GE Multilin g60 Instruction Manual Download | Manualshive

Page: 33 / 780

background image

GE Multilin

G60 Generator Protection System

2-1

2 PRODUCT DESCRIPTION

2.1 INTRODUCTION

2

2 PRODUCT DESCRIPTION 2.1INTRODUCTION

2.1.1 OVERVIEW

The G60 Generator Protection System is a microprocessor based relay that provides protection, monitoring, control, and
recording functions for AC generators driven by steam, gas, or hydraulic turbine. Current, voltage and frequency protection
are provided along with fault diagnostics. Breaker fail function is provided for up to four breakers.

Voltage, current, and power metering is built into the relay as a standard feature. Current parameters are available as total
waveform RMS magnitude, or as fundamental frequency only RMS magnitude and angle (phasor).

Diagnostic features include an event recorder capable of storing 1024 time-tagged events, oscillography capable of storing
up to 64 records with programmable trigger, content and sampling rate, and data logger acquisition of up to 16 channels,
with programmable content and sampling rate. The internal clock used for time-tagging can be synchronized with an IRIG-
B signal, using the Simple Network Time Protocol (SNTP) over the Ethernet port, or using the Precision Time Protocol
(PTP). This precise time stamping allows the sequence of events to be determined throughout the system. Events can also
be programmed (via FlexLogic™ equations) to trigger oscillography data capture which may be set to record the measured
parameters before and after the event for viewing on a personal computer (PC). These tools significantly reduce trouble-
shooting time and simplify report generation in the event of a system fault.

Several options are available for communication. A faceplate RS232 port can be used to connect to a computer for the pro-
gramming of settings and the monitoring of actual values. The RS232 port has a fixed baud rate of 19.2 kbps. The rear
RS485 port allows independent access by operating and engineering staff. It can be connected to system computers with
baud rates up to 115.2 kbps. All serial ports use the Modbus RTU protocol. The 100Base-FX or 100Base-T Ethernet inter-
face provides fast, reliable communications in noisy environments. The Ethernet port supports IEC 61850, IEC 61850-90-5,
Modbus/TCP, and TFTP protocols, PTP (according to IEEE Std. 1588-2008 or IEC 61588), and allows access to the relay
via any standard web browser (G60 web pages). The IEC 60870-5-104 protocol is supported on the Ethernet port, and
DNP 3.0 and IEC 60870-5-104 cannot be enabled at the same time. The Ethernet port also supports the Parallel Redun-
dancy Protocol (PRP) of IEC 62439-3 (clause 4, 2012) when purchased as an option.

Settings and actual values can be accessed from the front panel or EnerVista software.

The G60 IEDs use flash memory technology which allows field upgrading as new features are added. The following

Single

line diagram

illustrates the relay functionality using ANSI (American National Standards Institute) device numbers.

Table 2–1: ANSI DEVICE NUMBERS AND FUNCTIONS

DEVICE

NUMBER

FUNCTION

DEVICE

NUMBER

FUNCTION

21P

Phase distance backup

51N

Neutral time overcurrent

24

Volts per hertz

59N

Neutral overvoltage

25

Synchrocheck

59P

Phase overvoltage

27P

Phase undervoltage

59X

Auxiliary overvoltage

27TN

Third harmonic neutral undervoltage

59_2

Negative-sequence overvoltage

27X

Auxiliary undervoltage

64F

Field ground protection

32

Sensitive directional power

64S

Sub-harmonic stator ground protection

40

Loss of excitation

64TN

100% stator ground

46

Generator unbalance

67_2

Negative-sequence directional overcurrent

49

Thermal overload protection (RTD)

67N

Neutral directional overcurrent

50BF

Breaker failure

67P

Phase directional overcurrent

50G

Ground instantaneous overcurrent

68

Power swing blocking

50N

Neutral instantaneous overcurrent

78

Out-of-step protection

50P

Phase instantaneous overcurrent

81O

Overfrequency

50SP

Split phase protection

81R

Rate of change of frequency

50/27

Accidental energization

81U

Underfrequency

51G

Ground time overcurrent

87RGF

Restricted ground fault

51PV

Phase time overcurrent with voltage

restraint

87S

Stator differential

«
...
31
32
33
34
35
...
»

Summary of Contents for Multilin g60

Page 1: ...al Energy 650 Markland Street Markham Ontario Canada L6C 0M1 Tel 1 905 927 7070 Fax 1 905 927 5098 Internet http www GEDigitalEnergy com IISO 9001 G N E I L M I U T L TE S I R G E E D R GE Multilin s Quality Management System is registered to ISO 9001 2008 QMI 005094 UL A3775 1601 0110 Z3 GE Digital Energy LISTED 52TL IND CONT EQ E83849 ...

Page 2: ... Digital Energy Multilin and GE Multilin are trademarks or registered trademarks 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 number ...

Page 3: ... 1 5 2 MENU NAVIGATION 1 19 1 5 3 MENU HIERARCHY 1 19 1 5 4 RELAY ACTIVATION 1 19 1 5 5 RELAY PASSWORDS 1 20 1 5 6 FLEXLOGIC CUSTOMIZATION 1 20 1 5 7 COMMISSIONING 1 21 2 PRODUCT DESCRIPTION 2 1 INTRODUCTION 2 1 1 OVERVIEW 2 1 2 1 2 SECURITY 2 3 2 1 3 ORDERING 2 7 2 1 4 REPLACEMENT MODULES 2 13 2 2 SPECIFICATIONS 2 2 1 PROTECTION ELEMENTS 2 15 2 2 2 USER PROGRAMMABLE ELEMENTS 2 20 2 2 3 MONITORING...

Page 4: ...NG FIRMWARE 3 65 4 HUMAN INTERFACES 4 1 ENERVISTA UR SETUP SOFTWARE INTERFACE 4 1 1 INTRODUCTION 4 1 4 1 2 CREATING A SITE LIST 4 1 4 1 3 ENERVISTA UR SETUP OVERVIEW 4 1 4 1 4 ENERVISTA UR SETUP MAIN WINDOW 4 3 4 2 EXTENDED ENERVISTA UR SETUP FEATURES 4 2 1 SETTINGS TEMPLATES 4 4 4 2 2 SECURING AND LOCKING FLEXLOGIC EQUATIONS 4 8 4 2 3 SETTINGS FILE TRACEABILITY 4 10 4 3 FACEPLATE INTERFACE 4 3 1 ...

Page 5: ... 5 6 2 SETTING GROUP 5 159 5 6 3 DISTANCE 5 160 5 6 4 POWER SWING DETECT 5 168 5 6 5 STATOR DIFFERENTIAL 5 176 5 6 6 PHASE CURRENT 5 179 5 6 7 NEUTRAL CURRENT 5 189 5 6 8 GROUND CURRENT 5 196 5 6 9 NEGATIVE SEQUENCE CURRENT 5 203 5 6 10 GENERATOR UNBALANCE 5 207 5 6 11 SPLIT PHASE PROTECTION 5 209 5 6 12 BREAKER FAILURE 5 214 5 6 13 VOLTAGE ELEMENTS 5 222 5 6 14 LOSS OF EXCITATION 5 233 5 6 15 ACC...

Page 6: ...CONTACT OUTPUTS 6 5 6 2 7 VIRTUAL OUTPUTS 6 6 6 2 8 REMOTE DEVICES 6 6 6 2 9 DIGITAL COUNTERS 6 7 6 2 10 SELECTOR SWITCHES 6 7 6 2 11 FLEX STATES 6 7 6 2 12 ETHERNET 6 7 6 2 13 REAL TIME CLOCK SYNCHRONIZING 6 8 6 2 14 DIRECT INPUTS 6 9 6 2 15 DIRECT DEVICES STATUS 6 9 6 2 16 IEC 61850 GOOSE INTEGERS 6 10 6 2 17 EGD PROTOCOL STATUS 6 10 6 2 18 TELEPROTECTION CHANNEL TESTS 6 11 6 2 19 REMAINING CONN...

Page 7: ...AGES 7 6 7 2 3 RELAY SELF TESTS 7 6 8 THEORY OF OPERATION 8 1 PHASE DISTANCE THROUGH POWER TRANSFORMERS 8 1 1 DESCRIPTION 8 1 8 1 2 EXAMPLE 8 4 9 APPLICATION OF SETTINGS 9 1 SETTING EXAMPLE 9 1 1 DESCRIPTION 9 1 9 1 2 SYSTEM SETUP 9 1 9 1 3 POWER SYSTEM 9 2 9 1 4 SIGNAL SOURCES 9 2 9 1 5 STATOR DIFFERENTIAL 9 3 9 1 6 GENERATOR UNBALANCE 9 3 9 1 7 LOSS OF EXCITATION 9 4 9 1 8 REVERSE POWER 9 4 9 1 ...

Page 8: ... VALUES OR SETTINGS FUNCTION CODE 03 04H B 4 B 2 3 EXECUTE OPERATION FUNCTION CODE 05H B 5 B 2 4 STORE SINGLE SETTING FUNCTION CODE 06H B 5 B 2 5 STORE MULTIPLE SETTINGS FUNCTION CODE 10H B 6 B 2 6 EXCEPTION RESPONSES B 6 B 3 FILE TRANSFERS B 3 1 OBTAINING RELAY FILES VIA MODBUS B 7 B 4 MEMORY MAPPING B 4 1 MODBUS MEMORY MAP B 9 B 4 2 DATA FORMATS B 77 C IEC 61850 COMMUNICATIONS C 1 OVERVIEW C 1 1...

Page 9: ...S C 18 C 5 6 IMPORTING AN SCD FILE WITH ENERVISTA UR SETUP C 21 C 6 ACSI CONFORMANCE C 6 1 ACSI BASIC CONFORMANCE STATEMENT C 23 C 6 2 ACSI MODELS CONFORMANCE STATEMENT C 23 C 6 3 ACSI SERVICES CONFORMANCE STATEMENT C 24 C 7 LOGICAL NODES C 7 1 LOGICAL NODES TABLE C 27 D IEC 60870 5 104 COMMUNICATIONS D 1 IEC 60870 5 104 D 1 1 INTEROPERABILITY DOCUMENT D 1 D 1 2 IEC 60870 5 104 POINT LIST D 9 E DN...

Page 10: ...x G60 Generator Protection System GE Multilin TABLE OF CONTENTS INDEX ...

Page 11: ...imits Only qualified personnel are to operate the device Such personnel must be thoroughly familiar with all safety cau tions and warnings in this manual and with applicable country regional utility and plant safety regulations Hazardous voltages can exist in the power supply and at the device connection to current transformers voltage transformers control and test circuit terminals Make sure all ...

Page 12: ...NTER FOR PRODUCT SUPPORT GE Digital Energy 650 Markland Street Markham Ontario Canada L6C 0M1 TELEPHONE Worldwide 1 905 927 7070 Europe Middle East Africa 34 94 485 88 54 North America toll free 1 800 547 8629 FAX 1 905 927 5098 E MAIL Worldwide multilin tech ge com Europe multilin tech euro ge com HOME PAGE http www gedigitalenergy com multilin For updates to the instruction manual firmware and s...

Page 13: ...ES The contact inputs and outputs are digital signals associated with connections to hard wired contacts Both wet and dry contacts are supported The virtual inputs and outputs are digital signals associated with UR series internal logic signals Virtual inputs include signals generated by the local user interface The virtual outputs are outputs of FlexLogic equations used to customize the device Vi...

Page 14: ...ended for pilot aided schemes distributed logic applications or the extension of the input output capabilities of a single relay chassis c UR SCAN OPERATION The UR series devices operate in a cyclic scan fashion The device reads the inputs into an input status table solves the logic program FlexLogic equation and then sets each output to the appropriate state in an output status table Any result i...

Page 15: ...n the system Employing OOD OOP in the software architecture of the G60 achieves the same features as the hardware architecture modularity scalability and flexibility The application software for any UR series device for example feeder protection transformer protection distance protection is constructed by combining objects from the various functional classes This results in a common interface acro...

Page 16: ...the EnerVista UR Setup software US Robotics external 56K FaxModem 5686 US Robotics external Sportster 56K X2 PCTEL 2304WT V 92 MDC internal modem 1 3 2 INSTALLATION After ensuring that the requirements for using EnerVista UR Setup are met previous section install the EnerVista UR Setup software from the GE EnerVista DVD Or download the UR EnerVista software from http www gedigitalenergy com multil...

Page 17: ...ion The UR device is added to the list of installed intelligent electronic devices IEDs in the EnerVista Launchpad window as shown Figure 1 6 UR DEVICE ADDED TO LAUNCHPAD WINDOW 1 3 3 CONFIGURING THE G60 FOR SOFTWARE ACCESS a OVERVIEW You connect remotely to the G60 through the rear RS485 or Ethernet port with a computer running the EnerVista UR Setup software The G60 can also be accessed locally ...

Page 18: ...tton then select the new site to re open the Device Setup window 6 Click the Add Device button to define the new device 7 Enter a name in the Device Name field and a description optional of the site 8 Select Serial from the Interface drop down list This displays a number of interface parameters that must be entered for serial communications Figure 1 7 CONFIGURING SERIAL COMMUNICATIONS 9 Enter the ...

Page 19: ...etup window 16 Click the Add Device button to define the new device 17 Enter the desired name in the Device Name field and a description optional of the site 18 Select Ethernet from the Interface drop down list This displays a number of interface parameters that must be entered for proper Ethernet functionality Figure 1 8 CONFIGURING ETHERNET COMMUNICATIONS 19 Enter the relay IP address specified ...

Page 20: ...d click the Quick Connect button to establish direct communi cations to the G60 device This ensures that configuration of the EnerVista UR Setup software matches the G60 model number b USING QUICK CONNECT VIA THE REAR ETHERNET PORTS To use the Quick Connect feature to access the G60 from a computer through Ethernet first assign an IP address to the relay from the front panel keyboard 1 Press the M...

Page 21: ...ndows desktop right click the My Network Places icon and select Properties to open the network con nections window 2 Right click the Local Area Connection icon and select Properties 3 Select the Internet Protocol TCP IP item from the list and click the Properties button 4 Click the Use the following IP address box ...

Page 22: ...time and TTL vary depending on local network configuration 5 If the following sequence of messages appears when entering the C WINNT ping 1 1 1 1 command Pinging 1 1 1 1 with 32 bytes of data Request timed out Request timed out Request timed out Request timed out Ping statistics for 1 1 1 1 Packets Sent 4 Received 0 Lost 4 100 loss Approximate round trip time in milliseconds Minimum 0ms Maximum 0m...

Page 23: ...nection specific DNS suffix IP Address 0 0 0 0 Subnet Mask 0 0 0 0 Default Gateway Ethernet adapter Local Area Connection Connection specific DNS suffix IP Address 1 1 1 2 Subnet Mask 255 0 0 0 Default Gateway C WINNT Before using the Quick Connect feature through the Ethernet port disable any configured proxy settings in Internet Explorer 1 Start the Internet Explorer software 2 Select the Tools ...

Page 24: ...the Windows desktop right click the My Network Places icon and select Properties to open the network con nections window 2 Right click the Local Area Connection icon and select the Properties item 3 Select the Internet Protocol TCP IP item from the list provided and click the Properties button 4 Set the computer to Obtain a relay address automatically as shown If this computer is used to connect t...

Page 25: ...e green status indicator 3 The Display Properties settings can now be edited printed or changed See chapter 4 in this manual or the EnerVista UR Setup Help File for information about the using the EnerVista UR Setup software interface QUICK ACTION HOT LINKS The EnerVista UR Setup software has several quick action buttons to provide instant access to several functions that are often performed when ...

Page 26: ...hentication can be chosen on the login screen but the choice is available only in EnerVista Use device authentication to log in using the five pre configured roles Administrator Supervisor Engineer Operator Observer When using a serial connection only device authentication is supported When server authentication is required characteristics for communication with a RADIUS server must be configured ...

Page 27: ...ing EnerVista navigate to Settings Product Setup Security Change the Local Administrator Password for example It is strongly recommended that the password for the Administrator be changed from the default Changing the passwords for the other three roles is optional Figure 1 11 CHANGING THE DEFAULT PASSWORD ...

Page 28: ...omputer using a straight through serial cable A shielded twisted pair 20 22 or 24 AWG connects the F485 converter to the G60 rear communications port The converter terminals GND are connected to the G60 communication module COM terminals See the CPU communica tions ports section in chapter 3 for details The line is terminated with an R C network that is 120 Ω 1 nF as described in the chapter 3 1 4...

Page 29: ... actual value messages are arranged hierarchically The header display pages are indicated by double scroll bar characters while sub header pages are indicated by single scroll bar characters The header display pages represent the highest level of the hierarchy and the sub header display pages fall below this level The MESSAGE UP and DOWN keys move within a group of headers sub headers setting valu...

Page 30: ...rtual inputs Clear event records Clear oscillography records Operate user programmable pushbuttons 2 SETTING The SETTING access level allows the user to make any changes to any of the setting values See the Changing Settings section in Chapter 4 for complete instructions on setting security level passwords b CYBERSENTRY When the CyberSentry option is purchased advanced security services are availa...

Page 31: ...onding system 2 Visual verification of active alarms relay display messages and LED indications 3 LED test 4 Visual inspection for any damage corrosion dust or loose wires 5 Event recorder file download with further events analysis Out of service maintenance 1 Check wiring connections for firmness 2 Analog values currents voltages RTDs analog inputs injection test and metering accuracy verificatio...

Page 32: ...1 22 G60 Generator Protection System GE Multilin 1 5 USING THE RELAY 1 GETTING STARTED 1 ...

Page 33: ...stem computers with baud rates up to 115 2 kbps All serial ports use the Modbus RTU protocol The 100Base FX or 100Base T Ethernet inter face provides fast reliable communications in noisy environments The Ethernet port supports IEC 61850 IEC 61850 90 5 Modbus TCP and TFTP protocols PTP according to IEEE Std 1588 2008 or IEC 61588 and allows access to the relay via any standard web browser G60 web ...

Page 34: ...definable displays CyberSentry security Modbus communications User programmable fault reports Data logger Modbus user map User programmable LEDs Digital counters 8 Non volatile latches User programmable pushbuttons Digital elements 48 Non volatile selector switch User programmable self tests Direct inputs and outputs 32 RTD protection Virtual inputs 64 Disconnect switches Remote RTD protection Vir...

Page 35: ...b PASSWORD SECURITY Password security is a basic security feature present in the default offering of the product Two levels of password security are provided command and setting The following operations are under command password supervision Changing the state of virtual inputs Clearing the event records Clearing the oscillography records Changing the date and time Clearing energy records Clearing...

Page 36: ...e 2 2 CYBERSENTRY USER ROLES There are two types of authentication supported by CyberSentry that can be used to access the UR device Device Authentication local UR device authenticates Server Authentication RADIUS server authenticates The EnerVista software allows access to functionality that is determined by the user role which comes either from the local UR device or RADIUS server The EnerVista ...

Page 37: ...raphy RW RW R R R Data Logger RW RW R R R Demand RW RW R R R User Programmable LEDs RW RW R R R User Programmable self test RW RW R R R Control Pushbuttons RW RW R R R User programmable Pushbuttons RW RW R R R Flex states RW RW R R R User definable dis plays RW RW R R R Direct I O RW RW R R R Tele protection RW RW R R R Installation RW RW R R R System Setup RW RW R R R FlexLogic RW RW R R R Groupe...

Page 38: ...C61850 GOOSE Integers RW RW R R R Transducer I O RW RW R R R Testing RW RW R R R Front Panel Labels Designer NA NA NA NA NA Protection Summary NA NA NA NA NA Commands RW RW RW R R Virtual Inputs RW RW RW R R Clear Records RW RW RW R R Set date and time RW RW RW R R User Displays R R R R R Targets R R R R R Actual Values R R R R R Front Panel Labels Designer R R R R R Status R R R R R Metereing R R...

Page 39: ...P with LC U RS485 and Two Multi mode fiber 100Base FX SFP with LC One 10 100Base T SFP with RJ45 V RS485 and Three 10 100Base T SFP with RJ45 SOFTWARE 00 No Software Options 01 Ethernet Global Data EGD 03 IEC 61850 04 Ethernet Global Data EGD and IEC 61850 06 Phasor measurement unit PMU 07 IEC 61850 and phasor measurement unit PMU A0 CyberSentry Lvl 1 A1 CyberSentry Lvl 1 and Ethernet Global Data ...

Page 40: ...al inputs 6S 6S 6S 6S 6S 2 Form A no monitoring and 4 Form C outputs 4 digital inputs 6T 6T 6T 6T 6T 4 Form A no monitoring outputs 8 digital inputs 6U 6U 6U 6U 6U 6 Form A no monitoring outputs 4 digital inputs 6V 6V 6V 6V 6V 2 Form A outputs 1 Form C output 2 Form A no monitoring latching outputs 8 digital inputs TRANSDUCER INPUTS OUTPUTS select a maximum of 3 per unit 5A 5A 5A 5A 5A 4 DCmA inpu...

Page 41: ... 2 Form C outputs 8 digital inputs 6B 6B 6B 2 Form A voltage with optional current and 4 Form C outputs 4 digital inputs 6C 6C 6C 8 Form C outputs 6D 6D 6D 16 digital inputs 6E 6E 6E 4 Form C outputs 8 digital inputs 6F 6F 6F 8 Fast Form C outputs 6G 6G 6G 4 Form A voltage with optional current outputs 8 digital inputs 6H 6H 6H 6 Form A voltage with optional current outputs 4 digital inputs 6K 6K ...

Page 42: ...t unit PMU D7 IEEE 1588 and CyberSentry Lvl 1 and IEC 61850 and phasor measurement unit PMU E0 IEEE 1588 and PRP E1 IEEE 1588 PRP and Ethernet Global Dada E3 IEEE 1588 PRP and IEC 61850 E4 IEEE 1588 PRP Ethernet Global Data and IEC 61850 E6 IEEE 1588 PRP and PMU E7 IEEE 1588 PRP IEC 61850 and PMU F0 PRP and CyberSentry Lvl1 F1 PRP CyberSentry Lvl1 and Ethernet Global Data F3 PRP CyberSentry Lvl 1 ...

Page 43: ... Channel 1 G 703 Channel 2 1300 nm single mode ELED 7H 820 nm multi mode LED 2 Channels 7I 1300 nm multi mode LED 2 Channels 7J 1300 nm single mode ELED 2 Channels 7K 1300 nm single mode LASER 2 Channels 7L Channel 1 RS422 Channel 2 820 nm multi mode LED 7M Channel 1 RS422 Channel 2 1300 nm multi mode LED 7N Channel 1 RS422 Channel 2 1300 nm single mode ELED 7P Channel 1 RS422 Channel 2 1300 nm si...

Page 44: ...orm A current with optional voltage outputs 8 digital inputs 6P 6 Form A current with optional voltage outputs 4 digital inputs 6R 2 Form A no monitoring and 2 Form C outputs 8 digital inputs 6S 2 Form A no monitoring and 4 Form C outputs 4 digital inputs 6T 4 Form A no monitoring outputs 8 digital inputs 6U 6 Form A no monitoring outputs 4 digital inputs 6V 2 Form A outputs 1 Form C output 2 Form...

Page 45: ...puts 6B 2 Form A voltage with optional current and 4 Form C outputs 4 contact inputs 6C 8 Form C outputs 6D 16 contact inputs 6E 4 Form C outputs 8 contact inputs 6F 8 Fast Form C outputs 6G 4 Form A voltage with optional current outputs 8 contact inputs 6H 6 Form A voltage with optional current outputs 4 contact inputs 6K 4 Form C and 4 Fast Form C outputs 6L 2 Form A current with optional voltag...

Page 46: ...rm A current with optional voltage and 4 Form C outputs 4 contact inputs 6N 4 Form A current with optional voltage outputs 8 contact inputs 6P 6 Form A current with optional voltage outputs 4 contact inputs 6R 2 Form A no monitoring and 2 Form C outputs 8 contact inputs 6S 2 Form A no monitoring and 4 Form C outputs 4 contact inputs 6T 4 Form A no monitoring outputs 8 contact inputs 6U 6 Form A no...

Page 47: ...ver is greater Current supervision Level line to line current Pickup 0 050 to 30 000 pu in steps of 0 001 Dropout 97 to 98 Memory duration 5 to 25 cycles in steps of 1 VT location all delta wye and wye delta transformers CT location all delta wye and wye delta transformers Voltage supervision pickup series compensation applications 0 to 5 000 pu in steps of 0 001 Operation time 1 to 1 5 cycles typ...

Page 48: ...isting forward and reverse Polarizing Voltage Polarizing voltage V_2 Operating current I_2 Level sensing Zero sequence I_0 K I_1 Negative sequence I_2 K I_1 Restraint K 0 000 to 0 500 in steps of 0 001 Characteristic angle 0 to 90 in steps of 1 Limit angle 40 to 90 in steps of 1 independent for forward and reverse Angle accuracy 2 Offset impedance 0 00 to 250 00 Ω in steps of 0 01 Pickup level 0 0...

Page 49: ...kup level 0 000 to 3 000 pu in steps of 0 001 Dropout level 97 to 98 of pickup Level accuracy 0 5 of reading from 10 to 208 V Pickup delay 0 00 to 600 00 s in steps of 0 01 definite time or user defined curve Reset delay 0 00 to 600 00 s in steps of 0 01 Curve timing accuracy at 1 1 x pickup 3 5 of operate time or 1 cycle whichever is greater from pickup to operate Operate time 30 ms at 1 10 picku...

Page 50: ... 03 Hz Level accuracy 0 001 Hz Time delay 0 to 65 535 s in steps of 0 001 Timer accuracy 3 of operate time or 1 4 cycle whichever is greater Operate time typically 4 cycles at 0 1 Hz s change typically 3 5 cycles at 0 3 Hz s change typically 3 cycles at 0 5 Hz s change Typical times are average operate times including variables such as frequency change instance test method etc and may vary by 0 5 ...

Page 51: ...to 90 in steps of 1 Angle accuracy 2 Characteristic limit angles 40 to 140 in steps of 1 Timers 0 000 to 65 535 s in steps of 0 001 Timer accuracy 3 of operate time or 1 4 cycle whichever is greater ACCIDENTAL ENERGIZATION Operating condition Overcurrent Arming condition Undervoltage and or Machine Offline Overcurrent Pickup level 0 000 to 3 000 pu in steps of 0 001 Dropout level 97 to 98 of picku...

Page 52: ...tion control and FlexLogic USER PROGRAMMABLE LEDs Number 48 plus trip and alarm Programmability from any logical variable contact or vir tual input Reset mode self reset or latched LED TEST Initiation from any contact input or user program mable condition Number of tests 3 interruptible at any time Duration of full test approximately 3 minutes Test sequence 1 all LEDs on Test sequence 2 all LEDs o...

Page 53: ...E C37 118 or IEC 61850 90 5 standard Number of channels 14 synchrophasors 8 analogs 16 digi tals TVE total vector error 1 Triggering frequency voltage current power rate of change of frequency user defined Reporting rate 1 2 5 10 12 15 20 25 30 50 or 60 times per second for P and M class and 100 or 120 times per second for P class only Number of clients One over TCP IP port and one over UDP IP per...

Page 54: ...T rating RMS symmetrical Sensitive Ground CT module 0 002 to 4 6 CT rating RMS symmetrical Current withstand 20 ms at 250 times rated 1 sec at 100 times rated continuous 4xInom Short circuit rating 150000 RMS sym metrical amperes 250 V maximum pri mary current to external CT AC VOLTAGE VT rated secondary 50 0 to 240 0 V VT ratio 1 00 to 24000 00Relay burden 0 25 VA at 120 V Conversion range 1 to 2...

Page 55: ... 1 to 1000 in steps of 1 Unreturned message alarm Responding to Rate of unreturned messages in the ring configuration Monitoring message count 10 to 10000 in steps of 1 Alarm threshold 1 to 1000 in steps of 1 TELEPROTECTION Input points 16 Remote devices 3 Default states on loss of comms On Off Latest Off Latest On Ring configuration No Data rate 64 or 128 kbps CRC 32 bit 2 2 6 POWER SUPPLY LOW RA...

Page 56: ... s 300 A Breaking capacity CONTROL POWER EXTERNAL OUTPUT FOR DRY CONTACT INPUT Capacity 100 mA DC at 48 V DC Isolation 300 Vpk REMOTE OUTPUTS IEC 61850 GSSE GOOSE Standard output points 32 User output points 32 DIRECT OUTPUTS Output points 32 DCMA OUTPUTS Range 1 to 1 mA 0 to 1 mA 4 to 20 mA Max load resistance 12 kΩ for 1 to 1 mA range 12 kΩ for 0 to 1 mA range 600 Ω for 4 to 20 mA range Accuracy...

Page 57: ...240V AC at 50 60Hz and 10 VA 125 to 250V DC at 10W GPM F HM 100 to 240V AC at 50 60Hz and 10 VA 125 to 250V DC at 10W GPM S G MODULE CONTACT INPUTS Internal wetting 24 V DC Input comparator threshold 6 V DC External contact dry Current when energized 10 mA Debounce time 10 ms GPM S G MODULE POWER SUPPLY Power supply 100 to 240 V AC at 50 60 Hz and 110VA 125 to 250 V DC at 110W Output ratings 26 V ...

Page 58: ...errupts Radiated and conducted emissions CISPR11 CISPR22 IEC60255 25 Class A Class A Sinusoidal vibration IEC60255 21 1 Class 2 Class 1 Shock and Bump IEC60255 21 2 Class 2 Class 1 Seismic IEC60255 21 3 Class 2 Class 1 Power magnetic immunity IEC61000 4 8 Level 5 Level 5 Pulse magnetic immunity IEC61000 4 9 Level 4 Level 4 Damped magnetic immunity IEC61000 4 10 Level 4 Level 4 Voltage dip and inte...

Page 59: ...wer budgets are calculated from the manu facturer s worst case transmitter power and worst case receiver sensitivity The power budgets for the 1300 nm ELED are calcu lated from the manufacturer s transmitter power and receiver sensitivity at ambient temperature At extreme temperatures these values deviate based on component tolerance On average the output power decreases as the temperature is incr...

Page 60: ...TTER TYPE CABLE TYPE CONNECTOR TYPE TYPICAL DISTANCE 820 nm LED multimode 62 5 125 μm ST 1 65 km 50 125 μm ST 1 65 km 1300 nm LED multimode 62 5 125 μm ST 4 km 50 125 μm ST 4 km 1300 nm ELED single mode 9 125 μm ST 11 4 km 1300 nm Laser single mode 9 125 μm ST 64 km 1550 nm Laser single mode 9 125 μm ST 105 km Typical distances listed are based on the follow ing assumptions for system loss As actu...

Page 61: ...ple DC IEC 60255 11 12 ripple 200 ms interrupts Radiated and conducted emissions CISPR11 CISPR22 IEC 60255 25 Class A Sinusoidal vibration IEC 60255 21 1 Class 1 Shock and bump IEC 60255 21 2 Class 1 Seismic IEC 60255 21 3 Class 1 Power magnetic immunity IEC 61000 4 8 Level 5 Pulse magnetic immunity IEC 61000 4 9 Level 4 Damped magnetic immunity IEC 61000 4 10 Level 4 Voltage dip and interruption ...

Page 62: ...as accumulated on the faceplate display a dry cloth can be used To avoid deterioration of electrolytic capacitors power up units that are stored in a de energized state once per year for one hour continuously COMPLIANCE APPLICABLE COUNCIL DIRECTIVE ACCORDING TO CE Low voltage directive EN 60255 5 EMC directive EN 60255 26 EN 50263 EN 61000 6 5 C UL US UL 508 UL 1053 C22 2 No 14 EAC Machines and Eq...

Page 63: ...the removable modules and is itself removable to allow mounting on doors with limited rear depth The case dimensions are shown below along with panel cutout details for panel mounting When planning the location of your panel cutout ensure that provision is made for the faceplate to swing open without interference to or from adjacent equipment The relay must be mounted such that the faceplate sits ...

Page 64: ...ng When planning the location of your panel cutout ensure that provision is made for the faceplate to swing open without interference to or from adjacent equipment The relay must be mounted such that the faceplate sits semi flush with the panel or switchgear door allowing the operator access to the keypad and the RS232 communications port The relay is secured to the panel with the use of four scre...

Page 65: ...8 243 4 mm 7 00 177 7 mm 4 00 101 6 mm 7 10 180 2 mm 13 66 347 0 mm 14 03 356 2 mm 0 20 5 1 mm 1 55 39 3 mm 4 Places 0 213 5 41 mm Front of Panel Mounting Bracket Vertical Enhanced Front View Vertical Enhanced Top View Vertical Enhanced Mounting Panel CUTOUT Front of Panel Reference only Terminal Blocks Front Bezel Front of Panel Mounting Bracket Vertical Enhanced Side View 843809A2 cdr ...

Page 66: ...UR Device Instruction Sheet GEK 113182 Connecting a Remote UR V Enhanced Front Panel to a Vertically Mounted Horizontal UR Device Instruction Sheet For side mounting G60 devices with the standard front panel use the following figures 13 72 348 5 mm 7 00 177 8 mm 13 50 342 9 mm Front of panel Front bezel Panel Mounting bracket 1 57 39 9 mm 4 00 101 6 7 13 181 1 mm 0 46 11 7 mm 13 65 346 7 mm 14 40 ...

Page 67: ...GE Multilin G60 Generator Protection System 3 5 3 HARDWARE 3 1 DESCRIPTION 3 Figure 3 6 G60 VERTICAL SIDE MOUNTING INSTALLATION STANDARD PANEL ...

Page 68: ...ay is energized The relay being modular in design allows for the withdrawal and insertion of modules Modules must only be replaced with like modules in their original factory configured slots The enhanced faceplate can be opened to the left once the thumb screw has been removed as shown below This allows for easy accessibility of the modules for withdrawal The new wide angle hinge assembly in the ...

Page 69: ...ot Modules with current input provide automatic shorting of external CT circuits To properly insert a module ensure that the correct module type is inserted into the correct slot position The ejector inserter clips located at the top and at the bottom of each module must be in the disengaged position as the module is smoothly inserted into the slot Once the clips have cleared the raised edge of th...

Page 70: ...ing figure for an example of rear terminal assignments Figure 3 11 EXAMPLE OF MODULES IN F AND H SLOTS X W V U T S P N M L K J H D G F B R 8 4 7 3 6 2 5 1 b 8 4 7 3 6 2 5 1 a a b c a b c a b c a b c Optional direct input output module CPU module T module shown Optional contact input output module CT VT module Power supply module Tx1 Tx2 Rx1 Rx2 Tx1 Tx2 830767A3 CDR Optional CT VT or contact input ...

Page 71: ... 48 V DC OUTPUT CONTROL POWER HI LO POWER SUPPLY 1 FILTER SURGE B3a B1b B8a B6b B8b B6a B3b B1a B2b B5b AC or DC DC F1c F4a F8c F8a F3c F5a F5c F7c CURRENT INPUTS F6a F7a F6c F2c VX VA VB VC F4c F1a F4b F1b F2a F3a F2b F3b VOLTAGE INPUTS 8F 8G VX VA VB VC IA IB IC IG IA5 IA1 IB5 IC5 IG5 IB1 IC1 IG1 TYPICAL CONFIGURATION THE AC SIGNAL PATH IS CONFIGURABLE POSITIVE WATTS M3c M4c M4b M4a M1c M1a M1b ...

Page 72: ...3 10 G60 Generator Protection System GE Multilin 3 2 WIRING 3 HARDWARE 3 Figure 3 13 TYPICAL WIRING WITH GPM F AND GPM S MODULES T MODULE SHOWN FOR CPU T 859707A2 cdr ...

Page 73: ...ies power for dry contact input connections The power supply module provides 48 V DC power for dry contact input connections and a critical failure relay see the Typical wiring diagram earlier The critical failure relay is a form C device that is energized once control power is applied and the relay has successfully booted up with no critical self test failures If on going self test diagnostic che...

Page 74: ...nd current input that is the same as the phase current input Each AC current input has an isolating transformer and an automatic shorting mechanism that shorts the input when the module is withdrawn from the chassis There are no internal ground connections on the current inputs Current transformers with 1 to 50000 A primaries and 1 A or 5 A secondaries can be used CT VT modules with a sensitive gr...

Page 75: ...ound connection to neutral must be on the source side UNSHIELDED CABLE LOAD A B C N G Ground outside CT Source LOAD SHIELDED CABLE 996630A6 CDR A B C Source To ground must be on load side Stress cone shields NOTE 1a 1b 1c 2a 2b 2c 3a 4a 5a 6a 7a 8a 3b 4b 5c 6c 7c 8c 3c 4c Current inputs 8F 8G 8L and 8M modules 4 CTs and 4 VTs Voltage inputs VA VB VC VX VA VB VC VX IA IC IB IG IA5 IC5 IB5 IG5 IA1 I...

Page 76: ...nputs per common return When a contact input output module is ordered four inputs per common is used If the inputs must be isolated per row then two inputs per common return should be selected 4D module The tables and diagrams on the following pages illustrate the module types 6A etc and contact arrangements that can be ordered for the relay Since an entire row is used for a single contact output ...

Page 77: ...ay con tinue to read the form A contact as being closed after it has closed and subsequently opened when measured as an impedance The solution is to use the voltage measuring trigger input of the relay test set and connect the form A contact through a voltage dropping resistor to a DC voltage source If the 48 V DC output of the power supply is used as a source a 500 Ω 10 W resistor is appropriate ...

Page 78: ... 6a 6c 2 Inputs 6 Fast Form C 6a 6c 2 Inputs 6 Form A 7a 7c 2 Inputs 7 Fast Form C 7a 7c 2 Inputs 7a 7c 2 Inputs 8a 8c 2 Inputs 8 Fast Form C 8a 8c 2 Inputs 8a 8c 2 Inputs 6K MODULE 6L MODULE 6M MODULE 6N MODULE TERMINAL ASSIGNMENT OUTPUT TERMINAL ASSIGNMENT OUTPUT OR INPUT TERMINAL ASSIGNMENT OUTPUT OR INPUT TERMINAL ASSIGNMENT OUTPUT OR INPUT 1 Form C 1 Form A 1 Form A 1 Form A 2 Form C 2 Form A...

Page 79: ...6 Solid State 7a 7c 2 Inputs 7a 7c 2 Inputs 7 Form A 7 Not Used 8a 8c 2 Inputs 8a 8c 2 Inputs 8 Form A 8 Solid State 4B MODULE 4C MODULE 4D MODULE 4L MODULE TERMINAL ASSIGNMENT OUTPUT TERMINAL ASSIGNMENT OUTPUT TERMINAL ASSIGNMENT OUTPUT TERMINAL ASSIGNMENT OUTPUT 1 Not Used 1 Not Used 1a 1c 2 Inputs 1 2 Outputs 2 Solid State 2 Solid State 2a 2c 2 Inputs 2 2 Outputs 3 Not Used 3 Not Used 3a 3c 2 I...

Page 80: ...3 18 G60 Generator Protection System GE Multilin 3 2 WIRING 3 HARDWARE 3 Figure 3 18 CONTACT INPUT AND OUTPUT MODULE WIRING 1 of 2 842762A3 CDR ...

Page 81: ...N 8c COMMON 7b SURGE 8c 7c 8b I V I V I V I V DIGITAL I O 6N 1b 2b 3b 4b 6c 1a 2a 3a 4a 5a 6a 1c 2c 3c 4c 5c 5b 1 2 3 4 8a 7b 7a CONTACT IN 7a CONTACT IN 5a CONTACT IN 7c CONTACT IN 5c CONTACT IN 8a CONTACT IN 6a CONTACT IN 8c CONTACT IN 6c COMMON 7b COMMON 5b SURGE 8c 7c 8b DIGITAL I O 6T 1b 2b 3b 4b 6c 1a 2a 3a 4a 5a 6a 1c 2c 3c 4c 5c 5b 1 2 3 4 8a 7b 7a CONTACT IN 7a CONTACT IN 5a CONTACT IN 7c...

Page 82: ...aximum external source voltage for this arrangement is 300 V DC The voltage threshold at which each group of four contact inputs detects a closed contact input is programmable as 17 V DC for 24 V sources 33 V DC for 48 V sources 84 V DC for 110 to 125 V sources and 166 V DC for 250 V sources Figure 3 20 DRY AND WET CONTACT INPUT CONNECTIONS Wherever a tilde symbol appears substitute with the slot ...

Page 83: ...to burnishing allow currents up to 50 to 70 mA at the first instance when the change of state was sensed Then within 25 to 50 ms this current is slowly reduced to 3 mA as indicated above The 50 to 70 mA peak current burns any film on the con tacts allowing for proper sensing of state changes If the external device contact is bouncing the auto burnishing starts when external device contact bouncing...

Page 84: ...tor Protection System GE Multilin 3 2 WIRING 3 HARDWARE 3 The auto burnish circuitry has an internal fuse for safety purposes During regular maintenance check the auto burnish functionality using an oscilloscope NOTE ...

Page 85: ...rranged as three ter minals per row with a total of eight rows A given row can be used for either inputs or outputs with terminals in column a having positive polarity and terminals in column c having negative polarity Since an entire row is used for a single input output channel the name of the channel is assigned using the module slot position and row number Each module also requires that a conn...

Page 86: ... RTD CONNECTIONS Three wire shielded cable RTD terminals Maximum total lead resistance 25 ohms for Platinum RTDs Route cable in separate conduit from current carrying conductors RTD 859736A1 CDR RTD terminals RTD RTD For RTD RTD SURGE 1 1 2 2 8b 1a 1b 2a Hot Hot Return Comp Comp 2c 1c ...

Page 87: ...unning the EnerVista UR Setup software provided with the relay Cabling for the RS232 port is shown in the following figure for both 9 pin and 25 pin connectors The baud rate for this port is fixed at 19200 bps Figure 3 25 RS232 FACEPLATE PORT CONNECTION 3 2 9 CPU COMMUNICATION PORTS a OVERVIEW In addition to the faceplate RS232 port the G60 provides a rear RS485 communication port The CPU modules ...

Page 88: ...but insulated from the shield To avoid loop currents ground the shield at only one point If other system considerations require the shield to be grounded at more than one point install resistors typically 100 ohms between the shield and ground at each grounding point Each relay needs to be daisy chained to the next one in the link A maximum of 32 relays can be connected in this manner with out exc...

Page 89: ...7 RS485 SERIAL CONNECTION c 100BASE FX FIBER OPTIC PORTS Ensure that the dust covers are installed when the fiber is not in use Dirty or scratched connectors can lead to high losses on a fiber link The fiber optic communication ports allow for fast and efficient communications between relays at 100 Mbps Optical fiber can be connected to the relay supporting a wavelength of 1310 nm in multi mode SC...

Page 90: ... CONNECTION Using an amplitude modulated receiver causes errors up to 1 ms in event time stamping When IRIG B is used as the time synchronization source for synchrophasors the DC level shifted option must be used in order to achieve the 1 Total Vector Error specified by the standard If amplitude modulated IRIG B is used it results in a 20 to 25 degree error in the synchrophasor angle measurement T...

Page 91: ...TION The interconnection for dual channel type 7 communications modules is shown as follows Two channel modules allow for a redundant ring configuration That is two rings can be created to provide an additional independent data path The required connections are UR1 Tx1 to UR2 Rx1 UR2 Tx1 to UR3 Rx1 UR3 Tx1 to UR4 Rx1 and UR4 Tx1 to UR1 Rx1 for the first ring and UR1 Tx2 to UR4 Rx2 UR4 Tx2 to UR3 R...

Page 92: ...nel 2H IEEE C37 94 820 nm 128 kbps multi mode LED 2 channels 72 1550 nm single mode laser 1 channel 73 1550 nm single mode laser 2 channels 74 Channel 1 RS422 channel 2 1550 nm single mode laser 75 Channel 1 G 703 channel 2 1550 nm single mode laser 76 IEEE C37 94 820 nm 64 kbps multi mode LED 1 channel 77 IEEE C37 94 820 nm 64 kbps multi mode LED 2 channels 7A 820 nm multi mode LED 1 channel 7B 1...

Page 93: ... 72 73 7D and 7K fiber laser module Figure 3 33 LASER FIBER MODULES Observing any fiber transmitter output can injure the eye 7Q Channel 1 G 703 channel 2 1300 nm single mode laser 7R G 703 1 channel 7S G 703 2 channels 7T RS422 1 channel 7V RS422 2 channels 2 clock inputs 7W RS422 2 channels Table 3 3 CHANNEL COMMUNICATION OPTIONS Sheet 2 of 2 MODULE SPECIFICATION 7A 7B and 7C modules 7H 7I and 7...

Page 94: ...n System GE Multilin 3 3 DIRECT INPUT AND OUTPUT COMMUNICATIONS MODULES 3 HARDWARE 3 When using a laser Interface attenuators can be necessary to ensure that you do not exceed the maximum optical input power to the receiver NOTICE ...

Page 95: ...ONNECTION BETWEEN TWO G 703 INTERFACES Pin nomenclature can differ from one manufacturer to another Therefore it is not uncommon to see pinouts num bered TxA TxB RxA and RxB In such cases it can be assumed that A is equivalent to and B is equivalent to b G 703 SELECTION SWITCH PROCEDURES 1 With the power to the relay off remove the G 703 module 7R or 7S as follows Record the original location of t...

Page 96: ...ing is disabled OFF d G 703 TIMING MODES There are two timing modes for the G 703 module internal timing mode and loop timing mode default Internal Timing Mode The system clock is generated internally Therefore the G 703 timing selection should be in the internal timing mode for back to back UR to UR connections For back to back connections set for octet timing S1 OFF and timing mode to internal t...

Page 97: ...nterface Figure 3 37 G 703 MINIMUM REMOTE LOOPBACK MODE In dual loopback mode the multiplexers are active and the functions of the circuit are divided into two with each receiver transmitter pair linked together to deconstruct and then reconstruct their respective signals Differential Manchester data enters the Differential Manchester receiver module and then is returned to the differential Manche...

Page 98: ...s one clock input for the two RS422 channels The system functions correctly when the following connections are observed and your data module has a terminal timing feature Terminal timing is a common fea ture to most synchronous data units that allows the module to accept timing from an external source Using the terminal timing feature two channel applications can be achieved if these connections a...

Page 99: ... ensure proper system operation For example the following figure shows the positive edge of the Tx clock in the center of the Tx data bit Figure 3 42 CLOCK AND DATA TRANSITIONS Data module 1 Data module 2 Signal name Signal name SD A Send data TT A Terminal timing TT B Terminal timing SD B Send data RD A Received data RD A Received data SD A Send data SD B Send data RD B Received data RD B Receive...

Page 100: ...ound the shield only at one end For the direct fiber channel address power budget issues properly When using a LASER Interface attenuators can be necessary to ensure that you do not exceed maximum optical input power to the receiver Figure 3 43 RS422 AND FIBER INTERFACE CONNECTION Connections shown above are for multiplexers configured as DCE data communications equipment units 3 3 7 G 703 AND FIB...

Page 101: ... T recommended G 704 pattern from the standpoint of framing and data rate The frame is 256 bits and is repeated at a frame rate of 8000 Hz with a resultant bit rate of 2048 kbps The specifications for the module are as follows IEEE standard C37 94 for 1 128 kbps optical fiber interface for 2G and 2H modules or C37 94 for 2 64 kbps opti cal fiber interface for 76 and 77 modules Fiber optic cable ty...

Page 102: ...ere must be only one timing source configured For the looped timing mode the system clock is derived from the received line signal Therefore the timing selection should be in loop timing mode for connections to higher order systems The IEEE C37 94 communications module cover removal procedure is as follows 1 With power to the relay off remove the IEEE C37 94 module type 2G 2H 76 or 77 module as fo...

Page 103: ...E 3 3 DIRECT INPUT AND OUTPUT COMMUNICATIONS MODULES 3 Figure 3 45 IEEE C37 94 TIMING SELECTION SWITCH SETTING Cover screw Top cover Bottom cover Ejector inserter clip Ejector inserter clip Timing selection switches Channel 1 Channel 2 FRONT REAR 831774A3 CDR ...

Page 104: ...red switch to internal timing mode while not receiving a valid data packet The link activity LED status is as follows Flashing green FPGA is receiving a valid data packet Solid yellow FPGA is receiving a yellow bit and remains yellow for each yellow bit Solid red FPGA is not receiving a valid packet or the packet received is invalid Tx1 Tx2 Rx1 Rx2 Tx1 Tx2 CH1 Link Activity LED CH2 Link Activity L...

Page 105: ...ED compatible with HP HFBR 1315T transmitter and HP HFBR 2316T receiver Fiber optic cable length up to 11 4 km Fiber optic connector type ST Wavelength 1300 40 nm Connection as per all fiber optic connections a Tx to Rx connection is required The UR series C37 94SM communication module can be connected directly to any compliant digital multiplexer that sup ports C37 94SM as shown below It can also...

Page 106: ...ord the original location of the module to help ensure that the same or replacement module is inserted into the correct slot 2 Simultaneously pull the ejector inserter clips located at the top and at the bottom of each module in order to release the module for removal 3 Remove the module cover screw 4 Remove the top cover by sliding it towards the rear and then lift it upwards 5 Set the timing sel...

Page 107: ...s is as follows Flashing green loop timing mode while receiving a valid data packet Cover screw Top cover Bottom cover Ejector inserter clip Ejector inserter clip Timing selection switches Channel 1 Channel 2 FRONT REAR 831774A3 CDR Tx1 Tx2 Rx1 Rx2 Tx1 Tx2 CH1 Link Activity LED CH2 Link Activity LED COMMS 2B C37 94SM 1300nm single mode ELED 2 channel Technical support Tel 905 294 6222 Fax 905 201 ...

Page 108: ...a valid data packet Solid red switch to internal timing mode while not receiving a valid data packet The link activity LED status is as follows Flashing green FPGA is receiving a valid data packet Solid yellow FPGA is receiving a yellow bit and remains yellow for each yellow bit Solid red FPGA is not receiving a valid packet or the packet received is invalid ...

Page 109: ...ges greater than 600 V DC Stator protection system order code GPM S These systems are illustrated below for comparative purposes in the following figure Figure 3 49 GENERATOR GROUND PROTECTION COMPONENTS 30 6 6WDWRU JURXQG JHQHUDWRU PRGXOH 30 6 6WDWRU JURXQG EDQG SDVV ILOWHU PRGXOH 30 5 LHOG JURXQG SURWHFWLRQ KLJK YROWDJH UHVLVWRU ER 30 LHOG JURXQG ORZ YROWDJH SURWHFWLRQ PRGXOH 5 30 0 LHOG JURXQG ...

Page 110: ...TECTION SYSTEM The field ground low voltage protection system consists of one module the field ground protection low voltage module GPM F L The following figures show the mounting and dimension all dimensions are in inches Figure 3 50 DIMENSIONS FOR GPM F L PANEL MOUNTED UNIT Figure 3 51 DIMENSIONS FOR GPM F L WALL MOUNTED UNIT 5 5 ...

Page 111: ...60 Generator Protection System 3 49 3 HARDWARE 3 4 FIELD AND STATOR GROUND MODULES 3 Figure 3 52 MOUNTING DIAGRAM FOR GPM F L PANEL MOUNTED UNIT 6FUHZ î µ 3DQ LQF 3 1 47 5 1XW 1 ORFN LQF 3 1 47 DVKHU IODW LQF 3 1 47 ...

Page 112: ... field protection low voltage module as shown in the following figure Figure 3 54 REAR VIEW OF GPM F L MODULE SHOWING TERMINAL BLOCKS The following tables outline the pin assignments Table 3 5 GPM F L PIN ASSIGNMENTS FOR CONNECTOR A PIN LABEL DEFINITION 1 L AC L DC 2 N AC N DC 3 GND Ground 1XW 1 ORFN LQF 3 1 47 DVKHU IODW LQF 3 1 47 6FUHZ î µ 3DQ LQF 3 1 47 5 î RQQHFWRU RQQHFWRU RQQHFWRU 5 ...

Page 113: ... F R The following figures show the mounting and dimensions all dimensions are in inches Table 3 6 GPM F L PIN ASSIGNMENTS FOR CONNECTOR B PIN LABEL DEFINITION 1 CH1 RS485 channel 1 positive 2 CH1 RS485 channel 1 negative 3 COM RS485 common 4 CH2 RS485 channel 2 positive 5 CH2 RS485 channel 2 negative 6 IN3 Contact input 3 7 IN2 Contact input 2 8 IN1 Contact input 1 9 COM Contact input common 10 N...

Page 114: ... G60 Generator Protection System GE Multilin 3 4 FIELD AND STATOR GROUND MODULES 3 HARDWARE 3 Figure 3 56 DIMENSIONS FOR GPM F HM PANEL MOUNTED UNIT Figure 3 57 DIMENSIONS FOR GPM F HM WALL MOUNTED UNIT 5 5 ...

Page 115: ...GE Multilin G60 Generator Protection System 3 53 3 HARDWARE 3 4 FIELD AND STATOR GROUND MODULES 3 Figure 3 58 DIMENSIONS FOR GPM F R HIGH VOLTAGE RESISTOR BOX 5 ...

Page 116: ...ator Protection System GE Multilin 3 4 FIELD AND STATOR GROUND MODULES 3 HARDWARE 3 Figure 3 59 MOUNTING DIAGRAM FOR GPM F HM PANEL MOUNTED UNIT 6FUHZ î µ 3DQ LQF 3 1 47 5 1XW 1 ORFN LQF 3 1 47 DVKHU IODW LQF 3 1 47 ...

Page 117: ... WALL MOUNTED UNIT Figure 3 61 MOUNTING DIAGRAM FOR GPM F R HIGH VOLTAGE RESISTOR BOX There are three connectors on the field ground protection high voltage module as shown in the following figure 1XW 1 ORFN LQF 3 1 47 DVKHU IODW LQF 3 1 47 6FUHZ î µ 3DQ LQF 3 1 47 5 î 1XW 1 ORFN LQF 3 1 47 DVKHU IODW LQF 3 1 47 6FUHZ î µ 3DQ LQF 3 1 47 5 ...

Page 118: ... A PIN LABEL DEFINITION 1 L AC L DC 2 N AC N DC 3 GND Ground Table 3 9 GPM F HM PIN ASSIGNMENTS FOR CONNECTOR B PIN LABEL DEFINITION 1 CH1 RS485 channel 1 positive 2 CH1 RS485 channel 1 negative 3 COM RS485 common 4 CH2 RS485 channel 2 positive 5 CH2 RS485 channel 2 negative 6 IN3 Contact input 3 7 IN2 Contact input 2 8 IN1 Contact input 1 9 COM Contact input common 10 NC Relay NC normally closed ...

Page 119: ...used 3 A3 Injection secondary F1 4 A4 Not used 5 A5 Excitation secondary negative F 6 A6 Not used 7 A7 Excitation secondary positive F Table 3 12 GPM F R PIN ASSIGNMENTS FOR CONNECTOR B PIN LABEL DEFINITION 1 B1 Excitation primary positive F2 2 B2 Not used 3 B3 Injection to excitation positive F2 Table 3 13 GPM F R PIN ASSIGNMENTS FOR CONNECTOR C PIN LABEL DEFINITION 1 C1 Injection to excitation n...

Page 120: ...N MODULE TO THE HIGH VOLTAGE RESISTOR BOX 3 4 4 STATOR GROUND PROTECTION SYSTEM Using 100 stator ground fault protection based on sub harmonic injection a 20 Hz voltage is injected to detect ground faults at any point across 100 of the winding The stator ground module works in combination the G60 to provide 100 stator ground fault protection that is operational during generator start up running an...

Page 121: ...Multilin G60 Generator Protection System 3 59 3 HARDWARE 3 4 FIELD AND STATOR GROUND MODULES 3 Figure 3 65 DIMENSIONS FOR GPM S G PANEL MOUNTED UNIT Figure 3 66 DIMENSIONS FOR GPM S G WALL MOUNTED UNIT 5 5 ...

Page 122: ...3 60 G60 Generator Protection System GE Multilin 3 4 FIELD AND STATOR GROUND MODULES 3 HARDWARE 3 Figure 3 67 DIMENSIONS FOR GPM S B BAND PASS FILTER MODULE 5 ...

Page 123: ...0 Generator Protection System 3 61 3 HARDWARE 3 4 FIELD AND STATOR GROUND MODULES 3 Figure 3 68 MOUNTING DIAGRAM FOR GPM S G PANEL MOUNTED UNIT 6FUHZ î µ 3DQ LQF 3 1 47 1XW 1 ORFN LQF 3 1 47 DVKHU IODW LQF 3 1 47 î 5 ...

Page 124: ... WALL MOUNTED UNIT Figure 3 70 MOUNTING DIAGRAM FOR GPM S B BAND PASS FILTER MODULE There are two connectors on the stator ground protection 20 Hz generator module as shown in the following figure 6FUHZ î µ 3DQ LQF 3 1 47 1XW 1 ORFN LQF 3 1 47 DVKHU IODW LQF 3 1 47 5 î 5 6FUHZ î µ 3DQ LQF 3 1 47 DVKHU IODW LQF 3 1 47 1XW 1 ORFN LQF 3 1 47 ...

Page 125: ...protection band pass filter module as shown in the following figure Table 3 14 GPM S G PIN ASSIGNMENTS FOR CONNECTOR A PIN LABEL DEFINITION 1 A1 Contact input 1 2 A2 Contact input 2 3 A3 Alarm relay NC normally closed 4 A4 Not used 5 A5 Output 1 6 A6 Contact input common 7 A7 Alarm relay NO normally open 8 A8 Alarm relay common 9 A9 Not used 10 A10 Output 2 Table 3 15 GPM S G PIN ASSIGNMENTS FOR C...

Page 126: ...dule with the band pass filter module where the neutral grounding transformer NGT secondary voltage is less than or equal to 240 V Table 3 16 GPM S B PIN ASSIGNMENTS FOR CONNECTOR A PIN LABEL DEFINITION 1 A1 Input 1 2 A2 Not used 3 A3 Input 2 4 A4 Not used 5 A5 Reserved 6 A6 Divider out 7 A7 Divider low Table 3 17 GPM S B PIN ASSIGNMENTS FOR CONNECTOR B PIN LABEL DEFINITION 1 B1 Output 1 2 B2 Not ...

Page 127: ...ROUND PROTECTION SYSTEM CONNECTIONS NGT SECONDARY 240 V 3 4 5 UPGRADING FIRMWARE a UPGRADING THE GPM F FIRMWARE The following procedure describes how the upgrade the firmware for the GPM F modules Do the upgrade using the front port and one of the computer COM ports 1 to 4 6WDWRU JURXQG EDQG SDVV ILOWHU PRGXOH 30 6 6WDWRU JURXQG JHQHUDWRU PRGXOH 30 6 5Q WR DX LOLDU 97 5 Stator ground band pass fil...

Page 128: ...3 66 G60 Generator Protection System GE Multilin 3 4 FIELD AND STATOR GROUND MODULES 3 HARDWARE 3 1 Open the G60 device so that it appears in the online window ...

Page 129: ... Update GPM F Firmware tree node The following dialog will appear which allows the user to browse to the location of the firmware file 3 Click Open to start the firmware upgrade process will start Note that this process will also work for a serial port device but will take a longer time to complete approximately 5 min utes ...

Page 130: ...3 68 G60 Generator Protection System GE Multilin 3 4 FIELD AND STATOR GROUND MODULES 3 HARDWARE 3 ...

Page 131: ...ed See the EnerVista UR Setup Help File or refer to the Connecting EnerVista UR Setup with the G60 section in Chapter 1 for details 4 1 3 ENERVISTA UR SETUP OVERVIEW a ENGAGING A DEVICE The EnerVista UR Setup software can be used in online mode relay connected to directly communicate with the G60 relay Communicating relays are organized and grouped by communication interfaces and into sites Sites ...

Page 132: ... the application or provides focus to the already opened application If the file was a settings file has a URS extension that had been removed from the Settings List tree menu it is added back to the Settings List tree menu Drag and Drop The Site List and Settings List control bar windows are each mutually a drag source and a drop target for device order code compatible files or individual menu it...

Page 133: ...age 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 4 1 4 ENERVISTA UR SETUP MAIN WINDOW The EnerVista UR Setup software main window supports the following primary display components 1 Title bar that shows the pathname of the active data view 2 Main window menu bar 3 Main win...

Page 134: ...ed by default The following procedure describes how to enable the settings tem plate for UR series settings files 1 Select a settings file from the offline window of the EnerVista UR Setup main screen 2 Right click the selected device or settings file and select the Template Mode Create Template option The settings file template is now enabled and the file tree displayed in light blue The settings...

Page 135: ...le by clicking them The setting available to view is displayed against a yellow background as shown below Figure 4 3 SETTINGS TEMPLATE VIEW TWO SETTINGS SPECIFIED AS EDITABLE 6 Click on Save to save changes to the settings template 7 Proceed through the settings tree to specify all viewable settings c ADDING PASSWORD PROTECTION TO A TEMPLATE It is highly recommended that templates be saved with pa...

Page 136: ...y those settings available for editing Display all settings with settings not available for editing greyed out Use the following procedure to only display settings available for editing 1 Select an installed device or a settings file from the tree menu on the left of the EnerVista UR Setup main screen 2 Apply the template by selecting the Template Mode View In Template Mode option 3 Enter the temp...

Page 137: ...cified by the template but all settings are shown The effect of applying the template to the phase time overcurrent settings is shown below Figure 4 6 APPLYING TEMPLATES VIA THE VIEW ALL SETTINGS COMMAND e REMOVING THE SETTINGS TEMPLATE It can be necessary at some point to remove a settings template Once a template is removed it cannot be reapplied and it is necessary to define a new settings temp...

Page 138: ...ENTRIES The following procedure describes how to lock individual entries of a FlexLogic equation 1 Right click the settings file or online device and select the Template Mode Create Template item to enable the set tings template feature 2 Select the FlexLogic FlexLogic Equation Editor settings menu item By default all FlexLogic entries are specified as viewable and displayed against a yellow backg...

Page 139: ...low and on the front panel display Figure 4 9 SECURED FLEXLOGIC IN GRAPHICAL VIEW b LOCKING FLEXLOGIC EQUATIONS TO A SERIAL NUMBER A settings file and associated FlexLogic equations can also be locked to a specific UR serial number Once the desired FlexLogic entries in a settings file have been secured use the following procedure to lock the settings file to a specific serial number 1 Select the s...

Page 140: ...s infor mation can be compared with the G60 actual values at any later date to determine if security has been compromised The traceability information is only included in the settings file if a complete settings file is either transferred to the G60 device or obtained from the G60 device Any partial settings transfers by way of drag and drop do not add the traceability information to the settings ...

Page 141: ...y configuration since the settings file was saved a SETTINGS FILE TRACEABILITY INFORMATION The serial number and file transfer date are saved in the settings files when they are sent to a G60 device The G60 serial number and file transfer date are included in the settings file device definition within the EnerVista UR Setup offline window as shown in the example below Figure 4 12 DEVICE DEFINITION...

Page 142: ...L INFORMATION SERIAL NUMBER ACTUAL VALUES PRODUCT INFO MODEL INFORMATION LAST SETTING CHANGE c ADDITIONAL TRACEABILITY RULES The following additional rules apply for the traceability feature If the user changes any settings within the settings file in the offline window then the traceability information is removed from the settings file If the user creates a new settings file then no traceability ...

Page 143: ...erVista UR Setup software The front panel interface consists of LED panels an RS232 port keypad LCD display control pushbuttons and optional user programmable pushbuttons The faceplate is hinged to allow easy access to the removable modules There is also a removable dust cover that fits over the faceplate that must be removed in order to access the keypad panel The following figure shows the horiz...

Page 144: ...reset via the SETTINGS INPUT OUTPUTS RESETTING menu The RS232 port is intended for connection to a portable PC The USER keys are used by the breaker control feature Figure 4 18 TYPICAL LED INDICATOR PANEL FOR ENHANCED FACEPLATE The status indicators in the first column are described below IN SERVICE This LED indicates that control power is applied all monitored inputs outputs and internal systems ...

Page 145: ...ludes phase instantaneous overcurrent phase undervoltage etc This means that the phase A B and C operate oper ands for individual protection elements are ORed to turn on or off the phase A B or C LEDs VOLTAGE This LED indicates voltage was involved CURRENT This LED indicates current was involved FREQUENCY This LED indicates frequency was involved OTHER This LED indicates a composite function was i...

Page 146: ...n when the operate operand associated with the element is asserted and remain on until the RESET button on the front panel is pressed after the operand is reset All elements that are able to discriminate faulted phases can independently turn off or on the phase A B or C LEDs This includes phase instantaneous overcurrent phase undervoltage etc This means that the phase A B and C operate oper ands f...

Page 147: ... however are not pre programmed To match the pre printed label the LED settings must be entered as shown in the User programmable LEDs section of chapter 5 The LEDs are fully user programmable The default labels can be replaced by user printed labels for both panels as explained in the following section Figure 4 21 LED PANEL 2 DEFAULT LABELS 4 3 3 CUSTOM LABELING OF LEDS a ENHANCED FACEPLATE The f...

Page 148: ...ert tool from the package and bend the tabs as described in the following procedures These tabs are used for removal of the default and custom LED labels It is important that the tool be used EXACTLY as shown below with the printed side containing the GE part number facing the user The label package shipped with every G60 contains the three default labels shown below the custom label template shee...

Page 149: ...procedure describes how to remove the LED labels from the G60 enhanced front panel and insert the custom labels 1 Use the knife to lift the LED label and slide the label tool underneath Make sure the bent tabs are pointing away from the relay 2 Slide the label tool under the LED label until the tabs snap out as shown below This attaches the label tool to the LED label ...

Page 150: ...e pocket until the text is properly aligned with the LEDs as shown below The following procedure describes how to remove the user programmable pushbutton labels from the G60 enhanced front panel and insert the custom labels 1 Use the knife to lift the pushbutton label and slide the tail of the label tool underneath as shown below Make sure the bent tab is pointing away from the relay ...

Page 151: ...EPLATE INTERFACE 4 2 Slide the label tool under the user programmable pushbutton label until the tabs snap out as shown below This attaches the label tool to the user programmable pushbutton label 3 Remove the tool and attached user programmable pushbutton label as shown below ...

Page 152: ...mode These keys also scroll through alphanumeric values in the text edit mode Alternatively val ues can be entered with the numeric keypad The decimal key initiates and advances to the next character in text edit mode or enters a decimal point The HELP key can be pressed at any time for context sensitive help messages The ENTER key stores altered setting values 4 3 6 BREAKER CONTROL a INTRODUCTION...

Page 153: ... breakers 4 3 7 MENUS a NAVIGATION Press the MENU key to select a header display page top level menu The header title appears momentarily followed by a header display page menu item Each press of the MENU key advances through the following main heading pages Actual values Settings ENTER COMMAND PASSWORD This message appears when the USER 1 USER 2 or USER 3 key is pressed and a COMMAND PASSWORD is ...

Page 154: ...4 24 G60 Generator Protection System GE Multilin 4 3 FACEPLATE INTERFACE 4 HUMAN INTERFACES 4 Commands Targets User displays when enabled ...

Page 155: ...pears This page contains system and relay status information Repeatedly press the MESSAGE keys to display the other actual value headers SETTINGS PRODUCT SETUP Press the MENU key until the header for the first page of Settings appears This page contains settings to configure the relay SETTINGS SYSTEM SETUP Press the MESSAGE DOWN key to move to the next Settings page This page con tains settings fo...

Page 156: ... the VALUE DOWN key displays the previous selection c ENTERING ALPHANUMERIC TEXT Text settings have data values which are fixed in length but user defined in character They can be upper case letters lower case letters numerals and a selection of special characters FLASH MESSAGE TIME 1 0 s For example select the SETTINGS PRODUCT SETUP DISPLAY PROPERTIES FLASH MESSAGE TIME setting MINIMUM 0 5 MAXIMU...

Page 157: ...key until the SECURITY message appears on the display 3 Press the MESSAGE DOWN key until the INSTALLATION message appears on the display 4 Press the MESSAGE RIGHT key until the RELAY SETTINGS Not Programmed message is displayed 5 After the RELAY SETTINGS Not Programmed message appears on the display press the VALUE keys change the selection to Programmed 6 Press the ENTER key 7 When the NEW SETTIN...

Page 158: ...play press the VALUE UP or DOWN key to change the selection to Yes 6 Press the ENTER key and the display prompts you to ENTER NEW PASSWORD 7 Type in a numerical password up to 10 characters and press the ENTER key 8 When the VERIFY NEW PASSWORD is displayed re type in the same password and press ENTER 9 When the NEW PASSWORD HAS BEEN STORED message appears your new Setting or Command Password will...

Page 159: ...s within three minutes the REMOTE ACCESS DENIED FlexLogic operand is set to On and the G60 does not allow settings or command access via the any external communications interface for five minutes The REMOTE ACCESS DENIED FlexLogic operand is set to Off after five minutes for a Command password or 30 minutes for a Settings pass word These default settings can be changed in EnerVista under Settings ...

Page 160: ...4 30 G60 Generator Protection System GE Multilin 4 3 FACEPLATE INTERFACE 4 HUMAN INTERFACES 4 ...

Page 161: ...59 USER PROGRAMMABLE FAULT REPORT See page 5 64 OSCILLOGRAPHY See page 5 65 DATA LOGGER See page 5 67 USER PROGRAMMABLE LEDS See page 5 69 USER PROGRAMMABLE SELF TESTS See page 5 72 CONTROL PUSHBUTTONS See page 5 72 USER PROGRAMMABLE PUSHBUTTONS See page 5 74 FLEX STATE PARAMETERS See page 5 80 USER DEFINABLE DISPLAYS See page 5 80 DIRECT I O See page 5 83 TELEPROTECTION See page 5 90 INSTALLATION...

Page 162: ...e 5 153 FLEXELEMENTS See page 5 154 NON VOLATILE LATCHES See page 5 158 SETTINGS GROUPED ELEMENTS SETTING GROUP 1 See page 5 159 SETTING GROUP 2 SETTING GROUP 6 SETTINGS CONTROL ELEMENTS TRIP BUS See page 5 255 SETTING GROUPS See page 5 257 SELECTOR SWITCH See page 5 259 UNDERFREQUENCY See page 5 265 OVERFREQUENCY See page 5 266 FREQUENCY RATE OF CHANGE See page 5 267 FREQUENCY OOB ACCUMULATION Se...

Page 163: ...CES See page 5 298 REMOTE INPUTS See page 5 299 REMOTE DPS INPUTS See page 5 300 REMOTE OUTPUTS DNA BIT PAIRS See page 5 300 REMOTE OUTPUTS UserSt BIT PAIRS See page 5 301 RESETTING See page 5 301 REMOTE DEVICES See page 5 298 DIRECT INPUTS See page 5 302 DIRECT OUTPUTS See page 5 302 TELEPROTECTION See page 5 305 IEC 61850 GOOSE ANALOGS See page 5 307 IEC 61850 GOOSE UINTEGERS See page 5 308 SETT...

Page 164: ...ogic diagrams are defined in Appendix F Some settings are specified in per unit pu calculated quantities pu quantity actual quantity base quantity Where the current source is from a single CT the base quantity is the nominal secondary or primary current of the CT Use the secondary current base to convert per unit current settings to from a secondary current value and use the primary cur rent base ...

Page 165: ...ation of the element When set to Self Reset the target message and LED indication follow the operate state of the element and self resets once the operate element condition clears When set to Latched the target message and LED indication will remain visible after the element output returns to logic 0 until a RESET command is received by the relay EVENTS setting This setting is used to control whet...

Page 166: ...tings and becomes available to protection and metering elements in the UR platform Individual names can be given to each source to help identify them more clearly for later use For example in the scheme shown in the above diagram the user configures one source to be the sum of CT1 and CT2 and can name this source as Wdg1 I Once the sources have been configured the user has them available as select...

Page 167: ...uired by the user to know how to connect the relay to external circuits Bank identification consists of the letter designation of the slot in which the CT VT module is mounted as the first character followed by numbers indicating the channel either 1 or 5 See the HardFiber instruction manual for designations of HardFiber voltage and current banks For three phase channel sets the number of the lowe...

Page 168: ...orate email account Customer service provides a code to reset the relay to the factory defaults 2 Enter the reset code on the front panel under Commands Commands Relay Maintenance Service Command 3 Change the default password of ChangeMe1 as outlined in the Set Up CyberSentry and Change Default Password section in the first chapter PASSWORD REQUIREMENTS For password security and CyberSentry securi...

Page 169: ... by the user or by timeout via the setting and command level access timeout settings The remote setting and command ses sions are initiated by the user through the EnerVista UR Setup software and are disabled either by the user or by timeout The state of the session local or remote setting or command determines the state of the following FlexLogic operands ACCESS LOC SETG OFF Asserted when local s...

Page 170: ...ndow 2 Click the command or setting password Change button 3 Enter the new password in the New Password field Requirements are outlined in the Password Requirements section at the beginning of the chapter When an original password has already been used enter it in the Enter Password field and click the Send Password to Device button 4 Re enter the password in the Confirm Password field 5 Click the...

Page 171: ...IMEOUT This setting specifies the length of inactivity no local or remote access required to return to restricted access from the command password level DUAL PERMISSION SECURITY ACCESS PATH SETTINGS PRODUCT SETUP SECURITY DUAL PERMISSION SECURITY ACCESS The dual permission security access feature provides a mechanism for customers to prevent unauthorized or unintended upload of settings to a relay...

Page 172: ... for remote Ethernet or RS485 interfaces setting access supervision If this setting is On the default setting then remote setting access functions as normal that is a remote password is required If this setting is Off then remote setting access is blocked even if the correct remote setting password is pro vided If this setting is any other FlexLogic operand then the operand must be asserted set as...

Page 173: ...d to enter a username and password ADDING A NEW USER The following pre requisites are required to add user accounts to the EnerVista security management system The user adding the account must have administrator rights The EnerVista security management system must be enabled previous section To add user accounts 1 Select the Security User Management menu item to open the user management window 2 E...

Page 174: ...ual values Settings Allows the user to read setting values Commands Allows the user to execute commands Event Recorder Allows the user to use the digital fault recorder FlexLogic Allows the user to read FlexLogic values Update Info Allows the user to write to any function to which they have read privileges When any of the Settings Event Recorder and FlexLogic check boxes are enabled by themselves ...

Page 175: ...on and for customer enabled features are open All the other ports are closed For example Modbus is on by default so its TCP port number 502 is open But if Modbus is disabled port 502 is closed This function has been tested and no unused ports have been found open When CyberSentry is enabled Modbus communications over Ethernet is encrypted which is not always tolerated by SCADA systems The UR has a...

Page 176: ...tection System GE Multilin 5 2 PRODUCT SETUP 5 SETTINGS 5 CYBERSENTRY SETTINGS THROUGH ENERVISTA CyberSentry security settings are configured under Device Settings Product Setup Security Figure 5 2 CYBERSENTRY SECURITY PANEL ...

Page 177: ...812 Administrator Primary Accounting Port RADIUS accounting port 1 65535 1813 Administrator Vendor ID An identifier that specifies RADIUS vendor specific attributes used with the protocol Value that represents General Electric Administrator RADIUS Authentication Shared Secret Shared secret used in authentication It displays as asterisks This setting must meet the CyberSentry password requirements ...

Page 178: ...sabled To re enable device authentication the Supervisor unlocks the device for setting changes and then the Administrator can re enable device authentication Disabled Enabled Enabled Administrator Firmware Locked Indicates if the device receives firmware upgrades If Yes and the firmware upgrade attempt is made the device denies the upgrade and displays an error message that the lock is set On eac...

Page 179: ...ole authenticates to unlock the UR relay for setting changes and not approve changes after the fact Only Supervisor can set the Settings and Firmware Lock in the Security Settings This role also has the ability to forcefully logoff any other role and clear the security event log This role can also be disabled but only through a Supervisor authentication When this role is disabled its permissions a...

Page 180: ...pervisor approval can change the role associated password In CyberSentry password encryption is not supported Session Settings PATH SETTINGS PRODUCT SETUP SECURITY SESSION SETTINGS The following session settings are available SESSION LOCKOUT This setting specifies the number of failed authentications the default is three and the maxi mum is 99 before the device blocks subsequent authentication att...

Page 181: ...the Bypass Access feature for such situations which allows unencrypted Modbus over Ethernet Setting it to Remote ensures no authentication is required over Ethernet and Modbus communication is unen crypted Only a Supervisor or Administrator if Supervisor role is disabled can enable this feature Note that other protocols DNP 101 103 104 EGD are not encrypted and they are good communications options...

Page 182: ...abled then any firmware upgrade operation attempt when the LOCK FIRMWARE UPGRADE setting is set to Yes brings up this self test alarm Settings Lock If this setting is Enabled then an unauthorized write attempt to a setting for a given role activates this self test PATH SETTINGS PRODUCT SETUP SECURITY SUPERVISORY SELF TESTS FAILED AUTHENTICATE CYBERSENTRY SETUP When first using CyberSentry security...

Page 183: ... and log in using the user name and password configured on the RADIUS server for server authentication login 5 After making any required changes log out When changing settings offline ensure that only settings permitted by the role that performs the set tings download are changed because only those changes are applied Pushbuttons both user control buttons and user programmable buttons located on t...

Page 184: ...1 Authentication Failed 2 User Lockout 3 FW Upgrade 4 FW Lock 5 Settings Lock 6 Settings Change Because this can fill the entire event log it is supported by the already existing Settings_Change log file This event is not required 7 Clear Oscillography command 8 Clear Data Logger command not applicable to all UR products 9 Clear Demand Records command not applicable to all UR products 10 Clear Ene...

Page 185: ...sure ments at the fractional volt level can be affected by noise Some customers prefer these low voltages to be displayed as zero while others prefer the voltage to be displayed even when the value reflects noise rather than the actual sig nal The G60 applies a cut off value to the magnitudes and angles of the measured voltages If the magnitude is below the cut off level it is substituted with zer...

Page 186: ... protected by the command password Thus if they are used to clear records the user programma ble pushbuttons can provide extra security if required For example to assign user programmable pushbutton 1 to clear demand records the following settings should be applied 1 Assign the clear demand function to pushbutton 1 by making the following change in the SETTINGS PRODUCT SETUP CLEAR RELAY RECORDS me...

Page 187: ...33 MESSAGE MODBUS PROTOCOL See page 5 35 MESSAGE DNP PROTOCOL See page 5 36 MESSAGE DNP IEC104 POINT LISTS See page 5 39 MESSAGE IEC 61850 PROTOCOL See page 5 40 MESSAGE WEB SERVER HTTP PROTOCOL See page 5 55 MESSAGE TFTP PROTOCOL See page 5 55 MESSAGE IEC 60870 5 104 PROTOCOL See page 5 56 MESSAGE EGD PROTOCOL See page 5 57 SERIAL PORTS COM2 USAGE RS485 Range RS485 RRTD only GPM F only RRTD GPM F...

Page 188: ...e The port is strictly dedicated to RRTD or GPM F usage when COM2 USAGE is selected as RRTD only GPM F only or RRTD GPM F The field ground module GPM F has a fixed slave address of 1 Therefore the RRTD SLAVE ADDRESS setting is appli cable only to the RRTD unit and has a setting rage of 2 to 254 if the COM2 USAGE is set as RRTD GPM F Power must be cycled to the G60 for changes to the COM2 USAGE set...

Page 189: ...figuration monitoring through EnerVista software and access to the public network shared on LAN1 to which port 1 P1 is connected There is no redundancy provided on LAN1 Communica tions to SCADA is provided through LAN2 P2 and P3 are connected to LAN2 where P2 is the primary channel and P3 is the redundant channel In this configuration P3 uses the IP and MAC address of P2 Figure 5 5 MULTIPLE LANS W...

Page 190: ...k IP and subnet settings before configuring the rout ing settings PATH SETTINGS PRODUCT SETUP COMMUNICATIONS NETWORK 1 3 NETWORK PORT 1 PRT1 IP ADDRESS 127 0 0 1 Range Standard IPV4 address format MESSAGE PRT1 SUBNET IP MASK 255 0 0 0 Range Standard IPV4 address format MESSAGE PRT1 GOOSE ENABLED Enabled Range Enabled Disabled NETWORK PORT 2 PRT2 IP ADDRESS 127 0 0 1 Range Standard IPV4 address for...

Page 191: ... address IP address and mask The configuration fields for IP address and mask on port 3 are overwritten with those from port 2 This is visible on the front panel but not displayed in the EnerVista software Port 2 MCST ADDRESS field is visible The port 2 PTP function still uses only port 2 and the port 3 PTP function still uses only port 3 The relay still synchro nizes to whichever port has the bes...

Page 192: ...as such scenarios can bring down both LANs simultaneously Figure 5 7 EXAMPLE OF PARALLEL REDUNDANT NETWORK PRP uses specialized nodes called doubly attached nodes DANPs for handling the duplicated frames DANPs devices have an additional module called Link Redundancy Entity LRE LRE is responsible for duplicating frames and adding the specific PRP trailer when sending the frames out on the LAN as we...

Page 193: ... tion is configured for any of the entries 1 to 6 that entry becomes a static route and it must meet all the rules listed in the next section General Conditions to be Satisfied by Static Routes 2 To configure the default route enter a default gateway address Once a default gateway address is configured it must be validated against condition 2 of the General Conditions to be Satisfied by Static Rou...

Page 194: ...imited the ability to route to specific desti nations particularly if these destinations were reachable through a different interface than the one on which the default gateway was Starting with UR 7 10 up to six static network routes can be configured in addition to a default route The default route con figuration was also moved from the network settings into the routing section The figure shows a...

Page 195: ... UR and destined to EnerVista SHOW ROUTES AND ARP TABLES This feature is available on the Web interface where the main menu contains an additional Communications menu and two submenus Routing Table ARP Table The tables outline the information displayed when the two submenus are selected h MODBUS PROTOCOL PATH SETTINGS PRODUCT SETUP COMMUNICATIONS MODBUS PROTOCOL The serial communication ports util...

Page 196: ...setting sets the TCP port used by Modbus on Ethernet A MODBUS TCP PORT NUMBER of 0 disables Modbus over TCP IP meaning closes the Modbus TCP port When it is set to 0 use the front panel or serial port to communicate with the relay When a 0 value is involved in a change the changes to the MODBUS TCP PORT NUMBER setting take effect when the G60 is restarted Do not set more than one protocol to the s...

Page 197: ...E DEFAULT DEADBAND 30000 Range 0 to 100000000 in steps of 1 MESSAGE DNP POWER DEFAULT DEADBAND 30000 Range 0 to 100000000 in steps of 1 MESSAGE DNP ENERGY DEFAULT DEADBAND 30000 Range 0 to 100000000 in steps of 1 MESSAGE DNP PF DEFAULT DEADBAND 30000 Range 0 to 100000000 in steps of 1 MESSAGE DNP OTHER DEFAULT DEADBAND 30000 Range 0 to 100000000 in steps of 1 MESSAGE DNP TIME SYNC IIN PERIOD 1440 ...

Page 198: ...55 allows infinite re tries The DNP UNSOL RESPONSE DEST ADDRESS is the DNP address to which all unsolicited responses are sent The IP address to which unsolic ited responses are sent is determined by the G60 from the current TCP connection or the most recent UDP message The DNP scale factor settings are numbers used to scale analog input point values These settings group the G60 analog input data ...

Page 199: ...DNP binary outputs are mapped to virtual inputs However some legacy DNP implementations use a mapping of one DNP binary output to two physical or virtual control points to sup port the concept of trip close for circuit breakers or raise lower for tap changers using a single control point That is the DNP master can operate a single point for both trip and close or raise and lower operations The G60...

Page 200: ...assignable parameters The DNP IEC 60870 5 104 point lists always begin with point 0 and end at the first Off value Since DNP IEC 60870 5 104 point lists must be in one continuous block any points assigned after the first Off point are ignored Changes to the DNP IEC 60870 5 104 point lists will not take effect until the G60 is restarted k IEC 61850 PROTOCOL PATH SETTINGS PRODUCT SETUP COMMUNICATION...

Page 201: ...ion in this chapter describe the peer to peer GSSE GOOSE message scheme The GSSE GOOSE configuration main menu is divided into two areas transmission and reception PATH SETTINGS PRODUCT SETUP COMMUNICATIONS IEC 61850 PROTOCOL GSSE GOOSE CONFIGURATION The main transmission menu is shown below PATH SETTINGS PRODUCT SETUP COMMUNICATIONS IEC 61850 PROTOCOL GSSE GOOSE CONFIGURATION TRANSMISSION The gen...

Page 202: ...etting allows the destination Ethernet MAC address to be set This address must be a multicast address the least significant bit of the first byte must be set In G60 releases previous to 5 0x the destination Ethernet MAC address was determined automatically by taking the sending MAC address that is the unique local MAC address of the G60 and setting the multicast bit The GOOSE VLAN PRIORITY setting...

Page 203: ...ets 1 through 8 the integrity GOOSE message will still continue to be sent at the pre configured rate even if no changes in the data items are detected The GOOSE functionality was enhanced to prevent the relay from flooding a communications network with GOOSE mes sages due to an oscillation being created that is triggering a message The G60 has the ability of detecting if a data item in one of the...

Page 204: ... required to transfer IEC 61850 data items between two devices The general steps required for transmission configuration are 1 Configure the transmission dataset 2 Configure the GOOSE service settings 3 Configure the data The general steps required for reception configuration are 1 Configure the reception dataset 2 Configure the GOOSE service settings 3 Configure the data Table 5 5 GOOSE RETRANSMI...

Page 205: ... must match the configuration on the receiver the default value is 0 Set the CONFIG GSE 1 CONFREV value This value changes automatically as described in IEC 61850 part 7 2 For this example it can be left at its default value 3 Configure the data by making the following changes in the PRODUCT SETUP COMMUNICATION IEC 61850 PROTO COL GGIO1 STATUS CONFIGURATION settings menu Set GGIO1 INDICATION 1 to ...

Page 206: ...ed by the GGIO1 ST Ind1 stVal value in the sending device The above settings will be automatically populated by the EnerVista UR Setup software when a com plete SCD file is created by third party substation configurator software For intercommunication between G60 IEDs the fixed DNA UserSt dataset can be used The DNA UserSt dataset con tains the same DNA and UserSt bit pairs that are included in GS...

Page 207: ...e two data items The Boolean status values from these data items can be utilized as remote input FlexLogic operands First the REMOTE DEVICE 1 16 DATASET setting must be set to contain dataset GOOSEIn 1 that is the first configurable dataset Then REMOTE IN 1 16 ITEM settings must be set to Dataset Item 1 and Dataset Item 2 These remote input FlexLogic operands will then change state in accordance w...

Page 208: ... the G60 is restarted Do not set more than one protocol to the same TCP UDP port number as this results in unreliable operation of those protocols The SERVER SCANNING feature should be set to Disabled when IEC 61850 client server functionality is not required IEC 61850 has two modes of functionality GOOSE GSSE inter device communication and client server communication If the GOOSE GSSE functionali...

Page 209: ...nd values used to determine when the update the MMXU mag and cVal values from the associated instmag and instcVal values The mag and cVal values are used for the IEC 61850 buffered and unbuffered reports These settings correspond to the associated db data items in the CF functional con straint of the MMXU logical node as per the IEC 61850 standard According to IEC 61850 7 3 the db value shall repr...

Page 210: ...to control the G60 virtual inputs The GGIO4 analog configuration points are shown below PATH SETTINGS PRODUCT SETUP COMMUNICATIONS IEC 61850 PROTOCOL GGIO4 ANALOG CONFIGURATION The NUMBER OF ANALOG POINTS setting determines how many analog data points will exist in GGIO4 When this value is changed the G60 must be rebooted in order to allow the GGIO4 logical node to be re instantiated and contain t...

Page 211: ...ot all values can be stored Some values may be rounded to the closest possible floating point number The GGIO5 integer configuration points are shown below PATH SETTINGS PRODUCT SETUP COMMUNICATIONS IEC 61850 PROTOCOL GGIO5 ANALOG CONFIGURATION The GGIO5 logical node allows IEC 61850 client access to integer data values This allows access to as many as 16 unsigned integer value points associated t...

Page 212: ... a value from the list of IEC 61850 data attributes supported by the G60 Changes to the dataset will only take effect when the G60 is restarted It is recommended to use reporting service from logical node LLN0 if a user needs some but not all data from already existing GGIO1 GGIO4 and MMXU4 points and their quantity is not greater than 64 minus the number items in this dataset REPORT 1 DATASET ITE...

Page 213: ...can result in very large OpCnt values over time This setting allows the OpCnt to be reset to 0 for XCBR1 XCBR CONFIGURATION XCBR1 ST LOC OPERAND Off Range FlexLogic operand MESSAGE XCBR6 ST LOC OPERAND Off Range FlexLogic operand MESSAGE CLEAR XCBR1 OpCnt No Range No Yes MESSAGE CLEAR XCBR6 OpCnt No Range No Yes MESSAGE XCBR1 SYNCCHECK CLS Off Range FlexLogic operand MESSAGE XCBR6 SYNCCHECK CLS Of...

Page 214: ...ete details on these control models The XCBR1 Pos sboTimeout setting is used to select SBO timeout value To be successful the IEC 61850 operate com mand must be executed after the select command within the XCBR1 Pos sboTimeout setting value The disconnect switch configuration settings are shown below Changes to these values will not take effect until the UR is restarted PATH SETTINGS PRODUCT SETUP...

Page 215: ...number as this results in unreliable operation of those protocols m TFTP PROTOCOL PATH SETTINGS PRODUCT SETUP COMMUNICATIONS TFTP PROTOCOL The Trivial File Transfer Protocol TFTP can be used to transfer files from the G60 over a network The G60 operates as a TFTP server TFTP client software is available from various sources including Microsoft Windows NT The dir txt file obtained from the G60 cont...

Page 216: ...esholds are in effect The IEC REDUNDANCY setting decides whether multiple client connections are accepted or not If redundancy is set to Yes two simultaneous connections can be active at any given time When the IEC port number is set to 0 the change takes effect when the G60 is restarted Do not set more than one protocol to the same TCP UDP port number as this results in unreliable operation of th...

Page 217: ...tocols used for the real time transfer of data for display and control purposes The relay can be configured to produce EGD data exchanges and other devices can be configured to consume EGD data exchanges The number of produced exchanges up to three the data items in each exchange up to 50 and the exchange production rate can be configured EGD cannot be used to transfer data between UR series relay...

Page 218: ...GD exchange 1 has a setting range of 50 to 1000 ms Exchanges 2 and 3 have a setting range of 500 to 1000 ms FAST PROD EXCH 1 CONFIGURATION EXCH 1 FUNCTION Disable Range Disable Enable MESSAGE EXCH 1 DESTINATION 0 0 0 0 Range standard IP address MESSAGE EXCH 1 DATA RATE 1000 ms Range 50 to 1000 ms in steps of 1 MESSAGE EXCH 1 DATA ITEM 1 0 Range 0 to 65535 in steps of 1 Modbus register address rang...

Page 219: ...duced EGD exchange will contain three data items 5 2 5 MODBUS USER MAP PATH SETTINGS PRODUCT SETUP MODBUS USER MAP The Modbus user map provides read only access for up to 256 registers To obtain a memory map value enter the desired address in the ADDRESS line converted from hex to decimal format The corresponding value displays in the VALUE line A value of 0 in subsequent register ADDRESS lines au...

Page 220: ...e set to DC Shift or Amplitude Modulated IRIG B synchronization can be disabled by making this setting None To configure and enable PTP and or SNTP or to set local time parameters for example time zone daylight savings use the following sections b PRECISION TIME PROTOCOL 1588 PATH SETTINGS PRODUCT SETUP REAL TIME CLOCK PRECISION TIME PROTOCOL 1588 PATH SETTINGS PRODUCT SETUP REAL TIME CLOCK PRECIS...

Page 221: ...latency may not be compensated for and the time received at the end device could be in error by more than 100 µs See the Settings Product Setup Real Time Clock section of this manual for a description of when time values received via PTP are used to update the relay s real time clock The following settings are available for configuring the relay for PTP STRICT POWER PROFILE Power profile IEEE Std ...

Page 222: ...f path propagation delays to and from the relay For instance if it is known say from the physical length of the fibers and the propagation speed in the fibers that the delay from the relay to the Ethernet switch it is connected to is 9 000 ns and the that the delay from the switch to the relay is 11 000 ns then the mean delay is 10 000 ns and the path delay asymmetry is 11000 10000 1000 ns c SNTP ...

Page 223: ... is synchronized with a communications protocol providing only UTC such as PTP or SNTP the time offset setting is used to determine local time from the UTC provided PTP ALTERNATE_TIME_OFFSET_INDICATOR TLVs are not used to calculate local time When a communications protocol other than PTP provides UTC to local time offset meaning IRIG B that offset is used instead of the local time and daylight tim...

Page 224: ... fault reports to enable capture of two types of trips for example trip from ther mal protection with the report configured to include temperatures and short circuit trip with the report configured to include voltages and currents Both reports feed the same report file queue The last record is available as individual data items via communications protocols PRE FAULT 1 TRIGGER Specifies the FlexLog...

Page 225: ...tc A trigger position of 25 consists of 25 pre and 75 post trigger data The TRIGGER SOURCE is always captured in oscillography and may be any FlexLogic parameter element state contact input virtual output etc The relay sampling rate is 64 samples per cycle The AC INPUT WAVEFORMS setting determines the sampling rate at which AC input signals that is current and voltage are stored Reducing the sampl...

Page 226: ...used to expedite the selection of the parameter on the relay display It can be quite time consuming to scan through the list of parameters via the relay keypad and display entering this number via the relay keypad will cause the corresponding parameter to be displayed All eight CT VT module channels are stored in the oscillography file The CT VT module channels are named as follows slot_letter ter...

Page 227: ... channels over a long period or a larger number of channels for a shorter period The relay automatically partitions the available memory between the channels in use Exam ple storage capacities for a system frequency of 60 Hz are shown in the following table DATA LOGGER DATA LOGGER MODE Continuous Range Continuous Trigger MESSAGE DATA LOGGER TRIGGER Off Range FlexLogic operand MESSAGE DATA LOGGER R...

Page 228: ... is set to Trigger DATA LOGGER RATE This setting selects the time interval at which the actual value data will be recorded DATA LOGGER CHNL 1 16 This setting selects the metering actual value that is to be recorded in Channel 1 16 of the data log The parameters available in a given relay are dependent on the type of relay the type and number of CT VT hardware modules installed and the type and num...

Page 229: ...s are turned on One LED at a time turns off for 1 second then back on The test routine starts at the top left panel moving from top to bottom of each column of the LEDs This test checks for hardware failures that lead to more than one LED being turned off from a single logic point This stage can be interrupted at any time When testing is in progress the LEDs are controlled by the test sequence rat...

Page 230: ...start stage 2 At this point forward test may be aborted by pressing the pushbutton APPLICATION EXAMPLE 2 Assume one needs to check if any LEDs are burned as well as exercise one LED at a time to check for other failures This is to be performed via user programmable pushbutton 1 After applying the settings in application example 1 hold down the pushbutton as long as necessary to test all LEDs Next ...

Page 231: ... the location of these indexed LEDs The user programmable LED settings select the FlexLogic operands that control the LEDs If the LED 1 TYPE setting is Self Reset the default setting the LED illumination will track the state of the selected LED operand If the LED 1 TYPE setting is Latched the LED once lit remains so until reset by the faceplate RESET button from a remote device via a communica tio...

Page 232: ...here are three standard control pushbuttons labeled USER 1 USER 2 and USER 3 on the standard and enhanced front panels These are user programmable and can be used for various applications such as performing an LED test switching setting groups and invoking and scrolling though user programmable displays USER PROGRAMMABLE SELF TESTS DIRECT RING BREAK FUNCTION Enabled Range Disabled Enabled Valid fo...

Page 233: ...ed A dropout delay of 100 ms is incorporated to ensure fast pushbutton manipulation will be recognized by various features that may use control pushbuttons as inputs An event is logged in the event record as per user setting when a control pushbutton is pressed No event is logged when the pushbutton is released The faceplate keys including control keys cannot be operated simultaneously a given key...

Page 234: ...he user programmable pushbuttons are under the control level of password protection The user configurable pushbuttons for the enhanced faceplate are shown below USER PUSHBUTTON 1 PUSHBUTTON 1 FUNCTION Disabled Range Self Reset Latched Disabled MESSAGE PUSHBTN 1 ID TEXT Range Up to 20 alphanumeric characters MESSAGE PUSHBTN 1 ON TEXT Range Up to 20 alphanumeric characters MESSAGE PUSHBTN 1 OFF TEXT...

Page 235: ...d in non volatile memory and maintained through a loss of control power The pushbutton is reset deactivated in latched mode by asserting the operand assigned to the PUSHBTN 1 RESET set ting or by directly pressing the associated active front panel pushbutton It can also be programmed to reset automatically through the PUSHBTN 1 AUTORST and PUSHBTN 1 AUTORST DELAY set tings These settings enable th...

Page 236: ...mory Should the power supply be lost the correct state of the pushbutton is retained upon subsequent power up of the relay PUSHBTN 1 ID TEXT This setting specifies the top 20 character line of the user programmable message and is intended to provide ID information of the pushbutton Refer to the User definable displays section for instructions on how to enter alphanumeric characters from the keypad...

Page 237: ... to the PUSHBTN 1 OFF TEXT setting This message can be temporary removed if any front panel keypad button is pressed However ten seconds of keypad inactivity will restore the message if the PUSHBUTTON 1 ON operand is still active If the PUSHBTN 1 MESSAGE is set to Normal the message programmed in the PUSHBTN 1 ID and PUSHBTN 1 ON TEXT settings will be displayed as long as PUSHBUTTON 1 ON operand i...

Page 238: ...ock SETTING Off 0 Local Lock SETTING Off 0 Set SETTING Off 0 Reset SETTING Enabled Disabled Autoreset Function FLEXLOGIC OPERAND PUSHBUTTON 1 ON FLEXLOGIC OPERAND PUSHBUTTON 1 OFF TIMER 200 ms 0 AND AND AND AND AND TIMER 50 ms 0 TIMER 50 ms 0 SETTING Autoreset Delay TPKP 0 TIMER 200 ms 0 AND AND SETTING Drop Out Timer TRST 0 PUSHBUTTON ON To user programmable pushbuttons logic sheet 2 842024A2 LAT...

Page 239: ...G any FlexLogic operand PUSHBTN 1 LED CTL AND SETTING Flash Message Time TRST 0 PUSHBUTTON ON LATCHED LATCHED SELF RESET AND From user programmable pushbuttons logic sheet 1 842021A3 FLEXLOGIC OPERAND PUSHBUTTON 1 ON FLEXLOGIC OPERAND PUSHBUTTON 1 OFF SETTING TRST 0 Instantaneous reset LCD MESSAGE ENGAGE MESSAGE SETTINGS XXXXXXXXXX Top Text XXXXXXXXXX On Text The message is temporarily removed if ...

Page 240: ...and ACTUAL VALUES top level menus The sub menus facili tate text entry and Modbus register data pointer options for defining the user display content Once programmed the user definable displays can be viewed in two ways KEYPAD Use the MENU key to select the USER DISPLAYS menu item to access the first user definable display note that only the programmed screens are displayed The screens can be scro...

Page 241: ... character is used to mark the start of a data field the length of the data field needs to be accounted for Up to five separate data fields can be entered in a user display the nth tilde refers to the nth item A user display may be entered from the faceplate keypad or the EnerVista UR Setup interface preferred for convenience The following procedure shows how to enter text characters in the top an...

Page 242: ...nd bottom line items are different USER DISPLAY 1 DISP 1 TOP LINE Current X A Shows user defined text with first tilde marker MESSAGE DISP 1 BOTTOM LINE Current Y A Shows user defined text with second tilde marker MESSAGE DISP 1 ITEM 1 6016 Shows decimal form of user selected Modbus register address corresponding to first tilde marker MESSAGE DISP 1 ITEM 2 6357 Shows decimal form of user selected ...

Page 243: ... and signaled by the following FlexLogic operands 1 DIRECT RING BREAK direct input output ring break This FlexLogic operand indicates that direct output messages sent from a UR series relay are not being received back by the relay 2 DIRECT DEVICE 1 OFF to DIRECT DEVICE 16 OFF direct device offline These FlexLogic operands indicate that direct output messages from at least one direct device are not...

Page 244: ...ication channels The following application examples illustrate the basic concepts for direct input and output configuration Please refer to the Inputs and outputs section in this chapter for information on configuring FlexLogic operands flags bits to be exchanged Table 5 9 DIRECT INPUT AND OUTPUT DATA RATES MODULE CHANNEL SUPPORTED DATA RATES 74 Channel 1 64 kbps Channel 2 64 kbps 7L Channel 1 64 ...

Page 245: ... 1 DIRECT I O CH1 RING CONFIGURATION Yes DIRECT I O DATA RATE 128 kbps For UR series IED 2 DIRECT OUTPUT DEVICE ID 2 DIRECT I O CH1 RING CONFIGURATION Yes DIRECT I O DATA RATE 128 kbps The message delivery time is about 0 2 of power cycle in both ways at 128 kbps that is from device 1 to device 2 and from device 2 to device 1 Different communications cards can be selected by the user for this back...

Page 246: ...th rings are healthy IED 1 to IED 2 0 2 of power system cycle IED 1 to IED 3 0 4 of power system cycle IED 1 to IED 4 0 2 of power system cycle IED 2 to IED 3 0 2 of power system cycle IED 2 to IED 4 0 4 of power system cycle IED 3 to IED 4 0 2 of power system cycle If one ring is broken say TX2 RX2 the delivery times are as follows IED 1 to IED 2 0 2 of power system cycle IED 1 to IED 3 0 4 of po...

Page 247: ...TPUT DEVICE ID 2 DIRECT I O CH1 RING CONFIGURATION Yes DIRECT I O CH2 RING CONFIGURATION Yes For UR series IED 3 DIRECT OUTPUT DEVICE ID 3 DIRECT I O CH1 RING CONFIGURATION Yes DIRECT I O CH2 RING CONFIGURATION Yes In this configuration the following delivery times are expected at 128 kbps IED 1 to IED 2 0 2 of power system cycle IED 1 to IED 3 0 5 of power system cycle IED 2 to IED 3 0 2 of power...

Page 248: ... CH1 2 PATH SETTINGS PRODUCT SETUP DIRECT I O CRC ALARM CH1 2 The G60 checks integrity of the incoming direct input and output messages using a 32 bit CRC The CRC alarm function is available for monitoring the communication medium noise by tracking the rate of messages failing the CRC check The monitoring function counts all incoming messages including messages that failed the CRC check A separate...

Page 249: ...suming the best case of only 1 bit error in a failed packet having 1 failed packet for every 63 received is about equal to a BER of 10 4 c UNRETURNED MESSAGES ALARM CH1 2 PATH SETTINGS PRODUCT SETUP DIRECT I O UNRETURNED MESSAGES ALARM CH1 2 The G60 checks integrity of the direct input and output communication ring by counting unreturned messages In the ring configuration all messages originating ...

Page 250: ...OF TERMINALS is 3 three terminal system set the NUMBER OF CHANNELS to 2 For a two terminal system the NUMBER OF CHANNELS can set to 1 or 2 redundant channels LOCAL RELAY ID NUMBER TERMINAL 1 RELAY ID NUMBER and TERMINAL 2 RELAY ID NUMBER In installa tions that use multiplexers or modems it is desirable to ensure that the data used by the relays protecting a given line is from the correct relays Th...

Page 251: ...lay until RELAY SETTINGS is set to Programmed This setting is defaulted to Not Programmed when at the factory The UNIT NOT PROGRAMMED self test error message is displayed until the relay is put into the Programmed state The RELAY NAME setting allows the user to uniquely identify a relay This name will appear on generated reports INSTALLATION RELAY SETTINGS Not Programmed Range Not Programmed Progr...

Page 252: ... consists of the following steps Configure the field units This establishes the point to point connection between a specific port on the relay process bus module and a specific digital core on a specific Brick This is a necessary first step in configuring a process bus relay Configure the AC banks This sets the primary and secondary quantities and connections for currents and voltages AC bank conf...

Page 253: ... ground CT primary rating must be entered To detect low level ground fault currents the sensitive ground input may be used In this case the sensitive ground CT primary rating must be entered Refer to chapter 3 for more details on CT connections Enter the rated CT primary current values For both 1000 5 and 1000 1 CTs the entry would be 1000 For correct opera tion the CT secondary rating must match ...

Page 254: ...tage and with a 14400 120 volt VT in a delta connec tion the secondary voltage would be 115 that is 13800 14400 120 For a wye connection the voltage value entered must be the phase to neutral voltage which would be 115 66 4 On a 14 4 kV system with a delta connection and a VT primary to secondary turns ratio of 14400 120 the voltage value entered would be 120 that is 14400 120 5 4 2 POWER SYSTEM P...

Page 255: ...on phase A is used for angle referencing while Clarke transformation of the phase signals is used for frequency metering and tracking for better performance dur ing fault open pole and VT and CT fail conditions The phase reference and frequency tracking AC signals are selected based upon the Source configuration regardless of whether or not a particular signal is actually applied to the relay Phas...

Page 256: ...ltage parameters from the available inputs Users must select the specific input parameters to be measured by every element in the relevant settings menu The internal design of the ele ment specifies which type of parameter to use and provides a setting for source selection In elements where the parameter may be either fundamental or RMS magnitude such as phase time overcurrent two settings are pro...

Page 257: ...The following figure shows the arrangement of sources used to provide the functions required in this application and the CT VT inputs that are used to provide the data INCREASING SLOT POSITION LETTER CT VT MODULE 1 CT VT MODULE 2 CT VT MODULE 3 CTs VTs not applicable 827092A3 CDR SOURCE 1 CURRENT PHASOR PRODUCT SETUP DISPLAY PROPERTIES CURRENT CUT OFF LEVEL PRODUCT SETUP DISPLAY PROPERTIES CURRENT...

Page 258: ... USE OF SOURCES Y LV D HV AUX SRC 1 SRC 2 SRC 3 Phase CT M1 F1 F5 None Ground CT M1 None None Phase VT M5 None None Aux VT None None U1 827794A1 CDR F 5 F 1 DSP Bank U 1 M 1 M 1 M 5 51BF 1 51BF 2 Source 4 87T 51P UR Relay A V V A W W Var Var Amps Source 1 Source 3 Volts Amps Amps Volts Amps Source 2 ...

Page 259: ... Off Range FlexLogic operand MESSAGE BREAKER 1 ΦA 3P CLSD Off Range FlexLogic operand MESSAGE BREAKER 1 ΦA 3P OPND Off Range FlexLogic operand MESSAGE BREAKER 1 ΦB CLOSED Off Range FlexLogic operand MESSAGE BREAKER 1 ΦB OPENED Off Range FlexLogic operand MESSAGE BREAKER 1 ΦC CLOSED Off Range FlexLogic operand MESSAGE BREAKER 1 ΦC OPENED Off Range FlexLogic operand MESSAGE BREAKER 1 Toperate 0 070 ...

Page 260: ...nd used to track the breaker open or closed position If the mode is selected as 1 Pole the input mentioned above is used to track phase A and the BREAKER 1 ΦB and BREAKER 1 ΦC settings select operands to track phases B and C respectively BREAKER 1 ΦA 3P OPND This setting selects an operand usually a contact input that should be a normally closed 52 b status input to create a logic 1 when the break...

Page 261: ...TTING Enabled BREAKER 1 PUSHBUTTON CONTROL USER 2 OFF ON To close BRK1 Name SETTING Off 0 BREAKER 1 CLOSE FLEXLOGIC OPERAND AR CLOSE BKR 1 SETTING Off 0 BREAKER 1 BLOCK CLOSE SETTING MANUAL CLOSE RECAL1 TIME 0 FLEXLOGIC OPERAND BREAKER 1 MNL CLS FLEXLOGIC OPERAND BREAKER 1 ON CMD FLEXLOGIC OPERANDS BREAKER 1 OFF CMD BREAKER 1 TRIP A BREAKER 1 TRIP B BREAKER 1 TRIP C To breaker control logic sheet ...

Page 262: ...ND BREAKER 1 OPEN BREAKER 1 DISCREP FLEXLOGIC OPERAND BREAKER 1 TROUBLE FLEXLOGIC OPERAND BREAKER 1 BAD STATUS FLEXLOGIC OPERANDS BREAKER 1 ΦA BAD ST BREAKER 1 ΦA CLSD BREAKER 1 ΦA OPEN BREAKER 1 INTERM ΦA FLEXLOGIC OPERANDS BREAKER 1 ANY P OPEN BREAKER 1 1P OPEN BREAKER 1 OOS SETTING 3 Pole 1 Pole BREAKER 1 MODE SETTING Off BREAKER 1 EXT ALARM SETTING Off BREAKER 1 OUT OF SV AND OR OR SETTING BRE...

Page 263: ...to disconnect switch 1 SWITCH 1 MODE This setting selects 3 Pole mode where disconnect switch poles have a single common auxiliary switch or 1 Pole mode where each disconnect switch pole has its own auxiliary switch SWITCH 1 SWITCH 1 FUNCTION Disabled Range Disabled Enabled MESSAGE SWITCH 1 NAME SW 1 Range up to 6 alphanumeric characters MESSAGE SWITCH 1 MODE 3 Pole Range 3 Pole 1 Pole MESSAGE SWI...

Page 264: ...put to create a logic 1 when the disconnect switch is open If a separate 89 b contact input is not available then an inverted 89 a status signal can be used SWITCH 1 ΦB CLOSED If the mode is selected as three pole this setting has no function If the mode is selected as single pole this input is used to track the disconnect switch phase B closed position as above for phase A SWITCH 1 ΦB OPENED If t...

Page 265: ...CH 1 ΦB INTERM FLEXLOGIC OPERANDS SWITCH 1 Φ BAD ST C SWITCH 1 ΦC CLSD SWITCH 1 ΦC OPEN SWITCH 1 ΦC INTERM 859713A1 CDR SETTING SWITCH 1 ALARM DELAY 0 SETTING Off SWITCH 1 BLK CLOSE SETTING Off SWITCH 1 CLOSE SETTING Off SWITCH 1 BLK OPEN SETTING Off SWITCH 1 OPEN SETTING Disabled Enabled SWITCH 1 FUNCTION AND AND FLEXLOGIC OPERAND SWITCH 1 ON CMD FLEXLOGIC OPERAND SWITCH 1 OFF CMD OR OR AND AND S...

Page 266: ...00 to 0 98 and 1 03 to 20 00 This data is converted into two continuous curves by linear interpolation between data points To enter a custom FlexCurve enter the reset and operate times using the VALUE keys for each selected pickup point using the MESSAGE UP DOWN keys for the desired protection curve A B C or D FLEXCURVE A FLEXCURVE A TIME AT 0 00 xPKP 0 ms Range 0 to 65535 ms in steps of 1 Table 5...

Page 267: ...th a minimum response time and a fixed time above a specified pickup multiples There are 41 recloser curve types supported These definite oper ating times are useful to coordinate operating times typically at higher currents and where upstream and downstream pro tective devices have different operating characteristics The recloser curve configuration window shown below appears when the Initialize ...

Page 268: ... ms see below Figure 5 30 COMPOSITE RECLOSER CURVE WITH HCT DISABLED With the HCT feature enabled the operating time reduces to 30 ms for pickup multiples exceeding 8 times pickup Figure 5 31 COMPOSITE RECLOSER CURVE WITH HCT ENABLED Configuring a composite curve with an increase in operating time at increased pickup multiples is not allowed If this is attempted the EnerVista UR Setup software gen...

Page 269: ...ER CURVES GE113 GE120 GE138 AND GE142 GE104 1 1 2 1 5 2 2 5 3 4 5 6 7 8 9 10 12 15 20 0 01 0 02 0 05 0 1 0 2 0 5 1 2 CURRENT multiple of pickup TIME sec GE101 GE102 GE103 GE106 GE105 842723A1 CDR 1 1 2 1 5 2 2 5 3 4 5 6 7 8 9 10 12 15 20 0 05 0 1 0 2 0 5 1 2 5 10 20 50 CURRENT multiple of pickup TIME sec GE113 GE142 GE138 GE120 842725A1 CDR ...

Page 270: ...AND GE201 Figure 5 35 RECLOSER CURVES GE131 GE141 GE152 AND GE200 1 1 2 1 5 2 2 5 3 4 5 6 7 8 9 10 12 15 20 0 5 1 2 5 10 20 50 CURRENT multiple of pickup TIME sec GE134 GE151 GE140 GE137 GE201 842730A1 CDR 1 1 2 1 5 2 2 5 3 4 5 6 7 8 9 10 12 15 20 2 5 10 20 50 CURRENT multiple of pickup TIME sec GE131 GE200 GE152 GE141 842728A1 CDR ...

Page 271: ...S GE116 GE117 GE118 GE132 GE136 AND GE139 842729A1 CDR 1 1 2 1 5 2 2 5 3 4 5 6 7 8 9 10 12 15 20 0 01 0 02 0 05 0 1 0 2 0 5 1 2 5 10 20 50 CURRENT multiple of pickup TIME sec GE133 GE163 GE162 GE161 GE165 GE164 842726A1 CDR 1 1 2 1 5 2 2 5 3 4 5 6 7 8 9 10 12 15 20 0 01 0 02 0 05 0 1 0 2 0 5 1 2 5 10 20 CURRENT multiple of pickup TIME sec GE116 GE132 GE118 GE117 GE139 GE136 ...

Page 272: ... Figure 5 39 RECLOSER CURVES GE119 GE135 AND GE202 842724A1 CDR 1 1 2 1 5 2 2 5 3 4 5 6 7 8 9 10 12 15 20 0 01 0 02 0 05 0 1 0 2 0 5 1 2 5 10 20 CURRENT multiple of pickup TIME sec GE121 GE114 GE112 GE122 GE107 GE115 GE111 842727A1 CDR 1 1 2 1 5 2 2 5 3 4 5 6 7 8 9 10 12 15 20 0 2 0 5 1 2 5 10 20 50 CURRENT multiple of pickup TIME sec GE119 GE202 GE135 ...

Page 273: ...n the power system are networked to a central location The G60 offers PMU features over two communication standards IEC61850 9 5 and IEEE C37 118 The figure shows complete Synchrophasor implementation Figure 5 40 COMPLETE SYNCHROPHASOR IMPLEMENTATION UR Implementation of IEC61850 90 5 Synchrophasor data as measured and calculated by phasor measurement units PMUs is very useful to assess the condi ...

Page 274: ...evice PMUs Logical Device 2 through 5 and four aggregators located in Logical Device 1 LD1 while other UR family members support one PMU and only one aggregator The control blocks for the aggregators are located in LD1 A 64 char LDName setting is provided see figure below Figure 5 41 N60 SUPPORT FOR FOUR LOGICAL DEVICE PMUS The specifics of implementation by model number is summarized in the table...

Page 275: ...gregator inherits the Sample Rate SmpRate and IEEC C37 118 Class P or M of that PMU The value of the SmpRate DO in the Report Control Block is set based on the value of the Sample Rate in the PMU The Class of the Dataset are mapped into the MSVID of the Dataset see text below for the overall name of the MSVID If other PMUs are mapped into the same aggregator with different Sample Rates or from dif...

Page 276: ...es the maximum size of each PMU data set for version 7 0 using FCDA data non structured data EXAMPLE PROTECTION SYNCHROPHASORS DATA SET WITH REPORTING RATE 60 FRAMES SECOND This example gives the protection synchrophasors data set with a reporting rate of 60 frames per second P60MMXU1 See figure above Logical Nodes Supported in Each Logical Device This data or list of items see figure below is not...

Page 277: ...ATION USING IEC61850 90 5 The G60 is expected to send the CFG 2 file IEEE C37 118 config file upon request from the upstream synchrophasor devices e g P30 without stopping R SV multicasting see figure below The primary domain controller PDC does not need to use a stop start data stream command if the UR protocol is set to IEC61850 90 5 prior to requesting the configura tion via CFG 2 IEEE C37 118 ...

Page 278: ...information via the CFG 2 file for a given aggregator when the aggregator is set to 90 5 the version number of the CFG 2 file found in bits 0 3 of the frame SYNC word which should presently be set to 2 is set as follows The PMU settings are organized in logical groups as follows PATH SETTINGS SYSTEM SETUP PHASOR MEASUREMENT UNIT PHASOR MEASUREMENT UNIT 1 VALUE DECIMAL OF ASDUS 11 1 12 2 13 3 14 4 ...

Page 279: ...ar MESSAGE PMU 1 RATE 10 sec Range 1 sec 2 sec 4 sec 5 sec 10 sec 12 sec 15 sec 20 sec 25 sec 30 sec 50 sec 60 sec 100 sec 120 sec MESSAGE PMU 1 PHS 1 Off Range Available synchrophasor values MESSAGE PMU 1 PHS 1 NAME GE UR PMU PHS 1 Range 16 character ASCII string MESSAGE PMU 1 PHS 14 Off Range Available synchrophasor values MESSAGE PMU 1 PHS 14 NAME GE UR PMU PHS 14 Range 16 character ASCII strin...

Page 280: ...the content to be sent out or recorded When one source is selected by one PMU it cannot be selected by another PMU PMU 1 CLASS Range P M None This setting selects the synchrophasor class Note that a reporting rate of 100 or 120 can only be selected for class P synchrophasors and if the system frequency is 50 Hz or 60 Hz respectively PMU 1 NETWORK REPORTING FORMAT This setting selects whether synch...

Page 281: ...led concurrently with the synchrophasor instant These values are mapped into a two byte integer number with byte 1 LSB corresponding to the digital channel 1and byte 2 MSB corresponding to digital channel 16 PMU1 D CH 1 NM to PMU1 D CH 16 NM These settings allow for custom naming of the digital channels Sixteen character ASCII strings are allowed as in the CHNAM field of the configuration frame PM...

Page 282: ...spectively as specified in the IEC 61850 standard IEC 61850 90 5 PMU 1 CONFIGURATION PATH SETTINGS SYSTEM SETUP PHASOR MEASUREMENT BASIC CONFIGURATION PMU1 PMU 1 BASIC CONFIGURA TION 90 5 PMU 1 CONFIGURATION PMU1 LDINST A user defined visible string maximum 64 char ASCII test to assign Logical Device LD Inst for a PMU LD As per IEC 61850 6 standard specification the PMU LD Name is the concatenated...

Page 283: ...teps of 0 1 MESSAGE PMU 1 VB CALIBRATION ANGLE 0 00 Range 5 00 to 5 00 in steps of 0 05 MESSAGE PMU 1 VB CALIBRATION MAG 100 0 Range 95 0 to 105 0 in steps of 0 1 MESSAGE PMU 1 VC CALIBRATION ANGLE 0 00 Range 5 00 to 5 00 in steps of 0 05 MESSAGE PMU 1 VC CALIBRATION MAG 100 0 Range 95 0 to 105 0 in steps of 0 1 MESSAGE PMU 1 VX CALIBRATION ANGLE 0 00 Range 5 00 to 5 00 in steps of 0 05 MESSAGE PM...

Page 284: ...ntrol purposes without applying this correction 4 When connected to line to line voltages the PMU calculates symmetrical voltages with the reference to the AG voltage and not to the physically connected AB voltage see the Metering Conventions section in Chapter 6 PMU 1 SEQ CURR SHIFT ANGLE This setting allows correcting positive and negative sequence currents for vector groups of power transformer...

Page 285: ...ds to be implemented using FlexLogic e USER TRIGGERING PATH SETTINGS SYSTEM SETUP PHASOR MEASUREMENT PMU 1 TRIGGERING PMU 1 USER TRIGGER The user trigger allows customized triggering logic to be constructed from FlexLogic The entire triggering logic is refreshed once every two power system cycles f FREQUENCY TRIGGERING PATH SETTINGS SYSTEM SETUP PHASOR MEASUREMENT PMU 1 TRIGGERING PMU 1 FREQUENCY ...

Page 286: ...as long as the trig gering condition is asserted Figure 5 47 FREQUENCY TRIGGER SCHEME LOGIC g VOLTAGE TRIGGERING PATH SETTINGS SYSTEM SETUP PHASOR MEASUREMENT PMU 1 TRIGGERING PMU 1 VOLTAGE TRIGGER PMU 1 VOLTAGE TRIGGER PMU 1 VOLT TRIGGER FUNCTION Disabled Range Enabled Disabled MESSAGE PMU 1 VOLT TRIGGER LOW VOLT 0 800 pu Range 0 250 to 1 250 pu in steps of 0 001 MESSAGE PMU 1 VOLT TRIGGER HIGH V...

Page 287: ...hen using the recorder in the forced mode recording as long as the trig gering condition is asserted Figure 5 48 VOLTAGE TRIGGER SCHEME LOGIC h CURRENT TRIGGERING PATH SETTINGS SYSTEM SETUP PHASOR MEASUREMENT PMU 1 TRIGGERING PMU 1 CURRENT TRIGGER This element responds to elevated current The trigger responds to the phase current signal of the phasor measurement unit PMU source All current channel...

Page 288: ...er 1 pu is a product of 1 pu voltage and 1 pu current or the product of nominal secondary voltage the VT ratio and the nominal primary current For the three phase power 1 pu is three times that for a single phase power The comparator applies a 3 hysteresis PMU 1 POWER TRIGGER PMU 1 POWER TRIGGER FUNCTION Disabled Range Enabled Disabled MESSAGE PMU 1 POWER TRIGGER ACTIVE 1 250 pu Range 0 250 to 3 0...

Page 289: ...IGGER PMU 1 df dt TRIGGER FUNCTION Disabled Range Enabled Disabled MESSAGE PMU 1 df dt TRIGGER RAISE 0 25 Hz s Range 0 10 to 15 00 Hz s in steps of 0 01 MESSAGE PMU 1 df dt TRIGGER FALL 0 25 Hz s Range 0 10 to 15 00 Hz s in steps of 0 01 MESSAGE PMU 1 df dt TRIGGER PKP TIME 0 10 s Range 0 00 to 600 00 s in steps of 0 01 MESSAGE PMU 1 df dt TRIGGER DPO TIME 1 00 s Range 0 00 to 600 00 s in steps of...

Page 290: ...ositive df dt The comparator applies a 4 hysteresis PMU 1 df dt TRIGGER FALL This setting specifies the pickup threshold for the rate of change of frequency in the fall ing direction negative df dt The comparator applies a 4 hysteresis PMU 1 df dt TRIGGER PKP TIME This setting could be used to filter out spurious conditions and avoid unnecessary triggering of the recorder PMU 1 df dt TRIGGER DPO T...

Page 291: ...ROCOF df dt SETTINGS PMU 1 df dt TRIGGER RAISE PMU 1 df dt TRIGGER FALL df dt RAISE OR df dt FALL RUN SETTINGS PMU 1 df dt TRIGGER DPO TIME 0 t DPO FLEXLOGIC OPERAND PMU 1 ROCOF TRIGGER FLEXLOGIC OPERANDS PMU 1 VOLT TRIGGER PMU 1 CURR TRIGGER PMU 1 POWER TRIGGER PMU 1 FREQ TRIGGER SETTING PMU 1 USER TRIGGER Off 0 FLEXLOGIC OPERAND PMU 1 TRIGGERED to STAT bits of the data frame 847012A1 CDR AND OR ...

Page 292: ...e record This setting applies only to the timed mode of recording l AGGREGATORS PATH SETTINGS SYSTEM SETUP PHASOR MEASUREMENT UNIT PMU AGGREGATOR 1 When the protocol selection is set via the software or keypad all aggregators whose protocol is not set to None will be set to the last protocol saved i e IEEE C37 118 or IEC 61850 90 5 to any aggregators as both IEEE C37 118 and IEC 61850 90 5 simulta...

Page 293: ...exLogic operands as shown in table 2 The operands are asserted for 5 seconds following reception of the command frame If the new command frame arrives within the 5 second period the FlexLogic operands are updated and the 5 second timer is re started This setting enables or disables the control When enabled all 16 oper ands for each aggregator are active when disabled all 16 operands for each aggre...

Page 294: ...rol is set by either toggling an assigned FlexLogic operand or a remote client write to start and stop the streaming of R SV frames If remote client control is disabled a negative response is pro vided to the client in response to a write attempt A FlexLogic operand SvEna is provided for each Aggregator that Table 5 13 OF ASDU SETTINGS FOR OF ASDU TRANSMISSION 1 ASDU at T0 current values 2 ASDU at...

Page 295: ...ue from 1 to 4294967295 MSVCB 1 PRIORITY A value from 0 through 7 The default value is 4 MSVCB 1 IP Class The value represents the IPv4 Differentiated Services formerly called TypeOfService value The default value is set for Expedited Forwarding 101110B 46 or 2EH This value provides priority routing when sup ported in the routers MSVCB 1 VID A range of values limited from 0 to 4095 MSVCB 1 APPID T...

Page 296: ...pplies to the other features that set flags elements virtual inputs remote inputs schemes and human operators If more complex logic than presented above is required it is implemented via FlexLogic For example if it is desired to have the closed state of contact input H7a and the operated state of the phase undervoltage element block the operation of the phase time overcurrent element the two contr...

Page 297: ... 1 ON IF Contact Input On Cont Ip On Voltage is presently applied to the input external contact closed Off Cont Ip Off Voltage is presently not applied to the input external contact open Contact Output type Form A contact only Current On Cont Op 1 Ion Current is flowing through the contact Voltage On Cont Op 1 VOn Voltage exists across the contact Voltage Off Cont Op 1 VOff Voltage does not exists...

Page 298: ...NTRL UV DPO Third harmonic neutral undervoltage element has picked up Third harmonic neutral undervoltage element has operated Third harmonic neutral undervoltage element has dropped out ELEMENT Accidental energization ACCDNT ENRG ARMED ACCDNT ENRG DPO ACCDNT ENRG OP The accidental energization element is armed The accidental energization element has dropped out The accidental energization element...

Page 299: ...n comparison value Counter 2 to 8 Same set of operands as shown for Counter 1 ELEMENT Digital elements Dig Element 1 PKP Dig Element 1 OP Dig Element 1 DPO Digital Element 1 is picked up Digital Element 1 is operated Digital Element 1 is dropped out Dig Element 2 to 48 Same set of operands as shown for Dig Element 1 ELEMENT Sensitive directional power DIR POWER 1 STG1 PKP DIR POWER 1 STG2 PKP DIR ...

Page 300: ...c 0 LATCH 2 to 16 Same set of operands as shown for LATCH 1 ELEMENT Loss of excitation LOSS EXCIT STG1 PKP LOSS EXCIT STG2 PKP LOSS EXCIT STG1 DPO LOSS EXCIT STG2 DPO LOSS EXCIT STG1 OP LOSS EXCIT STG2 OP LOSS EXCIT PKP LOSS EXCIT DPO LOSS EXCIT OP Stage 1 of the loss of excitation element has picked up Stage 2 of the loss of excitation element has picked up Stage 1 of the loss of excitation eleme...

Page 301: ... overcurrent 1 has operated All phases of phase instantaneous overcurrent 1 have dropped out Phase A of phase instantaneous overcurrent 1 has picked up Phase B of phase instantaneous overcurrent 1 has picked up Phase C of phase instantaneous overcurrent 1 has picked up Phase A of phase instantaneous overcurrent 1 has operated Phase B of phase instantaneous overcurrent 1 has operated Phase C of pha...

Page 302: ...sequence impedance in outer characteristic Positive sequence impedance in middle characteristic Positive sequence impedance in inner characteristic Power swing blocking element operated Power swing timer 2 picked up Power swing timer 3 picked up Power swing timer 4 picked up Out of step tripping operated The power swing element detected a disturbance other than power swing An unstable power swing ...

Page 303: ...OP SPLIT PHASE PKP SPLIT PHASE DPO Phase A of the split phase protection has picked up Phase A of the split phase protection has dropped out Phase A of the split phase protection has operated Phase B of the split phase protection has picked up Phase B of the split phase protection has dropped out Phase B of the split phase protection has operated Phase C of the split phase protection has picked up...

Page 304: ...ted Synchrocheck 1 in synchronization has dropped out Synchrocheck 1 close has operated Synchrocheck 1 close has dropped out Synchrocheck 1 V1 is above the minimum live voltage Synchrocheck 1 V1 is below the maximum dead voltage Synchrocheck 1 V2 is above the minimum live voltage Synchrocheck 1 V2 is below the maximum dead voltage SYNC 2 to 4 Same set of operands as shown for SYNC 1 ELEMENT Telepr...

Page 305: ...EMOTE INPUT 1 On REMOTE INPUT 2 On REMOTE INPUT 3 On REMOTE INPUT 32 On Flag is set logic 1 Flag is set logic 1 Flag is set logic 1 Flag is set logic 1 INPUTS OUTPUTS Virtual inputs Virt Ip 1 On Virt Ip 2 On Virt Ip 3 On Virt Ip 64 On Flag is set logic 1 Flag is set logic 1 Flag is set logic 1 Flag is set logic 1 INPUTS OUTPUTS Virtual outputs Virt Op 1 On Virt Op 2 On Virt Op 3 On Virt Op 96 On F...

Page 306: ...s descriptions in Chapter 7 Commands and Targets ANY MAJOR ERROR ANY MINOR ERROR ANY SELF TESTS BATTERY FAIL CLOCK UNSYNCHRONIZED DIRECT DEVICE OFF DIRECT RING BREAK EQUIPMENT MISMATCH FLEXLOGIC ERR TOKEN LATCHING OUT ERROR MAINTENANCE ALERT FIRST ETHERNET FAIL PROCESS BUS FAILURE PTP FAILURE REMOTE DEVICE OFF RRTD COMM FAIL SECOND ETHERNET FAIL THIRD ETHERNET FAIL SNTP FAILURE SYSTEM EXCEPTION TE...

Page 307: ...at generates a pulse in response to an edge on the input The output from a one shot is True positive for only one pass through the FlexLogic equation There is a maximum of 64 one shots NEGATIVE ONE SHOT One shot that responds to a negative going edge DUAL ONE SHOT One shot that responds to both the positive and negative going edges Logic gate NOT Logical NOT Operates on the previous parameter OR 2...

Page 308: ...o 96 can only be properly assigned once Figure 5 54 EXAMPLE LOGIC SCHEME 1 Inspect the example logic diagram to determine if the required logic can be implemented with the FlexLogic operators If this is not possible the logic must be altered until this condition is satisfied Once this is done count the inputs to each gate to verify that the number of inputs does not exceed the FlexLogic limits whi...

Page 309: ...ter at a time until the required logic is complete It is generally easier to start at the out put end of the equation and work back towards the input as shown in the following steps It is also recommended to list operator inputs from bottom to top For demonstration the final output will be arbitrarily identified as parameter 99 and each preceding parameter decremented by one in turn Until accustom...

Page 310: ...ume for this example the state is to be ON for a closed contact The operand is therefore Cont Ip H1c On 95 The last step in the procedure is to specify the upper input to the AND gate the operated state of digital element 2 This operand is DIG ELEM 2 OP Writing the parameters in numerical order can now form the equation for virtual output 3 95 DIG ELEM 2 OP 96 Cont Ip H1c On 97 NOT 98 AND 2 99 Vir...

Page 311: ...e lower input to the XOR is operand DIG ELEM 1 PKP 88 The upper input to the XOR is operand Virt Ip 1 On 87 The input just below the upper input to OR 1 is operand Virt Op 2 On 86 The upper input to OR 1 is operand Virt Op 1 On 85 The last parameter is used to set the latch and is operand Virt Op 4 On The equation for virtual output 4 is 85 Virt Op 4 On 86 Virt Op 1 On 87 Virt Op 2 On 88 Virt Ip 1...

Page 312: ...er 1 as arranged in the order shown below DIG ELEM 2 OP Cont Ip H1c On NOT AND 2 Virt Op 3 Virt Op 4 On Virt Op 1 On Virt Op 2 On Virt Ip 1 On DIG ELEM 1 PKP XOR 2 Virt Op 3 On OR 4 LATCH S R Virt Op 3 On TIMER 1 Cont Ip H1c On OR 3 TIMER 2 Virt Op 4 END In the expression above the virtual output 4 input to the four input OR is listed before it is created This is typical of a form of feedback in t...

Page 313: ...l never be set to 1 The key may be used when editing FlexLogic equations from the keypad to quickly scan through the major parameter types 5 5 6 FLEXLOGIC TIMERS PATH SETTINGS FLEXLOGIC FLEXLOGIC TIMERS FLEXLOGIC TIMER 1 32 There are 32 identical FlexLogic timers available These timers can be used as operators for FlexLogic equations TIMER 1 TYPE This setting is used to select the time measuring u...

Page 314: ...bled Enabled MESSAGE FLEXELEMENT 1 NAME FxE1 Range up to 6 alphanumeric characters MESSAGE FLEXELEMENT 1 IN Off Range Off any analog actual value parameter MESSAGE FLEXELEMENT 1 IN Off Range Off any analog actual value parameter MESSAGE FLEXELEMENT 1 INPUT MODE Signed Range Signed Absolute MESSAGE FLEXELEMENT 1 COMP MODE Level Range Level Delta MESSAGE FLEXELEMENT 1 DIRECTION Over Range Over Under...

Page 315: ...Sample applications for the Absolute setting include monitoring the angular difference between two phasors with a symmetrical limit angle in both directions monitoring power regardless of its direction or monitoring a trend regardless of whether the signal increases of decreases The element responds directly to its operating signal as defined by the FLEXELEMENT 1 IN FLEXELEMENT 1 IN and FLEX ELEME...

Page 316: ...1 PKP FLEXELEMENT DIRECTION Over PICKUP HYSTERESIS of PICKUP FlexElement 1 OpSig FLEXELEMENT 1 PKP FLEXELEMENT DIRECTION Under PICKUP HYSTERESIS of PICKUP 842705A1 CDR 842706A2 CDR FlexElement 1 OpSig FLEXELEMENT 1 PKP FLEXELEMENT DIRECTION Over FLEXELEMENT INPUT MODE Signed FlexElement 1 OpSig FLEXELEMENT 1 PKP FLEXELEMENT DIRECTION Over FLEXELEMENT INPUT MODE Absolute FlexElement 1 OpSig FLEXELE...

Page 317: ...GROUND RESISTANCE RBASE 250 KΩ FIELD VOLTAGE VBASE 500 V FREQUENCY fBASE 1 Hz FREQUENCY RATE OF CHANGE df dtBASE 1 Hz s PHASE ANGLE ϕBASE 360 degrees see the UR angle referencing convention POWER FACTOR PFBASE 1 00 RTDs BASE 100 C SENSITIVE DIR POWER Sns Dir Power PBASE maximum value of 3 VBASE IBASE for the IN and IN inputs of the sources configured for the sensitive power directional element s S...

Page 318: ... interface action resets the latch The settings element operation is described below LATCH 1 TYPE This setting characterizes Latch 1 to be Set or Reset dominant LATCH 1 SET If asserted the specified FlexLogic operands sets Latch 1 LATCH 1 RESET If asserted the specified FlexLogic operand resets Latch 1 Figure 5 64 NON VOLATILE LATCH OPERATION TABLE N 1 to 16 AND LOGIC LATCH 1 LATCH 1 FUNCTION Disa...

Page 319: ...this chap ter 5 6 2 SETTING GROUP PATH SETTINGS GROUPED ELEMENTS SETTING GROUP 1 6 Each of the six setting group menus is identical Setting group 1 the default active group automatically becomes active if no other group is active see the Control elements section for additional details SETTING GROUP 1 DISTANCE See page 5 160 MESSAGE POWER SWING DETECT See page 5 168 MESSAGE STATOR DIFFERENTIAL See ...

Page 320: ...ing the memory in effect for too long may eventually lead to incorrect operation of the distance functions The distance zones can be forced to become self polarized through the FORCE SELF POLAR setting Any user selected con dition FlexLogic operand can be configured to force self polarization When the selected operand is asserted logic 1 the distance functions become self polarized regardless of o...

Page 321: ...0 02 to 500 00 ohms in steps of 0 01 MESSAGE PHS DIST Z1 REV REACH RCA 85 Range 30 to 90 in steps of 1 MESSAGE PHS DIST Z1 COMP LIMIT 90 Range 30 to 90 in steps of 1 MESSAGE PHS DIST Z1 DIR RCA 85 Range 30 to 90 in steps of 1 MESSAGE PHS DIST Z1 DIR COMP LIMIT 90 Range 30 to 90 in steps of 1 MESSAGE PHS DIST Z1 SUPV 0 200 pu Range 0 050 to 30 000 pu in steps of 0 001 MESSAGE PHS DIST Z1 VOLT LEVEL...

Page 322: ...ce settings described earlier must be properly chosen for correct operation of the phase distance ele ments Additional details may be found in chapter 8 Theory of operation Ensure that the Phase VT Secondary Voltage setting see the SETTINGS SYSTEM SETUP AC INPUTS VOLTAGE BANK menu is set correctly to prevent improper operation of associated mem ory action PHS DIST Z1 DIR All phase distance zones a...

Page 323: ...and CTs could be located independently from one another at different windings of the transformer If the potential source is located at the correct side of the transformer this set ting shall be set to None 837802A1 CDR X R RCA COMP LIMIT R E V R E A C H R E A C H REV REACH RCA 837722A1 CDR X R R E A C H RCA 80o COMP LIMIT 90o DIR RCA 80o DIR COMP LIMIT 90o X R R E A C H RCA 80o COMP LIMIT 90o DIR ...

Page 324: ...erse reach impedance in non directional applications is set independently The reach impedance is entered in secondary ohms The reach impedance angle is entered as the PHS DIST Z1 RCA setting To achieve specified operating speed of distance elements the relay internally calculates source to line impedance ratio SIR from fault phasors In these calculations line impedance is estimated based on the zo...

Page 325: ...meet for remote faults at the end of zones 2 and above If this is the case the current supervision pickup would be set below the full load current but this may result in maloperation during fuse fail conditions PHS DIST Z1 VOLT LEVEL This setting is relevant for applications on series compensated lines or in general if series capacitors are located between the relaying point and a point where the ...

Page 326: ...tionality Figure 5 72 PHASE DISTANCE ZONES 3 AND HIGHER OP SCHEME 25 1 25 5 IURP WKH RSHQ SROH HOHPHQW DQG RQO 2 23 5 1 23 1 32 23 2 23 5 1 3 67 3 3 2 23 5 1 3 67 3 3 2 23 5 1 3 67 3 3 7 0 5 PV PV 7 0 5 PV PV 7 0 5 PV PV 6 77 1 3 67 73 3 6 77 1 3 67 73 3 6 77 1 3 67 73 3 2 23 5 1 3 67 23 2 23 5 1 3 67 23 2 23 5 1 3 67 23 2 23 5 1 3 67 23 2 23 5 1 75 3 3 705 1 7 25 25 25 1 25 1 25 1 1 1 IURP WKH WU...

Page 327: ...NECTION PH DIST Z1 REACH PH DIST Z1 RCA PH DIST Z1 REV REACH PH DIST Z1 REV REACH RCA PH DIST Z1 COMP LIMIT PH DIST Z1 QUAD RGT BLD PH DIST Z1 QUAD RGT BLD RCA PH DIST Z1 QUAD LFT BLD PH DIST Z1 QUAD LFT BLD RCA PH DIST Z1 VOLT LEVEL TIMER 1 cycle 1 cycle SETTING PHS DIST Z1 SUPV RUN IA IB 3 Pickup RUN IB IC 3 Pickup RUN IC IA 3 Pickup FLEXLOGIC OPERANDS PH DIST Z1 PKP AB PH DIST Z1 DPO AB FLEXLOG...

Page 328: ...A 75 Range 40 to 90 in steps of 1 MESSAGE POWER SWING REV REACH 50 00 Ω Range 0 10 to 500 00 ohms in steps of 0 01 MESSAGE POWER SWING QUAD REV REACH MID 60 00 Ω Range 0 10 to 500 00 ohms in steps of 0 01 MESSAGE POWER SWING QUAD REV REACH OUT 70 00 Ω Range 0 10 to 500 00 ohms in steps of 0 01 MESSAGE POWER SWING REV RCA 75 Range 40 to 90 in steps of 1 MESSAGE POWER SWING OUTER LIMIT ANGLE 120 Ran...

Page 329: ... develop an under standing of the operation of the element The power swing detect element operates in three step or two step mode Three step operation The power swing blocking sequence essentially times the passage of the locus of the positive sequence impedance between the outer and the middle characteristic boundaries If the locus enters the outer charac teristic indicated by the POWER SWING OUT...

Page 330: ... operand is set immediately and sealed in for the interval set by the POWER SWING SEAL IN DELAY If the Delayed trip mode is selected the element waits until the impedance locus leaves the inner characteristic then times out the POWER SWING PICKUP DELAY 2 and sets Latch 4 the element is now ready to trip The trip operand is set later when the impedance locus leaves the outer characteristic Two step...

Page 331: ...WING INNER POWER SWING TMR2 PKP POWER SWING TMR3 PKP and POWER SWING TMR4 PKP FlexLogic operands are auxiliary operands that could be used to facilitate testing and special applications The POWER SWING BLOCK FlexLogic operand shall be used to block selected protection elements such as distance functions 842734A1 CDR 842735A1 CDR R FWD RCA X INNER LFT BLD MIDDLE LFT BLD OUTER LFT BLD INNER RGT BLD ...

Page 332: ...th settings of the power swing timers The two step mode uses only the outer and inner characteristics for both blocking and tripping functions This leaves more space in heavily loaded systems to place two power swing characteristics between the distance characteristics and the maximum load but allows for only one determination of the impedance trajectory POWER SWING SUPV A common overcurrent picku...

Page 333: ...racteristics Set this value high if no blinder is required for the Mho characteristic POWER SWING PICKUP DELAY 1 All the coordinating timers are related to each other and should be set to detect the fastest expected power swing and produce out of step tripping in a secure manner The timers should be set in consideration to the power swing detect characteristics mode of power swing detect operation...

Page 334: ...s long as the element is enabled The blocking signal resets the output POWER SWING TRIP operand but does not stop the out of step tripping sequence Figure 5 77 POWER SWING DETECT SCHEME LOGIC 1 of 3 Figure 5 78 POWER SWING DETECT SCHEME LOGIC 2 of 3 FLEXLOGIC OPERAND FLEXLOGIC OPERAND FLEXLOGIC OPERAND SETTINGS SETTING SETTING SETTING POWER SWING QUAD FWD REACH OUT POWER SWING QUAD REV REACH OUT P...

Page 335: ...SETTING POWER SWING SEAL IN DELAY POWER SWING DELAY 1 RESET POWER SWING DELAY 1 PICKUP POWER SWING DELAY 2 PICKUP POWER SWING DELAY 3 PICKUP POWER SWING DELAY 4 PICKUP POWER SWING BLK Off 0 POWER SWING TRIP MODE POWER SWING MODE POWER SWING TRIP POWER SWING TMR2 PKP POWER SWING TMR4 PKP POWER SWING OUTGOING POWER SWING TMR3 PKP POWER SWING INCOMING POWER SWING BLOCK POWER SWING UN BLOCK POWER SWIN...

Page 336: ...ATOR DIFF FUNCTION Disabled Range Disabled Enabled MESSAGE STATOR DIFF LINE END SOURCE SRC 1 Range SRC 1 SRC 2 SRC 3 SRC 4 MESSAGE STATOR DIFF NEUTRAL END SOURCE SRC 1 Range SRC 1 SRC 2 SRC 3 SRC 4 MESSAGE STATOR DIFF PICKUP 0 100 pu Range 0 050 to 1 000 pu in steps of 0 001 MESSAGE STATOR DIFF SLOPE 1 10 Range 1 to 100 in steps of 1 MESSAGE STATOR DIFF BREAK 1 1 15 pu Range 1 00 to 1 50 pu in ste...

Page 337: ... CT mismatch error when operating at the maximum permitted current This maximum error is generally in the range of 5 to 10 of CT rating STATOR DIFF BREAK 1 This setting defines the end of the Slope 1 region and the start of the transition region It should be set just above the maximum normal operating current level of the machine STATOR DIFF SLOPE 2 This setting is applicable for restraint current...

Page 338: ...rithm returns to the NORMAL state if the differential current is below the first slope SL for more than 200 ms When in the EXTERNAL FAULT state the algorithm goes into the EXTERNAL FAULT CT SAT URATION state if the differential flag is set DIF 1 When in the EXTERNAL FAULT CT SATURATION state the algorithm keeps the saturation flag set SAT 1 The state machine returns to the EXTERNAL FAULT state if ...

Page 339: ...ent levels above pickup Time overcurrent time calculations are made with an internal energy capacity memory variable When this variable indi cates that the energy capacity has reached 100 a time overcurrent element will operate If less than 100 energy capac ity 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 red...

Page 340: ...82 9 522 3 647 2 002 1 297 0 927 0 709 0 569 0 474 0 407 2 0 45 363 19 043 7 293 4 003 2 593 1 855 1 418 1 139 0 948 0 813 4 0 90 727 38 087 14 587 8 007 5 187 3 710 2 837 2 277 1 897 1 626 6 0 136 090 57 130 21 880 12 010 7 780 5 564 4 255 3 416 2 845 2 439 8 0 181 454 76 174 29 174 16 014 10 374 7 419 5 674 4 555 3 794 3 252 10 0 226 817 95 217 36 467 20 017 12 967 9 274 7 092 5 693 4 742 4 065 ...

Page 341: ...4 280 3 837 3 528 3 297 3 116 2 971 IEC CURVE B 0 05 1 350 0 675 0 338 0 225 0 169 0 135 0 113 0 096 0 084 0 075 0 10 2 700 1 350 0 675 0 450 0 338 0 270 0 225 0 193 0 169 0 150 0 20 5 400 2 700 1 350 0 900 0 675 0 540 0 450 0 386 0 338 0 300 0 40 10 800 5 400 2 700 1 800 1 350 1 080 0 900 0 771 0 675 0 600 0 60 16 200 8 100 4 050 2 700 2 025 1 620 1 350 1 157 1 013 0 900 0 80 21 600 10 800 5 400 ...

Page 342: ...488 1 239 1 060 0 926 IAC VERY INVERSE 0 5 1 451 0 656 0 269 0 172 0 133 0 113 0 101 0 093 0 087 0 083 1 0 2 901 1 312 0 537 0 343 0 266 0 227 0 202 0 186 0 174 0 165 2 0 5 802 2 624 1 075 0 687 0 533 0 453 0 405 0 372 0 349 0 331 4 0 11 605 5 248 2 150 1 374 1 065 0 906 0 810 0 745 0 698 0 662 6 0 17 407 7 872 3 225 2 061 1 598 1 359 1 215 1 117 1 046 0 992 8 0 23 209 10 497 4 299 2 747 2 131 1 8...

Page 343: ... instanta neous to 600 00 seconds in steps of 10 ms EQ 5 14 EQ 5 15 where T Operate Time sec TDM Multiplier setting I Input Current Ipickup Pickup Current setting TRESET Reset Time in seconds assuming energy capacity is 100 and RESET Timed RECLOSER CURVES The G60 uses the FlexCurve feature to facilitate programming of 41 recloser curves Please refer to the FlexCurve section in this chapter for add...

Page 344: ...y reduced by a voltage restraint feature when enabled This is accom plished via the multipliers Mvr corresponding to the phase phase voltages of the voltage restraint characteristic curve see the figure below the pickup level is calculated as Mvr times the PHASE TOC1 PICKUP setting If the voltage restraint feature is disabled the pickup level always remains at the setting value PHASE TOC1 PHASE TO...

Page 345: ...BLOCK C PHASE TOC1 BLOCK B PHASE TOC1 VOLT RESTRAINT PHASE TOC1 A PKP PHASE TOC1 A DPO PHASE TOC1 A OP PHASE TOC1 B PKP PHASE TOC1 B DPO PHASE TOC1 B OP PHASE TOC1 C PKP PHASE TOC1 C DPO PHASE TOC1 C OP PHASE TOC1 PKP PHASE TOC1 OP PHASE TOC1 SOURCE PHASE TOC1 RESET PHASE TOC1 CURVE PHASE TOC1 PICKUP PHASE TOC1 INPUT IA Seq ABC Seq ACB Set Multiplier Set Multiplier Set Multiplier Set Pickup Multip...

Page 346: ...ps of 0 001 MESSAGE PHASE IOC1 PICKUP DELAY 0 00 s Range 0 00 to 600 00 s in steps of 0 01 MESSAGE PHASE IOC1 RESET DELAY 0 00 s Range 0 00 to 600 00 s in steps of 0 01 MESSAGE PHASE IOC1 BLOCK A Off Range FlexLogic operand MESSAGE PHASE IOC1 BLOCK B Off Range FlexLogic operand MESSAGE PHASE IOC1 BLOCK C Off Range FlexLogic operand MESSAGE PHASE IOC1 TARGET Self reset Range Self reset Latched Disa...

Page 347: ...r quadrature connection If there is a requirement to supervise overcurrent elements for flows in opposite directions such as can happen through a bus tie breaker two phase directional elements should be programmed with opposite element characteristic angle ECA settings PHASE DIRECTIONAL 1 PHASE DIR 1 FUNCTION Disabled Range Disabled Enabled MESSAGE PHASE DIR 1 SIGNAL SOURCE SRC 1 Range SRC 1 SRC 2...

Page 348: ...select the source for the operating and polarizing signals The operating current for the phase directional element is the phase current for the selected current source The polar izing voltage is the line voltage from the phase VTs based on the 90 or quadrature connection and shifted in the leading direction by the element characteristic angle ECA PHASE DIR 1 ECA This setting is used to select the ...

Page 349: ...FLEXLOGIC OPERAND FLEXLOGIC OPERAND FLEXLOGIC OPERAND FLEXLOGIC OPERAND SETTING SETTING SETTING SETTING SETTING SETTING PHASE DIR 1 FUNCTION PHASE DIR 1 SOURCE PHASE DIR 1 BLOCK OC WHEN V MEM EXP PHASE DIR 1 BLOCK PHASE DIR 1 ECA PHASE DIR 1 POL V THRESHOLD PH DIR1 BLK A PH DIR1 BLK B PH DIR1 BLK C PH DIR1 BLK IA No Seq ABC Seq ACB Yes VBC VCB 827078A7 CDR Off 0 V MINIMUM Use V when V Min Use V me...

Page 350: ...n taneous and the element is blocked the time accumulator will be cleared immediately Figure 5 89 NEUTRAL TIME OVERCURRENT 1 SCHEME LOGIC NEUTRAL TOC1 NEUTRAL TOC1 FUNCTION Disabled Range Disabled Enabled MESSAGE NEUTRAL TOC1 SIGNAL SOURCE SRC 1 Range SRC 1 SRC 2 SRC 3 SRC 4 MESSAGE NEUTRAL TOC1 INPUT Phasor Range Phasor RMS MESSAGE NEUTRAL TOC1 PICKUP 1 000 pu Range 0 000 to 30 000 pu in steps of...

Page 351: ...three phase faults The positive sequence restraint must be considered when testing for pickup accuracy and response time multiple of pickup The operating quantity depends on how test currents are injected into the relay single phase injection three phase pure zero sequence injection Figure 5 90 NEUTRAL IOC1 SCHEME LOGIC NEUTRAL IOC1 NEUTRAL IOC1 FUNCTION Disabled Range Disabled Enabled MESSAGE NEU...

Page 352: ...ty EQ 5 17 The positive sequence restraint allows for more sensitive settings by counterbalancing spurious zero sequence currents resulting from System unbalances under heavy load conditions NEUTRAL DIRECTIONAL OC1 NEUTRAL DIR OC1 FUNCTION Disabled Range Disabled Enabled MESSAGE NEUTRAL DIR OC1 SOURCE SRC 1 Range SRC 1 SRC 2 SRC 3 SRC 4 MESSAGE NEUTRAL DIR OC1 POLARIZING Voltage Range Voltage Curr...

Page 353: ...current The following tables define the neutral directional overcurrent element where ECA element characteristic angle and IG ground current When NEUTRAL DIR OC1 POL VOLT is set to Measured VX one third of this voltage is used in place of V_0 The following figure explains the usage of the voltage polarized directional unit of the element The figure below shows the voltage polarized phase angle com...

Page 354: ...e of ground current The ground current must be greater than 0 05 pu to be vali dated as a polarizing signal If the polarizing signal is not valid neither forward nor reverse indication is given In addition the zero sequence current I_0 must be greater than the PRODUCT SETUP DISPLAY PROPERTIES CURRENT CUT OFF LEVEL setting value For a choice of current polarizing it is recommended that the polarizi...

Page 355: ...ensated lines In regular applications the offset impedance ensures proper operation even if the zero sequence voltage at the relaying point is very small If this is the intent the offset impedance shall not be larger than the zero sequence impedance of the protected circuit Practically it shall be several times smaller The offset impedance shall be entered in secondary ohms NEUTRAL DIR OC1 FWD ECA...

Page 356: ...EUTRAL DIR OC1 POLARIZING NEUTRAL DIR OC1 BLK NEUTRAL DIR OC1 FWD LIMIT ANGLE NEUTRAL DIR OC1 FWD ECA NEUTRAL DIR OC1 REV LIMIT ANGLE NEUTRAL DIR OC1 OFFSET NEUTRAL DIR OC1 FWD PICKUP NEUTRAL DIR OC1 REV PICKUP NEUTRAL DIR OC1 OP CURR NEUTRAL DIR OC1 OP CURR NEUTRAL DIR OC1 FWD NEUTRAL DIR OC1 REV Measured VX Voltage Calculated V_0 Current Ground Crt IG Zero Seq Crt I_0 Dual Dual V Dual I NOTE 1 C...

Page 357: ...s from 0 02 to 46 times the CT rating This channel may be also equipped with a sensitive input The conversion range of a sensitive channel is from 0 002 to 4 6 times the CT rating Figure 5 93 GROUND TOC1 SCHEME LOGIC GROUND TOC1 GROUND TOC1 FUNCTION Disabled Range Disabled Enabled MESSAGE GROUND TOC1 SIGNAL SOURCE SRC 1 Range SRC 1 SRC 2 SRC 3 SRC 4 MESSAGE GROUND TOC1 INPUT Phasor Range Phasor RM...

Page 358: ...hannel is from 0 002 to 4 6 times the CT rating Figure 5 94 GROUND IOC1 SCHEME LOGIC GROUND IOC1 GROUND IOC1 FUNCTION Disabled Range Disabled Enabled MESSAGE GROUND IOC1 SIGNAL SOURCE SRC 1 Range SRC 1 SRC 2 SRC 3 SRC 4 MESSAGE GROUND IOC1 PICKUP 1 000 pu Range 0 000 to 30 000 pu in steps of 0 001 MESSAGE GROUND IOC1 PICKUP DELAY 0 00 s Range 0 00 to 600 00 s in steps of 0 01 MESSAGE GROUND IOC1 R...

Page 359: ... extends the coverage towards the neutral point see the RGF and Percent Differential Zones of Protection diagram Figure 5 95 RGF AND PERCENT DIFFERENTIAL ZONES OF PROTECTION This protection is often applied to transformers having impedance grounded wye windings The element may also be applied to the stator winding of a generator having the neutral point grounded with a CT installed in the groundin...

Page 360: ...ult must be approached with care and is not recommended unless the settings are carefully selected to avoid maloperation due to CT saturation The differential current is produced as an unbalance current between the ground current of the neutral CT IG and the neu tral current derived from the phase CTs IN IA IB IC EQ 5 18 The relay automatically matches the CT ratios between the phase and ground CT...

Page 361: ...tive sequence restraint is removed if the zero sequence component is greater than the positive sequence line 3 or set at the net difference of the two line 2 The raw restraining signal Irest is further post filtered for better performance during external faults with heavy CT satura tion and for better switch off transient control EQ 5 22 where k represents a present sample k 1 represents the previ...

Page 362: ...ng values I_0 0 033 pu 0 I_2 0 033 pu 0 and I_1 1 033 pu 0 Igd abs 3 0 0333 0 05 0 15 pu IR0 abs 3 0 033 0 05 0 05 pu IR2 3 0 033 0 10 pu IR1 1 033 8 0 1292 pu and Igr 0 1292 pu Despite very low fault current level the differential current is above 100 of the restraining current EXAMPLE 5 INTERNAL LOW CURRENT HIGH LOAD SINGLE LINE TO GROUND FAULT WITH NO FEED FROM THE GROUND Given the following in...

Page 363: ...g the element operating quantity EQ 5 23 The positive sequence restraint allows for more sensitive settings by counterbalancing spurious negative sequence and zero sequence currents resulting from System unbalances under heavy load conditions Transformation errors of current transformers CTs Fault inception and switch off transients NEG SEQ DIR OC1 NEG SEQ DIR OC1 FUNCTION Disabled Range Disabled ...

Page 364: ...ent Table 5 29 NEGATIVE SEQUENCE DIRECTIONAL OVERCURRENT UNIT Table 5 30 NEGATIVE SEQUENCE DIRECTIONAL UNIT The negative sequence voltage must be greater than the VOLTAGE CUTOFF LEVEL setting specified in the PRODUCT SETUP DISPLAY PROPERTIES menu to be validated for use as a polarizing signal If the polarizing signal is not validated neither forward nor reverse indication is given The following fi...

Page 365: ...ation on how to calculate this setting In regular applications the offset impedance ensures proper operation even if the negative sequence voltage at the relaying point is very small If this is the intent the offset impedance shall not be larger than the negative sequence impedance of the protected circuit Practically it is several times smaller The offset impedance is entered in secondary ohms Se...

Page 366: ...on this pickup threshold applies to zero or negative sequence current When selecting this setting it must be kept in mind that the design uses a positive sequence restraint technique Figure 5 99 NEGATIVE SEQUENCE DIRECTIONAL OC1 SCHEME LOGIC 827091A7 CDR AND AND AND AND AND OR OR NOTE V_2 is negative sequence voltage I_2 is negative sequence current I_0 is zero sequence current AND SETTING Off 0 B...

Page 367: ...ANSI C50 13 for details GEN UNBAL STG1 TMIN This is the minimum operate time of the stage 1 element The stage will not operate before this time expires This is set to prevent false trips for faults that would be cleared normally by system protections GEN UNBAL STG1 TMAX This is the maximum operate time of the stage 1 element This setting can be applied to limit the maximum tripping time for low le...

Page 368: ...TG2 PKP DELAY This is the minimum operate time of the stage 2 element This is set to prevent nui sance alarms during system faults Figure 5 100 GENERATOR UNBALANCE INVERSE TIME CURVES Figure 5 101 GENERATOR UNBALANCE SCHEME LOGIC 0 1 1 10 100 1000 0 01 0 1 1 10 100 830714A1 CDR Tmax K 1 K 4 K 15 K 40 K 100 Tmin SETTING SETTING SETTINGS SETTING SETTINGS SETTING FLEXLOGIC OPERANDS FLEXLOGIC OPERAND ...

Page 369: ... SRC 4 MESSAGE SPLIT PHASE LOAD SOURCE SRC 2 Range SRC 1 SRC 2 SRC 3 SRC 4 MESSAGE SPLIT PHASE A PICKUP 0 200 pu Range 0 020 to 1 500 pu in steps of 0 001 MESSAGE SPLIT PHASE A OFFSET 0 000 pu Range 0 000 to 1 000 pu in steps of 0 001 MESSAGE SPLIT PHASE A SLOPE 0 0 Range 0 0 to 100 in steps of 0 1 MESSAGE SPLIT PHASE B PICKUP 0 200 pu Range 0 020 to 1 500 pu in steps of 0 001 MESSAGE SPLIT PHASE ...

Page 370: ...t define the following parameters Isplit split phase current Iload load current pickup pickup setting min_load minimum load supervision setting Then the expected value of the steady state unbalance defined as bias current is expressed as follows EQ 5 24 where EQ 5 25 and offset is the split phase current at no load In Over mode the element will pickup if EQ 5 26 In Over under mode the element will...

Page 371: ...ng specifies a signal source used to provide current from the load CT to the split phase protection SPLIT PHASE A C PICKUP This setting specifies a pickup level for each phase This should be set less than the minimum expected unbalance split phase current due to an inter turn fault Isplit Ibias pickup and Iload min_load 830729A1 CDR Iload pu I splt phs pu Offset Slope Operate Operate Min Load Oper...

Page 372: ...timum value for this setting SPLIT PHASE MIN LOAD This setting specifies the minimum load positive sequence current supervision level SPLIT PHASE MODE This setting specifies the mode of operation If the Over mode is chosen the element will pickup when the split phase current is rises above the biased offset current plus the pickup setting If Over under mode is chosen the element will also pickup i...

Page 373: ...P SPLIT PHASE C OFFSET SPLIT PHASE C SLOPE SPLIT PHASE MIN LOAD SPLIT PHASE MODE SETTINGS t 0 SETTING SPLIT PHASE DELAY START SPLIT PHASE A PICKUP SPLIT PHASE A OFFSET SPLIT PHASE A SLOPE SPLIT PHASE MIN LOAD SPLIT PHASE MODE SETTINGS t 0 SETTING SPLIT PHASE DELAY t 0 SETTING SPLIT PHASE DELAY OR SPLIT PHASE DPO A FLEXLOGIC OPERANDS SPLIT PHASE PKP B SPLIT PHASE OP B SPLIT PHASE DPO B FLEXLOGIC OP...

Page 374: ...PICKUP 1 050 pu Range 0 001 to 30 000 pu in steps of 0 001 MESSAGE BF1 USE TIMER 1 Yes Range Yes No MESSAGE BF1 TIMER 1 PICKUP DELAY 0 000 s Range 0 000 to 65 535 s in steps of 0 001 MESSAGE BF1 USE TIMER 2 Yes Range Yes No MESSAGE BF1 TIMER 2 PICKUP DELAY 0 000 s Range 0 000 to 65 535 s in steps of 0 001 MESSAGE BF1 USE TIMER 3 Yes Range Yes No MESSAGE BF1 TIMER 3 PICKUP DELAY 0 000 s Range 0 000...

Page 375: ...of a current supervised initiate results in the breaker failure element not being initiated for a breaker that has very little or no current flowing through it which may be the case for trans former faults For those situations where it is required to maintain breaker fail coverage for fault levels below the BF1 PH AMP SUPV PICKUP or the BF1 N AMP SUPV PICKUP setting a current supervised initiate s...

Page 376: ...inserts an opening resistor into the faulted circuit to a lower level after resistor insertion The high set detector is enabled after timeout of timer 1 or 2 along with a timer that will enable the low set detector after its delay interval The delay interval between high set and low set is the expected breaker opening time Both current detectors provide a fast operating time for currents at small ...

Page 377: ... for three pole tripping schemes BF1 USE TIMER 1 If set to Yes the early path is operational BF1 TIMER 1 PICKUP DELAY Timer 1 is set to the shortest time required for breaker auxiliary contact Status 1 to open from the time the initial trip signal is applied to the breaker trip circuit plus a safety margin BF1 USE TIMER 2 If set to Yes the main path is operational BF1 TIMER 2 PICKUP DELAY Timer 2 ...

Page 378: ...oximately 90 of the resistor current This setting is valid only for three pole breaker failure schemes BF1 LOSET TIME DELAY Sets the pickup delay for current detection after opening resistor insertion BF1 TRIP DROPOUT DELAY This setting is used to set the period of time for which the trip output is sealed in This timer must be coordinated with the automatic reclosing scheme of the failed breaker t...

Page 379: ... single pole breaker failure logic sheet 1 0 Timer 2 Pickup Delay SETTING AND Use Timer 3 SETTINGS Yes 1 Breaker Pos 2 Phase A 3P Off 0 Breaker Pos 2 Phase B Off 0 Breaker Pos 2 Phase C Off 0 Breaker Test On Off 0 AND Initiated from single pole breaker failure logic sheet 1 0 Timer 3 Pickup Delay SETTING AND AND OR AND OR OR SETTING Phase Current HiSet Pickup RUN IA 0 LoSet Time Delay SETTING SETT...

Page 380: ...O SHEET 2 OF 2 Initiated TO SHEET 2 OF 2 827068 cdr BF1 FUNCTION Disable 0 Enable 1 SETTING BF1 BLOCK Off 0 SETTING BF1 INITIATE Off 0 SETTING BF1 USE SEAL IN YES 1 NO 0 SETTING BF1 USE AMP SUPV YES 1 NO 0 SETTING IA IB IN IC BF1 SOURCE SETTING IA PICKUP RUN BF1 PH AMP SUPV SETTINGS PICKUP BF1 N AMP SUPV PICKUP RUN RUN RUN IB PICKUP IC PICKUP IN PICKUP BKR FAIL 1 RETRIP FLEXLOGIC OPERAND ...

Page 381: ...CKUP SETTING AND SETTING BF1 TIMER1 PICKUP DELAY 0 SETTING AND SETTING NO 0 YES 1 BF1 USE TIMER 1 SETTING BKR FAIL 1 T2 OP FLEXLOGIC OPERAND FLEXLOGIC OPERAND NO 0 YES 1 BF1 USE TIMER 3 SETTING BF1 BKR POS2 A 3P Φ Off 0 SETTING BF1 BREAKER TEST ON Off 0 SETTING BF1 TIMER3 PICKUP DELAY 0 SETTING SETTINGS IB PICKUP IC PICKUP IN PICKUP BF1 LOSET TIME DELAY 0 SETTING RUN RUN IA PICKUP RUN BF1 N AMP LO...

Page 382: ...utput relay when the voltage falls below the specified voltage setting The undervoltage feature may also be used to block the functioning of other elements through the block feature of those elements Source Transfer Schemes In the event of an undervoltage a transfer signal may be generated to transfer a load from its normal source to a standby or emergency power source VOLTAGE ELEMENTS PHASE UNDER...

Page 383: ...0 seconds in steps of 0 01 The undervoltage elements can also be programmed to have an inverse time delay char acteristic The undervoltage delay setting defines the family of curves shown below EQ 5 28 where T operating time D undervoltage delay setting D 0 00 operates instantaneously V secondary voltage applied to the relay Vpickup pickup level Figure 5 111 INVERSE TIME UNDERVOLTAGE CURVES At 0 o...

Page 384: ...ound Phase to Phase MESSAGE PHASE UV1 PICKUP 1 000 pu Range 0 000 to 3 000 pu in steps of 0 001 MESSAGE PHASE UV1 CURVE Definite Time Range Definite Time Inverse Time MESSAGE PHASE UV1 DELAY 1 00 s Range 0 00 to 600 00 s in steps of 0 01 MESSAGE PHASE UV1 MINIMUM VOLTAGE 0 100 pu Range 0 000 to 3 000 pu in steps of 0 001 MESSAGE PHASE UV1 BLOCK Off Range FlexLogic operand MESSAGE PHASE UV1 TARGET ...

Page 385: ...RC 2 SRC 3 SRC 4 MESSAGE PHASE OV1 PICKUP 1 000 pu Range 0 000 to 3 000 pu in steps of 0 001 MESSAGE PHASE OV1 PICKUP DELAY 1 00 s Range 0 00 to 600 00 s in steps of 0 01 MESSAGE PHASE OV1 RESET DELAY 1 00 s Range 0 00 to 600 00 s in steps of 0 01 MESSAGE PHASE OV1 BLOCK Off Range FlexLogic Operand MESSAGE PHASE OV1 TARGET Self reset Range Self reset Latched Disabled MESSAGE PHASE OV1 EVENTS Disab...

Page 386: ...his element must be configured for a phase VT VT errors and normal voltage unbalance must be considered when setting this element This function requires the VTs to be wye connected Figure 5 114 NEUTRAL OVERVOLTAGE1 SCHEME LOGIC NEUTRAL OV1 NEUTRAL OV1 FUNCTION Disabled Range Disabled Enabled MESSAGE NEUTRAL OV1 SIGNAL SOURCE SRC 1 Range SRC 1 SRC 2 SRC 3 SRC 4 MESSAGE NEUTRAL OV1 PICKUP 0 300 pu R...

Page 387: ... SEQ OV1 SIGNAL SOURCE SRC 1 Range SRC 1 SRC 2 SRC 3 SRC 4 MESSAGE NEG SEQ OV1 PICKUP 0 300 pu Range 0 000 to 1 250 pu in steps of 0 001 MESSAGE NEG SEQ OV1 PICKUP DELAY 0 50 s Range 0 00 to 600 00 s in steps of 0 01 MESSAGE NEG SEQ OV1 RESET DELAY 0 50 s Range 0 00 to 600 00 s in steps of 0 01 MESSAGE NEG SEQ OV1 BLOCK Off Range FlexLogic operand MESSAGE NEG SEQ OV1 TARGET Self reset Range Self r...

Page 388: ...ristics The operating characteristics and equations for both definite and inverse time delay are as for the phase undervoltage element The element resets instantaneously The minimum voltage setting selects the operating voltage below which the element is blocked Figure 5 116 AUXILIARY UNDERVOLTAGE SCHEME LOGIC AUXILIARY UV1 AUX UV1 FUNCTION Disabled Range Disabled Enabled MESSAGE AUX UV1 SIGNAL SO...

Page 389: ...utral resistor Figure 5 117 AUXILIARY OVERVOLTAGE SCHEME LOGIC AUXILIARY OV1 AUX OV1 FUNCTION Disabled Range Disabled Enabled MESSAGE AUX OV1 SIGNAL SOURCE SRC 1 Range SRC 1 SRC 2 SRC 3 SRC 4 MESSAGE AUX OV1 PICKUP 0 300 pu Range 0 000 to 3 000 pu in steps of 0 001 MESSAGE AUX OV1 PICKUP DELAY 1 00 s Range 0 00 to 600 00 s in steps of 0 01 MESSAGE AUX OV1 RESET DELAY 1 00 s Range 0 00 to 600 00 s ...

Page 390: ...mode is set to Phase ground then the operating quantity for this element will be the phase to ground nominal volt age It is beneficial to use the phase to phase voltage mode for this element when the G60 device is applied on an iso lated or resistance grounded system 3 When the auxiliary voltage Vx is used regarding the condition for None phase voltage setting mentioned above then the 1 pu value i...

Page 391: ...ickup setting Instantaneous operation can be obtained the same way by setting the TD multiplier to 0 INVERSE CURVE A The curve for the volts hertz inverse curve A shape is derived from the formula EQ 5 29 where T Operating Time TDM Time Delay Multiplier delay in seconds V fundamental RMS value of voltage pu F frequency of voltage signal pu Pickup volts per hertz pickup setpoint pu The volts hertz ...

Page 392: ...tpoint pu The volts hertz inverse B curves are shown below Figure 5 120 VOLTS PER HERTZ CURVES INVERSE CURVE B INVERSE CURVE C The curve for the Volts Hertz Inverse Curve C shape is derived from the formula EQ 5 31 where T Operating Time TDM Time Delay Multiplier delay in sec V fundamental RMS value of voltage pu F frequency of voltage signal pu Pickup volts per hertz pickup setpoint pu T TDM V F ...

Page 393: ...0 ohm Range 0 10 to 300 00 ohms in steps of 0 01 MESSAGE EXCITATION V SUPV 1 Enabled Range Disabled Enabled MESSAGE LOSS OF EXCITATION PKP DELAY1 0 050 s Range 0 000 to 65 535 s in steps of 0 01 MESSAGE LOSS OF EXCITATION CENTER 2 12 00 ohm Range 0 10 to 300 00 ohms in steps of 0 01 MESSAGE LOSS OF EXCITATION RADIUS 2 10 00 ohm Range 0 10 to 300 00 ohms in steps of 0 01 MESSAGE LOSS OF EXCITATION ...

Page 394: ...ositive sequence impedance may momentarily enter the stage 2 characteristic For security of the function under such conditions it is recommended to delay stage 2 by a minimum of 0 5 seconds The LOSS OF EXCIT BLK setting specifies a FlexLogic operand for blocking the feature based on user programmable condi tions When the blocking input is asserted the element resets its timers de asserts the PKP a...

Page 395: ... Range Self reset Latched Disabled MESSAGE ACCDNT ENRG EVENTS Disabled Range Disabled Enabled LOSS OF EXCITATION FUNCTION LOSS EXCIT BLK SETTING SETTING Generator 1 Motor 1 Disabled 0 SETTING Enabled 0 Disabled 1 LOSS OF EXCITATION SOURCE SETTING I_1 V_1 Off 0 830001AB CDR LOSS OF EXCITATION CENTER 1 LOSS OF EXCITATION FUNCTION LOSS OF EXCITATION CENTER 2 LOSS OF EXCITATION PKP DELAY 1 LOSS OF EXC...

Page 396: ...ature does not de arm immediately but after a 250 ms time delay this will result in operation under imprecise synchronization The ACCDNT ENRG OC PICKUP setting can control the required precision of synchronization The UV and Off line value shall be made when the VTs are on the generator side of the disconnecting device If this is the case both the undervoltage and machine off line conditions are r...

Page 397: ...tive powers as measured per the UR series metering convention θ is a sum of the element characteristic DIR POWER 1 RCA and calibration DIR POWER 1 CALIBRATION angles and SMIN is the minimum operating power The operating quantity is displayed in the ACTUAL VALUES METERING SENSITIVE DIRECTIONAL POWER 1 2 actual value The element has two independent as to the pickup and delay settings stages for alar...

Page 398: ...ted in the figure below For example section a in the figure below shows settings for reverse power while section b shows settings for low forward power applications Figure 5 126 DIRECTIONAL POWER ELEMENT SAMPLE APPLICATIONS RESTRAIN SMIN RCA CALIBRATION OPERATE D i r e c t i o n Q P 842702A1 CDR P Q OPERATE RESTRAIN RCA 0o SMIN 0 d P Q OPERATE RESTRAIN RCA 180o SMIN 0 a P Q OPERATE RESTRAIN RCA 0o...

Page 399: ...strain region along the RCA line Refer to the Directional power sample applications figure for details Together with the RCA this setting enables a wide range of operating characteristics This setting applies to three phase power and is entered in per unit pu values The base quantity is 3 phase power on primary side which is calculated as x Phase CT Primary x Phase VT Ratio x Phase VT Secondary in...

Page 400: ...e voltages to measure the power at the machine terminals for power supervision Phase currents measured at the terminal of the machine shall be configured as phase CT banks The element uses the currents to measures the power at the machine terminals for power supervision Voltage measured at the neutral of the machine shall be configured as the auxiliary VT bank The element extracts the third harmon...

Page 401: ...e machine terminals This element requires wye connected VTs for measurement of the third harmonic in the zero sequence voltage at the generator output terminals Example 1 Operating quantities under normal conditions Consider the figure shown below In the case of a high impedance grounded machine the neutral resistor is typically cho sen such that power dissipated in the resistor during a single li...

Page 402: ...ies during a fault condition refer to example 2 for details Example 2 Operating quantities for a fault at a fraction k from the neutral grounding point For analysis consider the above figure and assume that In this case we have the magnitude of the neutral voltage at EQ 5 39 and the magnitude of the neutral and zero sequence voltages as 830737A1 CDR S Vn 3rd Va 3rd Vb 3rd Vc 3rd Pickup 3rd rd 3 rd...

Page 403: ...sidered for stages 1 and 2 as one of them could be used for alarm and the other for trip The safe value of this setting could be established after putting a given machine into ser vice and reading the quantity from the relay under ACTUAL VALUES menu Figure 5 129 100 STATOR GROUND SCHEME LOGIC V0 1 k E3 1 k E3 1 k E3 3 3 0 85 10 3 8 5 VN V0 8 5 1 5 10 VN V0 10 pu Pickup VN VN V0 1 5 10 0 15 pu Supe...

Page 404: ...ement shall not operate This setting applies to three phase power and is entered in pu The base quantity is 3 phase power on primary side which is calculated as x Phase CT Primary x Phase VT Ratio x Phase VT Secondary in case of delta connected VTs and 3 x Phase CT Primary x Phase VT Ratio x Phase VT Secondary in case of wye connected VTs For example a setting of 20 for a 200 MW machine is 0 20 20...

Page 405: ...RD HARM NTRL UV PKP 3RD HARM NTRL UV DPO Enabled 1 AND 3RD HARM NTRL UV BLK Off 0 SETTING SETTINGS SETTINGS SETTINGS 3RD HARM NTRL UV PICKUP RUN RUN Vaux Pickup 3 Phase Real Power V_1 AND 3RD HARM NTRL UV MAX POWER Min 3 Phase Power Max 3RD HARM NTRL UV MIN POWER SETTING Vaux 3rd harmonic STATOR GROUND SOURCE 3RD HARM NTRL UV PKP DELAY 20 ms 3RD HARM NTRL UV OP SETTINGS 3RD HARM NTRL UV VOLT SUPV ...

Page 406: ...njection transformer to the primary circuit The signal is of a low frequency in order to minimize the effects of the capacitance of the primary circuit A frequency of 20 Hz is chosen Referring to the following figure the admittance seen looking into the grounding transformer is EQ 5 42 In the above equation RG is the ground fault resistance CT is the total capacitance to ground N is the neutral gr...

Page 407: ...be present in a G60 if it were to be used for sub harmonic stator ground protection Accessory modules required for sub harmonic injection based stator ground protection 20 Hz injection module GE Multilin order code GPM S G Coupling filter GE Multilin order code GPM S B Current transformer GE order code 204 SD 43737 The following settings are available for the sub harmonic stator ground fault featu...

Page 408: ...ent primary voltage if used in primary A typical setting of 1 V is suggested However when the neutral grounding transformer s load resistance is less than 0 5 ohms the use of voltage supervision is not recommended SH STATOR GND Isupv The 20 Hz source can be monitored using this current supervision This setting in per unit values provides the current level below which if the sub harmonic current ph...

Page 409: ... the synchrocheck function rather than phase to ground voltages under applications where a single voltage is being connected to one of the auxiliary VT channels of G60 device 6 The current from the CT in the secondary of the NGT fed to the sensitive ground input of G60 shall only be used for sub harmonic based stator ground protection and not for any other protection element such as ground over cu...

Page 410: ...alue of RG is known it can be substituted into the VINJ equation above to determine VF2 If the VFLD voltage refer to the single point injection cir cuit is known through measurement then the location of the fault is simply VF2 VFLD This gives the location of the fault as percentage of field winding from negative terminal in case of single point injection If double point injection is used fault loc...

Page 411: ...ield winding for detecting ground faults The injection frequency selection will depend on the value of field winding capacitance to ground The following simple formula can be used to set the injection frequency when the field winding capacitance is known in μF EQ 5 46 FIELD GROUND FIELD GROUND FUNCTION Disabled Range Disabled Enabled MESSAGE FIELD GROUND INJECTION FREQUENCY 1 0 Hz Range 0 1 to 3 0...

Page 412: ...ded to the operating time of the element to obtain the overall delay FIELD GROUND STG2 PICKUP If the measured ground resistance is less than the value specified by this setting then the stage 2 element will pickup Normally stage 2 is used to raise trip signals and typical settings may fall in the range of 2 to 5 kΩ FIELD GROUND STG2 DELAY This setting specifies a time delay for stage 2 Typical set...

Page 413: ...n steps of 0 01 MESSAGE FIELD UNDER CURRENT PICKUP 0 20 pu Range 0 05 to 1 00 pu in steps of 0 01 MESSAGE FIELD UNDER CURRENT DELAY 1 00 s Range 0 00 to 600 00 s in steps of 0 01 MESSAGE FIELD CURRENT BLK Off Range FlexLogic operand MESSAGE FIELD CURRENT TARGET Self reset Range Self reset Latched Disabled MESSAGE FIELD CURRENT EVENTS Disabled Range Disabled Enabled GPM F failure SETTINGS Enabled F...

Page 414: ...ies the field current level above which the overcurrent element picks up FIELD OVER CURRENT DELAY This setting specifies a time delay for the overcurrent element This delay is added to the operating time of the element to obtain the overall delay FIELD UNDER CURRENT PICKUP This setting specifies the field current level above which the undercurrent ele ment picks up FIELD UNDER CURRENT DELAY This s...

Page 415: ...pecific protection or control protection element and checking the desired bus box Once the desired element is selected for a specific bus a list of element operate type operands are displayed and can be assigned to a trip bus If more than one operate type operand is required it may be assigned directly from the trip bus menu TRIP BUS 1 TRIP BUS 1 FUNCTION Disabled Range Enabled Disabled MESSAGE TR...

Page 416: ...RIP BUS 1 LATCHING This setting enables or disables latching of the trip bus output This is typically used when lockout is required or user acknowledgement of the relay response is required TRIP BUS 1 RESET The trip bus output is reset when the operand assigned to this setting is asserted Note that the RESET OP operand is pre wired to the reset gate of the latch As such a reset command the front p...

Page 417: ...tting Group shown as follows On power up or restart the previously selected 61850 SG Level x is re instated Similarly the input to the setting group control in the UR can be designed with Non Volatile latches to achieve the same effect The setting groups menu controls the activation and deactivation of up to six possible groups of settings in the GROUPED ELEMENTS settings menu The faceplate Settin...

Page 418: ...he SETTING GROUP 1 NAME to SETTING GROUP 6 NAME settings allows the user to assign a name to each of the six settings groups Once programmed this name appears on the second line of the GROUPED ELEMENTS SETTING GROUP 1 6 menu display The relay can be set up via a FlexLogic equation to receive requests to activate or de activate a particular non default set tings group The following FlexLogic equati...

Page 419: ...er cycles SELECTOR 1 FULL RANGE This setting defines the upper position of the selector When stepping up through avail able positions of the selector the upper position wraps up to the lower position position 1 When using a direct three bit control word for programming the selector to a desired position the change would take place only if the control word is within the range of 1 to the SELECTOR F...

Page 420: ...r does not accept the change and an alarm is established by setting the SELECTOR STP ALARM output FlexLogic operand for 3 seconds SELECTOR 1 ACK This setting specifies an acknowledging input for the stepping up control input The pre selected position is applied on the rising edge of the assigned operand This setting is active only under Acknowledge mode of operation The acknowledging signal must a...

Page 421: ... the selector synchronizes to the position dictated by the three bit control input This operation does not wait for time out or the acknowledging input When the synchronization attempt is unsuccessful that is the three bit input is not available 0 0 0 or out of range then the selector switch output is set to position 0 no output operand selected and an alarm is established SELECTOR 1 PWR ALARM The...

Page 422: ...ese diagrams T represents a time out setting Figure 5 140 TIME OUT MODE 842737A1 CDR STEP UP 3BIT A0 3BIT A1 3BIT A2 POS 1 POS 2 POS 3 POS 4 POS 5 POS 6 POS 7 BIT 0 BIT 1 BIT 2 pre existing position 2 changed to 4 with a pushbutton changed to 1 with a 3 bit input changed to 2 with a pushbutton T T T T changed to 7 with a 3 bit input STP ALARM BIT ALARM ALARM ...

Page 423: ... it should synchronize the setting group to the three bit control input Make the following changes to setting group control in the SETTINGS CONTROL ELEMENTS SETTING GROUPS menu SETTING GROUPS FUNCTION Enabled GROUP 4 ACTIVATE ON SELECTOR 1 POS 4 SETTING GROUPS BLK Off GROUP 5 ACTIVATE ON Off GROUP 2 ACTIVATE ON SELECTOR 1 POS 2 GROUP 6 ACTIVATE ON Off GROUP 3 ACTIVATE ON SELECTOR 1 POS 3 Make the ...

Page 424: ...owing changes in the SETTINGS PRODUCT SETUP USER PROGRAMMABLE PUSHBUTTONS USER PUSHBUTTON 1 menu PUSHBUTTON 1 FUNCTION Self reset PUSHBUTTON 1 DROP OUT TIME 0 10 s The logic for the selector switch is shown below Figure 5 142 SELECTOR SWITCH LOGIC 842012A2 CDR step up acknowledge 3 bit position out ON FLEXLOGIC OPERANDS SELECTOR 1 POS 1 SELECTOR 1 POS 2 SELECTOR 1 POS 3 SELECTOR 1 POS 4 SELECTOR 1...

Page 425: ...rameter below the minimum voltage current setting The UNDERFREQ 1 MIN VOLT AMP setting selects the minimum per unit voltage or current level required to allow the underfre quency element to operate This threshold is used to prevent an incorrect operation because there is no signal to measure This UNDERFREQ 1 PICKUP setting is used to select the level at which the underfrequency element is to picku...

Page 426: ...The overfrequency element can be used to control the turbine frequency ramp down at a generating location This element can also be used for feeder reclosing as part of the after load shedding restoration The OVERFREQ 1 SOURCE setting selects the source for the signal to be measured The OVERFREQ 1 PICKUP setting selects the level at which the overfrequency element is to pickup Figure 5 144 OVERFREQ...

Page 427: ...uence voltage Overvoltage supervision should be used to pre vent operation under specific system conditions such as faults FREQ RATE 1 OC SUPV PICKUP This setting defines minimum current level required for operation of the element The supervising function responds to the positive sequence current Typical application includes load shedding Set the pickup threshold to zero if no overcurrent supervis...

Page 428: ...ut only if the frequency is already below certain level such as for load shedding this setting should be set to the required frequency level If the signal source assigned to the frequency rate of change element is only set to auxiliary VT then the minimum voltage supervision is 3 V Figure 5 145 FREQUENCY RATE OF CHANGE SCHEME LOGIC NOTE V_1 PICKUP FREQ RATE 1 BLOCK Off RUN FREQ RATE 1 SOURCE Pos s...

Page 429: ...e accumulation may be blocked during an out of service condition as set via an input to the relay The following settings are available and apply to all accumulators FREQ OOB ACCUM SOURCE This setting selects the source for the signal to be measured The element first checks for a live phase voltage available from the selected source If voltage is not available the element attempts to use a phase cu...

Page 430: ...urbine is known to start accumulation at a user specified value Figure 5 146 FREQUENCY OUT OF BAND ACCUMULATION LOGIC FREQUENCY OOB ACCUMULATOR 1 FREQ ACCUM 1 FUNCTION Disabled Range Enabled Disabled MESSAGE FREQ ACCUM 1 UPPER FREQ 60 00 Hz Range 20 00 to 70 00 Hz in steps of 0 01 MESSAGE FREQ ACCUM 1 LOWER FREQ 60 00 Hz Range 20 00 to 70 00 Hz in steps of 0 01 MESSAGE FREQ ACCUM 1 TIME LIMIT 200 ...

Page 431: ... equal to 2 ΔΦ at a frequency equal to the frequency difference ΔF This time can be calculated by EQ 5 47 SYNCHROCHECK 1 SYNCHK1 FUNCTION Disabled Range Disabled Enabled MESSAGE SYNCHK1 BLOCK Off Range FlexLogic operand MESSAGE SYNCHK1 V1 SOURCE SRC 1 Range SRC 1 SRC 2 SRC 3 SRC 4 MESSAGE SYNCHK1 V2 SOURCE SRC 2 Range SRC 1 SRC 2 SRC 3 SRC 4 MESSAGE SYNCHK1 MAX VOLT DIFF 10000 V Range 0 to 400000 ...

Page 432: ...AD SOURCE SELECT This setting selects the combination of dead and live sources that will by pass synchronism check function and permit the breaker to be closed when one or both of the two voltages V1 or and V2 are below the maximum voltage threshold A dead or live source is declared by monitoring the voltage level Six options are available None Dead Source function is disabled LV1 and DV2 Live V1 ...

Page 433: ... with both phase voltages and an auxiliary voltage ensure that only the auxiliary voltage is programmed in one of the sources to be used for synchrocheck Exception Synchronism cannot be checked between Delta connected phase VTs and a Wye connected auxil iary voltage 2 The relay measures frequency and Volts Hz from an input on a given source with priorities as established by the con figuration of i...

Page 434: ... SETTINGS ΔF Maximum Max Freq Diff Freq Hysteresis SETTING ΔΦ Maximum Max Angle Diff SETTING ΔV Maximum Max Volt Diff AND OR XOR AND AND AND AND AND 827076AD CDR ACTUAL VALUES Synchrocheck 1 ΔV Synchrocheck 1 ΔΦ Synchrocheck 1 ΔF AND SETTINGS Enabled 1 Function Off 0 Block AND AND AND AND FLEXLOGIC OPERAND SYNC1 V2 ABOVE MIN SYNC1 V1 ABOVE MIN SYNC1 V1 BELOW MAX SYNC1 V2 BELOW MAX FLEXLOGIC OPERAN...

Page 435: ...the following example Figure 5 148 SYNCHROCHECK APPLIED ACROSS A TRANSFORMER In this example the phase voltage VT input is programmed as Delta with a secondary setting of 120 volts and a ratio of 13800 V 120 V 115 The auxiliary VT connection is selected to be VAB since this vector is in phase with VA on the trans former primary The secondary setting is 69 volts and the auxiliary VT ratio is calcul...

Page 436: ... for pickup and reset delays for the output operand DIGITAL ELEMENT 1 INPUT Selects a FlexLogic operand to be monitored by the digital element DIGITAL ELEMENT 1 PICKUP DELAY Sets the required time delay from element pickup to element operation If a pickup delay is not required set to 0 To avoid nuisance alarms set the delay greater than the operating time of the breaker DIGITAL ELEMENT 1 RESET DEL...

Page 437: ...ons it is desired to monitor the breaker trip circuit integrity so problems can be detected before a trip oper ation is required The circuit is considered to be healthy when the voltage monitor connected across the trip output contact detects a low level of current well below the operating current of the breaker trip coil If the circuit presents a high resis tance the trickle current will fall bel...

Page 438: ... continuously independent of the breaker position open or closed a method to maintain the monitoring current flow through the trip circuit when the breaker is open must be provided as shown in the fig ure below This can be achieved by connecting a suitable resistor see figure below across the auxiliary contact in the trip circuit In this case it is not required to supervise the monitoring circuit ...

Page 439: ...perands are provided to indicate if the present value is more than HI equal to EQL or less than LO the set value COUNTER 1 UP Selects the FlexLogic operand for incrementing the counter If an enabled UP input is received when the accumulated value is at the limit of 2 147 483 647 counts the counter will rollover to 2 147 483 648 COUNTER 1 DOWN Selects the FlexLogic operand for decrementing the coun...

Page 440: ... for capturing freezing the accumulated count value into a separate register with the date and time of the operation and resetting the count to 0 COUNTER 1 FREEZE COUNT Selects the FlexLogic operand for capturing freezing the accumulated count value into a separate register with the date and time of the operation and continuing counting The present accumulated value and captured frozen value with ...

Page 441: ...ORING ELEMENTS MONITORING ELEMENTS BREAKER FLASHOVER 1 See below MESSAGE BREAKER FLASHOVER 2 See below MESSAGE CT FAILURE DETECTOR See page 5 286 MESSAGE VT FUSE FAILURE 1 See page 5 287 MESSAGE VT FUSE FAILURE 2 See page 5 287 MESSAGE VT FUSE FAILURE 3 See page 5 287 MESSAGE VT FUSE FAILURE 4 See page 5 287 MESSAGE THERMAL OVERLOAD PROTECTION See page 5 289 ...

Page 442: ...one SRC 1 SRC 2 SRC 3 SRC 4 MESSAGE BKR 1 STATUS CLSD A Off Range FlexLogic operand MESSAGE BKR 1 STATUS CLSD B Off Range FlexLogic operand MESSAGE BKR 1 STATUS CLSD C Off Range FlexLogic operand MESSAGE BKR 1 FLSHOVR V PKP 0 850 pu Range 0 000 to 1 500 pu in steps of 0 001 MESSAGE BKR 1 FLSHOVR DIFF V PKP 1000 V Range 0 to 100000 V in steps of 1 MESSAGE BKR 1 FLSHOVR AMP PKP 0 600 pu Range 0 000 ...

Page 443: ...s prior to flashover detection are 1 52a status 0 2 VAg VBg or VCg is greater than the pickup setting 3 IA IB IC 0 no current flows through the breaker 4 ΔVA is greater than pickup not applicable in this scheme The conditions at flashover detection are 1 52a status 0 2 IA IB or IC is greater than the pickup current flowing through the breaker 3 ΔVA is greater than pickup not applicable in this sch...

Page 444: ...BRK 1 STATUS CLSD A to BRK 1 STATUS CLSD C These settings specify FlexLogic operands to indicate the open status of the breaker A separate FlexLogic operand can be selected to detect individual breaker pole status and pro vide flashover detection The recommended setting is 52a breaker contact or another operand defining the breaker poles open status BRK 1 FLSHOVR V PKP This setting specifies a pic...

Page 445: ... FLSHOVR OP BRK 1 FLSHOVR PKP BRK 1 FLSHOVR DPO BRK 1 FLSHOVR OP A BRK 1 FLSHOVR DPO B BRK 1 FLSHOVR PKP B BRK 1 FLSHOVR OP B BRK 1 FLSHOVR DPO C BRK 1 FLSHOVR PKP C BRK 1 FLSHOVR OP C BRK 1 FLSHOVR SUPV A BRK 1 STATUS CLSD B BRK 1 FLSHOVR SUPV B BRK 1 STATUS CLSD C BRK 1 FLSHOVR SUPV C BRK 1 FLSHOVR AMP PKP BRK 1 FLSHOVR DIFF V PKP BRK 1 FLSHOVR SIDE 1 SRC BRK 1 FLSHOVR SIDE 2 SRC Enable 1 RUN RU...

Page 446: ...resenting operation of some remote current protection elements via communication chan nels can also be chosen CT FAIL 3I0 INPUT 1 This setting selects the current source for input 1 The most critical protection element should also be assigned to the same source CT FAIL 3I0 INPUT 1 PICKUP This setting selects the 3I_0 pickup value for input 1 the main supervised CT source CT FAIL 3I0 INPUT 2 This s...

Page 447: ...so rapid decrease in the phase voltages magnitude from a healthy voltage level without disturbance in current can indicate a VT fuse fail conditions These noted indications of fuse failure can also be present when faults are present on the system so a means of detecting faults and inhibiting fuse failure decla rations during these events is provided Once the fuse failure condition is declared it i...

Page 448: ...AND SET RESET Reset dominant Latch AND AND AND AND OR OR OR OR Function SETTING Enabled 1 SOURCE 1 V_2 V_1 I_1 Run V_1 0 05 pu Run V_2 0 1 pu Run I_1 0 075 pu Run V_1 0 80 pu Run I_1 0 05 pu SRC1 50DD OP FLEXLOGIC OPERANDS 2 cycles 20 cycles SRC1 VT FUSE FAIL OP FLEXLOGIC OPERANDS SRC1 VT FUSE FAIL DPO SRC1 VT FUSE FAIL VOL LOSS FLEXLOGIC OPERAND TIMER OPEN POLE OP The OPEN POLE OP operand applies...

Page 449: ...on trip time constant I measured overload RMS current Ip measured load RMS current before overload occurs k IEC 255 8 k factor applied to IB defining maximum permissible current above nominal current IB protected element base nominal current THERMAL PROTECTION 1 THERMAL PROTECTION 1 FUNCTION Disabled Range Disabled Enabled MESSAGE THERMAL PROTECTION 1 SOURCE SRC1 Range SRC 1 SRC 2 SRC 3 SRC 4 MESS...

Page 450: ...n trip time constant Tmin is a minimum reset time setting Figure 5 156 IEC 255 8 SAMPLE OPERATE AND RESET CURVES The thermal overload protection element estimates accumulated thermal energy E using the following equations calculated each power cycle When current is greater than the pickup level In k IB element starts increasing the thermal energy EQ 5 51 When current is less than the dropout level...

Page 451: ...cumulated energy reaches value 1 in any phase the thermal overload protection element operates and only resets when energy is less than 0 05 in all three phases The logic for the thermal overload protection element is shown below Figure 5 157 THERMAL OVERLOAD PROTECTION SCHEME LOGIC Table 5 33 TYPICAL TIME CONSTANTS PROTECTED EQUIPMENT TIME CONSTANT MINIMUM RESET TIME Capacitor bank 10 minutes 30 ...

Page 452: ...er settable debounce time in order for the G60 to validate the new contact state In the figure below the debounce time is set at 2 5 ms thus the 6th sample in a row validates the change of state mark no 1 in the diagram Once validated de bounced the contact input asserts a corresponding FlexLogic operand and logs an event as per user setting A time stamp of the first sample in the sequence that va...

Page 453: ...filter the LOW HIGH marks no 1 2 3 and 4 in the figure below and HIGH LOW marks no 5 6 7 and 8 below transitions Figure 5 158 INPUT CONTACT DEBOUNCING MECHANISM AND TIME STAMPING SAMPLE TIMING Contact inputs are isolated in groups of four to allow connection of wet contacts from different voltage sources for each group The CONTACT INPUT THRESHOLDS determine the minimum voltage required to detect a...

Page 454: ...ut operand will be set to on for only one evaluation of the FlexLogic equations and then return to off If set to Latched the virtual input sets the state of the output operand to the same state as the most recent received input The self reset operating mode generates the output operand for a single evaluation of the FlexLogic equations If the operand is to be used anywhere other than internally in...

Page 455: ...t damage to the less robust initiating contact This can be done by monitoring an auxiliary contact on the breaker which opens when the breaker has tripped but this scheme is subject to incorrect oper ation caused by differences in timing between breaker auxiliary contact change of state and interruption of current in the trip circuit The most dependable protection of the initiating contact is prov...

Page 456: ...pecifies the contact response under conflicting control inputs that is when both the OPERATE and RESET signals are applied With both control inputs applied simultaneously the contact will close if set to Operate dominant and will open if set to Reset dominant Application Example 1 A latching output contact H1a is to be controlled from two user programmable pushbuttons buttons number 1 and 2 The fo...

Page 457: ...ista UR Setup example shown Program the Latching Outputs by making the following changes in the SETTINGS INPUTS OUTPUTS CONTACT OUT PUTS CONTACT OUTPUT H1a menu assuming an H4L module OUTPUT H1a OPERATE VO1 OUTPUT H1a RESET VO2 5 8 4 VIRTUAL OUTPUTS PATH SETTINGS INPUTS OUTPUTS VIRTUAL OUTPUTS VIRTUAL OUTPUT 1 96 There are 96 virtual outputs that may be assigned via FlexLogic If not assigned the o...

Page 458: ...n includes features that are used to cope with the loss of communication between transmitting and receiving devices Each transmitting device will send a GSSE GOOSE message upon a successful power up when the state of any included point changes or after a specified interval the default update time if a change of state has not occurred The transmitting device also sends a hold time which is set grea...

Page 459: ...eceiving relay are extracted from GSSE GOOSE messages originat ing in remote devices Each remote input can be selected from a list consisting of DNA 1 through DNA 32 UserSt 1 through UserSt 32 and Dataset Item 1 through Dataset Item 32 The function of DNA inputs is defined in the IEC 61850 specification and is presented in the IEC 61850 DNA Assignments table in the Remote outputs section The funct...

Page 460: ...with the five remote double point status input settings REM DPS IN 1 ID This setting assigns descriptive text to the remote double point status input REM DPS IN 1 DEV This setting selects a remote device ID to indicate the origin of a GOOSE message The range is selected from the remote device IDs specified in the Remote devices section REM DPS IN 1 ITEM This setting specifies the required bits of ...

Page 461: ... LED event indicators and the target message on the display Once set the latching mechanism will hold all of the latched indicators or messages in the set state after the initiating condition has cleared until a RESET command is received to return these latches not including FlexLogic latches to the reset state The RESET command can be sent from the faceplate Reset button a remote device via a com...

Page 462: ...t communication exchange the input will default to Logic 1 When communication resumes the input becomes fully operational Setting DIRECT INPUT 1 DEFAULT STATE to Latest Off freezes the input in case of lost communications If the latest state is not known such as after relay power up but before the first communication exchange the input will default to Logic 0 When communication resumes the input b...

Page 463: ...gnal from downstream devices say 2 3 and 4 to the upstream device that monitors a single incomer of the busbar as shown in the figure below Figure 5 161 SAMPLE INTERLOCKING BUSBAR PROTECTION SCHEME Assume that Phase Instantaneous Overcurrent 1 is used by Devices 2 3 and 4 to block Device 1 If not blocked Device 1 would trip the bus upon detecting a fault and applying a short coordination time dela...

Page 464: ...rchitecture shown below The scheme output operand HYB POTT TX1 is used to key the permission Figure 5 163 SINGLE CHANNEL OPEN LOOP CONFIGURATION In the above architecture Devices 1 and 3 do not communicate directly Therefore Device 2 must act as a bridge The fol lowing settings should be applied UR IED 1 DIRECT OUT 2 OPERAND HYB POTT TX1 DIRECT INPUT 5 DEVICE ID 2 DIRECT INPUT 5 BIT NUMBER 2 this ...

Page 465: ...xLogic operands to be sent via the selected communications channel This allows the user to create distributed protec tion and control schemes via dedicated communications channels Some examples are directional comparison pilot schemes and direct transfer tripping It should be noted that failures of communications channels will affect teleprotection functionality The teleprotection function must be...

Page 466: ...tputs is dependent on the number of com munication channels and terminals On two terminal two channel systems they are processed continuously on each chan nel and mapped separately per channel Therefore to achieve redundancy the user must assign the same operand on both channels teleprotection outputs at the sending end or corresponding teleprotection inputs at the receiving end On three terminal ...

Page 467: ...t values with no units The GOOSE UNIT and PU base settings allow the user to configure GOOSE Analog so that it can be used in a FlexElement GOOSE ANALOG INPUT 1 ANALOG 1 DEFAULT 1000 000 Range 1000000 000 to 1000000 000 in steps of 0 001 MESSAGE ANALOG 1 DEFAULT MODE Default Value Range Default Value Last Known MESSAGE GOOSE ANALOG 1 UNITS Range up to 4 alphanumeric characters MESSAGE GOOSE ANALOG...

Page 468: ...GOOSE ANALOG INPUT BASE UNITS ELEMENT BASE UNITS DCmA BASE maximum value of the DCMA INPUT MAX setting for the two transducers configured under the IN and IN inputs FREQUENCY fBASE 1 Hz FREQUENCY RATE OF CHANGE df dtBASE 1 Hz s PHASE ANGLE ϕBASE 360 degrees see the UR angle referencing convention POWER FACTOR PFBASE 1 00 RTDs BASE 100 C SENSITIVE DIR POWER Sns Dir Power PBASE maximum value of 3 VB...

Page 469: ...as a 32 bit unsigned integer number UINTEGER 1 DEFAULT MODE When the sending device is offline and this setting is Last Known the value of the GOOSE uinteger input remains at the last received value When the sending device is offline and this setting value is Default Value then the value of the GOOSE uinteger input is defined by the UINTEGER 1 DEFAULT setting The GOOSE integer input FlexInteger va...

Page 470: ...re automatically generated for every channel available in the specific relay as shown above for the first channel of a type 5F transducer module installed in slot H The function of the channel may be either Enabled or Disabled If Disabled no actual values are created for the chan nel An alphanumeric ID is assigned to each channel this ID will be included in the channel actual value along with the ...

Page 471: ... function of the channel may be either Enabled or Disabled If set to Disabled there will not be an actual value created for the channel RTD INPUT H1 ID An alphanumeric ID is assigned to the channel This ID will be included in the channel actual val ues It is also used to reference the channel as the input parameter to features designed to measure this type of parameter RTD INPUT H1 RTD INPUT H1 FU...

Page 472: ... RTD INPUT H1 TRIP TEMPERATURE This setting specifies the temperature pickup level for the trip stage RTD INPUT H1 TRIP PKP DELAY This setting specifies time delay for the trip stage until the output can be asserted Table 5 36 RTD TEMPERATURE VS RESISTANCE TEMPERATURE RESISTANCE IN OHMS C F 100 OHM PT DIN 43760 120 OHM NI 100 OHM NI 10 OHM CU 50 58 80 31 86 17 71 81 7 10 40 40 84 27 92 76 77 30 7 ...

Page 473: ...D operation when a broken sensor is detected If targets are enabled a message will appear on the display identifying the broken RTD If this feature is used it is rec ommended that the alarm be programmed as latched so that intermittent RTDs are detected and corrective action may be taken RTD INPUT H1 BLOCK This setting is used to block RTD operation Figure 5 166 RTD INPUT PROTECTION LOGIC 5 9 3 RR...

Page 474: ...ing rules are followed If the RRTD 1 FUNCTION setting is Enabled then the RRTD 1 APPLICATION setting value will be written to RRTD device If the RRTD 1 FUNCTION setting is Disabled then RRTD1 APPLICATION setting value is set as None If the RRTD 1 APPLICATION or RRTD 1 TYPE settings are changes then these settings are immediately written to the RRTD device RRTD 1 RRTD 1 FUNCTION Disabled Range Disa...

Page 475: ...ype Four different RTD types are available 100 Ω Nickel 10 Ω Copper 100 Ω Platinum and 120 Ω Nickel The RRTD converts resistance to temperature as per the values in the following table The G60 reads the RTD temper atures from the RRTD once every five seconds and applies protection accordingly The RRTDs can be used to provide RTD bias in the existing thermal model An RRTD open condition is detected...

Page 476: ...he range of the RRTD unit RRTD 1 TRIP PKP DELAY This setting specifies time delay for the trip stage until the output can be asserted The range of 5 to 600 seconds differs from the existing RTD settings to correspond to the range of the RRTD unit RRTD 1 TRIP RST DELAY This setting specifies the reset delay to seal in the trip signal RRTD 1 TRIP VOTING This setting allows securing trip signal by vo...

Page 477: ...ecks the driving signal x in equations below for the minimum and maximum limits and subsequently re scales so the limits defined as MIN VAL and MAX VAL match the output range of the hardware defined as RANGE The follow ing equation is applied EQ 5 53 DCMA OUTPUT H1 DCMA OUTPUT H1 SOURCE Off Range Off any analog actual value parameter MESSAGE DCMA OUTPUT H1 RANGE 1 to 1 mA Range 1 to 1 mA 0 to 1 mA...

Page 478: ...t current The setting is entered in per unit values The base units are defined in the same manner as the FlexElement base units DCMA OUTPUT H1 MAX VAL This setting allows setting the maximum limit for the signal that drives the output This setting is used to control the mapping between an internal analog value and the output current The setting is entered in per unit values The base units are defi...

Page 479: ...onal details is EQ 5 60 The minimum and maximum power values to be monitored in pu are EQ 5 61 The following settings should be entered DCMA OUTPUT H2 SOURCE SRC 1 Ia RMS DCMA OUTPUT H2 RANGE 4 to 20 mA DCMA OUTPUT H2 MIN VAL 0 000 pu DCMA OUTPUT H2 MAX VAL 1 260 pu The worst case error for this application could be calculated by superimposing the following two sources of error 0 5 of the full sca...

Page 480: ...if the VTs are connected in Delta refer to the Metering conventions section in chapter 6 while at the same time the VT nominal voltage is 1 pu for the settings Consequently the settings required in this example differ from naturally expected by the factor of The worst case error for this application could be calculated by superimposing the following two sources of error 0 5 of the full scale for t...

Page 481: ...ns based inputs and outputs remain fully operational in test mode If a control action is programmed using direct inputs and outputs or remote inputs and outputs then the test procedure must take this into account When in Forcible mode the operand selected by the TEST MODE FORCING setting dictates further response of the G60 to testing conditions To force contact inputs and outputs through relay se...

Page 482: ... across the input terminals The force contact inputs feature provides a method of performing checks on the function of all contact inputs Once enabled the relay is placed into test mode allowing this feature to override the normal function of contact inputs The Test Mode LED will be on indicating that the relay is in test mode The state of each contact input may be programmed as Dis abled Open or ...

Page 483: ...d 3 should open and contact input 4 should close Also contact output 1 should freeze contact output 2 should open contact output 3 should close and contact output 4 should remain fully opera tional The required settings are shown below To enable user programmable pushbutton 1 to initiate the test mode make the following changes in the SETTINGS TESTING TEST MODE menu TEST MODE FUNCTION Enabled and ...

Page 484: ... MESSAGE PMU 1 VC TEST ANGLE 120 00 Range 180 00 to 180 00 in steps of 0 05 MESSAGE PMU 1 VX TEST MAGNITUDE 500 00 kV Range 0 00 to 700 00 kV in steps of 0 01 MESSAGE PMU 1 VX TEST ANGLE 0 00 Range 180 00 to 180 00 in steps of 0 05 MESSAGE PMU 1 IA TEST MAGNITUDE 1 000 kA Range 0 000 to 9 999 kA in steps of 0 001 MESSAGE PMU 1 IA TEST ANGLE 10 00 Range 180 00 to 180 00 in steps of 0 05 MESSAGE PMU...

Page 485: ...d in the outgoing data frames When required it is recommended to use the user pro grammable digital channels to signal the C37 118 client that test values are being sent in place of the real measurements The UR Synchrophasor Implementation defines a test mode which sends a pre defined set of Synchrophasors out over the communication channel when the test mode function setting is enabled In test mo...

Page 486: ...5 326 G60 Generator Protection System GE Multilin 5 10 TESTING 5 SETTINGS 5 ...

Page 487: ...ACT OUTPUTS See page 6 5 VIRTUAL OUTPUTS See page 6 6 REMOTE DEVICES STATUS See page 6 6 REMOTE DEVICES STATISTICS See page 6 6 DIGITAL COUNTERS See page 6 7 SELECTOR SWITCHES See page 6 7 FLEX STATES See page 6 7 ETHERNET See page 6 7 REAL TIME CLOCK SYNCHRONIZING See page 6 8 DIRECT INPUTS See page 6 9 DIRECT DEVICES STATUS See page 6 9 IEC 61850 GOOSE UINTEGERS See page 6 10 EGD PROTOCOL STATUS...

Page 488: ...FREQUENCY OOB ACCUMULATION See page 6 22 FLEXELEMENTS See page 6 23 IEC 61850 GOOSE ANALOGS See page 6 24 SENSITIVE DIRECTIONAL POWER See page 6 24 STATOR GROUND See page 6 24 SUB HARMONIC STATOR GROUND See page 6 25 FIELD GROUND See page 6 25 VOLTS PER HERTZ 1 See page 6 25 VOLTS PER HERTZ 2 See page 6 25 RESTRICTED GROUND FAULT CURRENTS See page 6 25 PHASOR MEASUREMENT UNIT See page 6 26 PMU AGG...

Page 489: ...VIEW 6 ACTUAL VALUES RECORDS USER PROGRAMMABLE FAULT REPORTS See page 6 28 EVENT RECORDS See page 6 28 OSCILLOGRAPHY See page 6 28 DATA LOGGER See page 6 29 PMU RECORDS See page 6 29 ACTUAL VALUES PRODUCT INFO MODEL INFORMATION See page 6 30 FIRMWARE REVISIONS See page 6 30 ...

Page 490: ...ates the ID of the virtual input For example Virt Ip 1 refers to the virtual input in terms of the default name The second line of the display indicates the logic state of the virtual input 6 2 3 REMOTE INPUTS PATH ACTUAL VALUES STATUS REMOTE INPUTS The present state of the 32 remote inputs is shown here The state displayed will be that of the remote point unless the remote device has been establi...

Page 491: ...re The first line of a message display indicates the ID of the contact output For example Cont Op 1 refers to the contact output in terms of the default name array index The second line of the display indicates the logic state of the contact output REMOTE DPS INPUTS REMOTE DPS INPUT 1 STATUS Bad Range On Off Intermediate Bad MESSAGE REMOTE DPS INPUT 2 STATUS Bad Range On Off Intermediate Bad MESSA...

Page 492: ...If the corresponding state is No then at least one required remote device is not online b STATISTICS PATH ACTUAL VALUES STATUS REMOTE DEVICES STATISTICS REMOTE DEVICE 1 16 Statistical data two types for up to 16 programmed remote devices is shown here The STNUM number is obtained from the indicated remote device and increments whenever a change of state of at least one item occurs in the GSSE GOOS...

Page 493: ...ge The current position only an integer from 0 through 7 is the actual value 6 2 11 FLEX STATES PATH ACTUAL VALUES STATUS FLEX STATES There are 256 FlexStateTM bits available The second line value indicates the state of the given FlexState bit 6 2 12 ETHERNET PATH ACTUAL VALUES STATUS ETHERNET DIGITAL COUNTERS Counter 1 Counter 1 ACCUM 0 MESSAGE Counter 1 FROZEN 0 MESSAGE Counter 1 FROZEN YYYY MM ...

Page 494: ...PORT 1 3 PTP STATE is the present state of the port s PTP clock The PTP clock state is DISABLED is the port s function setting is Disabled NO SIGNAL if enabled but no signal from an active master has been found and selected CALIBRATING if an active master has been selected but lock is not at present established SYNCH D NO PDELAY if the port is synchronized but the peer delay mechanism is non opera...

Page 495: ...eck High values for either of these counts may indicate on a problem with wiring the communication channel or one or more relays The UNRETURNED MSG COUNT and CRC FAIL COUNT values can be cleared using the CLEAR DIRECT I O COUNTERS command The DIRECT INPUT 1 to DIRECT INPUT 32 values represent the state of each direct input 6 2 15 DIRECT DEVICES STATUS PATH ACTUAL VALUES STATUS DIRECT DEVICES STATU...

Page 496: ...7 EGD PROTOCOL STATUS a FAST EXCHANGE PATH ACTUAL VALUES STATUS EGD PROTOCOL STATUS PRODUCER STATUS FAST EXCHANGE 1 These values provide information that may be useful for debugging an EGD network The EGD signature and packet size for the fast EGD exchange is displayed b SLOW EXCHANGE PATH ACTUAL VALUES STATUS EGD PROTOCOL STATUS PRODUCER STATUS SLOW EXCHANGE 1 2 These values provide information t...

Page 497: ...e teleprotection inputs outputs are not enabled 6 2 19 REMAINING CONNECTION STATUS PATH ACTUAL VALUES STATUS COMM STATUS REMAINING CONNECT These values specify the remaining number of TCP connections still available for each protocol Every time a connection is used the remaining number of connections decrements When released the remaining number of connections increments If no connection is made o...

Page 498: ...a counter for total messages received with an error bad port code frame length too short MISMATCHES PORT A is a counter for total messages received with an error on Port A PRP frame but port received through and LAN ID in the frame do not match MISMATCHES PORT B is a counter for total messages received with an error on Port B PRP frame but port received through and LAN ID in the frame do not match...

Page 499: ...ive PF Lag Current Voltage WATTS Positive VARS Negative PF Lead Current Voltage WATTS Negative VARS Negative PF Lag Current Voltage WATTS Negative VARS Positive PF Lead Current Generator Generator Inductive Inductive Resistive Resistive Generator Generator UR RELAY UR RELAY UR RELAY UR RELAY G G M M G G VCG IC VAG IA VBG IB 1 VCG IC VAG IA VBG IB 2 VCG IC VAG IA VBG IB 3 VCG IC VAG IA VBG IB 4 Q Q...

Page 500: ...ot measurable the phase angles are not referenced The phase angles are assigned as positive in the leading direction and are presented as negative in the lagging direction to more closely align with power system metering conventions This is illustrated below Figure 6 2 UR PHASE ANGLE MEASUREMENT CONVENTION c UR CONVENTION FOR MEASURING SYMMETRICAL COMPONENTS The UR series of relays calculate volta...

Page 501: ...trated in the following figure Figure 6 3 MEASUREMENT CONVENTION FOR SYMMETRICAL COMPONENTS ABC phase rotation ACB phase rotation Table 6 1 SYMMETRICAL COMPONENTS CALCULATION EXAMPLE SYSTEM VOLTAGES SEC V VT CONN RELAY INPUTS SEC V SYMM COMP SEC V VAG VBG VCG VAB VBC VCA F5AC F6AC F7AC V0 V1 V2 13 9 0 76 2 125 79 7 250 84 9 313 138 3 97 85 4 241 WYE 13 9 0 76 2 125 79 7 250 19 5 192 56 5 7 23 3 18...

Page 502: ...example if no phase VT is assigned to this source then any voltage energy and power val ues will be unavailable STATOR DIFFERENTIAL STATOR DIFF OPERATE Iad 0 00 A MESSAGE STATOR DIFF RESTRAIN Iar 0 00 A MESSAGE STATOR DIFF OPERATE Ibd 0 00 A MESSAGE STATOR DIFF RESTRAIN Iar 0 00 A MESSAGE STATOR DIFF OPERATE Icd 0 00 A MESSAGE STATOR DIFF RESTRAIN Icr 0 00 A SOURCE SRC 1 PHASE CURRENT SRC 1 See pa...

Page 503: ... this menu The SRC 1 text will be replaced by whatever name was programmed by the user for the associated source see SETTINGS SYSTEM SETUP SIGNAL SOURCES PHASE CURRENT SRC 1 SRC 1 RMS Ia 0 000 b 0 000 c 0 000 A MESSAGE SRC 1 RMS Ia 0 000 A MESSAGE SRC 1 RMS Ib 0 000 A MESSAGE SRC 1 RMS Ic 0 000 A MESSAGE SRC 1 RMS In 0 000 A MESSAGE SRC 1 PHASOR Ia 0 000 A 0 0 MESSAGE SRC 1 PHASOR Ib 0 000 A 0 0 M...

Page 504: ...t will be replaced by whatever name was programmed by the user for the associated source see SETTINGS SYSTEM SETUP SIGNAL SOURCES PHASE VOLTAGE SRC 1 SRC 1 RMS Vag 0 00 V MESSAGE SRC 1 RMS Vbg 0 00 V MESSAGE SRC 1 RMS Vcg 0 00 V MESSAGE SRC 1 PHASOR Vag 0 000 V 0 0 MESSAGE SRC 1 PHASOR Vbg 0 000 V 0 0 MESSAGE SRC 1 PHASOR Vcg 0 000 V 0 0 MESSAGE SRC 1 RMS Vab 0 00 V MESSAGE SRC 1 RMS Vbc 0 00 V ME...

Page 505: ...ate power in each phase and three phase power is measured as S VAB x ÎA VCB x ÎC EQ 6 2 where S is the apparent power VA VB VC IA IB IC are phase voltage and phase current phasors POWER SRC 1 SRC 1 REAL POWER 3φ 0 000 W MESSAGE SRC 1 REAL POWER φa 0 000 W MESSAGE SRC 1 REAL POWER φb 0 000 W MESSAGE SRC 1 REAL POWER φc 0 000 W MESSAGE SRC 1 REACTIVE PWR 3φ 0 000 var MESSAGE SRC 1 REACTIVE PWR φa 0 ...

Page 506: ...er a Clarke transformation of three phase voltages or currents auxiliary voltage or ground current as per source configuration see the SYSTEM SETUP POWER SYSTEM settings The signal used for frequency estimation is low pass filtered The final frequency measurement is passed through a validation filter that eliminates false readings due to signal distortions and transients i CURRENT HARMONICS AND TH...

Page 507: ... a percentage of the fundamental signal obtained as a ratio of harmonic amplitude to fundamental ampli tude multiplied by 100 The total harmonic distortion THD is the ratio of the total harmonic content to the fundamental EQ 6 4 Voltage harmonics are calculated only for Wye connected phase VTs Ensure the SYSTEM SETUP AC INPUTS VOLTAGE BANK F5 PHASE VT XX CONNECTION setting is Wye to enable voltage...

Page 508: ...r the frequency rate of change elements is shown here 6 3 7 FREQUENCY OUT OF BAND ACCUMULATION PATH ACTUAL VALUES METERING FREQUENCY OOB ACCUMULATION The frequency out of band accumulation metered values are displayed to the nearest percent as a ratio of the present accumulation to the user specified limit Note that this value can be greater than 100 TRACKING FREQUENCY TRACKING FREQUENCY 60 00 Hz ...

Page 509: ...al element s SOURCE CURRENT IBASE maximum nominal primary RMS value of the IN and IN inputs SOURCE ENERGY Positive and Negative Watthours Positive and Negative Varhours EBASE 10000 MWh or MVAh respectively SOURCE POWER PBASE maximum value of VBASE IBASE for the IN and IN inputs SOURCE VOLTAGE VBASE maximum nominal primary RMS value of the IN and IN inputs STATOR DIFFERENTIAL CURRENT Stator Diff Ia...

Page 510: ...nsating the angular errors of the CTs and VTs with the use of the RCA and CALIBRATION settings 6 3 11 STATOR GROUND PATH ACTUAL VALUES METERING STATOR GROUND Magnitudes of the third harmonic components of the machine neutral point voltage VN the zero sequence voltage at the machine terminals V0 and in the vector sum of the neutral point voltage and zero sequence voltage VN V0 are avail able for di...

Page 511: ...in this menu 6 3 15 RESTRICTED GROUND FAULT PATH ACTUAL VALUES METERING RESTRICTED GROUND FAULT CURRENTS RESTRICTED GROUND FAULT 1 6 The differential and restraint current values for the restricted ground fault element are displayed in this menu SUB HARMONIC STATOR GROUND SH INJECTION VOLTS 0 000 V MESSAGE SH INJECTION AMPS 0 000 A MESSAGE SH CURRENT ANGLE 0 MESSAGE STATOR GND RESIST 500 000 kΩ FI...

Page 512: ... VB 0 0000 kV 0 00 Range Va or Vab per VT bank connection MESSAGE PMU 1 VC 0 0000 kV 0 00 Range Va or Vab per VT bank connection MESSAGE PMU 1 VX 0 0000 kV 0 00 MESSAGE PMU 1 V1 0 0000 kV 0 00 MESSAGE PMU 1 V2 0 0000 kV 0 00 MESSAGE PMU 1 V0 0 0000 kV 0 00 Range Substituted with zero if delta connected VTs MESSAGE PMU 1 IA 0 0000 kA 0 00 MESSAGE PMU 1 IB 0 0000 kA 0 00 MESSAGE PMU 1 IC 0 0000 kA 0...

Page 513: ... 1500 bytes result in fragmented data frames causing increased network traffic 6 3 18 TRANSDUCER INPUTS AND OUTPUTS PATH ACTUAL VALUES METERING TRANSDUCER I O DCMA INPUTS DCMA INPUT xx Actual values for each DCmA input channel that is enabled are displayed with the top line as the programmed channel ID and the bottom line as the value followed by the programmed units PATH ACTUAL VALUES METERING TR...

Page 514: ...major output operands generate events not every operand Elements that assert output per phase for example log operating phase output only without asserting the common three phase operand event 6 4 3 OSCILLOGRAPHY PATH ACTUAL VALUES RECORDS OSCILLOGRAPHY This menu allows the user to view the number of triggers involved and number of oscillography traces available The CYCLES PER RECORD value is calc...

Page 515: ... values are static Refer to the COMMANDS CLEAR RECORDS menu for clearing data logger records 6 4 5 PHASOR MEASUREMENT UNIT RECORDS PATH ACTUAL VALUES RECORDS PMU RECORDS The number of triggers applicable to the phasor measurement unit recorder is indicated by the NUMBER OF TRIGGERS value The status of the phasor measurement unit recorder is indicated as follows PATH ACTUAL VALUES RECORDS PMU RECOR...

Page 516: ...ESSAGE ORDER CODE LINE 4 Range standard GE Multilin order code format MESSAGE SERIAL NUMBER Range standard GE Multilin serial number format MESSAGE ETHERNET MAC ADDRESS 000000000000 Range standard Ethernet MAC address format MESSAGE MANUFACTURING DATE 0 Range YYYY MM DD HH MM SS MESSAGE PMU FEATURE ACTIVE No Range Yes No MESSAGE CT VT ADVANCED DIAG ACTIVE No Range Yes No MESSAGE OPERATING TIME 0 0...

Page 517: ...in G60 Generator Protection System 6 31 6 ACTUAL VALUES 6 5 PRODUCT INFORMATION 6 The shown data is illustrative only A modification file number of 0 indicates that currently no modifications have been installed ...

Page 518: ...6 32 G60 Generator Protection System GE Multilin 6 5 PRODUCT INFORMATION 6 ACTUAL VALUES 6 ...

Page 519: ...mand entry 7 1 2 VIRTUAL INPUTS PATH COMMANDS VIRTUAL INPUTS The states of up to 64 virtual inputs are changed here The first line of the display indicates the ID of the virtual input The second line indicates the current or selected status of the virtual input This status will be a state off logic 0 or on logic 1 COMMANDS MESSAGE COMMANDS VIRTUAL INPUTS MESSAGE COMMANDS CLEAR RECORDS MESSAGE COMM...

Page 520: ...ock The complete date as a minimum must be entered to allow execution of this command The new time if entered and date will take effect at the moment the ENTER key is clicked The timescale of the entered time should be local time including daylight time where and when applicable COMMANDS CLEAR RECORDS CLEAR USER FAULT REPORTS No Range No Yes CLEAR EVENT RECORDS No Range No Yes CLEAR OSCILLOGRAPHY ...

Page 521: ...le can initiate the Reboot Relay command The SERVICE COMMAND is used to perform specific G60 service actions Presently there is only one service action avail able Code 101 is used to clear factory diagnostic information stored in the non volatile memory If a code other than 101 is entered the command will be ignored and no actions will be taken Various self checking diagnostics are performed in th...

Page 522: ...ot time The PMU ONE SHOT PENDING operand indicates that the one shot operation is pending that is the present time is before the scheduled one shot time The PMU ONE SHOT OP operand indicates the one shot operation and remains asserted for 30 seconds afterwards When the function is disabled all three operands are de asserted The one shot function applies to all logical PMUs of a given G60 relay Fig...

Page 523: ... are referenced to different time scales Figure 7 2 USING THE PMU ONE SHOT FEATURE TO TEST SYNCHROPHASOR MEASUREMENT ACCURACY COLLECTING SYNCHRONIZED MEASUREMENTS AD HOC The one shot feature can be used for ad hoc collection of synchronized measurements in the network Two or more PMU can be pre scheduled to freeze their measurements at the same time When frozen the measurements could be collected ...

Page 524: ...ormation will be included if applicable If a tar get message status changes the status with the highest priority will be displayed If a self test error is detected a message appears indicating the cause of the error For example UNIT NOT PROGRAMMED indicates that the minimal relay settings have not been programmed 7 2 3 RELAY SELF TESTS a DESCRIPTION The relay performs a number of self test diagnos...

Page 525: ... target message No Description of problem A FlexLogic equation is incorrect How often the test is performed The test is event driven performed whenever FlexLogic equations are modified What to do Finish all equation editing and use self tests to debug any errors Latched target message No Description of problem The PRODUCT SETUP INSTALLATION RELAY SETTINGS setting indicates the G60 is not pro gramm...

Page 526: ...software will list the valid items An IEC61850 client will also show which nodes are available for the G60 Latched target message Yes Description of problem The battery is not functioning How often the test is performed The battery is monitored every five seconds The error message displays after 60 sec onds if the problem persists What to do Replace the battery as outlined in the Maintenance chapt...

Page 527: ...nctioning If strict PP is enabled that entire network is PP compliant The network is delivering PTP messages to the relay Latched target message No Description of problem An Ethernet connection has failed How often the test is performed Monitored every five seconds What to do Check Ethernet connections Port 1 is the primary port and port 2 is the secondary port Latched target message No Descriptio...

Page 528: ... is performed when a device programmed to receive GOOSE messages stops receiving This can be from 1 to 60 seconds depending on GOOSE packets What to do Check GOOSE setup Latched target message Yes Description of problem The ambient temperature is greater than the maximum operating temperature 80 C How often the test is performed Every hour What to do Remove the G60 from service and install in a lo...

Page 529: ...rify that the injection voltage actual value in the G60 is around 15 V If the message remains cycle power the field ground module If the problem persists then contact the factory Latched target message No Description of problem Field ground module reports trouble with its circuitry How often the test is performed Every second What to do Verify that the actual values in G60 are within accepted valu...

Page 530: ... this self test Type minor Target self reset Message SFP MODULE x FAIL The webpage SFP Transceiver Information described in the previous section applies for this self test as well The SFP Module Fail has higher priority and it suppresses the Ethernet Fail target message The SFP MODULE FAIL FUNC TION setting enables disables this self test The target for this self test is priority based with the th...

Page 531: ... common causes To further isolate AC input discrepancy errors put the relay in test isolated mode then one by one temporally change an AC bank crosschecking setting to none until the Process Bus Failure clears Once the problem AC bank has been identi fied the values from each of the two Bricks can be examined individually by temporarily mapping each to an AC bank with a single origin Process Bus T...

Page 532: ...7 14 G60 Generator Protection System GE Multilin 7 2 TARGETS 7 COMMANDS AND TARGETS 7 ...

Page 533: ...location of the VTs and CTs with respect to the involved power transformer and the direction of any given zone In the following equations the VT and CT locations are referenced as None if the transformer is not present between the CT VT and the intended reach point Otherwise the location is to be selected as a type of a transformer as seen from the VT CT position towards the intended reach point T...

Page 534: ... IB VAB IB IC VBC IC IA VCA 3IA 1 3 VAB VCA 3IB 1 3 VBC VAB 3IC 1 3 VCA VBC IAB_21P 3IC VAB_21P 1 3 VBC VCA IBC_21P 3IA VBC_21P 1 3 VCA VAB ICA_21P 3IB VCA_21P 1 3 VAB VBC IAB_21P 3IB VAB_21P 1 3 VBC VAB IBC_21P 3IC VBC_21P 1 3 VCA VBC ICA_21P 3IA VCA_21P 1 3 VAB VCA IAB_21P 3IA VAB_21P 1 3 VCA VAB IBC_21P 3IB VBC_21P 1 3 VAB VBC ICA_21P 3IC VCA_21P 1 3 VBC VCA IAB_21P 3IC VAB_21P 1 3 VCA VBC IBC_...

Page 535: ...C_21P 1 3 2IB IA IC VBC_21P 3VB ICA_21P 1 3 2IC IA IB VCA_21P 3VC IAB_21P 1 3 IA IB 2IC VAB_21P 3VC IBC_21P 1 3 IB IC 2IA VBC_21P 3VA ICA_21P 1 3 IA IC 2IB VCA_21P 3VB IAB_21P 1 3 2IB IA IC VAB_21P 3VB IBC_21P 1 3 2IC IA IB VBC_21P 3VC ICA_21P 1 3 2IA IB IC VCA_21P 3VA IAB_21P 1 3 IB IC 2IA VAB_21P 3VA IBC_21P 1 3 IA IC 2IB VBC_21P 3VB ICA_21P 1 3 IA IB 2IC VCA_21P 3VC IAB_21P 1 3 2IC IA IB VAB_21...

Page 536: ...ation on set tings please refer to Chapter 9 Application of Settings 8 1 2 EXAMPLE Consider the system shown below Figure 8 2 SAMPLE SYSTEM CONFIGURATION Normally in order to respond to the fault shown in the figure a distance relay shall be applied at the relaying point X The relay input signals at this location are shown in the following table If installed at the location X the relay would use t...

Page 537: ...ndary side The above example illustrates how the relay maintains correct reach for fault behind power transformers When installed at X the relay shall be set to 0 687 Ω 85 secondary in order to reach to the fault shown in the figure When installed at H the relay shall be set to 2 569 Ω 88 4 to ensure exactly same coverage See Chapter 9 Application of Settings for more information on setting calcul...

Page 538: ...8 6 G60 Generator Protection System GE Multilin 8 1 PHASE DISTANCE THROUGH POWER TRANSFORMERS 8 THEORY OF OPERATION 8 ...

Page 539: ...pu x 1 967 pu I T capability 10 I capability 8 Motoring Power 22000 kW d d 2 2 GSU 200 MVA 18 138 kV X 10 1 Yd1 TX LINE 138 kV Z 15 j75 ohm 1 8000 5 A 8000 5 A 12000 240 V 18900 120 V 2 830712A7 CDR GE Consumer Industrial Multilin CONTACT INPUT H5a CONTACT INPUT H5c CONTACT INPUT H6a CONTACT INPUT H6c COMMON H5b CONTACT INPUT H7a CONTACT INPUT H7c CONTACT INPUT H8a CONTACT INPUT H8c COMMON H7b SUR...

Page 540: ...rough the SETTINGS SYSTEM SETUP POWER SYSTEM VOLTAGE BANK F5 menu 9 1 4 SIGNAL SOURCES Two sources are required for this application example The LINE source uses the phase and auxiliary VT inputs and the CT input wired to the generator output CT The NEUTRL source uses the phase VT inputs and the CT input wired to the generator neutral CT Including the phase VT inputs for both sources allows the us...

Page 541: ...CT saturation is expected to occur Make the following parameter changes in EnerVista UR Setup or through the SETTINGS GROUPED ELEMENTS SET TING GROUP 1 STATOR DIFFERENTIAL menu 9 1 6 GENERATOR UNBALANCE Stage 1 of the generator unbalance element is typically used to trip the generator In this example the I2 capability of the machine is 8 and the I2 2 T capability is 10 The generator nominal curren...

Page 542: ...rse power element should be set at the rated motoring power The pickup is calculated as follows EQ 9 15 For the example system If the example system has delta connected VTs instead of wye connected VTs and say the VT secondary setting is set to 115 V instead of 66 V then the setting value of Smin is calculated as follows EQ 9 16 Zb sec base kV 2 base MVA CT ratio VT ratio 18 kV 2 211 765 MVA 1600 ...

Page 543: ...this element The pickup of this element should be set at a safe margin above the max imum load expected on the machine EQ 9 17 The selection of all standard curves and FlexCurves is allowed for easy coordination with system relaying For the example system an IEEE extremely inverse curve will be used and a setting will be chosen such that the operate time for a three phase fault on the high side of...

Page 544: ...station Zone 3 will look in the reverse direction and cover the stator winding Zone 2 will not be used in this example Both the VTs and the CTs are located on the low voltage side of the GSU The transformer vector diagram see figure 9 1 shows this transformer to be Yd1 Conse quently due to the location of instrument transformers Dy11 is chosen for both the XFMR VOL CONNECTION and XFMR CUR CONNECTI...

Page 545: ...uxiliary overvoltage element will be used in this example The auxiliary voltage input has previously been assigned to the NEUTRL source In this example the element will be set to protect 97 of the stator against ground faults EQ 9 30 The time delay should be longer than the longest normal clearing time for faults outside the generator zone If the phase VTs are wye connected then this element shoul...

Page 546: ...t has two stages In this application stage 1 is used to trip the machine and stage 2 is used for alarm purposes Set the pickup to 0 15 for both stages to provide adequate overlap with the auxiliary overvoltage element Set stage 1 to 0 375 V secondary this value may be increased for security in particularly noisy environments Stage 2 is typically set at 0 3 V sec ondary The supervision settings are...

Page 547: ...ickup setting will be EQ 9 32 The third harmonic will dip below the pickup setting between 95 and 105 megawatts The element should be blocked over this range A margin of 5 should be added to the relay settings The values for maximum and minimum power will be EQ 9 33 EQ 9 34 Voltage supervision will be given a setting of 0 8 pu in order to prevent maloperation during a sustained undervoltage con di...

Page 548: ...aracteristic curve A a pickup of 1 05 and a TDM of 40 Program the volts per hertz 2 element with a definite time characteristic a pickup of 1 23 and a time delay of 2 seconds Both ele ments will issue a trip The volts per hertz 1 pickup will be used to generate an alarm Either source may be assigned in this example Make the following changes in EnerVista UR Setup or through the SETTINGS GROUPED EL...

Page 549: ... the following changes in EnerVista UR Setup or through the SETTINGS INPUTS OUTPUTS CONTACT INPUTS CONTACT INPUT H7a H7c menus Make the following changes in EnerVista UR Setup or through the SETTINGS INPUTS OUTPUTS VIRTUAL OUTPUTS VIRTUAL OUTPUT 1 4 menus Make the following changes in EnerVista UR Setup or through the SETTINGS INPUTS OUTPUTS CONTACT OUTPUTS CONTACT OUTPUT H1 H4 menus ...

Page 550: ...NTROL ELEMENTS UNDERFRE QUENCY UNDERFREQUENCY 1 2 and the SETTINGS CONTROL ELEMENTS OVERFREQUENCY OVERFREQUENCY 1 2 menus 9 1 15 ACCIDENTAL ENERGIZATION In this example the ACCDNT ENRG ARMING MODE is selected as UV and Offline The ACCDNT ENRG OC PICKUP setting should be set at the minimum expected fault current In this case 1 0 pu 8000 A primary is selected In cases where it is possible to re ener...

Page 551: ...P DIR POWER STG1 OP 16 17 SEQ TRIP ON VO9 STATOR DIFF OP 14 15 OR 7 FLD BKR TRIP VO2 STATOR GND STG1 OP OR 7 20 21 OVEREXCIT ON VO7 AUX OV1 OP 18 19 FLD BKR TRIP VO2 22 DIR POWER 1 STG1 OP ONLINE ON VO8 25 26 STATOR DIFF OP LOSS EXCIT OP 23 24 OR 6 TURBINE TRIP VO3 AUX OV1 OP OVEREXCIT ON VO7 AND 2 27 28 AND 2 35 36 33 34 39 37 38 GEN UNBAL STG2 OP OVERFREQ ON VO6 VOLTS PER HERTZ 1 PKP TIMER 1 OR ...

Page 552: ...former connection and vector group as seen from the CTs toward the reach point Otherwise the CT connection setting shall be set to None 4 The voltage signals require compensation if the transformer is located between the VTs and the intended reach point If this is the case the VT connection setting shall be set to transformer connection and vector group as seen from the VTs toward the reach point ...

Page 553: ...ed between the potential source and the reach point for Z1 the reach impedance must not include the positive sequence impedance of the transformer The CTs are located on the other side of the transformer thus transformer ratio must be included EQ 9 37 e ZONE 3 SETTING IN APPLICATION B As the transformer is located between the potential source and the reach point for Zone 3 the reach impedance must...

Page 554: ...ISTANCE THROUGH POWER TRANSFORMERS 9 APPLICATION OF SETTINGS 9 The Zone 3 settings are EQ 9 41 PHS DIST Z3 REACH 2 60 PHS DIST Z3 RCA 89 PHS DIST Z3 XMFR VOL CONNECTION Yd11 PHS DIST Z3 XMFR CUR CONNECTION None Z3 0 127 90 0 006 88 315 13 8 1600 2625 2 601Ω 89 4 ...

Page 555: ...equence component As such the same signal must not be injected to all three phases or the injected signal will be completely filtered out For an underfrequency element using phase quantities the phase A signal must be above the MIN VOLT AMP setting value There fore either inject into phase A only or inject a balanced three phase signal Figure 10 1 TYPICAL UNDERFREQUENCY ELEMENT TEST TIMING The sta...

Page 556: ...timer This is exclusive of the time taken by the frequency responding component to pickup The G60 oscillography can be used to measure the time between the calculated source frequency crossing the threshold and element operation however this method omits the delay in the calculated source frequency The security features of the source frequency measurement algorithm result in the calculated frequen...

Page 557: ... screw has been removed as shown below This allows for easy accessibility of the modules for withdrawal The new wide angle hinge assembly in the enhanced front panel opens completely and allows easy access to all modules in the G60 Figure 11 1 UR MODULE WITHDRAWAL AND INSERTION ENHANCED FACEPLATE The standard faceplate can be opened to the left once the sliding latch on the right side has been pus...

Page 558: ... the clips have cleared the raised edge of the chassis engage the clips simultaneously When the clips have locked into position the module will be fully inserted CPU connections must be individually disconnected from the module before the module can be removed from the chassis The new CT VT modules can only be used with new CPUs similarly old CT VT modules can only be used with old CPUs In the eve...

Page 559: ...ypically in the first slot on the left side and blocked by the hinge of the front panel To remove the front panel unscrew the bracket on the front left side of the unit 5 Simultaneously pull the ejector clips at the top and bottom of the power supply module and remove the module 6 Unscrew the screw that attaches the metal cover to the module 7 Slide the metal cover away from the clips about 1 cm 1...

Page 560: ...α μπαταρία που δεν πρέπει να απορρίπτεται σε δημόσια συστήματα απόρριψης στην Ευρωπαϊκή Κοινότητα είτε την τεκμηρίωση του προϊόντος για συγκεκριμένες πληροφορίες που αφορούν τη μπαταρία Η μπαταρία είναι φέρει σήμανση με αυτό το σύμβολο το οποίο μπορεί να περιλαμβάνει γράμματα για να δηλώσουν το κάδμιο Cd τον μόλυβδο Pb ή τον υδράργυρο Hg Για την κατάλληλη ανακύκλωση επιστρέψτε την μπαταρία στον πρ...

Page 561: ...i Dette produkt inneholder et batteri som ikke kan kastes med usortert kommunalt søppel i den Europeiske Unionen Se produktdokumentasjonen for spesifikk batteriinformasjon Batteriet er merket med dette symbolet som kan inkludere symboler for å indikere at kadmium Cd bly Pb eller kvikksølv Hg forekommer Returner batteriet til leverandøren din eller til et dedikert oppsamlingspunkt for korrekt gjenv...

Page 562: ... avsedd deponering För mer information se www recyclethis info TR Pil Geri Dönüşümü Bu ürün Avrupa Birliği genel atık sistemlerine atılmaması gereken pil içermektedir Daha detaylı pil bilgisi için ürünün kataloğunu inceleyiniz Bu sembolle işaretlenmiş piller Kadmiyum Cd Kurşun Pb ya da Civa Hg içerebilir Doğru geri dönüşüm için ürünü yerel tedarikçinize geri veriniz ya da özel işaretlenmiş toplama...

Page 563: ...ice for example to comply with data security regu lations On the computer settings files can identified by the urs extension To clear the current settings file create a default set tings file write it to the relay then delete all other urs files For the existing installation upgrading the firmware overwrites the flash memory Other files can be in standard formats such as COMTRADE or csv You cannot...

Page 564: ...ack the unit in a box with bubble wrap foam material or styrofoam inserts or packaging peanuts to cushion the item s You may also use double boxing whereby you place the box in a larger box that contains at least 5 cm of cushioning material Ship the unit by courier or freight forwarder along with the Commercial Invoice and RMA to the factory GE DIGITAL ENERGY 650 MARKLAND STREET MARKHAM ONTARIO CA...

Page 565: ... Store the unit indoors in a cool dry place If possible store in the original packaging Follow the storage temperature range outlined in the Specifications To avoid deterioration of electrolytic capacitors power up units that are stored in a de energized state once per year for one hour continuously NOTICE ...

Page 566: ...n the battery there are no special requirements for disposal of the unit at the end its service life For customers located in the European Union dispose of the battery as outlined earlier To prevent non intended use of the unit remove the modules as outlined earlier dismantle the unit and recycle the metal when possible ...

Page 567: ...ps Restricted ground fault 1 differential ground current magnitude 5794 RGF 1 Igr Mag Amps Restricted ground fault 1 restricted ground current magnitude 5796 RGF 2 Igd Mag Amps Restricted ground fault 2 differential ground current magnitude 5798 RGF 2 Igr Mag Amps Restricted ground fault 2 restricted ground current magnitude 5800 RGF 3 Igd Mag Amps Restricted ground fault 3 differential ground cur...

Page 568: ...ent angle 6222 SRC 2 Ic Mag Amps Source 2 phase C current magnitude 6224 SRC 2 Ic Angle Degrees Source 2 phase C current angle 6225 SRC 2 In Mag Amps Source 2 neutral current magnitude 6227 SRC 2 In Angle Degrees Source 2 neutral current angle 6228 SRC 2 Ig RMS Amps Source 2 ground current RMS 6230 SRC 2 Ig Mag Amps Source 2 ground current magnitude 6232 SRC 2 Ig Angle Degrees Source 2 ground curr...

Page 569: ...52 SRC 4 Ic Angle Degrees Source 4 phase C current angle 6353 SRC 4 In Mag Amps Source 4 neutral current magnitude 6355 SRC 4 In Angle Degrees Source 4 neutral current angle 6356 SRC 4 Ig RMS Amps Source 4 ground current RMS 6358 SRC 4 Ig Mag Amps Source 4 ground current magnitude 6360 SRC 4 Ig Angle Degrees Source 4 ground current angle 6361 SRC 4 I_0 Mag Amps Source 4 zero sequence current magni...

Page 570: ...e magnitude 6731 SRC 2 Vbg Angle Degrees Source 2 phase BG voltage angle 6732 SRC 2 Vcg Mag Volts Source 2 phase CG voltage magnitude 6734 SRC 2 Vcg Angle Degrees Source 2 phase CG voltage angle 6735 SRC 2 Vab RMS Volts Source 2 phase AB voltage RMS 6737 SRC 2 Vbc RMS Volts Source 2 phase BC voltage RMS 6739 SRC 2 Vca RMS Volts Source 2 phase CA voltage RMS 6741 SRC 2 Vab Mag Volts Source 2 phase ...

Page 571: ...e voltage magnitude 6827 SRC 3 V_2 Angle Degrees Source 3 negative sequence voltage angle 6848 SRC 4 Vag RMS Volts Source 4 phase AG voltage RMS 6850 SRC 4 Vbg RMS Volts Source 4 phase BG voltage RMS 6852 SRC 4 Vcg RMS Volts Source 4 phase CG voltage RMS 6854 SRC 4 Vag Mag Volts Source 4 phase AG voltage magnitude 6856 SRC 4 Vag Angle Degrees Source 4 phase AG voltage angle 6857 SRC 4 Vbg Mag Volt...

Page 572: ... 7204 SRC 2 Pb Watts Source 2 phase B real power 7206 SRC 2 Pc Watts Source 2 phase C real power 7208 SRC 2 Q Vars Source 2 three phase reactive power 7210 SRC 2 Qa Vars Source 2 phase A reactive power 7212 SRC 2 Qb Vars Source 2 phase B reactive power 7214 SRC 2 Qc Vars Source 2 phase C reactive power 7216 SRC 2 S VA Source 2 three phase apparent power 7218 SRC 2 Sa VA Source 2 phase A apparent p...

Page 573: ...stortion THD 8065 SRC 1 Va Harm 0 Source 1 phase A voltage second harmonic 8066 SRC 1 Va Harm 1 Source 1 phase A voltage third harmonic 8067 SRC 1 Va Harm 2 Source 1 phase A voltage fourth harmonic 8068 SRC 1 Va Harm 3 Source 1 phase A voltage fifth harmonic 8069 SRC 1 Va Harm 4 Source 1 phase A voltage sixth harmonic 8070 SRC 1 Va Harm 5 Source 1 phase A voltage seventh harmonic 8071 SRC 1 Va Har...

Page 574: ...RC 1 Vb Harm 19 Source 1 phase B voltage twenty first harmonic 8110 SRC 1 Vb Harm 20 Source 1 phase B voltage twenty second harmonic 8111 SRC 1 Vb Harm 21 Source 1 phase B voltage twenty third harmonic 8112 SRC 1 Vb Harm 22 Source 1 phase B voltage twenty fourth harmonic 8113 SRC 1 Vb Harm 23 Source 1 phase B voltage twenty fifth harmonic 8114 SRC 1 Vc THD Source 1 phase C voltage total harmonic d...

Page 575: ...56 SRC 2 Va Harm 16 Source 2 phase A voltage eighteenth harmonic 8157 SRC 2 Va Harm 17 Source 2 phase A voltage nineteenth harmonic 8158 SRC 2 Va Harm 18 Source 2 phase A voltage twentieth harmonic 8159 SRC 2 Va Harm 19 Source 2 phase A voltage twenty first harmonic 8160 SRC 2 Va Harm 20 Source 2 phase A voltage twenty second harmonic 8161 SRC 2 Va Harm 21 Source 2 phase A voltage twenty third har...

Page 576: ...03 SRC 2 Vc Harm 13 Source 2 phase C voltage fifteenth harmonic 8204 SRC 2 Vc Harm 14 Source 2 phase C voltage sixteenth harmonic 8205 SRC 2 Vc Harm 15 Source 2 phase C voltage seventeenth harmonic 8206 SRC 2 Vc Harm 16 Source 2 phase C voltage eighteenth harmonic 8207 SRC 2 Vc Harm 17 Source 2 phase C voltage nineteenth harmonic 8208 SRC 2 Vc Harm 18 Source 2 phase C voltage twentieth harmonic 82...

Page 577: ...250 SRC 3 Vb Harm 10 Source 3 phase B voltage twelfth harmonic 8251 SRC 3 Vb Harm 11 Source 3 phase B voltage thirteenth harmonic 8252 SRC 3 Vb Harm 12 Source 3 phase B voltage fourteenth harmonic 8253 SRC 3 Vb Harm 13 Source 3 phase B voltage fifteenth harmonic 8254 SRC 3 Vb Harm 14 Source 3 phase B voltage sixteenth harmonic 8255 SRC 3 Vb Harm 15 Source 3 phase B voltage seventeenth harmonic 825...

Page 578: ...onic 8297 SRC 4 Va Harm 7 Source 4 phase A voltage ninth harmonic 8298 SRC 4 Va Harm 8 Source 4 phase A voltage tenth harmonic 8299 SRC 4 Va Harm 9 Source 4 phase A voltage eleventh harmonic 8300 SRC 4 Va Harm 10 Source 4 phase A voltage twelfth harmonic 8301 SRC 4 Va Harm 11 Source 4 phase A voltage thirteenth harmonic 8302 SRC 4 Va Harm 12 Source 4 phase A voltage fourteenth harmonic 8303 SRC 4 ...

Page 579: ...e fifth harmonic 8344 SRC 4 Vc Harm 4 Source 4 phase C voltage sixth harmonic 8345 SRC 4 Vc Harm 5 Source 4 phase C voltage seventh harmonic 8346 SRC 4 Vc Harm 6 Source 4 phase C voltage eighth harmonic 8347 SRC 4 Vc Harm 7 Source 4 phase C voltage ninth harmonic 8348 SRC 4 Vc Harm 8 Source 4 phase C voltage tenth harmonic 8349 SRC 4 Vc Harm 9 Source 4 phase C voltage eleventh harmonic 8350 SRC 4 ...

Page 580: ...9559 PMU 1 Ia Angle Degrees Phasor measurement unit 1 phase A current angle 9560 PMU 1 Ib Mag Amps Phasor measurement unit 1 phase B current magnitude 9562 PMU 1 Ib Angle Degrees Phasor measurement unit 1 phase B current angle 9563 PMU 1 Ic Mag Amps Phasor measurement unit 1 phase C current magnitude 9565 PMU 1 Ic Angle Degrees Phasor measurement unit 1 phase C current angle 9566 PMU 1 Ig Mag Amps...

Page 581: ...ic 10279 SRC 1 Ib Harm 5 Source 1 phase B current seventh harmonic 10280 SRC 1 Ib Harm 6 Source 1 phase B current eighth harmonic 10281 SRC 1 Ib Harm 7 Source 1 phase B current ninth harmonic 10282 SRC 1 Ib Harm 8 Source 1 phase B current tenth harmonic 10283 SRC 1 Ib Harm 9 Source 1 phase B current eleventh harmonic 10284 SRC 1 Ib Harm 10 Source 1 phase B current twelfth harmonic 10285 SRC 1 Ib H...

Page 582: ...nic 10342 SRC 2 Ia Harm 2 Source 2 phase A current fourth harmonic 10343 SRC 2 Ia Harm 3 Source 2 phase A current fifth harmonic 10344 SRC 2 Ia Harm 4 Source 2 phase A current sixth harmonic 10345 SRC 2 Ia Harm 5 Source 2 phase A current seventh harmonic 10346 SRC 2 Ia Harm 6 Source 2 phase A current eighth harmonic 10347 SRC 2 Ia Harm 7 Source 2 phase A current ninth harmonic 10348 SRC 2 Ia Harm ...

Page 583: ...10405 SRC 2 Ic THD Source 2 phase C current total harmonic distortion 10406 SRC 2 Ic Harm 0 Source 2 phase C current second harmonic 10407 SRC 2 Ic Harm 1 Source 2 phase C current third harmonic 10408 SRC 2 Ic Harm 2 Source 2 phase C current fourth harmonic 10409 SRC 2 Ic Harm 3 Source 2 phase C current fifth harmonic 10410 SRC 2 Ic Harm 4 Source 2 phase C current sixth harmonic 10411 SRC 2 Ic Har...

Page 584: ...C 3 Ia Harm 21 Source 3 phase A current twenty third harmonic 10461 SRC 3 Ia Harm 22 Source 3 phase A current twenty fourth harmonic 10462 SRC 3 Ia Harm 23 Source 3 phase A current twenty fifth harmonic 10471 SRC 3 Ib THD Source 3 phase B current total harmonic distortion 10472 SRC 3 Ib Harm 0 Source 3 phase B current second harmonic 10473 SRC 3 Ib Harm 1 Source 3 phase B current third harmonic 10...

Page 585: ...SRC 3 Ic Harm 18 Source 3 phase C current twentieth harmonic 10524 SRC 3 Ic Harm 19 Source 3 phase C current twenty first harmonic 10525 SRC 3 Ic Harm 20 Source 3 phase C current twenty second harmonic 10526 SRC 3 Ic Harm 21 Source 3 phase C current twenty third harmonic 10527 SRC 3 Ic Harm 22 Source 3 phase C current twenty fourth harmonic 10528 SRC 3 Ic Harm 23 Source 3 phase C current twenty fi...

Page 586: ... SRC 4 Ib Harm 15 Source 4 phase B current seventeenth harmonic 10587 SRC 4 Ib Harm 16 Source 4 phase B current eighteenth harmonic 10588 SRC 4 Ib Harm 17 Source 4 phase B current nineteenth harmonic 10589 SRC 4 Ib Harm 18 Source 4 phase B current twentieth harmonic 10590 SRC 4 Ib Harm 19 Source 4 phase B current twenty first harmonic 10591 SRC 4 Ib Harm 20 Source 4 phase B current twenty second h...

Page 587: ...49 SRC 5 Ia Harm 12 Source 5 phase A current fourteenth harmonic 10650 SRC 5 Ia Harm 13 Source 5 phase A current fifteenth harmonic 10651 SRC 5 Ia Harm 14 Source 5 phase A current sixteenth harmonic 10652 SRC 5 Ia Harm 15 Source 5 phase A current seventeenth harmonic 10653 SRC 5 Ia Harm 16 Source 5 phase A current eighteenth harmonic 10654 SRC 5 Ia Harm 17 Source 5 phase A current nineteenth harmo...

Page 588: ...0712 SRC 5 Ic Harm 9 Source 5 phase C current eleventh harmonic 10713 SRC 5 Ic Harm 10 Source 5 phase C current twelfth harmonic 10714 SRC 5 Ic Harm 11 Source 5 phase C current thirteenth harmonic 10715 SRC 5 Ic Harm 12 Source 5 phase C current fourteenth harmonic 10716 SRC 5 Ic Harm 13 Source 5 phase C current fifteenth harmonic 10717 SRC 5 Ic Harm 14 Source 5 phase C current sixteenth harmonic 1...

Page 589: ...nic 10775 SRC 6 Ib Harm 6 Source 6 phase B current eighth harmonic 10776 SRC 6 Ib Harm 7 Source 6 phase B current ninth harmonic 10777 SRC 6 Ib Harm 8 Source 6 phase B current tenth harmonic 10778 SRC 6 Ib Harm 9 Source 6 phase B current eleventh harmonic 10779 SRC 6 Ib Harm 10 Source 6 phase B current twelfth harmonic 10780 SRC 6 Ib Harm 11 Source 6 phase B current thirteenth harmonic 10781 SRC 6...

Page 590: ...actual value 13506 DCmA Inputs 2 Value mA DCmA input 2 actual value 13508 DCmA Inputs 3 Value mA DCmA input 3 actual value 13510 DCmA Inputs 4 Value mA DCmA input 4 actual value 13512 DCmA Inputs 5 Value mA DCmA input 5 actual value 13514 DCmA Inputs 6 Value mA DCmA input 6 actual value 13516 DCmA Inputs 7 Value mA DCmA input 7 actual value 13518 DCmA Inputs 8 Value mA DCmA input 8 actual value 13...

Page 591: ... 26 actual value 13578 RTD Inputs 27 Value RTD input 27 actual value 13579 RTD Inputs 28 Value RTD input 28 actual value 13580 RTD Inputs 29 Value RTD input 29 actual value 13581 RTD Inputs 30 Value RTD input 30 actual value 13582 RTD Inputs 31 Value RTD input 31 actual value 13583 RTD Inputs 32 Value RTD input 32 actual value 13584 RTD Inputs 33 Value RTD input 33 actual value 13585 RTD Inputs 34...

Page 592: ...lexElement 2 actual value 39172 FlexElement 3 Value FlexElement 3 actual value 39174 FlexElement 4 Value FlexElement 4 actual value 39176 FlexElement 5 Value FlexElement 5 actual value 39178 FlexElement 6 Value FlexElement 6 actual value 39180 FlexElement 7 Value FlexElement 7 actual value 39182 FlexElement 8 Value FlexElement 8 actual value 39184 FlexElement 9 Value FlexElement 9 actual value 391...

Page 593: ...1850 GOOSE analog input 10 45604 GOOSE Analog In 11 IEC 61850 GOOSE analog input 11 45606 GOOSE Analog In 12 IEC 61850 GOOSE analog input 12 45608 GOOSE Analog In 13 IEC 61850 GOOSE analog input 13 45610 GOOSE Analog In 14 IEC 61850 GOOSE analog input 14 45612 GOOSE Analog In 15 IEC 61850 GOOSE analog input 15 45614 GOOSE Analog In 16 IEC 61850 GOOSE analog input 16 61439 PMU Num Triggers Phasor m...

Page 594: ...nput 2 9972 GOOSE UInt Input 3 IEC61850 GOOSE UInteger input 3 9974 GOOSE UInt Input 4 IEC61850 GOOSE UInteger input 4 9976 GOOSE UInt Input 5 IEC61850 GOOSE UInteger input 5 9978 GOOSE UInt Input 6 IEC61850 GOOSE UInteger input 6 9980 GOOSE UInt Input 7 IEC61850 GOOSE UInteger input 7 9982 GOOSE UInt Input 8 IEC61850 GOOSE UInteger input 8 9984 GOOSE UInt Input 9 IEC61850 GOOSE UInteger input 9 9...

Page 595: ...ear terminal RS485 port can be set for baud rates of 300 1200 2400 4800 9600 14400 19200 28800 33600 38400 57600 or 115200 bps and even odd and no parity options are available See the Communications section of chapter 5 for further details The Modbus TCP IP protocol is available on each of the rear Ethernet ports Depending on the relay s order code these ports can be 10 100Base TX or 100Base FX B ...

Page 596: ...ollowing describes the ADU MBAP header This Modbus Application Protocol header contains the following fields Transaction Identifier Used for transaction pairing The Modbus server copies in the response the transaction identifier of the request Protocol Identifier Used for intra system multiplexing The Modbus protocol is identified by the value 0 Length The length field is a byte count of the follo...

Page 597: ... number of data bytes Di i th data byte i 0 to N 1 G 16 bit characteristic polynomial 1010000000000001 binary with MSbit dropped and bit order reversed shr x right shift operator th LSbit of x is shifted into a carry flag a 0 is shifted into the MSbit of x all other bits are shifted right one location ALGORITHM 1 FFFF hex A 2 0 i 3 0 j 4 Di Alow Alow 5 j 1 j 6 shr A 7 Is there a carry No go to 8 Y...

Page 598: ...d Function codes 03h and 04h are therefore identical The following table shows the format of the master and slave packets in Modbus RTU Modbus TCP IP ADUs have a MBAP instead of slave address and CRC is in another stack layer The example shows a master device requesting three register values starting at address 4050h from slave device 11h 17 decimal the slave device responds with the values 40 300...

Page 599: ... at memory map address 4051h to slave device 11h 17 dec Table B 5 MASTER AND SLAVE DEVICE PACKET TRANSMISSION EXAMPLE MASTER TRANSMISSION SLAVE RESPONSE PACKET FORMAT EXAMPLE HEX PACKET FORMAT EXAMPLE HEX SLAVE ADDRESS 11 SLAVE ADDRESS 11 FUNCTION CODE 05 FUNCTION CODE 05 OPERATION CODE high 00 OPERATION CODE high 00 OPERATION CODE low 01 OPERATION CODE low 01 CODE VALUE high FF CODE VALUE high FF...

Page 600: ...he function code set to 1 The following table shows the format of the master and slave packets in Modbus RTU Modbus TCP IP ADUs have a MBAP instead of slave address and CRC is in another stack layer The example shows a master device sending the unsupported function code 39h to slave device 11h Table B 8 MASTER AND SLAVE DEVICE PACKET TRANSMISSION EXAMPLE MASTER TRANSMISSION SLAVE RESPONSE PACKET F...

Page 601: ...le transfer information so files may be read simultaneously on multiple Modbus connections b OTHER PROTOCOLS All the files available via Modbus may also be retrieved using the standard file transfer mechanisms in other protocols for example TFTP or MMS c COMTRADE OSCILLOGRAPHY AND DATA LOGGER FILES Oscillography and data logger files are formatted using the COMTRADE file format per IEEE C37 111 19...

Page 602: ...following to the filename before writing it To read from a specific time to the end of the log space startTime To read a specific range of records space startTime space endTime Replace startTime and endTime with the number of seconds since Jan 1 1970 as numeric text f READING EVENT RECORDER FILES To read the entire event recorder contents in ASCII format the only available format use the following...

Page 603: ...0B0 CPU Supplier Serial Number F203 none 00C0 Ethernet Sub Module Serial Number 8 items F203 none Product Information Read Only 0100 GPM F Version 0 to 655 35 0 01 F001 0 0101 GPM F Compile Date 0 to 4294967295 1 F050 0 0103 GPM F Order Code F205 none 0109 GPM F Serial Number F205 none 010F GPM F Hardware Revision 0 to 65535 1 F001 0 Product Information Read Only Written by Factory 0110 FPGA Versi...

Page 604: ...te 0 to 1 1 F108 0 Off 0424 Virtual Input 37 State 0 to 1 1 F108 0 Off 0425 Virtual Input 38 State 0 to 1 1 F108 0 Off 0426 Virtual Input 39 State 0 to 1 1 F108 0 Off 0427 Virtual Input 40 State 0 to 1 1 F108 0 Off 0428 Virtual Input 41 State 0 to 1 1 F108 0 Off 0429 Virtual Input 42 State 0 to 1 1 F108 0 Off 042A Virtual Input 43 State 0 to 1 1 F108 0 Off 042B Virtual Input 44 State 0 to 1 1 F108...

Page 605: ...00 Contact Input States 6 items 0 to 65535 1 F500 0 1508 Virtual Input States 8 items 0 to 65535 1 F500 0 1510 Contact Output States 4 items 0 to 65535 1 F500 0 1518 Contact Output Current States 4 items 0 to 65535 1 F500 0 1520 Contact Output Voltage States 4 items 0 to 65535 1 F500 0 1528 Virtual Output States 6 items 0 to 65535 1 F500 0 1530 Contact Output Detectors 4 items 0 to 65535 1 F500 0 ...

Page 606: ... Logger Channel Count 0 to 16 channel 1 F001 0 1619 Time of Oldest Available Samples 0 to 4294967295 seconds 1 F050 0 161B Time of Newest Available Samples 0 to 4294967295 seconds 1 F050 0 161D Data Logger Duration 0 to 999 9 days 0 1 F001 0 Stator Differential Actual Values Read Only 1660 Generator Differential Iad 0 to 999999 999 A 0 001 F060 0 1662 Generator Restraint Iar 0 to 999999 999 A 0 00...

Page 607: ...rrent RMS 0 to 999999 999 A 0 001 F060 0 1806 Source 1 Neutral Current RMS 0 to 999999 999 A 0 001 F060 0 1808 Source 1 Phase A Current Magnitude 0 to 999999 999 A 0 001 F060 0 180A Source 1 Phase A Current Angle 359 9 to 0 degrees 0 1 F002 0 180B Source 1 Phase B Current Magnitude 0 to 999999 999 A 0 001 F060 0 180D Source 1 Phase B Current Angle 359 9 to 0 degrees 0 1 F002 0 180E Source 1 Phase ...

Page 608: ...iary Voltage Magnitude 0 to 999999 999 V 0 001 F060 0 1A22 Source 1 Auxiliary Voltage Angle 359 9 to 0 degrees 0 1 F002 0 1A23 Source 1 Zero Sequence Voltage Magnitude 0 to 999999 999 V 0 001 F060 0 1A25 Source 1 Zero Sequence Voltage Angle 359 9 to 0 degrees 0 1 F002 0 1A26 Source 1 Positive Sequence Voltage Magnitude 0 to 999999 999 V 0 001 F060 0 1A28 Source 1 Positive Sequence Voltage Angle 35...

Page 609: ...1 Va Harmonics 2nd to 25th 24 items 0 to 99 9 0 1 F001 0 1F99 Source 1 Vb THD 0 to 99 9 0 1 F001 0 1F9A Source 1 Vb Harmonics 2nd to 25th 24 items 0 to 99 9 0 1 F001 0 1FB2 Source 1 Vc THD 0 to 99 9 0 1 F001 0 1FB3 Source 1 Vc Harmonics 2nd to 25th 24 items 0 to 99 9 0 1 F001 0 1FCB Repeated for Source 2 2016 Repeated for Source 3 2061 Repeated for Source 4 Breaker Flashover Read Write Setting 2 m...

Page 610: ...2552 PMU 1 Zero Sequence Voltage Magnitude 0 to 999999 999 V 0 001 F060 0 2554 PMU 1 Zero Sequence Voltage Angle 180 to 180 0 1 F002 0 2555 PMU 1 Phase A Current Magnitude 0 to 999999 999 A 0 001 F060 0 2557 PMU 1 Phase A Current Angle 180 to 180 0 1 F002 0 2558 PMU 1 Phase B Current Magnitude 0 to 999999 999 A 0 001 F060 0 255A PMU 1 Phase B Current Angle 180 to 180 0 1 F002 0 255B PMU 1 Phase C ...

Page 611: ...Only Actual Values 16 modules 26F0 IEC 61850 Received uinteger 1 0 to 4294967295 1 F003 0 26F2 IEC 61850 Received uinteger 2 0 to 4294967295 1 F003 0 26F4 IEC 61850 Received uinteger 3 0 to 4294967295 1 F003 0 26F6 IEC 61850 Received uinteger 4 0 to 4294967295 1 F003 0 26F8 IEC 61850 Received uinteger 5 0 to 4294967295 1 F003 0 26FA IEC 61850 Received uinteger 6 0 to 4294967295 1 F003 0 26FC IEC 6...

Page 612: ...1 Cleared Date 0 to 4294967295 1 F050 0 3073 Report Date 10 items 0 to 4294967295 1 F050 0 User Programmable Fault Report Read Write Setting 2 modules 3090 Fault Report 1 Fault Trigger 0 to 4294967295 1 F300 0 3092 Fault Report 1 Function 0 to 1 1 F102 0 Disabled 3093 Fault Report 1 Prefault Trigger 0 to 4294967295 1 F300 0 3095 Fault Report Analog Channel 1 32 items 0 to 65536 1 F600 0 30B5 Fault...

Page 613: ...y Service Mode Enable 0 to 1 1 F102 0 Disabled 3335 Failed Authentication Alarm Enable 0 to 1 1 F102 1 Enabled 3336 Firmware Lock Alarm 0 to 1 1 F102 1 Enabled 3337 Settings Lock Alarm 0 to 1 1 F102 1 Enabled 3338 Bypass Access 0 to 1 1 F628 0 Disabled 3339 Encryption 0 to 1 1 F102 1 Enabled 333A Serial Inactivity Timeout 1 to 9999 min 1 F001 1 Security Command Read Write Command 3350 Operator Log...

Page 614: ...TD Input 2 Value 32768 to 32767 C 1 F002 0 34F2 RTD Input 3 Value 32768 to 32767 C 1 F002 0 34F3 RTD Input 4 Value 32768 to 32767 C 1 F002 0 34F4 RTD Input 5 Value 32768 to 32767 C 1 F002 0 34F5 RTD Input 6 Value 32768 to 32767 C 1 F002 0 34F6 RTD Input 7 Value 32768 to 32767 C 1 F002 0 34F7 RTD Input 8 Value 32768 to 32767 C 1 F002 0 34F8 RTD Input 9 Value 32768 to 32767 C 1 F002 0 34F9 RTD Input...

Page 615: ...IUS Configuration Read Write Setting 3735 Undefined 0 to 4294967295 1 F003 0 3737 Undefined 1 to 65535 1 F001 1812 3738 Undefined 1 to 65535 1 F001 1813 3739 Undefined 0 to 4294967295 1 F003 0 373B Undefined 0 to 65535 1 F001 1812 373D Undefined 0 to 65535 1 F001 1813 373F Undefined 1 F619 0 EAP TTLS 3740 Undefined 1 to 65535 1 F001 2910 3741 Undefined 0 to 9999 sec 1 F001 10 3742 Undefined 0 to 9...

Page 616: ... Repeated for Filed Unit 7 3869 Repeated for Filed Unit 8 Field Unit Process Card Ports Read Write Setting 3878 Field Unit 1 Process Card Port 0 to 7 1 F244 6 H1a 3879 Field Unit 2 Process Card Port 0 to 7 1 F244 4 H2a 387A Field Unit3 Process Card Port 0 to 7 1 F244 2 H3a 387B Field Unit 4 Process Card Port 0 to 7 1 F244 0 H4a 387C Field Unit 5 Process Card Port 0 to 7 1 F244 7 H1b 387D Field Uni...

Page 617: ...nput 16 39B0 Repeated for Field Contact Input 17 39BB Repeated for Field Contact Input 18 39C6 Repeated for Field Contact Input 19 39D1 Repeated for Field Contact Input 20 39DC Repeated for Field Contact Input 21 39E7 Repeated for Field Contact Input 22 39F2 Repeated for Field Contact Input 23 39FD Repeated for Field Contact Input 24 3A08 Repeated for Field Contact Input 25 3A13 Repeated for Field...

Page 618: ... 8 Field Unit Latching Outputs Read Write Setting 8 modules 3DC7 Field Latching Output 1 ID 0 to 1 1 F205 FLO Ux LO 3DCD Field Latching Output 1 Open 0 to 4294967295 1 F300 0 3DCF Field Latching Output 1 Close 0 to 4294967295 1 F300 0 3DD1 Field Latching Output 1 Events 0 to 1 1 F102 1 Enabled 3DD2 Field Latching Output 1 Reserved 2 items 0 to 1 1 F001 0 3DD4 Repeated for Field Latching Output 2 3...

Page 619: ...sducer 1 Min Value 9999 999 to 9999 999 0 001 F004 0 3F4A Field Unit Transducer 1 Max Value 9999 999 to 9999 999 0 001 F004 100000 3F4C Field Unit Transducer 1 Units F206 none 3F4F Repeated for Field Unit Transducer 2 3F5E Repeated for Field Unit Transducer 3 3F6D Repeated for Field Unit Transducer 4 3F7C Repeated for Field Unit Transducer 5 3F8B Repeated for Field Unit Transducer 6 3F9A Repeated ...

Page 620: ...off Level 0 002 to 0 02 pu 0 001 F001 20 4056 Voltage Cutoff Level 0 1 to 1 V 0 1 F001 10 Remote RTD Communications Read Write Setting 407A RRTD Slave Address 1 to 254 1 F001 254 407B RRTD Baud Rate 0 to 4 1 F602 4 19200 Communications Read Write Setting 407D COM2 Selection 0 to 3 1 F601 0 RS485 407E COM1 Minimum Response Time 0 to 1000 ms 10 F001 0 407F COM2 Minimum Response Time 0 to 1000 ms 10 ...

Page 621: ... s 1 F001 120 40CA DNP Communications Reserved 22 items 0 to 1 1 F001 0 40E0 TCP Port Number for the IEC 60870 5 104 Protocol 0 to 65535 1 F001 2404 40E1 IEC 60870 5 104 Protocol Function 0 to 1 1 F102 0 Disabled 40E2 IEC 60870 5 104 Protocol Common Address of ASDU 0 to 65535 1 F001 0 40E3 IEC 60870 5 104 Protocol Cyclic Data Transmission Period 1 to 65535 s 1 F001 60 40E4 IEC 60870 5 104 Current ...

Page 622: ... 0 Fail 4156 Ethernet Switch Port 3 Status 0 to 2 1 F134 0 Fail 4157 Ethernet Switch Port 4 Status 0 to 2 1 F134 0 Fail 4158 Ethernet Switch Port 5 Status 0 to 2 1 F134 0 Fail 4159 Ethernet Switch Port 6 Status 0 to 2 1 F134 0 Fail 415A Switch Firmware Version 0 00 to 99 99 0 01 F001 0 Communications Actual Values Read Only 4160 Modbus Available TCP IP Connections 0 to 4 1 F001 4 4161 DNP Availabl...

Page 623: ...F300 0 42B2 Alarm LED Input FlexLogic Operand 0 to 4294967295 1 F300 0 User Programmable LEDs Read Write Setting 48 modules 42C0 FlexLogic Operand to Activate LED 0 to 4294967295 1 F300 0 42C2 User LED type latched or self resetting 0 to 1 1 F127 1 Self Reset 42C3 Repeated for User Programmable LED 2 42C6 Repeated for User Programmable LED 3 42C9 Repeated for User Programmable LED 4 42CC Repeated ...

Page 624: ...rk Route 1 Netmask 0 to 4294967295 1 F003 4278190080 4374 IPv4 Network Route 1 Gateway 0 to 4294967295 1 F003 2130706433 4376 Repeated for Route 2 437C Repeated for Route 3 4382 Repeated for Route 4 4388 Repeated for Route 5 438E Repeated for Route 6 Installation Read Write Setting 43E0 Relay Programmed State 0 to 1 1 F133 0 Not Programmed 43E1 Relay Name F202 Relay 1 User Programmable Self Tests ...

Page 625: ... Power System Read Write Setting 4600 Nominal Frequency 25 to 60 Hz 1 F001 60 4601 Phase Rotation 0 to 1 1 F106 0 ABC 4602 Frequency and Phase Reference 0 to 5 1 F167 0 SRC 1 4603 Frequency Tracking Function 0 to 1 1 F102 1 Enabled Change Phase Rotation Read Write Setting 4604 Change Phase Rotation 0 to 4294967295 1 F300 0 Breaker Control Read Write Settings 4 modules 47D0 Breaker 1 Function 0 to ...

Page 626: ...d for User Definable Display 12 4D80 Repeated for User Definable Display 13 4DA0 Repeated for User Definable Display 14 4DC0 Repeated for User Definable Display 15 4DE0 Repeated for User Definable Display 16 Field Unit Raw Data Actuals Read Only 8 modules 4E00 Raw Field Data AC1 Mag 0 to 0 001 A 0 001 F003 0 4E02 Raw Field Data AC1 Angle 0 to 0 1 degree 0 1 F002 0 4E03 Raw Field Data AC2 Mag 0 to ...

Page 627: ...xLogic Entry 512 items 0 to 4294967295 1 F300 2097152 RTD Inputs Read Write Setting 48 modules 5400 RTD Input 1 Function 0 to 1 1 F102 0 Disabled 5401 RTD Input 1 ID F205 RTD Ip 1 5407 RTD Input 1 Type 0 to 3 1 F174 0 100 ohm Platinum 5408 RTD Input 1 Application 0 to 5 1 F550 0 None 5409 RTD Input 1 Alarm Temperature 1 to 249 C 1 F001 130 540A RTD Input 1 Alarm Pickup Delay 0 to 600 s 0 01 F001 0...

Page 628: ...peated for RTD Input 45 5784 Repeated for RTD Input 46 5798 Repeated for RTD Input 47 57AC Repeated for RTD Input 48 FlexLogic Timers Read Write Setting 32 modules 5800 FlexLogic Timer 1 Type 0 to 2 1 F129 0 millisecond 5801 FlexLogic Timer 1 Pickup Delay 0 to 60000 1 F001 0 5802 FlexLogic Timer 1 Dropout Delay 0 to 60000 1 F001 0 5803 Reserved 5 items 0 to 65535 1 F001 0 5808 Repeated for FlexLog...

Page 629: ...ignal Source 0 to 5 1 F167 0 SRC 1 5A02 Phase Instantaneous Overcurrent 1 Pickup 0 to 30 pu 0 001 F001 1000 5A03 Phase Instantaneous Overcurrent 1 Delay 0 to 600 s 0 01 F001 0 5A04 Phase Instantaneous Overcurrent 1 Reset Delay 0 to 600 s 0 01 F001 0 5A05 Phase IOC1 Block For Each Phase 3 items 0 to 4294967295 1 F300 0 5A0B Phase Instantaneous Overcurrent 1 Target 0 to 2 1 F109 0 Self reset 5A0C Ph...

Page 630: ... Reset Delay 0 to 600 s 0 01 F001 0 5DA5 Ground Instantaneous Overcurrent 1 Block 0 to 4294967295 1 F300 0 5DA7 Ground Instantaneous Overcurrent 1 Target 0 to 2 1 F109 0 Self reset 5DA8 Ground Instantaneous Overcurrent 1 Events 0 to 1 1 F102 0 Disabled 5DA9 Reserved 8 items 0 to 1 1 F001 0 CT Fail Read Write Setting 6 modules 5E6C CT Fail 1 Function 0 to 1 1 F102 0 Disabled 5E6D CT Fail 1 Block 0 ...

Page 631: ... 800 6426 Stator Differential Block 0 to 4294967295 1 F300 0 6428 Stator Differential Targets 0 to 2 1 F109 0 Self reset 6429 Stator Differential Events 0 to 1 1 F102 0 Disabled 642A Stator Differential Line End Source 0 to 5 1 F167 0 SRC 1 642B Stator Differential Neutral End Source 0 to 5 1 F167 0 SRC 1 Negative Sequence Overvoltage Read Write Grouped Setting 3 modules 6440 Negative Sequence Ove...

Page 632: ...7 Power Swing Detect Quad Forward Middle 0 1 to 500 ohms 0 01 F001 6000 65D8 Power Swing Detect Quad Forward Outer 0 1 to 500 ohms 0 01 F001 7000 65D9 Power Swing Detect Quad Reverse Middle 0 1 to 500 ohms 0 01 F001 6000 65DA Power Swing Detect Quad Reverse Outer 0 1 to 500 ohms 0 01 F001 7000 65DB Power Swing Detect Outer Right Blinder 0 1 to 500 ohms 0 01 F001 10000 65DC Power Swing Detect Outer...

Page 633: ...00 6687 Sensitive Directional Power 1 STG2 Delay 0 to 600 s 0 01 F001 2000 6688 Sensitive Directional Power 1 Block 0 to 4294967295 1 F300 0 668A Sensitive Directional Power 1 Target 0 to 2 1 F109 0 Self reset 668B Sensitive Directional Power 1 Events 0 to 1 1 F102 0 Disabled 668C Reserved 5 items 0 to 65535 1 F001 0 6691 Repeated for Sensitive Directional Power 2 Third Harmonic Neutral Undervolta...

Page 634: ... Ground Stage 2 Pickup 0 to 0 9 pu 0 001 F001 150 6725 Stator Ground Stage 2 Pickup Delay 0 to 600 s 0 01 F001 0 6726 Stator Ground Stage 2 Supv 0 001 to 0 1 pu 0 0001 F001 45 6727 Stator Ground Block 0 to 4294967295 1 F300 0 6729 Stator Ground Target 0 to 2 1 F109 0 Self reset 672A Stator Ground Event 0 to 1 1 F102 0 Disabled 672B Reserved 5 items 0 to 65535 1 F001 0 Split Phase Protection Read W...

Page 635: ...64 Force Memory Polarization 0 to 4294967295 1 F300 0 Phase Distance Read Write Grouped Setting 3 modules 7070 Phase Distance Zone 1 Function 0 to 1 1 F102 0 Disabled 7071 Phase Distance Zone 1 Current Supervision 0 05 to 30 pu 0 001 F001 200 7072 Phase Distance Zone 1 Reach 0 02 to 500 ohms 0 01 F001 200 7073 Phase Distance Zone 1 Direction 0 to 2 1 F154 0 Forward 7074 Phase Distance Zone 1 Compa...

Page 636: ...egative Sequence Directional Overcurrent Read Write Grouped Settings 2 modules 7260 Negative Sequence Directional Overcurrent 1 Function 0 to 1 1 F102 0 Disabled 7261 Negative Sequence Directional Overcurrent 1 Source 0 to 5 1 F167 0 SRC 1 7262 Negative Sequence Directional Overcurrent 1 Type 0 to 1 1 F179 0 Neg Sequence 7263 Neg Sequence Directional Overcurrent 1 Forward ECA 0 to 90 Lag 1 F002 75...

Page 637: ... Thermal Protection 1 Minimum Reset Time 0 to 1000 min 1 F001 20 778F Thermal Protection 1 Reset 0 to 4294967295 1 F300 0 7791 Thermal Protection 1 Block 0 to 4294967295 1 F300 0 7793 Thermal Protection 1 Target 0 to 2 1 F109 0 Self reset 7794 Thermal Protection 1 Events 0 to 1 1 F102 0 Disabled 7795 Reserved 2 items F001 0 7797 Repeated for Thermal Protection 2 Ohm Inputs Read Write Setting 2 mod...

Page 638: ...13000 78A3 PMU 1 Phase C Current Test Magnitude 0 to 9 999 kA 0 001 F003 1000 78A5 PMU 1 Phase C Current Test Angle 180 to 180 0 05 F002 11000 78A6 PMU 1 Ground Current Test Magnitude 0 to 9 999 kA 0 001 F004 0 78A8 PMU 1 Ground Current Test Angle 180 to 180 0 05 F002 0 78A9 PMU 1 Test Frequency 20 to 70 Hz 0 001 F003 60000 78AB PMU 1 Test df dt 10 to 10 Hz s 0 01 F002 0 Phasor Measurement Unit Re...

Page 639: ...ection Settings Read Write Grouped Setting 7A60 Field Current Function 0 to 1 1 F102 0 Disabled 7A61 Field Current Origin 0 to 48 1 F151 0 NONE 7A62 Field Current OC Pickup 0 05 to 1 pu 0 01 F001 80 7A63 Field Current OC Delay 0 to 600 s 0 01 F001 100 7A64 Field Current UC Pickup 0 05 to 1 pu 0 01 F001 20 7A65 Field Current UC Delay 0 to 600 s 0 01 F001 100 7A66 Field Current Block 0 to 4294967295...

Page 640: ...1 F300 0 7B8D User Programmable Pushbutton 1 Set Operand 0 to 4294967295 1 F300 0 7B8F User Programmable Pushbutton 1 Hold 0 to 10 s 0 1 F001 1 7B90 Repeated for User Programmable Pushbutton 2 7BC0 Repeated for User Programmable Pushbutton 3 7BF0 Repeated for User Programmable Pushbutton 4 7C20 Repeated for User Programmable Pushbutton 5 7C50 Repeated for User Programmable Pushbutton 6 7C80 Repeat...

Page 641: ...ed for Auxiliary Overvoltage 3 Frequency Read Only 8000 Tracking Frequency 2 to 90 Hz 0 01 F001 0 Temp Monitor Actual Values Read Only Non Volatile 81C0 Reserved Register T1 55 to 125 C 1 F002 55 81C1 Reserved Register T2 55 to 125 C 1 F002 125 81C2 Reserved Register T3 2147483647 to 2147483647 1 F004 0 81C4 Reserved Register T4 0 to 4294967295 1 F003 0 81C6 Reserved Register T5 0 to 4294967295 1 ...

Page 642: ... 1 Phase Amp Hiset Pickup 0 001 to 30 pu 0 001 F001 1050 8618 Breaker Failure 1 Neutral Amp Hiset Pickup 0 001 to 30 pu 0 001 F001 1050 8619 Breaker Failure 1 Phase Amp Loset Pickup 0 001 to 30 pu 0 001 F001 1050 861A Breaker Failure 1 Neutral Amp Loset Pickup 0 001 to 30 pu 0 001 F001 1050 861B Breaker Failure 1 Loset Time 0 to 65 535 s 0 001 F001 0 861C Breaker Failure 1 Trip Dropout Delay 0 to ...

Page 643: ...tal Element 9 8AC6 Repeated for Digital Element 10 8ADC Repeated for Digital Element 11 8AF2 Repeated for Digital Element 12 8B08 Repeated for Digital Element 13 8B1E Repeated for Digital Element 14 8B34 Repeated for Digital Element 15 8B4A Repeated for Digital Element 16 8B60 Repeated for Digital Element 17 8B76 Repeated for Digital Element 18 8B8C Repeated for Digital Element 19 8BA2 Repeated fo...

Page 644: ...9001 FlexElement 1 Name F206 FxE 1 9004 FlexElement 1 InputP 0 to 65535 1 F600 0 9005 FlexElement 1 InputM 0 to 65535 1 F600 0 9006 FlexElement 1 Compare 0 to 1 1 F516 0 LEVEL 9007 FlexElement 1 Input 0 to 1 1 F515 0 SIGNED 9008 FlexElement 1 Direction 0 to 1 1 F517 0 OVER 9009 FlexElement 1 Hysteresis 0 1 to 50 0 1 F001 30 900A FlexElement 1 Pickup 90 to 90 pu 0 001 F004 1000 900C FlexElement 1 D...

Page 645: ... for module number 7 92EC Repeated for module number 8 9300 Repeated for module number 9 9314 Repeated for module number 10 9328 Repeated for module number 11 933C Repeated for module number 12 DCmA Outputs Read Write Setting 24 modules 9360 DCmA Output 1 Source 0 to 65535 1 F600 0 9361 DCmA Output 1 Range 0 to 2 1 F522 0 1 to 1 mA 9362 DCmA Output 1 Minimum 90 to 90 pu 0 001 F004 0 9364 DCmA Outp...

Page 646: ...put Output 22 9508 Repeated for Direct Input Output 23 9514 Repeated for Direct Input Output 24 9520 Repeated for Direct Input Output 25 952C Repeated for Direct Input Output 26 9538 Repeated for Direct Input Output 27 9544 Repeated for Direct Input Output 28 9550 Repeated for Direct Input Output 29 955C Repeated for Direct Input Output 30 9568 Repeated for Direct Input Output 31 9574 Repeated for...

Page 647: ...tection Local Relay ID 0 to 255 1 F001 0 9994 Teleprotection Terminal 1 ID 0 to 255 1 F001 0 9995 Teleprotection Terminal 2 ID 0 to 255 1 F001 0 9996 Reserved 10 items 0 to 1 1 F001 0 9A00 Teleprotection Input 1 n Default States 16 items 0 to 3 1 F086 0 Off 9A10 Teleprotection Input 2 n Default States 16 items 0 to 3 1 F086 0 Off 9A20 Teleprotection Output 1 n Operand 16 items 0 to 4294967295 1 F3...

Page 648: ...ounter 1 Up 0 to 4294967295 1 F300 0 A30E Digital Counter 1 Down 0 to 4294967295 1 F300 0 A311 Digital Counter 1 Preset 2147483647 to 2147483647 1 F004 0 A313 Digital Counter 1 Compare 2147483647 to 2147483647 1 F004 0 A315 Digital Counter 1 Reset 0 to 4294967295 1 F300 0 A317 Digital Counter 1 Freeze Reset 0 to 4294967295 1 F300 0 A319 Digital Counter 1 Freeze Count 0 to 4294967295 1 F300 0 A31B ...

Page 649: ...tile Latch 15 A7B4 Repeated for Non Volatile Latch 16 Frequency Rate of Change Read Write Setting 4 modules A900 Frequency Rate of Change 1 Function 0 to 1 1 F102 0 Disabled A901 Frequency Rate of Change 1 OC Supervision 0 to 30 pu 0 001 F001 200 A902 Frequency Rate of Change 1 Min 20 to 80 Hz 0 01 F001 4500 A903 Frequency Rate of Change 1 Max 20 to 80 Hz 0 01 F001 6500 A904 Frequency Rate of Chan...

Page 650: ...850 GOOSE Analog Input 12 AA54 Repeated for IEC 61850 GOOSE Analog Input 13 AA5B Repeated for IEC 61850 GOOSE Analog Input 14 AA62 Repeated for IEC 61850 GOOSE Analog Input 15 AA69 Repeated for IEC 61850 GOOSE Analog Input 16 AA70 Repeated for IEC 61850 GOOSE Analog Input 17 AA77 Repeated for IEC 61850 GOOSE Analog Input 18 AA7E Repeated for IEC 61850 GOOSE Analog Input 19 AA85 Repeated for IEC 61...

Page 651: ... F206 none AE54 IEC 61850 Logical Node XSWIx Name Prefix 24 items 0 to 65534 1 F206 none IEC 61850 GGIO4 General Analog Configuration Settings Read Write Setting AF00 Number of Analog Input Points in GGIO4 4 to 32 4 F001 4 IEC 61850 GGIO4 Analog Input Points Configuration Settings Read Write Setting 32 modules AF10 IEC 61850 GGIO4 Analog Input 1 Value F600 0 AF11 IEC 61850 GGIO4 Analog Input 1 Dea...

Page 652: ...ng Function 0 to 1 1 F102 0 Disabled B0B7 IEC 61850 LPHD Latitude 90 to 90 degrees 0 001 F004 0 B0B9 IEC 61850 LPHD DC PhyNam Longitude 180 to 180 degrees 0 001 F004 0 B9BB IEC 61850 LPHD DC PhyNam Altitude 0 to 10000 m 1 F003 0 B0BD Reserved 3 items 0 to 1 1 F001 0 IEC 61850 MMXU Deadbands Read Write Setting 6 modules B0C0 IEC 61850 MMXU TotW Deadband 1 0 001 to 100 0 001 F003 10000 B0C2 IEC 6185...

Page 653: ...Received Analog 10 B224 Repeated for Received Analog 11 B226 Repeated for Received Analog 12 B228 Repeated for Received Analog 13 B22A Repeated for Received Analog 14 B22C Repeated for Received Analog 15 B22E Repeated for Received Analog 16 B230 Repeated for Received Analog 17 B232 Repeated for Received Analog 18 B234 Repeated for Received Analog 19 B236 Repeated for Received Analog 20 B238 Repeat...

Page 654: ...ble GOOSE Function GoEna 0 to 1 1 F102 1 Enabled B5A1 IEC 61850 Configurable GOOSE ID F209 GOOSEOut_x_ B5C2 Configurable GOOSE Destination MAC Address F072 0 B5C5 IEC 61850 Configurable GOOSE VLAN Transmit Priority 0 to 7 1 F001 4 B5C6 IEC 61850 Configurable GOOSE VLAN ID 0 to 4095 1 F001 0 B5C7 IEC 61850 Configurable GOOSE ETYPE APPID 0 to 16383 1 F001 0 B5C8 IEC 61850 Configurable GOOSE ConfRev ...

Page 655: ...tact Input 14 BB70 Repeated for Contact Input 15 BB78 Repeated for Contact Input 16 BB80 Repeated for Contact Input 17 BB88 Repeated for Contact Input 18 BB90 Repeated for Contact Input 19 BB98 Repeated for Contact Input 20 BBA0 Repeated for Contact Input 21 BBA8 Repeated for Contact Input 22 BBB0 Repeated for Contact Input 23 BBB8 Repeated for Contact Input 24 BBC0 Repeated for Contact Input 25 B...

Page 656: ... BD28 Repeated for Contact Input 70 BD30 Repeated for Contact Input 71 BD38 Repeated for Contact Input 72 BD40 Repeated for Contact Input 73 BD48 Repeated for Contact Input 74 BD50 Repeated for Contact Input 75 BD58 Repeated for Contact Input 76 BD60 Repeated for Contact Input 77 BD68 Repeated for Contact Input 78 BD70 Repeated for Contact Input 79 BD78 Repeated for Contact Input 80 BD80 Repeated ...

Page 657: ... for Virtual Input 19 BF14 Repeated for Virtual Input 20 BF20 Repeated for Virtual Input 21 BF2C Repeated for Virtual Input 22 BF38 Repeated for Virtual Input 23 BF44 Repeated for Virtual Input 24 BF50 Repeated for Virtual Input 25 BF5C Repeated for Virtual Input 26 BF68 Repeated for Virtual Input 27 BF74 Repeated for Virtual Input 28 BF80 Repeated for Virtual Input 29 BF8C Repeated for Virtual In...

Page 658: ... for Virtual Output 7 C168 Repeated for Virtual Output 8 C170 Repeated for Virtual Output 9 C178 Repeated for Virtual Output 10 C180 Repeated for Virtual Output 11 C188 Repeated for Virtual Output 12 C190 Repeated for Virtual Output 13 C198 Repeated for Virtual Output 14 C1A0 Repeated for Virtual Output 15 C1A8 Repeated for Virtual Output 16 C1B0 Repeated for Virtual Output 17 C1B8 Repeated for Vi...

Page 659: ...for Virtual Output 61 C318 Repeated for Virtual Output 62 C320 Repeated for Virtual Output 63 C328 Repeated for Virtual Output 64 C330 Repeated for Virtual Output 65 C338 Repeated for Virtual Output 66 C340 Repeated for Virtual Output 67 C348 Repeated for Virtual Output 68 C350 Repeated for Virtual Output 69 C358 Repeated for Virtual Output 70 C360 Repeated for Virtual Output 71 C368 Repeated for ...

Page 660: ...erand 0 to 4294967295 1 F300 0 C46C Clear Unauthorized Access Operand 0 to 4294967295 1 F300 0 C470 Clear Platform Direct Input Output Statistics Operand 0 to 4294967295 1 F300 0 C472 Reserved 13 items F001 0 Platform Direct Outputs Read Write Setting 32 modules C600 Direct Output 1 Operand 0 to 4294967295 1 F300 0 C602 Direct Output 1 Events 0 to 1 1 F102 0 Disabled C603 Repeated for Direct Outpu...

Page 661: ...to 1 1 F126 0 No C882 Platform Direct I O Data Rate 64 to 128 kbps 64 F001 64 C883 Direct I O Channel 2 Ring Configuration Function 0 to 1 1 F126 0 No C884 Platform Direct I O Crossover Function 0 to 1 1 F102 0 Disabled Direct Input Output Commands Read Write Command C888 Direct Input Output Clear Counters Command 0 to 1 1 F126 0 No Direct Inputs Read Write Setting 32 modules C890 Direct Input 1 D...

Page 662: ...ed Messages Alarm Function 0 to 1 1 F102 0 Disabled CAE1 Direct Input Output Ch 1 Unreturned Messages Alarm Msg Count 100 to 10000 1 F001 600 CAE2 Direct Input Output Ch 1 Unreturned Messages Alarm Threshold 1 to 1000 1 F001 10 CAE3 Direct Input Output Ch 1 Unreturned Messages Alarm Events 0 to 1 1 F102 0 Disabled CAE4 Reserved 4 items 1 to 1000 1 F001 10 CAE8 Direct Input Output Ch 2 Unreturned M...

Page 663: ... for Remote Input 15 D036 Repeated for Remote Input 16 D040 Repeated for Remote Input 17 D04A Repeated for Remote Input 18 D054 Repeated for Remote Input 19 D05E Repeated for Remote Input 20 D068 Repeated for Remote Input 21 D072 Repeated for Remote Input 22 D07C Repeated for Remote Input 23 D086 Repeated for Remote Input 24 D090 Repeated for Remote Input 25 D09A Repeated for Remote Input 26 D0A4 ...

Page 664: ...St 1 Operand 0 to 4294967295 1 F300 0 D2A2 Remote Output UserSt 1 Events 0 to 1 1 F102 0 Disabled D2A3 Reserved 2 items 0 to 1 1 F001 0 D2A4 Repeated for Remote Output 2 D2A8 Repeated for Remote Output 3 D2AC Repeated for Remote Output 4 D2B0 Repeated for Remote Output 5 D2B4 Repeated for Remote Output 6 D2B8 Repeated for Remote Output 7 D2BC Repeated for Remote Output 8 D2C0 Repeated for Remote O...

Page 665: ...SO22 ctlModel Value 0 to 2 1 F001 1 D336 IEC 61850 GGIO2 CF SPCSO23 ctlModel Value 0 to 2 1 F001 1 D337 IEC 61850 GGIO2 CF SPCSO24 ctlModel Value 0 to 2 1 F001 1 D338 IEC 61850 GGIO2 CF SPCSO25 ctlModel Value 0 to 2 1 F001 1 D339 IEC 61850 GGIO2 CF SPCSO26 ctlModel Value 0 to 2 1 F001 1 D33A IEC 61850 GGIO2 CF SPCSO27 ctlModel Value 0 to 2 1 F001 1 D33B IEC 61850 GGIO2 CF SPCSO28 ctlModel Value 0 ...

Page 666: ...3 D38C Repeated for Remote Device 4 D390 Repeated for Remote Device 5 D394 Repeated for Remote Device 6 D398 Repeated for Remote Device 7 D39C Repeated for Remote Device 8 D3A0 Repeated for Remote Device 9 D3A4 Repeated for Remote Device 10 D3A8 Repeated for Remote Device 11 D3AC Repeated for Remote Device 12 D3B0 Repeated for Remote Device 13 D3B4 Repeated for Remote Device 14 D3B8 Repeated for R...

Page 667: ...put 18 DD9E Repeated for Contact Output 19 DDAD Repeated for Contact Output 20 DDBC Repeated for Contact Output 21 DDCB Repeated for Contact Output 22 DDDA Repeated for Contact Output 23 DDE9 Repeated for Contact Output 24 DDF8 Repeated for Contact Output 25 DE07 Repeated for Contact Output 26 DE16 Repeated for Contact Output 27 DE25 Repeated for Contact Output 28 DE34 Repeated for Contact Output ...

Page 668: ...9 999 to 9999 999 0 001 F004 20000 E063 Repeated for DCmA Inputs 2 E076 Repeated for DCmA Inputs 3 E089 Repeated for DCmA Inputs 4 E09C Repeated for DCmA Inputs 5 E0AF Repeated for DCmA Inputs 6 E0C2 Repeated for DCmA Inputs 7 E0D5 Repeated for DCmA Inputs 8 E0E8 Repeated for DCmA Inputs 9 E0FB Repeated for DCmA Inputs 10 E10E Repeated for DCmA Inputs 11 E121 Repeated for DCmA Inputs 12 E134 Repea...

Page 669: ... 1 Control Block IP Address 0 to 4294967295 1 F003 0 E65E PMU Aggregator 1 Control Block Security 0 to 2 1 F001 0 DNP IEC Points Read Write Setting E700 DNP IEC 60870 5 104 Binary Input Points 256 items 0 to 4294967295 1 F300 0 E900 DNP IEC 60870 5 104 Analog Input Points 256 items 0 to 65535 1 F300 0 Synchrocheck Read Write Setting 4 modules EC00 Synchrocheck 1 Function 0 to 1 1 F102 0 Disabled E...

Page 670: ...equency Trigger Events 0 to 1 1 F102 0 Disabled Settings File Template Read Write Setting ED00 FlexLogic Displays Active 0 to 1 1 F102 1 Enabled ED01 Reserved F205 none Setting File Template Read Only Non Volatile ED07 Last Settings Change Date 0 to 4294967295 1 F050 0 Settings File Template Read Write Setting ED09 Template Bitmask 750 items 0 to 65535 1 F001 0 Phasor Measurement Unit Records Read...

Page 671: ...lues indicate leading F050 UR_UINT32 TIME and DATE UNSIGNED 32 BIT INTEGER Gives the current time in seconds elapsed since 00 00 00 January 1 1970 F051 UR_UINT32 DATE in SR format alternate format for F050 First 16 bits are Month Day MM DD xxxx Month 1 January 2 February 12 December Day 1 to 31 in steps of 1 Last 16 bits are Year xx xx YYYY 1970 to 2106 in steps of 1 F052 UR_UINT32 TIME in SR form...

Page 672: ...ort Inv 15 FlexCurve C 7 IAC Ext Inv 16 FlexCurve D 8 IAC Very Inv Bitmask Value Bitmask Value Bitmask Value 0 300 4 9600 8 115200 1 1200 5 19200 9 14400 2 2400 6 38400 10 28800 3 4800 7 57600 11 33600 Mask Value Mask Value Mask Value Mask Value 0 0 00 30 0 88 60 2 90 90 5 90 1 0 05 31 0 90 61 3 00 91 6 00 2 0 10 32 0 91 62 3 10 92 6 50 3 0 15 33 0 92 63 3 20 93 7 00 4 0 20 34 0 93 64 3 30 94 7 50...

Page 673: ... Phase Undervoltage 3 148 Auxiliary Overvoltage 1 149 Auxiliary Overvoltage 2 150 Auxiliary Overvoltage 3 152 Phase Overvoltage 1 156 Neutral Overvoltage 1 157 Neutral Overvoltage 2 158 Neutral Overvoltage 3 160 Phase Distance Zone 1 161 Phase Distance Zone 2 162 Phase Distance Zone 3 190 Power Swing Detect 210 Volt per Hertz 1 211 Volt per Hertz 2 214 Sensitive Directional Power 1 215 Sensitive D...

Page 674: ...ter 4 548 Digital Counter 5 549 Digital Counter 6 550 Digital Counter 7 551 Digital Counter 8 Bitmask Element 692 Digital Element 1 693 Digital Element 2 694 Digital Element 3 695 Digital Element 4 696 Digital Element 5 697 Digital Element 6 698 Digital Element 7 699 Digital Element 8 700 Digital Element 9 701 Digital Element 10 702 Digital Element 11 703 Digital Element 12 704 Digital Element 13 ...

Page 675: ...shbutton 3 903 User Programmable Pushbutton 4 904 User Programmable Pushbutton 5 905 User Programmable Pushbutton 6 906 User Programmable Pushbutton 7 907 User Programmable Pushbutton 8 908 User Programmable Pushbutton 9 909 User Programmable Pushbutton 10 910 User Programmable Pushbutton 11 911 User Programmable Pushbutton 12 912 User Programmable Pushbutton 13 913 User Programmable Pushbutton 14...

Page 676: ...ermal overload protection 2 Bitmask Element Bitmask Error 0 Any Self Tests 1 IRIG B Failure 2 Port 1 Offline 3 Port 2 Offline 4 Port 3 Offline 5 Port 4 Offline 6 Port 5 Offline 7 Port 6 Offline 8 RRTD Communications Failure 9 Voltage Monitor 10 FlexLogic Error Token 11 Equipment Mismatch 12 Process Bus Failure 13 Unit Not Programmed 14 System Exception 15 Latching Output Discrepancy 17 Maintenance...

Page 677: ...lay Out Of Service 10 Watchdog Reset 11 Oscillography Clear 12 Reboot Command 13 Led Test Initiated 14 Flash Programming Bitmask Error 15 Fault Report Trigger 16 User Programmable Fault Report Trigger 17 18 Reload CT VT module Settings 19 20 Ethernet Port 1 Offline 21 Ethernet Port 2 Offline 22 Ethernet Port 3 Offline 23 Ethernet Port 4 Offline 24 Ethernet Port 5 Offline 25 Ethernet Port 6 Offline...

Page 678: ...ne 35 UserSt 3 1 DNA 1 36 UserSt 4 2 DNA 2 37 UserSt 5 3 DNA 3 38 UserSt 6 4 DNA 4 39 UserSt 7 5 DNA 5 40 UserSt 8 6 DNA 6 41 UserSt 9 7 DNA 7 42 UserSt 10 8 DNA 8 43 UserSt 11 9 DNA 9 44 UserSt 12 10 DNA 10 45 UserSt 13 11 DNA 11 46 UserSt 14 12 DNA 12 47 UserSt 15 13 DNA 13 48 UserSt 16 14 DNA 14 49 UserSt 17 15 DNA 15 50 UserSt 18 16 DNA 16 51 UserSt 19 17 DNA 17 52 UserSt 20 18 DNA 18 53 UserS...

Page 679: ...V2 Bitmask Definition 0 Off 1 8 samples cycle 2 16 samples cycle 3 32 samples cycle 4 64 samples cycle Value IEC 61850 dataset 0 Off 1 GooseIn 1 2 GooseIn 2 3 GooseIn 3 4 GooseIn 4 5 GooseIn 5 6 GooseIn 6 7 GooseIn 7 8 GooseIn 8 9 GooseIn 9 10 GooseIn 10 11 GooseIn 11 12 GooseIn 12 13 GooseIn 13 14 GooseIn 14 15 GooseIn 15 16 GooseIn 16 Bitmask Keypress Bitmask Keypress 0 No key use between real k...

Page 680: ...ECTIONAL POLARIZING 0 Voltage 1 Current 2 Dual 3 Dual V 4 Dual I F231 ENUMERATION POLARIZING VOLTAGE 0 Calculated V0 1 Measured VX F232 ENUMERATION CONFIGURABLE GOOSE Tx DATASET ITEMS Value Priority 0 Disabled 1 Normal 2 High Priority Value IEC 61850 Tx dataset item 0 None 1 GGIO1 ST Ind1 q 2 GGIO1 ST Ind1 stVal 3 GGIO1 ST Ind2 q 4 GGIO1 ST Ind2 stVal 255 GGIO1 ST Ind128 q 256 GGIO1 ST Ind128 stVa...

Page 681: ...MX PF phsA cVal mag f 329 MMXU2 MX PF phsB cVal mag f 330 MMXU2 MX PF phsC cVal mag f 331 MMXU3 MX TotW mag f Value IEC 61850 Tx dataset item 332 MMXU3 MX TotVAr mag f 333 MMXU3 MX TotVA mag f 334 MMXU3 MX TotPF mag f 335 MMXU3 MX Hz mag f 336 MMXU3 MX PPV phsAB cVal mag f 337 MMXU3 MX PPV phsAB cVal ang f 338 MMXU3 MX PPV phsBC cVal mag f 339 MMXU3 MX PPV phsBC cVal ang f 340 MMXU3 MX PPV phsCA c...

Page 682: ...phsA cVal mag f 434 MMXU5 MX VAr phsB cVal mag f 435 MMXU5 MX VAr phsC cVal mag f 436 MMXU5 MX VA phsA cVal mag f 437 MMXU5 MX VA phsB cVal mag f Value IEC 61850 Tx dataset item 438 MMXU5 MX VA phsC cVal mag f 439 MMXU5 MX PF phsA cVal mag f 440 MMXU5 MX PF phsB cVal mag f 441 MMXU5 MX PF phsC cVal mag f 442 MMXU6 MX TotW mag f 443 MMXU6 MX TotVAr mag f 444 MMXU6 MX TotVA mag f 445 MMXU6 MX TotPF ...

Page 683: ...In12 stVal 535 GGIO5 ST UIntIn13 q 536 GGIO5 ST UIntIn13 stVal 537 GGIO5 ST UIntIn14 q 538 GGIO5 ST UIntIn14 stVal 539 GGIO5 ST UIntIn15 q 540 GGIO5 ST UIntIn15 stVal 541 GGIO5 ST UIntIn16 q 542 GGIO5 ST UIntIn16 stVal Value IEC 61850 Tx dataset item Value IEC 61850 GOOSE Rx dataset item 0 None 1 GGIO3 ST Ind1 q 2 GGIO3 ST Ind1 stVal 3 GGIO3 ST Ind2 q 4 GGIO3 ST Ind2 stVal 127 GGIO1 ST Ind64q 128 ...

Page 684: ...4 stVal 174 GGIO3 ST UIntIn5 q 175 GGIO3 ST UIntIn5 stVal 176 GGIO3 ST UIntIn6 q 177 GGIO3 ST UIntIn6 stVal 178 GGIO3 ST UIntIn7 q 179 GGIO3 ST UIntIn7 stVal 180 GGIO3 ST UIntIn8 q 181 GGIO3 ST UIntIn8 stVal 182 GGIO3 ST UIntIn9 q 183 GGIO3 ST UIntIn9 stVal 184 GGIO3 ST UIntIn10 q 185 GGIO3 ST UIntIn10 stVal 186 GGIO3 ST UIntIn11 q 187 GGIO3 ST UIntIn11 stVal 188 GGIO3 ST UIntIn12 q 189 GGIO3 ST U...

Page 685: ... OK 2 Communications Trouble 3 Equip ment Mismatch 4 Brick Trouble 1 1 1mA 2 0 1mA 3 0 1mA 4 0 5mA 5 0 10mA 6 0 20mA 7 4 20mA 8 potentiometer 9 tap position Value Description 0 None 1 U1 AC1 3 2 U1 AC5 7 3 U2 AC1 3 4 U2 AC5 7 5 U3 AC1 3 6 U3 AC5 7 7 U4 AC1 3 8 U4 AC5 7 9 U5 AC1 3 10 U5 AC5 7 11 U6 AC1 3 12 U6 AC5 7 13 U7 AC1 3 14 U7 AC5 7 15 U8 AC1 3 16 U8 AC5 7 Value Description 0 None 1 U1 AC4 2...

Page 686: ...IMER 1 to 32 50 ASSIGN VIRTUAL OUTPUT 1 to 64 52 ONE SHOT 54 SELF TEST ERROR see F141 for range 56 PLATFORM DIRECT INPUT 1 to 96 58 PLATFORM DIRECT OUTPUT 1 to 96 60 PLATFORM DIRECT DEVICE 1 to 8 62 MISCELLANEOUS EVENTS see F146 for range 64 PDC NETWORK CONTROL 66 PMU RECORDERE OUT OF MEMORY 68 PMU RECORDER STOPPED 128 to 255 ELEMENT STATES see the Element States section in the Modbus memory map F...

Page 687: ... ENUMERATION LANGUAGE 0 English 1 French 2 Chinese 3 Russian 4 Turkish x F542 ENUMERATION PMU TRIGGERING MODE 0 Automatic Overwrite 1 Protected F543 ENUMERATION PMU PHASORS Bitmask Default variation 0 1 1 2 2 5 3 6 Bitmask Default variation 0 1 1 2 2 9 3 10 Bitmask Default variation 0 1 1 2 2 3 3 4 4 5 5 7 Value Keypress Value Keypress Value Keypress 0 None 15 3 33 User PB 3 1 Menu 16 Enter 34 Use...

Page 688: ...y all metering quantities used in protection F601 ENUMERATION COM2 PORT USAGE F602 ENUMERATION RRTD BAUD RATE Value Rate Value Rate 0 1 second 7 20second 1 2 second 8 25 second 2 4 second 9 30 second 3 5 second 10 50 second 4 10 second 11 60 second 5 12 second 12 100 second 6 15 second 13 120 second Enumeration RTD input application 0 None 1 Stator 2 Bearing 3 Ambient 4 Group 1 5 Group 2 Enumerati...

Page 689: ...3 Bad Enumeration Remote double point status input 0 None 1 Remote input 1 2 Remote input 2 3 Remote input 3 64 Remote input 64 Enumeration Configurable GOOSE retransmission scheme 0 Heartbeat 1 Aggressive 2 Medium 3 Relaxed Enumeration Connection type 0 Single point 1 Double point Enumeration IEC 61850 report dataset items 0 None 1 PDIF1 ST Str general 2 PDIF1 ST Op general 3 PDIF2 ST Str general...

Page 690: ...5 PIOC29 ST Str general 86 PIOC29 ST Op general 87 PIOC30 ST Str general Enumeration IEC 61850 report dataset items 88 PIOC30 ST Op general 89 PIOC31 ST Str general 90 PIOC31 ST Op general 91 PIOC32 ST Str general 92 PIOC32 ST Op general 93 PIOC33 ST Str general 94 PIOC33 ST Op general 95 PIOC34 ST Str general 96 PIOC34 ST Op general 97 PIOC35 ST Str general 98 PIOC35 ST Op general 99 PIOC36 ST St...

Page 691: ...al 190 PTOC9 ST Op general 191 PTOC10 ST Str general 192 PTOC10 ST Op general 193 PTOC11 ST Str general Enumeration IEC 61850 report dataset items 194 PTOC11 ST Op general 195 PTOC12 ST Str general 196 PTOC12 ST Op general 197 PTOC13 ST Str general 198 PTOC13 ST Op general 199 PTOC14 ST Str general 200 PTOC14 ST Op general 201 PTOC15 ST Str general 202 PTOC15 ST Op general 203 PTOC16 ST Str genera...

Page 692: ... OpEx general 298 RBRF10 ST OpIn general 299 RBRF11 ST OpEx general Enumeration IEC 61850 report dataset items 300 RBRF11 ST OpIn general 301 RBRF12 ST OpEx general 302 RBRF12 ST OpIn general 303 RBRF13 ST OpEx general 304 RBRF13 ST OpIn general 305 RBRF14 ST OpEx general 306 RBRF14 ST OpIn general 307 RBRF15 ST OpEx general 308 RBRF15 ST OpIn general 309 RBRF16 ST OpEx general 310 RBRF16 ST OpIn ...

Page 693: ...03 CSWI29 ST Loc stVal 404 CSWI29 ST Pos stVal 405 CSWI30 ST Loc stVal Enumeration IEC 61850 report dataset items 406 CSWI30 ST Pos stVal 407 GGIO1 ST Ind1 stVal 408 GGIO1 ST Ind2 stVal 409 GGIO1 ST Ind3 stVal 410 GGIO1 ST Ind4 stVal 411 GGIO1 ST Ind5 stVal 412 GGIO1 ST Ind6 stVal 413 GGIO1 ST Ind7 stVal 414 GGIO1 ST Ind8 stVal 415 GGIO1 ST Ind9 stVal 416 GGIO1 ST Ind10 stVal 417 GGIO1 ST Ind11 st...

Page 694: ...Enumeration IEC 61850 report dataset items 512 GGIO1 ST Ind106 stVal 513 GGIO1 ST Ind107 stVal 514 GGIO1 ST Ind108 stVal 515 GGIO1 ST Ind109 stVal 516 GGIO1 ST Ind110 stVal 517 GGIO1 ST Ind111 stVal 518 GGIO1 ST Ind112 stVal 519 GGIO1 ST Ind113 stVal 520 GGIO1 ST Ind114 stVal 521 GGIO1 ST Ind115 stVal 522 GGIO1 ST Ind116 stVal 523 GGIO1 ST Ind117 stVal 524 GGIO1 ST Ind118 stVal 525 GGIO1 ST Ind119...

Page 695: ...hsAB cVal ang f 616 MMXU3 MX PPV phsBC cVal mag f 617 MMXU3 MX PPV phsBC cVal ang f Enumeration IEC 61850 report dataset items 618 MMXU3 MX PPV phsCA cVal mag f 619 MMXU3 MX PPV phsCA cVal ang f 620 MMXU3 MX PhV phsA cVal mag f 621 MMXU3 MX PhV phsA cVal ang f 622 MMXU3 MX PhV phsB cVal mag f 623 MMXU3 MX PhV phsB cVal ang f 624 MMXU3 MX PhV phsC cVal mag f 625 MMXU3 MX PhV phsC cVal ang f 626 MMX...

Page 696: ...g f 719 MMXU5 MX PF phsC cVal mag f 720 MMXU6 MX TotW mag f 721 MMXU6 MX TotVAr mag f 722 MMXU6 MX TotVA mag f 723 MMXU6 MX TotPF mag f Enumeration IEC 61850 report dataset items 724 MMXU6 MX Hz mag f 725 MMXU6 MX PPV phsAB cVal mag f 726 MMXU6 MX PPV phsAB cVal ang f 727 MMXU6 MX PPV phsBC cVal mag f 728 MMXU6 MX PPV phsBC cVal ang f 729 MMXU6 MX PPV phsCA cVal mag f 730 MMXU6 MX PPV phsCA cVal a...

Page 697: ...Pos stVal 821 XSWI17 ST Loc stVal 822 XSWI17 ST Pos stVal 823 XSWI18 ST Loc stVal 824 XSWI18 ST Pos stVal 825 XSWI19 ST Loc stVal 826 XSWI19 ST Pos stVal 827 XSWI20 ST Loc stVal 828 XSWI20 ST Pos stVal 829 XSWI21 ST Loc stVal Enumeration IEC 61850 report dataset items 830 XSWI21 ST Pos stVal 831 XSWI22 ST Loc stVal 832 XSWI22 ST Pos stVal 833 XSWI23 ST Loc stVal 834 XSWI23 ST Pos stVal 835 XSWI24 ...

Page 698: ... q 78 GGIO1 ST Ind39 stVal 79 GGIO1 ST Ind40 q 80 GGIO1 ST Ind40 stVal 81 GGIO1 ST Ind41 q Enumeration GOOSE dataset items 82 GGIO1 ST Ind41 stVal 83 GGIO1 ST Ind42 q 84 GGIO1 ST Ind42 stVal 85 GGIO1 ST Ind43 q 86 GGIO1 ST Ind43 stVal 87 GGIO1 ST Ind44 q 88 GGIO1 ST Ind44 stVal 89 GGIO1 ST Ind45 q 90 GGIO1 ST Ind45 stVal 91 GGIO1 ST Ind46 q 92 GGIO1 ST Ind46 stVal 93 GGIO1 ST Ind47 q 94 GGIO1 ST I...

Page 699: ...GIO1 ST Ind92 stVal 185 GGIO1 ST Ind93 q 186 GGIO1 ST Ind93 stVal 187 GGIO1 ST Ind94 q Enumeration GOOSE dataset items 188 GGIO1 ST Ind94 stVal 189 GGIO1 ST Ind95 q 190 GGIO1 ST Ind95 stVal 191 GGIO1 ST Ind96 q 192 GGIO1 ST Ind96 stVal 193 GGIO1 ST Ind97 q 194 GGIO1 ST Ind97 stVal 195 GGIO1 ST Ind98 q 196 GGIO1 ST Ind98 stVal 197 GGIO1 ST Ind99 q 198 GGIO1 ST Ind99 stVal 199 GGIO1 ST Ind100 q 200 ...

Page 700: ...U1 MX PF phsB cVal mag f 293 MMXU1 MX PF phsC cVal mag f Enumeration GOOSE dataset items 294 MMXU2 MX TotW mag f 295 MMXU2 MX TotVAr mag f 296 MMXU2 MX TotVA mag f 297 MMXU2 MX TotPF mag f 298 MMXU2 MX Hz mag f 299 MMXU2 MX PPV phsAB cVal mag f 300 MMXU2 MX PPV phsAB cVal ang f 301 MMXU2 MX PPV phsBC cVal mag f 302 MMXU2 MX PPV phsBC cVal ang f 303 MMXU2 MX PPV phsCA cVal mag f 304 MMXU2 MX PPV ph...

Page 701: ...X VAr phsA cVal mag f 397 MMXU4 MX VAr phsB cVal mag f 398 MMXU4 MX VAr phsC cVal mag f 399 MMXU4 MX VA phsA cVal mag f Enumeration GOOSE dataset items 400 MMXU4 MX VA phsB cVal mag f 401 MMXU4 MX VA phsC cVal mag f 402 MMXU4 MX PF phsA cVal mag f 403 MMXU4 MX PF phsB cVal mag f 404 MMXU4 MX PF phsC cVal mag f 405 MMXU5 MX TotW mag f 406 MMXU5 MX TotVAr mag f 407 MMXU5 MX TotVA mag f 408 MMXU5 MX ...

Page 702: ...GGIO4 MX AnIn20 mag f 499 GGIO4 MX AnIn21 mag f 500 GGIO4 MX AnIn22 mag f 501 GGIO4 MX AnIn23 mag f 502 GGIO4 MX AnIn24 mag f 503 GGIO4 MX AnIn25 mag f 504 GGIO4 MX AnIn26 mag f 505 GGIO4 MX AnIn27 mag f Enumeration GOOSE dataset items 506 GGIO4 MX AnIn28 mag f 507 GGIO4 MX AnIn29 mag f 508 GGIO4 MX AnIn30 mag f 509 GGIO4 MX AnIn31 mag f 510 GGIO4 MX AnIn32 mag f 511 GGIO5 ST UIntIn1 q 512 GGIO5 S...

Page 703: ...IOC19 ST Op general 609 PIOC20 ST Str general 610 PIOC20 ST Op general 611 PIOC21 ST Str general Enumeration GOOSE dataset items 612 PIOC21 ST Op general 613 PIOC22 ST Str general 614 PIOC22 ST Op general 615 PIOC23 ST Str general 616 PIOC23 ST Op general 617 PIOC24 ST Str general 618 PIOC24 ST Op general 619 PIOC25 ST Str general 620 PIOC25 ST Op general 621 PIOC26 ST Str general 622 PIOC26 ST Op...

Page 704: ...PIOC72 ST Str general 714 PIOC72 ST Op general 715 PTOC1 ST Str general 716 PTOC1 ST Op general 717 PTOC2 ST Str general Enumeration GOOSE dataset items 718 PTOC2 ST Op general 719 PTOC3 ST Str general 720 PTOC3 ST Op general 721 PTOC4 ST Str general 722 PTOC4 ST Op general 723 PTOC5 ST Str general 724 PTOC5 ST Op general 725 PTOC6 ST Str general 726 PTOC6 ST Op general 727 PTOC7 ST Str general 72...

Page 705: ...eral 822 RBRF1 ST OpIn general 823 RBRF2 ST OpEx general Enumeration GOOSE dataset items 824 RBRF2 ST OpIn general 825 RBRF3 ST OpEx general 826 RBRF3 ST OpIn general 827 RBRF4 ST OpEx general 828 RBRF4 ST OpIn general 829 RBRF5 ST OpEx general 830 RBRF5 ST OpIn general 831 RBRF6 ST OpEx general 832 RBRF6 ST OpIn general 833 RBRF7 ST OpEx general 834 RBRF7 ST OpIn general 835 RBRF8 ST OpEx general...

Page 706: ...tVal 925 CSWI19 ST Loc stVal 926 CSWI19 ST Pos stVal 927 CSWI20 ST Loc stVal 928 CSWI20 ST Pos stVal 929 CSWI21 ST Loc stVal Enumeration GOOSE dataset items 930 CSWI21 ST Pos stVal 931 CSWI22 ST Loc stVal 932 CSWI22 ST Pos stVal 933 CSWI23 ST Loc stVal 934 CSWI23 ST Pos stVal 935 CSWI24 ST Loc stVal 936 CSWI24 ST Pos stVal 937 CSWI25 ST Loc stVal 938 CSWI25 ST Pos stVal 939 CSWI26 ST Loc stVal 940...

Page 707: ...ST Pos stVal 991 XSWI22 ST Loc stVal 992 XSWI22 ST Pos stVal 993 XSWI23 ST Loc stVal 994 XSWI23 ST Pos stVal 995 XSWI24 ST Loc stVal 996 XSWI24 ST Pos stVal 997 XCBR1 ST Loc stVal 998 XCBR1 ST Pos stVal 999 XCBR2 ST Loc stVal 1000 XCBR2 ST Pos stVal 1001 XCBR3 ST Loc stVal 1002 XCBR3 ST Pos stVal 1003 XCBR4 ST Loc stVal 1004 XCBR4 ST Pos stVal 1005 XCBR5 ST Loc stVal 1006 XCBR5 ST Pos stVal 1007 X...

Page 708: ...MOTE DEVICE F627 ENUMERATION REDUNDANCY MODE F628 ENUMERATION SECURITY BYPASS ACCESS Disables security on local access remote access or both Enumeration Item 0 None 1 Network Port 1 2 Network Port 2 3 Network Port 3 Enumeration Item 0 None 1 Failover 2 PRP Enumeration Item 0 Disabled 1 Local and Remote 2 Local 3 Remote ...

Page 709: ... that all those involved with any IEC 61850 implementation obtain this document set C 1 2 COMMUNICATION PROFILES IEC 61850 specifies the use of the Manufacturing Message Specification MMS at the upper application layer for transfer of real time data This protocol has been in existence for several of years and provides a set of services suitable for the transfer of data within a substation LAN envi...

Page 710: ...lorer window click the Tools menu and access the SISCO File Transfer Utility 2 Select the Remote AR Name from the drop down list Available files appear in the File Specification area on the right side of the window 3 With the Copy option active select a file to transfer and click the Go button The file is copied and displays in the Local list on the left side of the window 4 Repeat the process to ...

Page 711: ...y be used for SOE logs since the buffering capability reduces the chances of missing data state changes Unbuffered reporting should generally be used for local status display C 2 3 GGIO2 DIGITAL CONTROL VALUES The GGIO2 logical node is available to provide access to the G60 virtual inputs Virtual inputs are single point control binary values that can be written by clients They are generally used a...

Page 712: ...r MMXU1 MX Hz frequency MMXU1 MX PPV phsAB phase AB voltage magnitude and angle MMXU1 MX PPV phsBC phase BC voltage magnitude and angle MMXU1 MX PPV phsCA Phase CA voltage magnitude and angle MMXU1 MX PhV phsA phase AG voltage magnitude and angle MMXU1 MX PhV phsB phase BG voltage magnitude and angle MMXU1 MX PhV phsC phase CG voltage magnitude and angle MMXU1 MX A phsA phase A current magnitude a...

Page 713: ... locator function The XCBR logical node is directly associated with the breaker control feature XCBR1 ST Loc This is the state of the XCBR1 local remote switch A setting is provided to assign a FlexLogic operand to determine the state When local mode is true IEC 61850 client commands will be rejected XCBR1 ST Opcnt This is an operation counter as defined in IEC 61850 Command settings are provided ...

Page 714: ...e of the last change of either the value or quality flags of the data item To accomplish this functionality all IEC 61850 data items must be regularly scanned for data changes and the timestamp updated when a change is detected regardless of the connection status of any IEC 61850 cli ents For applications where there is no IEC 61850 client in use the IEC 61850 SERVER SCANNING setting can be pro gr...

Page 715: ...ection for greater than two minutes the connection will be aborted by the G60 This frees up the con nection to be used by other clients Therefore when using IEC 61850 reporting clients should configure report control block items such that an integrity report will be issued at least every 2 minutes 120000 ms This ensures that the G60 will not abort the connection If other MMS data is being polled o...

Page 716: ... two pre defined data structures named DNA and UserSt Each DNA and UserSt item is referred to as a bit pair GSSE messages are transmit ted in response to state changes in any of the data points contained in the message GSSE messages always contain the same number of DNA and UserSt bit pairs Depending the on the configuration only some of these bit pairs may have val ues that are of interest to rec...

Page 717: ...d for applications that require GOOSE data transfer between UR series IEDs and devices from other manufacturers Fixed GOOSE is recommended for applications that require GOOSE data transfer between UR series IEDs IEC 61850 GOOSE messaging contains a number of configurable parameters all of which must be correct to achieve the successful transfer of data It is critical that the configured datasets a...

Page 718: ...NICATION IEC 61850 PROTOCOL GSSE GOOSE CONFIGURATION RECEPTION CONFIGURABLE GOOSE CONFIGURABLE GOOSE 1 CONFIG GSE 1 DATASET ITEMS settings menu Set ITEM 1 to GGIO3 ST Ind1 q to indicate quality flags for GGIO3 status indication 1 Set ITEM 2 to GGIO3 ST Ind1 stVal to indicate the status value for GGIO3 status indication 1 The reception dataset now contains a set of quality flags a single point stat...

Page 719: ...onfigured to use an automated multicast MAC scheme If the G60 destination MAC address setting is not a valid multicast address that is the least significant bit of the first byte is not set the address used as the destina tion MAC will be the same as the local MAC address but with the multicast bit set Thus if the local MAC address is 00 A0 F4 01 02 03 then the destination MAC address will be 01 A...

Page 720: ...ration process for IEC 61850 BDA Basic Data Attribute that is not structured DAI Instantiated Data Attribute DO Data Object type or instance depending on the context 842790A2 CDR Ethernet System configurator SCD file System specification tool SSD file System specification data ICD file 2 Process of creating ICD vendor 2 Creating ICD GE Multilin EnerVista UR Setup ICD file 1 IED UR series OR ICD fi...

Page 721: ...e SCD to set communication configuration parame ters that is required addresses reception GOOSE datasets IDs of incoming GOOSE datasets etc for the IED The IED configurator functionality is implemented in the GE Multilin EnerVista UR Setup software C 5 2 CONFIGURING IEC 61850 SETTINGS Before creating an ICD file the user can customize the IEC 61850 related settings for the IED For example the IED ...

Page 722: ...ators we recommend configuring transmission GOOSE for GE Multilin IEDs before creating the ICD and strictly within EnerVista UR Setup software or the front panel display access through the Settings Product Setup Com munications IEC 61850 GSSE GOOSE Configuration Transmission Tx Configurable GOOSE menu tree in EnerVista UR Setup Configurable reception GOOSE which includes eight configurable dataset...

Page 723: ...ess node contains the address parameters of the access point The GSE node provides the address element for stat ing the control block related address parameters where IdInst is the instance identification of the logical device within the IED on which the control block is located and cbName is the name of the control block The IED node describes the pre configuration of an IED its access points the...

Page 724: ...DataSet name Other DataSet elements FCDA fc doName daName IdInst prefix InClass InInst Other FCDA elements DOI name SDI name Val Text Other DOI elements GSEControl name datSet type confRev appID LN InType InClass prefix inst DataSet name FCDA IdInst prefix InClass InInst doName fc Other FCDA elements ReportControl name datSet intgPd rptID confRev buffered TrgOps dchg OptFields seqNum RptEnabled Ot...

Page 725: ...SDO The attribute DA has a func tional constraint and can either have a basic type be an enumeration or a structure of a DAType The DAType is built from BDA elements defining the structure elements which again can be BDA elements of have a base type such as DA Figure C 5 ICD FILE STRUCTURE DATATYPETEMPLATES NODE 842798A1 CDR DataTypeTemplates LNodeType id InClass DO name type Other LNodeType eleme...

Page 726: ... procedure is pretty much the same First a substation project must be created either as an empty template or with some system information by importing a system specification file SSD Then IEDs are added to the substation Since each IED is represented by its associated ICD the ICD files are imported into the substation project and the system configurator validates the ICD files during the importing...

Page 727: ...file and its version and specifies options for the mapping of names to signals The Substation node describes the substation parameters Figure C 7 SCD FILE STRUCTURE SUBSTATION NODE 842791A1 CDR SCL Header id version revision toolID nameStructure IED Section IED 2 Communication IED Section IED 1 Substation Other IED Sections DataTypeTemplates 842792A1 CDR Substation EquipmentContainer VoltageLevel ...

Page 728: ...ectedAP node describes the IED access point connected to this sub network The Address node contains the address parameters of the access point The GSE node provides the address element for stat ing the control block related address parameters where IdInst is the instance identification of the logical device within the IED on which the control block is located and cbName is the name of the control ...

Page 729: ...date the G60 with the new configuration from an SCD file with the EnerVista UR Setup software 1 Right click anywhere in the files panel and select the Import Contents From SCD File item 2 Select the saved SCD file and click Open 842794A1 CDR IED Section IED 1 AccessPoint name Server Authentication none LDevice inst LN0 InType InClass inst DataSet elements DOI elements Inputs GSEControl elements Re...

Page 730: ... one GE Multilin IED defined in the SCD file the software prompt the user to save a UR series set tings file for each IED 4 After the URS file is created modify any settings if required 5 To update the relay with the new settings right click on the settings file in the settings tree and select the Write Set tings File to Device item 6 The software will prompt for the target device Select the targe...

Page 731: ...SCSM IEC 61850 9 2 used B24 SCSM other GENERIC SUBSTATION EVENT MODEL GSE B31 Publisher side O Yes B32 Subscriber side Yes TRANSMISSION OF SAMPLED VALUE MODEL SVC B41 Publisher side O B42 Subscriber side SERVICES SERVER PUBLISHER UR FAMILY IF SERVER SIDE B11 SUPPORTED M1 Logical device c2 Yes M2 Logical node c3 Yes M3 Data c4 Yes M4 Data set c5 Yes M5 Substitution O M6 Setting group control O REPO...

Page 732: ...et name M8 5 data reference M8 6 BufTm M8 7 IntgPd M8 8 GI Logging O M9 Log control O M9 1 IntgPd M10 Log O M11 Control M Yes IF GSE B31 32 IS SUPPORTED GOOSE O Yes M12 1 entryID M12 2 DataReflnc M13 GSSE O Yes IF SVC B41 B42 IS SUPPORTED M14 Multicast SVC O M15 Unicast SVC O M16 Time M Yes M17 File transfer O Yes SERVICES AA TP MC SERVER PUBLISHER UR FAMILY SERVER CLAUSE 7 S1 ServerDirectory TP M...

Page 733: ...es S26 SetBRCBValues TP c6 Yes UNBUFFERED REPORT CONTROL BLOCK URCB S27 Report TP c6 Yes S27 1 data change dchg Yes S27 2 qchg change qchg S27 3 data update dupd S28 GetURCBValues TP c6 Yes S29 SetURCBValues TP c6 Yes LOGGING CLAUSE 17 LOG CONTROL BLOCK S30 GetLCBValues TP M S31 SetLCBValues TP M LOG S32 QueryLogByTime TP M S33 QueryLogByEntry TP M S34 GetLogStatusValues TP M GENERIC SUBSTATION EV...

Page 734: ...endMSVMessage MC c10 S46 GetMSVCBValues TP O S47 SetMSVCBValues TP O UNICAST SVC S48 SendUSVMessage MC c10 S49 GetUSVCBValues TP O S50 SetUSVCBValues TP O CONTROL CLAUSE 20 S51 Select O Yes S52 SelectWithValue TP O S53 Cancel TP O Yes S54 Operate TP M Yes S55 Command Termination TP O S56 TimeActivated Operate TP O FILE TRANSFER CLAUSE 23 S57 GetFile TP M Yes S58 SetFile TP O S59 DeleteFile TP O S6...

Page 735: ...ing A LOGICAL NODES FOR AUTOMATIC CONTROL ANCR Neutral current regulator ARCO Reactive power control ATCC Automatic tap changer controller AVCO Voltage control C LOGICAL NODES FOR CONTROL CALH Alarm handling CCGR Cooling group control CILO Interlocking CPOW Point on wave switching CSWI Switch controller Yes CSYN Synchronizer controller F LOGICAL NODES FOR FUNCTIONAL BLOCKS FCNT Counter FCSD Curve ...

Page 736: ...s MSQI Sequence and imbalance Yes MSTA Metering statistics P LOGICAL NODES FOR PROTECTION FUNCTIONS PDIF Differential Yes PDIR Direction comparison PDIS Distance Yes PDOP Directional overpower PDUP Directional underpower PFRC Rate of change of frequency PHAR Harmonic restraint PHIZ Ground detector PIOC Instantaneous overcurrent Yes PMRI Motor restart inhibition PMSS Motor starting time supervision...

Page 737: ...erential measurements RPSB Power swing detection blocking Yes RREC Autoreclosing Yes RSYN Synchronism check or synchronizing S LOGICAL NODES FOR SENSORS AND MONITORING SARC Monitoring and diagnostics for arcs SCBR Circuit breaker supervision SIMG Insulation medium supervision gas SIML Insulation medium supervision liquid SLTC Tap changer supervision SOPM Supervision of operating mechanism SPDC Mon...

Page 738: ...rth fault neutralizer Petersen coil YLTC Tap changer YPSH Power shunt YPTR Power transformer Z LOGICAL NODES FOR FURTHER POWER SYSTEM EQUIPMENT ZAXN Auxiliary network ZBAT Battery ZBSH Bushing ZCAB Power cable ZCAP Capacitor bank ZCON Converter ZGEN Generator ZGIL Gas insulated line ZLIN Power overhead line ZMOT Motor ZREA Reactor ZRES Resistor ZRRC Rotating reactive component ZSAR Surge arrestor ...

Page 739: ... Circuit V 24 V 28 Recommended if 1200 bits s Balanced Interchange Circuit X 24 X 27 100 bits sec 200 bits sec 300 bits sec 600 bits sec 1200 bits sec 2400 bits sec 4800 bits sec 9600 bits sec 2400 bits sec 4800 bits sec 9600 bits sec 19200 bits sec 38400 bits sec 56000 bits sec 64000 bits sec Unbalanced Interchange Circuit V 24 V 28 Standard Unbalanced Interchange Circuit V 24 V 28 Recommended if...

Page 740: ...ate the following used in standard direction not used cannot be selected in IEC 60870 5 104 standard Process information in monitor direction 1 Single point information M_SP_NA_1 2 Single point information with time tag M_SP_TA_1 3 Double point information M_DP_NA_1 4 Double point information with time tag M_DP_TA_1 5 Step position information M_ST_NA_1 6 Step position information with time tag M_...

Page 741: ...of protection equipment with time tag CP56Time2a M_EP_TE_1 40 Packed output circuit information of protection equipment with time tag CP56Time2a M_EP_TF_1 45 Single command C_SC_NA_1 46 Double command C_DC_NA_1 47 Regulating step command C_RC_NA_1 48 Set point command normalized value C_SE_NA_1 49 Set point command scaled value C_SE_NB_1 50 Set point command short floating point value C_SE_NC_1 51...

Page 742: ...rectory select file call file call section F_SC_NA_1 123 Last section last segment F_LS_NA_1 124 Ack file ack section F_AF_NA_1 125 Segment F_SG_NA_1 126 Directory blank or X available only in monitor standard direction C_CD_NA_1 TYPE IDENTIFICATION CAUSE OF TRANSMISSION NO MNEMONIC 1 2 3 4 5 6 7 8 9 10 11 12 13 20 to 36 37 to 41 44 45 46 47 1 M_SP_NA_1 X X X X X 2 M_SP_TA_1 3 M_DP_NA_1 4 M_DP_TA_...

Page 743: ..._1 48 C_SE_NA_1 49 C_SE_NB_1 50 C_SE_NC_1 51 C_BO_NA_1 58 C_SC_TA_1 X X X X X 59 C_DC_TA_1 60 C_RC_TA_1 TYPE IDENTIFICATION CAUSE OF TRANSMISSION NO MNEMONIC 1 2 3 4 5 6 7 8 9 10 11 12 13 20 to 36 37 to 41 44 45 46 47 PERIODIC CYCLIC BACKGROUND SCAN SPONTANEOUS INITIALIZED REQUEST OR REQUESTED ACTIVATION ACTIVATION CONFIRMATION DEACTIVATION DEACTIVATION CONFIRMATION ACTIVATION TERMINATION RETURN I...

Page 744: ... P_ME_NC_1 X X X 113 P_AC_NA_1 120 F_FR_NA_1 121 F_SR_NA_1 122 F_SC_NA_1 123 F_LS_NA_1 124 F_AF_NA_1 125 F_SG_NA_1 126 F_DR_TA_1 TYPE IDENTIFICATION CAUSE OF TRANSMISSION NO MNEMONIC 1 2 3 4 5 6 7 8 9 10 11 12 13 20 to 36 37 to 41 44 45 46 47 PERIODIC CYCLIC BACKGROUND SCAN SPONTANEOUS INITIALIZED REQUEST OR REQUESTED ACTIVATION ACTIVATION CONFIRMATION DEACTIVATION DEACTIVATION CONFIRMATION ACTIVA...

Page 745: ...nt number M_ME_NC_1 M_ME_TC_1 and M_ME_TF_1 Station interrogation Clock synchronization Clock synchronization optional see Clause 7 6 Command transmission Direct command transmission Direct setpoint command transmission Select and execute command Select and execute setpoint command C_SE ACTTERM used No additional definition Short pulse duration duration determined by a system parameter in the outs...

Page 746: ...es of events Transmission of sequences of recorded analog values File transfer in control direction Transparent file Background scan Background scan Acquisition of transmission delay Acquisition of transmission delay Definition of time outs Maximum range of values for all time outs 1 to 255 s accuracy 1 s Maximum number of outstanding I format APDUs k and latest acknowledge APDUs w PARAMETER DEFAU...

Page 747: ... the Internet Architecture Board IAB It offers a broad spectrum of actual standards used in the Inter net The suitable selection of documents from RFC 2200 defined in this standard for given projects has to be chosen by the user of this standard Ethernet 802 3 Serial X 21 interface Other selection s from RFC 2200 list below if selected D 1 2 IEC 60870 5 104 POINT LIST The IEC 60870 5 104 data poin...

Page 748: ...D 10 G60 Generator Protection System GE Multilin D 1 IEC 60870 5 104 APPENDIX D D ...

Page 749: ...d in addition to the Highest DNP Levels Supported the complete list is described in the attached table Binary Inputs Object 1 Binary Input Changes Object 2 Binary Outputs Object 10 Control Relay Output Block Object 12 Binary Counters Object 20 Frozen Counters Object 21 Counter Change Event Object 22 Frozen Counter Event Object 23 Analog Inputs Object 30 Analog Input Changes Object 32 Analog Deadba...

Page 750: ...inary Outputs Never Always Sometimes Configurable SELECT OPERATE Never Always Sometimes Configurable DIRECT OPERATE Never Always Sometimes Configurable DIRECT OPERATE NO ACK Never Always Sometimes Configurable Count 1 Never Always Sometimes Configurable Pulse On Never Always Sometimes Configurable Pulse Off Never Always Sometimes Configurable Latch On Never Always Sometimes Configurable Latch Off ...

Page 751: ...Configurable Only certain objects Sometimes attach explanation ENABLE DISABLE unsolicited Function codes supported Sends Static Data in Unsolicited Responses Never When Device Restarts When Status Flags Change No other options are permitted Default Counter Object Variation No Counters Reported Configurable attach explanation Default Object 20 Default Variation 1 Point by point list attached Counte...

Page 752: ... 17 28 index 3 Binary Input Change with Relative Time 1 read 06 no range or all 07 08 limited quantity 10 0 Binary Output Status Variation 0 is used to request default variation 1 read 00 01 start stop 06 no range or all 07 08 limited quantity 17 28 index 2 Binary Output Status 1 read 00 01 start stop 06 no range or all 07 08 limited quantity 17 28 index 129 response 00 01 start stop 17 28 index s...

Page 753: ...riation 0 is used to request default variation 1 read 06 no range or all 07 08 limited quantity 1 32 Bit Counter Change Event 1 read 06 no range or all 07 08 limited quantity 129 response 130 unsol resp 17 28 index 2 16 Bit Counter Change Event 1 read 06 no range or all 07 08 limited quantity 129 response 130 unsol resp 17 28 index 5 32 Bit Counter Change Event with Time 1 read 06 no range or all ...

Page 754: ...ponse 130 unsol resp 17 28 index 3 32 Bit Analog Change Event with Time 1 read 06 no range or all 07 08 limited quantity 129 response 130 unsol resp 17 28 index 4 16 Bit Analog Change Event with Time 1 read 06 no range or all 07 08 limited quantity 129 response 130 unsol resp 17 28 index 5 short floating point Analog Change Event without Time 1 read 06 no range or all 07 08 limited quantity 129 re...

Page 755: ...close 30 abort 5b free format 129 response 130 unsol resp 5b free format 5 File transfer 1 read 2 write 5b free format 129 response 130 unsol resp 5b free format 6 File transfer status 129 response 130 unsol resp 5b free format 7 File descriptor 28 get file info 5b free format 129 response 130 unsol resp 5b free format 80 1 Internal Indications 1 read 00 01 start stop index 7 129 response 00 01 st...

Page 756: ... is performed on a binary counter point the frozen value is available in the corresponding frozen counter point BINARY INPUT POINTS Static Steady State Object Number 1 Change Event Object Number 2 Request Function Codes supported 1 read 22 assign class Static Variation reported when variation 0 requested 2 Binary Input with status Configurable Change Event Variation reported when variation 0 reque...

Page 757: ...tual Input 15 15 Virtual Input 16 16 Virtual Input 17 17 Virtual Input 18 18 Virtual Input 19 19 Virtual Input 20 20 Virtual Input 21 21 Virtual Input 22 22 Virtual Input 23 23 Virtual Input 24 24 Virtual Input 25 25 Virtual Input 26 26 Virtual Input 27 27 Virtual Input 28 28 Virtual Input 29 29 Virtual Input 30 30 Virtual Input 31 31 Virtual Input 32 32 Virtual Input 33 33 Virtual Input 34 34 Vir...

Page 758: ...reeze and clear noack 22 assign class Static Variation reported when variation 0 requested 1 32 Bit Binary Counter with Flag Change Event Variation reported when variation 0 requested 1 32 Bit Counter Change Event without time Change Event Buffer Size 10 Default Class for all points 3 FROZEN COUNTERS Static Steady State Object Number 21 Change Event Object Number 23 Request Function Codes supporte...

Page 759: ...all Analog Input points are in the same units as the Analog Input quantity For example an Analog Input quantity measured in volts has a corresponding deadband in units of volts This is in conformance with DNP Technical Bul letin 9809 001 Analog Input Reporting Deadband Relay settings are available to set default deadband values according to data type Deadbands for individual Analog Input Points ca...

Page 760: ...E 12 G60 Generator Protection System GE Multilin E 2 DNP POINT LISTS APPENDIX E E ...

Page 761: ... an Administrator role Tester User Password testpw GE PDC USER Role Administrator 4 In the clients conf file in the Path_to_Radius etc raddb folder add the following text to define the UR as a RADIUS client where the client IP address is 10 0 0 2 the subnet mask is 255 255 255 0 the shared secret specified here is also configured on the UR device for successful authentication and the shortname is ...

Page 762: ...ress and ports for the RADIUS server Leave the GE vendor ID field at the default of 2910 Update the RADIUS shared secret as specified in the clients conf file 9 Verify operation Log in to the UR software as follows In the login window select Server as the Authentication Type enter the user name entered for example user name Tester and password testpw Check that the RADIUS server log file shows the...

Page 763: ...3 4x 30 January 2004 URX 115 1601 0110 G1 4 0x 23 March 2004 URX 123 1601 0110 G2 4 0x 17 May 2004 URX 136 1601 0110 H1 4 2x 30 June 2004 URX 145 1601 0110 H2 4 2x 23 July 2004 URX 151 1601 0110 J1 4 4x 15 September 2004 URX 156 1601 0110 K1 4 6x 15 February 2005 URX 176 1601 0110 L1 4 8x 05 August 2005 URX 202 1601 0110 M1 4 9x 15 December 2005 URX 208 1601 0110 M2 4 9x 27 February 2006 URX 214 1...

Page 764: ...late section on how to customize LED and blank panels Clear Lexan front cover part number 1501 0014 no longer being sold Units with blank LED panels no longer being sold 5 23 5 23 Add Added Syslog Format section 5 31 5 31 Add Added Far End Fault Indication FEFI section 5 138 5 138 Update Updated FlexLogic operands table 5 206 5 206 Add Added Split Phase Function setting to enabled and disable the ...

Page 765: ... 5 24 and 5 25 Dual Breaker Control Scheme Logic sheets 1 and 2 5 93 5 93 Update Updated Figure 5 26 Disconnect Switch Scheme Logic 5 280 5 280 Add Reinserted section 5 8 5c Remote Devices ID of Device for Receiving GSSE GOOSE Messages meaning the Settings Input Outputs Remote Devices settings Table G 5 MAJOR UPDATES FOR G60 MANUAL REVISION Y3 PAGE Y2 PAGE Y3 CHANGE DESCRIPTION xi Add Added batter...

Page 766: ...igure Complete Synchrophasor Implementation 5 5 95 Add Added Figure N60 Support For Four Logical Device PMU 5 97 5 95 Update Updated Table Implementation By Model Number 5 5 96 Add Added Figure Logical Nodes Supported In Each Logical Device 5 5 97 Add Added Figure Data Set Created From User Selected Internal Items 5 5 98 Add Added Figure Example Of Aggregator Data Sets 5 5 98 Add Added Figure CFG ...

Page 767: ... the Relay Maintenance menu items 7 7 Add Added Security menu and submenu commands and descriptions to the Command menu 7 7 Add Added to Minor self test error message Bad PTP Signal 8 8 4 Add Added new section for CyberSentry software option with overview and security menu subsections A A Add Added Flexanalog item PTP IRIG B Delta to Table A 1 Flexanalog Data Items B 8 B 8 Update Updated Modbus me...

Page 768: ...ld FAIL Failure FD Fault Detector FDH Fault Detector high set FDL Fault Detector low set FLA Full Load Current FO Fiber Optic FREQ Frequency FSK Frequency Shift Keying FTP File Transfer Protocol FxE FlexElement FWD Forward G Generator GE General Electric GND Ground GNTR Generator GOOSE General Object Oriented Substation Event GPS Global Positioning System HARM Harmonic Harmonics HCT High Current T...

Page 769: ...esistance Temperature Detector RTU Remote Terminal Unit RX Rx Receive Receiver s second S Sensitive SAT CT Saturation SBO Select Before Operate SCADA Supervisory Control and Data Acquisition SEC Secondary SEL Select Selector Selection SENS Sensitive SEQ Sequence SIR Source Impedance Ratio SNTP Simple Network Time Protocol SRC Source SSB Single Side Band SSEL Session Selector STATS Statistics SUPN ...

Page 770: ...f 1 October 2013 GE Digital Energy warrants most of its GE manufactured products for 10 years For warranty details including any limitations and disclaimers see the GE Digital Energy Terms and Conditions at https www gedigitalenergy com multilin warranty htm For products shipped before 1 October 2013 the standard 24 month warranty applies ...

Page 771: ...ogic 5 228 Modbus registers B 47 settings 5 228 specifications 2 17 AUXILIARY VOLTAGE CHANNEL 3 13 AUXILIARY VOLTAGE METERING 6 18 AWG WIRE SIZE 3 12 3 33 3 36 3 38 B BANKS 5 6 5 93 5 94 BATTERY disposal 11 4 failure 7 8 replace 11 3 BATTERY FAILURE 7 8 BINARY INPUT POINTS E 8 BINARY OUTPUT POINTS E 9 BLOCK DIAGRAM 1 3 BLOCK SETTING 5 5 BREAKER CONTROL control of 2 breakers 4 23 description 4 22 d...

Page 772: ... CT BANKS settings 5 93 CT FAILURE FlexLogic operands 5 139 logic 5 287 settings 5 286 CT INPUTS 3 13 5 6 5 93 CT WIRING 3 13 CURRENT BANK 5 93 CURRENT DIFFERENTIAL Modbus registers B 16 CURRENT HARMONICS 2 22 6 21 CURRENT METERING actual values 6 17 specifications 2 21 CURVES definite time 5 183 5 223 FlexCurves 5 106 5 183 I2T 5 183 IAC 5 182 IEC 5 181 IEEE 5 180 inverse time undervoltage 5 223 ...

Page 773: ... E EGD PROTOCOL actual values 6 10 Modbus registers B 47 settings 5 57 ELECTROSTATIC DISCHARGE 2 29 ELEMENTS 5 4 END OF LIFE 11 10 ENERGY METERING actual values 6 20 Modbus registers B 15 specifications 2 21 2 22 ENERGY METERING CLEARING 5 26 7 2 ENERVISTA UR SETUP creating a site list 4 1 event recorder 4 2 firmware upgrades 4 2 installation 1 6 introduction 4 1 oscillography 4 2 overview 4 1 req...

Page 774: ...Y outputs 3 14 specifications 2 24 FREQUENCY METERING actual values 6 20 settings 5 95 specifications 2 22 FREQUENCY OUT OF BAND ACCUMULATION actual values 6 22 clearing 7 2 FlexLogic operands 5 140 Modbus registers B 22 settings 5 269 5 270 specifications 2 18 FREQUENCY RATE OF CHANGE FlexLogic operands 5 140 Modbus registers B 13 B 55 settings 5 267 FREQUENCY TRACKING 5 95 6 22 FREQUENCY NOMINAL...

Page 775: ...example 5 296 5 297 error messages 7 9 settings 5 295 specifications 2 24 LED INDICATORS 4 14 4 15 4 16 4 17 5 71 LED TEST FlexLogic operand 5 145 settings 5 69 specifications 2 20 LINK POWER BUDGET 2 27 LOCAL SETTING AUTHORIZATION 4 2 LOGIC GATES 5 147 LOGS SYSTEM 5 23 LOSS OF EXCITATION characteristics 5 234 FlexLogic operands 5 140 logic 5 235 Modbus registers B 39 settings 5 233 5 234 specific...

Page 776: ...cations 2 15 NON VOLATILE LATCHES FlexLogic operands 5 140 Modbus registers B 55 settings 5 158 specifications 2 20 O ONE SHOTS 5 147 OPERATING TEMPERATURE 2 28 OPERATING TIMES 2 15 ORDER CODES 2 7 2 8 2 10 2 11 6 30 7 3 ORDER CODES UPDATING 7 3 ORDERING 2 7 2 8 2 10 2 11 OSCILLATORY TRANSIENT TESTING 2 29 OSCILLOGRAPHY actual values 6 28 clearing 5 26 7 2 Modbus B 7 Modbus registers B 18 B 29 set...

Page 777: ...xLogic operands 5 142 logic 5 224 Modbus registers B 40 settings 5 224 specifications 2 17 PHASOR MEASUREMENT UNIT actual values 6 29 PMU see entry for SYNCHROPHASOR POWER METERING specifications 2 21 values 6 19 POWER SUPPLY description 3 11 low range 2 23 specifications 2 23 POWER SWING BLOCKING 2 19 5 169 POWER SWING DETECT FlexLogic operands 5 142 logic 5 174 5 175 Modbus registers B 38 settin...

Page 778: ... SECURITY delete files and records 11 7 SELECT BEFORE OPERATE 5 54 SELECTOR SWITCH actual values 6 7 application example 5 263 FlexLogic operands 5 143 logic 5 264 Modbus registers B 54 settings 5 259 specifications 2 20 timing 5 262 5 263 Self test errors 7 12 SELF TESTS description 7 6 error messages 7 7 FlexLogic operands 5 146 Modbus registers B 9 SENSITIVE DIRECTIONAL POWER actual values 6 24...

Page 779: ...EQUENCY 5 95 SYSTEM LOGS 5 23 SYSTEM REQUIREMENTS 1 6 SYSTEM SETUP 5 93 T TARGET MESSAGES 7 6 TARGET SETTING 5 5 TARGETS MENU 7 6 TCP PORT NUMBER 5 55 TELEPROTECTION actual values 6 5 clearing counters 7 2 FlexLogic operands 5 144 logic 5 307 Modbus registers B 53 overview 5 305 settings 5 90 5 305 5 306 specifications 2 23 TEMPERATURE MONITOR 5 146 7 10 TERMINALS 3 8 TESTING force contact inputs ...

Page 780: ...46 settings 5 74 specifications 2 20 USER PROGRAMMABLE SELF TESTS Modbus registers B 30 settings 5 72 USERST 1 BIT PAIR 5 301 V VAR HOURS 2 22 6 20 VIBRATION TESTING 2 29 VIRTUAL INPUTS actual values 6 4 commands 7 1 FlexLogic operands 5 145 logic 5 294 Modbus registers B 9 B 63 settings 5 294 VIRTUAL OUTPUTS actual values 6 6 FlexLogic operands 5 145 Modbus registers B 64 settings 5 297 VOLTAGE B...

Reviews:

No comments

Related manuals for Multilin g60

ServeRAID M5014

Brand: IBM Pages: 106

Brand: Dahua Pages: 58

Brand: Harman Pages: 2

Brand: T-Link Pages: 3

Brand: vacuubrand Pages: 12

Brand: Vacon Pages: 47

Brand: Vacon Pages: 40

Brand: Valco baby Pages: 24

Brand: ZIMMERLI MESSTECHNIK Pages: 12

Brand: H-Tronic Pages: 32

Brand: Eaton Pages: 448

Brand: Eaton Pages: 57

Smart Control Panel 880RGD

Brand: Raynor Pages: 4

Brand: PUTCO Pages: 2

Cutler-Hammer LMR

Brand: Eaton Pages: 38

Brand: baby joy Pages: 11

Brand: LOGICDATA Pages: 23

Brand: HANYOUNG NUX Pages: 4

Brands by name

0 1 2 3 4 5 6 7 8 9 A B C D E F G H I J K L M N O P Q R S T U V W X Y Z

Popular brands

Load more brands