MAX
(EQ 3.1)
For example, for a 0 to 1 mA input, if 5 V full scale corresponds to 1 mA, then RLOAD = 5 V /
0.001 A = 5000 Ω. For a 4 to 20 mA input, this resistor would be RLOAD = 5 V / 0.020
A = 250 Ω.
3.2.9
RTD Sensor Connections
The 489 can monitor up to 12 RTD inputs for Stator, Bearing, Ambient, or Other
temperature monitoring. The type of each RTD is field programmable as: 100 Ω Platinum
(DIN 43760), 100 Ω Nickel, 120 Ω Nickel, or 10 Ω Copper. RTDs must be three wire type.
Every two RTDs shares a common return.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
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CHAPTER 3: INSTALLATION
The 489 RTD circuitry compensates for lead resistance, provided that each of the three
leads is the same length. Lead resistance should not exceed 25 Ω per lead for platinum
and nickel RTDs and 3 Ω per lead for copper RTDs. Shielded cable should be used to
prevent noise pickup in the industrial environment. RTD cables should be kept close to
grounded metal casings and avoid areas of high electromagnetic or radio interference.
RTD leads should not be run adjacent to or in the same conduit as high current carrying
wires.
489
RELAY
3 WIRE SHIELDED CABLE
Route cable in separate conduit from
current carrying conductors
RTD TERMINALS
AT GENERATOR
SHIELD
B1
HOT
A1
COMPENSATION
A2
RETURN
A3
RTD #1
RTD SENSING
CHASSIS
GROUND
RTD IN
GENERATOR
STATOR
OR
BEARING
OPTIONAL GROUND
Shield is internally
connected to safety
ground terminal G12
RTD
TERMINALS
Maximum total lead resistance
25 ohms (Platinum & Nickel RTDs)
3 ohms (Copper RTDs)
808761E4.CDR
FIGURE 3–17: RTD Wiring
Note
IMPORTANT NOTE: The RTD circuitry is isolated as a group with the Analog Input circuitry
and the Analog Output circuitry. Only one ground reference should be used for the three
circuits. Transorbs limit this isolation to ±36 V with respect to the 489 safety ground. If code
requires that the RTDs be grounded locally at the generator terminal box, that will also be
the ground reference for the analog inputs and outputs.
3.2.10 Output Relays
There are six Form-C output relays (see Outputs on page 2–7). Five of the six relays are
always non-failsafe, the 6 Service relay is always failsafe. As a failsafe, the 6 Service relay
will be energized normally and de-energize when called upon to operate. It will also deenergize when control power to the 489 is lost and therefore, be in its operated state. All
other relays, being non-failsafe, will be de-energized normally and energize when called
upon to operate. Obviously, when control power is lost to the 489, these relays must be deenergized and therefore, they will be in their non-operated state. Shorting bars in the
drawout case ensure that when the 489 is drawn out, no trip or alarm occurs. The
6 Service output will however indicate that the 489 has been drawn out. Each output relay
has an LED indicator on the 489 front panel that comes on while the associated relay is in
the operated state.
•
1 TRIP: The trip relay should be wired such that the generator is taken offline when
conditions warrant. For a breaker application, the NO 1 Trip contact should be wired in
series with the Breaker trip coil.
Supervision of a breaker trip coil requires that the supervision circuit be paralleled with
the 1 Trip relay output contacts, as shown in the Typical Wiring Diagram on page 3–9.
With this connection made, the supervision input circuits will place an impedance
across the contacts that will draw a current of 2 to 5 mA (for an external supply
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489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 3: INSTALLATION
voltage from 30 to 250 V DC) through the breaker trip coil. The supervision circuits
respond to a loss of this trickle current as a failure condition. Circuit breakers equipped
with standard control circuits have a breaker auxiliary contact permitting the trip coil
to be energized only when the breaker is closed. When these contacts are open, as
detected by the Breaker Status digital input, trip coil supervision circuit is
automatically disabled. This logic provides that the trip circuit is monitored only when
the breaker is closed.
•
2 AUXILIARY, 3 AUXILIARY, 4 AUXILIARY: The auxiliary relays may be programmed for
numerous functions such as, trip echo, alarm echo, trip backup, alarm or trip
differentiation, control circuitry, etc. They should be wired as configuration warrants.
•
5 ALARM: The alarm relay should connect to the appropriate annunciator or
monitoring device.
•
6 SERVICE: The service relay will operate if any of the 489 diagnostics detect an
internal failure or on loss of control power. This output may be monitored with an
annunciator, PLC or DCS.
The service relay NC contact may also be wired in parallel with the trip relay on a
breaker application. This will provide failsafe operation of the generator; that is, the
generator will be tripped offline in the event that the 489 is not protecting it. Simple
annunciation of such a failure will allow the operator or the operation computer to
either continue, or do a sequenced shutdown.
Relay contacts must be considered unsafe to touch when the system is energized! If
the customer requires the relay contacts for low voltage accessible applications, it is
their responsibility to ensure proper insulation levels.
3.2.11 IRIG-B
IRIG-B is a standard time-code format that allows stamping of events to be synchronized
among connected devices within 1 millisecond. The IRIG-B time codes are serial, widthmodulated formats which are either DC level shifted or amplitude modulated (AM). Third
party equipment is available for generating the IRIG-B signal. This equipment may use a
GPS satellite system to obtain the time reference enabling devices at different geographic
locations to be synchronized.
Terminals E12 and F12 on the 489 unit are provided for the connection of an IRIG-B signal.
3.2.12 RS485 Ports
Two independent two-wire RS485 ports are provided. Up to 32 489 relays can be daisychained together on a communication channel without exceeding the driver capability. For
larger systems, additional serial channels must be added. It is also possible to use
commercially available repeaters to increase the number of relays on a single channel to
more than 32. A suitable cable should have a characteristic impedance of 120 Ω (e.g.
Belden #9841) and total wire length should not exceed 4000 feet (approximately 1200
metres). Commercially available repeaters will allow for transmission distances greater
than 4000 ft.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
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CHAPTER 3: INSTALLATION
Voltage differences between remote ends of the communication link are not uncommon.
For this reason, surge protection devices are internally installed across all RS485 terminals.
Internally, an isolated power supply with an optocoupled data interface is used to prevent
noise coupling.
Note
To ensure that all devices in a daisy-chain are at the same potential, it is imperative that
the common terminals of each RS485 port are tied together and grounded only once, at
the master. Failure to do so may result in intermittent or failed communications.
The source computer/PLC/SCADA system should have similar transient protection devices
installed, either internally or externally, to ensure maximum reliability. Ground the shield at
one point only, as shown below, to avoid ground loops.
Correct polarity is also essential. All 489s must be wired with all ‘+’ terminals connected
together, and all ‘–’ terminals connected together. Each relay must be daisy-chained to the
next one. Avoid star or stub connected configurations. The last device at each end of the
daisy chain should be terminated with a 120 Ω ¼ W resistor in series with a 1 nF capacitor
across the ‘+’ and ‘–’ terminals. Observing these guidelines will result in a reliable
communication system that is immune to system transients.
FIGURE 3–18: RS485 Communications Wiring
3.2.13 Dielectric Strength
It may be required to test a complete motor starter for dielectric strength (“flash” or hi-pot”)
with the 489 installed. The 489 is rated for 1.9 kV AC for 1 second, or 1.6 kV AC for 1 minute
(per UL 508) isolation between relay contacts, CT inputs, VT inputs, trip coil supervision,
and the safety ground terminal G12. Some precautions are required to prevent damage to
the 489 during these tests.
Filter networks and transient protection clamps are used between control power, trip coil
supervision, and the filter ground terminal G11. This filtering is intended to filter out high
voltage transients, radio frequency interference (RFI), and electromagnetic interference
(EMI). The filter capacitors and transient suppressors could be damaged by application
continuous high voltage. Disconnect filter ground terminal G11 during testing of control
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489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
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power and trip coil supervision. CT inputs, VT inputs, and output relays do not require any
special precautions. Low voltage inputs (<30 V), RTDs, analog inputs, analog outputs, digital
inputs, and RS485 communication ports are not to be tested for dielectric strength under
any circumstance (see below).
g
GE M ultilin
FIGURE 3–19: Testing the 489 for Dielectric Strength
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
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489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
Digital Energy
Multilin
489 Generator Management Relay
Chapter 4: Interfaces
Interfaces
4.1
Faceplate Interface
4.1.1
Display
All messages appear on a 40-character liquid crystal display. Messages are in plain English
and do not require the aid of an instruction manual for deciphering. When the user
interface is not being used, the display defaults to the user-defined status messages. Any
trip or alarm automatically overrides the default messages and is immediately displayed.
4.1.2
LED Indicators
There are three groups of LED indicators. They are 489 Status, Generator Status, and
Output Status.
808732A3.CDR
FIGURE 4–1: 489 LED Indicators
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
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CHAPTER 4: INTERFACES
489 Status LED Indicators
•
489 IN SERVICE: Indicates that control power is applied, all monitored input/output
and internal systems are OK, the 489 has been programmed, and is in protection
mode, not simulation mode. When in simulation or testing mode, the LED indicator will
flash.
•
SETPOINT ACCESS: Indicates that the access jumper is installed and passcode
protection has been satisfied. Setpoints may be altered and stored.
•
COMPUTER RS232: Flashes when there is any activity on the RS232 communications
port. Remains on continuously if incoming data is valid.
•
COMPUTER RS485 / AUXILIARY RS485: Flashes when there is any activity on the
computer/auxiliary RS485 communications port. These LEDs remain on continuously
if incoming data is valid and intended for the slave address programmed in the relay.
•
ALT. SETPOINTS: Flashes when the alternate setpoint group is being edited and the
primary setpoint group is active. Remains on continuously if the alternate setpoint
group is active. The alternate setpoint group feature is enabled as one of the
assignable digital inputs. The alternate setpoints group can be selected by setting the
S3 DIGITAL INPUTS ZV DUAL SETPOINTS ZV ACTIVATE SETPOINT GROUP setpoint to
“Group 2”.
•
RESET POSSIBLE: A trip or latched alarm may be reset. Pressing the RESET key clears
the trip/alarm.
•
MESSAGE: Under normal conditions, the default messages selected during setpoint
programming are displayed. If any alarm or trip condition is generated, 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 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.
Z To return to the diagnostic messages from the normally displayed
messages, press the MENU key until the following message is
displayed:
„
TARGET MESSAGES [w]
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.
Generator Status LED Indicators
4–2
•
BREAKER OPEN: Uses the breaker status input signal to indicate that the breaker is
open and the generator is offline.
•
BREAKER CLOSED: Uses the breaker status input signal to indicate that the breaker is
closed and the generator is online.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 4: INTERFACES
•
HOT STATOR: Indicates that the generator stator is above normal temperature when
one of the stator RTD alarm or trip elements is picked up or the thermal model trip
element is picked up.
•
NEG. SEQUENCE: Indicates that the negative sequence current alarm or trip element
is picked up.
•
GROUND: Indicates that at least one of the ground overcurrent, neutral overvoltage
(fundamental), or neutral undervoltage (3rd harmonic) alarm/trip elements is picked
up.
•
LOSS OF FIELD: Indicates that at least one of the reactive power (kvar) or field-breaker
discrepancy alarm/trip elements is picked up.
•
VT FAILURE: Indicates that the VT fuse failure alarm is picked up.
•
BREAKER FAILURE: Indicates that the breaker failure or trip coil monitor alarm is
picked up.
Output Status LED Indicators
4.1.3
•
1 TRIP: The 1 Trip relay has operated (energized).
•
2 AUXILIARY: The 2 Auxiliary relay has operated (energized).
•
3 AUXILIARY: The 3 Auxiliary relay has operated (energized).
•
4 AUXILIARY: The 4 Auxiliary relay has operated (energized).
•
5 ALARM: The 5 Alarm relay has operated (energized).
•
6 SERVICE: The 6 Service relay has operated (de-energized, 6 Service is fail-safe,
normally energized).
RS232 Program Port
This port is intended for connection to a portable PC. Setpoint files may be created at any
location and downloaded through this port with the EnerVista 489 Setup software. Local
interrogation of setpoint and actual values is also possible. New firmware may be
downloaded to the 489 flash memory through this port. Upgrading the relay firmware
does not require a hardware EEPROM change.
4.1.4
Keypad
Description
The 489 display messages are organized into main menus, pages, and sub-pages. There
are three main menus labeled Setpoints, Actual Values, and Target Messages.
Z Press the MENU key followed by the MESSAGE T key to scroll
through the three main menu headers, which appear in sequence as
follows:
SETPOINTS
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
[w ]
4–3
CHAPTER 4: INTERFACES
ACTUAL VALUES
[w ]
TARGET MESSAGES
[w ]
Z Press the MESSAGE X key or the ENTER key from these main menu
pages to display the corresponding menu page.
Use the MESSAGE T and MESSAGE S keys to scroll through the
page headers.
When the display shows SETPOINTS,
Z Press the MESSAGE X key or the ENTER key to display the page
headers of programmable parameters (referred to as setpoints in the
manual).
When the display shows ACTUAL VALUES,
Z Press the MESSAGE X key or the ENTER key to display the page
headers of measured parameters (referred to as actual values in the
manual).
When the display shows TARGET MESSAGES,
Z Press the MESSAGE X key or the ENTER key to display the page
headers of event messages or alarm conditions.
Each page is broken down further into logical sub-pages. The MESSAGE T and
MESSAGE S keys are used to navigate through the sub-pages. A summary of the setpoints
and actual values can be found in the chapters 5 and 6, 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 VALUE 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.
Z Press the HELP key to display 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.
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 coil
failure.
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489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
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The MESSAGE T and MESSAGE S 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.
Entering Alphanumeric Text
Text setpoints have data values that 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 decimal [.], VALUE, and ENTER keys.
Z Move to message S3 DIGITAL INPUTS ZV GENERAL INPUT A Z ASSIGN
DIGITAL INPUT, and scrolling with the VALUE keys, select “Input 1”.
The relay will display the following message:
ASSIGN DIGITAL
INPUT: Input 1
Z Press the MESSAGE T key to view the INPUT NAME setpoint.
The name of this user-defined input will be changed in this example
from the generic “Input A” to something more descriptive.
If an application is to be using the relay as a station monitor, it is more informative to
rename this input “Stn. Monitor”.
Z Press the decimal [.] to enter the text editing mode.
The first character will appear underlined as follows:
INPUT NAME:
Input A
Z Press the VALUE keys until the character “S” is displayed in the first
position.
Z Press the decimal [.] key to store the character and advance the
cursor to the next position.
Z Change the second character to a “t” in the same manner.
Z Continue entering characters in this way until all characters of the
text “Stn. Monitor” are entered.
Note that a space is selected like a character.
If a character is entered incorrectly, press the decimal [.] key
repeatedly until the cursor returns to the position of the error. Reenter the character as required.
Z Once complete, press the ENTER 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.
INPUT NAME:
Stn. Monitor
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The 489 does not have '+' or '–' keys. Negative numbers may be entered in one of two
manners.
•
•
Immediately pressing one of the VALUE keys causes the setpoint to
scroll through its range including any negative numbers.
After entering at least one digit of a numeric setpoint value, pressing the
VALUE keys changes the sign of the value where applicable.
4.1.5
Setpoint Entry
To store any setpoints, terminals C1 and C2 (access terminals) must be shorted (a
keyswitch may be used for security). There is also a setpoint passcode feature that restricts
access to setpoints. The passcode must be entered to allow the changing of setpoint
values. A passcode of “0” effectively turns off the passcode feature - in this case only the
access jumper is required for changing setpoints. If no key is pressed for 5 minutes, access
to setpoint values will be restricted until the passcode is entered again. To prevent setpoint
access before the 5 minutes expires, the unit may be turned off and back on, the access
jumper may be removed, or the SETPOINT ACCESS setpoint may be changed to “Restricted”.
The passcode cannot be entered until terminals C1 and C2 (access terminals) are shorted.
When setpoint access is allowed, the Setpoint Access LED indicator on the front of the 489
will be lit.
Setpoint changes take effect immediately, even when generator is running. However,
changing setpoints while the generator is running is not recommended as any mistake
may cause a nuisance trip.
The following procedure may be used to access and alter setpoints. This specific example
refers to entering a valid passcode to allow access to setpoints if the passcode was “489”.
Z Press the MENU key to access the header of each menu, which will
be displayed in the following sequence:
SETPOINTS
[w ]
ACTUAL VALUES
[w ]
TARGET MESSAGES
[w ]
Z Press the MENU key until the display shows the header of the
setpoints menu.
Z Press the MESSAGE X or ENTER key to display the header for the
first setpoints page.
The set point pages are numbered, have an 'S' prefix for easy
identification and have a name which gives a general idea of the
setpoints available in that page.
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Z Press the MESSAGE T or MESSAGE S keys to scroll through all the
available setpoint page headers.
Setpoint page headers look as follows:
„ SETPOINTS
S1 489 SETUP
[w]
To enter a given setpoints page,
Z Press the MESSAGE X or ENTER key.
Z Press the MESSAGE T or MESSAGE S keys to scroll through subpage headers until the required message is reached.
The end of a page is indicated by the message END OF PAGE. The
beginning of a page is indicated by the message TOP OF PAGE.
Each page is broken further into subgroups.
Z Press MESSAGE T or MESSAGE S to cycle through subgroups until
the desired subgroup appears on the screen.
Z Press the MESSAGE X or ENTER key to enter a subgroup.
„ PASSCODE
[w]
Each sub-group has one or more associated setpoint messages.
Z Press the MESSAGE T or MESSAGE S keys to scroll through setpoint
messages until the desired message appears.
ENTER PASSCODE
FOR ACCESS:
The majority of setpoints are changed by pressing the VALUE keys until the desired value
appears, and then pressing ENTER . Numeric setpoints may also be entered through the
numeric keys (including decimals). If the entered setpoint is out of range, the original
setpoint value reappears. If the entered setpoint is out of step, an adjusted value will be
stored (e.g. 101 for a setpoint that steps 95, 100, 105 is stored as 100). If a mistake is made
entering the new value, pressing ESCAPE returns the setpoint to its original value. Text
editing is a special case described in detail in Entering Alphanumeric Text on page 4–5.
Each time a new setpoint is successfully stored, a message will flash on the display stating
NEW SETPOINT HAS BEEN STORED.
Z Press the 4, 8, 9 keys, then press ENTER .
The following flash message is displayed:
NEW SETPOINT
HAS BEEN STORED
and the display returns to:
SETPOINT ACCESS:
PERMITTED
Z Press ESCAPE or MESSAGE W to exit the subgroup.
Pressing ESCAPE or MESSAGE W numerous times will always return
the cursor to the top of the page.
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4.1.6
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 TARGET MESSAGES, then press the
MESSAGE X key, followed by the MESSAGE T key, to scroll through the messages. For
additional information and a complete list of diagnostic messages, refer to Diagnostic
Messages on page 6–32.
4.1.7
Self-Test Warnings
The 489 relay performs self test diagnostics at initialization (after power up), and
continuously as a background task to ensure every testable unit of the hardware and
software is functioning correctly. There are two types of self-test warnings indicating either
a minor or major problem. Minor problems indicate a problem with the relay that does not
compromise protection. Major problems indicate a very serious relay problem which
comprises all aspects of relay operation.
Upon detection of either a minor or a major problem the relay will:
• De-energize the self-test warning relay
• Light the self-test warning LED
• Flash a diagnostic message periodically on the display screen
The 489 self-test warnings are shown below.
Table 4–1: Self-Test Warnings
Message
Severity
Major
This warning is caused by detection of a
corrupted 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.
Major
This warning is caused by a failure of the
analog to digital converter. The integrity of
system input measurements is affected by this
failure.
Major
This warning is caused by a failure of the
analog to digital converter. The integrity of
system input measurements is affected by this
failure.
Self-Test Warning 5
Replace Immediately
Major
This warning is caused by out of range reading
of self test RTD 13. The integrity of system
input measurements is affected by this failure.
Self-Test Warning 6
Replace Immediately
Major
This warning is caused by out of range reading
of self test RTD 14. The integrity of system
input measurements is affected by this failure.
Self-Test Warning 7
Replace Immediately
Major
This warning is caused by out of range reading
of self test RTD15. The integrity of system input
measurements is affected by this failure.
Self-Test Warning 1
Replace Immediately
Self-Test Warning 2
Replace Immediately
Self-Test Warning 3
Replace Immediately
4–8
Description
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Table 4–1: Self-Test Warnings
Message
Severity
Major
This warning is caused by out of range reading
of self test RTD16. The integrity of system input
measurements is affected by this failure.
Major
This message is displayed when 489 self
diagnostic detects ADC output values out of
operating range. The integrity of system input
measurements is affected by this failure.
Contact GE Multilin Technical Support.
Clock Not Set
Program Date/Time
Minor
Occurs if the clock has not been set.
Unit Temp. Exceeded
Service/CheckAmbient
Minor
Caused by the detection of unacceptably low
(less than –40°C) or high (greater than 85°C)
temperatures detected inside the unit.
Unit Not Calibrated
Replace Immediately
Minor
This warning occurs when the relay has not
been factory calibrated.
Relay Not Configured
Consult User Manual
Minor
This warning occurs when the 489 CT Primary
or Generator parameters are not set.
Service Required
Schedule Maintenance
Minor
This warning is caused by a failure of the Real
Time Clock circuit. The ability of the relay to
maintain the current date and time is lost.
Self-Test Warning 8
Replace Immediately
Self-Test Warning 9
Replace Immediately
4.1.8
Description
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 S1 RELAY SETUP ZV PREFERENCES ZV DEFAULT MESSAGE CYCLE TIME. The
factory default flash message time is 4 seconds. For additional information and a complete
list of flash messages, refer to Flash Messages on page 6–33.
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4.2
EnerVista Software Interface
4.2.1
Overview
The front panel provides local operator interface with a liquid crystal display. The EnerVista
489 Setup software provides a graphical user interface (GUI) as one of two human
interfaces to a 489 device. The alternate human interface is implemented via the device's
faceplate keypad and display (see the first section in this chapter).
The EnerVista 489 Setup software provides a single facility to configure, monitor, maintain,
and trouble-shoot the operation of relay functions, connected over serial communication
networks. It can be used while disconnected (i.e. off-line) or connected (i.e. on-line) to a 489
device. In off-line mode, setpoint 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 489 relay, can be run from any computer
supporting Microsoft Windows® 95 or higher. This chapter provides a summary of the
basic EnerVista 489 Setup software interface features. The EnerVista 489 Setup help file
provides details for getting started and using the software interface.
With the EnerVista 489 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
4.2.2
Hardware
Communications from the EnerVista 489 Setup to the 489 can be accomplished three
ways: RS232, RS485, and Ethernet (requires the MultiNet adapter) communications. The
following figures below illustrate typical connections for RS232 and RS485
communications. For additional details on Ethernet communications, please see the
MultiNet manual (GE Publication number GEK-106498).
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FIGURE 4–2: Communications using The Front RS232 Port
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FIGURE 4–3: Communications using Rear RS485 Port
4.2.3
Installing the EnerVista 489 Setup Software
The following minimum requirements must be met for the EnerVista 489 Setup software to
operate on your computer.
• Pentium class or higher processor (Pentium II 400 MHz or better recommended)
• Microsoft Windows 95, 98, 98SE, ME, NT 4.0 (SP4 or higher), 2000, XP
• Internet Explorer version 4.0 or higher (required libraries)
• 128 MB of RAM (256 MB recommended)
• Minimum of 200 MB hard disk space
A list of qualified modems for serial communications is shown below:
• US Robotics external 56K Faxmodem 5686
• US Robotics external Sportster 56K X2
• PCTEL 2304WT V.92 MDC internal modem
After ensuring these minimum requirements, use the following procedure to install the
EnerVista 489 Setup software from the enclosed GE EnerVista CD.
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Z Insert the GE EnerVista CD into your CD-ROM drive.
Z Click the Install Now button and follow the installation instructions
to install the no-charge EnerVista software on the local PC.
Z When installation is complete, start the EnerVista Launchpad
application.
Z Click the IED Setup section of the Launch Pad window.
Z In the EnerVista Launch Pad window, click the Add Product button
and select the “489 Generator Management Relay” from the Install
Software window as shown below.
Z Select the “Web” option to ensure the most recent software release,
or select “CD” if you do not have a web connection.
Z Click the Add Now button to list software items for the 489.
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EnerVista Launchpad will obtain the latest installation software from the Web or CD and
automatically start the installation process. A status window with a progress bar will be
shown during the downloading process.
Z Select the complete path, including the new directory name, where
the EnerVista 489 Setup software will be installed.
Z 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 489 Setup software to the Windows start menu.
Z Click Finish to end the installation.
The 489 device will be added to the list of installed IEDs in the
EnerVista Launchpad window, as shown below.
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4.3
Connecting EnerVista 489 Setup to the Relay
4.3.1
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 4–17.
Z Install and start the latest version of the EnerVista 489 Setup
software (available from the GE EnerVista CD).
See the previous section for the installation procedure.
Z Click on the Device Setup button to open the Device Setup window.
Z Click the Add Site button to define a new site.
Z 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 “Pumping Station 1” as the site name.
Z Click the OK button when complete.
The new site will appear in the upper-left list in the EnerVista 489 Setup window.
Z Click the Add Device button to define the new device.
Z Enter the desired name in the Device Name field and a description
(optional) of the site.
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Z Select “Serial” from the Interface drop-down list.
This will display a number of interface parameters that must be
entered for proper RS232 functionality.
Z Enter the slave address and COM port values (from the S1 489 SETUP
ZV COMMUNICATIONS menu) in the Slave Address and COM Port
fields.
Z Enter the physical communications parameters (baud rate and
parity setpoints) in their respective fields.
Note that when communicating to the relay from the front port, the
default communications setpoints are a baud rate of 9600, with
slave address of 1, no parity, 8 bits, and 1 stop bit. These values
cannot be changed.
Z Click the Read Order Code button to connect to the 489 device and
upload the order code.
If a communications error occurs, ensure that the 489 serial
communications values entered in the previous step correspond to
the relay setting values.
Z 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 489
Setup window.
The 489 Site Device has now been configured for serial communications. Proceed to
Connecting to the Relay on page 4–19 to begin communications.
4.3.2
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 489 relay.
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Z Press the Quick Connect button.
The following window will appear:
As indicated by the window, the Quick Connect feature quickly connects the EnerVista 489
Setup software to a 489 front port with the following setpoints: 9600 baud, no parity, 8 bits,
1 stop bit.
Z Select the PC communications port connected to the relay.
Z Press the Connect button.
The EnerVista 489 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.
The 489 Site Device has now been configured via the Quick Connect feature for serial
communications. Proceed to Connecting to the Relay on page 4–19 to begin
communications.
4.3.3
Configuring Ethernet Communications
Z Before starting, verify that the Ethernet cable is properly connected
to the RJ-45 Ethernet port.
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Z Install and start the latest version of the EnerVista 489 Setup
software (available from the GE EnerVista CD).
See the previous section for the installation procedure.
Z Click on the Device Setup button to open the Device Setup window.
Z Click the Add Site button to define a new site.
Z 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 “Pumping Station 2” as the site name.
Z Click the OK button when complete.
The new site will appear in the upper-left list.
Z Click the Add Device button to define the new device.
Z Enter the desired name in the Device Name field and a description
(optional).
Z Select “Ethernet” from the Interface drop-down list.
This will display a number of interface parameters that must be
entered for proper Ethernet functionality.
Z Enter the IP address assigned to the relay.
Z Enter the slave address and Modbus port values (from the S1 489
SETUP ZV COMMUNICATIONS menu) in the Slave Address and
Modbus Port fields.
Z Click the Read Order Code button to connect to the 489 device and
upload the order code.
If a communications error occurs, ensure that the 489 Ethernet
communications values entered in the previous step correspond to
the relay setting values.
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Z 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 489
Setup window.
The 489 Site Device has now been configured for Ethernet communications. Proceed to
the following section to begin communications.
4.3.4
Connecting to the Relay
Now that the communications parameters have been properly configured, the user can
easily connect to the relay.
Z Expand the Site list by double clicking on the site name or clicking on
the «+» box to list the available devices for the given site (for
example, in the “Pumping Station 1” site shown below).
Z Expand the desired device trees by clicking the «+» box.
The following list of headers is shown for each device:
•
Device Definitions
•
Setpoints
•
Actual Values
•
Commands
•
Communications
Z Expand the Setpoints > Protection > Current Elements list item and
select the Phase Overcurrent tab to open the Phase Overrcurrent
setpoint window as shown below:
Expand the Site List by doubleclicking or by selecting the [+] box
Communications Status Indicator
Green = OK, Red = No Comms
FIGURE 4–4: Main Window after Connection
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The Phase Overcurrent setpoint window will open with a corresponding status indicator on
the lower left of the EnerVista 489 Setup window.
Z If the status indicator is red, verify that the serial cable is properly
connected to the relay, and that the relay has been properly
configured for communications (steps described earlier).
Setpoints 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.
Note
4–20
Refer to the EnerVista 489 Setup help file for additional information about using the
software.
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4.4
Working with Setpoints and Setpoint Files
4.4.1
Engaging a Device
The EnerVista 489 Setup software may be used in on-line mode (relay connected) to
directly communicate with a 489 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.
4.4.2
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.
Z Establish communications with the relay.
Z Select the Setpoint > System Setup menu item.
This can be selected from the device setpoint tree or the main
window menu bar.
Z Select the Current Sensing menu item.
Z Select the PHASE CT PRIMARY setpoint by clicking anywhere in the
parameter box.
This will display three arrows: two to increment/decrement the value
and another to launch the numerical calculator.
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Z Click the arrow at the end of the box to display a numerical keypad
interface that allows the user to enter a value within the setpoint
range displayed near the top of the keypad:
Z Click Accept to exit from the keypad and keep the new value.
Z Click on Cancel to exit from the keypad and retain the old value.
For setpoints requiring non-numerical pre-set values (e.g. VT CONNECTION TYPE below, in
the Voltage Sensing window),
Z Click anywhere within the setpoint value box to display a drop-down
selection menu arrow.
Z Click on the arrow to select the desired setpoint.
For setpoints requiring an alphanumeric text string (e.g. message scratchpad messages),
the value may be entered directly within the setpoint value box.
Z In the Setpoint / System Setup dialog box, click on Save to save the
values into the 489.
Z Click Yes to accept any changes.
Z Click No, and then Restore to retain previous values and exit.
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4.4.3
Using Setpoint Files
Overview
The EnerVista 489 Setup software interface supports three ways of handling changes to
relay setpoints:
• In off-line mode (relay disconnected) to create or edit relay setpoint files for later
download to communicating relays.
• Directly modifying relay setpoints while connected to a communicating relay, then
saving the setpoints when complete.
• Creating/editing setpoint 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
• Digital Inputs
• Output Relays
• Voltage Elements
• Power Elements
• RTD Temperature
• Thermal Model
• Monitoring Functions
• Analog Inputs and Outputs
• Relay Testing
• User Memory Map Setting Tool
Factory default values are supplied and can be restored after any changes.
The EnerVista 489 Setup display relay setpoints with the same hierarchy as the front panel
display. For specific details on setpoints, refer to Chapter 5.
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 489 Setup window, setpoint files are accessed in the Setpoints List control
bar window or the Files window. Use the following procedure to download and save
setpoint files to a local PC.
Z Ensure that the site and corresponding device(s) have been properly
defined and configured as shown in Connecting EnerVista 489 Setup
to the Relay on page 4–15.
Z Select the desired device from the site list.
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Z Select the File > Read Settings from Device menu item to obtain
settings information from the device.
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.
Z 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.
Adding Setpoints Files to the Environment
The EnerVista 489 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.
Z In the files pane, right-click on ‘Files’
Z Select the Add Existing Setting File item as shown:
The Open dialog box will appear, prompting for a previously saved setting file. As for any
other Windows® application,
Z Browse for the file to add.
Z Click Open.
The new file and complete path will be added to the file list.
Creating a New Setpoint File
The EnerVista 489 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.
Z In the File pane, right click on ‘File’.
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Z Select the New Settings File item. The EnerVista 489 Setup software
displays the following box, 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.
Z Select the Firmware Version for the new setpoint file.
Z For future reference, enter some useful information in the
Description box to facilitate the identification of the device and the
purpose of the file.
Z To select a file name and path for the new file, click the button
beside the Enter File Name box.
Z Select the file name and path to store the file, or select any displayed
file name to update an existing file.
All 489 setpoint files should have the extension ‘489’ (for example,
‘motor1.489’).
Z 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 489 Setup software environment.
Upgrading Setpoint Files to a New Revision
It is often necessary to upgrade the revision code for a previously saved setpoint file after
the 489 firmware has been upgraded (for example, this is required for firmware upgrades).
This is illustrated in the following procedure.
Z Establish communications with the 489 relay.
Z Select the Actual > Product Information menu item and record the
Software Revision identifier of the relay firmware as shown below.
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Z Load the setpoint file to be upgraded into the EnerVista 489 Setup
environment as described in Adding Setpoints Files to the
Environment on page 4–24.
Z In the File pane, select the saved setpoint file.
Z From the main window menu bar, select the File > Properties menu
item and note the version code of the setpoint file.
If this version (e.g. 4.0X 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 software revision is 3.00 and the current setpoint file revision is
1.50, change the setpoint file revision to “3.0X”, as shown below.
Enter any special comments
about the setpoint file here.
Select the desired setpoint version
from this menu. The 3.0x indicates
versions 3.00, 3.01, 3.02, etc.
Z 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 4–28 for instructions on loading this setpoint file into the
489.
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Printing Setpoints and Actual Values
The EnerVista 489 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:
Z Select a previously saved setpoints file in the File pane or establish
communications with a 489 device.
Z From the main window, select the File > Print Settings menu item.
The Print/Export Options dialog box will appear.
Z Select Settings in the upper section.
Z 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.
Z Click OK.
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:
Z Establish communications with the desired 489 device.
Z From the main window, select the File > Print Settings menu item.
The Print/Export Options dialog box will appear.
Z Select Actual Values in the upper section.
Z 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.
Z Click OK.
Actual values 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.
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CHAPTER 4: INTERFACES
Loading Setpoints from a File
An error message will occur when attempting to download a setpoint file 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 4–25 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
setpoint file, it must first be added to the EnerVista 489 Setup environment as described in
Adding Setpoints Files to the Environment on page 4–24.
Z Select the previously saved setpoint file from the File pane of the
EnerVista 489 Setup software main window.
Z 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 4–25 for details on changing the setpoints file
version.
Z Right-click on the selected file.
Z Select the Write Settings to Device item.
The software will prompt for a target device.
Z Select the desired device.
Z Click Send.
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489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
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If there is an incompatibility, an error of the following type will occur.
If there are no incompatibilities between the target device and the Setpoints file, the data
will be transferred to the relay. An indication of the percentage completed will be shown in
the bottom of the main menu.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
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CHAPTER 4: INTERFACES
4.5
Upgrading Relay Firmware
4.5.1
Description
To upgrade the 489 firmware, follow the procedures listed in this section. Upon successful
completion of this procedure, the 489 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.
4.5.2
Saving Setpoints to a File
Before upgrading firmware, it is very important to save the current 489 settings to a file on
your PC. After the firmware has been upgraded, it will be necessary to load this file back
into the 489.
Refer to Downloading and Saving Setpoints Files on page 4–23 for details on saving relay
setpoints to a file.
4.5.3
Loading New Firmware
Loading new firmware into the 489 flash memory is accomplished as follows:
Z Connect the relay to the local PC and save the setpoints to a file as
shown in Downloading and Saving Setpoints Files on page 4–23.
Z Select the Communications > Update Firmware menu item.
The following warning message will appear.
Z Select Yes to proceed or No to cancel the process.
Do not proceed unless you have saved the current setpoints
An additional message will be displayed to ensure the PC is connected to the relay front
port, as the 489 cannot be upgraded via the rear RS485 ports.
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The EnerVista 489 Setup software will request the new firmware file. Locate the file to load
into the 489. The firmware filename has the following format:
32 J 300 A8 . 000
Modification Number (000 = none)
GE Multilin use only
Firmware version
Required 489 hardware revision
Product code (32 = 489)
FIGURE 4–5: Firmware File Format
The EnerVista 489 Setup software automatically lists all filenames beginning with ‘32’.
Z Select the appropriate file.
Z Click OK to continue.
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.
Z Click Yes to continue or No to cancel the upgrade.
The EnerVista 489 Setup software now prepares the 489 to receive the new firmware file.
The 489 will display a message indicating that it is in Upload Mode. While the file is being
loaded into the 489, 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.
The EnerVista 489 Setup software will notify the user when the 489 has finished loading
the file.
Z Carefully read any displayed messages and click OK to return the
main screen.
Note
Cycling power to the relay is recommended after a firmware upgrade.
After successfully updating the 489 firmware, the relay will not be in service and will
require setpoint programming. To communicate with the relay, the following settings will
have to be manually programmed.
MODBUS COMMUNICATION ADDRESS
BAUD RATE
PARITY (if applicable)
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CHAPTER 4: INTERFACES
When communications is established, the saved setpoints must be reloaded back into the
relay. See Loading Setpoints from a File on page 4–28 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 existing features are
enhanced or modified. The EEPROM DATA ERROR message displayed after 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.
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4.6
Advanced EnerVista 489 Setup Features
4.6.1
Triggered Events
While the interface is in either on-line or off-line mode, data generated by triggered
specified parameters can be viewed and analyzed via one of the following:
• Event Recorder: The event recorder captures contextual data associated with the
last 256 events, listed in chronological order from most recent to the oldest.
• Oscillography: The oscillography waveform traces provide a visual display of
power system and relay operation data captured during specific triggered events.
4.6.2
Waveform Capture (Trace Memory)
The EnerVista 489 Setup software can be used to capture waveforms (or view trace
memory) from the 489 relay at the instance of a trip. A maximum of 128 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 (Ia, Ib, and Ic)
• Neutral end A, B, and C currents (Ineutral_a, Ineutral_b, and Ineutral_c)
• Ground currents (Ig)
• Phase A-N, B-N, and C-N voltages (Va, Vb, and Vc)
Z With EnerVista 489 Setup running and communications established,
select the Actual > Waveform Capture menu item to open the
waveform capture setup window:
Number of available files
Files to be saved or viewed
Save waveform to a file
Z Click on Trigger Waveform to trigger a waveform capture.
The waveform file numbering starts with the number zero in the 489; therefore, the
maximum trigger number will always be one less then the total number triggers
available.
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CHAPTER 4: INTERFACES
Z 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 CSV (comma delimited values) file, which can be viewed and
manipulated with compatible third-party software.
To view a previously saved file,
Z Click the Open button and select the corresponding CSV file.
To view the captured waveforms,
Z Click the Launch Viewer button.
A detailed Waveform Capture window will appear as shown below:
TRIGGER TIME & DATE
Display the time & date of the
Trigger
Display graph values
at the corresponding
cursor line. Cursor
lines are identified by
their colors.
VECTOR DISPLAY SELECT
Click here to open a new graph
to display vectors
FILE NAME
Indicates the
file name and
complete path
(if saved)
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
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
The red vertical line indicates the trigger point of the relay.
The date and time of the trigger is displayed at the top left corner of the window. To match
the captured waveform with the event that triggered it,
Z Make note of the time and date shown in the graph.
Z Find the event that matches the same time and date in the event
recorder.
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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 4–40.
Z From the window main menu bar, press the Preference button to
open the Setup page to change the graph attributes.
Preference button
The following window will appear:
Z Change the Color of each graph as desired, and select other options,
as required, by checking the appropriate boxes.
Z Click OK to store these graph attributes, and to close the window.
The Waveform Capture window will reappear with the selected graph attributes available
for use.
4.6.3
Phasors
The EnerVista 489 Setup software can be used to view the phasor diagram of three-phase
currents and voltages. The phasors are for: Phase Voltages Va, Vb, and Vc; Phase Currents
Ia, Ib, and Ic.
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CHAPTER 4: INTERFACES
Z With the EnerVista 489 Setup software running and communications
established, open the Actual Values > Metering Data window.
Z Click on the Phasors tab.
The EnerVista 489 Setup software will display the following window:
Z Press the “View” button to display the following window:
VOLTAGE LEVEL
Displays the value
and the angle of
the voltage phasors
CURRENT LEVEL
Displays the value
and angle of the
current phasor
VOLTAGE VECTORS
Assigned to Phasor
Set 1, Graph 1
CURRENT VECTORS
Assigned to Phasor
Set 2, Graph 2
The 489 Generator Management Relay was designed to display lagging angles. Therefore,
if a system condition would cause the current to lead the voltage by 45°, the 489 relay will
display such angle as 315° Lag instead of 45° Lead.
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489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
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When the currents and voltages measured by the relay are zero, the angles displayed by
the relay and those shown by the EnerVista 489 Setup software are not fixed values.
4.6.4
Trending (Data Logger)
The trending or data logger feature is used to sample and record up to eight actual values
at an interval defined by the user. Several parameters can be trended and graphed at
sampling periods ranging from 1 second up to 1 hour. The parameters which can be
trended by the EnerVista 489 Setup software are:
• Currents/Voltages:
Phase Currents A, B, and C
Generator Load
Negative-Sequence Current
Ground Current and Neutral Current
Differential Currents A, B, and C
System Frequency
Voltages Vab, Vbc, Vca Van, Vbn & Vcn
• Power:
Power Factor
Real (kW) Reactive (kvar), and Apparent (kVA) Power
Positive Watthours
Positive and Negative Varhours
• Temperature:
Hottest Stator RTD
Thermal Capacity Used
RTDs 1 through 12
• Demand:
Current
Peak Current
Reactive Power
Peak Reactive Power
Apparent Power
Peak Apparent Power
• Others:
Analog Inputs 1, 2, 3, and 4
Tachometer
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CHAPTER 4: INTERFACES
With EnerVista 489 Setup running and communications established,
Z Select the Actual Values > Trending menu item to open the trending
window.
The following window will appear.
To prepare for new trending,
Z Select Stop to stop the data logger and Reset to clear the screen.
Z Select the graphs to be displayed through the pull-down menu
beside each channel description.
Z Select the Sample Rate through the pull-down menu.
If you want to save the information captured by trending,
Z Check the box besides Log Samples to File.
The following dialog box will appear requesting for file name and
path. The file is saved as 'csv' (comma delimited values) file, which
can be viewed and manipulated with compatible third-party
software.
Z Ensure that the sample rate is not less than 5 seconds, otherwise,
some data may not get written to the file.
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To limit the size of the saved file,
Z Enter a number in the Limit File Capacity To box.
The minimum number of samples is 1000. At a sampling rate of 5
seconds (or 1 sample every 5 seconds), the file will contain data
collected during the past 5000 seconds. The EnerVista 489 Setup
software will automatically estimate the size of the trending file.
Z Press “Run” to start the data logger.
If the Log Samples to File item is selected, the EnerVista 489 Setup
software will begin collecting data at the selected sampling rate and
will display it on the screen. The data log will continue until the Stop
button is pressed or until the selected number of samples is reached,
whichever occurs first.
During the process of data logging, the trending screen appears as shown below.
SAVE DATA TO FILE
Select to save the
information to a CSV
file on the PC
GRAPH CHANNEL
Select the desired
channel to be captured
from the pull-down menu
BUTTONS
Zoom In enlarges the graph
Zoom Out shrinks the graph
Reset clears the screen
Run/Stop starts and stops
the data logger
MODE SELECT
Select to view Cursor 1,
Cursor 2, or the Delta
(difference) values for
the graph
LEVEL
Displays the value
at the active
cursor line
CURSOR LINES
Click and drag the
cursor lines with
the left mouse
button
WAVEFORM
The trended data
from the 469 relay
FIGURE 4–7: Trending Screen
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
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CHAPTER 4: INTERFACES
4.6.5
Event Recorder
The 489 event recorder can be viewed through the EnerVista 489 Setup software. The
event recorder stores generator and system information each time an event occurs (e.g.
breaker failure). A maximum of 256 events can be stored. Each event is assigned an event
number, from E001 to E256. When the E256 is reached, E001 is assigned to the next event.
Refer to Event Recorder on page 6–28 for additional information on the event recorder.
Use the following procedure to view the event recorder with EnerVista 489 Setup:
With EnerVista 489 Setup running and communications established,
Z 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.
EVENT LISTING
Lists the last 256
events with the most
recent displayed at
top of list.
DEVICE ID
The events shown
here correspond to
the device shown.
EVENT SELECTION
Select an event row to view
event data information,
which will be displayed in
the window to the right.
EVENT DATA
System information as
measured by the relay at
the instant of the event
occurrence.
EVENT NUMBER
The event data
information is related
to the selected event,
as shown.
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.
FIGURE 4–8: Event Recorder Window (shown unconnected)
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489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
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To view detailed information for a given event and the system information at the moment
of the event occurrence,
Z Change the event number on the Select Event box.
4.6.6
Modbus User Map
The EnerVista 489 Setup software provides a means to program the 489 User Map
(Modbus addresses 0180h to 01F7h). Refer to GE Publication GEK-106491: 489
Communications Guide for additional information on the User Map.
Z Select a connected device in EnerVista 489 Setup.
Z Select the Setpoint > User Map menu item to open the following
window.
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.
4.6.7
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 with the following list:
1.
Generator and System Status:
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CHAPTER 4: INTERFACES
• Generator status either stopped, starting, or running. It includes values such as
generator load, thermal capacity used, generator speed, and instantaneous values
of power system quantities.
• The status of digital inputs.
• Last trip information, including values such as cause of last trip, time and date of
trip, generator speed and load at the time of trip, pre-trip temperature
measurements, pre-trip analog inputs values, and pre-trip instantaneous values of
power system quantities.
• Active alarms.
• Relay date and time.
• Present blocking conditions.
• General system status indication including the status of output relays, active
pickup, alarm and trip conditions.
2.
Metering Data:
• Instantaneous current measurements including phase, differential, unbalance,
ground, average, generator load, and differential currents.
• RTD Temperatures including hottest RTDs.
• Instantaneous phase to phase and phase to ground voltages (depending on the VT
connections), average voltage, and system frequency.
• Generator Speed
• Power Quantities including Apparent, Real and Reactive Power.
• Current and power demand including peak values.
• Analog inputs
• Vector information.
3.
Generator Learned Data:
• Average Generator Load
• Average Negative-Sequence Current
• Phase-Phase Voltage
• RTD Maximum Values
4.
Maintenance data.
This is useful statistical information that may be used for preventive maintenance. It
includes:
• Trip counters
• General counter such as Number of Breaker Operations.
• Timers such as Generator Running Hours.
4–42
5.
RTD Learned Data - includes the maximum temperature measured by each of the 12
RTDs.
6.
Event recorder downloading tool.
7.
Product information including model number, firmware version, additional product
information, and calibration dates.
8.
Oscillography and Data Logger downloading tool.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 4: INTERFACES
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 generator status values tiled in the
same window):
FIGURE 4–9: Actual Values Display (shown unconnected)
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
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CHAPTER 4: INTERFACES
4.7
Using EnerVista Viewpoint with the 489
4.7.1
Plug and Play Example
EnerVista Viewpoint is an optional software package that puts critical 489 information on
any PC with plug-and-play simplicity. EnerVista Viewpoint connects instantly to the 489 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.
Z Install the EnerVista Viewpoint software from the GE EnerVista CD.
Z Ensure that the 489 device has been properly configured for either
serial or Ethernet communications (see previous sections for details).
Z 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.
FIGURE 4–10: EnerVista Viewpoint Main Window
Z Click the Device Setup button to open the Device Setup window.
Z Click the Add Site button to define a new site.
Z 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.
Z Click the OK button when complete.
The new site will appear in the upper-left list in the EnerVista 489
Setup window.
Z Click the Add Device button to define the new device.
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Z Enter the desired name in the Device Name field and a description
(optional) of the site.
Z Select the appropriate communications interface (Ethernet or Serial)
and fill in the required information for the 489. See Connecting
EnerVista 489 Setup to the Relay on page 4–15 for details.
FIGURE 4–11: Device Setup Screen (Example)
Z Click the Read Order Code button to connect to the 489 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.
Z Click OK when complete.
Z From the EnerVista main window, select the IED Dashboard item to
open the Plug and Play IED dashboard.
An icon for the 489 will be displayed.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
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CHAPTER 4: INTERFACES
FIGURE 4–12: ‘Plug and Play’ Dashboard
Z Click the Dashboard button below the 489 icon to view the device
information.
We have now successfully accessed our 489 through EnerVista Viewpoint.
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489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
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FIGURE 4–13: EnerVista Plug and Play Screens
For additional information on EnerVista viewpoint, please visit the EnerVista website at
http://www.EnerVista.com.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
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CHAPTER 4: INTERFACES
4–48
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
Digital Energy
Multilin
489 Generator Management Relay
Chapter 5: Setpoints
Setpoints
5.1
Overview
5.1.1
Setpoint Message Map
The 489 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. S2 SYSTEM SETUP) has a section which describes
in detail all the setpoints found on that page.
„
SETPOINTS
„
PASSCODE
[Z]
[Z]
MESSAGE
„
PREFERENCES
[Z]
MESSAGE
„
COMMUNICATIONS
[Z]
MESSAGE
„ REAL TIME
CLOCK
MESSAGE
„
DEFAULT
[Z]
MESSAGE
„
MESSAGE
[Z]
MESSAGE
[Z]
„ CLEAR DATA
MESSAGE
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
[Z]
See page 5–9.
See page 5–10.
See page 5–12.
See page 5–13.
See page 5–14.
See page 5–15.
See page 5–16.
END OF PAGE
5–1
CHAPTER 5: SETPOINTS
„
SETPOINTS
„
CURRENT
[Z]
MESSAGE
„
VOLTAGE
[Z]
MESSAGE
„
GENERATOR
[Z]
MESSAGE
„
SERIAL
[Z]
[Z]
„
BREAKER
[Z]
MESSAGE
„
GENERAL
[Z]
MESSAGE
„
GENERAL
[Z]
[Z]
See page 5–18.
See page 5–19.
See page 5–20.
END OF PAGE
MESSAGE
„
SETPOINTS
See page 5–18.
See page 5–21.
See page 5–22.
See page 5–22.
↓
MESSAGE
MESSAGE
MESSAGE
MESSAGE
[Z]
„ REMOTE RESET
[Z]
„ TEST INPUT
[Z]
„ THERMAL RESET
[Z]
MESSAGE
„
DUAL
[Z]
MESSAGE
„
SEQUENTIAL
[Z]
MESSAGE
„ FIELDBREAKER
MESSAGE
„
TACHOMETER
[Z]
MESSAGE
„
WAVEFORM
[Z]
MESSAGE
„
GROUND
[Z]
MESSAGE
5–2
„
GENERAL
See page 5–22.
See page 5–23.
See page 5–23.
See page 5–23.
See page 5–24.
See page 5–25.
See page 5–26.
[Z]
See page 5–26.
See page 5–27.
See page 5–27.
END OF PAGE
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
„
SETPOINTS
[Z]
MESSAGE
1 SETPOINTS
[Z]
S5 CURRENT ELEM.
„
RELAY
[Z]
END OF PAGE
1 OVERCURRENT
ALARM
[Z]
MESSAGE
1 OFFLINE
OVERCURRENT
[Z]
MESSAGE
1 INADVERTENT
ENERGIZATION
[Z]
MESSAGE
1 PHASE
OVERCURRENT
[Z]
MESSAGE
1 NEGATIVE
SEQUENCE
[Z]
MESSAGE
1 GROUND
OVERCURRENT
[Z]
MESSAGE
1 PHASE
DIFFERENTIAL
[Z]
MESSAGE
1 GROUND
DIRECTIONAL
[Z]
MESSAGE
1 HIGH-SET
[Z]
PHASE OVERCURRENT
MESSAGE
MESSAGE
MESSAGE
MESSAGE
MESSAGE
MESSAGE
See page 5–33.
See page 5–33.
See page 5–34.
See page 5–35.
See page 5–36.
See page 5–38.
See page 5–39.
See page 5–40.
See page 5–42.
END OF PAGE
MESSAGE
1 SETPOINTS
[Z]
S6 VOLTAGE ELEM.
See page 5–28.
1 UNDERVOLTAGE
[Z]
1 OVERVOLTAGE
[Z]
1 VOLTS/HERTZ
[Z]
1 PHASE
REVERSAL
[Z]
1 UNDERFREQUENCY
[Z]
1 OVERFREQUENCY
[Z]
1 NEUTRAL O/V
(FUNDAMENTAL)
[Z]
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
See page 5–43.
See page 5–44.
See page 5–45.
See page 5–48.
See page 5–49.
See page 5–50.
See page 5–51.
5–3
CHAPTER 5: SETPOINTS
MESSAGE
1 NEUTRAL U/V
(3rd HARMONIC)
[Z]
MESSAGE
1 LOSS OF
EXCITATION
[Z]
MESSAGE
1 DISTANCE
ELEMENT
[Z]
1 REACTIVE
POWER
[Z]
MESSAGE
1 REVERSE
POWER
[Z]
MESSAGE
1 LOW FORWARD
POWER
[Z]
MESSAGE
MESSAGE
MESSAGE
See page 5–56.
See page 5–61.
See page 5–62.
See page 5–63.
END OF PAGE
MESSAGE
1 SETPOINTS
[Z]
S8 RTD TEMPERATURE
See page 5–55.
END OF PAGE
MESSAGE
1 SETPOINTS
[Z]
S7 POWER ELEMENTS
See page 5–53.
1 RTD TYPES
[Z]
1 RTD #1
[Z]
1 RTD #2
[Z]
1 RTD #3
[Z]
See page 5–64.
See page 5–65.
See page 5–65.
See page 5–65.
↓
1 RTD #12
[Z]
MESSAGE
1 OPEN RTD
SENSOR
[Z]
MESSAGE
1 RTD
SHORT/LOW TEMP
[Z]
MESSAGE
MESSAGE
1 SETPOINTS
[Z]
S9 THERMAL MODEL
MESSAGE
5–4
See page 5–67.
See page 5–68.
See page 5–69.
END OF PAGE
1 MODEL SETUP
[Z]
1 THERMAL
ELEMENTS
[Z]
See page 5–71.
See page 5–89.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
END OF PAGE
MESSAGE
„
SETPOINTS
„
TRIP
[Z]
MESSAGE
„
BREAKER
[Z]
MESSAGE
„ TRIP COIL
MONITOR
[Z]
MESSAGE
„ VT FUSE
FAILURE
[Z]
MESSAGE
„
CURRENT
[Z]
MESSAGE
MESSAGE
MESSAGE
„ MW DEMAND
[Z]
„ Mvar DEMAND
[Z]
„ MVA DEMAND
[Z]
MESSAGE
„
PULSE
[Z]
MESSAGE
„
RUNNING
[Z]
„
ANALOG
[Z]
MESSAGE
„
ANALOG
[Z]
MESSAGE
„
ANALOG
[Z]
MESSAGE
„
ANALOG
[Z]
MESSAGE
„
ANALOG
[Z]
MESSAGE
„
ANALOG
[Z]
MESSAGE
„
ANALOG
[Z]
[Z]
See page 5–90.
See page 5–91.
See page 5–92.
See page 5–93.
See page 5–93.
See page 5–93.
See page 5–93.
See page 5–94.
See page 5–95.
END OF PAGE
MESSAGE
„
SETPOINTS
[Z]
See page 5–90.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
See page 5–96.
See page 5–96.
See page 5–96.
See page 5–96.
See page 5–98.
See page 5–98.
See page 5–98.
5–5
CHAPTER 5: SETPOINTS
MESSAGE
„
ANALOG
[Z]
„
SIMULATION
[Z]
MESSAGE
„ PREFAULT
MESSAGE
„
FAULT
[Z]
MESSAGE
„
TEST
[Z]
MESSAGE
„
TEST
[Z]
MESSAGE
„
COMMUNICATION
[Z]
MESSAGE
„
FACTORY
[Z]
MESSAGE
5.1.2
See page 5–98.
END OF PAGE
MESSAGE
„
SETPOINTS
[Z]
See page 5–100.
See page 5–101.
[Z]
See page 5–102.
See page 5–102.
See page 5–103.
See page 5–104.
See page 5–104.
END OF PAGE
Trips / Alarms/ Control Features
The 489 Generator Management Relay has three basic function categories: TRIPS, ALARMS,
and CONTROL.
Trips
A 489 trip feature may be assigned to any combination of the four output relays: 1 Trip,
2 Auxiliary, 3 Auxiliary, and 4 Auxiliary. If a Trip becomes active, the appropriate LED
(indicator) on the 489 faceplate illuminates to indicate which output relay has operated.
Each trip feature may be programmed as latched or unlatched. Once a latched trip feature
becomes active, the RESET key must be pressed to reset that trip. If the condition that
caused the trip is still present (for example, hot RTD) the trip relay(s) will not reset until the
condition disappears. On the other hand, if an unlatched trip feature becomes active, that
trip resets itself (and associated output relay(s)) after the condition that caused the trip
ceases and the Breaker Status input indicates that the breaker is open. If there is a lockout
time, the trip relay(s) will not reset until the lockout time has expired. Immediately prior to
issuing a trip, the 489 takes a snapshot of generator parameters and stores them as pretrip values, allowing for troubleshooting after the trip. The cause of last trip message is
updated with the current trip and the 489 display defaults to that message. All trip features
are automatically logged and date and time stamped as they occur. In addition, all trips
are counted and logged as statistics such that any long term trends may be identified.
5–6
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
Note that a lockout time will occur due to overload trip (see Model Setup on page 5–71 for
additional details).
Alarms
A 489 alarm feature may be assigned to operate any combination of four output relays:
2 Auxiliary, 3 Auxiliary, 4 Auxiliary, and 5 Alarm. When an alarm becomes active, the
appropriate LED (indicator) on the 489 faceplate will illuminate when an output relay(s) has
operated. Each alarm feature may be programmed as latched or unlatched. Once a
latched alarm feature becomes active, the reset key must be pressed to reset that alarm. If
the condition that has caused the alarm is still present (for example, hot RTD) the Alarm
relay(s) will not reset until the condition is no longer present. If on the other hand, an
unlatched alarm feature becomes active, that alarm will reset itself (and associated output
relay(s)) as soon as the condition that caused the alarm ceases. As soon as an alarm
occurs, the alarms messages are updated to reflect the alarm and the 489 display defaults
to that message. Since it may not be desirable to log all alarms as events, each alarm
feature may be programmed to log as an event or not. If an alarm is programmed to log as
an event, when it becomes active, it is automatically logged as a date and time stamped
event.
Control
A 489 control feature may be assigned to operate any combination of five output relays:
1 Trip, 2 Auxiliary, 3 Auxiliary, 4 Auxiliary, and 5 Alarm. The combination of relays available
for each function is determined by the suitability of each relay for that particular function.
The appropriate LED (indicator) on the 489 faceplate will illuminate when an output relay(s)
has been operated by a control function. Since it may not be desirable to log all control
function as events, each control feature may be programmed to log as an event or not. If a
control feature is programmed to log as an event, each control relay event is automatically
logged with a date and time stamp.
5.1.3
Relay Assignment Practices
There are six output relays. Five of the relays are always non-failsafe, the other (Service) is
failsafe and dedicated to annunciate internal 489 faults (these faults include setpoint
corruption, failed hardware components, loss of control power, etc.). The five remaining
relays may be programmed for different types of features depending on what is required.
One of the relays, 1 Trip, is intended to be used as a trip relay wired to the unit trip breaker.
Another relay, 5 Alarm, is intended to be used as the main alarm relay. The three remaining
relays, 2 Auxiliary, 3 Auxiliary, and 4 Auxiliary, are intended for special requirements.
When assigning features to relays 2, 3, and 4, it is a good idea to decide early on what is
required since features that may be assigned may conflict. For example, if relay 2 is to be
dedicated as a relay for sequential tripping, it cannot also be used to annunciate a specific
alarm condition.
In order to ensure that conflicts in relay assignments do not occur, several precautions
have been taken. All trips default to the 1 Trip output relay and all alarms default to the
5 Alarm relay. It is recommended that relay assignments be reviewed once all the setpoints
have been programmed.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
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CHAPTER 5: SETPOINTS
5.1.4
Dual Setpoints
The 489 has dual settings for the current, voltage, power, RTD, and thermal model
protection elements (setpoints pages S5 to S9). These setpoints are organized in two
groups: the main group (Group 1) and the alternate group (Group 2). Only one group of
settings is active in the protection scheme at a time. The active group can be selected
using the ACTIVATE SETPOINT GROUP setpoint or an assigned digital input in the S3 Digital
Inputs setpoints page. The LED indicator on the faceplate of the 489 will indicate when the
alternate setpoints are active in the protection scheme. Independently, the setpoints in
either group can be viewed and/or edited using the EDIT SETPOINT GROUP setpoint.
Headers for each setpoint message subgroup that has dual settings will be denoted by a
superscript number indicating which setpoint group is being viewed or edited. Also, when a
setpoint that has dual settings is stored, the flash message that appears will indicate
which setpoint group setting has been changed.
If only one setting group is required, edit and activate only Group 1 (that is, do not assign a
digital input to Dual Setpoints, and do not alter the ACTIVATE SETPOINT GROUP setpoint or
EDIT SETPOINT GROUP setpoint in S3 DIGITAL INPUTS).
5.1.5
Commissioning
Tables for recording of 489 programmed setpoints are available as a Microsoft Word
document from the GE Multilin website at http://www.GEmultilin.com. See the Support
Documents section of the 489 Generator Management Relay page for the latest version.
This document is also available in print from the GE Multilin literature department (request
publication number GET-8445).
5–8
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
5.2
S1 489 Setup
5.2.1
Passcode
PATH: SETPOINTS Z S1 489 SETUP Z PASSCODE
„
PASSCODE
ENTER PASSCODE FOR
ACCESS:
Range: 1 to 8 numeric digits
MESSAGE
SETPOINT ACCESS:
Permitted
Range: Permitted, Restricted
MESSAGE
CHANGE PASSCODE:
No
Range: No, Yes
[Z]
A passcode access security feature is provided with the 489. The passcode is defaulted to
“0” (without the quotes) at the time of shipping. Passcode protection is ignored when the
passcode is “0”. In this case, the setpoint access jumper is the only protection when
programming setpoints from the front panel keypad and setpoints may be altered using
the RS232 and RS485 serial ports without access protection. If however, the passcode is
changed to a non-zero value, passcode protection is enabled. The access jumper must be
installed and the passcode must be entered, to program setpoints from the front panel
keypad. The passcode must also be entered individually from each serial communications
port to gain setpoint programming access from that port.
The ENTER PASSCODE FOR ACCESS setpoint is seen only if the passcode is not 0 and
SETPOINT ACCESS is “Restricted”. The SETPOINT ACCESS and CHANGE PASSWORD setpoints
are seen only if the passcode is 0 and the SETPOINT ACCESS is “Permitted”.
To enable passcode protection on a new relay, follow the procedure below:
Z Press ENTER then MESSAGE DOWN until CHANGE PASSCODE
message is displayed.
Z Select Yes and follow directions to enter a new passcode 1 to 8 digits
in length.
Once a new passcode (other than “0”) is programmed, it must be entered to gain setpoint
access whenever setpoint access is restricted. Assuming that a non-zero passcode has
been programmed and setpoint access is restricted, then selecting the passcode subgroup
causes the ENTER PASSCODE AGAIN message to appear.
Z Enter the correct passcode. A flash message will advise if the code is
incorrect and allow a retry. If it is correct and the setpoint access
jumper is installed, the SETPOINT ACCESS: Permitted message
appears.
Setpoints can now be entered.
Z Exit the passcode message with the ESCAPE key and program the
appropriate setpoints.
If no keypress occurs for 30 minutes, access will be disabled and the
passcode must be re-entered. Removing the setpoint access jumper
or setting SETPOINT ACCESS to Restricted also disables setpoint
access immediately.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
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CHAPTER 5: SETPOINTS
If a new passcode is required, gain setpoint access as follows:
Z Enter the current valid passcode.
Z Press MESSAGE DOWN to display the CHANGE PASSCODE
message and follow the directions.
If an invalid passcode is entered, the encrypted passcode is viewable
by pressing HELP.
Z Consult GE Multilin with this number if the currently programmed
passcode is unknown. The passcode can be determined with
deciphering software.
5.2.2
Preferences
PATH: SETPOINTS Z S1 489 SETUP ZV PREFERENCES
„
PREFERENCES
DEFAULT MESSAGE
CYCLE TIME: 2.0 s
Range: 0.5 to 10.0 s in steps of 1
MESSAGE
DEFAULT MESSAGE
TIMEOUT: 300 s
Range: 10 to 900 s in steps of 1
MESSAGE
PARAMETER AVERAGES
CALC. PERIOD: 15 min
Range: 1 to 90 min. in steps of 1
MESSAGE
TEMPERATURE DISPLAY:
Celsius
Range: Celsius, Fahrenheit
MESSAGE
WAVEFORM TRIGGER
POSITION: 25%
Range: 1 to 100% in steps of 1
MESSAGE
WAVEFORM MEM BUFFER
8x14 cycles
Range: 1x64, 2x42, 3x32, 4x35, 5x21,
6x18, 7x16, 8x14, 9x12, 10x11,
11x10, 12x9, 13x9, 14x8, 15x8,
16x7 cycles
[Z]
Some of the 489 characteristics can be modified to suit different situations. Normally the
S1 489 SETUP ZV PREFERENCES setpoints group will not require any changes.
5–10
•
DEFAULT MESSAGE CYCLE TIME: If multiple default messages are chosen, the display
automatically cycles through these messages. The messages display time can be
changed to accommodate different reading rates.
•
DEFAULT MESSAGE TIMEOUT: If no keys are pressed for a period of time then the relay
automatically scans through a programmed set of default messages. This time can be
modified to ensure messages remain on the screen long enough during programming
or reading of actual values.
•
PARAMETER AVERAGES CALCULATION PERIOD: The period of time over which the
parameter averages are calculated may be adjusted with this setpoint. The
calculation is a sliding window.
•
TEMPERATURE DISPLAY: Measurements of temperature may be displayed in either
Celsius or Fahrenheit. Each actual value temperature message will be denoted by
either °C for Celsius or °F for Fahrenheit. RTD setpoints are always displayed in Celsius.
•
WAVEFORM TRIGGER: The trigger setpoint allows the user to adjust how many pretrip and post-trip cycles are stored in the waveform memory when a trip occurs. A
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
value of 25%, for example, when the WAVEFORM MEMORY BUFFER is “7 x 16" cycles,
would produce a waveform of 4 pre-trip cycles and 12 post-trip cycles.
•
WAVEFORM MEMORY BUFFER: Selects the partitioning of the waveform memory. The
first number indicates the number of events and the second number, the number of
cycles. The relay captures 12 samples per cycle. When more waveform captures occur
than the available storage, the oldest data will be discarded.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
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CHAPTER 5: SETPOINTS
5.2.3
Communications
Serial Communications
The following setpoints appear when the relay is ordered with the regular enhanced (E)
option.
PATH: SETPOINTS Z S1 489 SETUP ZV COMMUNICATIONS
„ SERIAL PORTS
SLAVE ADDRESS:
254
Range: 1 to 254 in steps of 1
MESSAGE
COMPUTER RS485
BAUD RATE: 9600
Range: 300, 1200, 2400, 4800, 9600,
19200
MESSAGE
COMPUTER RS485
PARITY: None
Range: None, Odd, Even
MESSAGE
AUXILIARY RS485
BAUD RATE: 9600
Range: 300, 1200, 2400, 4800, 9600,
19200
MESSAGE
AUXILIARY RS485
PARITY: None
Range: None, Odd, Even
[Z]
The 489 is equipped with 3 independent serial communications ports supporting a subset
of Modbus RTU protocol. The front panel RS232 has a fixed baud rate of 9600 and a fixed
data frame of 1 start/8 data/1stop/no parity. The front port is intended for local use only
and will respond regardless of the slave address programmed. The front panel RS232
program port may be connected to a personal computer running the EnerVista 489 Setup
software. This program may be used for downloading and uploading setpoint files, viewing
measured parameters, and upgrading the 489 firmware to the latest revision.
For RS485 communications, each relay must have a unique address from 1 to 254. Address
0 is the broadcast address monitored by all relays. Addresses do not have to be sequential
but no two units can have the same address or errors will occur. Generally, each unit
added to the link will use the next higher address starting at 1. Baud rates can be selected
as 300, 1200, 2400, 4800, 9600, or 19200. The data frame is fixed at 1 start, 8 data, and 1
stop bits, while parity is optional. The computer RS485 port is a general purpose port for
connection to a DCS, PLC, or PC. The Auxiliary RS485 port may also be used as another
general purpose port or it may be used to talk to Auxiliary GE Multilin devices in the future.
5–12
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
Ethernet Communications
The following setpoints appear when the relay is ordered with the Ethernet (T) option.
PATH: SETPOINTS Z S1 489 SETUP ZV COMMUNICATIONS
„
COMMUNICATIONS
SLAVE ADDRESS:
254
Range: 1 to 254 in steps of 1
MESSAGE
COMPUTER RS485
BAUD RATE: 9600
Range: 300, 1200, 2400, 4800, 9600,
19200
MESSAGE
COMPUTER RS485
PARITY: None
Range: None, Odd, Even
MESSAGE
FRONT PORT RS232
BAUD RATE: 19200
Range: 300, 1200, 2400, 4800, 9600,
19200
MESSAGE
IP ADDRESS:
0.0.0.0
Range: standard IP address format
MESSAGE
SUBNET IP MASK:
255.255.255.000
Range: standard IP address format
MESSAGE
GATEWAY IP ADDRESS:
0.0.0.0
Range: standard IP address format
[Z]
The IP addresses are used with the Modbus protocol. Enter the dedicated IP, subnet IP, and
gateway IP addresses provided by the network administrator.
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
The RS485 COM2 port is disabled if the Ethernet option is ordered.
Note
5.2.4
Real Time Clock
PATH: SETPOINTS Z S1 489 SETUP ZV REAL TIME CLOCK
„ REAL TIME
CLOCK
DATE (MM, DD, YYYY):
01/01/2001
Range: 01/01/2001 to 12/31/2099
MESSAGE
TIME (HH.MM.SS):
12:00:00
Range: 00:00:00 to 23:59:59
MESSAGE
IRIG-B SIGNAL TYPE:
NONE
Range: None, DC Shift, Amplitude
Modulated
[Z]
For events that are recorded by the event recorder to be correctly time/date stamped, the
correct time and date must be entered. A battery backed internal clock runs continuously
even when power is off. It has the same accuracy as an electronic watch approximately ±1
minute per month. It must be periodically corrected either manually through the front
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
5–13
CHAPTER 5: SETPOINTS
panel or via the clock update command over the RS485 serial link. If the approximate time
an event occurred without synchronization to other relays is sufficient, then entry of time/
date from the front panel keys is adequate.
If the RS485 serial communication link is used then all the relays can keep time in
synchronization with each other. A new clock time is pre-loaded into the memory map via
the RS485 communications port by a remote computer to each relay connected on the
communications channel. The computer broadcasts (address 0) a “set clock” command to
all relays. Then all relays in the system begin timing at the exact same instant. There can
be up to 100 ms of delay in receiving serial commands so the clock time in each relay is
±100 ms, ± the absolute clock accuracy in the PLC or PC. See the chapter on
Communications for information on programming the time preload and synchronizing
commands.
An IRIG-B signal receiver may be connected to 489 units with hardware revision G or
higher. The relay will continuously decode the time signal and set its internal time
correspondingly. The “signal type” setpoint must be set to match the signal provided by the
receiver.
5.2.5
Default Messages
PATH: SETPOINTS Z S1 489 SETUP ZV DEFAULT MESSAGES
„
DEFAULT
[Z]
Range: N/A
GENERATOR STATUS:
Stopped
MESSAGE
A:
C:
0
0
B:
Amps
0
Range: N/A
MESSAGE
Vab:
Vca:
0
0
Vbc:
Volts
0
Range: N/A
MESSAGE
FREQUENCY:
0.00 Hz
Range: N/A
MESSAGE
POWER FACTOR:
0.00
Range: N/A
MESSAGE
REAL POWER:
0 MW
Range: N/A
MESSAGE
REACTIVE POWER
0 Mvar
Range: N/A
MESSAGE
DATE: 01/01/2001
TIME: 12:00:00
Range: N/A
MESSAGE
GE MULTILIN
489 GENERATOR RELAY
Range: N/A
The 489 displays default messages after a period of keypad inactivity. Up to 20 default
messages can be selected for display. If more than one message is chosen, they will
automatically scroll at a rate determined by the S1 489 SETUP ZV PREFERENCES Z DEFAULT
MESSAGE CYCLE TIME setpoint. Any actual value can be selected for display. In addition, up
to 5 user-programmable messages can be created and displayed with the message
5–14
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
scratchpad. For example, the relay could be set to alternately scan a generator
identification message, the current in each phase, and the hottest stator RTD. Currently
selected default messages can be viewed in DEFAULT MESSAGES subgroup.
Default messages can be added to the end of the default message list, as follows:
Z Enter the correct passcode at S1 489 SETUP Z PASSCODE Z ENTER
PASSCODE FOR ACCESS to allow setpoint entry (unless it has already
been entered or is “0”, defeating the passcode security feature).
Z Select the message to be add to the default message list using the
MESSAGE keys.
The selected message can be any actual value or message
scratchpad message.
Z Press ENTER.
The PRESS [ENTER] TO ADD DEFAULT MESSAGES message will
be displayed for 5 seconds:
Z Press ENTER again while this message is displayed to add the
current message to the end of the default message list.
If the procedure was followed correctly, the DEFAULT MESSAGE HAS BEEN
ADDED flash message is displayed:
Z To verify that the message was added, view the last message under
the S1 489 SETUP ZV DEFAULT MESSAGES menu.
Default messages can be removed from the default message list, as follows:
Z Enter the correct passcode at S1 489 SETUP Z PASSCODE Z ENTER
PASSCODE FOR ACCESS to allow setpoint entry (unless the passcode
has already been entered or unless the passcode is “0” defeating the
passcode security feature).
Z Select the message to remove from the default message list under
the S1 489 SETUP ZV DEFAULT MESSAGES menu.
Z Select the default message to remove and press ENTER.
The relay will display PRESS [ENTER] TO REMOVE MESSAGE.
Z Press ENTER while this message is displayed to remove the current
message out of the default message list.
If the procedure was followed correctly, the DEFAULT MESSAGE HAS BEEN
REVOVED flash message is displayed.
5.2.6
Message Scratchpad
PATH: SETPOINTS Z S1 489 SETUP ZV MESSAGE SCRATCHPAD
„
MESSAGE
TEXT 1
Range: 40 alphanumeric characters
TEXT 2
Range: 40 alphanumeric characters
TEXT 3
Range: 40 alphanumeric characters
[Z]
MESSAGE
MESSAGE
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
5–15
CHAPTER 5: SETPOINTS
MESSAGE
MESSAGE
TEXT 4
Range: 40 alphanumeric characters
GE MULTILIN
489 GENERATOR RELAY
Range: 40 alphanumeric characters
Up to 5 message screens can be programmed under the message scratchpad area. These
messages may be notes that pertain to the installation of the generator. In addition, these
notes may be selected for scanning during default message display. This might be useful
for reminding operators to perform certain tasks. The messages may be entered from the
communications ports or through the keypad. To enter a 40 character message:
Z Select the user message to be changed.
Z Press the decimal [.] key to enter text mode.
An underscore cursor will appear under the first character.
Z Use the VALUE keys to display the desired character.
A space is selected like a character.
Z Press the [.] key to advance to the next character.
To skip over a character press the [.] key.
If an incorrect character is accidentally stored, press the [.] key
enough times to scroll the cursor around to the character.
Z When the desired message is displayed press the ENTER key to
store or the ESCAPE key to abort.
The message is now permanently stored.
Z Press ESCAPE to cancel the altered message.
5.2.7
Clear Data
PATH: SETPOINTS Z S1 489 SETUP ZV CLEAR DATA
„ CLEAR DATA
5–16
CLEAR LAST TRIP
DATA: No
Range: No, Yes
MESSAGE
RESET MWh and Mvarh
METERS: No
Range: No, Yes
MESSAGE
CLEAR PEAK DEMAND
DATA: No
Range: No, Yes
MESSAGE
CLEAR RTD
MAXIMUMS: No
Range: No, Yes
MESSAGE
CLEAR ANALOG I/P
MIN/MAX: No
Range: No, Yes
MESSAGE
CLEAR TRIP
COUNTERS: No
Range: No, Yes
MESSAGE
CLEAR EVENT
RECORD: No
Range: No, Yes
MESSAGE
CLEAR GENERATOR
INFORMATION: No
Range: No, Yes
[Z]
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
MESSAGE
CLEAR BREAKER
INFORMATION: No
Range: No, Yes
These commands may be used to clear various historical data.
•
CLEAR LAST TRIP DATA: The Last Trip Data may be cleared by executing this
command.
•
CLEAR MWh and Mvarh METERS: Executing this command will clear the MWh and
Mvarh metering to zero.
•
CLEAR PEAK DEMAND DATA: Execute this command to clear peak demand values.
•
CLEAR RTD MAXIMUMS: All maximum RTD temperature measurements are stored
and updated each time a new maximum temperature is established. Execute this
command to clear the maximum values.
•
CLEAR ANALOG I/P MIN/MAX: The minimum and maximum analog input values are
stored for each Analog Input. Those minimum and maximum values may be cleared
at any time.
•
CLEAR TRIP COUNTERS: There are counters for each possible type of trip. Those
counters may be cleared by executing this command.
•
CLEAR EVENT RECORD: The event recorder saves the last 256 events, automatically
overwriting the oldest event. If desired, all events can be cleared using this command
to prevent confusion with old information.
•
CLEAR GENERATOR INFORMATION: The number of thermal resets and the total
generator running hours can be viewed in actual values. On a new installation, or if
new equipment is installed, this information is cleared through this setpoint.
•
CLEAR BREAKER INFORMATION: The total number of breaker operations can be
viewed in actual values. On a new installation or if maintenance work is done on the
breaker, this accumulator can be cleared with this setpoint.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
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CHAPTER 5: SETPOINTS
5.3
S2 System Setup
5.3.1
Current Sensing
PATH: SETPOINTS ZV S2 SYSTEM SETUP Z CURRENT SENSING
„
CURRENT
PHASE CT PRIMARY:
-------------
Range: 1 to 5000 in steps of 1, Not
Programmed
MESSAGE
GROUND CT:
50:0.025
Range: None, 1A Secondary, 5A
Secondary, 50:0.025
MESSAGE
GROUND CT RATIO:
100: 1
Range: 10 to 10000 in steps of 1. Seen
only if Ground CT Type is 1 A
MESSAGE
GROUND CT RATIO:
100: 5
Range: 10 to 10000 in steps of 1. Seen
only if Ground CT Type is 5 A
[Z]
As a safeguard, the PHASE CT PRIMARY and GENERATOR PARAMETERS setpoints are
defaulted to “--------” when shipped, indicating that the 489 was never programmed. Once
these values are entered, the 489 will be in service. Select the Phase CT so that the
maximum fault current does not exceed 20 times the primary rating. When relaying class
CTs are purchased, this precaution helps prevent CT saturation under fault conditions. The
secondary value of 1 or 5 A must be specified when ordering so the proper hardware will
be installed. The PHASE CT PRIMARY setpoint applies to both the neutral end CTs as well as
the output CTs.
For high resistance grounded systems, sensitive ground current detection is possible if the
50:0.025 Ground CT is used. To use the 50:0.025 CT input, set GROUND CT to “50:0.025”. No
additional ground CT messages will appear. On solid or low resistance grounded systems,
where fault currents may be quite large, the 489 1 A/5 A secondary Ground CT input should
be used. Select the Ground CT primary so that potential fault current does not exceed 20
times the primary rating. When relaying class CTs are purchased, this precaution will
ensure that the Ground CT does not saturate under fault conditions.
The 489 uses a nominal CT primary rating of 5 A for calculation of pickup levels.
5.3.2
Voltage Sensing
PATH: SETPOINTS Z S2 SYSTEM SETUP ZV VOLTAGE SENSING
„
VOLTAGE
5–18
VT CONNECTION TYPE:
None
Range: Open Delta, Wye, None
MESSAGE
VOLTAGE TRANSFORMER
RATIO: 5.00:1
Range: 1.00:1 to 300.00:1 in steps of
0.01
MESSAGE
NEUTRAL VOLTAGE
TRANSFORMER: No
Range: No, Yes
MESSAGE
NEUTRAL VT
RATIO: 5.00:1
Range: 1.00:1 to 240.00:1 in steps of
0.01.
[Z]
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
The NEUTRAL VT RATIO setpoint is seen only if NEUTRAL VOLTAGE TRANSFORMER setpoint is
“Yes”.
Note
The voltage transformer connections and turns ratio are entered here. The VT should be
selected such that the secondary phase-phase voltage of the VTs is between 70.0 and
135.0 V when the primary is at generator rated voltage.
The Neutral VT ratio must be entered here for voltage measurement across the neutral
grounding device. Note that the neutral VT input is not intended to be used at continuous
voltages greater than 240 V. If the voltage across the neutral input is less than 240 V during
fault conditions, an auxiliary voltage transformer is not required. If this is not the case, use
an auxiliary VT to drop the fault voltage below 240 V. The NEUTRAL VT RATIO entered must
be the total effective ratio of the grounding transformer and any auxiliary step up or step
down VT.
For example, if the distribution transformer ratio is 13200:480 and the auxiliary VT ratio is
600:120, the NEUTRAL VT RATIO setpoint is calculated as:
NEUTRAL VT RATIO
= Distribution Transformer Ratio × Auxiliary VT Ratio : 1
13200 600
= --------------- × --------- : 1 = 137.50 : 1
480
120
(EQ 0.1)
Therefore, set NEUTRAL VT RATIO to 137.50:1
5.3.3
Generator Parameters
PATH: SETPOINTS ZV S2 SYSTEM SETUP ZV GENERATOR PARAMETERS
„
GENERATOR
GENERATOR RATED
MVA: ----------------
Range: 0.050 to 2000.000 MVA or Not
Programmed
MESSAGE
GENERATOR RATED
POWER FACTOR: -------
Range: 0.05 to 0.99 or Not
Programmed
MESSAGE
GENERATOR VOLTAGE
PHASE-PHASE: --------
Range: 100 to 30000 V in steps of 1
or Not Programmed
MESSAGE
GENERATOR NOMINAL
FREQUENCY: ----------
Range: 25 Hz, 50 Hz, 60 Hz, or
Not Programmed
MESSAGE
GENERATOR PHASE
SEQUENCE: -----------
Range: ABC, ACB, or Not Programmed
[Z]
As a safeguard, when a unit is received from the factory, the PHASE CT PRIMARY and
Generator Parameters setpoints will be defaulted to “--------”, indicating they are not
programmed. The 489 indicates that it was never programmed. Once these values are
entered, the 489 will be in service. All elements associated with power quantities are
programmed in per unit values calculated from the rated MVA and power factor. The
generator full load amps (FLA) is calculated as
Generator Rated MVA
Generator FLA = ------------------------------------------------------------------------------------------------------------3 × Generator Rated Phase-Phase Voltage
(EQ 0.2)
All voltage protection features that require a level setpoint are programmed in per unit of
the rated generator phase-phase voltage.The nominal system frequency must be entered
here. This setpoint allows the 489 to determine the internal sampling rate for maximum
accuracy. If the sequence of phase rotation for a given system is ACB rather than the
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
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CHAPTER 5: SETPOINTS
standard ABC, the system phase sequence setpoint may be used to accommodate this
rotation. This setpoint allows the 489 to properly calculate phase reversal and negative
sequence quantities.
5.3.4
Serial Start/Stop Initiation
PATH: SETPOINTS ZV S2 SYSTEM SETUP ZV SERIAL START/STOP
„
SERIAL
SERIAL START/STOP
INITIATION: Off
Range: On, Off
MESSAGE
STARTUP INITIATION
RELAYS (2-5): ----
Range: Any Combination of Relays 2 to
5
MESSAGE
SHUTDOWN INITIATION
RELAYS (1-4): ----
Range: Any Combination of Relays 1 to
4
MESSAGE
SERIAL START/STOP
EVENTS: Off
Range: On, Off
[Z]
If enabled, this feature will allow the user to initiate a generator startup or shutdown via
the RS232/RS485 communication ports. Refer to GE publication number GEK-106495: 489
Communications Guide for command formats. When a startup command is issued, the
auxiliary relay(s) assigned for starting control will be activated for 1 second to initiate
startup. When a stop command is issued, the assigned relay(s) will be activated for 1
second to initiate a shutdown.
5–20
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
5.4
S3 Digital Inputs
5.4.1
Description
The 489 has nine (9) digital inputs for use with external contacts. Two of the 489 digital
inputs have been pre-assigned as inputs having a specific function. The Access Switch
does not have any setpoint messages associated with it. The Breaker Status input, may be
configured for either an 'a' or 'b' auxiliary contact. The remaining seven digital inputs are
assignable; that is to say, each input may be assigned to any of a number of different
functions. Some of those functions are very specific, others may be programmed to adapt
to user requirements.
Terminals C1 and C2 must be shorted to allow changing of any setpoint values from the
front panel keypad. This safeguard is in addition to the setpoint passcode feature, which
functions independently (see the S1 489 SETUP Z PASSCODE menu). The access switch has no
effect on setpoint programming from the RS232 and RS485 serial communications ports.
5.4.2
Breaker Status
PATH: SETPOINTS ZV S3 DIGITAL INPUTS Z BREAKER STATUS
„
BREAKER
[Z]
BREAKER STATUS:
Breaker Auxiliary b
Range: Breaker Auxiliary a,
Breaker Auxiliary b
This input is necessary for all installations. The 489 determines when the generator is
online or offline based on the Breaker Status input. Once 'Breaker Auxiliary a' is chosen,
terminals C3 and C4 will be monitored to detect the state of the machine main breaker,
open signifying the breaker is open and shorted signifying the breaker is closed. Once
“Breaker Auxiliary b” is chosen, terminals C3 and C4 will be monitored to detect the state of
the breaker, shorted signifying the breaker is open and open signifying the breaker is
closed.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
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CHAPTER 5: SETPOINTS
5.4.3
General Input A to G
PATH: SETPOINTS ZV S3 DIGITAL INPUTS ZV GENERAL INPUT A(G)
„
GENERAL
Note
ASSIGN DIGITAL
INPUT: None
Range: None, Input 1 to Input 7. See
note below.
MESSAGE
ASSERTED DIGITAL
INPUT STATE: Closed
Range: Closed, Open
MESSAGE
INPUT NAME:
Input A
Range: 12 alphanumeric characters
MESSAGE
BLOCK INPUT
FROM ONLINE: 0 s
Range: 0 to 5000 s in steps of 1.
MESSAGE
GENERAL INPUT A
CONTROL: Off
Range: Off, On
MESSAGE
PULSED CONTROL RELAY
DWELL TIME: 0.0 s
Range: 0.0 to 25.0 s in steps of 0.1
MESSAGE
ASSIGN CONTROL
RELAYS (1-5): -----
Range: Any combination of Relays 1 to
5
MESSAGE
GENERAL INPUT A
CONTROL EVENTS: Off
Range: Off, On
MESSAGE
GENERAL INPUT A
ALARM: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN ALARM
RELAYS (2-5): ---5
Range: Any combination of Relays 2 to
5
MESSAGE
GENERAL INPUT A
ALARM DELAY: 0.5 s
Range: 0.1 to 5000.0 s in steps of 0.1
MESSAGE
GENERAL INPUT A
ALARM EVENTS: Off
Range: Off, On
MESSAGE
GENERAL INPUT A
TRIP: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN TRIP
RELAYS (1-4): 1---
Range: Any combination of Relays 1 to
4
MESSAGE
GENERAL INPUT A
TRIP DELAY: 5.0 s
Range: 0.1 to 5000.0 in steps of 0.1
[Z]
If an input is assigned to the Tachometer function, it may not be assigned via the ASSIGN
DIGITAL INPUT setpoint.
The seven General Input functions are flexible enough to meet most of the desired digital
input requirements. The asserted state and the name of the digital inputs are
programmable. To disable the input functions when the generator is offline, until some
time after the generator is brought online, a block time should be set. The input functions
will be enabled once the block delay has expired. A value of “0 s” for the BLOCK INPUT FROM
ONLINE block time indicates that the input functions are always enabled while the
generator is offline as well as online.
5–22
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
Inputs may be configured for control, alarm, or trip. If the control feature is enabled, the
assigned output relay(s) operate when the input is asserted. If the PULSED CONTROL RELAY
DWELL TIME is set to “0”, the output relay(s) operate only while the input is asserted.
However, if a dwell time is assigned, the output relay(s) operate as soon as the input is
asserted for a period of time specified by the setpoint. If an alarm or trip is enabled and the
input is asserted, an alarm or trip will occur after the specified delay.
5.4.4
Remote Reset
PATH: SETPOINTS ZV S3 DIGITAL INPUTS ZV REMOTE RESET
„ REMOTE RESET
[Z]
ASSIGN DIGITAL
INPUT: None
Range: None, Input 1, Input 2, Input 3,
Input 4, Input 5, Input 6, Input 7
Once an input is assigned to the Remote Reset function, shorting that input will reset any
latched trips or alarms that may be active, provided that any thermal lockout time has
expired and the condition that caused the alarm or trip is no longer present.
If an input is assigned to the tachometer function, it may not be used here.
5.4.5
Test Input
PATH: SETPOINTS ZV S3 DIGITAL INPUTS ZV TEST INPUT
„ TEST INPUT
[Z]
ASSIGN DIGITAL
INPUT: None
Range: None, Input 1, Input 2, Input 3,
Input 4, Input 5, Input 6, Input 7
Once the 489 is in service, it may be tested from time to time as part of a regular
maintenance schedule. The unit will have accumulated statistical information relating
historically to generator and breaker operation. This information includes: last trip data,
peak demand data, MWh and Mvarh metering, parameter averages, RTD maximums,
analog input minimums and maximums, number of trips, number of trips by type, number
of breaker operations, the number of thermal resets, total generator running hours, and
the event record. When the unit is under test and one of the inputs is assigned to the Test
Input function, shorting that input will prevent all of this data from being corrupted or
updated.
If an input is assigned to the tachometer function, it may not be used here.
5.4.6
Thermal Reset
PATH: SETPOINTS ZV S3 DIGITAL INPUTS ZV THERMAL RESET
„ THERMAL RESET
[Z]
ASSIGN DIGITAL
INPUT: None
Range: None, Input 1, Input 2, Input 3,
Input 4, Input 5, Input 6, Input 7
During testing or in an emergency, it may be desirable to reset the thermal memory used
to zero. If an input is assigned to the Thermal Reset function, shorting that input will reset
the thermal memory used to zero. All Thermal Resets will be recorded as events.
If an input is assigned to the tachometer function, it may not be used here.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
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CHAPTER 5: SETPOINTS
5.4.7
Dual Setpoints
PATH: SETPOINTS ZV S3 DIGITAL INPUTS ZV DUAL SETPOINTS
„
DUAL
ASSIGN DIGITAL
INPUT: None
Range: None, Input 1, Input 2, Input 3,
Input 4, Input 5, Input 6, Input 7
MESSAGE
ACTIVATE SETPOINT
GROUP: Group 1
Range: Group 1, Group 2
MESSAGE
EDIT SETPOINT
GROUP: Group 1
Range: Group 1, Group 2
[Z]
If an input is assigned to the tachometer function, it may not be used here.
This feature allows for dual settings for the current, voltage, power, RTD, and thermal
model protection elements (setpoint pages S5 to S9). These settings are organized in two
setpoint groups: the main group (Group 1) and the alternate group (Group 2). Only one
group of settings are active in the protection scheme at a time.
When accessing the Group 2 setpoints, the block character („) for the setpoints menu
header will be replaced by the number two (2) as indicated below.
The following chart illustrates the available Group 2 (alternate group) setpoints
2 SETPOINTS
[Z]
S5 CURRENT ELEM.
2 SETPOINTS
[Z]
S6 VOLTAGE ELEM.
2 SETPOINTS
[Z]
S7 POWER ELEMENTS
2 SETPOINTS
[Z]
S8 RTD TEMPERATURE
2 SETPOINTS
[Z]
S9 THERMAL MODEL
2 OVERCURRENT
ALARM
[Z]
2 UNDERVOLTAGE
[Z]
2 REACTIVE
POWER
[Z]
2 RTD
TYPES
[Z]
2 MODEL
SETUP
[Z]
2 OFFLINE
OVERCURRENT
[Z]
2 OVERVOLTAGE
[Z]
2 REVERSE
POWER
[Z]
2 RTD
[Z]
2 THERMAL
ELEMENTS
[Z]
2 INADVERTENT
ENERGIZATION
[Z]
2 VOLTS/HERTZ
[Z]
2 LOW
[Z]
FORWARD POWER
2 PHASE
OVERCURRENT
[Z]
2 PHASE
REVERSAL
[Z]
2 NEGATIVE
SEQUENCE
[Z]
2 GROUND
OVERCURRENT
[Z]
2 PHASE
DIFFERENTIAL
[Z]
2 GROUND
DIRECTIONAL
[Z]
2 HIGH-SET
[Z]
PHASE OVERCURRENT
↓
2 RTD #12
[Z]
2 UNDERFREQUENCY[Z]
2 OPEN
RTD SENSOR
[Z]
2 OVERFREQUENCY [Z]
2 RTD
[Z]
SHORT/LOW TEMP
2 NEUTRAL
OVERVOLTAGE
(Fund)
[Z]
2 NEUTRAL U/
V
[Z]
(3rd HARMONIC)
2 LOSS
[Z]
OF EXCITATION
2 DISTANCE
ELEMENT
5–24
#1
[Z]
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
The active group can be selected using the ACTIVATE SETPOINT GROUP setpoint or the
assigned digital input (shorting that input will activate the alternate set of protection
setpoints, Group 2). In the event of a conflict between the ACTIVATE SETPOINT GROUP
setpoint or the assigned digital input, Group 2 will be activated. The LED indicator on the
faceplate of the 489 will indicate when the alternate setpoints are active in the protection
scheme. Changing the active setpoint group will be logged as an event. Independently, the
setpoints in either group can be viewed and/or edited using the EDIT SETPOINT GROUP
setpoint. Headers for each setpoint message subgroup that has dual settings will be
denoted by a superscript number indicating which setpoint group is being viewed or
edited. Also, when a setpoint that has dual settings is stored, the flash message that
appears will indicate which setpoint group setting has been changed.
5.4.8
Sequential Trip
PATH: SETPOINTS ZV S3 DIGITAL INPUTS ZV SEQUENTIAL TRIP
„
SEQUENTIAL
ASSIGN DIGITAL
INPUT: None
Range: None, Input 1 to Input 7.
MESSAGE
SEQUENTIAL TRIP TYPE
Low Forward Power
Range: Low Forward Power, Reverse
Power
MESSAGE
ASSIGN TRIP
RELAYS (1-4): 1---
Range: Any combination of Relays 1 to
4
MESSAGE
SEQUENTIAL TRIP
LEVEL: 0.05 x Rated
Range: 0.02 to 0.99 × Rated MW in
steps of 0.01
MESSAGE
SEQUENTIAL TRIP
DELAY: 1.0 s
Range: 0.2 to 120.0 s in steps of 0.1
[Z]
If an input is assigned to the tachometer function, it may not be used here.
During routine shutdown and for some less critical trips, it may be desirable to use the
sequential trip function to prevent overspeed. If an input is assigned to the sequential trip
function, shorting that input will enable either a low forward power or reverse power
function. Once the measured 3-phase total power falls below the low forward power level,
or exceeds the reverse power level for the period of time specified, a trip will occur. This
time delay will typically be shorter than that used for the standard reverse power or low
forward power elements. The level is programmed in per unit of generator rated MW
calculated from the rated MVA and rated power factor. If the VT type is selected as None,
the sequential trip element will operate as a simple timer. Once the input has been shorted
for the period of time specified by the delay, a trip will occur.
Note
The minimum magnitude of power measurement is determined by the phase CT minimum
of 2% rated CT primary. If the level for reverse power is set below that level, a trip will only
occur once the phase current exceeds the 2% cutoff.
Users are cautioned that a reverse power element may not provide reliable indication
when set to a very low setting, particularly under conditions of large reactive loading on
the generator. Under such conditions, low forward power is a more reliable element.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
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CHAPTER 5: SETPOINTS
5.4.9
Field-Breaker
PATH: SETPOINTS ZV S3 DIGITAL INPUTS ZV FIELD-BREAKER DISCREPANCY
„ FIELDBREAKER
ASSIGN DIGITAL
INPUT: None
Range: None, Input 1 to Input 7
MESSAGE
FIELD STATUS
CONTACT: Auxiliary a
Range: Auxiliary a, Auxiliary b
MESSAGE
ASSIGN TRIP
RELAYS (1-4): 1---
Range: Any combination of Relays 1 to
4
MESSAGE
FIELD-BKR DISCREP.
TRIP DELAY: 1.0 s
Range: 0.1 to 500.0 s in steps of 0.1
[Z]
If an input is assigned to the tachometer function, it may not be used here.
The field-breaker discrepancy function is intended for use with synchronous generators. If
a digital input is assigned to this function, any time the field status contact indicates the
field is not applied and the breaker status input indicates that the generator is online, a trip
will occur once the time delay has expired. The time delay should be used to prevent
possible nuisance tripping during shutdown. The field status contact may be chosen as
“Auxiliary a”, open signifying the field breaker or contactor is open and shorted signifying
the field breaker or contactor is closed. Conversely, the field status contact may be chosen
as “Auxiliary b”, shorted signifying the field breaker or contactor is open and open
signifying it is closed.
5.4.10 Tachometer
PATH: SETPOINTS ZV S3 DIGITAL INPUTS ZV TACHOMETER
„
TACHOMETER
5–26
ASSIGN DIGITAL
INPUT: None
Range: None, Inputs 4 to 7.
MESSAGE
RATED SPEED:
3600 RPM
Range: 100 to 3600 RPM in steps of 1
MESSAGE
TACHOMETER
ALARM: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN ALARM
RELAYS (2-5): ---5
Range: Any combination of Relays 2 to
5
MESSAGE
TACHOMETER ALARM
SPEED: 110% Rated
Range: 101 to 175% in steps of 1
MESSAGE
TACHOMETER ALARM
DELAY: 1 s
Range: 1 to 250 s in steps of 1
MESSAGE
TACHOMETER ALARM
EVENTS: Off
Range: On, Off
MESSAGE
TACHOMETER
TRIP: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN TRIP
RELAYS (1-4): 1---
Range: Any combination of Relays 1 to
4
[Z]
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
MESSAGE
TACHOMETER TRIP
SPEED: 110% Rated
Range: 101 to 175% in steps of 1
MESSAGE
TACHOMETER TRIP
DELAY: 1 s
Range: 1 to 250 s in steps of 1
One of assignable digital inputs 4 to 7 may be assigned to the tachometer function to
measure mechanical speed. The time between each input closure is measured and
converted to an RPM value based on one closure per revolution. If an overspeed trip or
alarm is enabled, and the measured RPM exceeds the threshold setpoint for the time
specified by the delay, a trip or alarm will occur. The RPM value can be viewed with the A2
METERING DATA ZV SPEED ZV TACHOMETER actual value.
For example, an inductive proximity probe or hall effect gear tooth sensor may be used to
sense the key on the generator. The probe could be powered from the +24V from the digital
input power supply. The NPN transistor output could be taken to one of the assignable
digital inputs assigned to the tachometer function.
5.4.11 Waveform Capture
PATH: SETPOINTS ZV S3 DIGITAL INPUTS ZV WAVEFORM CAPTURE
„
WAVEFORM
[Z]
ASSIGN DIGITAL
INPUT: None
Range: None, Input 1 to Input 7.
If an input is assigned to the tachometer function, it may not be used here.
This feature may be used to trigger the waveform capture from an external contact. When
one of the inputs is assigned to the Waveform Capture function, shorting that input will
trigger the waveform.
5.4.12 Ground Switch Status
PATH: SETPOINTS ZV S3 DIGITAL INPUTS ZV GND SWITCH STATUS
„
GROUND
[Z]
MESSAGE
ASSIGN DIGITAL
INPUT: None
Range: None, Input 1 to Input 7
GROUND SWITCH
CONTACT: Auxiliary a
Range: Auxiliary a, Auxiliary b
If an input is assigned to the tachometer function, it may not be used here.
This function is used to detect the status of a grounding switch for the generator for which
the relay is installed. Refer to Stator Ground Fault on page A–1 for additional details.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
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CHAPTER 5: SETPOINTS
5.5
S4 Output Relays
5.5.1
Description
Five of the six output relays are always non-failsafe; the 6 Service relay is always failsafe.
As a failsafe, the 6 Service relay will be energized normally and de-energize when called
upon to operate. It will also de-energize when control power to the 489 is lost and
therefore, be in its operated state. All other relays, being non-failsafe, will be de-energized
normally and energize when called upon to operate. Obviously, when control power is lost
to the 489, the output relays must be de-energized and therefore, they will be in their nonoperated state. Shorting bars in the drawout case ensure that when the 489 is drawn out,
no trip or alarm occurs. The 6 Service output will however indicate that the 489 has been
drawn out.
5.5.2
Relay Reset Mode
PATH: SETPOINTS ZV S4 OUTPUT RELAYS Z RELAY RESET MODE
„
RELAY
1 TRIP:
All Resets
Range: All Resets, Remote Reset Only
MESSAGE
2 AUXILIARY:
All Resets
Range: All Resets, Remote Reset Only
MESSAGE
3 AUXILIARY:
All Resets
Range: All Resets, Remote Reset Only
MESSAGE
4 AUXILIARY:
All Resets
Range: All Resets, Remote Reset Only
MESSAGE
5 ALARM:
All Resets
Range: All Resets, Remote Reset Only
MESSAGE
6 SERVICE:
All Resets
Range: All Resets, Remote Reset Only
[Z]
Unlatched trips and alarms will reset automatically once the condition is no longer
present. Latched trip and alarm features may be reset at any time, providing that the
condition that caused the trip or alarm is no longer present and any lockout time has
expired. If any condition may be reset, the Reset Possible LED will be lit. The relays may be
programmed to All Resets which allows reset from the front keypad or the remote reset
digital input or the communications port. Optionally, they may be programmed to reset by
the Remote Reset Only (by the remote reset digital input or the communications port).
For example, selected trips such as Instantaneous Overcurrent and Ground Fault may be
assigned to output relay 2 so that they may only be reset via. the Remote Reset digital
input or the communication port. The Remote Reset terminals would be connected to a
keyswitch so that only authorized personnel could reset such a critical trip.
Z Assign only Short Circuit and Ground Fault to relay 2.
Z Program relay 2 to Remote Reset Only.
5–28
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
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5.6
S5 Current Elements
5.6.1
Inverse Time Overcurrent Curve Characteristics
Description
The 489 inverse time overcurrent curves may be either ANSI, IEC, or GE Type IAC standard
curve shapes. This allows for simplified coordination with downstream devices. If however,
none of these curve shapes is adequate, the FlexCurve™ may be used to customize the
inverse time curve characteristics. Definite time is also an option that may be appropriate
if only simple protection is required.
Table 5–1: 489 Overcurrent Curve Types
ANSI
IEC
GE Type IAC
Other
Extremely Inverse
Curve A (BS142)
Extremely Inverse
FlexCurve™
Very Inverse
Curve B (BS142)
Very Inverse
Definite Time
Normally Inverse
Curve C (BS142)
Inverse
Moderately Inverse
Short Inverse
Short Inverse
A multiplier setpoint allows selection of a multiple of the base curve shape that is selected
with the curve shape setpoint. Unlike the electromechanical time dial equivalent, trip times
are directly proportional to the time multiplier setting value. For example, all trip times for a
multiplier of 10 are 10 times the multiplier 1 or base curve values. Setting the multiplier to
zero results in an instantaneous response to all current levels above pickup.
Note
Regardless of the trip time that results from the curve multiplier setpoint, the 489
cannot trip any quicker than one to two cycles plus the operate time of the output
relay.
Time overcurrent tripping time calculations are made with an internal “energy capacity”
memory variable. When this variable indicates that the energy capacity has reached
100%, a time overcurrent trip is generated. If less than 100% is accumulated in this
variable and the current falls below the dropout threshold of 97 to 98% of the pickup value,
the variable must be reduced. Two methods of this resetting operation are available,
“Instantaneous” and “Linear”. The Instantaneous selection is intended for applications with
other relays, such as most static units, which set the energy capacity directly to zero when
the current falls below the reset threshold. The Linear selection can be used where the 489
must coordinate with electromechanical units. With this setting, the energy capacity
variable is decremented according to the following equation.
E×M×C
T RESET = -------------------------R100
(EQ 0.3)
where: TRESET = reset time in seconds
E = energy capacity reached (in %)
M = curve multiplier
CR= characteristic constant (5 for ANSI, IAC, Definite Time and FlexCurves™, 8 for
IEC curves)
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
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CHAPTER 5: SETPOINTS
ANSI Curves
The ANSI time overcurrent curve shapes conform to industry standard curves and fit into
the ANSI C37.90 curve classifications for extremely, very, normally, and moderately
inverse. The 489 ANSI curves are derived from the formula:
⎛
⎞
B
E
D
T = M × ⎜ A + ----------------------------------- + ------------------------------------------⎟
- + -----------------------------------------2
3
( I ⁄ I pickup ) – C ( ( I ⁄ I pickup ) – C )
⎝
( ( I ⁄ I pickup ) – C ) ⎠
(EQ 0.4)
where: T = Trip Time in seconds
M = Multiplier setpoint
I = Input Current
Ipickup = Pickup Current setpoint
A, B, C, D, E = Constants
Table 5–2: ANSI Inverse Time Curve Constants
ANSI Curve Shape
Constants
A
B
C
D
E
Extremely Inverse
0.0399
0.2294
0.5000
3.0094
0.7222
Very Inverse
0.0615
0.7989
0.3400
–0.2840
4.0505
Normally Inverse
0.0274
2.2614
0.3000
–4.1899
9.1272
Moderately Inverse
0.1735
0.6791
0.8000
–0.0800
0.1271
IEC Curves
For European applications, the relay offers the four standard curves defined in IEC 255-4
and British standard BS142. These are defined as IEC Curve A, IEC Curve B, IEC Curve C, and
Short Inverse. The formula for these curves is:
⎛
⎞
K
-⎟
T = M × ⎜ ------------------------------------E
⎝ ( I ⁄ I pickup ) – 1⎠
(EQ 0.5)
where: T = Trip Time in seconds
M = Multiplier setpoint
I = Input Current
Ipickup = Pickup Current setpoint
K, E = Constants
Table 5–3: IEC (BS) Inverse Time Curve Constants
IEC (BS) Curve Shape
Constants
K
5–30
E
IEC Curve A (BS142)
0.140
0.020
IEC Curve B (BS142)
13.500
1.000
IEC Curve C (BS142)
80.000
2.000
Short Inverse
0.050
0.040
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
IAC Curves
The curves for the General Electric type IAC relay family are derived from the formula:
⎛
⎞
B
E
D
T = M × ⎜ A + ------------------------------------ + ------------------------------------------- + -------------------------------------------⎟
2
3
I
I
(
⁄
)
–
C
⎝
( ( I ⁄ I pickup ) – C )
( ( I ⁄ I pickup ) – C ) ⎠
pickup
(EQ 0.6)
where: T = Trip Time in seconds
M = Multiplier setpoint
I = Input Current
Ipickup = Pickup Current setpoint
A, B, C, D, E = Constants
Table 5–4: IAC Inverse Time Curve Constants
IAC Curve Shape
Constants
A
B
C
D
E
Extreme Inverse
0.0040
0.6379
0.6200
1.7872
0.2461
Very Inverse
0.0900
0.7955
0.1000
–1.2885
7.9586
Inverse
0.2078
0.8630
0.8000
–0.4180
0.1947
Short Inverse
0.0428
0.0609
0.6200
–0.0010
0.0221
FlexCurve™
The custom FlexCurve™ has setpoints for entering times to trip at the following current
levels: 1.03, 1.05, 1.1 to 6.0 in steps of 0.1 and 6.5 to 20.0 in steps of 0.5. The relay then
converts these points to a continuous curve by linear interpolation between data points. To
enter a custom FlexCurve™, read off each individual point from a time overcurrent
coordination drawing and enter it into a table as shown. Then transfer each individual
point to the 489 using either the EnerVista 489 Setup software or the front panel keys and
display.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
5–31
CHAPTER 5: SETPOINTS
Table 5–5: FlexCurve™ Trip Times
Pickup
I/Ipkp
Trip
Time
(ms)
Pickup
I/Ipkp
Trip
Time
(ms)
Pickup
I/Ipkp
Trip
Time
(ms)
Pickup
I/Ipkp
1.03
2.9
4.9
10.5
1.05
3.0
5.0
11.0
1.1
3.1
5.1
11.5
1.2
3.2
5.2
12.0
1.3
3.3
5.3
12.5
1.4
3.4
5.4
13.0
1.5
3.5
5.5
13.5
1.6
3.6
5.6
14.0
1.7
3.7
5.7
14.5
1.8
3.8
5.8
15.0
1.9
3.9
5.9
15.5
2.0
4.0
6.0
16.0
2.1
4.1
6.5
16.5
2.2
4.2
7.0
17.0
2.3
4.3
7.5
17.5
2.4
4.4
8.0
18.0
2.5
4.5
8.5
18.5
2.6
4.6
9.0
19.0
2.7
4.7
9.5
19.5
2.8
4.8
10.0
20.0
Trip
Time
(ms)
Definite Time Curve
The definite time curve shape causes a trip as soon as the pickup level is exceeded for a
specified period of time. The base definite time curve delay is 100 ms. The curve multiplier
of 0.00 to 1000.00 makes this delay adjustable from instantaneous to 100.00 seconds in
steps of 1 ms.
T = M × 100 ms, when I > I pickup
(EQ 0.7)
where: T = Trip Time in seconds
M = Multiplier Setpoint
I = Input Current
Ipickup = Pickup Current Setpoint
5–32
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
5.6.2
Overcurrent Alarm
PATH: SETPOINTS ZV S5 CURRENT ELEM. Z OVERCURRENT ALARM
1 OVERCURRENT
ALARM
OVERCURRENT
ALARM: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN ALARM
RELAYS (2-5): ---5
Range: Any combination of Relays 2 to
5
MESSAGE
OVERCURRENT ALARM
LEVEL: 1.01 x FLA
Range: 0.10 to 1.50 × FLA in steps of
0.01
MESSAGE
OVERCURRENT ALARM
DELAY: 0.1 s
Range: 0.1 to 250.0 s in steps of 0.1
MESSAGE
OVERCURRENT ALARM
EVENTS: Off
Range: On, Off
[Z]
If enabled as Latched or Unlatched, the Overcurrent Alarm will function as follows: If the
average generator current (RMS) measured at the output CTs exceeds the level
programmed for the period of time specified, an alarm will occur. If programmed as
unlatched, the alarm will reset itself when the overcurrent condition is no longer present. If
programmed as latched, once the overcurrent condition is gone, the reset key must be
pressed to reset the alarm. The generator FLA is calculated as:
Generator Rated MVA
Generator FLA = ------------------------------------------------------------------------------------------------------------3 × Generator Rated Phase-Phase Voltage
5.6.3
(EQ 0.8)
Offline Overcurrent
PATH: SETPOINTS ZV S5 CURRENT ELEM. ZV OFFLINE OVERCURRENT
1 OFFLINE
OVERCURRENT
OFFLINE OVERCURRENT
TRIP: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN TRIP
RELAYS (1-4): 1---
Range: Any combination of Relays 1 to
4
MESSAGE
OFFLINE OVERCURRENT
PICKUP: 0.05 x CT
Range: 0.05 to 1.00 × CT in steps of
0.01
MESSAGE
OFFLINE OVERCURRENT
TRIP DELAY: 5 cycles
Range: 3 to 99 cycles in steps of 1
[Z]
When a synchronous generator is offline, there should be no measurable current flow in
any of the three phases unless the unit is supplying its own station load. Also, since the
generator is not yet online, differentiation between system faults and machine faults is
easier. The offline overcurrent feature is active only when the generator is offline and uses
the neutral end CT measurements (Ia, Ib, Ic). It may be set much more sensitive than the
differential element to detect high impedance phase faults. Since the breaker auxiliary
contacts wired to the 489 Breaker Status input may not operate at exactly the same time
as the main breaker contacts, the time delay should be coordinated with the difference of
the operation times. In the event of a low impedance fault, the differential element will still
shutdown the generator quickly.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
5–33
CHAPTER 5: SETPOINTS
If the unit auxiliary transformer is on the generator side of the breaker, the pickup level
must be set greater than the unit auxiliary load.
Note
5.6.4
Inadvertent Energization
PATH: SETPOINTS ZV S5 CURRENT ELEM. ZV INADVERTENT ENERG.
1 INADVERTENT
ENERGIZATION
INADVERTENT ENERGIZE
TRIP: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN TRIP
RELAYS (1-4): 1---
Range: Any combination of Relays 1 to
4
MESSAGE
ARMING SIGNAL:
U/V and Offline
Range: U/V and Offline, U/V or Offline
MESSAGE
INADVERTENT ENERGIZE
O/C PICKUP: 0.05 x CT
Range: 0.05 to 3.00 × CT in steps of
0.01
MESSAGE
INADVERTENT ENERGIZE
PICKUP: 0.50 x Rated
Range: 0.50 to 0.99 × Rated Voltage in
steps of 0.01
[Z]
The logic diagram for the inadvertent energization protection feature is shown below. The
feature may be armed when all of the phase voltages fall below the undervoltage pickup
level and the unit is offline. This would be the case when the VTs are on the generator side
of the disconnect device. If however, the VTs are on the power system side of the
disconnect device, the feature should be armed if all of the phase voltages fall below the
undervoltage pickup level or the unit is offline. When the feature is armed, if any one of the
phase currents measured at the output CTs exceeds the overcurrent level programmed, a
trip will occur.
Note
This feature requires 5 seconds to arm, 250 ms to disarm.
Protection can be provided for poor synchronization by using the “U/V or Offline” arming
signal. During normal synchronization, there should be relatively low current measured. If
however, synchronization is attempted when conditions are not appropriate, a large
current that is measured within 250 ms after the generator is placed online would result in
a trip.
Operate
Iphase > O/C Level
AND
Vphase < U/V Level
Breaker Status = Offline
5s
AND
OR
250 ms
OR
Arming Signal = U/V or Offline
AND
808731A1.CDR
FIGURE 5–1: Inadvertent Energization Logic
5–34
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
5.6.5
Phase Overcurrent
PATH: SETPOINTS ZV S5 CURRENT ELEM. ZV PHASE OVERCURRENT
1 PHASE
OVERCURRENT
PHASE OVERCURRENT
TRIP: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN TRIP
RELAYS (1-4): 1---
Range: Any combination of Relays 1 to
4
MESSAGE
ENABLE VOLTAGE
RESTRAINT: No
Range: No, Yes
MESSAGE
VOLTAGE LOWER
LIMIT: 10%
Range: 10 to 60%. Seen only if ENABLE
VOLTAGE RESTRAINT is "Yes"
MESSAGE
PHASE OVERCURRENT
PICKUP: 10.00 x CT
Range: 0.15 to 20.00 × CT in steps of
0.01
MESSAGE
CURVE SHAPE:
ANSI Extremely Inv.
Range: See Table 5–1: 489 Overcurrent
Curve Types on page –29.
MESSAGE
Range: 0 to 65535 ms Seen only if
FLEXCURVE TRIP TIME
CURVE SHAPE is “Flexcurve”
AT 1.03 x PU: 65535 ms
[Z]
↓
MESSAGE
Range: 0 to 65535 ms. Seen only if
FLEXCURVE TRIP TIME
CURVE SHAPE is “Flexcurve”
AT 20.0 x PU: 65535 ms
MESSAGE
OVERCURRENT CURVE
MULTIPLIER: 1.00
Range: 0.00 to 1000.00 in steps of 0.01
MESSAGE
OVERCURRENT CURVE
RESET: Instantaneous
Range: Instantaneous, Linear
If the primary system protection fails to properly isolate phase faults, the voltage
restrained overcurrent acts as system backup protection. The magnitude of each phase
current measured at the output CTs is used to time out against an inverse time curve. The
489 inverse time curve for this element may be either ANSI, IEC, or GE Type IAC standard
curve shapes. This allows for simplified coordination with downstream devices. If these
curve shapes are not adequate, FlexCurves™ may be used to customize the inverse time
curve characteristics.
The voltage restraint feature lowers the pickup value of each phase time overcurrent
element in a fixed relationship (see figure below) with the corresponding input voltage to a
minimum pickup of 0.15 × CT. The VOLTAGE LOWER LIMIT setpoint prevents very rapid
tripping prior to primary protection clearing a fault when voltage restraint is enabled and
severe close-in fault has occurred. If voltage restraint is not required, select “No” for this
setpoint. If the VT type is selected as “None” or a VT fuse loss is detected, the voltage
restraint is ignored and the element operates as simple phase overcurrent.
Note
A fuse failure is detected within 99 ms; therefore, any voltage restrained overcurrent trip
should have a time delay of 100 ms or more or nuisance tripping on fuse loss could occur.
For example, to determine the voltage restrained phase overcurrent pickup level under the
following situation:
•
PHASE OVERCURRENT PICKUP: “2.00 × CT”
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
5–35
CHAPTER 5: SETPOINTS
•
ENABLE VOLTAGE RESTRAINT:
“Yes”
•
VOLTAGE LOWER LIMIT: 10%
•
Phase-Phase Voltage / Rated Phase-Phase Voltage = 0.4 p.u. V
The voltage restrained phase overcurrent pickup level is calculated as follows:
Pickup vrest = Phase OC Pickup × Voltage Rest. Pickup Multiplier × CT
(EQ 5.9)
= ( 2 × 0.4 ) × CT = 0.8 × CT
The 489 phase overcurrent restraint voltages and restraint characteristic are shown below.
1
Phase Overcurrent Restraint Voltages:
VOLTAGE
IA
Vab
IB
Vbc
IC
Vca
0.9
Curve Pickup Multiplier
CURRENT
0.8
0.7
0.6
0.5
0.4
0.3
0.2
0.1
808792A4.CDR
0
0
0.1
0.2
0.3
0.4
0.5
0.6
0.7
0.8
0.9
1
Phase-Phase Voltage / Rated Phase-Phase Voltage
FIGURE 5–2: Voltage Restraint Characteristic
5.6.6
Negative Sequence
PATH: SETPOINTS ZV S5 CURRENT ELEM. ZV NEGATIVE SEQUENCE
1 NEGATIVE
SEQUENCE
5–36
NEGATIVE SEQUENCE
ALARM: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN ALARM
RELAYS (2-5): ---5
Range: Any combination of Relays 2 to
5
MESSAGE
NEG. SEQUENCE ALARM
PICKUP: 3% FLA
Range: 3 to 100% FLA in steps of 1
MESSAGE
NEGATIVE SEQUENCE
ALARM DELAY: 0.5 s
Range: 0.1 to 100.0 s in steps of 0.1
MESSAGE
NEGATIVE SEQUENCE
ALARM EVENTS: Off
Range: On, Off
MESSAGE
NEGATIVE SEQUENCE
O/C TRIP: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN TRIP
RELAYS (1-4): 1---
Range: Any combination of Relays 1 to
4
MESSAGE
NEG. SEQUENCE O/C
TRIP PICKUP: 8% FLA
Range: 3 to 100% FLA in steps of 1
MESSAGE
NEG. SEQUENCE O/C
CONSTANT K: 1
Range: 1 to 100 in steps of 1
MESSAGE
NEG. SEQUENCE O/C
MAX. TIME: 1000 s
Range: 10 to 1000 s in steps of 1
[Z]
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
MESSAGE
NEG. SEQUENCE O/C
RESET RATE: 227.0 s
Range: 0.0 to 999.9 s in steps of 0.01
Rotor heating in generators due to negative sequence current is a well known
phenomenon. Generators have very specific capability limits where unbalanced current is
concerned (see ANSI C50.13). A generator should have a rating for both continuous and
also short time operation when negative sequence current components are present.
The short time negative-sequence capability of the generator is defined as follows:
2
K = I2 T
(EQ 5.10)
where: K = constant from generator manufacturer depending on size and design;
I2 = negative sequence current as a percentage of generator rated FLA as
measured at the output CTs;
t = time in seconds when I2 > pickup (minimum 250 ms, maximum defined by
setpoint).
The 489 has a definite time alarm and inverse time overcurrent curve trip to protect the
generator rotor from overheating due to the presence of negative sequence currents.
Pickup values are negative sequence current as a percent of generator rated full load
current. The generator FLA is calculated as:
Generator Rated MVA
Generator FLA = ------------------------------------------------------------------------------------------------------------3 × Rated Generator Phase-Phase Voltage
(EQ 5.11)
Negative sequence overcurrent maximum time defines the maximum time that any value
of negative sequence current in excess of the pickup value will be allowed to persist before
a trip is issued. The reset rate provides a thermal memory of previous unbalance
conditions. It is the linear reset time from the threshold of trip.
Note
Unusually high negative sequence current levels may be caused by incorrect phase CT
wiring.
808791A2.CDR
FIGURE 5–3: Negative-Sequence Inverse Time Curves
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
5–37
CHAPTER 5: SETPOINTS
5.6.7
Ground Overcurrent
PATH: SETPOINTS ZV S5 CURRENT ELEM. ZV GROUND OVERCURRENT
1 GROUND
OVERCURRENT
GROUND OVERCURRENT
ALARM: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN ALARM
RELAYS (2-5): ---5
Range: Any combination of Relays 2 to
5
MESSAGE
GROUND O/C ALARM
PICKUP: 0.20 x CT
Range: 0.05 to 20.00 × CT in steps of
0.01
MESSAGE
GROUND O/C ALARM
DELAY: 0 cycles
Range: 0 to 100 cycles in steps of 1
MESSAGE
GROUND OVERCURRENT
ALARM EVENTS: Off
Range: On, Off
MESSAGE
GROUND OVERCURRENT
TRIP: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN TRIP
RELAYS (1-4): 1---
Range: Any combination of Relays 1 to
4
MESSAGE
GROUND O/C TRIP
PICKUP: 0.20 x CT
Range: 0.05 to 20.00 × CT in steps of
0.01
MESSAGE
CURVE SHAPE:
ANSI Extremely Inv.
Range: see Table 5–1: 489 Overcurrent
Curve Types on page –29.
MESSAGE
Range: 0 to 65535 ms. Seen only if
FLEXCURVE TRIP TIME
CURVE SHAPE is Flexcurve
AT 1.03 x PU: 65535 ms
MESSAGE
Range: 0 to 65535 ms. Seen only if
FLEXCURVE TRIP TIME
CURVE SHAPE is Flexcurve
AT 1.05 x PU: 65535 ms
[Z]
↓
MESSAGE
Range: 0 to 65535 ms. Seen only if
FLEXCURVE TRIP TIME
CURVE SHAPE is Flexcurve
AT 20.0 x PU: 65535 ms
MESSAGE
OVERCURRENT CURVE
MULTIPLIER: 1.00
Range: 0.00 to 1000.00 in steps of 0.01
MESSAGE
OVERCURRENT CURVE
RESET: Instantaneous
Range: Instantaneous, Linear
The 489 ground overcurrent feature consists of both an alarm and a trip element. The
magnitude of measured ground current is used to time out against the definite time alarm
or inverse time curve trip. The 489 inverse time curve for this element may be either ANSI,
IEC, or GE Type IAC standard curve shapes. This allows for simplified coordination with
downstream devices. If however, none of these curves shapes is adequate, the FlexCurve™
may be used to customize the inverse time curve characteristics. If the Ground CT is
selected as “None”, the ground overcurrent protection is disabled.
Note
5–38
The pickup level for the ground current elements is programmable as a multiple of the
CT. The 50:0.025 CT is intended for very sensitive detection of ground faults and its
nominal CT rating for the 489 is 50:0.025.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
For example, if the ground CT is 50:0.025, a pickup of 0.20 would be 0.20 × 50 = 10 A
primary. If the ground CT is 50:0.025, a pickup of 0.05 would be 0.05 × 50 = 2.5 A primary.
5.6.8
Phase Differential
PATH: SETPOINTS ZV S5 CURRENT ELEM. ZV PHASE DIFFERENTIAL
1 PHASE
DIFFERENTIAL
PHASE DIFFERENTIAL
TRIP: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN TRIP
RELAYS (1-4): 1---
Range: Any combination of Relays 1 to
4
MESSAGE
DIFFERENTIAL TRIP
MIN. PICKUP: 0.10 x
Range: 0.05 to 1.00 × CT in steps of
0.01
MESSAGE
DIFFERENTIAL TRIP
SLOPE 1: 10%
Range: 1 to 100% in steps of 1
MESSAGE
DIFFERENTIAL TRIP
SLOPE 2: 20%
Range: 1 to 100% in steps of 1
MESSAGE
DIFFERENTIAL TRIP
DELAY: 0 cycles
Range: 0 to 100 cycles in steps of 1
[Z]
The 489 differential element consists of the well known, dual slope, percent restraint
characteristic. A differential signal is derived from the phasor sum of the currents on either
side of the machine. A restraint signal is derived from the average of the magnitudes of
these two currents. An internal flag (DIFF) is asserted when the differential signal crosses
the operating characteristic as defined by the magnitude of the restraint signal. The DIFF
flag produces a relay operation.
External faults near generators typically result in very large time constants of dc
components in the fault currents. This creates a real danger of CT saturation.
The external fault currents will be large and the CTs will initially reproduce the fault current
without distortion. Consequently the relay will see a large restraint signal coupled with a
small differential signal. This condition is used as an indication of the possible onset of ac
saturation of the CTs.
Magnetizing Inrush current due to the energizing of a step-up transformer or a sudden
change of load, could cause a large dc offset on even very small currents that would
saturate poor quality or mismatched CTs within a few power system cycles.
In order to provide additional security against maloperations during these events, an
internal flag, SC, is set when either an ac or a dc saturation condition is indicated. Once the
SC flag has been set, a comparison of the phase angles of the currents on either side of the
generator is carried out. An external fault is inferred if the phase comparison indicates
both currents are flowing in the same direction. An internal fault is inferred if the phase
comparison indicates that the currents are flowing in opposite directions. In this case an
internal flag, DIR, is set.
If the SC flag is not set, then the relay will operate for a DIFF flag alone. If the SC flag is set
then the directional flag supervises the differential flag. The requirement for both the DIFF
flag and the DIR flag during the period where CT saturation is likely therefore enhances the
security of the scheme.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
5–39
CHAPTER 5: SETPOINTS
The differential element for phase A will operate when:
I operate > k × I restraint
(EQ 5.12)
I operate = I A + I a = operate current
(EQ 5.13)
IA + Ia
I restraint = -------------------= restraint current
2
(EQ 5.14)
k = characteristic slope of the differential element in percent
k = Slope1 if I R < 2 × CT ; k = Slope2 if I R ≥ 2 × CT
(EQ 5.15)
IA = phase current measured at the output CT
(EQ 5.16)
Ia = phase current measured at the neutral end CT
(EQ 5.17)
where the following hold:
Differential elements for phase B and phase C operate in the same manner.
1
0.8
0.7
OPERATE
REGION
0.6
Slope 2 = 20%
0.5
0.4
0.3
0.2
Slope 1 = 10%
I
OPERATE
(multiples of CT)
0.9
Minimum Pickup = 0.10 x CT
0.1
0
0
0.5
1
1.5
2
2.5
3
3.5
4
I RESTRAINT (multiples of CT)
4.5
5
808790A2.CDR
FIGURE 5–4: Differential Elements
5.6.9
Ground Directional
PATH: SETPOINTS ZV S5 CURRENT ELEM. ZV GROUND DIRECTIONAL
1 GROUND
DIRECTIONAL
5–40
SUPERVISE WITH
DIGITAL INPUTS: Yes
Range: Yes, No.
MESSAGE
GROUND DIRECTIONAL
MTA: 0°
Range: 0°, 90°, 180°, 270°
MTA = Maximum Torque Angle
MESSAGE
GROUND DIRECTIONAL
ALARM: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN ALARM
RELAYS (2-5): ---5
Range: Any combination of Relays 2 to
5
MESSAGE
GROUND DIR. ALARM
PICKUP: 0.05 x CT
Range: 0.05 to 20.00 × CT in steps of
0.01
[Z]
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
Note
MESSAGE
GROUND DIR. ALARM
DELAY: 3.0 sec.
Range: 0.1 to 120.0 sec. in steps of 0.1
MESSAGE
GROUND DIR. ALARM
EVENTS: Off
Range: On, Off
MESSAGE
GROUND DIRECTIONAL
TRIP: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN TRIP
RELAYS (1-4): 1---
Range: Any combination of Relays 1 to
4
MESSAGE
GROUND DIR. TRIP
PICKUP: 0.05 x CT
Range: 0.05 to 20.00 × CT in steps of
0.01
MESSAGE
GROUND DIR. TRIP
DELAY: 3.0 sec.
Range: 0.1 to 120.0 sec. in steps of 0.1
The SUPERVISE WITH DIGITAL INPUTS setpoint is seen only if a digital input assigned to
Ground Switch Status.
The 489 detects ground directional by using two measurement quantities: V0 and I0. The
angle between these quantities determines if a ground fault is within the generator or not.
This function should be coordinated with the 59GN element (95% stator ground protection)
to ensure proper operation of the element. Particularly, this element should be faster. This
element must use a core balance CT to derive the I0 signal. Polarity is critical in this
element. The protection element is blocked for neutral voltages, V0, below 2.0 V secondary.
Note
The pickup level for the ground current elements is programmed as a multiple of ground
CT. The 50:0.025 CT is intended for measuring very small ground fault currents when
connected to a sensitive ground CT having the same ratio.
For example, a pickup to 0.2xCT translates into 0.2x0.0025A = 0.5mA secondary on the
terminals of the sensitive ground CT, with a relay measuring 0.2x5A = 1 A primary. A pickup
setting of 0.05xCT would lead to 0.05x0.0025A = 0.125mA secondary, or 0.05x5A =0. 25A
primary current.
It is strongly recommended not to exceed the CT continuous rating of 150mA for long
periods of time during tests.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
5–41
CHAPTER 5: SETPOINTS
AUXILIARY
CONTACT
GROUNDING SWITCH
C(B)
C(B)
A
59G
B(C)
A
B(C)
I0
TO Vneutral OF EACH 489
50:0.025
TO 50:0.025
GROUND
INPUTS
808812A3.CDR
FIGURE 5–5: Ground Directional Detection
5.6.10 High-Set Phase OC
PATH: SETPOINTS ZV S5 CURRENT ELEM. ZV HIGH-SET PHASE OVERCURRENT
HIGH-SET PHASE O/C
TRIP: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN TRIP
RELAYS (1-4): 1---
Range: Any combination of Relays 1 to
4
MESSAGE
HIGH-SET PHASE O/C
PICKUP: 5.00 x CT
Range: 0.15 to 20.00 x CT in steps of
0.01
MESSAGE
HIGH-SET PHASE O/C
DELAY: 1.00 s
Range: 0.00 to 100.00 s in steps of 0.01
1 HIGH-SET
[Z]
PHASE OVERCURRENT
If any individual phase current exceeds the pickup level for the specified trip time a trip will
occur if the feature is enabled. The element operates in both online and offline conditions.
This element can be used as a backup feature to other protection elements. In situations
where generators are connected in parallel this element would be set above the maximum
current contribution from the generator on which the protection is installed. With this
setting, the element would provide proper selective tripping. The basic operating time of
the element with no time delay is 50 ms at 50/60 Hz.
5–42
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
5.7
S6 Voltage Elements
5.7.1
Undervoltage
PATH: SETPOINTS ZV S6 VOLTAGE ELEM. Z UNDERVOLTAGE
1 UNDERVOLTAGE
UNDERVOLTAGE
ALARM: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN ALARM
RELAYS (2-5): ---5
Range: Any combination of Relays 2 to
5
MESSAGE
UNDERVOLTAGE ALARM
PICKUP: 0.85 x Rated
Range: 0.50 to 0.99 × Rated in steps of
0.01
MESSAGE
UNDERVOLTAGE ALARM
DELAY: 3.0 s
Range: 0.2 to 120.0 s in steps of 0.1
MESSAGE
UNDERVOLTAGE ALARM
EVENTS: Off
Range: On, Off
MESSAGE
UNDERVOLTAGE
TRIP: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN TRIP
RELAYS (1-4): 1---
Range: Any combination of Relays 1 to
4
MESSAGE
UNDERVOLTAGE TRIP
PICKUP: 0.80 x Rated
Range: 0.50 to 0.99 × Rated in steps of
0.01
MESSAGE
UNDERVOLTAGE TRIP
DELAY: 1.0 s
Range: 0.2 to 10.0 s in steps of 0.1
MESSAGE
UNDERVOLTAGE CURVE
RESET RATE: 1.4 s
Range: 0.0 to 999.9 s in steps of 0.1
MESSAGE
UNDERVOLTAGE CURVE
ELEMENT: Curve
Range: Curve, Definite Time
[Z]
The undervoltage elements may be used for protection of the generator and/or its
auxiliary equipment during prolonged undervoltage conditions. They are active only when
the generator is online. The alarm element is definite time and the trip element can be
definite time or a curve. When the magnitude of the average phase-phase voltage is less
than the pickup × the generator rated phase-phase voltage, the element will begin to time
out. If the time expires, a trip or alarm will occur.
The curve reset rate is a linear reset time from the threshold of trip. If the VT type is
selected as None, VT fuse loss is detected, or the magnitude of I1< 7.5% CT, the
undervoltage protection is disabled. The pickup levels are insensitive to frequency over the
range of 5 to 90 Hz.
The formula for the undervoltage curve is:
D
- , when V < V pickup
T = --------------------------------1 – V ⁄ V pickup
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
(EQ 5.18)
5–43
CHAPTER 5: SETPOINTS
where: T = trip time in seconds
D = UNDERVOLTAGE TRIP DELAY setpoint
V = actual average phase-phase voltage
Vpickup= UNDERVOLTAGE TRIP PICKUP setpoint
1000
3
Time to Trip (seconds)
100
1
TIME DELAY SETTING
10
0.3
10
1
0.1
0
0.2
0.4
0.6
0.8
1
Multiples of Undervoltage Pickup
808742A1.CDR
FIGURE 5–6: Undervoltage Curves
5.7.2
Overvoltage
PATH: SETPOINTS ZV S6 VOLTAGE ELEM. ZV OVERVOLTAGE
1 OVERVOLTAGE
5–44
OVERVOLTAGE
ALARM: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN ALARM
RELAYS (2-5): ---5
Range: Any combination of Relays 2 to
5
MESSAGE
OVERVOLTAGE ALARM
PICKUP: 1.15 x Rated
Range: 1.01 to 1.50 × Rated in steps of
0.01
MESSAGE
OVERVOLTAGE ALARM
DELAY: 3.0 s
Range: 0.2 to 120.0 s in steps of 0.1
MESSAGE
OVERVOLTAGE ALARM
EVENTS: Off
Range: On, Off
MESSAGE
OVERVOLTAGE
TRIP: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN TRIP
RELAYS (1-4): 1---
Range: Any combination of Relays 1 to
4
MESSAGE
OVERVOLTAGE TRIP
PICKUP: 1.20 x Rated
Range: 1.01 to 1.50 × Rated in steps of
0.01
MESSAGE
OVERVOLTAGE TRIP
DELAY: 1.0 s
Range: 0.1 to 10.0 s in steps of 0.1
[Z]
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
MESSAGE
OVERVOLTAGE CURVE
RESET RATE: 1.4 s
Range: 0.0 to 999.9 s in steps of 0.1
MESSAGE
OVERVOLTAGE CURVE
ELEMENT: Curve
Range: Curve, Definite Time
The overvoltage elements may be used for protection of the generator and/or its auxiliary
equipment during prolonged overvoltage conditions. They are always active (when the
generator is offline or online). The alarm element is definite time and the trip element can
be either definite time or an inverse time curve. When the average of the measured phasephase voltages rises above the pickup level x the generator rated phase-phase voltage,
the element will begin to time out. If the time expires, a trip or alarm will occur. The reset
rate is a linear reset time from the threshold of trip. The pickup levels are insensitive to
frequency over the range of 5 to 90 Hz.
The formula for the curve is:
D
- , when V > V pickup
T = -------------------------------------( V ⁄ V pickup ) – 1
(EQ 5.19)
where: T = trip time in seconds
D = OVERVOLTAGE TRIP DELAY setpoint
V = actual average phase-phase voltage
Vpickup= OVERVOLTAGE TRIP PICKUP setpoint
100
10
10
3
1
1
0.3
TIME DELAY SETTING
Time to Trip (seconds)
1000
0.1
0.1
1
1.1
1.2
1.3
1.4
1.5
1.6
1.7
1.8
1.9
2
Multiples of Overvoltage Pickup
808741A1.CDR
FIGURE 5–7: Overvoltage Curves
5.7.3
Volts/Hertz
PATH: SETPOINTS ZV S6 VOLTAGE ELEM. ZV VOLTS/HERTZ
1 VOLTS/HERTZ
[Z]
MESSAGE
VOLTS/HERTZ
ALARM: Off
Range: Off, Latched, Unlatched
ASSIGN ALARM
RELAYS (2-5): ---5
Range: Any combination of Relays 2 to
5
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
5–45
CHAPTER 5: SETPOINTS
MESSAGE
VOLTS/HERTZ ALARM
PICKUP: 1.00 xNominal
Range: 0.50 to 1.99 ×Nominal in steps
of 0.01
MESSAGE
VOLTS/HERTZ ALARM
DELAY: 3.0 s
Range: 0.1 to 150.0 s in steps of 0.1
MESSAGE
VOLTS/HERTZ ALARM
EVENTS: Off
Range: On, Off
MESSAGE
VOLTS/HERTZ
TRIP: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN TRIP
RELAYS (1-4): 1---
Range: Any combination of Relays 1 to
4
MESSAGE
VOLTS/HERTZ TRIP
PICKUP: 1.00 xNominal
Range: 0.50 to 1.99 ×Nominal in steps
of 0.01
MESSAGE
VOLTS/HERTZ TRIP
DELAY: 1.0 s
Range: 0.1 to 150.0 s in steps of 0.1
MESSAGE
VOLTS/HERTZ CURVE
RESET RATE: 1.4 s
Range: 0.0 to 999.9 s in steps of 0.1
MESSAGE
VOLTS/HERTZ TRIP
ELEMENT: Curve #1
Range: Curve #1, Curve #2, Curve #3,
Definite Time
The Volts Per Hertz elements may be used generator and unit transformer protection. They
are active as soon as the magnitude and frequency of Vab is measurable. The alarm
element is definite time; the trip element can be definite time or a curve. Once the V/Hz
measurement Vab exceeds the pickup level for the specified time, a trip or alarm will occur.
The reset rate is a linear reset time from the threshold of trip and should be set to match
cooling characteristics of the protected equipment. The measurement of V/Hz will be
accurate through a frequency range of 5 to 90 Hz. Settings less than 1.00 only apply for
special generators such as short circuit testing machines.
The formula for Volts/Hertz Curve 1 is:
D
V
T = ------------------------------------------------------------------- , when --- > Pickup
2
F
V
⁄
F
⎛ --------------------------------------------------⎞ – 1
⎝ ( V nom ⁄ F s ) × Pickup⎠
(EQ 5.20)
where: T = trip time in seconds
D = VOLTS/HERTZ TRIP DELAY setpoint
V = RMS measurement of Vab
F = frequency of Vab
VNOM = generator voltage setpoint
FS = generator frequency setpoint
Pickup = VOLTS/HERTZ TRIP PICKUP setpoint
5–46
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
The V/Hz Curve 1 trip curves are shown below for delay settings of 0.1, 0.3, 1, 3, and 10
seconds.
1000
10
10
1
3
1
0.1
0.3
TIME DELAY SETTING
Time to Trip (seconds)
100
0.1
0.01
1.00
1.20
1.40
1.60
1.80
2.00
Multiples of Volts/Hertz Pickup
808743A1-X1.CDR
The formula for Volts/Hertz Curve 2 is:
D
V
T = ----------------------------------------------------------- , when --- > Pickup
F
V⁄F
-------------------------------------------------–1
( V nom ⁄ F s ) × Pickup
(EQ 5.21)
where: T = trip time in seconds
D = VOLTS/HERTZ TRIP DELAY setpoint
V = RMS measurement of Vab
F = frequency of Vab
VNOM = generator voltage setpoint
FS = generator frequency setpoint
Pickup = VOLTS/HERTZ TRIP PICKUP setpoint
The V/Hz Curve 2 trip curves are shown below for delay settings of 0.1, 0.3, 1, 3, and 10
seconds.
1000
10
10
3
1
1
0.3
0.1
1.00
TIME DELAY SETTING
Time to Trip (seconds)
100
0.1
1.20
1.40
1.60
1.80
2.00
Multiples of Volts/Hertz Pickup
808743A1-X2.CDR
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
5–47
CHAPTER 5: SETPOINTS
The formula for Volts/Hertz Curve 3 is:
D
V
T = ----------------------------------------------------------------------- , when --- > Pickup
0.5
F
V
⁄
F
⎛ --------------------------------------------------⎞ – 1
⎝ ( V nom ⁄ F s ) × Pickup⎠
(EQ 5.22)
where: T = trip time in seconds
D = VOLTS/HERTZ TRIP DELAY setpoint
V = RMS measurement of Vab
F = frequency of Vab
VNOM = generator voltage setpoint
FS = generator frequency setpoint
Pickup = VOLTS/HERTZ TRIP PICKUP setpoint
The V/Hz Curve 3 trip curves are shown below for delay settings of 0.1, 0.3, 1, 3, and 10
seconds.
10000
100
10
10
3
1
1
0.3
TIME DELAY SETTING
Time to Trip (seconds)
1000
0.1
0.1
1.00
1.20
1.40
1.60
1.80
2.00
Multiples of Voltz/Hertz Pickup
808743A1-X3.CDR
Volts/Hertz is calculated per unit as follows:
Note
voltage ⁄ rated phase-phase voltageVolts/Hertz = phase-phase
---------------------------------------------------------------------------------------------------------------------------frequency ⁄ rated frequency
5.7.4
Phase Reversal
PATH: SETPOINTS ZV S6 VOLTAGE ELEM. ZV PHASE REVERSAL
1 PHASE
REVERSAL
[Z]
MESSAGE
PHASE REVERSAL
TRIP: Off
Range: Off, Latched, Unlatched
ASSIGN TRIP
RELAYS (1-4): 1---
Range: Any combination of Relays 1 to
4
The 489 can detect the phase rotation of the three phase voltages. A trip will occur within
200 ms if the Phase Reversal feature is turned on, the generator is offline, each of the
phase-phase voltages is greater than 50% of the generator rated phase-phase voltage
5–48
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
and the phase rotation is not the same as the setpoint. Loss of VT fuses cannot be
detected when the generator is offline and could lead to maloperation of this element. If
the VT type is selected as “None”, the phase reversal protection is disabled.
5.7.5
Underfrequency
PATH: SETPOINTS ZV S6 VOLTAGE ELEM. ZV UNDERFREQUENCY
1 UNDERFREQUENCY
BLOCK UNDERFREQUENCY
FROM ONLINE: 1 s
Range: 0 to 5 s in steps of 1
MESSAGE
VOLTAGE LEVEL
CUTOFF: 0.50 x Rated
Range: 0.50 to 0.99 × Rated in steps of
0.01
MESSAGE
UNDERFREQUENCY
ALARM: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN ALARM
RELAYS (2-5): ---5
Range: Any combination of Relays 2 to
5
MESSAGE
UNDERFREQUENCY
ALARM LEVEL: 59.50 Hz
Range: 20.00 to 60.00 Hz in steps of
0.01
MESSAGE
UNDERFREQUENCY
ALARM DELAY: 5.0 s
Range: 0.1 to 5000.0 s in steps of 0.1
MESSAGE
UNDERFREQUENCY
ALARM EVENTS: Off
Range: On, Off
MESSAGE
UNDERFREQUENCY
TRIP: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN TRIP
RELAYS (1-4): 1---
Range: Any combination of Relays 1 to
4
MESSAGE
UNDERFREQUENCY
TRIP LEVEL1: 59.50 Hz
Range: 20.00 to 60.00 Hz in steps of
0.01
MESSAGE
UNDERFREQUENCY
TRIP DELAY1: 60.0 s
Range: 0.1 to 5000.0 s in steps of 0.1
MESSAGE
UNDERFREQUENCY
TRIP LEVEL2: 58.00 Hz
Range: 20.00 to 60.00 Hz in steps of
0.01
MESSAGE
UNDERFREQUENCY
TRIP DELAY2: 30.0 s
Range: 0.1 to 5000.0 s in steps of 0.1
[Z]
It may be undesirable to enable the underfrequency elements until the generator is online.
This feature can be blocked until the generator is online and the block time expires. From
that point forward, the underfrequency trip and alarm elements will be active. A value of
zero for the block time indicates that the underfrequency protection is active as soon as
voltage exceeds the cutoff level (programmed as a multiple of the generator rated phasephase voltage). Frequency is then measured. Once the frequency of Vab is less than the
underfrequency setpoints, for the period of time specified, a trip or alarm will occur. There
are dual level and time setpoints for the trip element.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
5–49
CHAPTER 5: SETPOINTS
5.7.6
Overfrequency
PATH: SETPOINTS ZV S6 VOLTAGE ELEM. ZV OVERFREQUENCY
1 OVERFREQUENCY
BLOCK OVERFREQUENCY
FROM ONLINE: 1 s
Range: 0 to 5 s in steps of 1
MESSAGE
VOLTAGE LEVEL
CUTOFF: 0.50 x Rated
Range: 0.50 to 0.99 × Rated in steps of
0.01
MESSAGE
OVERFREQUENCY
ALARM: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN ALARM
RELAYS (2-5): ---5
Range: Any combination of Relays 2 to
5
MESSAGE
OVERFREQUENCY
ALARM LEVEL: 60.50 Hz
Range: 25.01 to 70.00 Hz in steps of
0.01
MESSAGE
OVERFREQUENCY
ALARM DELAY: 5.0 s
Range: 0.1 to 5000.0 s in steps of 0.1
MESSAGE
OVERFREQUENCY
ALARM EVENTS: Off
Range: On, Off
MESSAGE
OVERFREQUENCY
TRIP: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN TRIP
RELAYS (1-4): 1---
Range: Any combination of Relays 1 to
4
MESSAGE
OVERFREQUENCY
TRIP LEVEL1: 60.50 Hz
Range: 25.01 to 70.00 Hz in steps of
0.01
MESSAGE
OVERFREQUENCY
TRIP DELAY1: 60.0 s
Range: 0.1 to 5000.0 s in steps of 0.1
MESSAGE
OVERFREQUENCY
TRIP LEVEL2: 62.00 Hz
Range: 25.01 to 70.00 Hz in steps of
0.01
MESSAGE
OVERFREQUENCY
TRIP DELAY2: 30.0 s
Range: 0.1 to 5000.0 s in steps of 0.1
[Z]
It may be undesirable to enable the overfrequency elements until the generator is online.
This feature can be blocked until the generator is online and the block time expires. From
that point forward, the overfrequency trip and alarm elements will be active. A value of
zero for the block time indicates that the overfrequency protection is active as soon as
voltage exceeds the cutoff level (programmed as a multiple of the generator rated phasephase voltage). Frequency is then measured. Once the frequency of Vab exceeds the
overfrequency setpoints, for the period of time specified, a trip or alarm will occur. There
are dual level and time setpoints for the trip element.
5–50
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
5.7.7
Neutral Overvoltage
PATH: SETPOINTS ZV S6 VOLTAGE ELEM. ZV NEUTRAL O/V (FUNDAMENTAL)
1 NEUTRAL O/V
(FUNDAMENTAL)
Note
SUPERVISE WITH
DIGITAL INPUT: No
Range: Yes, No
MESSAGE
NEUTRAL OVERVOLTAGE
ALARM: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN ALARM
RELAYS (2-5): ---5
Range: Any combination of Relays 2 to
5
MESSAGE
NEUTRAL O/V ALARM
LEVEL: 3.0 Vsec
Range: 2.0 to 100.0 Vsec in steps of 0.1
MESSAGE
NEUTRAL OVERVOLTAGE
ALARM DELAY: 1.0 s
Range: 0.1 to 120.0 s in steps of 0.1
MESSAGE
NEUTRAL OVERVOLTAGE
ALARM EVENTS: Off
Range: On, Off
MESSAGE
NEUTRAL OVERVOLTAGE
TRIP: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN TRIP
RELAYS (1-4): 1---
Range: Any combination of Relays 1 to
4
MESSAGE
NEUTRAL O/V TRIP
LEVEL: 5.0 Vsec
Range: 2.0 to 100.0 Vsec in steps of 0.1
MESSAGE
NEUTRAL OVERVOLTAGE
TRIP DELAY: 1.0 s
Range: 0.1 to 120.0 s in steps of 0.1
MESSAGE
NEUTRAL O/V CURVE
RESET RATE: 0.0
Range: 0.0 to 999.9 in steps of 0.1
MESSAGE
NEUTRAL O/V TRIP
ELEM.: Time
Range: Curve, Definite Time
[Z]
The SUPERVISE WITH DIGITAL INPUT setpoint is seen only if a digital input assigned to
Ground Switch Status.
The neutral overvoltage function responds to fundamental frequency voltage at the
generator neutral. It provides ground fault protection for approximately 95% of the stator
windings. 100% protection is provided when this element is used in conjunction with the
Neutral Undervoltage (3rd harmonic) function. The alarm element is definite time and the
trip element can be either definite time or an inverse time curve. When the neutral voltage
rises above the pickup level the element will begin to time out. If the time expires an alarm
or trip will occur. The reset rate is a linear reset time from the threshold of trip. The alarm
and trip levels are programmable in terms of Neutral VT secondary voltage.
The formula for the curve is:
D
T = --------------------------------------( V ⁄ V pickup ) – 1
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
when V > V pickup
(EQ 5.23)
5–51
CHAPTER 5: SETPOINTS
where
T = trip time in seconds
D = NEUTRAL OVERVOLTAGE TRIP DELAY setpoint
V = neutral voltage
Vpickup = NEUTRAL O/V TRIP LEVEL setpoint
The neutral overvoltage curves are shown below. Refer to Appendix B for Application
Notes.
100
10
10
3
1
1
0.3
TIME DELAY SETTING
Time to Trip (seconds)
1000
0.1
0.1
1
1.1
1.2
1.3
1.4
1.5
1.6
1.7
1.8
1.9
2
Multiples of Overvoltage Pickup
808741A1.CDR
FIGURE 5–8: Neutral Overvoltage Curves
AUXILIARY CONTACT
TO DIGITAL INPUT FOR
NEUTRAL O/V SUPERVISION
GROUNDING SWITCH
C(B)
C(B)
A
59G
B(C)
GENERATOR 1
A
B(C)
GENERATOR 2
808816A3.CDR
TO Vneutral OF EACH 489
FIGURE 5–9: Neutral Overvoltage Detection
Note
5–52
If the ground directional element is enabled, the Neutral Overvoltage element should be
coordinated with it. In cases of paralleled generator grounds through the same point, with
individual ground switches, per sketch below, it is recommended to use a ground switch
status function to prevent maloperation of the element.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
5.7.8
Neutral Undervoltage
PATH: SETPOINTS ZV S6 VOLTAGE ELEM. ZV NEUTRAL U/V (3RD HARMONIC)
1 NEUTRAL U/V
(3rd HARMONIC)
Note
LOW POWER BLOCKING
LEVEL: 0.05 x Rated
Range: 0.02 to 0.99 × Rated MW in
steps of 0.01
MESSAGE
LOW VOLTAGE BLOCKING
LEVEL: 0.75 x Rated
Range: 0.50 to 1.00 × Rated in steps of
0.01
MESSAGE
NEUTRAL UNDERVOLTAGE
ALARM: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN ALARM
RELAYS (2-5): ---5
Range: Any combination of Relays 2 to
5
MESSAGE
NEUTRAL U/V ALARM
LEVEL: 0.5 Vsec
Range: 0.5 to 20.0 Vsec in steps of 0.1
MESSAGE
NEUTRAL UNDERVOLTAGE
ALARM DELAY: 30 s
Range: 5 to 120 s in steps of 1
MESSAGE
NEUTRAL UNDERVOLTAGE
ALARM EVENTS: Off
Range: On, Off
MESSAGE
NEUTRAL UNDERVOLTAGE
TRIP: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN TRIP
RELAYS (1-4): 1---
Range: Any combination of Relays 1 to
4
MESSAGE
NEUTRAL U/V TRIP
LEVEL: 1.0 Vsec
Range: 0.5 to 20.0 Vsec in steps of 0.1
MESSAGE
NEUTRAL UNDERVOLTAGE
TRIP DELAY: 30 s
Range: 5 to 120 s in steps of 1
[Z]
The LOW POWER BLOCKING LEVEL , NEUTRAL U/V ALARM LEVEL , and NEUTRAL U/V TRIP
LEVEL setpoints are seen only if the S2 SYSTEM SETUP ZV VOLTAGE ZV VT CONNECTION
setpoint is “Delta”
The neutral undervoltage function responds to 3rd harmonic voltage measured at the
generator neutral and output terminals. When used in conjunction with the Neutral
Overvoltage (fundamental frequency) function, it provides 100% ground fault protection of
the stator windings.
For Wye connected VTs:
Since the amount of third harmonic voltage that appears in the neutral is both load and
machine dependent, the protection method of choice is an adaptive method. If the phase
VT connection is wye, the following formula is used to create an adaptive neutral
undervoltage pickup level based on the amount of third harmonic that appears at the
generator terminals.
V N3
----------------------------------- ≤ 0.15 which simplifies to V P3 ≥ 17V N3
( V P3 ⁄ 3 ) + V N3
(EQ 5.24)
The 489 tests the following permissives prior to testing the basic operating equation to
ensure that VN3’ should be of a measurable magnitude for an unfaulted generator:
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
5–53
CHAPTER 5: SETPOINTS
Neutral VT Ratio
V P3 ′ > 0.25 V and V P3 ′ ≥ Threshold × 17 × ---------------------------------------Phase VT Ratio
(EQ 5.25)
where: VN3 = magnitude of the third harmonic voltage at generator neutral;
VP3 = magnitude of the third harmonic voltage at the generator terminals
VP3´ = VT secondary magnitude of the third harmonic voltage measured at the
generator terminals;
VN3´ = VT sec. magnitude of 3rd harmonic voltage at generator neutral;
Threshold = 0.15 V for the alarm element and 0.1875 V for the trip element
For Open Delta connected VTs:
If the phase VT connection is open delta, it is not possible to measure the third harmonic
voltages at the generator terminals and a simple third harmonic neutral undervoltage
element is used. The level is programmable in terms of Neutral VT secondary voltage. In
order to prevent nuisance tripping at low load or low generator voltages, two blocking
functions are provided. They apply to both the alarm and trip functions. When used as a
simple undervoltage element, settings should be based on measured 3rd harmonic
neutral voltage of the healthy machine.
Note
5–54
This method of using 3rd harmonic voltages to detect stator ground faults near the
generator neutral has proved feasible on generators with unit transformers. Its usefulness
in other generator applications is unknown.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
5.7.9
Loss of Excitation
PATH: SETPOINTS ZV S6 VOLTAGE ELEM. ZV LOSS OF EXCITATION
1 LOSS OF
EXCITATION
Note
ENABLE VOLTAGE
SUPERVISION: Yes
Range: Yes, No
MESSAGE
VOLTAGE
LEVEL: 0.70 x Rated
Range: 0.70 to 1.00 × Rated in steps of
0.01
MESSAGE
CIRCLE 1
TRIP: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN CIRCLE 1 TRIP
RELAYS (1-4): 1---
Range: Any combination of Relays 1 to
4
MESSAGE
CIRCLE 1
DIAMETER: 25.0 Ωsec
Range: 2.5 to 300.0 Ωsec in steps of 0.1
MESSAGE
CIRCLE 1
OFFSET: 2.5 Ωsec
Range: 1.0 to 300.0 Ωsec in steps of 0.1
MESSAGE
CIRCLE 1 TRIP
DELAY: 5.0 s
Range: 0.1 to 10.0 s in steps of 0.1
MESSAGE
CIRCLE 2
TRIP: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN CIRCLE 2 TRIP
RELAYS (1-4): 1---
Range: Any combination of Relays 1 to
4
MESSAGE
CIRCLE 2
DIAMETER: 35.0 Ωsec
Range: 2.5 to 300.0 Ωsec in steps of 0.1
MESSAGE
CIRCLE 2
OFFSET: 2.5 Ωsec
Range: 1.0 to 300.0 Ωsec in steps of 0.1
MESSAGE
CIRCLE 2 TRIP
DELAY: 5.0 s
Range: 0.1 to 10.0 s in steps of 0.1
[Z]
The VOLTAGE LEVEL setpoint is seen only if ENABLE VOLTAGE SUPERVISION is set to “Yes”.
Loss of excitation is detected with an impedance element. When the impedance falls
within the impedance circle for the specified delay time, a trip will occur if it is enabled.
Circles 1 and/or 2 can be tuned to a particular system. The larger circle diameter should be
set to the synchronous reactance of the generator, xd, and the circle offset to the
generator transient reactance x’d / 2. Typically the smaller circle (if used) is set to minimum
time with a diameter set to 0.7xd and an offset of x’d / 2. This feature is blocked if voltage
supervision is enabled and the generator voltage is above the VOLTAGE LEVEL setpoint.
The trip feature is supervised by minimum current of 0.05 × CT. Note that the Loss of
Excitation element will be blocked if there is a VT fuse failure or if the generator is offline.
Also, it uses output CT inputs.
The secondary phase-phase loss of excitation impedance is defined as:
V AB
- = M loe ∠θ loe
Z loe = ------------IA – IB
(EQ 5.26)
where: Zloe = secondary phase-to-phase loss of excitation impedance
Mloe∠θloe= Secondary impedance phasor (magnitude and angle)
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
5–55
CHAPTER 5: SETPOINTS
All relay quantities are in terms of secondary impedances. The formula to convert primary
impedance quantities to secondary impedance quantities is provided below.
Z primary × CT Ratio
Z sec ondary = ----------------------------------------------VT Ratio
(EQ 5.27)
where: Zprimary= primary ohms impedance;
CT Ratio = programmed CT ratio,
if CT ratio is 1200:5 use a value of 1200 / 5 = 240;
VT Ratio = programmed VT ratio, if VT ratio is 100:1 use a value of 100
FIGURE 5–10: Loss of Excitation R-X Diagram
5.7.10 Distance Element
PATH: SETPOINTS ZV S6 VOLTAGE ELEM. ZV DISTANCE ELEMENT
1 DISTANCE
ELEMENT
5–56
STEP UP TRANSFORMER
SETUP: None
Range: None, Delta/Wye
MESSAGE
FUSE FAILURE
SUPERVISION: On
Range: On, Off
MESSAGE
ZONE #1
TRIP: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN ZONE #1 TRIP
RELAYS (1-4): 1---
Range: Any combination of Relays 1 to
4
MESSAGE
ZONE #1
REACH: 10.0 Ωsec
Range: 0.1 to 500.0 Ωsec in steps of 0.1
MESSAGE
ZONE #1
ANGLE: 75°
Range: 50 to 85° in steps of 1
MESSAGE
ZONE #1 TRIP
DELAY: 0.4 s
Range: 0.0 to 150.0 s in steps of 0.1
MESSAGE
ZONE #2
TRIP: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN ZONE #2 TRIP
RELAYS (1-4): 1---
Range: Any combination of Relays 1 to
4
[Z]
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
MESSAGE
ZONE #2
REACH: 15.0 Ωsec
Range: 0.1 to 500.0 Ωsec in steps of 0.1
MESSAGE
ZONE #2
ANGLE: 75°
Range: 50 to 85° in steps of 1
MESSAGE
ZONE #2 TRIP
DELAY: 2.0 s
Range: 0.0 to 150.0 s in steps of 0.1
The distance protection function (ANSI device 21) implements two zones of mho phase-tophase distance protection (six elements total) using the conventional phase comparator
approach, with the polarizing voltage derived from the pre-fault positive sequence voltage
of the protected loop. This protection is intended as backup for the primary line protection.
The elements make use of the neutral-end current signals and the generator terminal
voltage signals (see figure below), thus providing some protection for internal and unit
transformer faults. In systems with a delta-wye transformer (DY330°), the appropriate
transformations of voltage and current signals are implemented internally to allow proper
detection of transformer high-side phase-to-phase faults. The reach setting is the positive
sequence impedance to be covered, per phase, expressed in secondary ohms. The same
transformation shown for the Loss of Excitation element can be used to calculate the
desired settings as functions of the primary-side impedances.
The elements have a basic operating time of 150 ms. A VT fuse failure could cause a
maloperation of a distance element unless the element is supervised by the VTFF element.
In order to prevent nuisance tripping the elements require a minimum phase current of
0.05 x CT.
Protection Zone 1
Protection Zone 2
Neutral End CT
52
Terminal VT
489
Relay
808740A1.CDR
FIGURE 5–11: Distance Element Setup
The 489 phase distance element is intended to provide backup protection for phase-tophase faults on the electric power system. This element uses the phase-to-phase voltage
measured at the generator terminals and phase currents measured at the neutral side of
the generator. As such this element will provide coverage for the generator step-up
transformer and will also provide a degree of protection for stator phase-to-phase faults.
The element has a offset mho characteristic as shown in FIGURE 5–12: Distance Element
Characteristics on page –59. Offset in the third quadrant is 1/8th of the forward reach to
provide better resistive fault coverage for close-in faults. The element provides a separate
measurement in three loops for AB, BC, and CA faults. There is a setting for specification of
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
5–57
CHAPTER 5: SETPOINTS
the step-up transformer connection. If this setting is chosen as “None”, then it is assumed
that the transformer is Wye-Wye connected or that there is no step-up transformer. In this
case the element will use the following operating quantities.
Element
Voltage
Current
AB
Va – Vb
Ia – Ib
BC
Vb – Vc
Ib – Ic
CA
Vc – Va
Ic – Ia
If this setting is chosen as “Delta/Wye” then it is assumed that the transformer is Yd1 or
Yd11. In this case the following operating quantities are used.
Element
Voltage
Current
AB
(Vab – Vca) / 3
3 × Ia
BC
(Vbc – Vab) / 3
3 × Ib
CA
(Vca – Vbc) / 3
3 × Ic
The first zone is typically used to provide a backup protection for a step-up transformer
and generator system bus protection (generator impedance should not be included into
reach setting). The reach is set to cover the step-up transformer impedance with some
margin, say 25%. The time delay should be coordinated with step up transformer and bus
backup protection.
The second zone reach is typically set to cover the longest transmission line or feeder
leaving the generating station. Care must be taken for possible under-reaching effects due
to the fault contribution from other lines or generators. The element is intended for backup
protection and therefore time delay should always be included. This element is typically set
to coordinate with the longest operating time of the system distance relays protecting
lines leaving station.
The measuring point of the element is defined by the location of the VT and CT as shown in
FIGURE 5–11: Distance Element Setup on page –57. Therefore, the impedance of the stepup transformer should be included and the impedance of the generator should not be
included. Care should also be taken to ensure the apparent impedance seen by the
element when the machine is operating at worst-case load and power factor does not
encroach into the operating characteristic. The reach setting is in secondary ohms. The
minimum operating time of the element is 150 ms to coordinate with VTFF operating time
(99 ms).
5–58
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
etting
Reach s
ZR
CHAPTER 5: SETPOINTS
Characteristic
angle
ZR*0.125
808838A2.CDR
FIGURE 5–12: Distance Element Characteristics
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
5–59
CHAPTER 5: SETPOINTS
5.8
S7 Power Elements
5.8.1
Power Measurement Conventions
Generation of power will be displayed on the 489 as positive watts. By convention, an
induction generator normally requires reactive power from the system for excitation. This
is displayed on the 489 as negative vars. A synchronous generator on the other hand has
its own source of excitation and can be operated with either lagging or leading power
factor. This is displayed on the 489 as positive vars and negative vars, respectively. All
power quantities are measured from the phase-phase voltage and the currents measured
at the output CTs.
^
I
1
^
I
2
^
I
3
^
I
4
FIGURE 5–13: Power Measurement Conventions
5–60
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
5.8.2
Reactive Power
PATH: SETPOINTS ZV S7 POWER ELEMENTS Z REACTIVE POWER
1 REACTIVE
POWER
BLOCK Mvar ELEMENT
FROM ONLINE: 1 s
Range: 0 to 5000 s in steps of 1
MESSAGE
REACTIVE POWER
ALARM: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN ALARM
RELAYS (2-5): ---5
Range: Any combination of Relays 2 to
5
MESSAGE
POSITIVE Mvar ALARM
LEVEL: 0.85 x Rated
Range: 0.02 to 2.01 × Rated in steps of
0.01
MESSAGE
NEGATIVE Mvar ALARM
LEVEL: 0.85 x Rated
Range: 0.02 to 2.01 × Rated in steps of
0.01
MESSAGE
POSITIVE Mvar ALARM
DELAY: 10.0 s
Range: 0.2 to 120.0 s in steps of 0.1
(lagging vars, overexcited)
MESSAGE
NEGATIVE Mvar ALARM
DELAY: 1.0 s
Range: 0.2 to 120.0 s in steps of 0.1
(leading vars, underexcited)
MESSAGE
REACTIVE POWER ALARM
EVENTS: Off
Range: On, Off
MESSAGE
REACTIVE POWER
TRIP: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN TRIP
RELAYS (1-4): 1---
Range: Any combination of Relays 1 to
4
MESSAGE
POSITIVE Mvar TRIP
LEVEL: 0.80 x Rated
Range: 0.02 to 2.01 × Rated in steps of
0.01
MESSAGE
NEGATIVE Mvar TRIP
LEVEL: 0.80 x Rated
Range: 0.02 to 2.01 × Rated in steps of
0.01
MESSAGE
POSITIVE Mvar TRIP
DELAY: 20.0 s
Range: 0.2 to 120.0 s in steps of 0.1
(lagging vars, overexcited)
MESSAGE
NEGATIVE Mvar TRIP
DELAY: 20.0 s
Range: 0.2 to 120.0 s in steps of 0.1
(leading vars, underexcited)
[Z]
In a motor/generator application, it may be desirable not to trip or alarm on reactive power
until the machine is online and the field has been applied. Therefore, this feature can be
blocked until the machine is online and adequate time has expired during which the field
had been applied. From that point forward, the reactive power trip and alarm elements will
be active. A value of zero for the block time indicates that the reactive power protection is
active as soon as both current and voltage are measured regardless of whether the
generator is online or offline. Once the 3-phase total reactive power exceeds the positive
or negative level, for the specified delay, a trip or alarm will occur indicating a positive or
negative Mvar condition. The level is programmed in per unit of generator rated Mvar
calculated from the rated MVA and rated power factor. The reactive power elements can
be used to detect loss of excitation. If the VT type is selected as “None” or VT fuse loss is
detected, the reactive power protection is disabled. Rated Mvars for the system can be
calculated as follows:
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
5–61
CHAPTER 5: SETPOINTS
For example, given Rated MVA = 100 MVA and Rated Power Factor = 0.85, we have
–1
Rated Mvars = Rated MVA × sin ( cos ( Rated PF ) )
–1
(EQ 5.28)
= 100 × sin ( cos 0.85 )
= 52.67 Mvars
5.8.3
Reverse Power
PATH: SETPOINTS ZV S7 POWER ELEMENTS ZV REVERSE POWER
1 REVERSE
POWER
BLOCK REVERSE POWER
FROM ONLINE: 1 s
Range: 0 to 5000 s in steps of 1
MESSAGE
REVERSE POWER
ALARM: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN ALARM
RELAYS (2-5): ---5
Range: Any combination of Relays 2 to
5
MESSAGE
REVERSE POWER ALARM
LEVEL: 0.05 x Rated
Range: 0.02 to 0.99 × Rated MW in
steps of 0.01
MESSAGE
REVERSE POWER ALARM
DELAY: 10.0 s
Range: 0.2 to 120.0 s in steps of 0.1
MESSAGE
REVERSE POWER ALARM
EVENTS: Off
Range: On, Off
MESSAGE
REVERSE POWER
TRIP: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN TRIP
RELAYS (1-4): 1---
Range: Any combination of Relays 1 to
4
MESSAGE
REVERSE POWER TRIP
LEVEL: 0.05 x Rated
Range: 0.02 to 0.99 × Rated MW in
steps of 0.01
MESSAGE
REVERSE POWER TRIP
DELAY: 20.0 s
Range: 0.2 to 120.0 s in steps of 0.1
[Z]
If enabled, once the magnitude of 3-phase total power exceeds the Pickup Level in the
reverse direction (negative MW) for a period of time specified by the Delay, a trip or alarm
will occur. The level is programmed in per unit of generator rated MW calculated from the
rated MVA and rated power factor. If the generator is accelerated from the power system
rather than the prime mover, the reverse power element may be blocked from start for a
specified period of time. A value of zero for the block time indicates that the reverse power
protection is active as soon as both current and voltage are measured regardless of
whether the generator is online or offline. If the VT type is selected as “None” or VT fuse
loss is detected, the reverse power protection is disabled.
Note
5–62
The minimum magnitude of power measurement is determined by the phase CT minimum
of 2% rated CT primary. If the level for reverse power is set below that level, a trip or alarm
will only occur once the phase current exceeds the 2% cutoff.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
Users are cautioned that a reverse power element may not provide reliable indication
when set to a very low setting, particularly under conditions of large reactive loading on
the generator. Under such conditions, low forward power is a more reliable element.
5.8.4
Low Forward Power
PATH: SETPOINTS ZV S7 POWER ELEMENTS ZV LOW FORWARD POWER
1 LOW FORWARD
POWER
BLOCK LOW FWD POWER
FROM ONLINE: 0 s
Range: 0 to 15000 s in steps of 1
MESSAGE
LOW FORWARD POWER
ALARM: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN ALARM
RELAYS (2-5): ---5
Range: Any combination of Relays 2 to
5
MESSAGE
LOW FWD POWER ALARM
LEVEL: 0.05 x Rated
Range: 0.02 to 0.99 × Rated MW in
steps of 0.01
MESSAGE
LOW FWD POWER ALARM
DELAY: 10.0 s
Range: 0.2 to 120.0 s in steps of 0.1
MESSAGE
LOW FWD POWER ALARM
EVENTS: Off
Range: On, Off
MESSAGE
LOW FORWARD POWER
TRIP: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN TRIP
RELAYS (1-4): 1---
Range: Any combination of Relays 1 to
4
MESSAGE
LOW FWD POWER TRIP
LEVEL: 0.05 x Rated
Range: 0.02 to 0.99 × Rated MW in
steps of 0.01
MESSAGE
LOW FWD POWER TRIP
DELAY: 20.0 s
Range: 0.2 to 120.0 s in steps of 0.1
[Z]
If enabled, once the magnitude of 3-phase total power in the forward direction (+MW) falls
below the Pickup Level for a period of time specified by the Delay, an alarm will occur. The
level is programmed in per unit of generator rated MW calculated from the rated MVA and
rated power factor. The low forward power element is active only when the generator is
online and will be blocked until the generator is brought online, for a period of time defined
by the setpoint Block Low Fwd Power From Online. The pickup level should be set lower
than expected generator loading during normal operations. If the VT type is selected as
“None” or VT fuse loss is detected, the low forward power protection is disabled.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
5–63
CHAPTER 5: SETPOINTS
5.9
S8 RTD Temperature
5.9.1
RTD Types
PATH: SETPOINTS ZV S8 RTD TEMPERATURE Z RTD TYPES
1 RTD TYPES
[Z]
STATOR RTD TYPE:
100 Ohm Platinum
Range: 100 Ohm Platinum, 120 Ohm
Nickel, 100 Ohm Nickel, 10 Ohm
Copper
Range: as above
MESSAGE
BEARING RTD TYPE:
100 Ohm Platinum
MESSAGE
AMBIENT RTD TYPE:
100 Ohm Platinum
Range: as above
MESSAGE
OTHER RTD TYPE:
100 Ohm Platinum
Range: as above
Each of the twelve RTDs may be configured as None or any one of four application types,
Stator, Bearing, Ambient, or Other. Each of those types may in turn be any one of four
different RTD types: 100 ohm Platinum, 120 ohm Nickel, 100 ohm Nickel, 10 ohm Copper.
The table below lists RTD resistance vs. temperature.
Table 5–6: RTD Temperature vs. Resistance
Temperature
°C
°F
–50
–40
–30
–20
–10
0
10
20
30
40
50
60
70
80
90
100
110
120
130
140
150
160
170
5–64
–58
–40
–22
–4
14
32
50
68
86
104
122
140
158
176
194
212
230
248
266
284
302
320
338
100 Ω Pt
(DIN 43760)
80.31
84.27
88.22
92.16
96.09
100.00
103.90
107.79
111.67
115.54
119.39
123.24
127.07
130.89
134.70
138.50
142.29
146.06
149.82
153.58
157.32
161.04
164.76
120 Ω Ni
86.17
92.76
99.41
106.15
113.00
120.00
127.17
134.52
142.06
149.79
157.74
165.90
174.25
182.84
191.64
200.64
209.85
219.29
228.96
238.85
248.95
259.30
269.91
100 Ω Ni
71.81
77.30
82.84
88.45
94.17
100.00
105.97
112.10
118.38
124.82
131.45
138.25
145.20
152.37
159.70
167.20
174.87
182.75
190.80
199.04
207.45
216.08
224.92
10 Ω Cu
7.10
7.49
7.88
8.26
8.65
9.04
9.42
9.81
10.19
10.58
10.97
11.35
11.74
12.12
12.51
12.90
13.28
13.67
14.06
14.44
14.83
15.22
15.61
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
Table 5–6: RTD Temperature vs. Resistance
Temperature
°C
°F
180
190
200
210
220
230
240
250
5.9.2
356
374
392
410
428
446
464
482
100 Ω Pt
(DIN 43760)
168.47
172.46
175.84
179.51
183.17
186.82
190.45
194.08
120 Ω Ni
280.77
291.96
303.46
315.31
327.54
340.14
353.14
366.53
100 Ω Ni
233.97
243.30
252.88
262.76
272.94
283.45
294.28
305.44
10 Ω Cu
16.00
16.39
16.78
17.17
17.56
17.95
18.34
18.73
RTDs 1 to 6
PATH: SETPOINTS ZV S8 RTD TEMPERATURE ZV RTD #1(6)
1 RTD #1
RTD #1 APPLICATION:
Stator
Range: Stator, Bearing, Ambient, Other,
None
RTD #1 NAME:
Range: 8 alphanumeric characters
MESSAGE
RTD #1 ALARM:
Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN ALARM
RELAYS (2-5): ---5
Range: Any combination of Relays 2 to
5.
MESSAGE
RTD #1 ALARM
TEMPERATURE: 130°C
Range: 1 to 250°C in steps of 1
MESSAGE
RTD #1 ALARM
EVENTS: Off
Range: On, Off
MESSAGE
RTD #1 TRIP:
Off
Range: Off, Latched, Unlatched
MESSAGE
RTD #1 TRIP VOTING:
RTD #1
Range: RTD #1 to RTD #12
MESSAGE
ASSIGN TRIP
RELAYS (1-4): 1---
Range: Any combination of Relays 1 to
4
MESSAGE
RTD #1 TRIP
TEMPERATURE: 155°C
Range: 1 to 250°C in steps of 1
[Z]
MESSAGE
RTDs 1 through 6 default to Stator RTD type. There are individual alarm and trip
configurations for each RTD. This allows one of the RTDs to be turned off if it malfunctions.
The alarm level is normally set slightly above the normal running temperature. The trip
level is normally set at the insulation rating. Trip voting has been added for extra reliability
in the event of RTD malfunction. If enabled, a second RTD must also exceed the trip
temperature of the RTD being checked before a trip will be issued. If the RTD is chosen to
vote with itself, the voting feature is disabled. Each RTD name may be changed if desired.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
5–65
CHAPTER 5: SETPOINTS
5.9.3
RTDs 7 to 10
PATH: SETPOINTS ZV S8 RTD TEMPERATURE ZV RTD #7(10)
1 RTD #7
RTD #7 APPLICATION:
Bearing
Range: Stator, Bearing, Ambient, Other,
None
RTD #7 NAME:
Range: 8 alphanumeric characters
MESSAGE
RTD #7 ALARM:
Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN ALARM
RELAYS (2-5): ---5
Range: Any combination of Relays 2 to
5.
MESSAGE
RTD #7 ALARM
TEMPERATURE: 80°C
Range: 1 to 250°C in steps of 1
MESSAGE
RTD #7 ALARM
EVENTS: Off
Range: On, Off
MESSAGE
RTD #7 TRIP:
Off
Range: Off, Latched, Unlatched
MESSAGE
RTD #7 TRIP VOTING:
RTD #7
Range: RTD #1 to RTD #12
MESSAGE
ASSIGN TRIP
RELAYS (1-4): 1---
Range: Any combination of Relays 1 to
4
MESSAGE
RTD #7 TRIP
TEMPERATURE: 90°C
Range: 1 to 250°C in steps of 1
[Z]
MESSAGE
RTDs 7 through 10 default to Bearing RTD type. There are individual alarm and trip
configurations for each RTD. This allows one of the RTDs to be turned off if it malfunctions.
The alarm level and the trip level are normally set slightly above the normal running
temperature, but below the bearing temperature rating. Trip voting has been added for
extra reliability in the event of RTD malfunction. If enabled, a second RTD must also exceed
the trip temperature of the RTD being checked before a trip will be issued. If the RTD is
chosen to vote with itself, the voting feature is disabled. Each RTD name may be changed if
desired.
5–66
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
5.9.4
RTD 11
PATH: SETPOINTS ZV S8 RTD TEMPERATURE ZV RTD #11
1 RTD #11
RTD #11 APPLICATION:
Other
Range: Stator, Bearing, Ambient, Other,
None
RTD #11 NAME:
Range: 8 alphanumeric characters
MESSAGE
RTD #11 ALARM:
Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN ALARM
RELAYS (2-5): ---5
Range: Any combination of Relays 2 to
5.
MESSAGE
RTD #11 ALARM
TEMPERATURE: 80°C
Range: 1 to 250°C in steps of 1
MESSAGE
RTD #11 ALARM
EVENTS: Off
Range: On, Off
MESSAGE
RTD #11 TRIP:
Off
Range: Off, Latched, Unlatched
MESSAGE
RTD #11 TRIP VOTING:
RTD #11
Range: RTD #1 to RTD #12
MESSAGE
ASSIGN TRIP
RELAYS (1-4): 1---
Range: Any combination of Relays 1 to
4
MESSAGE
RTD #11 TRIP
TEMPERATURE: 90°C
Range: 1 to 250°C in steps of 1
[Z]
MESSAGE
RTD 11 defaults to Other RTD type. The Other selection allows the RTD to be used to
monitor any temperature that might be required, either for a process or additional
bearings or other. There are individual alarm and trip configurations for this RTD. Trip
voting has been added for extra reliability in the event of RTD malfunction. If enabled, a
second RTD must also exceed the trip temperature of the RTD being checked before a trip
will be issued. If the RTD is chosen to vote with itself, the voting feature is disabled. The RTD
name may be changed if desired.
5.9.5
RTD 12
PATH: SETPOINTS ZV S8 RTD TEMPERATURE ZV RTD #12
1 RTD #12
RTD #12 APPLICATION:
Ambient
Range: Stator, Bearing, Ambient, Other,
None
RTD #12 NAME:
Range: 8 alphanumeric characters
MESSAGE
RTD #12 ALARM:
Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN ALARM
RELAYS (2-5): ---5
Range: Any combination of Relays 2 to
5.
[Z]
MESSAGE
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
5–67
CHAPTER 5: SETPOINTS
MESSAGE
RTD #12 ALARM
TEMPERATURE: 60°C
Range: 1 to 250°C in steps of 1
MESSAGE
RTD #12 ALARM
EVENTS: Off
Range: On, Off
MESSAGE
RTD #12 TRIP:
Off
Range: Off, Latched, Unlatched
MESSAGE
RTD #12 TRIP VOTING:
RTD #12
Range: RTD #1 to RTD #12
MESSAGE
ASSIGN TRIP
RELAYS (1-4): 1---
Range: Any combination of Relays 1 to
4
MESSAGE
RTD #12 TRIP
TEMPERATURE: 80°C
Range: 1 to 250°C in steps of 1
RTDs 12 defaults to Ambient RTD type. The Ambient selection allows the RTD to be used to
monitor ambient temperature. There are individual alarm and trip configurations for this
RTD. Trip voting has been added for extra reliability in the event of RTD malfunction. If
enabled, a second RTD must also exceed the trip temperature of the RTD being checked
before a trip will be issued. If the RTD is chosen to vote with itself, the voting feature is
disabled. The RTD name may be changed if desired.
5.9.6
Open RTD Sensor
SETPOINTS ZV S8 RTD TEMPERATURE ZV OPEN RTD SENSOR
1 OPEN RTD
SENSOR
OPEN RTD SENSOR:
Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN ALARM
RELAYS (2-5): ---5
Range: Any combination of Relays 2 to
5
MESSAGE
OPEN RTD SENSOR
ALARM EVENTS: Off
Range: On, Off
[Z]
The 489 has an Open RTD Sensor Alarm. This alarm will look at all RTDs that have either an
alarm or trip programmed and determine if an RTD connection has been broken. Any RTDs
that do not have a trip or alarm associated with them will be ignored for this feature. When
a broken sensor is detected, the assigned output relay will operate and a message will
appear on the display identifying the RTD that is broken. It is recommended that if this
feature is used, the alarm be programmed as latched so that intermittent RTDs are
detected and corrective action may be taken.
5–68
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
5.9.7
RTD Short/Low Temp
PATH: SETPOINTS ZV S8 RTD TEMPERATURE ZV RTD SHORT/LOW TEMP
1 RTD
SHORT/LOW TEMP
RTD SHORT/LOW TEMP
ALARM: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN ALARM
RELAYS (2-5): ---5
Range: Any combination of Relays 2 to
5
MESSAGE
RTD SHORT/LOW TEMP
ALARM EVENTS: Off
Range: On, Off
[Z]
The 489 has an RTD Short/Low Temperature alarm. This alarm will look at all RTDs that
have either an alarm or trip programmed and determine if an RTD has either a short or a
very low temperature (less than –50°C). Any RTDs that do not have a trip or alarm
associated with them will be ignored for this feature. When a short/low temperature is
detected, the assigned output relay will operate and a message will appear on the display
identifying the RTD that caused the alarm. It is recommended that if this feature is used,
the alarm be programmed as latched so that intermittent RTDs are detected and
corrective action may be taken.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
5–69
CHAPTER 5: SETPOINTS
5.10 S9 Thermal Model
5.10.1 489 Thermal Model
The thermal model of the 489 is primarily intended for induction generators, especially
those that start on the system bus in the same manner as induction motors. However,
some of the thermal model features may be used to model the heating that occurs in
synchronous generators during overload conditions.
One of the principle enemies of generator life is heat. Generator thermal limits are dictated
by the design of both the stator and the rotor. Induction generators that start on the
system bus have three modes of operation: locked rotor or stall (when the rotor is not
turning), acceleration (when the rotor is coming up to speed), and generating (when the
rotor turns at super-synchronous speed). Heating occurs in the generator during each of
these conditions in very distinct ways. Typically, during the generator starting, locked rotor
and acceleration conditions, the generator will be rotor limited. That is to say that the rotor
will approach its thermal limit before the stator. Under locked rotor conditions, voltage is
induced in the rotor at line frequency, 50 or 60 Hz. This voltage causes a current to flow in
the rotor, also at line frequency, and the heat generated (I2R) is a function of the effective
rotor resistance. At 50 or 60 Hz, the reactance of the rotor cage causes the current to flow
at the outer edges of the rotor bars. The effective resistance of the rotor is therefore at a
maximum during a locked rotor condition as is rotor heating. When the generator is
running at above rated speed, the voltage induced in the rotor is at a low frequency
(approximately 1 Hz) and therefore, the effective resistance of the rotor is reduced quite
dramatically. During overloads, the generator thermal limit is typically dictated by stator
parameters. Some special generators might be all stator or all rotor limited. During
acceleration, the dynamic nature of the generator slip dictates that rotor impedance is
also dynamic, and a third thermal limit characteristic is necessary.
The figure below illustrates typical thermal limit curves for induction motors. The starting
characteristic is shown for a high inertia load at 80% voltage. If the machine started
quicker, the distinct characteristics of the thermal limit curves would not be required and
the running overload curve would be joined with locked rotor safe stall times to produce a
single overload curve.
The generator manufacturer should provide a safe stall time or thermal limit curves for any
generator that is started as an induction motor. These thermal limits are intended to be
used as guidelines and their definition is not always precise. When operation of the
generator exceeds the thermal limit, the generator insulation does not immediately melt,
rather, the rate of insulation degradation reaches a point where continued operation will
significantly reduce generator life.
5–70
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
400
HIGH
INERTIA
MOTOR
300
200
RUNNING OVERLOAD
100
80
A,B,AND C ARE THE
ACCELERATION THERMAL LIMIT
CURVES AT 100%, 90%, AND
80%VOLTAGE, REPECTIVELY
TIME-SECONDS
60
40
C
B
20
A
G
F
10
8
E
6
4
E,F, AND G ARE THE
SAFE STALL THERMAL LIMIT
TIMES AT 100%, 90%, AND
80%VOLTAGE, REPECTIVELY
2
1
0
100
200
300
400
500
600
% CURRENT
806827A1.CDR
FIGURE 5–14: Typical Time-Current and Thermal Limit Curves
(ANSI/IEEE C37.96)
5.10.2 Model Setup
Setpoints
PATH: SETPOINTS ZV S9 THERMAL MODEL Z MODEL SETUP
1 MODEL SETUP
ENABLE THERMAL
MODEL: No
Range: No, Yes
MESSAGE
OVERLOAD PICKUP
LEVEL: 1.01 x FLA
Range: 1.01 to 1.25 × FLA in steps of
0.01
MESSAGE
UNBALANCE BIAS
K FACTOR: 0
Range: 0 to 12 in steps of 1. A value of
“0” disables this feature
MESSAGE
COOL TIME CONSTANT
ONLINE: 15 min.
Range: 0 to 500 min. in steps of 1
MESSAGE
COOL TIME CONSTANT
OFFLINE: 30 min.
Range: 0 to 500 min. in steps of 1
MESSAGE
HOT/COLD SAFE
STALL RATIO: 1.00
Range: 0.01 to 1.00 in steps of 0.01
MESSAGE
ENABLE RTD
BIASING: No
Range: No, Yes
MESSAGE
RTD BIAS
MINIMUM: 40°C
Range: 0 to 250°C in steps of 1
[Z]
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
5–71
CHAPTER 5: SETPOINTS
MESSAGE
RTD BIAS CENTER
POINT: 130°C
Range: 0 to 250°C in steps of 1
MESSAGE
RTD BIAS
MAXIMUM: 155°C
Range: 0 to 250°C in steps of 1
MESSAGE
SELECT CURVE STYLE:
Standard
Range: Standard, Custom, Voltage
Dependent
MESSAGE
STANDARD OVERLOAD
CURVE NUMBER: 4
Range: 1 to 15 in steps of 1. See Note
below.
MESSAGE
TIME TO TRIP AT
1.01 x FLA: 17414.5 s
Range: 0.5 to 99999.9 in steps of 0.1.
See Notes below.
↓
Note
Note
MESSAGE
TIME TO TRIP AT
20.0 x FLA: 5.6 s
Range: 0.5 to 99999.9 in steps of 0.1.
See Notes below.
MESSAGE
MINIMUM ALLOWABLE
VOLTAGE: 80%
Range: 70 to 95% in steps of 1. See
Notes below.
MESSAGE
STALL CURRENT @ MIN
VOLTAGE: 4.80 x FLA
Range: 2.00 to 15.00 × FLA in steps of
0.01. See Notes below.
MESSAGE
SAFE STALL TIME @
MIN VOLTAGE: 20.0 s
Range: 0.5 to 999.9 in steps of 0.1. See
Notes below.
MESSAGE
ACCEL. INTERSECT @
MIN VOLT: 3.80 x FLA
MESSAGE
STALL CURRENT @ 100%
VOLTAGE: 6.00 x FLA
Range: 2.00 to STALL CURRENT @ MIN
VOLTAGE in steps of 0.01. See
Notes below.
Range: 2.00 to 15.00 × FLA in steps of
0.01. See Note below.
MESSAGE
SAFE STALL TIME @
100% VOLTAGE: 10.0 s
Range: 0.5 to 999.9 in steps of 0.1. See
Notes below.
MESSAGE
ACCEL. INTERSECT @
100% VOLT: 5.00 x FLA
Range: 2.00 to STALL CURRENT @ 100%
VOLTAGE in steps of 0.01. See
Notes below.
The RTD BIAS MINIMUM, RTD BIAS CENTER , and RTD BIAS MAXIMUM setpoints is are seen
only if ENABLE RTD BIASING is set to “Yes”.
The STANDARD OVERLOAD CURVE NUMBER is seen only if SELECT CURVE STYLE is set to
“Standard”. If the SELECT CURVE STYLE is set to “Voltage Dependent”, all setpoints shown
after the STANDARD OVERLOAD CURVE NUMBER are displayed. If the SELECT CURVE STYLE is
set to “Custom”, the setpoints shown after TIME TO TRIP AT 20.0 X FLA are not displayed.
The current measured at the output CTs is used for the thermal model. The thermal model
consists of five key elements: the overload curve and overload pickup level, the unbalance
biasing of the generator current while the machine is running, the cooling time constants,
and the biasing of the thermal model based on hot/cold generator information and
measured stator temperature. Each of these elements are described in detail in the
sections that follow.
5–72
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
Note
The generator FLA is calculated as:
Generator Rated MVA
-------------------------------------------------------------------------------------------------------------3 × Rated Generator Phase-Phase Voltage
(EQ 5.29)
The 489 integrates both stator and rotor heating into one model. Machine heating is
reflected in a register called Thermal Capacity Used. If the machine has been stopped for a
long period of time, it will be at ambient temperature and thermal capacity used should be
zero. If the machine is in overload, once the thermal capacity used reaches 100%, a trip will
occur.
The overload curve accounts for machine heating during stall, acceleration, and running in
both the stator and the rotor. The Overload Pickup setpoint defines where the running
overload curve begins as the generator enters an overload condition. This is useful to
accommodate a service factor. The curve is effectively cut off at current values below this
pickup.
Generator thermal limits consist of three distinct parts based on the three conditions of
operation, locked rotor or stall, acceleration, and running overload. Each of these curves
may be provided for both a hot and cold machine. A hot machine is defined as one that
has been running for a period of time at full load such that the stator and rotor
temperatures have settled at their rated temperature. A cold machine is defined as a
machine that has been stopped for a period of time such that the stator and rotor
temperatures have settled at ambient temperature. For most machines, the distinct
characteristics of the thermal limits are formed into one smooth homogeneous curve.
Sometimes only a safe stall time is provided. This is acceptable if the machine has been
designed conservatively and can easily perform its required duty without infringing on the
thermal limit. In this case, the protection can be conservative. If the machine has been
designed very close to its thermal limits when operated as required, then the distinct
characteristics of the thermal limits become important.
The 489 overload curve can take one of three formats, Standard, Custom Curve, or Voltage
Dependent. Regardless of which curve style is selected, the 489 will retain thermal memory
in the form of a register called Thermal Capacity Used. This register is updated every 50 ms
using the following equation:
TC used t = TC used
t – 50ms
50 ms
+ --------------------------- × 100%
time to trip
(EQ 5.30)
where time to trip = time taken from the overload curve at Ieq as a function of FLA.
The overload protection curve should always be set slightly lower than the thermal limits
provided by the manufacturer. This will ensure that the machine is tripped before the
thermal limit is reached. If the starting times are well within the safe stall times, it is
recommended that the 489 Standard Overload Curve be used. The standard overload
curves are a series of 15 curves with a common curve shape based on typical generator
thermal limit curves (see the following figure and table).
When the generator trips offline due to overload the generator will be locked out (the trip
relay will stay latched) until generator thermal capacity reaches 15%.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
5–73
CHAPTER 5: SETPOINTS
100000
TIME IN SECONDS
10000
1000
100
x15
10
x1
1.00
0.10
1.00
10
100
MULTIPLE OF FULL LOAD AMPS
1000
806804A5.CDR
FIGURE 5–15: 489 Standard Overload Curves
Note
Above 8.0 × Pickup, the trip time for 8.0 is used. This prevents the overload curve from
acting as an instantaneous element.
The standard overload curves equation is:
Curve Multiplier × 2.2116623
Time to Trip = --------------------------------------------------------------------------------------------------------------------------------------------2
0.02530337 × ( Pickup – 1 ) + 0.05054758 × ( Pickup – 1 )
5–74
(EQ 5.31)
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
Table 5–7: 489 Standard Overload Curve Multipliers
PICKUP
(× FLA)
STANDARD CURVE MULTIPLIERS
×1
×2
×3
×4
×5
×6
×7
×8
×9
× 10
× 11
× 12
× 13
× 14
× 15
1.0
1
435
3.6
870
7.2
130
61
174
14
217
68
261
22
304
75
348
29
391
83
435
36
478
90
522
43
565
97
609
51
653
04
1.0
5
853.
71
170
7.4
256
1.1
341
4.9
426
8.6
512
2.3
597
6.0
682
9.7
768
3.4
853
7.1
939
0.8
102
45
110
98
119
52
128
06
1.1
0
416.
68
833.
36
125
0.0
166
6.7
208
3.4
250
0.1
291
6.8
333
3.5
375
0.1
416
6.8
458
3.5
500
0.2
541
6.9
583
3.6
625
0.2
1.2
0
198.
86
397.
72
596.
58
795.
44
994.
30
119
3.2
139
2.0
159
0.9
178
9.7
198
8.6
218
7.5
238
6.3
258
5.2
278
4.1
298
2.9
1.3
0
126.
80
253.
61
380.
41
507.
22
634.
02
760.
82
887.
63
101
4.4
114
1.2
126
8.0
139
4.8
152
1.6
164
8.5
177
5.3
190
2.1
1.4
0
91.1
4
182.
27
273.
41
364.
55
455.
68
546.
82
637.
96
729.
09
820.
23
911.
37
100
2.5
109
3.6
118
4.8
127
5.9
136
7.0
1.5
0
69.9
9
139.
98
209.
97
279.
96
349.
95
419.
94
489.
93
559.
92
629.
91
699.
90
769.
89
839.
88
909.
87
979.
86
104
9.9
1.7
5
42.4
1
84.8
3
127.
24
169.
66
212.
07
254.
49
296.
90
339.
32
381.
73
424.
15
466.
56
508.
98
551.
39
593.
81
636.
22
2.0
0
29.1
6
58.3
2
87.4
7
116.
63
145.
79
174.
95
204.
11
233.
26
262.
42
291.
58
320.
74
349.
90
379.
05
408.
21
437.
37
2.2
5
21.5
3
43.0
6
64.5
9
86.1
2
107.
65
129.
18
150.
72
172.
25
193.
78
215.
31
236.
84
258.
37
279.
90
301.
43
322.
96
2.5
0
16.6
6
33.3
2
49.9
8
66.6
4
83.3
0
99.9
6
116.
62
133.
28
149.
94
166.
60
183.
26
199.
92
216.
58
233.
24
249.
90
2.7
5
13.3
3
26.6
5
39.9
8
53.3
1
66.6
4
79.9
6
93.2
9
106.
62
119.
95
133.
27
146.
60
159.
93
173.
25
186.
58
199.
91
3.0
0
10.9
3
21.8
6
32.8
0
43.7
3
54.6
6
65.5
9
76.5
2
87.4
6
98.3
9
109.
32
120.
25
131.
19
142.
12
153.
05
163.
98
3.2
5
9.15
18.2
9
27.4
4
36.5
8
45.7
3
54.8
7
64.0
2
73.1
6
82.3
1
91.4
6
100.
60
109.
75
118.
89
128.
04
137.
18
3.5
0
7.77
15.5
5
23.3
2
31.0
9
38.8
7
46.6
4
54.4
1
62.1
9
69.9
6
77.7
3
85.5
1
93.2
8
101.
05
108.
83
116.
60
3.7
5
6.69
13.3
9
20.0
8
26.7
8
33.4
7
40.1
7
46.8
6
53.5
6
60.2
5
66.9
5
73.6
4
80.3
4
87.0
3
93.7
3
100.
42
4.0
0
5.83
11.6
6
17.4
9
23.3
2
29.1
5
34.9
8
40.8
1
46.6
4
52.4
7
58.3
0
64.1
3
69.9
6
75.7
9
81.6
2
87.4
5
4.2
5
5.12
10.2
5
15.3
7
20.5
0
25.6
2
30.7
5
35.8
7
41.0
0
46.1
2
51.2
5
56.3
7
61.5
0
66.6
2
71.7
5
76.8
7
4.5
0
4.54
9.08
13.6
3
18.1
7
22.7
1
27.2
5
31.8
0
36.3
4
40.8
8
45.4
2
49.9
7
54.5
1
59.0
5
63.5
9
68.1
4
4.7
5
4.06
8.11
12.1
7
16.2
2
20.2
8
24.3
3
28.3
9
32.4
4
36.5
0
40.5
5
44.6
1
48.6
6
52.7
2
56.7
7
60.8
3
5.0
0
3.64
7.29
10.9
3
14.5
7
18.2
2
21.8
6
25.5
0
29.1
5
32.7
9
36.4
3
40.0
8
43.7
2
47.3
6
51.0
1
54.6
5
5.5
0
2.99
5.98
8.97
11.9
6
14.9
5
17.9
4
20.9
3
23.9
1
26.9
0
29.8
9
32.8
8
35.8
7
38.8
6
41.8
5
44.8
4
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
5–75
CHAPTER 5: SETPOINTS
Table 5–7: 489 Standard Overload Curve Multipliers
PICKUP
(× FLA)
STANDARD CURVE MULTIPLIERS
×1
×2
×3
×4
×5
×6
×7
×8
×9
× 10
× 11
× 12
× 13
× 14
× 15
6.0
0
2.50
5.00
7.49
9.99
12.4
9
14.9
9
17.4
9
19.9
9
22.4
8
24.9
8
27.4
8
29.9
8
32.4
8
34.9
7
37.4
7
6.5
0
2.12
4.24
6.36
8.48
10.6
0
12.7
2
14.8
4
16.9
6
19.0
8
21.2
0
23.3
2
25.4
4
27.5
5
29.6
7
31.7
9
7.0
0
1.82
3.64
5.46
7.29
9.11
10.9
3
12.7
5
14.5
7
16.3
9
18.2
1
20.0
4
21.8
6
23.6
8
25.5
0
27.3
2
7.5
0
1.58
3.16
4.75
6.33
7.91
9.49
11.0
8
12.6
6
14.2
4
15.8
2
17.4
1
18.9
9
20.5
7
22.1
5
23.7
4
8.0
0
1.39
2.78
4.16
5.55
6.94
8.33
9.71
11.1
0
12.4
9
13.8
8
15.2
7
16.6
5
18.0
4
19.4
3
20.8
2
10.
00
1.39
2.78
4.16
5.55
6.94
8.33
9.71
11.1
0
12.4
9
13.8
8
15.2
7
16.6
5
18.0
4
19.4
3
20.8
2
15.
00
1.39
2.78
4.16
5.55
6.94
8.33
9.71
11.1
0
12.4
9
13.8
8
15.2
7
16.6
5
18.0
4
19.4
3
20.8
2
20.
00
1.39
2.78
4.16
5.55
6.94
8.33
9.71
11.1
0
12.4
9
13.8
8
15.2
7
16.6
5
18.0
4
19.4
3
20.8
2
Custom Overload Curve
If the induction generator starting current begins to infringe on the thermal damage
curves, it may become necessary to use a custom curve to tailor generator protection so
successful starting may be possible without compromising protection. Furthermore, the
characteristics of the starting thermal (locked rotor and acceleration) and the running
thermal damage curves may not fit together very smoothly. In this instance, it may be
necessary to use a custom curve to tailor protection to the thermal limits to allow the
generator to be started successfully and utilized to its full potential without compromising
protection. The distinct parts of the thermal limit curves now become more critical. For
these conditions, it is recommended that the 489 custom curve thermal model be used.
The custom overload curve allows users to program their own curves by entering trip
times for 30 pre-determined current levels.
The curves below show that if the running overload thermal limit curve were smoothed
into one curve with the locked rotor thermal limit curve, the induction generator could not
be started at 80% voltage. A custom curve is required.
5–76
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
489
TYPICAL CUSTOM CURVE
GE Multilin
10000
1000
1
PROGRAMMED 469 CUSTOM CURVE
2
RUNNING SAFETIME (STATOR LIMIT)
3
ACCELERATION SAFETIME (ROTOR LIMIT)
4
MACHINE CURRENT @ 100% VOLTAGE
5
MACHINE CURRENT @ 80% VOLTAGE
TIME TO TRIP IN SECONDS
1
2
100
3
10
4
5
MULTIPLE OF FULL LOAD CURRENT SETPOINT
1000
100
10
0.5
0.1
1
1.0
808825A3.CDR
FIGURE 5–16: Custom Curve Example
Voltage Dependent Overload Curve
It is possible and acceptable that the acceleration time exceeds the safe stall time (bearing
in mind that a locked rotor condition is quite different than an acceleration condition). In
this instance, each distinct portion of the thermal limit curve must be known and
protection coordinated against that curve. The protection relay must be able to distinguish
between a locked rotor condition, an accelerating condition, and a running condition. The
489 voltage dependent overload curve feature is tailored to protect these types of
machines. Voltage is monitored constantly during starting and the acceleration thermal
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
5–77
CHAPTER 5: SETPOINTS
limit curve adjusted accordingly. If the VT Connection setpoint is set to none or if a VT fuse
failure is detected, the acceleration thermal limit curve for the minimum allowable voltage
will be used.
The voltage dependent overload curve is comprised of the three characteristic thermal
limit curve shapes determined by the stall or locked rotor condition, acceleration, and
running overload. The curve is constructed by entering a custom curve shape for the
running overload protection curve. Next, a point must be entered for the acceleration
protection curve at the point of intersection with the custom curve, based on the minimum
allowable starting voltage as defined by the minimum allowable voltage. Locked Rotor
Current and safe stall time must also be entered for that voltage. A second point of
intersection must be entered for 100% voltage. Once again, the locked rotor current and
the safe stall time must be entered, this time for 100% voltage. The protection curve that is
created from the safe stall time and intersection point will be dynamic based on the
measured voltage between the minimum allowable voltage and the 100% voltage. This
method of protection inherently accounts for the change in speed as an impedance relay
would. The change in impedance is reflected by machine terminal voltage and line current.
For any given speed at any given voltage, there is only one value of line current.
5–78
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
489
THERMAL LIMITS
FOR HIGH INERTIAL LOAD
GE Multilin
1000
900
800
700
1- Running Overload Thermal Limit
2- Acceleration Thermal Limit @ 80%V
3- Acceleration Thermal Limit @ 100%V
4- Locked Rotor Thermal Limit
5- Machine Acceleration Curve @ 80% V
6- Machine Acceleration Curve @ 100%V
1
600
500
400
300
2
200
TIME TO TRIP (SECONDS)
3
100
90
80
70
60
50
40
30
20
10
9
8
7
6
4
5
4
5
3
6
2
1
2
1
3
4
5
6
MULTIPLES OF FULL LOAD AMPS
7
8
808826A3.CDR
FIGURE 5–17: Thermal Limits for High Inertial Load
To illustrate the Voltage Dependent Overload Curve feature, the thermal limits shown in
Thermal Limits for High Inertial Load on page 5–79 will be used.
Z Construct a custom curve for the running overload thermal limit.
If the curve does not extend to the acceleration thermal limits,
extend it such that the curve intersects the acceleration thermal limit
curves. (see the custom curve below).
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
5–79
CHAPTER 5: SETPOINTS
GE Multilin
489
VOLTAGE DEPENDENT OVERLOAD
(CUSTOM CURVE)
1000
900
800
700
600
500
400
300
Acceleration Intersect at 80%V
200
TIME TO TRIP (SECONDS)
Acceleration Intersect at 100%V
100
90
80
70
60
50
40
30
20
10
9
8
7
6
5
4
3
2
1
1
2
3
4
5
6
MULTIPLES OF FULL LOAD AMPS
7
8
808827A3.CDR
FIGURE 5–18: Voltage Dependent Overload Curve (Custom)
Z Enter the per unit current value for the acceleration overload curve
intersect with the custom curve for 80% voltage.
Z Enter the per unit current and safe stall protection time for 80%
voltage (see the acceleration curves below).
Z Enter the per unit current value for the acceleration overload curve
intersect with the custom curve for 100% voltage.
Z Enter the per unit current and safe stall protection time for 100%
voltage (see the acceleration curves below).
5–80
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
GE Multilin
489
VOLTAGE DEPENDENT OVERLOAD
(ACCELERATION CURVES)
1000
900
800
700
600
500
489 Custom Curve
400
300
TIME TO TRIP (SECONDS)
200
100
90
80
70
60
50
40
30
20
10
9
8
7
6
5
4
3
2
1
1
2
3
4
5
6
MULTIPLES OF FULL LOAD AMPS
7
8
808828A3.CDR
FIGURE 5–19: Voltage Dependent Overload Curve (Acceleration Curves)
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
5–81
CHAPTER 5: SETPOINTS
The 489 takes the information provided and create protection curves for any voltage
between the minimum and 100%. For values above the voltage in question, the 489
extrapolates the safe stall protection curve to 110% voltage. This current level is calculated
by taking the locked rotor current at 100% voltage and multiplying by 1.10. For trip times
above the 110% voltage level, the trip time of 110% will be used (see the figure below).
489
VOLTAGE DEPENDENT
OVERLOAD PROTECTION CURVES
GE Multilin
1000
900
800
700
600
Custom Curve
500
400
300
Acceleration Intersect at 80%V
200
TIME TO TRIP (SECONDS)
Acceleration Intersect at 100%V
100
90
80
70
60
50
40
30
Safe Stall Time at 80%V,
80%V Stall Current
20
Safe Stall Time at 100%V,
100%V Stall Current
10
9
8
7
6
5
Safe Stall Points
Extrapolated to 110%V
4
3
2
1
1
2
3
4
5
MULTIPLES OF FULL LOAD AMPS
6
8
7
808831A3.CDR
FIGURE 5–20: Voltage Dependent Overload Protection Curves
Note
5–82
The safe stall curve is in reality a series of safe stall points for different voltages. For a given
voltage, there can be only one value of stall current, and therefore only one safe stall time.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
The following curves illustrate the resultant overload protection for 80% and 100%
voltage, respectively. For voltages between these levels, the 489 shifts the acceleration
curve linearly and constantly based upon the measured voltage during generator start.
GE Multilin
489
VOLTAGE DEPENDENT
OVERLOAD PROTECTION at 80% V
1000
900
800
700
600
500
400
300
TIME TO TRIP (SECONDS)
200
100
90
80
70
60
50
40
30
20
10
9
8
7
6
5
4
3
2
1
1
2
3
4
5
6
MULTIPLES OF FULL LOAD AMPS
7
8
808830A3.CDR
FIGURE 5–21: Voltage Dependent Overload Protection at 80% Voltage
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
5–83
CHAPTER 5: SETPOINTS
489
VOLTAGE DEPENDENT
OVERLOAD PROTECTION at 100% V
GE Multilin
1000
900
800
700
600
500
400
300
TIME TO TRIP (SECONDS)
200
100
90
80
70
60
50
40
30
20
10
9
8
7
6
5
4
3
2
1
1
2
3
4
5
6
MULTIPLES OF FULL LOAD AMPS
7
8
808829A3.CDR
FIGURE 5–22: Voltage Dependent Overload Protection at 100% Voltage
Unbalance Bias
Unbalanced phase currents will cause additional rotor heating that will not be accounted
for by electromechanical relays and may not be accounted for in some electronic
protective relays. When the generator is running, the rotor will rotate in the direction of the
positive sequence current at near synchronous speed. Negative sequence current, which
has a phase rotation that is opposite to the positive sequence current, and hence, opposite
to the rotor rotation, will generate a rotor voltage that will produce a substantial rotor
current. This induced current will have a frequency that is approximately twice the line
frequency, 100 Hz for a 50 Hz system or 120 Hz for a 60 Hz system. Skin effect in the rotor
bars at this frequency will cause a significant increase in rotor resistance and therefore, a
5–84
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
significant increase in rotor heating. This extra heating is not accounted for in the thermal
limit curves supplied by the generator manufacturer as these curves assume positive
sequence currents only that come from a perfectly balanced supply and generator design.
The 489 measures the ratio of negative to positive sequence current. The thermal model
may be biased to reflect the additional heating that is caused by negative sequence
current when the machine is running. This biasing is done by creating an equivalent
heating current rather than simply using average current (Iper_unit). This equivalent current
is calculated using the equation shown below.
I eq =
2
I 1 + kI 2
2
(EQ 5.32)
where: Ieq = equivalent motor heating current in per unit (based on FLA)
I2= negative-sequence current in per unit (based on FLA)
I1= positive-sequence current in per unit (based on FLA)
k = constant relating negative-sequence rotor resistance to positive-sequence
rotor resistance, not to be confused with the k indicating generator negativesequence capability for an inverse time curve.
1.05
1.05
1.00
1.00
DERATING FACTOR
DERATING FACTOR
The figure below shows induction machine derating as a function of voltage unbalance as
recommended by NEMA (National Electrical Manufacturers Association). Assuming a
typical inrush of 6 × FLA and a negative sequence impedance of 0.167, voltage unbalances
of 1, 2, 3, 4, and 5% equal current unbalances of 6, 12, 18, 24, and 30%, respectively. Based
on this assumption, the GE curve illustrates the amount of machine derating for different
values of k entered for the UNBALANCE BIAS K FACTOR setpoint. Note that the curve
created when k = 8 is almost identical to the NEMA derating curve.
0.95
0.90
0.85
0.80
0.75
0.95
k= 2
0.90
0.85
k= 4
0.80
k= 6
k= 8
0.75
k= 10
0.70
0.70
0
1
2
3
4
5
PERCENT VOLTAGE UNBALANCE
NEMA
0
1
2
3
4
5
PERCENT VOLTAGE UNBALANCE
GE MULTILIN
808728A1.CDR
If a k value of 0 is entered, the unbalance biasing is defeated and the overload curve will
time out against the measured per unit motor current. k may be calculated conservatively
as:
175
230
k = --------- (typical estimate); k = --------- (conservative estimate)
2
2
I LR
I LR
(EQ 5.33)
where ILR is the per-unit locked rotor current.
Machine Cooling
The 489 thermal capacity used value is reduced exponentially when the motor current is
below the OVERLOAD PICKUP setpoint. This reduction simulates machine cooling. The
cooling time constants should be entered for both stopped and running cases (the
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
5–85
CHAPTER 5: SETPOINTS
generator is assumed to be running if current is measured or the generator is online). A
machine with a stopped rotor normally cools significantly slower than one with a turning
rotor. Machine cooling is calculated using the following formulae:
TC used = ( TC used_start – TC used_end ) ( e
–t ⁄ τ
) + TC used_end
(EQ 5.34)
I eq
hot
TC used_end = ⎛ -----------------------------------------⎞ ⎛ 1 – ----------⎞ × 100%
⎝ overload_pickup⎠ ⎝
cold⎠
(EQ 5.35)
100
100
75
75
Thermal Capacity Used
Thermal Capacity Used
where: TCused = thermal capacity used
TCused_start = TCused value caused by overload condition
TCused_end = TCused value dictated by the hot/cold safe stall ratio when the
machine is running (= 0 when the machine is stopped)
t = time in minutes
τ = Cool Time Constant (running or stopped)
Ieq = equivalent heating current
overload_pickup = overload pickup setpoint as a multiple of FLA
hot / cold = hot/cold safe stall ratio
Cool Time Constant= 15 min
TCused_start= 85%
Hot/Cold Ratio= 80%
Ieq/Overload Pickup= 80%
50
25
50
25
0
0
0
30
60
90
120
150
180
0
30
60
90
120
Time in Minutes
Time in Minutes
80% LOAD
100% LOAD
100
150
180
100
75
Thermal Capacity Used
Thermal Capacity Used
Cool Time Constant= 15 min
TCused_start= 85%
Hot/Cold Ratio= 80%
Ieq/Overload Pickup= 100%
Cool Time Constant= 30 min
TCused_start= 85%
Hot/Cold Ratio= 80%
Motor Stopped after running Rated Load
TCused_end= 0%
50
25
0
75
Cool Time Constant= 30 min
TCused_start= 100%
Hot/Cold Ratio= 80%
Motor Overload
TCused_end= 0%
50
25
0
0
30
60
90
120
150
180
0
30
60
90
120
Time in Minutes
Time in Minutes
MOTOR STOPPED
MOTOR TRIPPED
150
180
808705A2.CDR
FIGURE 5–23: Thermal Model Cooling
5–86
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
Hot/Cold Safe Stall Ratio
When thermal limit information is available for both a hot and cold machine, the 489
thermal model will adapt for the conditions if the HOT/COLD SAFE STALL RATIO is
programmed. The value entered for this setpoint dictates the level of thermal capacity
used that the relay will settle at for levels of current that are below the OVERLOAD PICKUP
LEVEL. When the generator is running at a level below the OVERLOAD PICKUP LEVEL, the
thermal capacity used will rise or fall to a value based on the average phase current and
the entered HOT/COLD SAFE STALL RATIO. Thermal capacity used will either rise at a fixed
rate of 5% per minute or fall as dictated by the running cool time constant.
hot-⎞ × 100%
TC used_end = I eq × ⎛ 1 – --------⎝
cold⎠
(EQ 5.36)
where: TCused_end = Thermal Capacity Used if Iper_unit remains steady state
Ieq = equivalent generator heating current
hot/cold = HOT/COLD SAFE STALL RATIO setpoint
The hot/cold safe stall ratio may be determined from the thermal limit curves, if provided,
or the hot and cold safe stall times. Simply divide the hot safe stall time by the cold safe
stall time. If hot and cold times are not provided, there can be no differentiation and the
HOT/COLD SAFE STALL RATIO should be entered as “1.00”.
RTD Bias
The thermal replica created by the features described in the sections above operates as a
complete and independent model. However, the thermal overload curves are based solely
on measured current, assuming a normal 40°C ambient and normal machine cooling. If
there is an unusually high ambient temperature, or if machine cooling is blocked,
generator temperature will increase. If the stator has embedded RTDs, the 489 RTD bias
feature should be used to correct the thermal model.
The RTD bias feature is a two part curve, constructed using 3 points. If the maximum stator
RTD temperature is below the RTD BIAS MINIMUM setpoint (typically 40°C), no biasing
occurs. If the maximum stator RTD temperature is above the RTD BIAS MAXIMUM setpoint
(typically at the stator insulation rating or slightly higher), then the thermal memory is fully
biased and thermal capacity is forced to 100% used. At values in between, the present
thermal capacity used created by the overload curve and other elements of the thermal
model, is compared to the RTD Bias thermal capacity used from the RTD Bias curve. If the
RTD Bias thermal capacity used value is higher, then that value is used from that point
onward. The RTD BIAS CENTER POINT should be set at the rated running temperature of the
machine. The 489 automatically determines the thermal capacity used value for the center
point using the HOT/COLD SAFE STALL RATIO setpoint.
hot-⎞ × 100%
TC used at RBC = ⎛ 1 – --------⎝
cold⎠
(EQ 5.37)
At temperatures less that the RTD Bias Center temperature,
Temp actual – Temp min
RTD_Bias_TC used = ------------------------------------------------------ × TC used at RBC
Temp center – Temp min
(EQ 5.38)
At temperatures greater than the RTD Bias Center temperature,
Temp actual – Temp center
RTD_Bias_TC used = ---------------------------------------------------------- × ( 100 – TC used at RBC ) + TC used at RBC
Temp max – Temp center
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
(EQ 5.39)
5–87
CHAPTER 5: SETPOINTS
where: RTD_Bias_TCused = TC used due to hottest stator RTD
Tempactual = current temperature of the hottest stator RTD
Tempmin = RTD Bias minimum setpoint
Tempcenter = RTD Bias center setpoint
Tempmax = RTD Bias maximum setpoint
TCused at RBC = TC used defined by the HOT/COLD SAFE STALL RATIO setpoint
In simple terms, the RTD bias feature is real feedback of measured stator temperature. This
feedback acts as correction of the thermal model for unforeseen situations. Since RTDs are
relatively slow to respond, RTD biasing is good for correction and slow generator heating.
The rest of the thermal model is required during high phase current conditions when
machine heating is relatively fast.
It should be noted that the RTD bias feature alone cannot create a trip. If the RTD bias
feature forces the thermal capacity used to 100%, the machine current must be above the
over-load pickup before an overload trip occurs. Presumably, the machine would trip on
stator RTD temperature at that time.
Note
No biasing occurs if the hottest stator RTD is open or short.
RTD Bias Maximum
RTD Thermal Capacity Used
100
Hot/Cold = 0.85
Rated Temperature=130°C
Insulation Rating=155°C
80
60
40
20
RTD Bias Center Point
RTD Bias Minimum
0
–50
0
50
100
150
200
250
Maximum Stator RTD Temperature
808721A1.CDR
FIGURE 5–24: RTD Bias Curve
5–88
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
5.10.3 Thermal Elements
SETPOINTS ZV S9 THERMAL MODEL ZV THERMAL ELEMENTS
1 THERMAL
ELEMENTS
THERMAL MODEL
ALARM: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN ALARM
RELAYS (2-5): ---5
Range: Any combination of Relays
2 to 5
MESSAGE
THERMAL ALARM
LEVEL: 75% Used
Range: 10 to 100% Used in steps of 1
MESSAGE
THERMAL MODEL
ALARM EVENTS: Off
Range: On, Off
MESSAGE
THERMAL MODEL
TRIP: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN TRIP
RELAYS (1-4): 1---
Range: Any combination of Relays
1 to 4
[Z]
Once the thermal model is setup, an alarm and/or trip element can be enabled. If the
generator has been offline for a long period of time, it will be at ambient temperature and
thermal capacity used should be zero. If the generator is in overload, once the thermal
capacity used reaches 100%, a trip will occur. The thermal model trip will remain active
until a lockout time has expired. The lockout time will be based on the reduction of thermal
capacity from 100% used to 15% used. This reduction will occur at a rate defined by the
offline cooling time constant. The thermal capacity used alarm may be used as a warning
indication of an impending overload trip.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
5–89
CHAPTER 5: SETPOINTS
5.11 S10 Monitoring
5.11.1 Trip Counter
PATH: SETPOINTS ZV S10 MONITORING Z TRIP COUNTER
„
TRIP
TRIP COUNTER
ALARM: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN ALARM
RELAYS (2-5): ---5
Range: Any combination of Relays 2 to
5
MESSAGE
TRIP COUNTER ALARM
LEVEL: 25 Trips
Range: 1 to 50000 Trips in steps of 1
MESSAGE
TRIP COUNTER ALARM
EVENTS: Off
Range: On, Off
[Z]
When enabled, a trip counter alarm will occur when the TRIP COUNTER ALARM LEVEL is
reached. The trip counter must be cleared or the alarm level raised and the reset key must
be pressed (if the alarm was latched) to reset the alarm.
For example, it might be useful to set a Trip Counter alarm at 100 trips, prompting the
operator or supervisor to investigate the type of trips that have occurred. A breakdown of
trips by type may be found in the A4 MAINTENANCE ZV TRIP COUNTERS actual values page.
If a trend is detected, it would warrant further investigation.
5.11.2 Breaker Failure
PATH: SETPOINTS ZV S10 MONITORING ZV BREAKER FAILURE
„
BREAKER
BREAKER FAILURE
ALARM: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN ALARM
RELAYS (2-5): ---5
Range: Any combination of Relays 2 to
5
MESSAGE
BREAKER FAILURE
LEVEL: 1.00 x CT
Range: 0.05 to 20.00 × CT in steps of
0.01
MESSAGE
BREAKER FAILURE
DELAY: 100 ms
Range: 10 to 1000 ms in steps of 10
MESSAGE
BREAKER FAILURE
ALARM EVENTS: Off
Range: On, Off
[Z]
If the breaker failure alarm feature may be enabled as latched or unlatched. If the 1 Trip
output relay is operated and the generator current measured at any of the three output
CTs is above the level programmed for the period of time specified by the delay, a breaker
failure alarm will occur. The time delay should be slightly longer than the breaker clearing
time.
5–90
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
5.11.3 Trip Coil Monitor
PATH: SETPOINTS ZV S10 MONITORING ZV TRIP COIL MONITOR
„ TRIP COIL
MONITOR
TRIP COIL MONITOR
ALARM: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN ALARM
RELAYS (2-5): ---5
Range: Any combination of Relays 2 to
5
MESSAGE
SUPERVISION OF TRIP
COIL: 52 Closed
Range: 52 Closed, 52 Open/Closed
MESSAGE
TRIP COIL MONITOR
ALARM EVENTS: Off
Range: On, Off
[Z]
If the trip coil monitor alarm feature is enabled as latched or unlatched, the trip coil
supervision circuitry will monitor the trip coil circuit for continuity any time that the breaker
status input indicates that the breaker is closed. If that continuity is broken, a trip coil
monitor alarm will occur in approximately 300 ms.
If 52 Open/Closed is selected, the trip coil supervision circuitry monitors the trip coil circuit
for continuity at all times regardless of breaker state. This requires an alternate path
around the 52a contacts in series with the trip coil when the breaker is open. See the figure
below for modifications to the wiring and proper resistor selection. If that continuity is
broken, a Starter Failure alarm will indicate Trip Coil Supervision.
TRIP COIL
SUPERVISION
E11
R1 TRIP
CONTACT
E2
F11
F1
TRIP COIL
SUPERVISION
E11
R1 TRIP
CONTACT
E2
F11
F1
TRIP COIL
SUPERVISION
E11
R1 TRIP
CONTACT
E2
F11
F1
52a
TRIP
COIL
TRIP COIL CLOSED SUPERVISION
"52 Closed"
TRIP COIL
OPEN/CLOSED
SUPERVISION
"52 Open/Closed"
WITH MULTIPLE
BREAKER AUX
CONTACTS
52a
52a
TRIP
COIL
TRIP
COIL
52a
TRIP COIL OPEN/CLOSED SUPERVISION
"52 Open/Closed"
VALUE OF RESISTOR 'R'
808727A1.CDR
SUPPLY
OHMS
WATTS
48 VDC
10 K
2
125 VDC
25 K
5
250 VDC
50 K
5
FIGURE 5–25: Trip Coil Supervision
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
5–91
CHAPTER 5: SETPOINTS
5.11.4 VT Fuse Failure
PATH: SETPOINTS ZV S10 MONITORING ZV VT FUSE FAILURE
„ VT FUSE
FAILURE
VT FUSE FAILURE
ALARM: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN ALARM
RELAYS (2-5): ---5
Range: Any combination of Relays 2 to
5
MESSAGE
VT FUSE FAILURE
ALARM EVENTS: Off
Range: On, Off
[Z]
A fuse failure is detected when there are significant levels of negative sequence voltage
without corresponding levels of negative sequence current measured at the output CTs.
Also, if the generator is online and there is not significant positive sequence voltage, it
could indicate that all VT fuses have been pulled or the VTs are racked out. If the alarm is
enabled and a VT fuse failure detected, elements that could nuisance operation are
blocked and an alarm occurs. These blocked elements include voltage restraint for the
phase overcurrent, undervoltage, phase reversal, and all power elements.
I2 / I1 < 20%
V2 / V1 > 25%
I1 > 0.075 x CT
99ms
AND
0
V1 > 0.05 x Full Scale
Breaker Status = Online
OR
99ms
V1 < 0.05 × Full Scale
Block
Appropriate
Elements
&
Operate
Alarm
Relay
AND
0
FIGURE 5–26: VT Fuse Failure Logic
5–92
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
5.11.5 Demand
PATH: SETPOINTS ZV S10 MONITORING ZV CURRENT DEMAND...
„
CURRENT
„ MW DEMAND
„ Mvar DEMAND
„ MVA DEMAND
CURRENT DEMAND
PERIOD: 15 min.
Range: 5 to 90 min. in steps of 1
MESSAGE
CURRENT DEMAND
ALARM: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN ALARM
RELAYS (2-5): ---5
Range: Any combination of Relays 2 to
5
MESSAGE
CURRENT DEMAND
LIMIT: 1.25 x FLA
Range: 0.10 to 20.00 × FLA in steps of
0.01
MESSAGE
CURRENT DEMAND
ALARM EVENTS: Off
Range: On, Off
MW DEMAND
PERIOD: 15 min.
Range: 5 to 90 min. in steps of 1
MESSAGE
MW DEMAND
ALARM: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN ALARM
RELAYS (2-5): ---5
Range: Any combination of Relays 2 to
5
MESSAGE
MW DEMAND
LIMIT: 1.25 x Rated
Range: 0.10 to 2.00 × Rated in steps of
0.01
MESSAGE
MW DEMAND
ALARM EVENTS: Off
Range: On, Off
Mvar DEMAND
PERIOD: 15 min.
Range: 5 to 90 min. in steps of 1
MESSAGE
Mvar DEMAND
ALARM: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN ALARM
RELAYS (2-5): ---5
Range: Any combination of Relays 2 to
5
MESSAGE
Mvar DEMAND
LIMIT: 1.25 x Rated
Range: 0.10 to 2.00 × Rated in steps of
0.01
MESSAGE
Mvar DEMAND
ALARM EVENTS: Off
Range: On, Off
MVA DEMAND
PERIOD: 15 min.
Range: 5 to 90 min. in steps of 1
MESSAGE
MVA DEMAND
ALARM: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN ALARM
RELAYS (2-5): ---5
Range: Any combination of Relays 2 to
5
MESSAGE
MVA DEMAND
LIMIT: 1.25 x Rated
Range: 0.10 to 2.00 × Rated in steps of
0.01
[Z]
[Z]
[Z]
[Z]
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
5–93
CHAPTER 5: SETPOINTS
Range: On, Off
MVA DEMAND
ALARM EVENTS: Off
MESSAGE
The 489 can measure the demand of the generator for several parameters (current, MW,
Mvar, MVA). The demand values of generators may be of interest for energy management
programs where processes may be altered or scheduled to reduce overall demand on a
feeder. The generator FLA is calculated as:
Generator Rated MVA
Generator FLA = ------------------------------------------------------------------------------------------------------------3 × Generator Rated Phase-Phase Voltage
(EQ 5.40)
Power quantities are programmed as per unit calculated from the rated MVA and rated
power factor.
Demand is calculated in the following manner. Every minute, an average magnitude is
calculated for current, +MW, +Mvar, and MVA based on samples taken every 5 seconds.
These values are stored in a FIFO (First In, First Out buffer).The size of the buffer is dictated
by the period that is selected for the setpoint. The average value of the buffer contents is
calculated and stored as the new demand value every minute. Demand for real and
reactive power is only positive quantities (+MW and +Mvar).
1
Demand = --N
N
∑
n=1
Average N
(EQ 5.41)
where: N = programmed Demand Period in minutes,
n = time in minutes
160
MAGNITUDE
140
120
100
80
60
40
20
0
t=0
t+10
t+20
t+30
t+40
t+50
t+60
t+70
t+80
TIME
t+90
t+100
808717A1.CDR
FIGURE 5–27: Rolling Demand (15 Minute Window)
5.11.6 Pulse Output
PATH: SETPOINTS ZV S10 MONITORING ZV PULSE OUTPUT
„
PULSE
5–94
POS. kWh PULSE OUT
RELAYS (2-5): ----
Range: Any combination of Relays 2 to
5
MESSAGE
POS. kWh PULSE OUT
INTERVAL: 10 kWh
Range: 1 to 50000 kWh in steps of 1
MESSAGE
POS. kvarh PULSE OUT
RELAYS (2-5): ----
Range: Any combination of Relays 2 to
5
[Z]
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
MESSAGE
POS. kvarh PULSE OUT
INTERVAL: 10 kvarh
Range: 1 to 50000 kvarh in steps of 1
MESSAGE
NEG. kvarh PULSE OUT
RELAYS (2-5): ----
Range: Any combination of Relays 2 to
5
MESSAGE
NEG. kvarh PULSE OUT
INTERVAL: 10 kvarh
Range: 1 to 50000 kvarh in steps of 1
MESSAGE
PULSE WIDTH:
200 ms
Range: 200 to 1000 ms in steps of 1
The 489 can perform pulsed output of positive kWh and both positive and negative kvarh.
Each output parameter can be assigned to any one of the alarm or auxiliary relays. Pulsed
output is disabled for a parameter if the relay setpoint is selected as OFF for that pulsed
output. The minimum time between pulses is fixed to 400 milliseconds.
This feature should be programmed so that no more than one pulse per 600 milliseconds is
required or the pulsing will lag behind the interval activation. Do not assign pulsed outputs
to the same relays as alarms and trip functions.
Note
normally open (NO) contact
→
status
↓
OPEN
status
↓
CLOSED
status
↓
OPEN
normally closed (NC) contact
→
CLOSED
OPEN
CLOSED
PULSE
WIDTH
808738A1.CDR
FIGURE 5–28: Pulse Output
5.11.7 Running Hour Setup
PATH: SETPOINTS ZV S10 MONITORING ZV RUNNING HOUR SETUP
„
RUNNING
INITIAL GEN. RUNNING
HOURS: 0 h
Range: 0 to 999999 h in steps of 1
MESSAGE
GEN. RUNNING HOURS
ALARM: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN ALARM
RELAYS (2-5): ---5
Range: Any combination of Relays 2 to
5
MESSAGE
GEN. RUNNING HOURS
LIMIT: 1000 h
Range: 1 to 1000000 h in steps of 1
[Z]
The 489 can measure the generator running hours. This value may be of interest for
periodic maintenance of the generator. The initial generator running hour allows the user
to program existing accumulated running hours on a particular generator the relay is
protecting. This feature switching 489 relays without losing previous generator running
hour values.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
5–95
CHAPTER 5: SETPOINTS
5.12 S11 Analog Inputs/Outputs
5.12.1 Analog Outputs 1 to 4
PATH: SETPOINTS ZV S11 ANALOG I/O Z ANALOG OUTPUT 1(4)
„
ANALOG
„
ANALOG
„
ANALOG
„
ANALOG
ANALOG OUTPUT 1:
Real Power (MW)
Range: See Table 5–8: Analog Output
Parameters on page –97.
MESSAGE
REAL POWER (MW)
MIN: 0.00 x Rated
Range: 0.00 to 2.00 × Rated in steps of
0.01
MESSAGE
REAL POWER (MW)
MAX: 1.25 x Rated
Range: 0.00 to 2.00 × Rated in steps of
0.01
ANALOG OUTPUT 2:
Apparent Power (MVA)
Range: See Table 5–8: Analog Output
Parameters on page –97.
MESSAGE
APPARENT POWER (MVA)
MIN: 0.00 x Rated
Range: 0.00 to 2.00 × Rated in steps of
0.01
MESSAGE
APPARENT POWER (MVA)
MAX: 1.25 x Rated
Range: 0.00 to 2.00 × Rated in steps of
0.01
ANALOG OUTPUT 3:
Avg. Output Current
Range: See Table 5–8: Analog Output
Parameters on page –97.
MESSAGE
AVG. OUTPUT CURRENT
MIN: 0.00 x FLA
Range: 0.00 to 20.00 × Rated in steps
of 0.01
MESSAGE
AVG. OUTPUT CURRENT
MAX: 1.25 x FLA
Range: 0.00 to 20.00 × Rated in steps
of 0.01
ANALOG OUTPUT 4:
Average Voltage
Range: See Table 5–8: Analog Output
Parameters on page –97.
MESSAGE
AVERAGE VOLTAGE
MIN: 0.00 x Rated
Range: 0.00 to 1.50 × Rated in steps of
0.01
MESSAGE
AVERAGE VOLTAGE
MAX: 1.25 x Rated
Range: 0.00 to 1.50 × Rated in steps of
0.01
[Z]
[Z]
[Z]
[Z]
The 489 has four analog output channels (4 to 20 mA or 0 to 1 mA as ordered). Each
channel may be individually configured to represent a number of different measured
parameters as shown in the table below. The minimum value programmed represents the
4 mA output. The maximum value programmed represents the 20 mA output. All four of
the outputs are updated once every 50 ms. Each parameter may only be used once.
The analog output parameter may be chosen as Real Power (MW) for a 4 to 20 mA output.
If rated power is 100 MW, the minimum is set for 0.00 × Rated, and the maximum is set for
1.00 × Rated, the analog output channel will output 4 mA when the real power
5–96
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
measurement is 0 MW. When the real power measurement is 50 MW, the analog output
channel will output 12 mA. When the real power measurement is 100 MW, the analog
output channel will output 20 mA.
Table 5–8: Analog Output Parameters
Parameter Name
Range / Units
Step
Default
Min.
Max
IA Output Current
0.00 to 20.00 × FLA
0.01
0.00
1.25
IB Output Current
0.00 to 20.00 × FLA
0.01
0.00
1.25
IC Output Current
0.00 to 20.00 × FLA
0.01
0.00
1.25
Avg. Output Current
0.00 to 20.00 × FLA
0.01
0.00
1.25
Neg. Seq. Current
0 to 2000% FLA
1
0
100
Averaged Gen. Load
0.00 to 20.00 × FLA
0.01
0.00
1.25
Hottest Stator RTD
–50 to +250°C or –58 to +482°F
1
0
200
Hottest Bearing RTD
–50 to +250°C or –58 to +482°F
1
0
200
Ambient RTD
–50 to +250°C or –58 to +482°F
1
0
70
RTDs 1 to 12
–50 to +250°C or –58 to +482°F
1
0
200
AB Voltage
0.00 to 1.50 × Rated
0.01
0.00
1.25
BC Voltage
0.00 to 1.50 × Rated
0.01
0.00
1.25
CA Voltage
0.00 to 1.50 × Rated
0.01
0.00
1.25
Volts/Hertz
0.00 to 2.00 × Rated
0.01
0.00
1.50
Frequency
0.00 to 90.00 Hz
0.01
59.00
61.00
Neutral Volt. (3rd)
0 to 25000 V
0.1
0.0
45.0
Average Voltage
0.00 to 1.50 × Rated
0.01
0.00
1.25
Power Factor
0.01 to 1.00 lead/lag
0.01
0.8 lag
0.8 lead
Reactive Power (Mvar)
–2.00 to 2.00 × Rated
0.01
0.00
1.25
Real Power
–2.00 to 2.00 × Rated
0.01
0.00
1.25
Apparent Power
0.00 to 2.00 × Rated
0.01
0.00
1.25
Analog Inputs 1 to 4
–50000 to +50000
1
0
50000
Tachometer
0 to 7200 RPM
1
3500
3700
Thermal Capacity Used
0 to 100%
1
0
100
Current Demand
0.00 to 20.00 × FLA
0.01
0.00
1.25
Mvar Demand
0.00 to 2.00 × Rated
0.01
0.00
1.25
MW Demand
0.00 to 2.00 × Rated
0.01
0.00
1.25
MVA Demand
0.00 to 2.00 × Rated
0.01
0.00
1.25
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
5–97
CHAPTER 5: SETPOINTS
5.12.2 Analog Inputs 1 to 4
PATH: SETPOINTS ZV S11 ANALOG I/O ZV ANALOG INPUT 1(4)
„
ANALOG
ANALOG INPUT1:
Disabled
Range: Disabled, 4-20 mA, 0-20 mA, 01 mA
MESSAGE
ANALOG INPUT1 NAME:
Analog I/P 1
Range: 12 alphanumeric characters
MESSAGE
ANALOG INPUT1 UNITS:
Units
Range: 6 alphanumeric characters
MESSAGE
ANALOG INPUT1
MINIMUM: 0
Range: –50000 to 50000 in steps of 1
MESSAGE
ANALOG INPUT1
MAXIMUM: 100
Range: –50000 to 50000 in steps of 1
MESSAGE
BLOCK ANALOG INPUT1
FROM ONLINE: 0 s
Range: 0 to 5000 sec. in steps of 1
MESSAGE
ANALOG INPUT1
ALARM: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN ALARM
RELAYS (2-5): ---5
Range: Any combination of Relays 2 to
5
MESSAGE
ANALOG INPUT1 ALARM
LEVEL: 10 Units
MESSAGE
ANALOG INPUT1 ALARM
PICKUP: Over
Range: –50000 to 50000 in steps of 1
Units reflect ANALOG INPUT 1
UNITS above
Range: Over, Under
MESSAGE
ANALOG INPUT1 ALARM
DELAY: 0.1 s
Range: 0.1 to 300.0 s in steps of 0.1
MESSAGE
ANALOG INPUT1 ALARM
EVENTS: Off
Range: On, Off
MESSAGE
ANALOG INPUT1
TRIP: Off
Range: Off, Latched, Unlatched
MESSAGE
ASSIGN TRIP
RELAYS (1-4): 1---
Range: Any combination of Relays 1 to
4
MESSAGE
ANALOG INPUT1 TRIP
LEVEL: 20 Units
MESSAGE
ANALOG INPUT1 TRIP
PICKUP: Over
Range: –50000 to 50000 in steps of 1
Units reflect ANALOG INPUT 1
UNITS above
Range: Over, Under
MESSAGE
ANALOG INPUT1 TRIP
DELAY: 0.1 s
[Z]
Range: 0.1 to 300.0 s in steps of 0.1
There are 4 analog inputs (4 to 20 mA, 0 to 20 mA, or 0 to 1 mA) that may be used to
monitor transducers such as vibration monitors, tachometers, pressure transducers, etc.
These inputs may be used for alarm and/or tripping purposes. The inputs are sampled
every 50 ms. The level of the analog input is also available over the communications port.
With the EnerVista 489 Setup program, the level of the transducer may be trended and
graphed.
5–98
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
Before the input may be used, it must be configured. A name may be assigned for the
input, units may be assigned, and a minimum and maxi-mum value must be assigned.
Also, the trip and alarm features may be blocked until the generator is online for a
specified time delay. If the block time is 0 seconds, there is no block and the trip and alarm
features will be active when the generator is offline or online. If a time is programmed
other than 0 seconds, the feature will be disabled when the generator is offline and also
from the time the machine is placed online until the time entered expires. Once the input is
setup, both the trip and alarm features may be configured. In addition to programming a
level and time delay, the PICKUP setpoint may be used to dictate whether the feature picks
up when the measured value is over or under the level.
If a vibration transducer is to be used, program the name as “Vib Monitor”, the units as
“mm/s”, the minimum as “0”, the maximum as “25”, and the Block From Online as “0 s”. Set
the alarm for a reasonable level slightly higher than the normal vibration level. Program a
delay of “3 s” and the pickup as “Over”.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
5–99
CHAPTER 5: SETPOINTS
5.13 S12 Testing
5.13.1 Simulation Mode
PATH: SETPOINTS ZV S12 489 TESTING Z SIMULATION MODE
„
SIMULATION
[Z]
MESSAGE
SIMULATION MODE:
Off
PRE-FAULT TO FAULT
TIME DELAY:
15 s
Range: Off, Simulate Pre-Fault,
Simulate Fault, Pre-Fault to
Fault
Range: 0 to 300 s in steps of 1
The 489 may be placed in several simulation modes. This simulation may be useful for
several purposes. First, it may be used to under-stand the operation of the 489 for learning
or training purposes. Second, simulation may be used during startup to verify that control
circuitry operates as it should in the event of a trip or alarm. In addition, simulation may be
used to verify that setpoints had been set properly in the event of fault conditions.
The SIMULATION MODE setpoint may be entered only if the generator is offline, no current
is measured, and there are no trips or alarms active. The values entered as Pre-Fault
Values will be substituted for the measured values in the 489 when the SIMULATION MODE
is “Simulate Pre-Fault”. The values entered as Fault Values will be substituted for the
measured values in the 489 when the SIMULATION MODE is “Simulate Fault”. If the
SIMULATION MODE is set to “Pre-Fault to Fault”, the Pre-Fault values will be substituted for
the period of time specified by the delay, followed by the Fault values. If a trip occurs, the
SIMULATION MODE reverts to “Off”. Selecting “Off” for the SIMULATION MODE places the 489
back in service. If the 489 measures current or control power is cycled, the SIMULATION
MODE automatically reverts to “Off”.
If the 489 is to be used for training, it might be desirable to allow all parameter averages,
statistical information, and event recording to update when operating in simulation mode.
If however, the 489 has been installed and will remain installed on a specific generator, it
might be desirable assign a digital input to Test Input and to short that input to prevent all
of this data from being corrupted or updated. In any event, when in simulation mode, the
489 In Service LED (indicator) will flash, indicating that the 489 is not in protection mode.
5–100
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
5.13.2 Pre-Fault Setup
PATH: SETPOINTS ZV S12 489 TESTING ZV PRE-FAULT SETUP
„ PREFAULT
PRE-FAULT Iphase
OUTPUT: 0.00 x CT
Range: 0.00 to 20.00 × CT in steps of
0.01
MESSAGE
PRE-FAULT VOLTAGES
PHASE-N: 1.00 x Rated
MESSAGE
PRE-FAULT CURRENT
LAGS VOLTAGE: 0°
Range: 0.00 to 1.50 × Rated in steps of
0.01. Enter as a phase-toneutral quantity.
Range: 0 to 359° in steps of 1
MESSAGE
PRE-FAULT Iphase
NEUTRAL: 0.00 x CT
MESSAGE
PRE-FAULT CURRENT
GROUND: 0.00 x CT
MESSAGE
PRE-FAULT VOLTAGE
NEUTRAL: 0 Vsec
MESSAGE
PRE-FAULT STATOR
RTD TEMP: 40°C
MESSAGE
PRE-FAULT BEARING
RTD TEMP: 40°C
Range: –50 to 250°C in steps of 1
MESSAGE
PRE-FAULT OTHER
RTD TEMP: 40°C
Range: –50 to 250°C in steps of 1
MESSAGE
PRE-FAULT AMBIENT
RTD TEMP: 40°C
Range: –50 to 250°C in steps of 1
MESSAGE
PRE-FAULT SYSTEM
FREQUENCY: 60.0 Hz
Range: 5.0 to 90.0 Hz in steps of 0.1
MESSAGE
PRE-FAULT ANALOG
INPUT 1: 0%
Range: 0 to 100% in steps of 1
MESSAGE
PRE-FAULT ANALOG
INPUT 2: 0%
Range: 0 to 100% in steps of 1
MESSAGE
PRE-FAULT ANALOG
INPUT 3: 0%
Range: 0 to 100% in steps of 1
MESSAGE
PRE-FAULT ANALOG
INPUT 4: 0%
Range: 0 to 100% in steps of 1
[Z]
Range: 0.00 to 20.00 × CT in steps of
0.01 180° phase shift with
respect to Iphase OUTPUT
Range: 0.00 to 20.00 × CT in steps of
0.01. CT is either XXX:1 or
50:0.025
Range 0.0 to 100.0 Vsec in steps of 0.1
Fundamental value only in
secondary units
Range: –50 to 250°C in steps of 1
The values entered under Pre-Fault Values will be substituted for the measured values in
the 489 when the SIMULATION MODE is “Simulate Pre-Fault”.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
5–101
CHAPTER 5: SETPOINTS
5.13.3 Fault Setup
PATH: SETPOINTS ZV S12 489 TESTING ZV FAULT SETUP
„
FAULT
FAULT Iphase
OUTPUT: 0.00 x CT
Range: 0.00 to 20.00 × CT in steps of
0.01
MESSAGE
FAULT VOLTAGES
PHASE-N: 1.00 x Rated
MESSAGE
FAULT CURRENT
LAGS VOLTAGE:
Range: 0.00 to 1.50 × Rated in steps of
0.01. Enter as a phase-toneutral quantity.
Range: 0 to 359° in steps of 1
MESSAGE
FAULT Iphase
NEUTRAL: 0.00 x CT
MESSAGE
FAULT CURRENT
GROUND: 0.00 x CT
MESSAGE
FAULT VOLTAGE
NEUTRAL: 0 Vsec
MESSAGE
FAULT STATOR
RTD TEMP: 40°C
MESSAGE
FAULT BEARING
RTD TEMP: 40°C
Range: –50 to 250°C in steps of 1
MESSAGE
FAULT OTHER
RTD TEMP: 40°C
Range: –50 to 250°C in steps of 1
MESSAGE
FAULT AMBIENT
RTD TEMP: 40°C
Range: –50 to 250°C in steps of 1
MESSAGE
FAULT SYSTEM
FREQUENCY: 60.0 Hz
Range: 5.0 to 90.0 Hz in steps of 0.1
MESSAGE
FAULT ANALOG
INPUT 1: 0%
Range: 0 to 100% in steps of 1
MESSAGE
FAULT ANALOG
INPUT 2: 0%
Range: 0 to 100% in steps of 1
MESSAGE
FAULT ANALOG
INPUT 3: 0%
Range: 0 to 100% in steps of 1
MESSAGE
FAULT ANALOG
INPUT 4: 0%
Range: 0 to 100% in steps of 1
[Z]
0°
Range: 0.00 to 20.00 × CT in steps of
0.01. (180° phase shift with
respect to Iphase OUTPUT)
Range: 0.00 to 20.00 × CT in steps of
0.01. CT is either XXX:1 or
50:0.025
Range: 0.0 to 100.0 Vsec in steps of 0.1
Fundamental value only in
secondary volts
Range: –50 to 250°C in steps of 1
The values entered here are substituted for the measured values in the 489 when the
SIMULATION MODE is “Simulate Fault”.
5.13.4 Test Output Relays
PATH: SETPOINTS ZV S12 489 TESTING ZV TEST OUTPUT RELAYS
„
TEST
5–102
[Z]
FORCE OPERATION OF
RELAYS: Disabled
Range: Disabled, 1 Trip, 2 Auxiliary,
3 Auxiliary, 4 Auxiliary, 5 Alarm,
6 Service, All Relays, No Relays
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 5: SETPOINTS
The test output relays setpoint may be used during startup or testing to verify that the
output relays are functioning correctly. The output relays can be forced to operate only if
the generator is offline, no current is measured, and there are no trips or alarms active. If
any relay is forced to operate, the relay will toggle from its normal state. The appropriate
relay indicator will illuminate at that time. Selecting “Disabled” places the output relays
back in service. If the 489 measures current or control power is cycled, the force operation
of relays setpoint will automatically become disabled and the output relays will revert back
to their normal states.
If any relay is forced, the 489 In Service indicator will flash, indicating that the 489 is not in
protection mode.
5.13.5 Test Analog Output
PATH: SETPOINTS ZV S12 489 TESTING ZV TEST ANALOG OUTPUT
„
TEST
FORCE ANALOG OUTPUTS
FUNCTION: Disabled
Range: Enabled, Disabled
MESSAGE
ANALOG OUTPUT 1
FORCED VALUE: 0%
Range: 0 to 100% in steps of 1
MESSAGE
ANALOG OUTPUT 2
FORCED VALUE: 0%
Range: 0 to 100% in steps of 1
MESSAGE
ANALOG OUTPUT 3
FORCED VALUE: 0%
Range: 0 to 100% in steps of 1
MESSAGE
ANALOG OUTPUT 4
FORCED VALUE: 0%
Range: 0 to 100% in steps of 1
[Z]
These setpoints may be used during startup or testing to verify that the analog outputs are
functioning correctly. The analog outputs can be forced only if the generator is offline, no
current is measured, and there are no trips or alarms active. When the FORCE ANALOG
OUTPUTS FUNCTION is “Enabled”, the output reflects the forced value as a percentage of the
range 4 to 20 mA or 0 to 1 mA. Selecting “Disabled” places all four analog output channels
back in service, reflecting their programmed parameters. If the 489 measures current or
control power is cycled, the force analog output function is automatically disabled and all
analog outputs will revert back to their normal state.
Any time the analog outputs are forced, the In Service indicator will flash, indicating that
the 489 is not in protection mode.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
5–103
CHAPTER 5: SETPOINTS
5.13.6 Comm Port Monitor
PATH: SETPOINTS ZV S12 489 TESTING ZV COMMUNICATION PORT MONITOR
„
COMMUNICATION
MONITOR COMM. PORT:
Computer RS485
Range: Computer RS485, Auxiliary
RS485, Front Panel RS232
MESSAGE
CLEAR COMM.
BUFFERS: No
Range: No, Yes
MESSAGE
LAST Rx BUFFER:
Received OK
MESSAGE
Rx1: 02,03,00,67,00,
03,B4,27
Range: Buffer Cleared, Received OK,
Wrong Slave Addr., Illegal
Function, Illegal Count, Illegal
Reg. Addr., CRC Error, Illegal
Data
Range: received data in HEX
[Z]
MESSAGE
MESSAGE
MESSAGE
Rx2:
Range: received data in HEX
Tx1: 02,03,06,00,64,
00,0A,00,0F
Range: transmit data in HEX
Tx2:
Range: transmit data in HEX
During communications troubleshooting, it can be useful to see the data being transmitted
to the 489 from some master device, as well as the data transmitted back to that master
device. The messages shown here make it possible to view that data. Any of the three
communications ports may be monitored. After the communications buffers are cleared,
any data received from the monitored communications port is stored in Rx1 and Rx2. If the
489 transmits a message, it appears in the Tx1 and Tx2 buffers. In addition to these
buffers, there is a message indicating the status of the last received message.
5.13.7 Factory Service
PATH: SETPOINTS ZV S12 489 TESTING ZV FACTORY SERVICE
„
FACTORY
[Z]
ENTER FACTORY
PASSCODE: 0
Range: N/A
This section is for use by GE Multilin personnel for testing and calibration purposes.
5–104
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
Digital Energy
Multilin
489 Generator Management Relay
Chapter 6: Actual Values
Actual Values
6.1
Overview
6.1.1
Actual Values Main Menu
The actual values message map is shown below.
„ ACTUAL VALUES
A1 STATUS
„
NETWORK STATUS
[Z]
MESSAGE
„
GENERATOR
[Z]
MESSAGE
„ LAST TRIP
DATA
[Z]
„ ALARM STATUS
[Z]
„ TRIP PICKUPS
[Z]
„ ALARM PICKUPS
[Z]
[Z]
MESSAGE
MESSAGE
MESSAGE
MESSAGE
„
DIGITAL
MESSAGE
„ REAL TIME
CLOCK
MESSAGE
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
[Z]
[Z]
See page 6–4.
See page 6–4.
See page 6–5.
See page 6–6.
See page 6–9.
See page 6–12.
See page 6–15.
See page 6–15.
END OF PAGE
6–1
CHAPTER 6: ACTUAL VALUES
„ ACTUAL VALUES
[Z]
A2 METERING DATA
„
CURRENT
[Z]
MESSAGE
„
VOLTAGE
[Z]
MESSAGE
„
POWER
[Z]
MESSAGE
„
TEMPERATURE
[Z]
MESSAGE
„
DEMAND
[Z]
MESSAGE
„
ANALOG
[Z]
MESSAGE
„
SPEED
[Z]
„
PARAMETER
[Z]
MESSAGE
„
RTD
[Z]
MESSAGE
„ ANALOG INPUT
MIN/MAX
[Z]
„
TRIP
[Z]
MESSAGE
„
GENERAL
[Z]
MESSAGE
„
TIMERS
[Z]
[Z]
See page 6–18.
See page 6–19.
See page 6–20.
See page 6–20.
See page 6–21.
See page 6–22.
See page 6–22.
See page 6–23.
END OF PAGE
MESSAGE
„ ACTUAL VALUES
A4 MAINTENANCE
See page 6–17.
END OF PAGE
MESSAGE
„ ACTUAL VALUES
[Z]
A3 LEARNED DATA
See page 6–16.
See page 6–25.
See page 6–27.
See page 6–27.
END OF PAGE
MESSAGE
„ ACTUAL VALUES
[Z]
A5 EVENT RECORD
„
E255
[Z]
MESSAGE
„
E254
[Z]
See page 6–28.
See page 6–28.
↓
6–2
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 6: ACTUAL VALUES
MESSAGE
„
E000
MESSAGE
„ 489 MODEL
INFORMATION
„
CALIBRATION
[Z]
[Z]
See page 6–31.
See page 6–31.
END OF PAGE
MESSAGE
6.1.2
See page 6–28.
END OF PAGE
MESSAGE
„ ACTUAL VALUES
[Z]
A6 PRODUCT INFO.
[Z]
Description
Measured values, maintenance and fault analysis information are accessed in the actual
values. Actual values may be accessed via one of the following methods:
1.
Front panel, using the keys and display.
2.
Front program port and a portable computer running the EnerVista 489 Setup
software supplied with the relay.
3.
Rear terminal RS485 port and a PLC/SCADA system running user-written
software.
Any of these methods can be used to view the same information. However, a computer
makes viewing much more convenient since many variables may be viewed
simultaneously.
Actual value messages are organized into logical groups, or pages, for easy reference, as
shown below. All actual value messages are illustrated and described in blocks throughout
this chapter. All values shown in these message illustrations assume that no inputs
(besides control power) are connected to the 489.
In addition to the actual values, there are also diagnostic and flash messages that appear
only when certain conditions occur. They are described later in this chapter.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
6–3
CHAPTER 6: ACTUAL VALUES
6.2
A1 Status
6.2.1
Network Status
PATH: ACTUAL VALUES Z A1 STATUS ZV NETWORK STATUS
„ NETWORK STATUS
[Z]
Ethernet Lnk Con Dia
Status
[„] [„] [ ]
Range: see description below
This actual value appears when the relay is ordered with the Ethernet (T) option.
The ETHERNET STATUS actual value message indicates the status of the Ethernet link,
connection, and diagnostic via three indicators. The [„] symbol indicates on, and the [ ]
symbol indicates off. There is also a blinking indication.
The box under LNK column indicates the Ethernet link status. If it is on, the Ethernet port is
connected to the network; if it is off, the port is disconnected. This indicator is normally on.
The box under the CON column indicates the connection status. If on, the Ethernet port is
configured and ready to transmit and receive data. If blinking, the Ethernet port is either
active (transmitting or receiving data) or indicating an error if the diagnostic status is also
on or blinking.
The box under the DIA column indicates the diagnostic status. If it is on, then either a fatal
Ethernet port error has occurred or there is a duplicate IP address on the network. If
blinking, then there is a non-fatal network error. Off indicates no errors.
6.2.2
Generator Status
PATH: ACTUAL VALUES Z A1 STATUS Z GENERATOR STATUS
„
GENERATOR
GENERATOR STATUS:
Offline
Range: Online, Offline, Tripped
MESSAGE
GENERATOR THERMAL
CAPACITY USED: 0%
Range: 0 to 100%. Seen only if the
Thermal Model is enabled
MESSAGE
ESTIMATED TRIP TIME
ON OVERLOAD: Never
Range: 0 to 10000 sec., Never. Seen
only if the Thermal Model is
enabled
[Z]
These messages describe the status of the generator at any given point in time. If the
generator has been tripped, is still offline, and the 489 has not yet been reset, the
GENERATOR STATUS will be “Tripped”. The GENERATOR THERMAL CAPACITY USED value
reflects an integrated value of both the stator and rotor thermal capacity used. The values
for ESTIMATED TRIP TIME ON OVERLOAD will appear whenever the 489 thermal model picks
up on the overload curve.
6–4
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 6: ACTUAL VALUES
6.2.3
Last Trip Data
PATH: ACTUAL VALUES Z A1 STATUS ZV LAST TRIP DATA
„ LAST TRIP
DATA
CAUSE OF LAST TRIP:
No Trip to Date
Range: see Note below.
MESSAGE
TIME OF LAST TRIP:
09:00:00.00
Range: hour:min:sec
MESSAGE
DATE OF LAST TRIP:
Jan 01 2001
Range: Month Day Year
MESSAGE
TACHOMETER
PRETRIP: 3600 RPM
Range: 0 to 3600 RPM. Seen only if
Tachometer is assigned.
MESSAGE
A:
C:
0
0
B:
0
A PreTrip
MESSAGE
a:
c:
0
0
b:
0
A PreTrip
MESSAGE
NEG. SEQ. CURRENT
PRETRIP: 0% FLA
Range: 0 to 999999 A. Represents
current measured from output
CTs. Seen only if a trip has
occurred.
Range: 0 to 999999 A. Represents
differential current. Seen only if
differential element is enabled.
Range: 0 to 2000% FLA. Seen only if
there has been a trip.
MESSAGE
GROUND CURRENT
PRETRIP: 0.00 A
Range: 0.00 to 200000.00 A. Not seen if
GROUND CT is “None”
MESSAGE
GROUND CURRENT
PRETRIP: 0.00 Amps
Range: 0.0 to 5000.0 A
MESSAGE
Vab:
Vca:
Range: 0 to 50000 V. Not seen if VT
CONNECTION is “None”
MESSAGE
FREQUENCY
PRETRIP: 0.00 Hz
Range: 0.00 to 90.00 Hz. Not seen if VT
CONNECTION is “None”
MESSAGE
NEUTRAL VOLT (FUND)
PRETRIP: 0.0 V
Range: 0.0 to 25000.0 V. Seen only if
there is a neutral VT.
MESSAGE
NEUTRAL VOLT (3rd)
PRETRIP: 0.0 V
Range: 0.0 to 25000.0 V. Seen only if
there is a neutral VT.
MESSAGE
REAL POWER (MW)
PRETRIP: 0.000
MESSAGE
REACTIVE POWER Mvar
PRETRIP: 0.00 Hz
MESSAGE
APPARENT POWER MVA
PRETRIP: 0.00 Hz
MESSAGE
HOTTEST STATOR RTD
RTD #1: 0°C PreTrip
Range: 0.000 to ±2000.000 MW. Not
seen if VT CONNECTION is
“None”
Range: 0.000 to ±2000.000 Mvar. Not
seen if VT CONNECTION is
“None”
Range: 0.000 to ±2000.000 MVA. Not
seen if VT CONNECTION is
“None”
Range: –50 to 250°C. Seen only if at
least one RTD is “Stator”
MESSAGE
HOTTEST BEARING RTD
RTD #7: 0°C PreTrip
Range: –50 to 250°C. Seen only if at
least one RTD is “Bearing”
MESSAGE
HOTTEST OTHER RTD
RTD #11: 0°C PreTrip
Range: –50 to 250°C. Seen only if at
least one RTD is “Other”
[Z]
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
0
0
Vbc:
0
V PreTrip
6–5
CHAPTER 6: ACTUAL VALUES
NOTE
MESSAGE
AMBIENT RTD
RTD#12: 0°C PreTrip
Range: –50 to 250°C. Seen only if at
least one RTD is Ambient
MESSAGE
ANALOG INPUT 1
PreTrip: 0 Units
Range: –50000 to 50000. Not seen if
ANALOG INPUT 1 is “Disabled”
MESSAGE
ANALOG INPUT 2
PreTrip: 0 Units
Range: –50000 to 50000. Not seen if
ANALOG INPUT 2 is “Disabled”
MESSAGE
ANALOG INPUT 3
PreTrip: 0 Units
Range: –50000 to 50000. Not seen if
ANALOG INPUT 3 is “Disabled”
MESSAGE
ANALOG INPUT 4
PreTrip: 0 Units
Range: –50000 to 50000. Not seen if
ANALOG INPUT 4 is “Disabled”
MESSAGE
Vab/Iab PreTrip:
0.0 Ωsec.
0°
Range: 0 to 65535 Ωsec.; 0 to 359°.
Seen only if Loss of Excitation is
enabled
The range for the CAUSE OF LAST TRIP setpoint is: No Trip to Date, General Inputs A to G,
Sequential Trip, Field-Bkr Discrep., Tachometer, Thermal Model, Offline Overcurrent, Phase
Overcurrent, Neg. Seq. Overcurrent, Ground Overcurrent, Phase Differential, RTDs 1 to 12,
Overvoltage, Undervoltage, Volts/Hertz, Phase Reversal, Underfrequency, Overfrequency,
Neutral O/V, Neutral U/V (3rd), Reactive Power, Reverse Power, Low Forward Power,
Inadvertent Energ., and Analog Inputs 1 to 4.
Immediately prior to issuing a trip, the 489 takes a snapshot of generator parameters and
stores them as pre-trip values; this allows for troubleshooting after the trip occurs. The
cause of last trip message is updated with the current trip and the screen defaults to that
message. All trip features are automatically logged as date and time stamped events as
they occur. This information can be cleared using the S1 489 SETUP ZV CLEAR DATA ZV
CLEAR LAST TRIP DATA setpoint. If the cause of last trip is “No Trip To Date”, the subsequent
pretrip messages will not appear. Last Trip Data will not update if a digital input
programmed as Test Input is shorted.
6.2.4
Alarm Status
PATH: ACTUAL VALUES Z A1 STATUS ZV ALARM STATUS
„ ALARM STATUS
6–6
NO ALARMS
Range: N/A. Message seen when no
alarms are active
MESSAGE
Input A ALARM
STATUS: Active
Range: Active, Latched. See Note
below.
MESSAGE
Input B ALARM
STATUS: Active
Range: Active, Latched. See Note
below.
MESSAGE
Input C ALARM
STATUS: Active
Range: Active, Latched. See Note
below.
MESSAGE
Input D ALARM
STATUS: Active
Range: Active, Latched. See Note
below.
MESSAGE
Input E ALARM
STATUS: Active
Range: Active, Latched. See Note
below.
[Z]
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 6: ACTUAL VALUES
MESSAGE
Input F ALARM
STATUS: Active
Range: Active, Latched. See Note
below.
MESSAGE
Input G ALARM
STATUS: Active
Range: Active, Latched. See Note
below.
MESSAGE
TACHOMETER
ALARM: 3000 RPM
Range: 0 to 3600 RPM
MESSAGE
OVERCURRENT
ALARM: 10.00 x FLA
Range: 0.00 to 20.00 × FLA
MESSAGE
NEG. SEQ. CURRENT
ALARM: 15% FLA
Range: 0 to 100% FLA
MESSAGE
GROUND OVERCURRENT
ALARM: 5.00 A
Range: 0.00 to 200000.00 A. Seen only
if the GE 50:0.025 CT is used.
MESSAGE
GROUND DIRECTIONAL
ALARM: 5.00 A
Range: 0.00 to 200000.00 A
MESSAGE
UNDERVOLTAGE ALARM
Vab= 3245 V 78%
Range: 0 to 20000 V; 50 to 99% of
Rated
MESSAGE
OVERVOLTAGE ALARM
Vab= 4992 V 120%
Range: 0 to 20000 V; 101 to 150% of
Rated
MESSAGE
VOLTS/HERTZ ALARM
PER UNIT V/Hz: 1.15
Range: 0.00 to 2.00. Not seen if VT
CONNECTION is None.
MESSAGE
UNDERFREQUENCY
ALARM: 59.4 Hz
Range: 0.00 to 90.00 Hz
MESSAGE
OVERFREQUENCY
ALARM: 60.6 Hz
Range: 0.00 to 90.00 Hz
MESSAGE
NEUTRAL O/V (FUND)
ALARM: 0.0 V
Range: 0.0 to 25000.0 V
MESSAGE
NEUTRAL U/V (3rd)
ALARM: 0.0 V
Range: 0.0 to 25000.0 V
MESSAGE
REACTIVE POWER Mvar
ALARM: +20.000
Range: –2000.000 to +2000.000 Mvar
MESSAGE
REVERSE POWER
ALARM: –20.000 MW
Range: –2000.000 to +2000.000 MW
MESSAGE
LOW FORWARD POWER
ALARM: –20.000 MW
Range: –2000.000 to +2000.000 MW
MESSAGE
RTD #1
ALARM: 135°C
Range: –50 to +250°C. Top line displays
the RTD name as programmed.
MESSAGE
RTD #2
ALARM: 135°C
Range: –50 to +250°C. Top line displays
the RTD name as programmed.
MESSAGE
RTD #3
ALARM: 135°C
Range: –50 to +250°C. Top line displays
the RTD name as programmed.
MESSAGE
RTD #4
ALARM: 135°C
Range: –50 to +250°C. Top line displays
the RTD name as programmed.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
6–7
CHAPTER 6: ACTUAL VALUES
6–8
MESSAGE
RTD #5
ALARM: 135°C
Range: –50 to +250°C. Top line displays
the RTD name as programmed.
MESSAGE
RTD #6
ALARM: 135°C
Range: –50 to +250°C. Top line displays
the RTD name as programmed.
MESSAGE
RTD #7
ALARM: 135°C
Range: –50 to +250°C. Top line displays
the RTD name as programmed.
MESSAGE
RTD #8
ALARM: 135°C
Range: –50 to +250°C. Top line displays
the RTD name as programmed.
MESSAGE
RTD #9
ALARM: 135°C
Range: –50 to +250°C. Top line displays
the RTD name as programmed.
MESSAGE
RTD #10
ALARM: 135°C
Range: –50 to +250°C. Top line displays
the RTD name as programmed.
MESSAGE
RTD #11
ALARM: 135°C
Range: –50 to +250°C. Top line displays
the RTD name as programmed.
MESSAGE
RTD #12
ALARM: 135°C
Range: –50 to +250°C. Top line displays
the RTD name as programmed.
MESSAGE
OPEN SENSOR ALARM:
RTD # 1 2 3 4 5 6 ...
Range: RTDs 1 to 12
MESSAGE
SHORT/LOW TEMP ALARM
RTD # 7 8 9 10 11 ...
Range: RTDs 1 to 12
MESSAGE
THERMAL MODEL
ALARM: 100% TC USED
Range: 1 to 100%
MESSAGE
TRIP COUNTER
ALARM: 25 Trips
Range: 1 to 10000
MESSAGE
BREAKER FAILURE
ALARM: Active
Range: Active, Latched
MESSAGE
TRIP COIL MONITOR
ALARM: Active
Range: Active, Latched
MESSAGE
VT FUSE FAILURE
ALARM: Active
Range: Active, Latched
MESSAGE
CURRENT DEMAND
ALARM: 1053 A
Range: 1 to 999999 A
MESSAGE
MW DEMAND
ALARM: 50.500
Range: –2000.000 to +2000.000 MW
MESSAGE
Mvar DEMAND
ALARM: –20.000
Range: –2000.000 to +2000.000 Mvar
MESSAGE
MVA DEMAND
ALARM: 20.000
Range: 0 to 2000.000 MVA
MESSAGE
GEN. RUNNING HOURS
ALARM: 1000 h
Range: 0 to 1000000 hrs. Seen only if
Running Hr. Alarm is enabled.
MESSAGE
ANALOG I/P 1
ALARM: 201 Units
Range: –50000 to +50000
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 6: ACTUAL VALUES
MESSAGE
ANALOG I/P 2
ALARM: 201 Units
Range: –50000 to +50000
MESSAGE
ANALOG I/P 3
ALARM: 201 Units
Range: –50000 to +50000
MESSAGE
ANALOG I/P 4
ALARM: 201 Units
Range: –50000 to +50000
MESSAGE
ALARM, 489 NOT
INSERTED PROPERLY
Range: N/A
MESSAGE
489 NOT IN SERVICE
Simulation Mode
MESSAGE
IRIG-B FAILURE
ALARM: Active
Range: Not Programmed, Simulation
Mode, Output Relays Forced,
Analog Output Forced, Test
Switch Shorted
Range: Active. Seen only if IRIG-B is
enabled and the associated
signal input is lost.
Any active or latched alarms may be viewed here.
The various alarm and alarm status actual values reflect the Input Name as programmed
in the first line of the message. The status is “Active” if the condition that caused the alarm
is still present.
If the 489 chassis is only partially engaged with the case, the ALARM, 489 NOT INSERTED
PROPERLY service alarm appears after 1 sec. Secure the chassis handle to ensure that all
contacts mate properly.
6.2.5
Trip Pickups
PATH: ACTUAL VALUES Z A1 STATUS ZV TRIP PICKUPS
„ TRIP PICKUPS
Input A
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip
MESSAGE
Input B
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip
MESSAGE
Input C
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip
MESSAGE
Input D
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip
MESSAGE
Input E
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip
MESSAGE
Input F
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip
MESSAGE
Input G
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip
MESSAGE
SEQUENTIAL TRIP
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip
MESSAGE
FIELD-BKR DISCREP.
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip
[Z]
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
6–9
CHAPTER 6: ACTUAL VALUES
6–10
MESSAGE
TACHOMETER
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip
MESSAGE
OFFLINE OVERCURRENT
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip.
MESSAGE
INADVERTENT ENERG.
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip.
MESSAGE
PHASE OVERCURRENT
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip.
MESSAGE
NEG. SEQ. OVERCURRENT
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip.
MESSAGE
GROUND OVERCURRENT
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip.
MESSAGE
PHASE DIFFERENTIAL
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip.
MESSAGE
GROUND DIRECTIONAL
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip.
MESSAGE
HIGH-SET PHASE O/C
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip.
MESSAGE
UNDERVOLTAGE
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip.
MESSAGE
OVERVOLTAGE
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip.
MESSAGE
VOLTS/HERTZ
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip.
MESSAGE
PHASE REVERSAL
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip.
MESSAGE
UNDERFREQUENCY
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip.
MESSAGE
OVERFREQUENCY
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip.
MESSAGE
NEUTRAL O/V (FUND)
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip.
MESSAGE
NEUTRAL U/V (3rd)
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip.
MESSAGE
LOSS OF EXCITATION 1
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip.
MESSAGE
LOSS OF EXCITATION 2
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip.
MESSAGE
DISTANCE ZONE 1
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip.
MESSAGE
DISTANCE ZONE 2
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 6: ACTUAL VALUES
MESSAGE
REACTIVE POWER
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip.
MESSAGE
REVERSE POWER
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip.
MESSAGE
LOW FORWARD POWER
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip.
MESSAGE
RTD #1
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip.
MESSAGE
RTD #2
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip.
MESSAGE
RTD #3
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip.
MESSAGE
RTD #4
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip.
MESSAGE
RTD #5
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip.
MESSAGE
RTD #6
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip.
MESSAGE
RTD #7
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip.
MESSAGE
RTD #8
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip.
MESSAGE
RTD #9
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip.
MESSAGE
RTD #10
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip.
MESSAGE
RTD #11
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip.
MESSAGE
RTD #12
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip.
MESSAGE
THERMAL MODEL
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip.
MESSAGE
ANALOG I/P 1
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip
MESSAGE
ANALOG I/P 2
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip
MESSAGE
ANALOG I/P 3
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip
MESSAGE
ANALOG I/P 4
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing
Out, Active Trip, Latched Trip
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
6–11
CHAPTER 6: ACTUAL VALUES
The various trip pickup actual values reflect the Input Name as programmed in the first line
of the message. The various digital and analog input functions are shown only if the
function has been assigned as an input.
Note
The trip pickup messages may be very useful during testing. They will indicate if a trip
feature has been enabled, if it is inactive (not picked up), timing out (picked up and timing),
active trip (still picked up, timed out, and causing a trip), or latched tip (no longer picked up,
but had timed out and caused a trip that is latched). These values may also be particularly
useful as data transmitted to a master device for monitoring.
6.2.6
Alarm Pickups
PATH: ACTUAL VALUES Z A1 STATUS ZV ALARM PICKUPS
„ ALARM PICKUPS
6–12
Input A
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
Input B
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
Input C
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
Input D
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
Input E
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
Input F
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
Input G
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
TACHOMETER
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
OVERCURRENT
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
NEG. SEQ. OVERCURRENT
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
GROUND OVERCURRENT
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
GROUND DIRECTIONAL
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
UNDERVOLTAGE
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
OVERVOLTAGE
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
VOLTS/HERTZ
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
[Z]
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 6: ACTUAL VALUES
MESSAGE
UNDERFREQUENCY
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
OVERFREQUENCY
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
NEUTRAL O/V (FUND)
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
NEUTRAL U/V (3rd)
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
REACTIVE POWER
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
REVERSE POWER
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
LOW FORWARD POWER
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
RTD #1
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
RTD #2
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
RTD #3
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
RTD #4
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
RTD #5
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
RTD #6
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
RTD #7
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
RTD #8
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
RTD #9
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
RTD #10
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
RTD #11
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
RTD #12
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
OPEN SENSOR
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
SHORT/LOW TEMP
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
6–13
CHAPTER 6: ACTUAL VALUES
Note
MESSAGE
THERMAL MODEL
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
TRIP COUNTER
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
BREAKER FAILURE
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
TRIP COIL MONITOR
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
VT FUSE FAILURE
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
CURRENT DEMAND
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
MW DEMAND
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
Mvar DEMAND
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
MVA DEMAND
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
GEN. RUNNING HOURS
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
ANALOG I/P 1
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
ANALOG I/P 2
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
ANALOG I/P 3
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
MESSAGE
ANALOG I/P 4
PICKUP: Not Enabled
Range: Not Enabled, Inactive, Timing Out,
Active Alarm, Latched Alarm.
The various alarm pickup actual values reflect the Input Name as programmed in the first
line of the message. The various digital and analog input functions are shown only if the
function has been assigned as an input.
The alarm pickup messages may be very useful during testing. They will indicate if a alarm
feature has been enabled, if it is inactive (not picked up), timing out (picked up and timing),
active alarm (still picked up, timed out, and causing an alarm), or latched alarm (no longer
picked up, but had timed out and caused a alarm that is latched). These values may also be
particularly useful as data transmitted to a master device for monitoring.
6–14
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 6: ACTUAL VALUES
6.2.7
Digital Inputs
PATH: ACTUAL VALUES Z A1 STATUS ZV DIGITAL INPUTS
„ DIGITAL
INPUTS
ACCESS
SWITCH STATE: Open
Range: Open, Shorted
MESSAGE
BREAKER STATUS
SWITCH STATE: Open
Range: Open, Shorted
MESSAGE
ASSIGNABLE DIGITAL
INPUT1 STATE: Open
Range: Open, Shorted
MESSAGE
ASSIGNABLE DIGITAL
INPUT2 STATE: Open
Range: Open, Shorted
MESSAGE
ASSIGNABLE DIGITAL
INPUT3 STATE: Open
Range: Open, Shorted
MESSAGE
ASSIGNABLE DIGITAL
INPUT4 STATE: Open
Range: Open, Shorted
MESSAGE
ASSIGNABLE DIGITAL
INPUT5 STATE: Open
Range: Open, Shorted
MESSAGE
ASSIGNABLE DIGITAL
INPUT6 STATE: Open
Range: Open, Shorted
MESSAGE
ASSIGNABLE DIGITAL
INPUT7 STATE: Open
Range: Open, Shorted
MESSAGE
TRIP COIL
SUPERVISION: No Coil
Range: Open, Shorted
[Z]
The messages shown here may be used to monitor digital input status. This may be useful
during relay testing or during installation.
6.2.8
Real Time Clock
PATH: ACTUAL VALUES Z A1 STATUS ZV REAL TIME CLOCK
„ REAL TIME
CLOCK
[Z]
DATE: 01/01/2001
TIME: 12:00:00
Range: 01/01/2001 to 12/31/2099,
00:00:00 to 23:59:59
The time and date from the 489 real time clock may be viewed here.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
6–15
CHAPTER 6: ACTUAL VALUES
6.3
A2 Metering Data
6.3.1
Current Metering
PATH: ACTUAL VALUES ZV A2 METERING DATA Z CURRENT METERING
„
CURRENT
6–16
A:
C:
0
0
B:
Amps
0
Range: 0 to 999999 A
MESSAGE
a:
c:
0
0
b:
0
Neut.Amps
Range: 0 to 999999 A
MESSAGE
a:
c:
0
0
MESSAGE
AVERAGE PHASE
CURRENT: 0 Amps
Range: 0 to 999999 A
MESSAGE
GENERATOR LOAD:
0% FLA
Range: 0 to 2000% FLA
MESSAGE
NEGATIVE SEQUENCE
CURRENT: 0% FLA
Range: 0 to 2000% FLA
MESSAGE
PHASE A CURRENT:
0 A
0° Lag
Range: 0 to 999999 A, 0 to 359°
MESSAGE
PHASE B CURRENT:
0 A
0° Lag
Range: 0 to 999999 A, 0 to 359°
MESSAGE
PHASE C CURRENT:
0 A
0° Lag
Range: 0 to 999999 A, 0 to 359°
MESSAGE
NEUT. END A CURRENT:
0 A
0° Lag
Range: 0 to 999999 A, 0 to 359°
MESSAGE
NEUT. END B CURRENT:
0 A
0° Lag
Range: 0 to 999999 A, 0 to 359°
MESSAGE
NEUT. END C CURRENT:
0 A
0° Lag
Range: 0 to 999999 A, 0 to 359°
MESSAGE
DIFF. A CURRENT:
0 A
0° Lag
Range: 0 to 999999 A, 0 to 359°
MESSAGE
DIFF. B CURRENT:
0 A
0° Lag
Range: 0 to 999999 A, 0 to 359°
MESSAGE
DIFF. C CURRENT:
0 A
0° Lag
Range: 0 to 999999 A, 0 to 359°
MESSAGE
GROUND CURRENT:
0.0 A
0° Lag
MESSAGE
GROUND CURRENT:
0.00 A
0° Lag
Range: 0.0 to 200000.0 A, 0 to 359°.
Seen only if 1 A or 5 A Ground
CT is used
Range: 0.00 to 100.00 A, 0 to 359°.
Seen only if 50:0.025 CT is used
[Z]
b:
0
Diff.Amps
Range: 0 to 999999 A
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 6: ACTUAL VALUES
All measured current values are displayed here. A, B, C AMPS represent the output side CT
measurements: A, B, C NEUT. AMPS the neutral end CT measurements, and A, B, C DIFF. AMPS
the differential operating current calculated as the vector difference between the output
side and the neutral end CT measurements on a per phase basis. The 489 negativesequence current is defined as the ratio of negative-sequence current to generator rated
FLA, I2 / FLA × 100%. The generator full load amps is calculated as: generator rated MVA /
( 3 × generator phase-to-phase voltage). Polar coordinates for measured currents are
also shown using Va (wye connection) or Vab (open delta connection) as a zero angle
reference vector. In the absence of a voltage signal (Va or Vab), the IA output current is
used as the zero angle reference vector.
6.3.2
Voltage Metering
PATH: ACTUAL VALUES ZV A2 METERING DATA ZV VOLTAGE METERING
„
VOLTAGE
[Z]
Vab:
Vca:
0
0
Vbc:
Volts
0
Range: 0 to 50000 V. Not seen if VT
CONNECTION is “None”.
Range: 0 to 50000 V. Not seen if VT
CONNECTION is “None”.
MESSAGE
AVERAGE LINE
VOLTAGE: 0 Volts
MESSAGE
Van:
Vcn:
MESSAGE
AVERAGE PHASE
VOLTAGE: 0 Volts
Range: 0 to 50000 V. Not seen if VT
CONNECTION is “Wye”.
MESSAGE
LINE A-B VOLTAGE:
0 V
0° Lag
MESSAGE
LINE B-C VOLTAGE:
0 V
0° Lag
Range: 0 to 50000 V, 0 to 359°. Not
seen if VT CONNECTION is
“None”.
Range: as above
MESSAGE
LINE C-A VOLTAGE:
0 V
0° Lag
Range: as above
MESSAGE
PHASE A-N VOLTAGE:
0 V
0° Lag
MESSAGE
PHASE B-N VOLTAGE:
0 V
0° Lag
Range: 0 to 50000 V, 0 to 359°. Not
seen if VT CONNECTION is
“Wye”.
Range: as above
MESSAGE
PHASE C-N VOLTAGE:
0 V
0° Lag
Range: as above
MESSAGE
PER UNIT MEASUREMENT
OF V/Hz: 0.00
Range: 0.00 to 2.00. Not seen if VT
CONNECTION is “None”.
MESSAGE
FREQUENCY:
0.00 Hz
Range: 0.00 to 90.00 Hz. Not seen if VT
CONNECTION is “None”.
MESSAGE
NEUTRAL VOLTAGE
FUND: 0.0 V
Range: 0.0 to 25000.0 V. Seen only if
there is a neutral VT.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
0
0
Vbn:
Volts
0
Range: 0 to 50000 V. Not seen if VT
CONNECTION is “Wye”.
6–17
CHAPTER 6: ACTUAL VALUES
MESSAGE
NEUTRAL VOLTAGE
3rd HARM: 0.0 V
Range: 0.0 to 25000.0 V. Seen only if
there is a neutral VT.
MESSAGE
TERMINAL VOLTAGE
3rd HARM: 0.0 V
Range: 0.0 to 25000.0 V. Seen only if VT
CONNECTION is “Wye”.
MESSAGE
IMPEDANCE Vab / Iab
0.0 Ω sec.
0°
Range: 0.0 to 6553.5 Ωsec., 0 to 359°
Measured voltage parameters will be displayed here. The V/Hz measurement is a per unit
value based on Vab voltage/measured frequency divided by generator phase-to-phase
nominal voltage/nominal system frequency. Polar coordinates for measured phase and/or
line voltages are also shown using Va (wye connection) or Vab (open delta connection) as a
zero angle reference vector. In the absence of a voltage signal (Va or Vab), IA output current
is used as the zero angle reference vector.
If VT CONNECTION TYPE is programmed as “None” and NEUTRAL VOLTAGE TRANSFORMER is
“No” in S2 SYSTEM, the THIS FEATURE NOT PROGRAMMED flash message will appear
when an attempt is made to enter this group of messages.
6.3.3
Power Metering
PATH: ACTUAL VALUES ZV A2 METERING DATA ZV POWER METERING
„ POWER
METERING
POWER FACTOR:
0.00
Range: 0.01 to 0.99 Lead or Lag, 0.00,
1.00
MESSAGE
REAL POWER:
0.000 MW
Range: 0.000 to ±2000.000 MW
MESSAGE
REACTIVE POWER:
0.000 Mvar
Range: 0.000 to ±2000.000 Mvar
MESSAGE
APPARENT POWER:
0.000 MVA
Range: 0.000 to 2000.000 MVA
MESSAGE
POSITIVE WATTHOURS:
0.000 MWh
Range: 0.000 to 4000000.000 MWh
MESSAGE
POSITIVE VARHOURS:
0.000 Mvarh
Range: 0.000 to 4000000.000 Mvarh
MESSAGE
NEGATIVE VARHOURS:
0.000 Mvarh
Range: 0.000 to 4000000.000 Mvarh
[Z]
The values for power metering appear here. Three-phase total power quantities are
displayed here. Watthours and varhours are also shown here. Watthours and varhours will
not update if a digital input programmed as Test Input is shorted.
Note
An induction generator, by convention generates Watts and consumes vars (+W and –
vars). A synchronous generator can also generate vars (+vars).
If the VT CONNECTION TYPE is programmed as “None”, the THIS FEATURE NOT
PROGRAMMED flash message will appear when an attempt is made to enter this group of
messages.
6–18
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 6: ACTUAL VALUES
6.3.4
Temperature
PATH: ACTUAL VALUES ZV A2 METERING DATA ZV TEMPERATURE
„
TEMPERATURE
Note
MESSAGE
RTD #1
TEMPERATURE: 40°C
Range: –50 to 250°C, No RTD Seen only
if at least 1 RTD programmed
as Stator
Range: –50 to 250°C, No RTD (open)
--- (shorted)
MESSAGE
RTD #2
TEMPERATURE: 40°C
Range: –50 to 250°C, No RTD (open)
--- (shorted)
MESSAGE
RTD #3
TEMPERATURE: 40°C
Range: –50 to 250°C, No RTD (open)
--- (shorted)
MESSAGE
RTD #4
TEMPERATURE: 40°C
Range: –50 to 250°C, No RTD (open)
--- (shorted)
MESSAGE
RTD #5
TEMPERATURE: 40°C
Range: –50 to 250°C, No RTD (open)
--- (shorted)
MESSAGE
RTD #6
TEMPERATURE: 40°C
Range: –50 to 250°C, No RTD (open)
--- (shorted)
MESSAGE
RTD #7
TEMPERATURE: 40°C
Range: –50 to 250°C, No RTD (open)
--- (shorted)
MESSAGE
RTD #8
TEMPERATURE: 40°C
Range: –50 to 250°C, No RTD (open)
--- (shorted)
MESSAGE
RTD #9
TEMPERATURE: 40°C
Range: –50 to 250°C, No RTD (open)
--- (shorted)
MESSAGE
RTD #10
TEMPERATURE: 40°C
Range: –50 to 250°C, No RTD (open)
--- (shorted)
MESSAGE
RTD #11
TEMPERATURE: 40°C
Range: –50 to 250°C, No RTD (open)
--- (shorted)
MESSAGE
RTD #12
TEMPERATURE: 40°C
Range: –50 to 250°C, No RTD (open)
--- (shorted)
[Z]
HOTTEST STATOR RTD
RTD#1: 40°C
These messages are seen only if the corresponding RTDs are programmed. The actual
messages reflect the RTD Names as programmed.
The current level of the 12 RTDs will be displayed here. If the RTD is not connected, the
value will be “No RTD”. If the RTD is shorted, then “---” will be displayed. If no RTDs are
programmed in the S7 RTD TEMPERATURE setpoints menu, the THIS FEATURE NOT
PROGRAMMED flash message will appear when an attempt is made to enter this group of
messages.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
6–19
CHAPTER 6: ACTUAL VALUES
6.3.5
Demand Metering
PATH: ACTUAL VALUES ZV A2 METERING DATA ZV DEMAND METERING
„ DEMAND
METERING
CURRENT
DEMAND: 0 Amps
Range: 0 to 999999 A
MESSAGE
MW DEMAND:
0.000 MW
Range: 0 to 2000.000 MW. Not seen if
VT CONNECTION TYPE is None
MESSAGE
Mvar DEMAND:
0.000 Mvar
Range: 0 to 2000.000 Mvar. Not seen if
VT CONNECTION TYPE is None
MESSAGE
MVA DEMAND:
0.000 MVA
Range: 0 to 2000.000 MVA. Not seen if
VT CONNECTION TYPE is None
MESSAGE
PEAK CURRENT
DEMAND: 0 Amps
Range: 0 to 999999 A
MESSAGE
PEAK MW DEMAND:
0.000 MW
Range: 0 to 2000.000 MW. Not seen if
VT CONNECTION TYPE is None
MESSAGE
PEAK Mvar DEMAND:
0.000 Mvar
Range: 0 to 2000.000 Mvar. Not seen if
VT CONNECTION TYPE is None
MESSAGE
PEAK MVA DEMAND:
0.000 MVA
Range: 0 to 2000.000 MVA. Not seen if
VT CONNECTION TYPE is None
[Z]
The values for current and power demand are shown here. This peak demand information
can be cleared using the S1 489 SETUP ZV CLEAR DATA ZV CLEAR PEAK DEMAND setpoint.
Demand is shown only for positive real and positive reactive power (+Watts, +vars). Peak
demand will not update if a digital input programmed as Test Input is shorted.
6.3.6
Analog Inputs
PATH: ACTUAL VALUES ZV A2 METERING DATA ZV ANALOG INPUTS
„ ANALOG
INPUTS
Note
ANALOG I/P 1
0 Units
Range: –50000 to 50000.
MESSAGE
ANALOG I/P 2
0 Units
Range: –50000 to 50000.
MESSAGE
ANALOG I/P 3
0 Units
Range: –50000 to 50000.
MESSAGE
ANALOG I/P 4
0 Units
Range: –50000 to 50000.
[Z]
These messages are seen only if the corresponding Analog Inputs are programmed. The
actual messages reflect the Analog Input Names as programmed.
The values for analog inputs are shown here. The name of the input and the units will
reflect those programmed for each input. If no analog inputs are programmed in the S11
ANALOG I/O setpoints page, the THIS FEATURE NOT PROGRAMMED flash message will
appear when an attempt is made to enter this group of messages.
6–20
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 6: ACTUAL VALUES
6.3.7
Speed
PATH: ACTUAL VALUES ZV A2 METERING DATA ZV SPEED
„ SPEED
[Z]
TACHOMETER: 0 RPM
Range: 0 to 7200 RPM
If the Tachometer function is assigned to one of the digital inputs, its speed be viewed here.
If no digital input is configured for tachometer, the THIS FEATURE NOT PROGRAMMED
flash message will appear when an attempt is made to enter this group of messages.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
6–21
CHAPTER 6: ACTUAL VALUES
6.4
A3 Learned Data
6.4.1
Parameter Averages
PATH: ACTUAL VALUES ZV A3 LEARNED DATA Z PARAMETER AVERAGES
„ PARAMETER
AVERAGES
AVERAGE GENERATOR
LOAD: 100% FLA
Range: 0 to 2000% FLA
MESSAGE
AVERAGE NEG. SEQ.
CURRENT: 0% FLA
Range: 0 to 2000% FLA
MESSAGE
AVERAGE PHASE-PHASE
VOLTAGE:
0 V
Range: 0 to 50000 V. Not seen if VT
CONNECTION is “None”
[Z]
The 489 calculates the average magnitude of several parameters over a period of time.
This time is specified by S1 489 SETUP ZV PREFERENCES ZV PARAMETER AVERAGES CALC.
PERIOD setpoint (default 15 minutes). The calculation is a sliding window and is ignored
when the generator is offline (that is, the value that was calculated just prior to going
offline will be held until the generator is brought back online and a new calculation is
made). Parameter averages will not update if a digital input programmed as Test Input is
shorted.
6.4.2
RTD Maximums
PATH: ACTUAL VALUES ZV A3 LEARNED DATA ZV RTD MAXIMUMS
„
RTD
6–22
RTD #1
MAX. TEMP.: 40°C
Range: –50 to 250°C
MESSAGE
RTD #2
MAX. TEMP.: 40°C
Range: –50 to 250°C
MESSAGE
RTD #3
MAX. TEMP.: 40°C
Range: –50 to 250°C
MESSAGE
RTD #4
MAX. TEMP.: 40°C
Range: –50 to 250°C
MESSAGE
RTD #5
MAX. TEMP.: 40°C
Range: –50 to 250°C
MESSAGE
RTD #6
MAX. TEMP.: 40°C
Range: –50 to 250°C
MESSAGE
RTD #7
MAX. TEMP.: 40°C
Range: –50 to 250°C
MESSAGE
RTD #8
MAX. TEMP.: 40°C
Range: –50 to 250°C
MESSAGE
RTD #9
MAX. TEMP.: 40°C
Range: –50 to 250°C
MESSAGE
RTD #10
MAX. TEMP.: 40°C
Range: –50 to 250°C
[Z]
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 6: ACTUAL VALUES
MESSAGE
RTD #11
MAX. TEMP.: 40°C
Range: –50 to 250°C
MESSAGE
RTD #12
MAX. TEMP.: 40°C
Range: –50 to 250°C
These messages are seen only if the corresponding RTDs are programmed. The actual
messages reflect the RTD Names as programmed.
Note
The 489 will learn the maximum temperature for each RTD. This information can be
cleared using the S1 489 SETUP ZV CLEAR DATA ZV CLEAR RTD MAXIMUMS setpoint. The
RTD maximums will not update if a digital input programmed as Test Input is shorted. If no
RTDs are programmed in the S7 RTD TEMPERATURE setpoints page, the THIS FEATURE
NOT PROGRAMMED flash message will appear when an attempt is made to enter this
group of messages.
6.4.3
Analog Input Min/Max
PATH: ACTUAL VALUES ZV A3 LEARNED DATA ZV ANALOG INPUT MIN/MAX
„ ANALOG INPUT
MIN/MAX
Note
ANALOG I/P 1
MIN: O Units
Range: –50000 to 50000
MESSAGE
ANALOG I/P 1
MAX: 0 Units
Range: –50000 to 50000
MESSAGE
ANALOG I/P 2
MIN: O Units
Range: –50000 to 50000
MESSAGE
ANALOG I/P 2
MAX: 0 Units
Range: –50000 to 50000
MESSAGE
ANALOG I/P 3
MIN: O Units
Range: –50000 to 50000
MESSAGE
ANALOG I/P 3
MAX: 0 Units
Range: –50000 to 50000
MESSAGE
ANALOG I/P 4
MIN: O Units
Range: –50000 to 50000
MESSAGE
ANALOG I/P 4
MAX: 0 Units
Range: –50000 to 50000
[Z]
These messages are seen only if the corresponding Analog Inputs are programmed. The
actual messages reflect the Analog Input Names as programmed.
The 489 learns the minimum and maximum values of the analog inputs since they were
last cleared. This information can be cleared using the S1 489 SETUP ZV CLEAR DATA ZV
CLEAR ANALOG I/P MIN/MAX setpoint. When the data is cleared, the present value of each
analog input will be loaded as a starting point for both minimum and maximum. The name
of the input and the units will reflect those programmed for each input. Analog Input
minimums and maximums will not update if a digital input programmed as Test Input is
shorted.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
6–23
CHAPTER 6: ACTUAL VALUES
If no Analog Inputs are programmed in the S11 ANALOG I/O setpoints menu, the THIS
FEATURE NOT PROGRAMMED flash message will appear when an attempt is made to
enter this group of messages.
6–24
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 6: ACTUAL VALUES
6.5
A4 Maintenance
6.5.1
Trip Counters
PATH: ACTUAL VALUES ZV A4 MAINTENANCE Z TRIP COUNTERS
„
TRIP
TOTAL NUMBER OF
TRIPS: 0
Range: 0 to 50000
MESSAGE
DIGITAL INPUT
TRIPS: 0
Range: 0 to 50000. Caused by the
General Input Trip feature
MESSAGE
SEQUENTIAL
TRIPS: 0
Range: 0 to 50000
MESSAGE
FIELD-BKR DISCREP.
TRIPS: 0
Range: 0 to 50000
MESSAGE
TACHOMETER
TRIPS: 0
Range: 0 to 50000
MESSAGE
OFFLINE OVERCURRENT
TRIPS: 0
Range: 0 to 50000
MESSAGE
PHASE OVERCURRENT
TRIPS: 0
Range: 0 to 50000
MESSAGE
NEG. SEQ. OVERCURRENT
TRIPS: 0
Range: 0 to 50000
MESSAGE
GROUND OVERCURRENT
TRIPS: 0
Range: 0 to 50000
MESSAGE
PHASE DIFFERENTIAL
TRIPS: 0
Range: 0 to 50000
MESSAGE
GROUND DIRECTIONAL
TRIPS: 0
Range: 0 to 50000
MESSAGE
HIGH-SET PHASE O/C
TRIPS: 0
Range: 0 to 50000
MESSAGE
UNDERVOLTAGE
TRIPS: 0
Range: 0 to 50000
MESSAGE
OVERVOLTAGE
TRIPS: 0
Range: 0 to 50000
MESSAGE
VOLTS/HERTZ
TRIPS: 0
Range: 0 to 50000
MESSAGE
PHASE REVERSAL
TRIPS: 0
Range: 0 to 50000
MESSAGE
UNDERFREQUENCY
TRIPS: 0
Range: 0 to 50000
MESSAGE
OVERFREQUENCY
TRIPS: 0
Range: 0 to 50000
[Z]
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
6–25
CHAPTER 6: ACTUAL VALUES
6–26
MESSAGE
NEUTRAL O/V (Fund)
TRIPS: 0
Range: 0 to 50000
MESSAGE
NEUTRAL U/V (3rd)
TRIPS: 0
Range: 0 to 50000
MESSAGE
LOSS OF EXCITATION 1
TRIPS: 0
Range: 0 to 50000
MESSAGE
LOSS OF EXCITATION 2
TRIPS: 0
Range: 0 to 50000
MESSAGE
DISTANCE ZONE 1
TRIPS: 0
Range: 0 to 50000
MESSAGE
DISTANCE ZONE 2
TRIPS: 0
Range: 0 to 50000
MESSAGE
REACTIVE POWER
TRIPS: 0
Range: 0 to 50000
MESSAGE
REVERSE POWER
TRIPS: 0
Range: 0 to 50000
MESSAGE
LOW FORWARD POWER
TRIPS: 0
Range: 0 to 50000
MESSAGE
STATOR RTD
TRIPS: 0
Range: 0 to 50000
MESSAGE
BEARING RTD
TRIPS: 0
Range: 0 to 50000
MESSAGE
OTHER RTD
TRIPS: 0
Range: 0 to 50000
MESSAGE
AMBIENT RTD
TRIPS: 0
Range: 0 to 50000
MESSAGE
THERMAL MODEL
TRIPS: 0
Range: 0 to 50000
MESSAGE
INADVERTENT ENERG.
TRIPS: 0
Range: 0 to 50000
MESSAGE
ANALOG I/P 1
TRIPS: 0
Range: 0 to 50000. Reflects Analog In
Name/units as programmed
MESSAGE
ANALOG I/P 2
TRIPS: 0
Range: 0 to 50000. Reflects Analog In
Name/units as programmed
MESSAGE
ANALOG I/P 3
TRIPS: 0
Range: 0 to 50000. Reflects Analog In
Name/units as programmed
MESSAGE
ANALOG I/P 4
TRIPS: 0
Range: 0 to 50000. Reflects Analog In
Name/units as programmed
MESSAGE
COUNTERS CLEARED:
Jan 1, 2001
Range: Date in format shown
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 6: ACTUAL VALUES
The number of trips by type is displayed here. When the total reaches 50000, all counters
reset. This information can be cleared with the S1 489 SETUP ZV CLEAR DATA ZV
CLEAR TRIP COUNTERS setpoint. Trip counters will not update if a digital input programmed
as Test Input is shorted. In the event of multiple trips, the only the first trip will increment
the trip counters.
6.5.2
General Counters
PATH: ACTUAL VALUES ZV A4 MAINTENANCE ZV GENERAL COUNTERS
„ GENERAL
COUNTERS
[Z]
MESSAGE
NUMBER OF BREAKER
OPERATIONS: 0
Range: 0 to 50000
NUMBER OF THERMAL
RESETS: 0
Range: 0 to 50000. Seen only if a
Digital Input is assigned to
Thermal Reset.
One of the 489 general counters will count the number of breaker operations over time.
This may be useful information for breaker maintenance. The number of breaker
operations is incremented whenever the breaker status changes from closed to open and
all phase currents are zero. Another counter counts the number of thermal resets if one of
the assignable digital inputs is assigned to thermal reset. This may be useful information
when troubleshooting. When either of these counters exceeds 50000, that counter will
reset to 0.
The NUMBER OF BREAKER OPERATIONS counter can also be cleared using the S1 489 SETUP
ZV CLEAR DATA ZV CLEAR BREAKER INFORMATION setpoint. The NUMBER OF THERMAL
RESETS counter can be cleared using the S1 489 SETUP ZV CLEAR DATA ZV CLEAR
GENERATOR INFORMATION setpoint.
The number of breaker operations will not update if a digital input programmed as Test
Input is shorted.
6.5.3
Timers
PATH: ACTUAL VALUES ZV A4 MAINTENANCE ZV TIMERS
„ TIMERS
[Z]
GENERATOR HOURS
ONLINE:
Range: 1 to 1000000 hrs.
0 h
The 489 accumulates the total online time for the generator. This may be useful for
scheduling routine maintenance. When this timer exceeds 1000000, it resets to 0. This
timer can be cleared using the S1 489 SETUP ZV CLEAR DATA ZV CLEAR GENERATOR
INFORMATION setpoint. The generator hours online will not update if a digital input
programmed as Test Input is shorted.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
6–27
CHAPTER 6: ACTUAL VALUES
6.6
A5 Event Recorder
6.6.1
Event Recorder
PATH: ACTUAL VALUES ZV A5 EVENT RECORDER ZV E001(E256)
„ E001
<Cause>
6–28
TIME OF E001:
00:00:00.0
Range: hour: minutes: seconds
MESSAGE
DATE OF E001:
Jan. 01, 2001
Range: month day, year
MESSAGE
ACTIVE
GROUP E001: 1
Range: 1, 2
MESSAGE
TACHOMETER
E001: 3600 RPM
Range: 0 to 3600 RPM. Seen only if a
Digital Input set as Tachometer
MESSAGE
A:
C:
Range: 0 to 999999 A
MESSAGE
a:
c:
MESSAGE
NEG. SEQ. CURRENT
E001: 0% FLA
Range: 0 to 2000% FLA
MESSAGE
GROUND CURRENT
E001: 0.00 A
Range: 0 to 20000.0 A. Not seen if
GROUND CT TYPE is “None”.
MESSAGE
Vab:
Vca:
Range: 0 to 50000 V. Not seen if VT
CONNECTION is “None”.
MESSAGE
FREQUENCY
E001: 0.00 Hz
Range: 0.00 to 90.00 Hz. Not seen if VT
CONNECTION is “None”.
MESSAGE
NEUTRAL VOLT (FUND)
E001:
0.0 V
Range: 0.0 to 25000.0 V. Seen only if
there is a neutral VT.
MESSAGE
NEUTRAL VOLT (3rd)
E001:
0.0 V
Range: 0.0 to 25000.0 V. Seen only if
there is a neutral VT.
MESSAGE
Vab/Iab E001:
0.0 Ωsec.
MESSAGE
REAL POWER (MW)
E001:
0.000
Range: 0.0 to 6553.5 Ωsec., 0 to 359°.
Seen only if the Loss of
Excitation element is Enabled.
Range: 0 to ±2000.000 MW. Not seen if
VT CONNECTION is “None”
MESSAGE
REACTIVE POWER Mvar
E001:
0.000
Range: 0 to ±2000.000 Mvar. Not seen
if VT CONNECTION is “None”
MESSAGE
APPARENT POWER MVA
E001:
0.000
Range: 0 to 2000.000 MVA. Not seen if
VT CONNECTION is “None”
MESSAGE
HOTTEST STATOR
RTD#1: 0°C E001
Range: –50 to +250°C. Seen only if 1 or
more RTDs are set as Stator.
MESSAGE
HOTTEST BEARING
RTD#7: 0°C E001
Range: –50 to +250°C. Seen only if 1 or
more RTDs are set as Bearing.
[Z]
0
0
B:
0
A E001
0
0
b:
NA
0
0
0
E001
Vbc:
0
V E001
0°
Range: 0 to 999999 NA. Represents
neutral end current.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 6: ACTUAL VALUES
MESSAGE
HOTTEST OTHER
RTD#11: 0°C E001
Range: –50 to +250°C. Seen only if 1 or
more RTDs are set as Other.
MESSAGE
AMBIENT
RTD#12 0°C
Range: –50 to +250°C. Seen only if 1 or
more RTDs are set as Ambient.
MESSAGE
ANALOG INPUT 1
E001: 0.0 Units
MESSAGE
ANALOG INPUT 2
E001: 0.0 Units
MESSAGE
ANALOG INPUT 3
E001: 0.0 Units
MESSAGE
ANALOG INPUT 4
E001: 0.0 Units
E001
Range: –50000 to 50000. Reflects the
Analog Input name. Not seen if
Analog Input 1 is disabled.
Range: –50000 to 50000. Reflects the
Analog Input name. Not seen if
Analog Input 2 is disabled.
Range: –50000 to 50000. Reflects the
Analog Input name. Not seen if
Analog Input 3 is disabled.
Range: –50000 to 50000. Reflects the
Analog Input name. Not seen if
Analog Input 4 is disabled.
The 489 Event Recorder stores generator and system information each time an event
occurs. The description of the event is stored and a time and date stamp is also added to
the record.
Note
The event recorder data may be inaccurate if 489 relay power-on time is less than
2 seconds.
The date and time stamping feature allows reconstruction of the sequence of events for
troubleshooting. Events include all trips, any alarm optionally (except Service Alarm, and
489 Not Inserted Alarm, which always records as events), loss of control power, application
of control power, thermal resets, simulation, serial communication starts/stops, and
general input control functions optionally.
E001 is the most recent event and E256 is the oldest event. Each new event bumps the other
event records down until the 256th event is reached. The 256th event record is lost when
the next event occurs. This information can be cleared using S1 489 SETUP ZV CLEAR DATA
ZV CLEAR EVENT RECORD setpoint. The event record will not update if a digital input
programmed as Test Input is shorted.
Table 6–1: Cause of Events (Sheet 1 of 2)
TRIPS
Ambient RTD12 Trip *
Analog I/P 1 to 4 Trip *
Bearing RTD 7 Trip *
Bearing RTD 8 Trip *
Bearing RTD 9 Trip *
Bearing RTD 10 Trip *
Differential Trip
Distance Zone 1 Trip
Distance Zone 2 Trip
Field-Bkr Discr. Trip
Gnd Directional Trip
Ground O/C Trip
Hiset Phase O/C Trip
Inadvertent Energization
Trip
Input A to G Trip *
Loss of Excitation 1
Loss of Excitation 2
Low Fwd Power Trip
Neg Seq O/C Trip
Neutral O/V Trip
Neut. U/V (3rd) Trip
Offline O/C Trip
Overfrequency Trip
Overvoltage Trip
* reflects the name as programmed
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
6–29
CHAPTER 6: ACTUAL VALUES
Table 6–1: Cause of Events (Sheet 2 of 2)
TRIPS
Phase O/C Trip
Phase Reversal Trip
Reactive Power Trip
Reverse Power Trip
RTD11 Trip *
Sequential Trip
Stator RTD 1 Trip *
Stator RTD 2 Trip *
Stator RTD 3 Trip *
Stator RTD 4 Trip *
Stator RTD 5 Trip *
Stator RTD 6 Trip *
Tachometer Trip
Thermal Model Trip
Underfrequency Trip
Undervoltage Trip
Volts/Hertz Trip
ALARMS (OPTIONAL EVENTS)
489 Not Inserted
Ambient RTD12 Alarm *
Analog I/P 1 to 4 Alarm
*
Bearing RTD 7 Alarm
*
Bearing RTD 8 Alarm *
Bearing RTD 9 Alarm *
Bearing RTD 10 Alarm *
Breaker Failure
Current Demand Alarm
Gnd Directional Alarm
Ground O/C Alarm
Input A to G Alarm *
Low Fwd Power Alarm
MVA Demand Alarm
Mvar Demand Alarm
MW Demand Alarm
NegSeq Current Alarm
Neut. U/V 3rd Alarm
Neutral O/V Alarm
Open RTD Alarm
Overcurrent Alarm
Overfrequency Alarm
Overvoltage Alarm
Reactive Power Alarm
Reverse Power Alarm
RTD11 Alarm *
Service Alarm
Short/Low RTD Alarm
Stator RTD 1 Alarm
Stator RTD 2 Alarm
Stator RTD 3 Alarm
Stator RTD 4 Alarm
Stator RTD 5 Alarm
Stator RTD 6 Alarm
Tachometer Alarm
Thermal Model Alarm
Trip Coil Monitor
Trip Counter Alarm
Underfrequency Alarm
Undervoltage Alarm
Volts Per Hertz Alarm
VT Fuse Fail Alarm
OTHER
Control Power Applied
Control Power Lost
Dig I/P Waveform Trig
Input A to G Control *
Serial Comm. Start
Serial Comm. Stop
Serial Waveform Trip
Setpoint 1 Active
Setpoint 2 Active
Simulation Started
Simulation Stopped
Thermal Reset Close
* reflects the name as programmed
6–30
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 6: ACTUAL VALUES
6.7
A6 Product Information
6.7.1
489 Model Info
PATH: ACTUAL VALUES ZV A6 PRODUCT INFO Z 489 MODEL INFO
„ 489 MODEL
INFORMATION
ORDER CODE:
489-P5-HI-A20
Range: N/A
MESSAGE
489 SERIAL NO:
A3260001
Range: N/A
MESSAGE
489 REVISION:
32E100A4.000
Range: N/A
MESSAGE
489 BOOT REVISION:
30K401A0.000
Range: N/A
[Z]
All of the 489 model information may be viewed here when the unit is powered up. In the
event of a product software upgrade or service question, the information shown here
should be jotted down prior to any inquiry.
6.7.2
Calibration Info
PATH: ACTUAL VALUES ZV A6 PRODUCT INFO ZV CALIBRATION INFO
„ CALIBRATION
INFORMATION
[Z]
MESSAGE
ORIGINAL CALIBRATION
DATE: Jan 01 1996
Range: month day year
LAST CALIBRATION
DATE: Jan 01 1996
Range: month day year
The date of the original calibration and last calibration may be viewed here.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
6–31
CHAPTER 6: ACTUAL VALUES
6.8
Diagnostics
6.8.1
Diagnostic Messages
In the event of a trip or alarm, some of the actual value messages are very helpful in
diagnosing the cause of the condition. The 489 will automatically default to the most
important message. The hierarchy is trip and pretrip messages, then alarm messages. In
order to simplify things for the operator, the Message LED (indicator) will flash prompting
the operator to press the MESSAGE X key. When the MESSAGE X key is pressed, the 489
will automatically display the next relevant message and continue to cycle through the
messages with each keypress. When all of these conditions have cleared, the 489 will
revert back to the normal default messages.
Any time the 489 is not displaying the default messages because other actual value or
setpoint messages are being viewed and there are no trips or alarms, the Message LED
(indicator) will be on solid. From any point in the message structure, pressing the
MESSAGE X key will cause the 489 to revert back to the normal default messages. When
normal default messages are being displayed, pressing the MESSAGE X key will cause the
489 to display the next default message immediately.
EXAMPLE:
If a thermal model trip occurred, an RTD alarm may also occur as a result of the overload.
The 489 would automatically default to the CAUSE OF LAST TRIP message at the top of the
A1 STATUS ZV LAST TRIP DATA queue and the Message LED would flash. Pressing the
MESSAGE X key cycles through the time and date stamp information as well as all of the
pre-trip data. When the bottom of this queue is reached, an additional press of the
MESSAGE X key would normally return to the top of the queue. However, because there is
an alarm active, the display will skip to the alarm message at the top of the A1 STATUS ZV
ALARM STATUS queue. Finally, another press of the MESSAGE X key will cause the 489 to
return to the original CAUSE OF LAST TRIP message, and the cycle could be repeated.
LAST TRIP DATA:
CAUSE OF LAST TRIP:
Overload
TIME OF LAST TRIP:
12:00:00.0
DATE OF LAST TRIP
Jan 01 2002
↓
↓
↓
ANALOG INPUT 4
PreTrip: 0 Units
6–32
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 6: ACTUAL VALUES
ACTIVE ALARMS:
START BLOCK
LOCKOUTS:
STATOR RTD #1
ALARM: 135°C
OVERLOAD LOCKOUT
BLOCK: 25 min
When the RESET has been pressed and the hot RTD condition is no longer present, the
display will revert back to the normal default messages.
6.8.2
Flash Messages
Flash messages are warning, error, or general information messages that are temporarily
displayed in response to certain key presses. These messages are intended to assist with
navigation of the 489 messages by explaining what has happened or by prompting the
user to perform certain actions.
Table 6–2: Flash Messages
[.] KEY IS USED TO
ADVANCE THE CURSOR
ACCESS DENIED,
ENTER PASSCODE
ACCESS DENIED,
SHORT ACCESS SWITCH
ALL POSSIBLE RESETS
HAVE BEEN PERFORMED
ARE YOU SURE? PRESS
[ENTER] TO VERIFY
DATA CLEARED
SUCCESSFULLY
DATE ENTRY
OUT OF RANGE
DATE ENTRY WAS
NOT COMPLETE
DEFAULT MESSAGE
HAS BEEN ADDED
DEFAULT MESSAGE
HAS BEEN REMOVED
DEFAULT MESSAGE
LIST IS FULL
DEFAULT MESSAGES
6 TO 20 ARE ASSIGNED
END OF LIST
END OF PAGE
ENTER A NEW
PASSCODE FOR ACCESS
INVALID PASSCODE
ENTERED!
INVALID SERVICE CODE
ENTERED
KEY PRESSED IS
INVALID HERE
NEW PASSCODE
HAS BEEN ACCEPTED
NEW SETPOINT HAS
BEEN STORED
NO ALARMS ACTIVE
NO TRIPS OR ALARMS
TO RESET
OUT OF RANGE.! ENTER:
#### TO ##### BY #
PASSCODE SECURITY
NOT ENABLED, ENTER 0
PRESS [ENTER] TO ADD
DEFAULT MESSAGE
PRESS [ENTER] TO
REMOVE MESSAGE
RESET PERFORMED
SUCCESSFULLY
ROUNDED SETPOINT
HAS BEEN STORED
SETPOINT ACCESS IS
NOW PERMITTED
SETPOINT ACCESS IS
NOW RESTRICTED
TACHOMETER MUST USE
INPUT 4, 5, 6, OR 7
THAT DIGITAL INPUT
IS ALREADY IN USE
THAT INPUT ALREADY
USED FOR TACHOMETER
THIS FEATURE NOT
PROGRAMMED
THIS PARAMETER IS
ALREADY ASSIGNED
TIME ENTRY
OUT OF RANGE
TIME ENTRY WAS
NOT COMPLETE
TOP OF LIST
TOP OF PAGE
•
NEW SETPOINT HAS BEEN STORED: This message appear each time a setpoint has
been altered and stored as shown on the display.
•
ROUNDED SETPOINT HAS BEEN STORED: Since the 489 has a numeric keypad, an
entered setpoint value may fall between valid setpoint values. The 489 detects this
condition and store a value rounded to the nearest valid setpoint value. To find the
valid range and step for a given setpoint, press the HELP key while the setpoint is
being displayed.
•
OUT OF RANGE! ENTER: #### TO ##### BY #: If a setpoint value outside the
acceptable range of values is entered, the 489 displays this message and substitutes
proper values for that setpoint. An appropriate value may then be entered.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
6–33
CHAPTER 6: ACTUAL VALUES
6–34
•
ACCESS DENIED, SHORT ACCESS SWITCH: The Access Switch must be shorted to store
any setpoint values. If this message appears and it is necessary to change a setpoint,
short the Access terminals C1 and C2.
•
ACCESS DENIED, ENTER PASSCODE: The 489 has a passcode security feature. If this
feature is enabled, not only must the Access Switch terminals be shorted, but a valid
passcode must also be entered. If the correct passcode has been lost or forgotten,
contact the factory with the encrypted access code. All passcode features may be
found in the S1 489 SETUP Z PASSCODE setpoints menu.
•
INVALID PASSCODE ENTERED: This flash message appears if an invalid passcode is
entered for the passcode security feature.
•
NEW PASSCODE HAS BEEN ACCEPTED: This message will appear as an acknowledge
that the new passcode has been accepted when changing the passcode for the
passcode security feature.
•
PASSCODE SECURITY NOT ENABLED, ENTER 0: The passcode security feature is
disabled whenever the passcode is zero (factory default). Any attempts to enter a
passcode when the feature is disabled results in this flash message, prompting the
user to enter “0” as the passcode. When this has been done, the feature may be
enabled by entering a non-zero passcode.
•
ENTER A NEW PASSCODE FOR ACCESS: The passcode security feature is disabled if
the passcode is zero. If the CHANGE PASSCODE SETPOINT is entered as yes, this flash
message appears prompting the user to enter a non-zero passcode and enable the
passcode security feature.
•
SETPOINT ACCESS IS NOW PERMITTED: Any time the passcode security feature is
enabled and a valid passcode is entered, this flash message appears to notify that
setpoints may now be altered and stored.
•
SETPOINT ACCESS IS NOW RESTRICTED: If the passcode security feature is enabled
and a valid passcode entered, this message appears when the S1 489 SETUP Z
PASSCODE ZV SETPOINT ACCESS setpoint is altered to “Restricted”. This message also
appears any time that setpoint access is permitted and the access jumper is removed.
•
DATE ENTRY WAS NOT COMPLETE: Since the DATE setpoint has a special format
(entered as MM/DD/YYYY), this message appears and the new value will not be stored
if the ENTER key is pressed before all of the information has been entered. Another
attempt will have to be made with the complete information.
•
DATE ENTRY WAS OUT OF RANGE: Appears if an invalid entry is made for the DATE (for
example, 15 entered for the month).
•
TIME ENTRY WAS NOT COMPLETE: Since the TIME setpoint has a special format
(entered as HH/MM/SS.s), this message appears and the new value will not be stored if
the ENTER key is pressed before all of the information has been entered. Another
attempt will have to be made with the complete information.
•
TIME ENTRY WAS OUT OF RANGE: Appears if an invalid entry is made for the TIME (for
example, 35 entered for the hour).
•
NO TRIPS OR ALARMS TO RESET: Appears if the RESET key is pressed when there are
no trips or alarms present.
•
RESET PERFORMED SUCCESSFULLY: If all trip and alarm features that are active can
be cleared (that is, the conditions that caused these trips and/or alarms are no longer
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 6: ACTUAL VALUES
present), then this message appears when a reset is performed, indicating that all trips
and alarms have been cleared.
•
ALL POSSIBLE RESETS HAVE BEEN PERFORMED: If only some of the trip and alarm
features that are active can be cleared (that is, the conditions that caused some of
these trips and/or alarms are still present), then this message appears when a reset is
performed, indicating that only trips and alarms that could be reset have been reset.
•
ARE YOU SURE? PRESS [ENTER] TO VERIFY: If the RESET key is pressed and resetting
of any trip or alarm feature is possible, this message appears to verify the operation. If
RESET is pressed again while this message is displayed, the reset will be performed.
•
PRESS [ENTER] TO ADD DEFAULT MESSAGE: Appears if the decimal [.] key,
immediately followed by the ENTER key, is entered anywhere in the actual value
message structure. This message prompts the user to press ENTER to add a new
default message. To add a new default message, ENTER must be pressed while this
message is being displayed.
•
DEFAULT MESSAGE HAS BEEN ADDED: Appears anytime a new default message is
added to the default message list.
•
DEFAULT MESSAGE LIST IS FULL: Appears if an attempt is made to add a new default
message to the default message list when 20 messages are already assigned. To add
a new message, one of the existing messages must be removed.
•
PRESS [ENTER] TO REMOVE MESSAGE: Appears if the decimal [.] key, immediately
followed by the ENTER key, is entered in the S1 489 SETUP ZV DEFAULT MESSAGES
setpoint page. This message prompts the user to press ENTER to remove a default
message. To remove the default message, ENTER must be pressed while this message
is being displayed.
•
DEFAULT MESSAGE HAS BEEN REMOVED: Appears anytime a default message is
removed from the default message list.
•
DEFAULT MESSAGES 6 of 20 ARE ASSIGNED: Appears anytime the S1 489 SETUP ZV
DEFAULT MESSAGES setpoint page is entered, notifying the user of the number of
default messages assigned.
•
INVALID SERVICE CODE ENTERED: Appears if an invalid code is entered in the S12 489
TESTING ZV FACTORY SERVICE setpoints page.
•
KEY PRESSED HERE IS INVALID: Under certain situations, certain keys have no
function (for example, any number key while viewing actual values). This message
appears if a keypress has no current function.
•
DATA CLEARED SUCCESSFULLY: Confirms that data is reset in the S1 489 SETUP ZV
CLEAR DATA setpoints page.
•
[.] KEY IS USED TO ADVANCE THE CURSOR: Appears immediately to prompt the use of
the [.] key for cursor control anytime a setpoint requiring text editing is viewed. If the
setpoint is not altered for 1 minute, this message flashes again.
•
TOP OF PAGE: This message will indicate when the top of a page has been reached.
•
BOTTOM OF PAGE: This message will indicate when the bottom of a page has been
reached.
•
TOP OF LIST: This message will indicate when the top of subgroup has been reached.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
6–35
CHAPTER 6: ACTUAL VALUES
6–36
•
END OF LIST: This message will indicate when the bottom of a subgroup has been
reached.
•
NO ALARMS ACTIVE: If an attempt is made to enter the Alarm Status message
subgroup, but there are no active alarms, this message will appear.
•
THIS FEATURE NOT PROGRAMMED: If an attempt is made to enter an actual value
message subgroup, when the setpoints are not configured for that feature, this
message will appear.
•
THIS PARAMETER IS ALREADY ASSIGNED: A given analog output parameters can only
be assigned to one output. If an attempt is made to assign a parameter to a second
output, this message will appear.
•
THAT INPUT ALREADY USED FOR TACHOMETER: If a digital input is assigned to the
tachometer function, it cannot be used for any other digital input function. If an
attempt is made to assign a digital input to a function when it is already assigned to
tachometer, this message will appear.
•
TACHOMETER MUST USE INPUT 4, 5, 6, or 7: Only digital inputs 4, 5, 6, or 7 may be
used for the tachometer function. If an attempt is made to assign inputs 1,2,3, or 4 to
the tachometer function, this message will appear.
•
THAT DIGITAL INPUT IS ALREADY IN USE: If an attempt is made to assign a digital
input to tachometer when it is already assigned to another function, this message will
appear.
•
To edit use VALUE UP or VALUE DOWN key: If a numeric key is pressed on a setpoint
parameter that is not numeric, this message will prompt the user to use the value
keys.
•
GROUP 1 SETPOINT HAS BEEN STORED: This message appear each time a setpoint
has been altered and stored to setpoint Group 1 as shown on the display.
•
GROUP 2 SETPOINT HAS BEEN STORED: This message appear each time a setpoint
has been altered and stored to setpoint Group 2 as shown on the display.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
Digital Energy
Multilin
489 Generator Management Relay
Chapter 7: Testing
Testing
7.1
Test Setup
7.1.1
Description
The purpose of this testing description is to demonstrate the procedures necessary to
perform a complete functional test of all the 489 hardware while also testing firmware/
hardware interaction in the process. Since the 489 is packaged in a drawout case, a demo
case (metal carry case in which the 489 may be mounted) may be useful for creating a
portable test set with a wiring harness for all of the inputs and outputs. Testing of the relay
during commissioning using a primary injection test set will ensure that CTs and wiring are
correct and complete.
The 489 tests are listed below. For the following tests refer to Secondary Current Injection
Testing on page 7–3:
1.
Output Current Accuracy Test
2.
Phase Voltage Input Accuracy Test
3.
Ground, Neutral, and Differential Current Accuracy Test
4.
Neutral Voltage (Fundamental) Accuracy Test
5.
Negative Sequence Current Accuracy Test
6.
RTD Accuracy Test
7.
Digital Input and Trip Coil Supervision Accuracy Test
8.
Analog Input and Outputs Test
9.
Output Relay Test
10. Overload Curve Test
11. Power Measurement Test
12. Reactive Power Test
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
7–1
CHAPTER 7: TESTING
13. Voltage Phase Reversal Test
14. For the following tests refer to Secondary Injection Setup #2 on page 7–15:
15. GE Multilin (HGF) Ground Current Accuracy Test
16. Neutral Voltage (3rd Harmonic) Accuracy Test
17. Phase Differential Trip Test
18. For the following test refer to Secondary Injection Test Setup #3 on page 7–19:
19. Voltage Restrained Overcurrent Test
7–2
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 7: TESTING
VC
3 PHASE VARIABLE AC TEST SET
VA
IN
VB
IA
IC
PHASE a PHASE b PHASE c
PHASE A PHASE B PHASE C
NEUTRAL END CT's
OUTPUT CT's
Vc
PHASE
VOLTAGE INPUTS
H12
H11
FILTER GROUND
RTD SHIELD
A1
HOT
A2
COMPENSATION
A3
RTD RETURN
A4
COMPENSATION
500 Ohms
SAFETY GROUND G12
E12
IRIG - B
F12
RTD #2
A5
HOT
A6
HOT
A7
COMPENSATION
A8
RTD RETURN
500 Ohms
TRIP COIL
SUPERVISION
RTD #3
A9
COMPENSATION
A10
HOT
500 Ohms
F11
HOT
COMPENSATION
1 TRIP
F2
2 AUXILIARY
RTD RETURN
F3
A14
COMPENSATION
E5
500 Ohms
RTD #6
A15
HOT
D1
HOT
D2
COMPENSATION
D3
RTD RETURN
D4
COMPENSATION
3 AUXILIARY
500 Ohms
4 AUXILIARY
5 ALARM
COMPENSATION
E7
RTD RETURN
F8
D9
COMPENSATION
D10
HOT
D11
HOT
D12
COMPENSATION
6 SERVICE
RTD #10
G
R
G
G
G
E9
F9
500 Ohms
TIMER
F7
D7
D8
500 Ohms
R
F6
RTD #9
G
E6
E8
500 Ohms
G
F4
F5
RTD #8
HOT
R
E4
RTD #7
500 Ohms
R
START
TRIGGER
E3
A13
HOT
STOP
TRIGGER
F1
RTD #5
D6
SWITCH
COMMON
E1
A11
A12
D5
SWITCH
+24VAC
E11
E2
RTD #4
500 Ohms
R
RTD #11
D13
RTD RETURN
D14
COMPENSATION
500 Ohms
RTD #12
ACCESS
C2
C3
C4
BREAKER
STATUS
COMPUTER
COMM.
RS485
AUXILIARY
RS485
D25 D26 D27 B2
B3
ANALOG I/O
ANALOG OUTPUTS
ANALOG INPUTS
4+
COM
SWITCH +24Vdc
C1
3+
COMMON
D24
2+
ASSIGNABLE INPUT 7
D23
1+
D22
+24
VDC
ASSIGNABLE INPUT 6
SHIELD
ASSIGNABLE INPUT 4
ASSIGNABLE INPUT 5
D21
GE Multilin
SECONDARY INJECTION
TEST SETUP
4+
D19
D20
g
1+
ASSIGNABLE INPUT 3
3+
ASSIGNABLE INPUT 2
D18
2+
D17
COM
ASSIGNABLE INPUT 1
COM
HOT
D16
COM
D15
DIGITAL INPUTS
V
G11
RTD #1
500 Ohms
RTD
SIMULATION
RESISTORS
OR RESISTANCE
DECADE BOX
Vcom
Va
Vb
COM
COM
1A/5A
COM
1A/5A
1A/5A
AUTOMATIC CT
SHORTING
BAR
CONTROL
POWER
B1
START
VA VB VC VN
G6 H6 G7 H7 G8 H8 G2 H1 H2 G1
COM
COM
1A/5A
COM
1A/5A
HGF
COM
GROUND INPUTS
1A/5A
1A
COM
V
NEUTRAL
E10 F10 G9 H9 G10 H10 G3 H3 G4 H4 G5 H5
IB
B4 A16 A17 A18 A19 A20 A21 A22 A23 A24 A25 A26 A27
A
A
RS485
RS485
V
A
A
808818A3.CDR
FIGURE 7–1: Secondary Current Injection Testing
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
7–3
CHAPTER 7: TESTING
7.2
Hardware Functional Tests
7.2.1
Output Current Accuracy
The specification for output and neutral end current input is ±0.5% of 2 × CT when the
injected current is less than 2 × CT. Perform the steps below to verify accuracy.
Z Alter the following setpoint:
S2 SYSTEM SETUP Z CURRENT SENSING ZV PHASE CT PRIMARY: “1000 A”
Measured values should be ±10 A.
Z Inject the values shown in the table below and verify accuracy of the
measured values.
Z View the measured values in the A2 METERING DATA ZV CURRENT
METERING menu.
Injected Current
1 A Unit
7.2.2
Expected
Current
5 A Unit
0.1 A
0.5 A
100 A
0.2 A
1.0 A
200 A
0.5 A
2.5 A
500 A
1A
5A
1000 A
1.5 A
7.5 A
1500 A
2A
10 A
2000 A
Measured Current
Phase A
Phase B
Phase C
Phase Voltage Input Accuracy
The specification for phase voltage input accuracy is ±0.5% of full scale (200 V). Perform
the steps below to verify accuracy.
Z Alter the following setpoints in the S2 SYSTEM SETUP ZV VOLTAGE
SENSING menu:
VT CONNECTION TYPE: “Wye”
VOLTAGE TRANSFORMER RATIO: “10.00:1”
Measured values should be ±1.0 V.
Z Apply the voltage values shown in the table and verify accuracy of
the measured values.
Z View the measured values in the A2 METERING DATA ZV VOLTAGE
METERING menu.
Applied LineNeutral Voltage
7–4
Expected Voltage
Reading
30 V
300 V
50 V
500 V
100 V
1000 V
150 V
1500 V
Measured Voltage
A-N
B-N
C-N
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 7: TESTING
Applied LineNeutral Voltage
Expected Voltage
Reading
200 V
7.2.3
Measured Voltage
A-N
B-N
C-N
2000 V
Ground (1 A), Neutral, and Differential Current Accuracy
The specification for neutral, differential and 1 A ground current input accuracy is ±0.5% of
2 × CT. Perform the steps below to verify accuracy.
Z In the S2 SYSTEM SETUP Z CURRENT SENSING menu, set:
GROUND CT: “1A Secondary”
GROUND CT RATIO: “1000:1”
PHASE CT PRIMARY: “1000 A”
Z In the S5 CURRENT ELEMENTS ZV PHASE DIFFERENTIAL menu, set:
PHASE DIFFERENTIAL TRIP: “Unlatched”
DIFFERENTIAL TRIP MIN. PICKUP: “0.1 x CT”
The last two setpoints are needed to view the neutral and the differential current.
The trip element will operate when differential current exceeds 100 A.
Measured values should be ±10 A.
Z Inject (IA only) the values shown in the table below into one phase
only and verify accuracy of the measured values.
Z View the measured values in the A2 METERING DATA Z CURRENT
METERING menu or press the NEXT key to view the current values
when differential trip element is active.
Table 7–1: Neutral and Ground Current Test Results
Injected
Current
1 A Unit
Expected
Current
Measured
Ground Current
Measured Neutral Current
Phase A
0.1 A
100 A
0.2 A
200 A
0.5 A
500 A
1A
1000 A
Phase B
Phase C
Table 7–2: Differential Current Test Results
Injected
Current
Expected Current Reading
Differential
Phase A
Differential
Phase B,C
0.1 A
200 A
100 A
0.2 A
400 A
200 A
0.5 A
1000 A
500 A
1A
2000 A
1000 A
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
Measured Differential Current
Phase A
Phase B
Phase C
7–5
CHAPTER 7: TESTING
7.2.4
Neutral Voltage (Fundamental) Accuracy
The specification for neutral voltage (fundamental) accuracy is ±0.5% of full scale (100 V).
Perform the steps below to verify accuracy.
Z In the S2 SYSTEM SETUP ZV VOLTAGE SENSING menu, set:
NEUTRAL VOLTAGE TRANSFORMER: “Yes”
NEUTRAL V.T. RATIO: “10.00:1”
Z In the S2 SYSTEM SETUP ZV GEN. PARAMETERS menu, set:
GENERATOR NOMINAL FREQUENCY: “60 Hz”
Measured values should be ±5.0 V.
Z Apply the voltage values shown in the table and verify accuracy of
the measured values.
Z View the measured values in the A2 METERING DATA ZV VOLTAGE
METERING menu.
Applied Neutral Voltage
at 60 Hz
7.2.5
Expected Neutral Voltage
10 V
100 V
30 V
300 V
50 V
500 V
Measured Neutral
Voltage
Negative Sequence Current Accuracy
The 489 measures negative sequence current as a percent of Full Load Amperes (FLA). A
sample calculation of negative sequence current is shown below. Given the following
generator parameters:
Rated MVA (PA) = 1.04
Voltage Phase to Phase (Vpp): 600 V
We have:
6
PA
× 10 - = 1000 A
FLA = --------------------------------------------- = 1.04
3 × 600
3 × V pp
(EQ 7.1)
With the following output currents:
I a = 780 ∠0°, I b = 1000 ∠113° lag, I c = 1000 ∠247° lag
(EQ 7.2)
The negative-sequence current Ins is calculated as:
7–6
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 7: TESTING
1
2
I ns = --- ( I a + a I b + aI c ) where a = 1 ∠120° = – 0.5 + j0.866
3
2
1
= --- ( 780 ∠0° + ( 1 ∠120° ) ( 1000 ∠– 113° ) + ( 1 ∠120° ) ( 1000 ∠113° ) )
3
1
= --- ( 780 ∠0° + 1000 ∠127° + 1000 ∠233° )
3
(EQ 7.3)
1
= --- ( 780 – 601.8 + j798.6 – 601.8 – j798.6 )
3
⇒ %I ns
= – 141.2
I ns
= --------- × 100 = 14%
FLA
Therefore, the negative sequence current is 14% of FLA. The specification for negativesequence current accuracy is per output current inputs. Perform the steps below to verify
accuracy.
Z In the S2 SYSTEM SETUP ZV GEN. PARAMETERS menu, set:
GENERATOR RATED MVA: “1.04”
VOLTAGE PHASE-PHASE: “600”
Note that setting VOLTAGE PHASE-PHASE to “600” is equivalent to setting FLA = 1000 A. This
is for testing purposes only!
Z In the S2 SYSTEM SETUP Z CURRENT SENSING menu, set:
PHASE CT PRIMARY: “1000 A”
Z Inject the values shown in the table below and verify accuracy of the
measured values.
Z View the measured values in the A2 METERING DATA Z CURRENT
METERING menu.
Injected Current
1 A Unit
7.2.6
5 A Unit
Expected Negative
Sequence Current
Ia = 0.78 A ∠0°
Ib = 1 A ∠113° lag
Ic = 1 A ∠247° lag
Ia = 3.9 A ∠0°
Ib = 5 A ∠113° lag
Ic = 5 A ∠247° lag
14% FLA
Ia = 1.56 A ∠0°
Ib = 2 A ∠113° lag
Ic = 2 A ∠247° lag
Ia = 7.8 A ∠0°
Ib = 10 A ∠113° lag
Ic = 10 A ∠247° lag
28% FLA
Ia = 0.39 A ∠0°
Ib = 0.5 A ∠113° lag
Ic = 0.5 A ∠247° lag
Ia = 1.95 A ∠0°
Ib = 2.5 A ∠113° lag
Ic = 2.5 A ∠247° lag
7% FLA
Measured Negative
Sequence Current
RTD Accuracy
The specification for RTD input accuracy is ±2° for Platinum/Nickel and ±5° for Copper.
Perform the steps below.
Z In the S8 RTD TEMPERATURE MENU, set:
RTD TYPE Z STATOR RTD TYPE: “100 Ohm Platinum” (select desired type)
RTD #1 Z RTD #1 APPLICATION: “Stator” (repeat for RTDs 2 to 12)
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
7–7
CHAPTER 7: TESTING
Measured values should be ±2°C / ±4°F for platinum/nickel and ±5°C / ±9°F for
copper.
Z Alter the resistance applied to the RTD inputs as shown below to
simulate RTDs and verify accuracy.
Z View the measured values in A2 METERING DATA ZV TEMPERATURE.
Applied
Resistance
100 Ω Platinum
°C
°F
84.27 Ω
–40°C
–40°F
100.00 Ω
0°C
32°F
119.39 Ω
50°C
122°F
138.50 Ω
100°C
212°F
157.32 Ω
150°C
302°F
175.84 Ω
200°C
392°F
194.08 Ω
250°C
482°F
Applied
Resistance
120 Ω Nickel
°C
°F
–40°C
–40°F
120.00 Ω
0°C
32°F
157.74 Ω
50°C
122°F
200.64 Ω
100°C
212°F
248.95 Ω
150°C
302°F
303.46 Ω
200°C
392°F
366.53 Ω
250°C
482°F
1
2
3
°C
°F
–40°C
–40°F
100.00 Ω
0°C
32°F
131.45 Ω
50°C
122°F
167.20 Ω
100°C
212°F
207.45 Ω
150°C
302°F
252.88 Ω
200°C
392°F
305.44 Ω
250°C
482°F
1
2
3
°C
°F
–40°C
–40°F
9.04 Ω
0°C
32°F
10.97 Ω
50°C
122°F
12.90 Ω
100°C
212°F
14.83 Ω
150°C
302°F
16.78 Ω
200°C
392°F
5
6
7
8
9
10
11
12
4
5
6
7
8
9
10
11
12
10
11
12
10
11
12
Measured RTD Temperature
Select One: ____°C ____°F
1
2
3
Expected RTD
Temperature Reading
7.49 Ω
4
Measured RTD Temperature
Select One: ____°C ____°F
Expected RTD
Temperature Reading
77.30 Ω
Applied
Resistance
10 Ω Copper
Measured RTD Temperature
Select One: ____°C ____°F
Expected RTD
Temperature Reading
92.76 Ω
Applied
Resistance
100 Ω Nickel
7–8
Expected RTD
Temperature Reading
4
5
6
7
8
9
Measured RTD Tempeature
Select One: ____°C ____°F
1
2
3
4
5
6
7
8
9
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 7: TESTING
Applied
Resistance
10 Ω Copper
18.73 Ω
7.2.7
Expected RTD
Temperature Reading
°C
°F
250°C
482°F
Measured RTD Tempeature
Select One: ____°C ____°F
1
2
3
4
5
6
7
8
9
10
11
12
Digital Inputs and Trip Coil Supervision
The digital inputs and trip coil supervision can be verified easily with a simple switch or
pushbutton. Verify the Switch +24 V DC with a voltmeter. Perform the steps below to verify
functionality of the digital inputs.
Z Open switches of all of the digital inputs and the trip coil supervision
circuit.
Z View the status of the digital inputs and trip coil supervision in the A1
STATUS ZV DIGITAL INPUTS menu.
Z Close switches of all of the digital inputs and the trip coil supervision
circuit.
Z View the status of the digital inputs and trip coil supervision in the A1
STATUS ZV DIGITAL INPUTS menu.
Input
7.2.8
Expected Status
(Switch Open)
4 Pass
8 Fail
Expected Status
(Switch Closed)
Access
Open
Shorted
Breaker Status
Open
Shorted
Assignable Input 1
Open
Shorted
Assignable Input 2
Open
Shorted
Assignable Input 3
Open
Shorted
Assignable Input 4
Open
Shorted
Assignable Input 5
Open
Shorted
Assignable Input 6
Open
Shorted
Assignable Input 7
Open
Shorted
Trip Coil Supervision
No Coil
Coil
4 Pass
8 Fail
Analog Inputs and Outputs
The specification for analog input and analog output accuracy is ±1% of full scale. Perform
the steps below to verify accuracy. Verify the Analog Input +24 V DC with a voltmeter.
4 to 20 mA Inputs:
Z In the S11 ANALOG I/O ZV ANALOG INPUT 1 menu, set:
ANALOG INPUT 1: “4-20 mA”
ANALOG INPUT 1 MINIMUM: “0”
ANALOG INPUT 1 MAXIMUM: “1000” (repeat all for Analog Inputs 2 to 4)
Analog output values should be ±0.2 mA on the ammeter. Measured analog input
values should be ±10 units.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
7–9
CHAPTER 7: TESTING
Z Force the analog outputs using the following setpoints from the S12
TESTING ZV TEST ANALOG OUTPUT menu:
FORCE ANALOG OUTPUTS FUNCTION: “Enabled”
ANALOG OUTPUT 1 FORCED VALUE: “0%” (enter %, repeat for Outputs 2 to
4)
Z Verify the ammeter readings and the measured analog input
readings.
For the purposes of testing, the analog input is fed in from the analog
output (see Secondary Current Injection Testing on page 7–3).
Z View the measured values in the A2 METERING DATA Z ANALOG
INPUTS menu.
Analog
Output
Force Value
Expected
Ammeter
Reading
Measured Ammeter
Reading (ma)
1
2
3
4
Expected
Analog Input
Reading
0%
4 mA
25%
8 mA
250 units
50%
12 mA
500 units
75%
16 mA
750 units
100%
20 mA
1000 units
Measured Analog Input
Reading (units)
1
2
3
4
0 units
0 to 1 mA Analog Inputs:
Z In the S11 ANALOG I/O ZV ANALOG INPUT 1 menu, set:
ANALOG INPUT 1: “0-1 mA”
ANALOG INPUT 1 MINIMUM: “0”
ANALOG INPUT 1 MAXIMUM: “1000” (repeat for Analog Inputs 2 to 4)
Analog output values should be ±0.01 mA on the ammeter. Measured analog input
values should be ±10 units.
Z Force the analog outputs using the following setpoints in the S12
TESTING ZV TEST ANALOG OUTPUT menu:
FORCE ANALOG OUTPUTS FUNCTION: “Enabled”
ANALOG OUTPUT 1 FORCED VALUE: “0%” (enter %, repeat for
Outputs 2 to 4)
Z Verify the ammeter readings as well as the measured analog input
readings.
Z View the measured values in the A2 METERING DATA ZV ANALOG
INPUTS menu.
Analog
Output Force
Value
7–10
Expected
Ammeter
Reading
Measured Ammeter
Reading (mA)
1
2
3
4
Expected
Analog Input
Reading
0%
0 mA
0 units
25%
0.25 mA
250 units
50%
0.50 mA
500 units
75%
0.75 mA
750 units
100%
1.00 mA
1000 units
Measured Analog Input
Reading (units)
1
2
3
4
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 7: TESTING
7.2.9
Output Relays
To verify the functionality of the output relays, perform the following steps:
Using the setpoint:
S12 TESTING ZV TEST OUTPUT RELAYS ZV FORCE OPERATION OF RELAYS: “1 Trip”
Z Select and store values as per the table below, verifying operation
Force
Operation
Setpoint
Expected Measurement (4 for short)
1
2
3
4
Actual Measurement (4 for short)
5
6
1
2
3
4
5
6
no nc no nc no nc no nc no nc no nc no nc no nc no nc no nc no nc no nc
1 Trip
4
4
4
2 Auxiliary
4
3 Auxiliary
4
4
4 Auxiliary
4
4
4
5 Alarm
4
4
4
4
6 Service
4
4
4
4
All Relays
No Relays
Note
4
4
4
4
4
4
4
4
4
4
4
4
4
4
4
4
4
4
4
4
4
4
4
4
4
4
4
4
4
4
4
The 6 Service relay is failsafe or energized normally. Operating output relay 6 causes it to
de-energize.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
7–11
CHAPTER 7: TESTING
7.3
Additional Functional Tests
7.3.1
Overload Curve Accuracy
The specification for overload curve timing accuracy is ±100 ms or ±2% of time to trip.
Pickup accuracy is as per the current inputs (±0.5% of 2 × CT when the injected current is
less than 2 × CT and ±1% of 20 × CT when the injected current is equal to or greater than
2 × CT). Perform the steps below to verify accuracy.
Z In the S2 SYSTEM SETUP ZV GEN. PARAMETERS menu, set:
GENERATOR RATED MVA: “1.04”
GENERATOR VOLTAGE PHASE-PHASE: “600”
Note that setting GENERATOR VOLTAGE PHASE-PHASE to “600” is equivalent to setting
FLA = 1000 A. For testing purposes ONLY!
Z In the S2 SYSTEM SETUP Z CURRENT SENSING menu, set:
PHASE CT PRIMARY: “1000”
Z In the S9 THERMAL MODEL Z MODEL SETUP menu, set:
SELECT CURVE STYLE: “Standard”
OVERLOAD PICKUP LEVEL: “1.10 x FLA”
UNBALANCE BIAS K FACTOR: “0”
HOT/COLD SAFE STALL RATIO: “1.00”
ENABLE RTD BIASING: “No”
STANDARD OVERLOAD CURVE NUMBER: “4”
ENABLE THERMAL MODEL: “Yes”
Z In the S9 THERMAL MODEL Z THERMAL ELEMENTS menu, set:
THERMAL MODEL TRIP: “Latched” or “Unlatched”
Any trip must be reset prior to each test. Short the emergency restart terminals
momentarily immediately prior to each overload curve test to ensure that the thermal
capacity used is zero. Failure to do so will result in shorter trip times. Inject the current of
the proper amplitude to obtain the values as shown and verify the trip times. Motor load
may be viewed in the A2 METERING DATA Z CURRENT METERING menu.
The thermal capacity used and estimated time to trip may be viewed in the A1 STATUS ZV
GENERATOR STATUS menu.
Average Phase
Current
Displayed
Note
7–12
Pickup Level
Expected
Time to Trip
Tolerance Range
1050 A
1.05 × FLA
never
n/a
1200 A
1.20 × FLA
795.44 s
779.53 to 811.35 s
1750 A
1.75 × FLA
169.66 s
166.27 to 173.05 s
3000 A
3.00 × FLA
43.73 s
42.86 to 44.60 s
6000 A
6.00 × FLA
9.99 s
9.79 to 10.19 s
10000 A
10.00 × FLA
5.55 s
5.44 to 5.66 s
Generator Rated MVA
FLA = ---------------------------------------------------------------------------------------------------3 × Generator Phase-to-Phase Voltage
Measured Time
to Trip (sec.)
(EQ 7.4)
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 7: TESTING
7.3.2
Power Measurement Test
The specification for reactive and apparent power is ± 1% of 3 × 2 × CT × VTratio × VTfull× CT. Perform the steps below to verify accuracy.
scale at Iavg < 2
Z In the S2 SYSTEM SETUP Z CURRENT SENSING menu, set:
PHASE CT PRIMARY: “1000”
Z In the S2 SYSTEM SETUP ZV VOLTAGE SENSING menu, set:
VT CONNECTION TYPE: “Wye”
VOLTAGE TRANSFORMER RATIO: “10.00:1”
Z Inject current and apply voltage as per the table below.
Z Verify accuracy of the measured values.
Z View the measured values in the A2 METERING DATA ZV POWER
METERING menu:
Injected Current / Applied Voltage
(Ia is the reference vector)
1 A UNIT
Power Quantity
5 A UNIT
Expected
Tolerance
Power Factor
Measured
Expected
Ia = 1 A∠0°
Ib = 1 A∠120° lag
Ic = 1 A∠240° lag
Va = 120 V∠342° lag
Vb = 120 V∠102° lag
Vc = 120 V∠222° lag
Ia = 5 A∠0°
Ib = 5 A∠120° lag
Ic = 5 A∠240° lag
Ia = 120 V∠342° lag
Vb = 120 V∠102° lag
Vc = 120 V∠222° lag
+3424 kW
3355 to
3493 kW
0.95 lag
Ia = 1 A∠0°
Ib = 1 A∠120° lag
Ic = 1 A∠240° lag
Va = 120 V∠288° lag
Vb = 120 V∠48° lag
Vc = 120 V∠168° lag
Ia = 5 A∠0°
Ib = 5 A∠120° lag
Ic = 5 A∠240° lag
Va = 120 V∠288° lag
Vb = 120 V∠48° lag
Vc = 120 V∠168° lag
+3424 kvar
3355 to
3493 kvar
0.31 lag
7.3.3
Measured
Reactive Power Accuracy
The specification for reactive power is ±1% of 3 × 2 × CT × VTratio × VTfull scale at
Iavg < 2 × CT. Perform the steps below to verify accuracy and trip element.
Z In the S2 SYSTEM SETUP Z CURRENT SENSING menu, set:
PHASE CT PRIMARY: “5000”
Z In the S2 SYSTEM SETUP ZV VOLTAGE SENSING menu, set:
VT CONNECTION TYPE: “Wye”
VOLTAGE TRANSFORMER RATIO: “100:1”
Z In the S2 SYSTEM SETUP ZV GEN. PARAMETERS menu, set
GENERATOR RATED MVA: “100”
GENERATOR RATED POWER FACTOR: “0.85”
GENERATOR VOLTAGE PHASE-PHASE: “12000”
–1
The rated reactive power is 100 sin ( cos ( 0.85 ) ) = ± 52.7 Mvar .
Z Alter the following reactive power setpoints in the S7 POWER
ELEMENTS Z REACTIVE POWER menu:
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
7–13
CHAPTER 7: TESTING
REACTIVE POWER ALARM: “Unlatched”
ASSIGN ALARM RELAYS(2-5): “---5”
POSTIVE MVAR ALARM LEVEL: “0.6 x Rated”
NEGATIVE MVAR ALARM LEVEL: “0.6 x Rated”
REACTIVE POWER ALARM DELAY: “5 s”
REACTIVE POWER ALARM EVENT: “On”
REACTIVE POWER TRIP: “Unlatched”
ASSIGN TRIP RELAYS(1-4): “1---”
POSTIVE MVAR TRIP LEVEL: “0.75 x Rated”
NEGATIVE MVAR TRIP LEVEL: “0.75 x Rated”
REACTIVE POWER TRIP DELAY: “10 s”
Z Inject current and apply voltage as per the table below.
Z Verify the alarm/trip elements and the accuracy of the measured
values.
Z View the measured values in the A2 METERING DATA Z POWER
METERING page.
Z View the Event Records in the A5 EVENT RECORD menu.
Current/Voltage
Mvar
Alarm
Trip
Expected Tolerance Measured Expected Observed Delay Expected Observed Delay
Vab=120V∠0°
Vbc=120V∠120°lag
Vca=120V∠240°lag 18
Ian=5 A∠10°lag
Ibn=5 A∠130°lag
Icn=5 A∠250°lag
13 to 23
4
Vab=120V∠0°
Vbc=120V∠120°lag
Vca=120V∠240°lag –35
Ian=5 A∠340°lag
Ibn=5 A∠100°lag
Icn=5 A∠220°lag
–40 to –30
Vab=120V∠0°
Vbc=120V∠120°lag
Vca=120V∠240°lag –52
Ian=5 A∠330°lag
Ibn=5 A∠90°lag
Icn=5 A∠210°lag
Vab=120V∠0°
Vbc=120V∠120°lag
Vca=120V∠240°lag 52
Ian=5 A∠30°lag
Ibn=5 A∠150°lag
Icn=5 A∠270°lag
N/A
8
N/A
4
8
N/A
–57 to –47
4
4
47 to 57
4
4
4: Activated, 8: Not Activated
7.3.4
Voltage Phase Reversal Accuracy
The relay can detect voltage phase rotation and protect against phase reversal. To test the
phase reversal element, perform the following steps:
Z In the S2 SYSTEM SETUP ZV VOLTAGE SENSING menu, set:
VT CONNECTION TYPE: “Wye”
Z In the S2 SYSTEM SETUP ZV GEN. PARAMETERS menu, set:
7–14
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 7: TESTING
GENERATOR PHASE SEQUENCE: “ABC”
Z In the S3 DIGITAL INPUTS Z BREAKER STATUS menu, set:
BREAKER STATUS: “Breaker Auxiliary a”
Z In the S6 VOLTAGE ELEMENTS ZV PHASE REVERSAL menu, set:
PHASE REVERSAL TRIP: “Unlatched”
ASSIGN TRIP RELAYS: “1---”
Z Apply voltages as per the table below. Verify the operation on voltage
phase reversal
Applied Voltage
7.3.5
Expected Result
Va = 120 V∠0°
Vb = 120 V∠120° lag
Vc = 120 V∠240° lag
No Trip
Va = 120 V∠0°
Vb = 120 V∠240° lag
Vc = 120 V∠120° lag
Phase Reversal Trip
Observed Result
Injection Test Setup #2
Set up the 489 device as follows for the GE Multilin HGF Ground Accuracy Test, Neutral
Voltage (3rd Harmonic) Accuracy Test, and the Phase Differential Trip Test.
VC
3 PHASE VARIABLE AC TEST SET
VA
VB
IA
VA VB VC VN
NC
IB
IC
IN
NC
50:0.25
PHASE a PHASE b PHASE c
PHASE A PHASE B PHASE C
NEUTRAL END CT's
OUTPUT CT's
Vc
Vcom
Va
Vb
COM
COM
1A/5A
COM
AUTOMATIC CT
SHORTING
BAR
1A/5A
G6 H6 G7 H7 G8 H8 G2 H1 H2 G1
1A/5A
COM
COM
1A/5A
COM
1A/5A
1A/5A
HGF
GROUND INPUTS
COM
1A
COM
V
NEUTRAL
E10 F10 G9 H9 G10 H10 G3 H3 G4 H4 G5 H5
PHASE
VOLTAGE INPUTS
808817A1.CDR
FIGURE 7–2: Secondary Injection Setup #2
7.3.6
GE Multilin 50:0.025 Ground Accuracy
The specification for GE Multilin HGF 50:0.025 ground current input accuracy is ±0.5% of
2 × CT rated primary (25 A). Perform the steps below to verify accuracy.
Z In the S2 SYSTEM SETUP Z CURRENT SENSING menu, set:
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
7–15
CHAPTER 7: TESTING
GROUND CT: “50:0.025 CT”
Measured values should be ±0.25 A.
Z Inject the values shown in the table below either as primary values
into a GE Multilin 50:0.025 Core Balance CT or as secondary values
that simulate the core balance CT.
Z Verify accuracy of the measured values in the A2 METERING DATA Z
CURRENT METERING menu.
Injected Current
Primary 50:0.025 CT
7.3.7
Current Reading
Secondary
Expected
0.25 A
0.125 mA
0.25 A
1A
0.5 mA
1.00 A
5A
2.5 mA
5.00 A
10 A
5 mA
10.00 A
Measured
Neutral Voltage (3rd Harmonic) Accuracy
The 489 specification for neutral voltage (3rd harmonic) accuracy is ±0.5% of full scale
(100 V). Perform the steps below to verify accuracy.
Z In the S2 SYSTEM SETUP ZV VOLTAGE SENSING menu, set
NEUTRAL VOLTAGE TRANSFORMER: “Yes”
NEUTRAL V.T. RATIO: “10.00:1”
Z In the S2 SYSTEM SETUP ZV GEN. PARAMETERS menu, set:
GENERATOR NOMINAL FREQUENCY: “60 Hz”
Measured values should be ±5.0 V.
Z Apply the voltage values shown in the table and verify accuracy of
the measured values.
Z View the measured values in the A2 METERING DATA ZV VOLTAGE
METERING menu.
Applied Neutral Voltage
at 180 Hz
7.3.8
Note
7–16
Expected Neutral Voltage
10 V
100 V
30 V
300 V
50 V
500 V
Measured Neutral
Voltage
Phase Differential Trip Accuracy
These tests will require a dual channel current source. The unit must be capable of
injecting prefault currents and fault currents of a different value. Application of
excessive currents (greater than 3 × CT) for extended periods will cause damage to the
relay.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 7: TESTING
Minimum Pickup Check
Z Connect the relay test set to inject Channel X current (Ix) into the G3
terminal and out of H3 terminal (Phase A). Increase Ix until the
differential element picks up.
Z Record this value as pickup.
Z Switch off the current.
The theoretical pickup can be computed as follows:
I XPU = Pickup setting × CT
(EQ 7.5)
Single Infeed Fault
Z Set the Ix prefault current equal to 0.
Z Set the fault current equal to CT.
Z Apply the fault.
Z Switch off the current.
Z Record the operating time.
Z Set the Ix prefault current equal to 0.
Z Set the fault current equal to 5 × CT.
Z Apply the fault.
Z Switch off the current.
Z Record the operating time.
Slope 1 Check
Z Connect the relay test set to inject Channel Y current (IY) into the G6
terminal and out of H6 terminal.
The angle between Ix and IY will be 180°.
Z Set pre-fault current, Ix and IY equal to zero.
Z Set fault current, IY equal to 1½ CT.
At this value the relay should operate according to the following formula:
2 – Slope 1 setting 3 × CT
I XOP1 = ---------------------------------------------- × --------------2 + Slope 1 setting
2
(EQ 7.6)
Z Set fault current, Ix equal to 0.95 × IXOP1.
Z Apply the fault.
The relay should operate.
Z Switch off the current.
Z Set fault current, Ix equal to 1.05 × IXOP1.
Z Apply the fault.
The relay should restrain.
Z Switch off the current.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
7–17
CHAPTER 7: TESTING
Slope 2 Check
Z Set fault current, IY equal to 2.5 × CT.
At this value the relay should operate according to the following formula.
2 – Slope 2 setting
I XOP2 = ---------------------------------------------- × 2.5 × CT
2 + Slope 2 setting
(EQ 7.7)
Z Set fault current, Ix equal to 0.95 × IXOP2.
Z Switch on the test set.
The relay should operate.
Z Switch off the current.
Z Set fault current, Ix equal to 1.05 × IXOP2.
Z Switch on the test set.
The relay should restrain.
Z Switch off the current.
Directional Check
Z Set pre-fault current, Ix and IY equal to 3.5 × CT.
At this value the conditions for CT saturation detection are set and
the relay will enable the directional check.
Z Set fault current, Ix equal to 0.95 × IXOP2.
Z Switch on the test set.
The relay should restrain.
Z Switch off the current.
Z Repeat steps from Minimum Pickup Check onward for phases B
and C.
Test Results
Test
Phase A
Calculated
Phase B
Measured
Calculated
Phase C
Measured
Calculated
Measured
Minimum Pickup
Test
Phase A
CT
Phase B
5 × CT
CT
5 × CT
Phase C
CT
5 × CT
Single Infeed Fault
7–18
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 7: TESTING
Test
Phase A
operate
Phase B
restrain
operate
Phase C
restrain
operate
restrain
Ix
Iy
Slope 1
Operation
(OK/not
OK)
Ix
Iy
Slope 2
Operation
(OK/not
OK)
Directional
Check
7.3.9
Ix
N/A
N/A
N/A
Iy
N/A
N/A
N/A
Operation
(OK/not
OK)
N/A
N/A
N/A
Injection Test Setup #3
Setup the 489 device as follows for the Voltage Restrained Overcurrent test.
VC
3 PHASE VARIABLE AC TEST SET
VA
IA
VA VB VC VN
IB
IC
IN
PHASE a PHASE b PHASE c
PHASE A PHASE B PHASE C
NEUTRAL END CT's
OUTPUT CT's
Vc
Vcom
Va
Vb
COM
COM
1A/5A
AUTOMATIC CT
SHORTING
BAR
COM
G6 H6 G7 H7 G8 H8 G2 H1 H2 G1
1A/5A
COM
COM
1A/5A
COM
1A/5A
1A/5A
HGF
GROUND INPUTS
COM
1A
COM
V
NEUTRAL
E10 F10 G9 H9 G10 H10 G3 H3 G4 H4 G5 H5
1A/5A
VB
PHASE
VOLTAGE INPUTS
808822A2.CDR
FIGURE 7–3: Secondary Injection Test Setup #3
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
7–19
CHAPTER 7: TESTING
7.3.10 Voltage Restrained Overcurrent Accuracy
Setup the relay as shown in FIGURE 7–3: Secondary Injection Test Setup #3 on page 7–19.
Z In the S2 SYSTEM SETUP ZV GEN. PARAMETERS menu, set:
GENERATOR RATED MVA: “100 MVA”
GENERATOR VOLTAGE PHASE-PHASE: “12000”
Z In the S2 SYSTEM SETUP ZV VOLTAGE SENSING menu, set:
VT CONNECTION TYPE: “Open Delta”
VOLTAGE TRANSFORMER RATIO: “100:1”
Z In the S5 CURRENT ELEMENTS Z OVERCURRENT ALARM menu, set:
OVERCURRENT ALARM: “Unlatched”
O/C ALARM LEVEL: “1.10 x FLA”
OVERCURRENT ALARM DELAY: “2 s”
O/C ALARM EVENTS: “On”
Z In the S5 CURRENT ELEMENTS ZV PHASE OVERCURRENT menu, set:
PHASE OVERCURRENT TRIP: “Latched”
ENABLE VOLTAGE RESTRAINT: “Yes”
PHASE O/C PICKUP: “1.5 x CT”
CURVE SHAPE: “ANSI Extremely Inv.”
O/C CURVE MULTIPLIER: “2.00”
O/C CURVE RESET: “Instantaneous”
The trip time for the extremely inverse ANSI curve is given as:
⎛
⎞
D
B
E
⎜ A + ---------------------------- + ------------------------------------ + ------------------------------------⎟
2
3
Time to Trip = M × ⎜
I -–C ⎛
I
I - – C⎞ ⎟
⎛ ----------------------------------------------------- – C⎞
⎜
⎝ 〈 K〉 × I
⎠
⎝ 〈 K〉 × I
⎠ ⎟
×
〈
K
〉
I
p
⎝
⎠
p
p
(EQ 7.8)
where:M = O/C CURVE MULTIPLIER setpoint
I = input current
Ip = PHASE O/C PICKUP setpoint
A, B, C, D, E = curve constants, where A = 0.0399, B = 0.2294, C = 0.5000, D = 3.0094,
and E = 0.7222
K = voltage restrained multiplier <optional>
The voltage restrained multiplier is calculated as:
phase-to-phase voltage K = -------------------------------------------------------------------------rated phase-to-phase voltage
(EQ 7.9)
and has a range of 0.1 to 0.9.
Z Using Secondary Injection Test Setup #3 on page 7–19, inject current
and apply voltage as per the table below.
Z Verify the alarm/trip elements and view the event records in the A5
EVENT RECORD menu.
7–20
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER 7: TESTING
Current/voltage (5 A unit)
Current
Alarm
Voltage
expected
Ian = 5 A∠0°
Ibn = 5 A∠120° lag
Icn = 5 A∠240° lag
Vab = 120 V∠0° lag
Vbc = 120 V∠120° lag 8
Vca = 120 V∠240° lag
Ian = 6 A∠0°
Ibn = 6 A∠120° lag
Icn = 6 A∠240° lag
observed
Trip
delay
N/A
expected
Trip Delay
observed
expected
observed
8
N/A
N/A
Vab = 120 V∠0°
Vbc = 120 V∠120° lag 4
Vca = 120 V∠240° lag
8
N/A
N/A
Ian = 10 A∠0°
Vab = 120 V∠0°
Ibn = 10 A∠120° lag Vbc = 120 V∠120° lag 4
Icn = 10 A∠240° lag Vca = 120 V∠240° lag
4
11.8 s
Vab = 100 V∠0°
Ian = 10 A∠0°
Ibn = 10 A∠120° lag Vbc = 100 V∠120° lag 4
Icn = 10 A∠240° lag Vca = 100 V∠240° lag
4
6.6 s
Ian = 10 A∠0°
Vab = 60 V∠0°
Ibn = 10 A∠120° lag Vbc = 60 V∠120° lag
Icn = 10 A∠240° lag Vca = 60 V∠240° lag
4
1.7 s
4
4 activated; 8 Not Activated
7.3.11 Distance Element Accuracy
The theoretical impedance on the R-X plane can be calculated as:
2
2
0.875 × Z d × cos ( θ d – θ i ) + ( 0.875 × Z d × cos ( θ d – θ i ) ) + 4 × Z d × 0.125
Z i = ----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------- (EQ 7.10)
2
where: Zd = programmed distance impedance
θd = programmed distance characteristic angle
θi = variable angle on the R-X plane at point i for which boundary
impedance is to be calculated
It is recommended that voltage is kept constant while increasing the current magnitude at
certain angles referenced to voltage phase A until element operates.
Then the expected operating current (assuming that current in the two phases are 180°
apart) can be calculated as:
Va – Vb
I i = ----------------2Z i
where Z i = Z i × e
jθ i
(EQ 7.11)
.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
7–21
CHAPTER 7: TESTING
7–22
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
Digital Energy
Multilin
489 Generator Management Relay
Appendix
Appendix
A.1
Stator Ground Fault
A.1.1
Description
This application note describes general protection concepts and provides guidelines on
the use of the 489 to protect a generator stator against ground faults. Detailed
connections for specific features must be obtained from the relay manual. Users are
also urged to review the material contained in the 489 manual on each specific
protection feature discussed here.
The 489 Generator Management Relay offers a number of elements to protect a generator
against stator ground faults. Inputs are provided for a neutral-point voltage signal and for
a zero-sequence current signal. The zero-sequence current input can be into a nominal 1 A
secondary circuit or an input reserved for a special GE Multilin type HGF ground CT for very
sensitive ground current detection. Using the HGF CT allows measurement of ground
current values as low as 0.25 A primary. With impedance-grounded generators, a single
ground fault on the stator does not require that the unit be quickly removed from service.
The grounding impedance limits the fault current to a few amperes. A second ground fault
can, however, result in significant damage to the unit. Thus the importance of detecting all
ground faults, even those in the bottom 5% of the stator. The fault detection methods
depend on the grounding arrangement, the availability of core balance CT, and the size of
the unit. With modern full-featured digital generator protection relays such as the 489,
users do not incur additional costs for extra protection elements as they are all part of the
same device. This application note provides general descriptions of each of the elements in
the 489 suitable for stator ground protection, and discusses some special applications.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
A–1
CHAPTER A: APPENDIX
A.1.2
Neutral Overvoltage Element
The simplest, and one of the oldest methods to detect stator ground faults on highimpedance-grounded generators, is to sense the voltage across the stator grounding
resistor (See References [1, 2] at the end of this section). This is illustrated, in a simplified
form in the figure below. The voltage signal is connected to the Vneutral input of the 489,
terminals E10 and F10. The Vneutral signal is the input signal for the 489 neutral overvoltage
protection element. This element has an alarm and a trip function, with separately
adjustable operate levels and time delays. The trip function offers a choice of timing curves
as well as a definite time delay. The neutral overvoltage function responds to fundamental
frequency voltage at the generator neutral. It provides ground fault protection for
approximately 95% of the stator winding. The limiting factor is the level of voltage signal
available for a fault in the bottom 5% of the stator winding. The element has a range of
adjustment, for the operate levels, of 2 to 100 V.
Generator
R is selected for a
maximum fault current
of 10 A, typically.
Distribution
Transformer
R
Overvoltage
Relay
808739A1.CDR
FIGURE A–1: Stator Ground Fault Protection
The operating time of this element should be coordinated with protective elements
downstream, such as feeder ground fault elements, since the neutral overvoltage element
will respond to external ground faults if the generator is directly connected to a power grid,
without the use of a delta-wye transformer.
In addition, the time delay should be coordinated with the ground directional element
(discussed later), if it is enabled, by using a longer delay on the neutral overvoltage element
than on the directional element.
It is recommended that an isolation transformer be used between the relay and the
grounding impedance to reduce common mode voltage problems, particularly on
installations requiring long leads between the relay and the grounding impedance.
When several small generators are operated in parallel with a single step-up transformer,
all generators may be grounded through the same impedance (the impedance normally
consists of a distribution transformer and a properly sized resistor). It is possible that only
one generator is grounded while the others have a floating neutral point when connected
to the power grid (see the figure below). This operating mode is often adopted to prevent
circulation of third-harmonic currents through the generators, if the installation is such
that all the star points would end up connected together ahead of the common grounding
impedance (if each generator has its own grounding impedance, the magnitude of the
A–2
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER A: APPENDIX
circulating third harmonic current will be quite small). With a common ground point, the
same Vneutral signal is brought to all the relays but only the one which is grounded should
have the neutral overvoltage element in service.
For these cases, the neutral overvoltage element has been provided with a supervising
signal obtained from an auxiliary contact off the grounding switch. When the grounding
switch is opened, the element is disabled. The grounding switch auxiliary contact is also
used in the ground directional element, as is the breaker auxiliary contact, as discussed
later.
If all the generators are left grounded through the same impedance, the neutral
overvoltage element in each relay will respond to a ground fault in any of the generators.
For this reason, the ground directional element should be used in each relay, in addition to
the neutral overvoltage element.
Common
Grounding
Impedance
Grounding
Switch
G1
Breaker
Trans. & R
Isolating
Trans.
Aux.
Contact
Aux.
Contact
489
Relay
Vneutral
Grounding
Switch
G2
Breaker
Aux.
Contact
Vneutral
Aux.
Contact
489
Relay
Other Generators,
as the case may be
808737A1.CDR
FIGURE A–2: Parallel Generators with Common Grounding Impedance
A.1.3
Ground Overcurrent Element
The ground overcurrent element can be used as a direct replacement or a backup for the
neutral overvoltage element, with the appropriate current signal from the generator
neutral point, for grounded generators. This element can also be used with a Core Balance
CT, either in the neutral end or the output end of the generator, as shown below. The use of
the special CT, with its dedicated input to the relay, offers very sensitive current detection,
but still does not offer protection for the full stator. The setting of this element must be
above the maximum unbalance current that normally flows in the neutral circuit. Having
the element respond only to the fundamental frequency component allows an increase in
sensitivity.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
A–3
CHAPTER A: APPENDIX
The core balance CT can be a conventional CT or a 50:0.025 Ground CT, allowing the
measurement of primary-side current levels down to 0.25 A. Using a Core Balance CT, on
the output side of the transformer will provide protection against stator ground faults in
ungrounded generators, provided that there is a source of zero-sequence current from the
grid.
Though in theory one could use this element with a zero sequence current signal obtained
from a summation of the three phase currents (neutral end or output end), by connecting it
in the star point of the phase CTs, Options 4 and 5 in the figure below, this approach is not
very useful. The main drawback, for impedance-grounded generators is that the zerosequence current produced by the CT ratio and phase errors could be much larger than
the zero sequence current produced by a real ground fault inside the generator.
Again the time delay on this element must be coordinated with protection elements
downstream, if the generator is grounded. Refer to Ground Directional on page 5–40 for
the range of settings of the pickup levels and the time delays. The time delay on this
element should always be longer than the longest delay on line protection downstream.
GENERATOR
CORE
BALANCE
CT
Option 2
Option 1
CORE
BALANCE
CT
Option 5
(similar to
Option 4)
Phase CTs
BREAKER
Breaker
Aux.
Option 3
489
Option 4
Ground current input
from one of the five
options
Ground
Overcurrent
Element
808736A1.CDR
FIGURE A–3: Ground Overcurrent Element with Different Current Source Signals
A.1.4
Ground Directional Element
The 489 can detect internal stator ground faults using a Ground Directional element
implemented using the Vneutral and the ground current inputs. The voltage signal is
obtained across the grounding impedance of the generator. The ground, or zero sequence,
current is obtained from a core balance CT, as shown below (due to CT inaccuracies, it is
generally not possible to sum the outputs of the conventional phase CTs to derive the
generator high-side zero sequence current, for an impedance-grounded generator).
If correct polarities are observed in the connection of all signals to the relay, the Vneutral
signal will be in phase with the ground current signal. The element has been provided with
a setting allowing the user to change the plane of operation to cater to reactive grounding
impedances or to polarity inversions.
This element’s normal ‘plane of operation’ for a resistor-grounded generator is the 180°
plane, as shown in FIGURE A–4: Ground Directional Element Polarities and Plane of
Operation, for an internal ground fault. That is, for an internal stator-to-ground fault, the Vo
signal is 180° away from the Io signal, if the polarity convention is observed. If the
A–4
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER A: APPENDIX
grounding impedance is inductive, the plane of operation will be the 270° plane, again,
with the polarity convention shown below. If the polarity convention is reversed on one
input, the user will need to change the plane of operation by 180°.
GENERATOR
Io
Io
CORE
BALANCE
CT
90°
Plane of operation
for resistive
grounding impedance
Io
180°
0°
Vo
±
F10
H10
489
Relay
Io
G10
E10
270°
±
Isolating
Transformer
808735A1.CDR
FIGURE A–4: Ground Directional Element Polarities and Plane of Operation
GENERATOR
CORE
BALANCE
CT
BREAKER
Aux.
Contact
Grounding
Switch
Grounding
Impedance
(Trans. &
Resistor)
Aux.
Breaker
489
To Relay
Ground
Directional
Element
(or O/C)
Vneutral
Input
Isolating
Transformer
Grounding
Switch
Aux. Cont.
Neutral
O/V
Element
G.S.
Status
Ground
Current
Input
Ground
O/C
Element
Breaker
Status
808734A1.CDR
FIGURE A–5: Ground Directional Element Conceptual Arrangement
The operating principle of this element is quite simple: for internal ground faults the two
signals will be 180° out of phase and for external ground faults, the two signals will be in
phase. This simple principle allows the element to be set with a high sensitivity, not
normally possible with an overcurrent element.
The current pickup level of the element can be adjusted down to 0.05 × CT primary,
allowing an operate level of 0.25 A primary if the 50:0.025 ground CT is used for the core
balance. The minimum level of Vneutral at which the element will operate is determined by
hardware limitations and is internally set at 2.0 V.
Because this element is directional, it does not need to be coordinated with downstream
protections and a short operating time can be used. Definite time delays are suitable for
this element.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
A–5
CHAPTER A: APPENDIX
Applications with generators operated in parallel and grounded through a common
impedance require special considerations. If only one generator is grounded and the other
ones left floating, the directional element for the floating generators does not receive a
correct Vneutral signal and therefore cannot operate correctly. In those applications, the
element makes use of auxiliary contacts off the grounding switch and the unit breaker to
turn the element into a simple overcurrent element, with the pickup level set for the
directional element (note that the ground directional element and the ground overcurrent
elements are totally separate elements). In this mode, the element can retain a high
sensitivity and fast operate time since it will only respond to internal stator ground faults.
The table below illustrates the status of different elements under various operating
conditions.
Table A–1: Detection Element Status
Generator
Condition
A.1.5
Unit
Breaker
Ground
Switch
Element
Ground
Directional
Neutral
Overvoltage
Ground
Overcurrent
Shutdown
Open
Open
Out-of-service
Out-of-service
In-service
Open Circuit
and
grounded
Open
Closed
In-service (but will
not operate due to
lack of I0)
In-service
In-service
Loaded and
Grounded
Closed
Closed
In-service
In-service
In-service
Loaded and
Not
Grounded
Closed
Open
In service as a
simple overcurrent
element
Out-of-service
In-service
Third Harmonic Voltage Element
The conventional neutral overvoltage element or the ground overcurrent element are not
capable of reliably detecting stator ground faults in the bottom 5% of the stator, due to
lack of sensitivity. In order to provide reliable coverage for the bottom part of the stator,
protective elements, utilizing the third harmonic voltage signals in the neutral and at the
generator output terminals, have been developed (see Reference 4).
In the 489 relay, the third-harmonic voltage element, Neutral Undervoltage (3rd Harmonic)
derives the third harmonic component of the neutral-point voltage signal from the Vneutral
signal as one signal, called VN3. The third harmonic component of the internally summed
phase-voltage signals is derived as the second signal, called VP3. For this element to
perform as originally intended, it is necessary to use wye-connected VTs.
Since the amount of third harmonic voltage that appears in the neutral is both load and
machine dependent, the protection method of choice is an adaptive method. The following
formula is used to create an adaptive third-harmonic scheme:
V N3
------------------------------≤ 0.15
V P3 ⁄ 3 + V N3
which simplifies to
V P3 ≥ 17V N3
(EQ 1.1)
The 489 tests the following conditions prior to testing the basic operating equation to
ensure that VN3 is of a measurable magnitude:
A–6
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER A: APPENDIX
Neutral CT Ratio
V P3′ > 0.25 V and V P3′ ≥ Permissive_Threshold × 17 × ---------------------------------------Phase CT Ratio
(EQ 1.2)
where: VN3 is the magnitude of third harmonic voltage at the generator neutral
VP3 is the magnitude of third harmonic voltage at the generator terminals
VP3' and VN3' are the corresponding voltage transformer secondary values
Permissive_Threshold is 0.15 V for the alarm element and 0.1875 V for the trip
element.
In addition, the logic for this element verifies that the generator positive sequence terminal
voltage is at least 30% of nominal, to ensure that the generator is actually excited.
This method of using 3rd harmonic voltages to detect stator ground faults near the
generator neutral has proved feasible on larger generators with unit transformers. Its
usefulness in other generator applications is unknown.
Note
If the phase VT connection is “Open Delta”, it is not possible to measure the third harmonic
voltage at the generator terminals and a simple third harmonic neutral undervoltage
element is used. In this case, the element is supervised by both a terminal voltage level and
by a power level. When used as a simple undervoltage element, settings should be based
on measured 3rd harmonic neutral voltage of the healthy machine. It is recommended
that the element only be used for alarm purposes with open delta VT connections.
A.1.6
References
1.
C. R. Mason, “The Art & Science of Protective Relaying”, John Wiley & Sons, Inc., 1956,
Chapter 10.
2.
J. Lewis Blackburn, “Protective Relaying: Principles and Applications”, Marcel Dekker,
Inc., New York, 1987, chapter 8.
3.
GE Multilin, “Instruction Manual for the 489 Generator Management Relay”.
4.
R. J. Marttila, “Design Principles of a New Generator Stator Ground Relay for 100%
Coverage of the Stator Winding”, IEEE Transactions on Power Delivery, Vol. PWRD-1,
No. 4, October 1986.
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
A–7
CHAPTER A: APPENDIX
A.2
Stator Differential Protection Special Application
A.2.1
Background
The 489 relay is applied in a dual breaker arrangement as shown in the figure below. In this
configuration one breaker is closed at a time eliminating a danger of through fault
conditions. However, the customer prefers not to sum up the two breaker currents to
obtain effectively the terminal-side current of the generator, nor to install an extra CT at
the generator to measure the terminal-side current explicitly. Instead, the customer
applies two 489 relays each spanning its differential zone between the neutral-side CT of
the generator and the CT at the corresponding breaker.
In this application, when a breaker is closed, the other (opposite) relay would measure the
neutral-side current without the matching terminal-side current, as the latter flows via the
other (closed) breaker and it not visible to the opposite relay.
Block 87 when CB closed
489-2
489-1
G
FIGURE A–6: Considered application of two 489s protecting a dual-breaker generator configuration
When both breakers are opened both relays be operational with the differential function
enabled. The application is based on blocking the differential function using the position of
the opposite breaker via the multiple setting group mechanism of the relay.
When both breakers are opened, both relays are in their setting group 1 with the
differential functions operational. When a breaker is closed, its relay remains in group 1 so
that no setting group switching takes place and therefore continuous uninterrupted
protection is provided for the generator. At the same time the opposite relay is blocked by
switching to group 2 in which the differential function is disabled. This prevents misoperation. There is no provision for an “advanced close” signal, and the breaker position
signal is used instead.
A–8
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER A: APPENDIX
In addition, enhanced differential protection algorithm takes care the timing offset
between the main and auxiliary contacts of the breaker. As a result, maximum of 50ms
timing offset between the main and auxiliary contacts of the breaker will block the
differential function.
A.2.2
Stator Differential Logic
The differential function uses an internal timer of 130ms as shown in the figure below. This
timer is a common timer for all three phases of the differential function. Normally, the timer
is not engaged ensuring instantaneous operation and backward compatibility with the
previous firmware revisions of the product.
The timer is engaged only when the terminal-side currents in all three phases are zero. If
any of the terminal currents is above 5% of CT nominal, the timer is by-passed. Also, if any
of the neutral-side current is above 5 times CT nominal, the timer is by-passed as well.
In this logic the current magnitudes are filtered fundamental frequency components (T
stands for terminal-side currents, and N stands for neutral-side currents); PKP denotes the
pickup state of the element prior to any user set delay that may or may not be used in a
particular application; A, B and C designate phases.
The differential element works as follows:
With the machine under load, the terminal currents are above 5% of CT nominal and no
delay is applied to the differential function.
With the machine on-line but with no load (below 5%) the delay is applied. However, should
a fault occur at that time, at least one of the terminal current would get elevated
cancelling the delay and resulting in an instantaneous trip.
With the opposite breaker being closed as in the considered dual-breaker application, a
current is drawn (either transformer inrush or load or both). This will activate the
differential characteristic. However, the timer remains engaged because all the terminal
currents (ABC) are zero, and all the neutral-side currents (ABC) are below 5 times CT
nominal. The timer keeps timing out. However, before it expires the relay switches to group
2 and blocks the differential function. This prevents misoperation.
Normally, no extra
delay is applied
0ms
100ms
OR
IT mag B > 0.05pu
OR
IT mag A > 0.05pu
IT mag C > 0.05pu
OR
IN mag B > 5pu
AND
IN mag A > 5pu
OR
IN mag C > 5pu
87 PKP
87 PKP B
OR
87 PKP A
130ms
0ms
87 PKP C
With no terminal side currents, a
delay of an extra 130ms is applied
to the differential function.
FIGURE A–7: Enhancements to the stator differential logic
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
A–9
CHAPTER A: APPENDIX
Should a fault occur during the first 50-60ms after closing the breaker, the corresponding
relay would trip instantly. Before closing the breaker the corresponding relay too applies a
delay. However, once the load/inrush current exceeds 5% of CT nominal, its timer is bypassed and instantaneous protection is provided.
Should a fault occur during generator start-up with both breakers opened, both relays
would operate after the extra time delay of 130ms. This delay is acceptable under such
conditions. Even this delay will be eliminated if the fault is heavy enough to draw more
than 5 times CT nominal from the neutral-side of the generator.
For proper implementation, the internal timer is cleared each time the 87 function
becomes enabled (so that a partial time out from the previous “enabled” period does not
affect the intended operation).
A–10
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER A: APPENDIX
A.3
Current Transformers
A.3.1
Ground Fault CTs for 50:0.025 A CT
CTs that are specially designed to match the ground fault input of GE Multilin motor
protection relays should be used to ensure correct performance. These CTs have a
50:0.025A (2000:1 ratio) and can sense low leakage currents over the relay setting range
with minimum error. Three sizes are available with 3½-inch, 5½-inch, or 8-inch diameter
windows.
HGF3C
808840A1
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
A–11
CHAPTER A: APPENDIX
HGF5C
808841A1
HGF8
808842A1
A–12
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER A: APPENDIX
A.3.2
Ground Fault CTs for 5 A Secondary CT
For low resistance or solidly grounded systems, a 5 A secondary CT should be used. Two
sizes are available with 5½” or 13” × 16” windows. Various Primary amp CTs can be chosen
(50 to 250).
GCT5
GCT16
DIMENSIONS
DIMENSIONS
808709A1.CDR
A.3.3
Phase CTs
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
A–13
CHAPTER A: APPENDIX
Current transformers in most common ratios from 50:5 to 1000:5 are available for use as
phase current inputs with motor protection relays. These come with mounting hardware
and are also available with 1 A secondaries. Voltage class: 600 V BIL, 10 KV.
808712A1.CDR
A–14
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER A: APPENDIX
A.4
Time Overcurrent Curves
A.4.1
ANSI Curves
GE Multilin
489 ANSI
MODERATELY INVERSE
1000
100
MULTIPLIER
10
TRIP TIME (sec)
30.0
20.0
15.0
10.0
8.0
6.0
1
4.0
3.0
2.0
1.0
0.5
0.1
0.01
0.1
1
10
CURRENT (I/Ipu)
100
808802A4.CDR
FIGURE A–8: ANSI Moderately Inverse Curves
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
A–15
CHAPTER A: APPENDIX
GE Multilin
489 ANSI
NORMALLY INVERSE
1000
100
MULTIPLIER
TRIP TIME (sec)
10
30.0
20.0
15.0
10.0
8.0
1
6.0
4.0
3.0
2.0
1.0
0.1
0.5
0.01
0.1
1
10
CURRENT (I/Ipu)
100
808801A4.CDR
FIGURE A–9: ANSI Normally Inverse Curves
A–16
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER A: APPENDIX
489 ANSI
VERY INVERSE
GE Multilin
1000
100
10
TRIP TIME (sec)
MULTIPLIER
30.0
20.0
15.0
1
10.0
8.0
6.0
4.0
3.0
2.0
1.0
0.1
0.5
0.01
0.1
1
10
CURRENT (I/Ipu)
100
808800A4.DWG
FIGURE A–10: ANSI Very Inverse Curves
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
A–17
CHAPTER A: APPENDIX
489 ANSI
EXTREME INVERSE
GE Multilin
1000
100
TRIP TIME (sec)
10
MULTIPLIER
30.0
20.0
1
15.0
10.0
8.0
6.0
4.0
3.0
2.0
0.1
1.0
0.5
0.01
0.1
1
10
CURRENT (I/Ipu)
100
808799A4.CDR
FIGURE A–11: ANSI Extremely Inverse Curves
A–18
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER A: APPENDIX
A.4.2
Definite Time Curves
489
DEFINITE TIME
GE Multilin
1000
100
TRIP TIME (sec)
10
MULTIPLIER
30.0
20.0
15.0
10.0
1
8.0
6.0
4.0
3.0
2.0
1.0
0.1
0.5
100
10
1
0.1
0.01
CURRENT (I/Ipu)
808798A4.CDR
FIGURE A–12: Definite Time Curves
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
A–19
CHAPTER A: APPENDIX
A.4.3
IAC Curves
GE Multilin
489 IAC
SHORT INVERSE
1000
100
MULTIPLIER
TRIP TIME (sec)
10
30.0
1
20.0
15.0
10.0
8.0
6.0
4.0
3.0
0.1
2.0
1.0
0.5
CURRENT (I/Ipu)
100
10
1
0.1
0.01
808811A4.CDR
FIGURE A–13: IAC Short Inverse Curves
A–20
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER A: APPENDIX
489
IAC INVERSE
GE Multilin
1000
100
MULTIPLIER
10
TRIP TIME (sec)
30.0
20.0
15.0
10.0
8.0
6.0
4.0
1
3.0
2.0
1.0
0.5
0.1
CURRENT (I/Ipu)
100
10
1
0.1
0.01
808810A4.CDR
FIGURE A–14: IAC Inverse Curves
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
A–21
CHAPTER A: APPENDIX
489 IAC
VERY INVERSE
GE Multilin
1000
100
10
TRIP TIME (sec)
MULTIPLIER
30.0
20.0
15.0
10.0
8.0
1
6.0
4.0
3.0
2.0
1.0
0.1
0.5
CURRENT (I/Ipu)
100
10
1
0.1
0.01
808807A3.CDR
FIGURE A–15: IAC Very Inverse Curves
A–22
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER A: APPENDIX
489 IAC
EXTREME INVERSE
GE Multilin
1000
100
TRIP TIME (sec)
10
MULTIPLIER
30.0
1
20.0
15.0
10.0
8.0
6.0
4.0
3.0
0.1
2.0
1.0
0.5
CURRENT (I/Ipu)
100
10
1
0.1
0.01
808806A4.CDR
FIGURE A–16: IAC Extreme Inverse Curves
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
A–23
CHAPTER A: APPENDIX
A.4.4
IEC Curves
GE Multilin
489
IEC CURVE A (BS142)
1000
100
TRIP TIME (sec)
10
MULTIPLIER
1.00
0.80
0.60
0.50
0.40
1
0.30
0.20
0.15
0.10
0.05
0.1
CURRENT (I/Ipu)
100
10
1
0.1
0.01
808803A4.CDR
FIGURE A–17: IEC Curves A (BS142)
A–24
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER A: APPENDIX
GE Multilin
489
IEC CURVE B (BS142)
1000
100
TRIP TIME (sec)
10
MULTIPLIER
1
1.00
0.80
0.60
0.50
0.40
0.30
0.20
0.15
0.1
0.10
0.05
100
10
1
0.1
0.01
CURRENT (I/Ipu)
808804A4.CDR
FIGURE A–18: IEC Curves B (BS142)
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
A–25
CHAPTER A: APPENDIX
GE Multilin
489
IEC CURVE C (BS142)
1000
100
TRIP TIME (sec)
10
1
MULTIPLIER
1.00
0.80
0.60
0.50
0.1
0.40
0.30
0.20
0.15
0.10
0.05
CURRENT (I/Ipu)
100
10
1
0.1
0.01
808805A4.CDR
FIGURE A–19: IEC Curves C (BS142)
A–26
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER A: APPENDIX
A.5
Revision History
A.5.1
Change Notes
Table A–2: Revision History
MANUAL P/N
REVISION
RELEASE DATE
ECO
1601-0150-A1
3.00
26 April 2004
489-249
1601-0150-A2
3.00
21 May 2004
---
1601-0150-A3
3.00
22 July 2004
---
1601-0150-A5
4.0x
21 July 2006
1601-0150-A6
4.0x
9 February, 2007
1601-0150-A7
4.0x
31 March, 2007
1601-0150-A8
4.0x
3 April, 2008
1601-0150-A9
4.0x
12 June, 2008
1601-0150-AA
4.0x
10 September, 2008
1601-0150-AB
4.0x
2 December, 2008
1601-0150-AC
4.0x
23 April, 2009
1601-0150-AD
4.0x
21 July, 2009
1601-0150-A4
A.5.2
Changes to the 489 Manual
Table A–3: Major Updates for 489 Manual Revision AD
SECT
(AC)
SECT
(AD)
CHANGE
DESCRIPTION
Title
Title
Update
Manual part number to 1601-0150-AD
3.1.6
3.1.6
Revision
Figure 3-9 revised.
3.2.1
3.2.1
Revision
Figure 3-10 revised.
Table A–4: Major Updates for 489 Manual Revision AC
SECT
(AB)
Title
SECT
(AC)
Title
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHANGE
Update
DESCRIPTION
Manual part number to 1601-0150-AC
A–27
CHAPTER A: APPENDIX
Table A–4: Major Updates for 489 Manual Revision AC
SECT
(AB)
4.1.7
SECT
(AC)
4.1.7
CHANGE
DESCRIPTION
Self-test Warnings table: Relay Not Configured
revised.
Revision
Table A–5: Major Updates for 489 Manual Revision AB
SECT
(AA)
SECT
(AB)
CHANGE
DESCRIPTION
Title
Title
Update
Manual part number to 1601-0150-AB
2.2.5
2.2.5
Revision
Power Metering - changes to spec.
7.3.2
7.3.2
Revision
Changes to specs.
Table A–6: Major Updates for 489 Manual Revision AA
SECT
(A9)
SECT
(AA)
Title
Title
5.6.9
5.6.9
CHANGE
Update
DESCRIPTION
Manual part number to 1601-0150-AA
Change Note (Pickup Level)
Table A–7: Major Updates for 489 Manual Revision A9
SECT
(A8)
SECT
(A9)
Title
Title
5.6.5
5.6.5
CHANGE
Update
DESCRIPTION
Manual part number to 1601-0150-A9
Fig 5-2: Change graph
Table A–8: Major Updates for 489 Manual Revision A8
SECT
(A7)
SECT
(A8)
DESCRIPTION
Title
Title
Update
Manual part number to 1601-0150-A8
2.1.2
2.2.5
2.1.2
2.2.5
Update
Changes to DC Power Supply range
fig 5-2
fig 5-2
8.2.1
A–28
CHANGE
Change graph
Add
New Section: Stator Differential Protection
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER A: APPENDIX
Table A–8: Major Updates for 489 Manual Revision A8
SECT
(A7)
SECT
(A8)
CHANGE
DESCRIPTION
8.2.1
8.3.1
Update
Drawings changed
Equn 7.7
Equn 7.7
Update
Change equation
Table A–9: Major Updates for 489 Manual Revision A7
PAGE
(A5)
SECT
(A6)
CHANGE
DESCRIPTION
Title
Title
Update
Manual part number to 1601-0150-A6
5-31
5.6.8
Correction
Changes to step value - Differential Trip Delay
2-9
2.2.6
Correction
Changes to Littelfuse SLO-BLO data
2-7,8
5-39,40
2.2.3
5.7.5,6
Update
Changes to OverFrequency and Underfrequency
parameters
Table A–10: Major Updates for 489 Manual Revision A6
PAG
E
(A5)
PAG
E
(A6)
CHANGE
DESCRIPTION
Title
Title
Update
Manual part number to 1601-0150-A6
2-14
2-14
Update
Changes to ELECTROSTATIC DISCHARGE value
Table A–11: Major Updates for 489 Manual Revision A4
PAG
E
(A3)
PAG
E
(A4)
CHANGE
DESCRIPTION
Title
Title
Update
Manual part number to 1601-0150-A4
2-
2-
Update
Updated ORDERING section
2-
2-
Update
Updated SPECIFICATIONS section
---
3-4
Add
Added ETHERNET COMMUNICATION section
5-
---
Remove
Removed SERIAL PORTS section
---
5-
Add
Added COMMUNICATIONS section
5-44
5-44
Update
Updated DISTANCE ELEMENT section
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
A–29
CHAPTER A: APPENDIX
Table A–11: Major Updates for 489 Manual Revision A4
PAG
E
(A3)
PAG
E
(A4)
CHANGE
DESCRIPTION
---
6-3
Add
Added NETWORK STATUS section
---
7-16
Add
Added DISTANCE ELEMENT ACCURACY section
Table A–12: Major Updates for 489 Manual Revision A3
PAG
E
(A2)
PAG
E
(A3)
CHANGE
DESCRIPTION
Title
Title
Update
Manual part number to 1601-0150-A3
5-67
5-67
Update
Updated THERMAL MODEL COOLING diagram to
808705A2
Table A–13: Major Updates for 489 Manual Revision A2
PAG
E
(A1)
Title
PAG
E
(A2)
Title
CHANGE
Update
DESCRIPTION
Manual part number to 1601-0150-A2
Additional changes for revision A2 were cosmetic. There was no change to content.
A–30
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
CHAPTER A: APPENDIX
A.6
EU Declaration of Conformity
A.6.1
EU Declaration of Conformity
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
A–31
CHAPTER A: APPENDIX
A.7
Warranty
A.7.1
GE Multilin Warranty
General Electric Multilin Inc. (GE Multilin) warrants each relay it manufactures to be free
from defects in material and workmanship under normal use and service for a period of 24
months from date of shipment from factory.
In the event of a failure covered by warranty, GE Multilin will undertake to repair or replace
the relay providing the warrantor determined that it is defective and it is returned with all
transportation charges prepaid to an authorized service centre or the factory. Repairs or
replacement under warranty will be made without charge.
Warranty shall not apply to any relay which has been subject to misuse, negligence,
accident, incorrect installation or use not in accordance with instructions nor any unit that
has been altered outside a GE Multilin authorized factory outlet.
GE Multilin is not liable for special, indirect or consequential damages or for loss of profit or
for expenses sustained as a result of a relay malfunction, incorrect application or
adjustment.
For complete text of Warranty (including limitations and disclaimers), refer to GE Multilin
Standard Conditions of Sale.
A–32
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
INDEX
Index
Numerics
0-1mA ANALOG INPUT ................................................................................... 3-15
4-20mA ANALOG INPUT ................................................................................. 3-15
50:0.025 CT ...................................................................................................... 3-12
A
ACCESS SWITCH .............................................................................................. 5-21
ACCESSORIES .................................................................................................... 2-5
ACTUAL VALUES
messages .......................................................................................................... 6-3
ALARM PICKUPS ............................................................................................... 6-12
ALARM RELAY .......................................................................................... 3-17, 5-28
ALARM STATUS ................................................................................................. 6-6
ALARMS ....................................................................................................... 5-6, 5-7
ANALOG IN MIN/MAX ...................................................................................... 6-23
ANALOG INPUTS .............................................................................................. 3-14
actual values .......................................................................................... 6-20, 6-23
analog I/P min/max ......................................................................................... 5-17
min/max .......................................................................................................... 6-23
minimums and maximums .............................................................................. 5-23
setpoints .......................................................................................................... 5-98
specifications ................................................................................................... 2-6
testing .............................................................................................................. 7-9
ANALOG OUTPUTS ........................................................................................... 3-15
setpoints .......................................................................................................... 5-96
specifications ................................................................................................... 2-7
table ................................................................................................................ 5-97
testing .............................................................................................................. 7-9
ANSI CURVES .......................................................................................... 5-30, A-15
ANSI DEVICE NUMBERS ................................................................................... 2-2
APPLICATION NOTES
current transformers ...................................................................................... A-11
stator ground fault ........................................................................................... A-1
AUXILIARY RELAY .................................................................................... 3-17, 5-28
B
BAUD RATE .............................................................................................. 2-14, 5-12
setpoints .......................................................................................................... 5-13
BREAKER FAILURE ........................................................................................... 5-90
BREAKER STATUS ............................................................................................. 5-21
BURDEN ............................................................................................................. 2-6
C
CALIBRATION INFO .......................................................................................... 6-31
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
I–1
INDEX
CASE ........................................................................................................... 2-15, 3-1
CAUSE OF EVENTS TABLE ............................................................................... 6-29
CHANGING SETPOINTS ..................................................................................... 1-9
CLEAR DATA ..................................................................................................... 5-16
CLOCK ...................................................................................................... 5-13, 6-15
COMM PORT MONITOR ................................................................................. 5-104
COMMUNICATIONS
monitoring ..................................................................................................... 5-104
RS232 ............................................................................................ 4-11, 4-15, 4-17
RS485 ............................................................................................ 4-12, 4-15, 4-17
setpoints .......................................................................................................... 5-12
specifications .................................................................................................. 2-14
wiring ...................................................................................................... 4-11, 4-12
CONTROL FEATURES ......................................................................................... 5-6
CONTROL POWER ............................................................................................ 3-10
COOLING .......................................................................................................... 5-85
COOLING TIME CONSTANTS ........................................................................... 5-85
CORE BALANCE ................................................................................................ 3-12
CT RATIO ........................................................................................................... 5-18
CTs
burden ............................................................................................................... 2-6
ground fault .................................................................................................... A-13
phase .............................................................................................................. A-13
setpoints .......................................................................................................... 5-18
withstand ........................................................................................................... 2-6
CURRENT
CURRENT
CURRENT
CURRENT
CURRENT
CURVES
ACCURACY TEST ............................................................................... 7-4
DEMAND .......................................................................................... 5-93
INPUTS .............................................................................................. 2-7
METERING ....................................................................................... 6-16
SENSING .......................................................................................... 5-18
see OVERLOAD CURVES
CUSTOM OVERLOAD CURVE ........................................................................... 5-76
D
DEFAULT MESSAGES ..................................................................... 5-10, 5-14, 5-15
DEFINITE TIME CURVE ........................................................................... 5-32, A-19
DEMAND DATA ................................................................................................. 5-23
DEMAND METERING ...................................................................... 2-12, 5-93, 6-20
DEMAND PERIOD ............................................................................................. 5-94
DESCRIPTION ..................................................................................................... 2-1
DEVICE NUMBERS .............................................................................................. 2-2
DIAGNOSTIC MESSAGES ................................................................................. 6-32
DIELECTRIC STRENGTH
specifications .................................................................................................. 2-14
testing ............................................................................................................. 3-18
DIFFERENTIAL CURRENT ACCURACY TEST ..................................................... 7-5
DIGITAL COUNTER ........................................................................................... 5-23
DIGITAL INPUTS ............................................................................................... 3-14
actual values ................................................................................................... 6-15
dual setpoints .................................................................................................. 5-24
field-breaker discrepancy ............................................................................... 5-26
general input ................................................................................................... 5-22
ground switch status ....................................................................................... 5-27
I–2
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
INDEX
remote reset .................................................................................................... 5-23
sequential trip ................................................................................................. 5-25
specifications ................................................................................................... 2-6
tachometer ...................................................................................................... 5-26
test input ......................................................................................................... 5-23
testing .............................................................................................................. 7-9
thermal reset ................................................................................................... 5-23
DIMENSIONS ..................................................................................................... 3-2
DISPLAY ............................................................................................................. 4-1
DISTANCE ELEMENTS ...................................................................................... 5-56
DRAWOUT INDICATOR .................................................................................... 3-17
DUAL SETPOINTS ...................................................................................... 5-8, 5-24
E
EMERGENCY RESTARTS ................................................................................... 5-23
ENERVISTA VIEWPOINT WITH THE 489 ......................................................... 4-44
ENTERING TEXT ................................................................................................. 4-5
ETHERNET
actual values .................................................................................................... 6-4
setpoints .......................................................................................................... 5-13
EU ..................................................................................................................... A-31
EU Declaration of Conformity ...................................................................... A-31
EVENT RECORD
cause of events ............................................................................................... 6-29
EVENT RECORDER .......................................................................... 5-17, 5-23, 6-28
F
FACTORY SERVICE ......................................................................................... 5-104
FAULT SETUP .................................................................................................. 5-102
FEATURES ........................................................................................... 2-2, 2-3, 2-10
FIELD-BREAKER DISCREPANCY ...................................................................... 2-11
FIRMWARE
upgrading via EnerVista 489 setup software .................................................. 4-30
FLASH MESSAGES ............................................................................................ 6-33
FLEXCURVE ....................................................................................................... 5-31
FLOW ................................................................................................................. 3-14
FREQUENCY TRACKING .................................................................................... 2-6
FRONT PANEL
using ................................................................................................................. 1-3
FUSE .................................................................................................................. 2-13
G
GENERAL COUNTERS ....................................................................................... 6-27
GENERAL INPUTS .................................................................................... 2-12, 5-22
GENERATOR INFORMATION ............................................................................ 5-17
GENERATOR LOAD ........................................................................................... 6-22
GENERATOR PARAMETERS ............................................................................. 5-19
GENERATOR STATUS ........................................................................................ 6-4
GETTING STARTED ............................................................................................ 1-1
GROUND CT
burden .............................................................................................................. 2-6
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
I–3
INDEX
setpoint ........................................................................................................... 5-18
withstand ........................................................................................................... 2-6
GROUND
GROUND
GROUND
GROUND
GROUND
GROUND
CURRENT ACCURACY TEST ..................................................... 7-5, 7-15
CURRENT INPUT .............................................................................. 3-12
DIRECTIONAL ........................................................................... 5-40, A-4
FAULT CTs ....................................................................................... A-13
OVERCURRENT ........................................................................ 5-38, A-3
SWITCH STATUS .............................................................................. 5-27
H
HELP KEY .......................................................................................................... 1-10
HIGH-SET PHASE OVERCURRENT .................................................................. 5-42
HI-POT .............................................................................................................. 3-18
HOT/COLD SAFE STALL RATIO ....................................................................... 5-87
I
IAC CURVES ............................................................................................ 5-31, A-20
IDENTIFICATION ................................................................................................. 3-2
IEC CURVES ............................................................................................ 5-30, A-24
IED SETUP ......................................................................................................... 4-13
INADVERTENT ENERGIZATION ................................................................ 2-9, 5-34
INJECTION TEST SETUP .................................................................. 7-3, 7-15, 7-19
INPUTS
analog ...................................................................................................... 2-6, 3-14
current ............................................................................................. 2-7, 3-11, 3-12
digital ....................................................................................................... 2-6, 3-14
general ............................................................................................................ 2-12
RTD ........................................................................................................... 2-7, 3-15
voltage ..................................................................................................... 2-7, 3-14
INSERTION .......................................................................................................... 3-4
INSPECTION CHECKLIST ................................................................................... 1-1
INSTALLATION .................................................................................................... 3-3
IRIG-B ....................................................................................................... 3-17, 5-13
K
KEYPAD ............................................................................................................... 4-3
help .................................................................................................................. 1-10
L
LAST TRIP DATA ............................................................... 5-17, 5-23, 6-5, 6-9, 6-12
LEARNED PARAMETERS .................................................................................. 5-23
LEDs ..................................................................................................... 4-1, 4-2, 4-3
LONG-TERM STORAGE .................................................................................... 2-17
LOOP POWERED TRANSDUCERS .................................................................... 3-14
LOSS OF EXCITATION ............................................................................... 2-9, 5-55
LOSS OF LOAD ................................................................................................... 4-3
LOW FORWARD POWER ................................................................................. 5-63
I–4
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
INDEX
M
MACHINE COOLING ......................................................................................... 5-85
MESSAGE SCRATCHPAD .................................................................................. 5-15
METERING
current ............................................................................................................. 6-16
demand .................................................................................................. 2-12, 6-20
Mvarh ............................................................................................. 5-17, 5-23, 6-18
MWh ............................................................................................... 5-17, 5-23, 6-18
power ............................................................................................................... 2-13
specifications ................................................................................................... 2-4
voltage ............................................................................................................. 6-17
MODEL INFORMATION .................................................................................... 6-31
MODEL SETUP .................................................................................................. 5-71
MOTOR STARTS ................................................................................................ 5-23
MOTOR TRIPS ................................................................................................... 5-23
MVA DEMAND ......................................................................................... 5-93, 6-20
MVAR DEMAND ....................................................................................... 5-93, 6-20
Mvarh METERING ........................................................................... 5-17, 5-23, 6-18
MW DEMAND ........................................................................................... 5-93, 6-20
MWh METERING ............................................................................. 5-17, 5-23, 6-18
N
NAMEPLATE ....................................................................................................... 1-1
NEGATIVE SEQUENCE CURRENT ACCURACY TEST ....................................... 7-6
NEGATIVE SEQUENCE OVERCURRENT .......................................................... 5-36
NEGATIVE-SEQUENCE CURRENT ................................................................... 6-17
NEUTRAL CURRENT ACCURACY TEST ............................................................. 7-5
NEUTRAL OVERVOLTAGE ........................................................................ 5-51, A-2
NEUTRAL UNDERVOLTAGE ............................................................................. 5-53
NEUTRAL VOLTAGE ACCURACY TEST ..................................................... 7-6, 7-16
NUMERICAL SETPOINTS .................................................................................. 1-10
O
OFFLINE OVERCURRENT ................................................................................. 5-33
OPEN DELTA ..................................................................................................... 3-14
OPEN DELTA CONNECTED VTs ....................................................................... 5-54
OPEN RTD SENSOR .......................................................................................... 5-68
ORDER CODES ................................................................................................... 2-6
OUTPUT CURRENT ACCURACY TEST ............................................................... 7-4
OUTPUT RELAY LEDs ........................................................................................ 4-3
OUTPUT RELAYS
1 Trip ................................................................................................................ 3-16
2 Auxiliary ........................................................................................................ 3-17
3 Auxiliary ........................................................................................................ 3-17
4 Auxiliary ........................................................................................................ 3-17
5 Alarm ............................................................................................................ 3-17
6 Service .......................................................................................................... 3-17
setpoints .......................................................................................................... 5-28
specifications ................................................................................................... 2-8
testing ............................................................................................................. 7-11
wiring ............................................................................................................... 3-16
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
I–5
INDEX
OUTPUTS
analog ...................................................................................................... 2-7, 3-15
OVERCURRENT
ground ............................................................................................................. 5-38
ground directional ........................................................................................... 5-40
high-set ........................................................................................................... 5-42
negative-sequence .......................................................................................... 5-36
phase ............................................................................................................... 5-35
phase differential ............................................................................................ 5-39
setpoints .......................................................................................................... 5-33
specifications ........................................................................................... 2-9, 2-10
TOC .................................................................................................................. 5-29
OVERCURRENT ALARM .................................................................................... 5-33
OVERCURRENT CURVES
ANSI ................................................................................................................ A-15
characteristics ................................................................................................. 5-29
definite time ................................................................................................... A-19
graphs ............................................................................................................ A-15
IAC ......................................................................................................... 5-31, A-20
IEC ......................................................................................................... 5-30, A-24
OVERFREQUENCY ................................................................................... 2-10, 5-50
OVERLOAD CURVE MULTIPLIERS ................................................................... 5-75
OVERLOAD CURVES
custom ............................................................................................................. 5-76
definite time .................................................................................................... 5-32
standard multipliers ........................................................................................ 5-75
testing ............................................................................................................. 7-12
OVERVOLTAGE ........................................................................................ 2-10, 5-44
P
PACKAGING ...................................................................................................... 2-15
PARAMETER AVERAGES .................................................................................. 6-22
PARITY ...................................................................................................... 5-12, 5-13
PASSCODE ................................................................................................... 5-9, 6-1
PEAK DEMAND ........................................................................................ 5-17, 6-20
PHASE CT PRIMARY ................................................................................ 5-18, 5-19
PHASE CTs ....................................................................................................... A-13
PHASE CURRENT INPUTS ................................................................................ 3-11
PHASE DIFFERENTIAL ...................................................................................... 5-39
PHASE DIFFERENTIAL TRIP TEST .................................................................... 7-16
PHASE OVERCURRENT .................................................................................... 5-35
PHASE REVERSAL ............................................................................................. 5-48
PHASE REVERSAL TEST ................................................................................... 7-14
POSITIVE-SEQUENCE CURRENT ..................................................................... 6-17
POWER DEMAND ............................................................................................. 5-93
POWER MEASUREMENT CONVENTIONS ....................................................... 5-60
POWER MEASUREMENT TEST ......................................................................... 7-13
POWER METERING .................................................................................. 2-13, 6-18
POWER SUPPLY ...................................................................................... 2-13, 3-11
POWER SYSTEM ...................................................................................... 5-19, 5-20
PRE-FAULT SETUP ......................................................................................... 5-101
PREFERENCES .................................................................................................. 5-10
PRESSURE ......................................................................................................... 3-14
PRODUCT IDENTIFICATION ............................................................................... 3-2
I–6
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
INDEX
PRODUCTION TESTS ........................................................................................ 2-14
PROTECTION FEATURES ................................................................................... 2-3
PROXIMITY PROBE ........................................................................................... 3-14
PULSE OUTPUT ..........................................................................................2-8, 5-94
R
REACTIVE POWER ............................................................................................ 5-61
REACTIVE POWER TEST ................................................................................... 7-13
REAL TIME CLOCK ................................................................................... 5-13, 6-15
RELAY ASSIGNMENT PRACTICES ..................................................................... 5-7
RELAY RESET MODE ......................................................................................... 5-28
REMOTE RESET ................................................................................................. 5-23
RESETTING THE 489 ........................................................................................ 5-28
RESIDUAL GROUND CONNECTION ................................................................ 3-12
REVERSE POWER ............................................................................................. 5-62
REVISION HISTORY ......................................................................................... A-27
RS232 COMMUNICATIONS ...................................................................... 4-3, 5-12
configuring with EnerVista 469 setup ............................................................. 4-17
configuring with EnerVista 489 setup ............................................................. 4-15
configuring with EnerVista 750/760 Setup ...................................................... 4-17
connections ..................................................................................................... 4-11
RS485 COMMUNICATIONS .................................................................... 3-17, 5-12
configuring with EnerVista 469 setup ............................................................. 4-17
configuring with EnerVista 489 setup ............................................................. 4-15
configuring with EnerVista 750/760 Setup ...................................................... 4-17
connections ..................................................................................................... 4-12
RTD
actual values .......................................................................................... 6-19, 6-23
maximums ..................................................................................... 5-17, 5-23, 6-22
sensor connections ......................................................................................... 3-15
setpoints ........................................................................................ 5-65, 5-66, 5-67
specifications ........................................................................................... 2-7, 2-11
testing .............................................................................................................. 7-7
RTD ACCURACY TEST ........................................................................................ 7-7
RTD BIAS ........................................................................................................... 5-87
RTD MAXIMUMS ............................................................................................... 6-22
RTD SENSOR, OPEN ......................................................................................... 5-68
RTD SHORT/LOW TEMPERATURE ................................................................... 5-69
RTD TYPES ........................................................................................................ 5-64
RUNNING HOUR SETUP .................................................................................. 5-95
RUNNING HOURS ............................................................................................ 5-23
S
SEQUENTIAL TRIP ................................................................................... 2-12, 5-25
SERIAL PORTS .................................................................................................. 5-12
SERIAL START/STOP INITIATION .................................................................... 5-20
SERVICE RELAY ................................................................................................ 3-17
SETPOINT ENTRY ............................................................................................... 4-6
SETPOINT MESSAGE MAP ................................................................................ 5-1
SETPOINTS
changing ........................................................................................................... 1-9
dual setpoints ................................................................................................... 5-8
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
I–7
INDEX
entering with EnerVista 489 setup software ................................................... 4-21
loading from a file ........................................................................................... 4-28
messages .......................................................................................................... 5-1
numerical ........................................................................................................ 1-10
saving to a file ................................................................................................. 4-30
text .................................................................................................................. 1-15
SIMULATION MODE ....................................................................................... 5-100
SINGLE LINE DIAGRAM ..................................................................................... 2-1
SLAVE ADDRESS .............................................................................................. 5-13
SOFTWARE
entering setpoints ........................................................................................... 4-21
hardware requirements ................................................................................... 4-10
installation ....................................................................................................... 4-12
loading setpoints ............................................................................................. 4-28
overview .......................................................................................................... 4-10
saving setpoints .............................................................................................. 4-30
serial communications ........................................................................... 4-15, 4-17
SPECIFICATIONS ................................................................................................ 2-6
SPEED ................................................................................................................ 6-21
STANDARD OVERLOAD CURVES
multipliers ........................................................................................................ 5-75
STARTER
information ...................................................................................................... 5-17
operations ....................................................................................................... 5-23
status .............................................................................................................. 5-21
STATOR GROUND FAULT PROTECTION .......................................................... A-1
STATUS LEDs ...................................................................................................... 4-2
T
TACHOMETER ................................................................................. 2-12, 5-26, 6-21
TEMPERATURE ................................................................................................. 6-19
TEMPERATURE DISPLAY .................................................................................. 5-10
TERMINAL LAYOUT ............................................................................................ 3-7
TERMINAL LIST ................................................................................................... 3-8
TERMINAL LOCATIONS ...................................................................................... 3-7
TERMINAL SPECIFICATIONS ........................................................................... 2-15
TEST ANALOG OUTPUT ................................................................................. 5-103
TEST INPUT ....................................................................................................... 5-23
TEST OUTPUT RELAYS ................................................................................... 5-102
TESTS
differential current accuracy ............................................................................ 7-5
ground current accuracy .......................................................................... 7-5, 7-15
list ...................................................................................................................... 7-1
negative-sequence current accuracy ............................................................... 7-6
neutral current accuracy ................................................................................... 7-5
neutral voltage accuracy ......................................................................... 7-6, 7-16
output current accuracy ................................................................................... 7-4
output relays ................................................................................................... 7-11
overload curves ............................................................................................... 7-12
phase current accuracy .................................................................................... 7-4
power measurement ....................................................................................... 7-13
production tests .............................................................................................. 2-14
reactive power ................................................................................................ 7-13
RTD accuracy ..................................................................................................... 7-7
secondary injection setup ................................................................................. 7-3
I–8
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
INDEX
voltage input accuracy ..................................................................................... 7-4
voltage phase reversal .................................................................................... 7-14
TEXT SETPOINTS .............................................................................................. 1-15
THERMAL CAPACITY USED ............................................................................... 6-4
THERMAL ELEMENTS ....................................................................................... 5-89
THERMAL MODEL
machine cooling .............................................................................................. 5-85
setpoints .......................................................................................................... 5-70
specifications .................................................................................................. 2-10
unbalance bias ................................................................................................ 5-84
THERMAL RESET ............................................................................................... 5-23
THIRD HARMONIC VOLTAGE ........................................................................... A-6
TIME .......................................................................................................... 5-13, 6-15
TIME OVERCURRENT CURVES ........................................................................ A-15
TIMERS .............................................................................................................. 6-27
TOC CHARACTERISTICS ................................................................................... 5-29
TOC CURVES .................................................................................................... A-15
TRIP COIL MONITOR ........................................................................................ 5-91
TRIP COIL SUPERVISION .......................................................................... 2-13, 7-9
TRIP COUNTER ............................................................................... 5-17, 5-90, 6-25
TRIP PICKUPS .................................................................................................... 6-9
TRIP RELAY .............................................................................................. 3-16, 5-28
TRIP TIME ON OVERLOAD, ESTIMATED ........................................................... 6-4
TRIPS .................................................................................................................. 5-6
TYPE TESTS ....................................................................................................... 2-15
TYPICAL WIRING DIAGRAM .............................................................................. 3-9
U
UNBALANCE BIAS ............................................................................................ 5-84
UNDERFREQUENCY ......................................................................................... 5-49
UNDERVOLTAGE ..................................................................................... 2-11, 5-43
UNPACKING THE RELAY ................................................................................... 1-1
UPGRADING FIRMWARE .................................................................................. 4-30
V
VIBRATION ........................................................................................................ 3-14
VOLTAGE DEPENDENT OVERLOAD CURVE ................................................... 5-77
VOLTAGE INPUTS
description ....................................................................................................... 3-14
specifications ................................................................................................... 2-6
testing .............................................................................................................. 7-4
VOLTAGE METERING ........................................................................................ 6-17
VOLTAGE RESTRAINED OVERCURRENT
setpoints .......................................................................................................... 5-35
testing ............................................................................................................. 7-20
VOLTAGE SENSING .......................................................................................... 5-18
VOLTS/HERTZ ................................................................................................... 5-45
VT FUSE FAILURE ............................................................................................. 5-92
VT RATIO ........................................................................................................... 5-18
VTFF .................................................................................................................. 5-92
VTs
open delta ....................................................................................................... 5-54
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
I–9
INDEX
setpoints .......................................................................................................... 5-18
wye connected ................................................................................................ 5-53
W
WARRANTY ............................................................................................. A-27, A-32
WAVEFORM CAPTURE ..................................................................................... 5-27
WIRING DIAGRAM ............................................................................................ 3-10
WITHDRAWAL .................................................................................................... 3-4
WYE ................................................................................................................... 3-14
WYE CONNECTED VTs ..................................................................................... 5-53
I–10
489 GENERATOR MANAGEMENT RELAY – INSTRUCTION MANUAL
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