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GEK-113328A

G650 Generator Protection & Control System

B-25

APPENDIX B 

B.2 FACTORY DEFAULT CONFIGURATION

B

LVI_11_BLOCK 59P

PHASE OV3 BLOCK

GROUP 3 BLOCKED

LVI_11_BLOCK 59P

AUXILIARY OV1 BLOCK

GROUP 1 BLOCKED

AUXILIARY OV2 BLOCK

GROUP 2 BLOCKED

AUXILIARY OV3 BLOCK

GROUP 3 BLOCKED

NEG SEQ TOC1 BLOCK

GROUP 1 BLOCKED

CONT IP_F_CC7 (51-
2 BLOCK)(CC7)

NEG SEQ TOC2 BLOCK

GROUP 2 BLOCKED

CONT IP_F_CC7 (51-
2 BLOCK)(CC7)

NEG SEQ TOC3 BLOCK

GROUP 3 BLOCKED

CONT IP_F_CC7 (51-
2 BLOCK)(CC7)

OVERFREQ1 BLOCK

GROUP 1 BLOCKED

OVERFREQ2 BLOCK

GROUP 2 BLOCKED

OVERFREQ3 BLOCK

GROUP 3 BLOCKED

UNDERFREQ1 BLOCK

GROUP 1 BLOCKED

UNDERFREQ2 BLOCK

GROUP 2 BLOCKED

UNDERFREQ3 BLOCK

GROUP 3 BLOCKED

SETT GROUPS BLOCK

Not Configured

PH TOC1 LOW A BLK

GROUP 1 BLOCKED

LVI_6_BLOCK 51PL

PH TOC1 LOW B BLK

GROUP 1 BLOCKED

LVI_6_BLOCK 51PL

PH TOC1 LOW C BLK

GROUP 1 BLOCKED

LVI_6_BLOCK 51PL

PH TOC2 LOW A BLK

GROUP 2 BLOCKED

LVI_6_BLOCK 51PL

PH TOC2 LOW B BLK

GROUP 2 BLOCKED

LVI_6_BLOCK 51PL

PH TOC2 LOW C BLK

GROUP 2 BLOCKED

LVI_6_BLOCK 51PL

PH TOC3 LOW A BLK

GROUP 3 BLOCKED

LVI_6_BLOCK 51PL

PH TOC3 LOW B BLK

GROUP 3 BLOCKED

LVI_6_BLOCK 51PL

PH TOC3 LOW C BLK

GROUP 3 BLOCKED

LVI_6_BLOCK 51PL

DIR PWR1 BLOCK

GROUP 1 BLOCKED

DIR PWR2 BLOCK

GROUP 2 BLOCKED

DIR PWR3 BLOCK

GROUP 3 BLOCKED

FREQ RATE1 BLOCK

GROUP 1 BLOCKED

FREQ RATE2 BLOCK

GROUP 2 BLOCKED

FREQ RATE3 BLOCK

GROUP 3 BLOCKED

RESTR GND FLT1 
BLOCK (*)

GROUP 1 BLOCKED

RESTR GND FLT2 
BLOCK (*)

GROUP 2 BLOCKED

RESTR GND FLT3 
BLOCK (*)

GROUP 3 BLOCKED

SETPOINT>RELAY CONFIGURATION>PROTECTION ELEMENTS

PROTECTION ELEMENT SOURCE

SIGNAL LOGIC

SOURCE LOGIC

Summary of Contents for Multilin GEK-113328A

Page 1: ...et www GEMultilin com Firmware version 3 74 EnerVista 650 Setup version 3 76 Copyright 2008 GE Multilin G650 Generator Protection Control System Instruction manual GEK 113328A GE Multilin Avda Pinoa 10 48170 Zamudio SPAIN T 34 94 485 88 00 F 34 94 485 88 45 E gemultilin euro ge com g GE Consumer Industrial Multilin ...

Page 2: ......

Page 3: ...RDERING CODE 2 4 TECHNICAL SPECIFICATIONS 2 4 1 PROTECTION ELEMENTS 2 7 2 4 2 CONTROL 2 17 2 4 3 MONITORING 2 22 2 4 4 USER PROGRAMMABLE ELEMENTS 2 24 2 4 5 METERING 2 25 2 4 6 INPUTS 2 26 2 4 7 REAL TIME CLOCK 2 28 2 4 8 OUTPUTS 2 28 2 4 9 CONTROL POWER SUPPLY 2 29 2 4 10 COMMUNICATIONS 2 29 2 4 11 OPTIC FEATURES 2 31 2 4 12 ENVIRONMENTAL CHARACTERISTICS 2 32 2 4 13 PACKAGING AND WEIGHT 2 32 2 4 ...

Page 4: ...NG PASSWORDS 4 3 ENABLING SECURITY 4 4 LOGING INTO ENERVISTA 650 SETUP 5 BOOTCODE AND FIRMWARE UPGRADE 5 1 INTRODUCTION 5 1 1 COMMUNICATION PARAMETERS 5 2 5 2 BOOT CODE UPGRADE 5 3 FIRMWARE VERSION UPGRADE 5 3 1 FIRMWARE UPGRADE 5 9 5 3 2 BOOT CODE UPGRADE 5 11 5 3 3 FIRMWARE UPGRADE 5 12 6 COMMISSIONING 6 1 VISUAL INSPECTION 6 2 GENERAL CONSIDERATIONS ON THE POWER SUPPLY NETWORK 6 3 ISOLATION TES...

Page 5: ...3 2 27X ELEMENT 6 16 6 14 OVERVOLTAGE ELEMENTS 59P 59X 59NH 6 14 1 59P ELEMENT 6 17 6 14 2 59X ELEMENT 6 17 6 14 3 59NH ELEMENT 6 18 6 14 4 47 ELEMENT NEG SEQ OV 6 19 6 15 FREQUENCY ELEMENTS 81O 81U 7 FREQUENTLY ASKED QUESTIONS 7 1 COMMUNICATIONS 7 2 PROTECTION 7 3 CONTROL AND HMI 7 4 RELAY CONFIGURATION 8 G650TROUBLESHOOTING GUIDE 8 1 SYMPTOMS AND RECOMMENDED ACTIONS A FACTORY DEFAULT LOGIC A 1 F...

Page 6: ...4 G650 Generator Protection Control System GEK 113328 TABLE OF CONTENTS ...

Page 7: ...o help guide you through the initial installation procedures of your new relay BEFORE ATTEMPTING TO INSTALL OR USE THE RELAY IT IS IMPERATIVE THAT ALL WARNINGS AND CAUTIONS IN THIS MANUAL ARE REVIEWED TO HELP PREVENT PERSONAL INJURY EQUIPMENT DAMAGE AND OR DOWNTIME CAUTION THE OPERATOR OF THIS INSTRUMENT IS ADVISED THAT IF THE EQUIPMENT IS USED IN A MANNER NOT SPECIFIED IN THIS MANUAL THE PROTECTI...

Page 8: ...RTION SHALL ONLY BE PERFORMED BY DULY QUALIFIED SERVICE PERSONNEL FOR PERSONAL SECURITY PURPOSES BEFORE ACCOMPLISHING ANY WITHDRAWAL OR INSERTION OPERATION THE RELAY MUST BE POWERED OFF AND ALL THE REAR TERMINALS MUST BE POTENTIAL FREE THE RELAY MUST BE GROUNDED USING THE REAR GROUNDING SCREW Before performing any of these actions control power must be removed from the relay and all the rear termi...

Page 9: ...he case The current inputs incorporate shorting bars so that the module can be extracted without the need to short circuit the currents externally It is very important for safety reasons not to change or switch the terminals for CTs and VTs Figure 1 3 REAR VIEW OF G650 UNIT GE Multilin will not be responsible for any damage of the relay connected equipment or personnel whenever these safety rules ...

Page 10: ... the relay for physical damage Verify that the model on the label on the side of the relay matches the model ordered Figure 1 4 IDENTIFICATION LABEL A4454P30 Please ensure that you received the following items with your relay Mounting screws for fixing the relay to a cabinet CD containing EnerVista 650 Setup software Wiring diagram Certificate of Compliance ...

Page 11: ...o Vizcaya SPAIN Tel 34 94 485 88 54 Fax 34 94 485 88 38 E mail multilin tech euro ge com AMERICA ASIA AND AUSTRALIA GE MULTILIN 215 Anderson Avenue L6E 1B3 Markham ON CANADA Tel 1 905 294 6222 Fax 1 905 201 2098 E mail multilin tech ge com The information provided herein is not intended to cover all the details of the variations of the equipment nor does it take into account the circumstances that...

Page 12: ...se of using a laptop it is recommended not to have it connected to its power supply In many cases it might not be correctly grounded either due to the power supply or to the connector cables used This is required not only for personal protection but also to avoid a potential voltage difference between the relay s serial port and the computer s port which could produce permanent damage to the compu...

Page 13: ...g system reliability and efficiency These objectives are realized through software which is used to perform functions at both the station and supervisory levels The use of these systems is growing rapidly High speed communications are required to meet the data transfer rates required by modern automatic control and monitoring systems In the near future very high speed communications will be requir...

Page 14: ...contacts from independent modules connected to the 650 unit via a CAN Bus Not available for W650 models PLC Programmable Logic Controller Control module that enables the unit configuration assignment of inputs outputs and the implementation of logic circuits Protection Elements Relay protection elements for example Overcurrent overvoltage etc Not available for C650 models Remote inputs and outputs...

Page 15: ...ation Available options are Table 1 1 REAR SERIAL COMMUNICATIONS BOARD 1 The other module provides Ethernet communications COM3 port using 10 100BaseTX self negotiable speed or 100BaseFX connectors depending on the selected model The most complete models include a double redundant 100BaseFX fiber optic port Redundancy is provided at the physical level the unit incorporates internally duplicated an...

Page 16: ...1 10 G650 Generator Protection Control System GEK 113328A 1 2 OVERVIEW 1 GETTING STARTED 1 Figure 1 7 COMMUNICATIONS ARCHITECTURE B6816F1 ...

Page 17: ...higher Windows 2000 Windows XP Internet Explorer 5 0 or higher 64 MB of RAM 128 MB recommended 40 MB of available space on system drive and 40 MB of available space on installation drive RS232C serial and or Ethernet port for communications to the relay 1 3 2 INSTALLATION After ensuring the minimum requirements for using EnerVista 650 Setup are met see previous section use the following procedure ...

Page 18: ...nstall Software window as shown below Select the Web option to ensure the most recent software release or select CD if you do not have a web connection then click the Add Now button to list software items for the G650 Figure 1 9 ADD PRODUCT WINDOW 6 If Web option is selected choose the G650 software program and release notes if desired from the list and click the Download Now button to obtain the ...

Page 19: ...alled in the directory indicated and the installation program will automatically create icons and add EnerVista 650 Setup to the Windows start menu 10 Follow the on screen instructions to install the EnerVista 650 Setup software When the Welcome window appears click on Next to continue with the installation procedure Figure 1 11 ENERVISTA 650 SETUP INSTALLATION 11 When the Choose Destination Locat...

Page 20: ... the application will be added to is shown in the Selected Program Folder window Click Next to begin the installation process and all the necessary program files will be copied into the chosen directory Figure 1 13 SELECT PROGRAM FOLDER 13 To finish with the installation process select the desired language for startup Figure 1 14 LANGUAGE WINDOW ...

Page 21: ...le from the GE EnerVista CD or online from http www GEindustrial com multilin see previous section for installation instructions 2 Go to Communication Computer and enter the following data referring to communications 3 Select Control Type as MODBUS TCP IP from the drop down list This option will display a number of interface parameters that must be entered for proper Ethernet communications 4 Ente...

Page 22: ...he following data referred to communications 3 Select Control Type as No Control Type from the drop down list This option will display a number of interface parameters that must be entered for proper serial communications 4 Enter the relay Slave Address Setpoint Product Setup Communication Settings ModBus Protocol menu in the Slave Address field The default value is 254 5 Enter the physical commun...

Page 23: ...ended to use a shielded twist pair In order to avoid loops where external currents could flow the cable shield must be grounded only at one end The converter box GND terminals are connected to the relay SDA SDB GND terminals respectively For long communications cables longer than 1 km the RS485 circuit must be terminated in an RC network i e 120 ohm 1 nF This circuit is shown on Figure 1 17 RS485 ...

Page 24: ...ossover cable is required If the connection is performed through a hub or a switch a direct Ethernet cable is required 1 4 3 FACEPLATE DISPLAY All messages are displayed on a 20x4 character LCD display An optional graphic display is also available Messages are displayed in different languages according to selected model 1 4 4 MAINTENANCE G650 requires a minimum amount of maintenance when it is com...

Page 25: ... of setting file entries against relay settings schedule 4 Contact inputs and outputs verification This test can be conducted by direct change of state forcing or as part of the system functional testing 5 Visual inspection for any damage corrosion or dust 6 Event recorder file download with further events analysis Unscheduled maintenance such as during a disturbance causing system interruption 1 ...

Page 26: ...1 20 G650 Generator Protection Control System GEK 113328A 1 4 650 HARDWARE 1 GETTING STARTED 1 ...

Page 27: ...apabilities The main features of G650 devices include Protection relay with control capabilities for protection of small and medium generators Replacement for legacy devices in the long term based on improved and open protocols in communications as well as orientation to machine protection system rather than individual protection functions Based on the 650 platform Full graphic capabilities in lar...

Page 28: ...2 2 G650 Generator Protection Control System GEK 113328A 2 1 OVERVIEW 2 PRODUCT DESCRIPTION 2 Figure 2 2 G650 BLOCK DIAGRAM FOR ENHANCED FUNCTIONALITY MODELS ...

Page 29: ... measured from 4th current transformer 50N Neutral Instantaneous Overcurrent calculated from the phase currents 50P Phase Instantaneous Overcurrent 51G Ground Time Overcurrent measured from 4th current transformer 51N Neutral Time Overcurrent calculated from the phase currents 51P V Voltage Restraint Overcurrent 50SG 51SG Sensitive Ground Fault only enhanced model 55 Power Factor Limiting Only enh...

Page 30: ... 3 0 Level 2 32 Latched Virtual Inputs 32 Self Reset Virtual Inputs Three Phase Energy IEC 870 5 104 Virtual Outputs up to 512 Frequency ModBus User Map Tripping and closing circuit supervision Sequence components of currents and voltages Analog Inputs dCmA Pulse Counters Analog Comparators USER INTERFACE RECORDS OTHERS Alphanumerical display 4x20 Data Logger Breaking Arcing Current I2 t Graphic d...

Page 31: ...aphic Display with IEC symbols 240x128 pixels and enhanced protection functionality see Note 2 REAR SERIAL COMMUNICATIONS BOARD 1 F None A Redundant RS485 P Redundant plastic fiber optic G Redundant glass fiber optic X Redundant RS485 fiber remote CAN bus I O Y Redundant plastic fiber optic fiber remote CAN bus I O Z Redundant glass fiber optic fiber remote CAN bus I O C Cable Remote CAN Bus I O M...

Page 32: ...3328A 2 3 ORDERING CODE 2 PRODUCT DESCRIPTION 2 F1G5 is a valid selection and F5G1 is and invalid selection 2 The Protection functionality description for basic and enhanced models is listed in section 2 2 1 ANSI DEVICE NUMBERS AND FUNCTIONS on page 2 3 ...

Page 33: ...2 4 1 1 PHASE TIME OVERCURRENT 51PH 51PL Current Input Phasor without harmonics or RMS Rated current For connection to 1 or 5 A CTs Pickup level 0 05 to 160 00 A in steps of 0 01 A Dropout level 97 to 98 of the pickup level Level Accuracy Values at nominal frequency 0 5 of the reading 10 mA from 0 05 to 10 A 1 5 of the reading for higher values Curve Shapes IEEE extremely very moderately inverse I...

Page 34: ... or time delayed according to IEEE Timing accuracy Operate at 1 03 times the pickup 3 of operate time or 50 ms whichever is greater Saturation Level 48 times the pickup level Snapshot Events Selectable by setting Current Input Fundamental Phasor without harmonics Pickup level 0 05 to 160 00 A in steps of 0 01 A Dropout level 97 to 98 of the pickup level Level Accuracy Values at nominal frequency 0...

Page 35: ...urve Curve Multiplier Time Dial 0 00 to 900 00 s in steps of 0 01 s Reset type Instantaneous or time delayed according to IEEE Timing accuracy Operate at 1 03 times the pickup 3 of operate time or 50 ms whichever is greater Saturation Level 48 times the pickup level Snapshot Events Selectable by setting Current Input Phasor without harmonics or RMS Rated current For connection to 1 or 5 A CTs Pick...

Page 36: ...time delay 3 of operate time or 50 ms whichever is greater Snapshot Events Selectable by setting Current Input Phasor without harmonics or RMS Rated current For connection to 1 or 5 A CTs Pickup level 0 005 to 16 000 A in steps of 0 001 A Dropout level 97 to 98 of the pickup level Level Accuracy Values at nominal frequency 1 5 of the reading 1 mA from 0 005 to 16 A Overreach 2 Trip delay 0 00 to 9...

Page 37: ...acy Operate at 1 03 times the pickup 3 of operate time or 50 ms whichever is greater Saturation Level 48 times the pickup level Snapshot Events Selectable by setting Current Input Fundamental Phasor without harmonics Rated current For connection to 1 or 5 A CTs Pickup level 0 05 to 160 00 A in steps of 0 01 A Dropout level 97 to 98 of the pickup level Level Accuracy Values at nominal frequency 0 5...

Page 38: ... Directionality Forward and reverse selectable by setting Polarizing Voltage current dual Polarizing Voltage VN measured or calculated selected by setting Polarizing Current Isg measured from 5th current transformer Operating Current Ig measured from 4th current transformer Polarizing Voltage threshold 0 to 00 Vac in steps of 1 V Polarizing Current threshold 0 005 A Characteristic angle 90º to 90º...

Page 39: ...constant 0 0 to 8 0 in steps of 0 1 Negative sequence influence Snapshot Events Selectable by setting Pickup level 0 02 to 20 00 in units of Phase CT Primary in steps of 0 01 Dropout level 97 to 98 of the pickup level Slope 0 00 to 100 00 in steps of 0 01 Trip delay 0 00 to 600 00 s in steps of 0 01 s Operate time 50 ms at 50 Hz typically Timing accuracy 3 of operate time or 50 ms whichever is gre...

Page 40: ... Supervised by Breaker Selectable by setting Snapshot Events Selectable by setting Voltage Input Fundamental Phasor of the neutral voltage calculated from phases Pickup level 3 to 500 in steps of 1 V Dropout level 97 to 98 of the pickup level Level accuracy 1 reading 0 1 Full Scale from 10 to 500 V at nominal frequency Trip delay 0 00 to 900 00 s in steps of 0 01 s Reset delay 0 00 to 900 00 s in ...

Page 41: ...f 1 V Dropout level 97 to 98 of the pickup level Level accuracy 1 reading 0 1 Full Scale from 10 to 500 V at nominal frequency Curve Shapes Fixed time or inverse curve Reset type Instantaneous Curve Multiplier Time Dial 0 00 to 900 00 s in steps of 0 01 s Timing accuracy 3 5 of operate time or 50 ms whichever is greater Snapshot Events Selectable by setting Voltage Input Fundamental Phasor of phas...

Page 42: ... Trip delay 0 00 to 900 00 s in steps of 0 01 s Reset delay 0 00 to 900 00 s in steps of 0 01 s Minimum voltage threshold 30 to 00V in steps of 1 V Timing accuracy 3 5 of operate time or 100 ms whichever is greater Snapshot Events Selectable by setting Current Voltage Fundamental Phasor primary values Number of stages 2 Pickup level two stages 10000 00 to 10000 00 MW primary values in steps of 0 0...

Page 43: ...fference 2 00 to 300 00 V in steps of 0 01 V Maximum angle difference 2 0º to 80 0º in steps of 0 1º Maximum frequency slip 10 to 5000 mHz in steps of 10 mHz Synchronism time 0 01 to 600 00 s in steps of 0 01 s Angle accuracy 3º Dead Source function None DL DB Dead Line Dead Bus LL DB Live Line Dead Bus DL LB Dead Line Live Bus Snapshot Events Selectable by setting Algorithm based on positive sequ...

Page 44: ...iplier factor 0 000 to 65000 000 in steps of 0 001 Overload factor 0 to 1000000 in steps of 1 Board Origin All available input outputs boards in the device See ordering code F G H J Input origin up to 32 depending on the board type selection Analog Input Any analog value available in the device Analog Maximum Threshold value 100000 000 to 100000 000 in steps of 0 001 Analog Minimum Threshold value...

Page 45: ...eps of 0 01 df dt level accuracy 80 mHz s or 3 5 whichever is greater Overvoltage supv 0 00 to 110 00 in steps of 0 01 95 settling time for df dt 24 cycles Operate time at 2 x pickup 12 cycles at 3 x pickup 8 cycles at 5 x pickup 6 cycles Frequency Rate min 20 00 to 80 00 Hz in steps of 0 01 Frequency Rate max 20 00 to 80 00 Hz in steps of 0 01 Frequency Rate delay 0 00 to 60 00 s in steps of 0 01...

Page 46: ...V at nomi nal frequency Operate time 50 ms at 50 Hz typically Timing accuracy 3 5 of operate time or 50 ms whichever is greater Snapshot Events Selectable by setting Loss of Mains Mode One Phase Phase Shift Angle 2 00 to 22 00 in steps of 0 01 degrees Minimum Voltage 30 to 500 in steps of 1 V Level accuracy 3º Timing accuracy 3 5 of operate time or 60 ms whichever is greater Snapshot Events Select...

Page 47: ...KER SETTINGS Number of Switchgear 1 to 16 selection of switchgear for breaker control Maximum KI2 t 0 00 to 9999 99 in steps of 0 01 kA 2 s KI2 t integration Time 0 03 to 0 25 s in steps of 0 01 s Maximum openings 0 to 9999 in steps of 1 Maximum Openings in one hour 1 to 60 in steps of 1 Snapshot Events Selectable by setting ...

Page 48: ...torage In non volatile memory flash without battery Format International Standard COMTRADE ASCII IEEE C37 111 1999 Automatic Overwrite Selectable by setting Oscillography records can be concatenated Snapshot Events Selectable by setting Method Single ended Positive Sequence Module 0 01 to 250 00 Ohm in steps of 0 01 Ohms Positive Sequence Angle 25 to 90º in steps of 1º Zero Sequence Module 0 01 to...

Page 49: ...ts must be added Timing Accuracy 1 ms using the IRIG B synchronization input Triggers By any digital signal programmable through PLC Alarm Possibility to display the event as an alarm on the alarms panel Information available always through Communications for all models and also in HMI for models with graphical display M in ordering code Data Storage In non volatile memory flash without battery Co...

Page 50: ...o create user programmable logic to be distributed as a single object Inputs Any logical variable contact or virtual input Number of timers 8 maximum in each logic scheme provided in library format Number 4 A through D Reset points 40 0 through 1 of pickup Operate points 80 1 through 20 of pickup Time delay 0 to 65535 ms in steps of 1 Saturation Level 20 times the pickup level Number 15 configurab...

Page 51: ... outputs In graphical displays only Number of selectable displays Logotype metering or both in scrolling mode can be selectable as default screen in text display for all models basic and mimic The metering screen contains current and voltages for phases and ground in primary values Number of configurable Keys 5 Operation drive PLC operands Accuracy 0 5 of the reading 10 mA from 0 05 to 10 A for ph...

Page 52: ...ccuracy 1 0 of the reading Range 0 to 2147 MVArh Parameters 3 phase only Update rate 100 ms Accuracy 0 02 Parameters 3 Phase and single phase Accuracy 30 mHz at 50 Hz 36 mHz at 60 Hz Accuracy 3º CT Ratio 1 0 to 6000 0 in steps of 0 1 Rated currents Appropriate for 1 or 5 A G650 has universal range for CT valid for 1 or 5 A to only one terminal Relay Burden 0 04 Ohm Current Withstand Continuous at ...

Page 53: ...dance 100 kOhm Maximum error 10 setting or 5 V Load for voltage supervision inputs 2 mA V 100 kOhm Voltage threshold for voltage supervision inputs 10 V fixed Debounce Time 1 to 50 in steps of 1 ms Recognition time 1ms Timing resolution 1 ms For Input Activation Voltage Threshold and Debounce Time there is a single setting for all inputs in the same group inputs sharing the same common Input Type ...

Page 54: ... DC max at 250 Vdc Operate Time 8 ms Contact material Silver Alloy Output Logic Type Output Type and Pulse Output Time are selectable by setting for each output Output Logic Type Positive Negative Output Type Normal Pulse Latch Selectable by setting for each output Pulse Output Time 0 to 60000 ms in steps of 1 ms applicable only to signals set as pulse type Separate operate and reset signal can be...

Page 55: ...300 600 1200 2400 4800 9600 19200 38400 57600 y 115200 bauds Default Baud Rate 19200 Protocols available ModBus RTU DNP 3 0 Typical distance 1200 m Isolation 2 kV ASYNCHRONOUS REAR PORTS None or two rear ports depending on model COM1 COM2 rear COM2 multiplexed with front port Type depending on model Model F None Model A Redundant RS485 Model X Redundant RS485 fiber CAN for inputs outputs module Mo...

Page 56: ...ng on model Model B 10 100BaseTX self negotiable Model C 10 100BaseTX 100Base FX Model D 10 100BaseTX redundant 100BaseFX Physical media redundancy Model E Redundant 10 100BaseTX self negotiable ports 10 100BaseTX RJ45 connector 100BaseFX ST connectors Wave length 1300 nm Fiber type multimode 62 5 125 μm or 50 125 μm Protocols available ModBus TCP IP DNP over TCP IP and UDP IP Http ftp tftp allow ...

Page 57: ...esponse to a logic 0 input This specification applies to either 62 5 125 μm or 50 125 μm fiber cables 3 This specification is intended to indicate the performance of the receiver section of the transceiver when Input Optical Power signal characteristics are present per the following definitions The Input Optical Power dynamic range from the minimum level with a window time width to the maximum lev...

Page 58: ...NDARD CLASS TEST EMC IEC 61000 4 1 IEC 60255 22 1 III Oscillatory waves immunity IEC 61000 4 2 IEC 60255 22 2 IV Electrostatic discharge immunity test IEC 61000 4 3 IEC 60255 22 3 III Radiated electromagnetic field disturbance test IEC 61000 4 4 IEC 60255 22 4 IV Electrical fast transient IEC 61000 4 5 IEC 60255 22 5 IV Surge immunity test IEC 61000 4 6 IEC 60255 22 6 III Conducted electromagnetic...

Page 59: ...GEK 113328A G650 Generator Protection Control System 2 33 2 PRODUCT DESCRIPTION 2 5 EXTERNAL CONNECTIONS 2 2 5EXTERNAL CONNECTIONS Figure 2 3 G650 WIRING DIAGRAM 189C4216H17R1 ...

Page 60: ...1P BLOCK F25 F8 CC4 50 2 BLOCK F26 F9 COMMON 1 4 COMMON 1 4 F27 F10 COMMON 5 8 COMMON 5 8 F28 F11 CC5 50G BLOCK F29 F12 CC6 51G BLOCK F30 F13 CC7 51 2 BLOCK I SENS F31 F14 CC8 67G BLOCK F32 F15 COIL 2 F33 F16 52 a I SENS F34 F17 COIL 2 F35 F18 52 b F36 INPUTS F1 OUTPUTS F1 USER CONFIGURABLE INPUTS USER CONFIGURABLE OUTPUTS O1 FREQ PICKUP O2 27 59 PICKUP O3 50 67G PICKUP O4 51 67G PICKUP O5 50 67P ...

Page 61: ...Vista 650 Setup software interface 3 1 2 ENERVISTA 650 SETUP SOFTWARE OVERVIEW This software package uses ModBus protocol and it is designed to communicate with a single relay at a time GE offers different communication software packages such as GE POWER which can be used to communicate simultaneously with several relays EnerVista 650 Setup software provides an easy way to configure monitor and ma...

Page 62: ...ovide a visual display of power system and relay operation data captured during specific triggered events 3 1 2 5 FIRMWARE UPGRADES The firmware of a G650 device can be upgraded locally or remotely via the EnerVista 650 Setup software The corresponding instructions are provided by the EnerVista 650 Setup Help file under the topic Upgrading Firmware Modbus addresses assigned to firmware modules fea...

Page 63: ...AL VALUES 3 1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 3 3 1 3 MAIN SCREEN The EnerVista 650 Setup software main window supports the following primary display components Title bar Main menu bar Main icon bar Working area Status bar Figure 3 1 ENERVISTA 650 SETUP MAIN SCREEN Working Area Title ...

Page 64: ... viable or even in worst cases the relay and or the computer could result damaged by overvoltages For on line working previously ensure that all relay communication parameters such as baudrate slave ModBus address etc match the computer settings Figure 3 2 COMMUNICATION PARAMETERS MENU The Communication computer screen is divided in several subsections Computer settings Main communication paramete...

Page 65: ...BUS TCP this option selects ModBus TCP IP communication mode for communication through the Ethernet port In this case the top right window will show the typical parameters to be programmed IP address port address and unit identifier in the MODBUS TCP SETUP section MODEM this option displays the parameter to set in case of using a modem for the communication such as Phone number Time out sec init c...

Page 66: ... relay configuration Is it necessary to program additional logic Launch the Logic Configuration tool in EnerVista 650 Setup Setpoint Logic Configuration Create new or modify the existing logic File Open Project Compile and save logic file pep and drawing design aut in Logic Configuration tool Exit PLC Graphic Editor and save the 650 file from the main application menu Is the relay completely confi...

Page 67: ...ditor PLC Editor Contents Relay configuration file containing all protection elements Settings input output and LEDs configuration graphic display configuration etc Equations corresponding to the logic created and compiled in the PLC Editor PLC project file containing the necessary information relative to the relay model logic libraries included in the project lib graphic file name aut etc PLC Pro...

Page 68: ... logic Launch the Logic Configuration tool in EnerVista 650 Setup Setpoint Logic Configuration Create new or modify the existing logic File Open Project Compile Run Compile and save logic file pep and drawing design aut in Logic Configuration tool File Save Project Send logic to relay Run Send Equations to Relay and Exit PLC Graphic Editor Is the relay completely configured Save all settings confi...

Page 69: ... projects How to transfer to relay Connect with the relay Communications Computer Connect with the relay Communications Computer Send settings and configuration from file Launch 650 Logic equations editor Setpoint Logic Configuration Open the created PLC project File Open Project Compile the project Run Compile Now the logic virtual outputs can be sent directly to relay Run Send Equations to Relay...

Page 70: ...le has been opened Table 3 3 ENERVISTA 650 SETUP MENUS STRUCTURE FILE SETPOINT ACTUAL OPERATIONS COMMUNICATION SECURITY VIEW HELP New Product Setup Front Panel NA Computer Login user Traces Instruction Manual Open System Setup Status NA Modem Change Password ModBus Memory Map GE Multilin on the web Save Protection Elements Metering NA Troubleshooting User Management About EnerVista 650 Setup Save ...

Page 71: ...tings and configuration file Save As Save as 650 settings and configuration file Close Close the opened 650 file in EnerVista 650 Setup Config File 650 Converter Tool to convert the 650 files from one version to another Properties File properties for 650 Get info from relay Retrieve the 650 settings and relay configuration compiled equations from the relay Send info to relay Send and write the 650...

Page 72: ...e options to fully program the unit The enabled menus in the EnerVista 650 Setup program are File Setpoint Actual Communication View and Help The off line mode displays the File Setpoint Actual Communication Security View and Help submenus to program the unit The Actual values submenus are for structure purposes only Values are not refreshed while the relay is not communicating The Save as and Clo...

Page 73: ...le and select the version and model to be converted to It is possible to change the model type FXGX using the conversion tool It must be taken into account that part of the logic can be readjusted to fit the new input and output boards selection Notice also that the external wiring of inputs and outputs board are different for type 1 2 4 and 5 3 1 7 3 PROPERTIES When this option is selected the pr...

Page 74: ...nting options and settings for the printing device b PRINT PREVIEW Option to preview the whole settings and configuration file 650 in paper format to be printed as shown in Figure 3 8 Figure 3 8 PRINT PREVIEW OF SETTINGS FILE c PRINT In this option the program will print the relay configuration using the PC default active printer on port COMx or LPT This option is active only in off line mode in f...

Page 75: ...Contact I O settings for all boards available in device Remote Comms Relay Configuration Configuration of Outputs LEDs Operations Protection Elements Oscillography Control Events Switchgear Inputs Virtual Inputs Operations and HMI Whole relay configuration with internal relay signals or user definable ones as logic virtual outputs Logic Configuration Logic configuration graphic editor PLC Editor I...

Page 76: ... and IEC61850 models IEC 870 5 104 TCP Port Common Addr of ASDU Cyclic Meter Period and Synchronization Event settings Available for standard and IEC61850 models SNTP Synchronization over Ethernet settings SYSTEM SETUP General Settings This screen describes and enables the settings of the power system where the relay will operate Some of these settings will be used only for metering values present...

Page 77: ...tions for phase current Neutral Current All overcurrent grouped functions for neutral current Calculated from phases not measured Ground Current All overcurrent grouped functions for ground current Measured from 4th current input Sensitive Ground Current All overcurrent grouped functions for sensitive ground current Measured from 5th current input Negative Sequence Current All Negative sequence ov...

Page 78: ...ent and dual polarization Restricted Gnd Fault Restricted Ground Fault 87G Enhanced models only SENSITIVE GROUND CURRENT Sensitive Ground TOC Sensitive ground time overcurrent 51SG Enhanced models only Sensitive Ground IOC Sensitive ground instantaneous overcurrent 50SG Enhanced models only NEGATIVE SEQUENCE CURRENT Negative Sequence TOC Negative sequence time overcurrent 51 2 Negative Sequence IO...

Page 79: ...and over and under frequency which are usually considered as control elements The rest of control elements such as fuse failure breaker failure synchronism and breaker settings are not involved in the tabled groups concept Underfrequency Underfrequency unit 81U Grouped element Overfrequency Overfrequency unit 81O Grouped element Synchrocheck Synchronism check unit 25 Not grouped a single unit prov...

Page 80: ...y logical variable contact or virtual input Text configuration is only for off line mode NOTE This screen is used for the configuration of digital channels and oscillography trigger The rest of parameters such as function enabling disabling sampling rate number of oscillography files etc must be set on the Setpoint Product Setup Oscillography menu Control Events Up to 128 user programmable events ...

Page 81: ...otection Control System 3 21 3 HUMAN INTERFACES SETTINGS ACTUAL VALUES 3 1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 3 The following figures show an example of the default factory configuration for G650 Figure 3 9 RELAY CONFIGURATION ...

Page 82: ... project file containing the necessary information relative to the relay model logic libraries included in the project lib graphic file name aut etc aut PLC Project file containing all the drawings used by the logic required by 650 relay based on IEC 61131 3 standard Functional block diagram FDB lib User programmable logic objects Library file to be included as an object in a PLC project Logic pac...

Page 83: ...ecuted and interlocks are fulfilled Breaker Breaker status open closed or undefined The rest of the status signals corresponding to the switchgear XX configured as breaker are in the Status Switchgear Status Switchgear XX menu Protection Status of all the protection units in the device Control Elements Status of all the control units available in the device Protection Summary This screen shows a c...

Page 84: ...for ground current measured from 5th current input Negative Sequence Current Protection status signals pickups and operations for negative sequence time overcurrent function Voltage Protection status signals pickups and operations for all voltage functions undervoltage overvoltage neutral overvoltage negative sequence overvoltage and auxiliary under and over voltage Volts Hz and ground overvoltage...

Page 85: ...als for energy counters Breaker Maintenance All signals related to breaker maintenance such as number of openings closings KI 2 t counters alarm signal for KI 2 t etc METERING Primary Values Primary values measurements for currents voltages power energy and demand Secondary Values Secondary values measurements for currents voltages and power Phasor Diagram Current voltage and sequence components F...

Page 86: ...ations previously configured in the relay with their corresponding texts Table 3 23 GENERAL OVERVIEW OF OPERATIONS MENU Options enabled only in On line mode are marked as Options enabled only in Off line mode are marked as RECORDS Event recorder Retrieval and visualization of snapshot event all and new control events and alarm panel By serial or Ethernet ModBus RTU or TCP IP Waveform capture Retri...

Page 87: ... Troubleshooting Serial or Ethernet connection Lets the user to perform reading or writing in ModBus addresses for verifying communications and access to different positions in the ModBus memory map Only available if the COMMUNICATION Computer Menu to start communication with the relay Modem Menu to set modem communication parameters only available if control type is set to modem in computer menu ...

Page 88: ...ate the firmware version of the relay through Ethernet communication Firmware is related to the relay internal program designed by GE Multilin which performs the protection and control functions and which is run by the relay main microprocessor Upgrade operating system Serial and Ethernet connection Go to Communications Upgrade operating system This option allows the user to update the relay opera...

Page 89: ...piled logic equations This file can be retrieved from the relay using the File Get info from relay option in EnerVista 650 Setup through serial or Ethernet communication File Send info to relay option stores this 650 file in the relay pep aut and lib files contain the logic configuration projects necessary to modify the logic virtual outputs in the relay These files can be stored in the relay usin...

Page 90: ...n manual English only and can be obtained from EnerVista 650 Setup program Table 3 26 GENERAL OVERVIEW OF VIEW MENU Options enabled only in On line mode are marked as Options enabled only in Off line mode are marked as 3 1 14 HELP MENU OVERVIEW Complete instructions manual and data about EnerVista 650 Setup release Table 3 27 GENERAL OVERVIEW OF HELP MENU SECURITY Login User Log on menu for EnerVi...

Page 91: ... ordering code option for the text display model basic and M the code for the mimic display graphical The boot code and firmware versions can be seen in the relay text main screen this screen is the default screen in the text menu for all models After the text G650 appears the relay firmware version 3 22in the example and between brackets the boot program version 4 10 in the example followed by Ge...

Page 92: ...will be reset The latched conditions can also be reset via communications using the LED reset input to configure this signal go to Setpoint Relay Configuration Protection elements LED RESET INPUT By default this LED reset input signal is set to LEDS RESET operation 3 2 3 PUSHBUTTONS The front panel provides Push buttons keypad 5 user programmable plus ESC non configurable shuttle key or shuttle ke...

Page 93: ...een OFF red Press the command button to switch from local to remote operations mode and vice versa OFF status operation inhibited for maintenance and safety can be reach pressing the commands pushbutton during several seconds local remote off sequence 3 2 4 FRONT PORT AND COVER SEALING SYSTEM Figure 3 16 shows the detail of the front RS232 communication port and local remote button access cover se...

Page 94: ... level menu without changing to other low levels rotate the shuttle key left to move up and right to move down When rotating the shuttle key the selected menu is marked by a single scroll bar character The mark in the right part of any menu means that contains more than one level Figure 3 17 Shows an example of main menu navigation Figure 3 17 NAVIGATION IN MAIN TEXT MENU Symbol Action Performed N...

Page 95: ...otection and control settings available in device Press shuttle key to enter next level Move L R to select submenu Press ESC to return to previous level Change Settings Menu that allows changing all protection and control settings available in device Inputs and outputs settings relay configuration and logic configuration are not available in HMI only via EnerVista 650 Setup software Press shuttle ...

Page 96: ...s Status Operation Bits Breaker Protection Protection Blocks Phase Current Neutral Current Ground Current Sens Ground Current Neg Seq Current Thermal Model Voltage Power Control Elements Frequency Synchrocheck Breaker Failure enhanced models only VT Fuse Failure enhanced models only Setting Groups Pulse Counters Analog Comparators Loss of Mains enhanced models only Loss of Excitation Accdnt Energ ...

Page 97: ...el in actual values Phase Current in the example Second Line Data identifier in the example PH IOC1 HIGH A is the pickup signal for the first instantaneous overcurrent function level high for phase A Third line Status of the displayed actual value Fourth Line Relative position in the menu it is the first value of 114 Figure 3 18 ACTUAL VALUES SCREEN DATA In the Actual Values menus are different ty...

Page 98: ...ation Press shuttle key from the default main screen and enter in the main text menu Move the shuttle key until a single scroll bar character appears in the left part of Snapshot event header Press shuttle key to enter in the snapshot events menu Select the snapshot event to display using the shuttle key left and right to move up and down inside the recorded snapshot events Once selected the snaps...

Page 99: ...must press the shuttle key for this screen to disappear The HMI will not allow to perform any other operation until the screen is acknowledged In the event of several consecutive faults the HMI will always show the most recent fault and the user will need to acknowledge all of them up to a maximum of ten faults In the second option viewing the fault reports in the menu available in the HMI the Fau...

Page 100: ...pe distance and date and time Second screen with metering data for that fault record All this data is a summary from the fault report file that can be retrieved via EnerVista 650 Setup software Figure 3 20 FAULT REPORT NAVIGATION IN HMI Possible fault types are as follows GROUND Ground faults AG phase A to ground ABG phase AB to ground BG phase BG to ground BCG phase BCG to ground CG phase CG to g...

Page 101: ...t sublevel is reached move up and down to visualize the settings selected Table 3 30 GENERAL OVERVIEW OF VIEW CHANGE SETTINGS MAIN MENU MAIN SETTINGS MENU FIRST LEVEL SECOND LEVEL THIRD LEVEL Product Setup Communication Serial Ports Ethernet Ethernet 1 Ethernet 2 ModBus Protocol DNP3 Slave DNP3 Slave 1 DNP3 Slave 2 DNP3 Slave 3 IEC 870 5 104 SNTP Fault Report Oscillography Demand System Setup Gene...

Page 102: ... Ground Dir 3 Restd Gnd Fault Enhanced models only Restd Gnd Fault 1 Restd Gnd Fault 2 Restd Gnd Fault 3 Sens Ground Curr Sens Ground TOC Enhanced models only Sens Ground TOC 1 Sens Ground TOC 2 Sens Ground TOC 3 Sens Ground IOC Sens Ground IOC 1 Sens Ground IOC 2 Sens Ground IOC 3 Neg Seq Current Neg Seq TOC Neg Seq TOC 1 Neg Seq TOC 2 Neg Seq TOC 3 Neg Seq IOC Neg Seq IOC 1 Neg Seq IOC 2 Neg Seq...

Page 103: ...Auxiliary UV 1 Auxiliary UV 2 Auxiliary UV 3 Volts per Hertz Enhanced models only Volts per Hertz 1 Volts per Hertz 2 Volts per Hertz 3 Ground OV Ground OV 1 Ground OV 2 Ground OV 3 Power Directional Power Directional Power 1 Directional Power 2 Directional Power 3 PF Limiting Enhanced models only PF Limiting 1 PF Limiting 2 PF Limiting 3 Control Elements Setting Group Underfrequency Underfrequenc...

Page 104: ...tion Control System GEK 113328A 3 2 HUMAN MACHINE INTERFACE HMI 3 HUMAN INTERFACES SETTINGS ACTUAL VALUES 3 Autoreclose Breaker Failure VT Fuse Failure Enhanced models only MAIN SETTINGS MENU FIRST LEVEL SECOND LEVEL THIRD LEVEL ...

Page 105: ...3 Freq Rate of Change Freq Rate of Change 1 Freq Rate of Change 2 Freq Rate of Change 3 Loss of Mains Enhanced models only Loss of Mains 1 Loss of Mains 2 Loss of Mains 3 Loss of exc Loss of exc 1 Loss of exc 2 Loss of exc 3 Accdn Energ Accdn Energ 1 Accdn Energ 2 Accdn Energ 3 MAIN SETTINGS MENU FIRST LEVEL SECOND LEVEL THIRD LEVEL ...

Page 106: ...ackets Choose the new value moving up and down the shuttle key After selecting the appropriate value press again the shuttle key to fix that value To save the new settings go to the end of the menu rotating the shuttle key right and select the menu Press Enter to save settings When pressing the shuttle key inside this menu the new settings will be saved Select the menu Change settings and press th...

Page 107: ...ating the shuttle key after selecting the desired value press again the shuttle key to store the value Year Date Day Month Year Time Hour Minutes Seconds After storing the value for Year Month will appear between brackets and can be modified Month Date Day Month Year Time Hour Minutes Seconds After storing the value for Month Day will appear between brackets and can be modified Day Date Day Month ...

Page 108: ...ion text will be displayed Example of commands operations executions via HMI Press the shuttle key in the menu commands when it is selected in the display All the previously configured commands will be displayed Rotate the shuttle key move through the available commands Press ESC to return to previous level Press shuttle key to pre select the operation to be executed When the message Push Enter fo...

Page 109: ...in this menu there are three types of functionality Login For entering the password either for settings or commands and enable access to settings or commands Once entering the password the relay is no longer password protected and access is enabled to settings modification or commands execution Logout Once the necessary setting changes or operation commands have been executed the user can log out ...

Page 110: ... the user must logout Logout Pwd Settings or Logout Pwd Commands For safety reasons if the user does not log out the relay will do it automatically 15 minutes after the last keypad action d CHANGING THE PASSWORD CHANGE PWD COMMANDS To set a password in the relay both for settings and commands the corresponding menu must be accessed inside the Password menu Change Pwd Settings or Change Pwd Command...

Page 111: ... screen the relay logotype including the firmware and boot code versions the relay model and the communication parameters for local port COM2 Figure 3 24 DEFAULT LOGOTYPE SCREEN Metering This option shows a Metering screen including the phase and ground currents as well as phase to phase voltage and zero sequence voltage values all of them in primary values Figure 3 25 DEFAULT METERING SCREEN All ...

Page 112: ...ality is described in section 3 2 5 in this manual Intro Next Pressing the shuttle key the user access the next graphical screen which in this case corresponds to the primary metering values screen L R Select Once the different switchgear elements to be operated have been configured using EnerVista 650 Setup the user will be able to operate them from the graphic display If a single line diagram ha...

Page 113: ...ne Frequency Primary Phasor Ib Primary V1 Primary Phase B Reactive Pwr Bus Frequency Primary Phasor Ic Primary V2 Primary Phase B Apparent Pwr Vx Primary Phasor Ig Primary Vab Primary Phase B Real Pwr Pos MVarhour Freeze Phasor Isg Primary Vbc Primary Phase C Reactive Pwr NegMVarhour Freeze Phasor In Primary Vca Primary Phase C Apparent Pwr PosMWatthour Freeze RMS Ia Primary Vn Primary Phase C Rea...

Page 114: ...ng the shuttle key the user accesses the Events menu that offers the following options at the bottom of the screen next prev reload details At To access the different options in the snapshot events graphic menu the user must move the cursor from left to right The selected option will be displayed in upper case and between brackets To access the selected option the user must press again the shuttle...

Page 115: ... user must press the shuttle key A new metering screen will be displayed containing the primary metering values in the snapshot event such as Once inside the Metering screen a new legend will be shown for each event Intro or ESC Prev L R Scroll this legend indicates that by pressing ESC or the shuttle key the system will return to the Event Detail screen and rotating the shuttle key the user will ...

Page 116: ...is as follows Esc Out At Intro Tag event Esc Out At The relative event marking is eliminated and the system returns to the general events screen Intro Tag event If the user places the cursor on a different event by rotating the shuttle key left or right pressing the shuttle key will change the relative mark to that new event 3 2 6 4 NEW EVENTS SCREEN This screen shows the new events that have been...

Page 117: ...ification text and its status active ON or inactive OFF In the previous example the produced alarm is the change to local of the execution of operations OPERATIONS IN LOCAL MODE the date and time when this event has been produced and its status ON The bottom of the screen shows the legend that indicates how to navigate through the different options available in the screen ESC Prev Intro Next ESC P...

Page 118: ... to verify wiring The format of this screen is shown on the figure below The first line shows the name of the screen I O Cards followed by the type and description of the board where the cursor is located which will appear between selection marks and blinking Figure 3 31 INPUTS OUTPUTS GENERAL SCREEN The navigation legend on this screen is as follows Esc Prev Intro Menu L R Chg Card Esc Prev This ...

Page 119: ...the I O menu next view test input test output L R Chg Card Moving the shuttle key to the left or right provides access to the status of inputs outputs for the different boards available in the relay TEST INPUT This option allows testing the input activation in emulation mode The displayed screen is similar to the viewing screen but in this case the user can operate the different relay inputs This ...

Page 120: ...reen shows the Output name lit up showing that this is an output emulation mode The first relay output will appear blinking and between brackets the user can select a different output by rotating the shuttle key When the shuttle key is pressed the selected output will be activated Navigation through this screen is indicated by the following legend Esc Exit Text Intro Chg Output Esc Exit Text The E...

Page 121: ...dress which must be configured in Setpoint Product Setup Communication Settings Ethernet The main screen of the G650 web server shows the different monitoring possibilities for snapshot events events alarms oscillography fault reports data logger and metering values provided by the relay through the web In order to access the different functions provided by the web server the user must simply clic...

Page 122: ...ute The information provided in this screen includes first the relative event index the lowest index corresponding to the most recent event next the event text that shows the reason for the event its status active ON or inactive OFF and finally the date and time when the event was produced The bottom of the screen shows a Metering screen clicking on one of the events the associated metering values...

Page 123: ...onfigured in the Control Events screen inside the Relay Configuration menu of EnerVista 650 Setup Figure 3 35 CONTROL EVENTS SCREEN Unlike the case of Snapshot events in this screen the highest index corresponds to the most recent event The information provided is the control event index the text that has been associated to such event when configured its status active ON or inactive OFF and its da...

Page 124: ...3 HUMAN INTERFACES SETTINGS ACTUAL VALUES 3 3 3 4 ALARMS The alarms screen provides access to alarms configured in the relay As in the case of snapshot events and control events this screen allows only to view the alarms but not to acknowledge them Figure 3 36 ALARMS SCREEN ...

Page 125: ...igure 3 37 OSCILLOGRAPHY SCREEN If the user clicks on the oscillo record he wants to retrieve the window on the right will show a description of the record header indicating its date time and the most relevant parameters of the record Once a record is selected it is required to press the Download button The system will then open a window to allow saving the files in Comtrade format in the PC hard ...

Page 126: ...f a safety warning message Figure 3 39 FAULT REPORT SCREEN The information provided in this screen includes the date and time when the fault was registered fault calculations such as distance to the fault type of fault date and time and the line parameters as well as the recloser and breaker status during the fault This screen shows also prefault and fault voltage and current primary values At the...

Page 127: ...SERVER 3 3 3 7 DATA LOGGER The data logger screen allows viewing the data logger first and last value retrieval date and allows downloading the data record files in Comtrade format by pressing the Download option Stored files can be viewed later using any Comtrade format viewer Figure 3 40 DATA LOGGER SCREEN ...

Page 128: ...Protection Control System GEK 113328A 3 3 WEB SERVER 3 HUMAN INTERFACES SETTINGS ACTUAL VALUES 3 3 3 8 METERING This screen includes the 54 primary metering values provided by the relay display Figure 3 41 METERING SCREEN ...

Page 129: ...u to confirm the delete and if the Administrator chooses yes then the user whose Delete Entry box was checked will be permanently deleted from the list Admin WARNING When this box is checked the user will become an EnerVista 650 Setup Administrator therefore receiving all of the Administrative rights Actual Values When this box is checked the user will have the ability to view Actual Values and al...

Page 130: ...ose Change Password Figure 4 1 CHANGE SECURITY When the operator enters a new password for the first time he she should also enter a personal question that only they could answer There is a limit of 50 characters available to enter the personal question One example as in the above diagram would be What is my mother s maiden name This question will be posed to the user if the user forgets their pas...

Page 131: ...ion and are granted access as Administrator Security Control can be enabled through Security from the tool bar when logged on as an Administrator Click on User Management and a dialog box will show up Figure 4 2 SECURITY ENABLING Security Control is enabled by checking the ENABLE SECURITY check box The first time the enable security option is selected is necessary to close and open EnerVista 650 S...

Page 132: ... TestUser For the first log in session of any user name the default password will be password User will be prompt to change the password to something else after the first successfully log in Log on can also be done by clicking Security from the toolbar and choose Login New User User will be prompted with the same log in dialog box for a different user name and password combination In case a user h...

Page 133: ... maintain version compatibility between firmware and boot code in the upgrade procedure otherwise the relay will not start after upgrading WARNING BEFORE PERFORMING THE UPGRADE PROCEDURE CHECK THAT BOOT AND FIRMWARE VERSION MATCH FIRMWARE AND BOOT VERSIONS COMPATIBILITY FIRMWARE VERSION BOOT VERSION 3 74 4 10 3 22 4 10 NOTE A STEP LIST SUMMARY that will allow the user to control the upgrading proc...

Page 134: ...o avoid collisions In the case of relay that has upgraded previously its Bootcode Sections 2 the IP address already has been assigned in the previous process see Figure 5 14 For example if the relay settings are IP address 192 168 37 177 Netmask 255 255 255 0 and Gateway 192 168 37 10 The computer settings have to follow the pattern NOTE RELAYS WITH FIBER OPTIC ETHERNET The upgrade of the boot pro...

Page 135: ...rn in the computer it should be added in order to communicate with the relay following these steps Go to the Control Panel of the computer and select the Network option the name of this option may depend on the PC boot code Figure 5 2 NETWORK IN CONTROL PANEL In Network enter in Protocols select TCP IP protocol and click on Properties Figure 5 3 TCP IP PROPERTIES In the IP address tab select Advan...

Page 136: ...ODUCTION 5 BOOTCODE AND FIRMWARE UPGRADE 5 Figure 5 4 IP ADDRESS FOR COMPUTER Windows allows Multihosting so it permits having as many IP addresses as desired It is necessary to turn off and on the computer to activate the new address that has been assigned to the PC ...

Page 137: ...aphy etc from the relay before the upgrade It is extremely important to save the relay settings and calibration before continuing with the process Figure 5 5 LOST DATA WARNING MESSAGE To upgrade the boot code it is required to connect an RS232 cable to the front of the relay and an Ethernet cable to the rear port COM3 The serial communication parameters will be the ones selected in the Communicati...

Page 138: ...ss that is going to be used lately in the relay for Ethernet connection Figure 5 7 TEMPORARY IP ADDRESS SELECTION FOR BOOT UPGRADE After entering the temporary IP address a window will open up for selecting the appropriate file from the Multilin web site or Product CD Figure 5 8 BOOT FILE SELECTION Once the appropriate boot program file has been selected the program will proceed to load the select...

Page 139: ...ed in the boot upgrade procedure is the one selected in the Communication computer menu Figure 5 11 ERROR MESSAGE FOR COMMUNICATIONS PROBLEMS After switching the relay off and on if the serial communication between EnerVista 650 Setup and the relay is correct the program shows a message to select to upgrade the current version to the new one Figure 5 12 UPGRADE CURRENT VERSION At this moment selec...

Page 140: ... values should match the LAN structure in which the relay will be connected The gateway must be the one used in the LAN structure connecting the relay The relay IP address should have the first three octets corresponding with the Gateway and the last octet must be a free IP address reserved to the relay to avoid possible collisions with other devices After assigning the Ethernet parameters the upg...

Page 141: ...etup software after connecting the relay by Ethernet port COM3 5 3 1 FIRMWARE UPGRADE Once the communication with the relay through Ethernet connection has been verified1 enter the EnerVista 650 Setup program select Communication and the Upgrade Firmware Version option Therefore it is necessary to save all settings to a file before following with the process Figure 5 16 FIRMWARE BOOT VERSION COMPA...

Page 142: ...NDOW When upgrading models with Enhanced protection and control functionality see ordering code selection the program will request a password in order to continue with the process Figure 5 18 PASSWORD FOR ENHANCED MODEL UPGRADE This password can be obtained placing an order with GE Multilin The following parameters must be clearly indicated in the order ...

Page 143: ...t the firmware has been upgraded properly When upgrading the firmware the entire settings and relay configuration are reset to factory default value Once the equipment has been properly checked the G650 is ready to be used Remember that calibration settings and configuration must be loaded to the relay To recover the relay calibration Go to EnerVista 650 Setup main menu Communication Calibration S...

Page 144: ...D ORDERING CODE OF THE RELAY TO UPGRADE 7 WHEN REQUIRED BY THE PROGRAM SWITCH OFF AND BACK ON THE RELAY 8 LOCATE THE UPGRADE TXT FILE ACCORDING TO THE MODEL OF THE RELAY 9 PRESS UPGRADE FIRMWARE AND INITIATE THE UPGRADE PROCESS 10 TO COMPLETE THE PROCEDURE SWITCH OFF AND BACK ON THE RELAY WHEN REQUIRED BY THE PROGRAM 11 SET CALIBRATION SETTINGS FROM THE PC TO THE RELAY 12 THE SETTINGS AND CONFIGUR...

Page 145: ...amage during transportation and that all screws are correctly fixed and all relay terminal boards are in good condition Verify that the information shown on the relay front plate corresponds to the data shown on the display and to the requested relay model Display information Firmware version Kernel version G650 X XX K KK GENERAL ELECTRIC G650XXXXXXXXX 19200N81 MODBUS 254 Model ...

Page 146: ... used for the testing contains wide harmonics the voltmeter and relay responses will be different Relays have been calibrated in factory using a Network of 50 or 60 Hz with a minimum harmonic content When the relay is tested a power supply network with no harmonics in its waveform must be used The ammeters and chronometers used for testing the pickup current and relay operation time must be calibr...

Page 147: ...ne second WARNING No communication circuit shall be tested for isolation Groups to be created will depend on the type of modules included in G650 selectable according to the model The following table shows the different groups depending on the module type SOURCE 1 G1 H10 H18 G2 H13 H14 H15 SOURCE 2 G1 H1 H9 G2 H4 H5 H6 MAGNETIC MODULE G1 A5 A12 G2 B1 B12 I O F1 MIXED G1 Inp 1 F1 9 G2 Inp 2 F10 18 ...

Page 148: ...l System GEK 113328A 6 4 INDICATORS 6 COMMISSIONING 6 6 4INDICATORS Feed the relay and verify that when commanding a LED reset operation all LED indicators light up and they are turned off when pressing the ESC key for more than 3 seconds ...

Page 149: ...d when there is no feed If the power supply source incorporates AC feed this test will be performed also for VAC If the relay incorporates a redundant power supply these tests shall be performed on both power supplies Voltage values to be applied will be the ones indicated below according to the relay model NOTE Codes HIR and LOR correspond to a redundant power supply SUPPLY V MIN V MAX HI HIR 110...

Page 150: ...UNICATIONS Verify that available communication ports allow communication with the relay Ports to be checked are as follows Front RS232 Rear 2 x RS485 2 x Fiber Optic Serial 2 x Fiber Optic Ethernet 1 x RJ45 Ethernet A computer with EnerVista 650 Setup software and an appropriate connector must be used ...

Page 151: ... relay measures the values with an error lower than 1 5 of the test value or 1 mA whichever is greater for sensitive ground SG GENERAL SETTINGS NAME VALUE UNITS RANGE PHASE CT RATIO 1 0 0 1 1 0 6000 0 GROUND CT RATIO 1 0 0 1 1 0 6000 0 STV GROUND CT RATIO 1 0 0 1 1 0 6000 0 PHASE VT RATIO 1 0 0 1 1 0 6000 0 PHASE VT CONNECTION WYE N A WYE DELTA NOMINAL VOLTAGE 100 V 0 1 1 250 V NOMINAL FREQUENCY 5...

Page 152: ...m admissible error 10 mHz Apply 50 Vac at 60 Hz on channel VII Maximum admissible error 12 mHz Frequency measure on channel Vx terminals A11 A12 Apply 50 Vac at 50 Hz on channel Vx Maximum admissible error 10 mHz Apply 50 Vac at 60 Hz on channel Vx Maximum admissible error 12 mHz Results POWER PER PHASE THREE PHASE POWER P V I Cosϕ P Pa Pb Pc Q V I Senϕ Q Qa Qb Qc APPLIED VOLTAGE AND CURRENT VALUE...

Page 153: ... the same common For the first 8 inputs the voltage threshold setting is determined by Voltage Threshold A For the next 8 inputs the setting is Voltage Threshold B Inputs or contact converters CC1 CC16 must also be set to POSITIVE Test settings for mixed board type 2 8 digital inputs 4 blocks for supervision and 8 outputs The inputs test is completed by groups of 4 inputs as this type of board has...

Page 154: ...o both 52 a terminals F1 F2 and 52 b terminals F3 F4 Coil 1 circuit supervision inputs and verify that they are activated Remove voltage from both inputs and verify that it takes them 500 ms to change state deactivate Coil 2 Apply 19 Vdc to both 52 a terminals F15 F16 and 52 b terminals F17 F18 Coil 2 circuit supervision inputs and verify that they are activated Apply 19 Vdc to both 52 a terminals...

Page 155: ...CTION ELEMENTS 6 6 9CONNECTIONS FOR TESTING PROTECTION ELEMENTS Connect current sources to the relay according to the wiring diagram Current and voltage input terminals are as follows PHASE CONNECTIONS Current IA B1 B2 IB B3 B4 IC B5 B6 IG B9 B10 ISG B11 B12 Voltage VI A5 A6 VII A7 A8 VIII A9 A10 VX A11 A12 ...

Page 156: ...tantaneous in a time frame of 10 to 55 ms All the relay trip contacts must operate as well as the contact set as 50 Remove current and apply it again suddenly to a value of 4 times the pickup current The relay should trip instantaneously in a time frame of 10 to 45 ms Test one point for each phase and group of the protection element Note Only available for Enhanced models 50 ELEMENTS TEST PARAMETE...

Page 157: ...ccording to the time corresponding to its set curve PROTECTION ELEMENT SETTINGS 51PH 51PL 51N 51G SETTING VALUE UNIT FUNCTION ENABLED INPUT PHASOR DFT PICKUP LEVEL 1 A CURVE MODIFY FOR EACH TEST TD MULTIPLIER MODIFY FOR EACH TEST VOLTAGE RESTRAINT DISABLED ELEMENT PHASE CURVE TYPE DIAL TIMES IPICKUP TRIPPING TIMES SEC EXPECTED ADMISSIBLE 51PH IA IEEE Ext Inv 0 5 0 9 NA 1 5 11 34 11 00 11 60 5 0 64...

Page 158: ... unit will not operate If the directional element is not enabled or if it is enabled and it detects a fault in a trip direction then the overcurrent unit will operate if the set current level is exceeded 6 12 1 67N ELEMENT Activate only protection elements 50N and 67N and set the relay as follows Configure one of the outputs to be activated only by unit 50G Apply the following tests 67N SETTINGS 5...

Page 159: ...activated only by unit 50G Apply the following tests 67G SETTINGS 50G SETTINGS Function ENABLED Function ENABLED MTA 45 Deg Input PHASOR DFT Direction FORWARD Pickup Level 0 50 A Polarization VO Trip Delay 0 30 Block Logic PERMISSION Reset Delay 0 00 Pol V Threshold 10 V ELEMENTS PHASE UNDER TEST POLARIZATION PHASE ELEMENT TRIP CHANNE L MAGNITUDE CHANNEL MAGNITUDE MOD ARG MOD ARG 50G 67G IG 2 A 0º...

Page 160: ... the protection element being tested Set the relay as follows Apply voltage as indicated on the table over the undervoltage setting level and verify that the relay does not trip Decrease voltage level gradually and verify that the relay trips for the set voltage with an admissible error of 5 PHASE UV 27P Function ENABLED Mode PHASE GROUND Pickup Level 50 V Curve DEFINITE TIME Delay 2 00 sec Minimu...

Page 161: ...elay as follows Apply voltage as indicated on the table under the overvoltage setting level and verify that the relay does not trip Verify that the relay trips for the set voltage with an admissible error of 5 PHSE OV 59P Function ENABLED Pickup Level 120 V Trip Delay 2 00 Reset Delay 0 00 Logic ANY PHASE ELEMENT PHASE PICKUP LEVEL VOLTS TRIP DELAY SECONDS APPLIED VOLTAGE V TRIPPING TIME S EXPECTE...

Page 162: ...evel and verify that the relay does not trip Verify that the relay trips for the set voltage with an admissible error of 5 Vn voltage is calculated as a sum of the phase voltages NEUTRAL OV HIGH 59NH Function ENABLED Pickup Level 120 V Trip Delay 2 00 Reset Delay 0 00 ELEMENTS INPUT PICKUP LEVEL VOLTS TRIP DELAY SECONDS APPLIED VOLTAGE V TRIPPING TIME S EXPECTED ADMISSIBLE 59NH VI 120 2 114 NO TRI...

Page 163: ...rips for the set voltage with an admissible error of 5 NOTE All angles mentioned on the tables are delay angles where a balanced ABC system would be composed by NEG SEQ OV 47 Function ENABLED Pickup Level 50 V Trip Delay 2 00 Reset Delay 0 00 CHANNEL APPLIED VOLTAGE V ANGLE TRIPPING TIME S EXPECTED ADMISSIBLE VI 65 0º NO TRIP NA VII 65 120º VIII 65 240º VI 55 0º 2 1 9 2 1 VII 55 240º VIII 55 120º ...

Page 164: ...relay trips at the set frequency in the corresponding element with an error of 3 ó 50 mHz Apply a voltage that is lower than the Minimum Voltage setting with a frequency under 81U or over 81O the setting and verify that the relay does not trip GENERAL SETTINGS Nominal Frequency 50 Hz ELEMENT SETTINGS FREQUENCY 81 81U 81O Function ENABLED ENABLED Pickup Level 47 50 Hz 52 50 Hz Trip Delay 2 00 sec 2...

Page 165: ...he front serial RS232 port whereas the COM1 port is completely independent from COM2 The synchronous LAN port is COM3 Q6 Are there one or two Ethernet ports A6 The equipment has only 1 Ethernet port For redundant fiber optic versions redundancy is done at the physical level fiber optic but there is just one port Q7 How many different communication Ethernet sessions can be opened through the LAN po...

Page 166: ... for 100 it is the 50 125 or 62 5 125 multimode this last one allows longer distances Q16 What is the difference between a hub and a switch A16 In a repeater type hub shared hub one unit talks and the rest listen If all the units are talking at the same time there may be collisions in the messages what may produce certain communication delays The switch switched hub has very powerful processors an...

Page 167: ...ould be driven with externally generated DC current No special 48 Vdc or other outputs are included in the equipment to drive these inputs therefore contacts connected to the equipment should be connected to a DC source Q3 Is it oscillography programmable A3 Yes the sampling rate is programmable 4 8 16 32 or 64 samples per input The depth will depend on the sampling rate Q4 Do I have to select a d...

Page 168: ...op or handheld to program the unit A4 No all main operations can easily be performed with just the incorporated HMI Handheld or laptops may be required to download large quantities of information such as oscillograms etc but they are not mandatory for a conventional user that just needs to change settings view measurements states etc Q5 Is there password security for protection and control A5 Yes ...

Page 169: ... can access in the logic A1 The power supply ready contact only monitor hardware failures in the power supply to monitor the internal error of the unit it is necessary to configure a virtual output to and the assign it to the device desired contact output LED etc Q2 I set an output contact as Latched If I do not set a reset condition will it reset from the ESC key A2 No you have to configure the c...

Page 170: ...7 6 G650 Generator Protection Control System GEK 113328A 7 4 RELAY CONFIGURATION 7 FREQUENTLY ASKED QUESTIONS 7 ...

Page 171: ...on using ENERVISTA 650 Setup logic configuration General When feeding the unit no indicator is lit up Insufficient power supply Wrong versions Fuse failure Loose fuse Incorrect wiring Verify the voltage level using a multimeter in the power supply terminals and check that it is within the model range Check relay and ENERVISTA 650 Setup versions are the same Remove power supply dismount the power s...

Page 172: ...ommunication Enervista 650 Setup does not retrieve osc fault reports and Data Logger files Bad communication in TFTP using Windows 2000 Disable and Enable the Ethernet connection on Control Panel inside Windows 2000 Try again to retrieve files from relay Firmware and bootware upgrade Bootware The relay gets stuck during the upgrading process after switching off and on the relay giving the followin...

Page 173: ...e message Os Loading and the relay will not start up Firmware The procedure can not start due to ethernet problems The Ethernet connection does not work properly Check the same as in the point above for bootware Note if the firmware upgrading procedure got stuck at this point the relay will not be upgraded After switching it off and on will continue working with the former firmware and bootware ve...

Page 174: ... started again during the bootware and firmware upgrade process the program will ask to confirm the IEC password Firmware Password for IEC61850 incorrect Model change Incorrect mac or serial number The password is tied to the model MAC Address and serial number any change in any of the following will need a password change If the model has been modified to add or replace any boards or communicatio...

Page 175: ...PKP 91 PH IOC2 HIGH PKP 92 PH IOC3 HIGH PKP 93 PH TOC1 HIGH PKP 94 PH TOC2 HIGH PKP 95 PH TOC3 HIGH PKP 96 OR3 161 OR3 162 NEUTRAL IOC1 PKP 163 NEUTRAL IOC2 PKP 164 NEUTRAL IOC3 PKP 165 NEUTRAL TOC1 PKP 166 NEUTRAL TOC2 PKP 167 VO_004_50N_PKP 168 VO_005_51N_PKP 169 VO_051_50PH_PKP 175 VO_053_51P_PKP 176 VO_007_PHASE_OVERCURRENT_PKP 177 OR 178 VO_005_51N_PKP 179 VO_004_50N_PKP 180 VO_008_NEUTRAL_OV...

Page 176: ...GROUND_PKP 187 inOR1 inOR2 inOR3 outOR1 SENSITIVE GROUND FOR ENHANCED MODELS ONLY OR 314 NEGATIVE SEQUENCE OVERCURRENT OR3 319 NEG SEQ1 IOC PKP 320 NEG SEQ2 IOC PKP 321 NEG SEQ3 IOC PKP 322 VO_033_50 2_PKP 323 OR3 324 GEN UNBAL1 PKP 325 GEN UNBAL2 PKP 326 GEN UNBAL3 PKP 327 VO_034_GEN_UNBALANCE_PKP 328 OR3 329 VO_035_NEGATIVE_SEQ_OVERCURRENT_PKP 330 VO_006_51 2_PKP 331 VO_033_50 2_PKP 332 VO_034_G...

Page 177: ...ARY UV2 PKP 198 AUXILIARY UV3 PKP 199 AUXILIARY OV1 PKP 200 AUXILIARY OV2 PKP 201 AUXILIARY OV3 PKP 202 NEG SEQ OV1 PKP 203 NEG SEQ OV2 PKP 204 NEG SEQ OV3 PKP 205 OR3 206 OR3 207 OR3 208 VO_012_59NH_PKP 209 VO_014_27X_PKP 210 VO_015_59X_PKP 211 VO_016_V2_OV_PKP 212 OR6 inOR1 inOR2 inOR3 239 outOR1 VO_001_GEN_THERMAL_ALARM 240 inOR1 inOR2 inOR3 outOR1 inOR1 inOR2 inOR3 outOR1 inOR1 inOR2 inOR3 out...

Page 178: ...59X_PKP 215 VO_016_V2_OV_PKP 216 VO_046_59P_PKP 217 OR3 298 FREQ RATE1 PKP 299 FREQ RATE2 PKP 300 FREQ RATE3 PKP 301 VO_052_81DF DT PKP 302 OR3 303 VO_052_81DF DT PKP 304 OR3 342 VOLTS Hz1 PKP 343 VOLTS Hz2 PKP 344 VOLTS Hz3 PKP 345 inOR1 inOR2 inOR1 inOR3 outOR1 inOR2 inOR3 outOR1 VO_036_VOLTS_HERTZ_PKP 350 VO_045_27P_PKP 352 VO_014_27X_PKP 353 OR 354 VO_038_UNDERVOLTAGE_PKP 355 OR5 356 VO_037_59...

Page 179: ...KP 218 VO_017_ALL_VOLTAGE_PKP 219 VO_056_ALL_FREQUENCY_PKP 220 GENERAL PICKUP DIRECTIONAL POWER VO_025_DIRECTIONAL_POWER_PKP 277 DIR PWR2 STG PKP 278 DIR PWR3 STG PKP 279 OR3 280 POWER VO_026_POWER_PKP 282 VO_026_POWER_PKP 283 DIR PWR1 STG PKP 295 inOR1 inOR2 inOR3 outOR1 OR4 380 inOR1 inOR2 inOR3 inOR4 outOR1 VO_025_DIRECTIONAL_POWER_PKP 443 ...

Page 180: ..._TRIP 51 VO_068_50G_TRIP 52 PH TOC1 HIGH OP 103 PH TOC2 HIGH OP 104 PH TOC3 HIGH OP 105 PH IOC1 HIGH OP 106 PH IOC2 HIGH OP 107 PH IOC3 HIGH OP 108 NEUTRAL IOC1 OP 112 NEUTRAL IOC2 OP 113 NEUTRAL IOC3 OP 114 NEUTRAL TOC1 OP 115 NEUTRAL TOC3 OP 116 NEUTRAL TOC2 OP 117 GROUND IOC1 OP 118 GROUND IOC2 OP 119 GROUND IOC3 OP 120 GROUND TOC1 OP 121 GROUND TOC2 OP 122 GROUND TOC3 OP 123 VO_019_PHASE_OVERC...

Page 181: ...TRIP FOR ENHANCED MODELS ONLY NEGATIVE SEQUENCE OVERCURRENT TRIP NEG SEQ1 IOC OP 388 NEG SEQ2 IOC OP 389 NEG SEQ3 IOC OP 390 OR3 391 VO_041_50 1_TRIP 392 GEN UNBAL1 OP 393 GEN UNBAL2 OP 394 GEN UNBAL3 OP 395 OR3 396 VO_042_GEN_UNBALANCE_TRIP 397 OR3 398 VO_061_51 2_TRIP 399 VO_041_50 1_TRIP 400 VO_042_GEN_UNBALANCE_TRIP 401 GENERATOR THERMAL MODEL TRIP OR3 inOR1 inOR2 inOR3 403 outOR1 THERMAL1 49S...

Page 182: ...LIARY OV3 OP 141 AUXILIARY UV1 OP 142 AUXILIARY UV2 OP 143 AUXILIARY UV3 OP 144 VO_020_ALL_OVERCURRENT_TRIP 225 VO_019_PHASE_OVERCURRENT_TRIP 226 VO_066_NEUTRAL_OVERCURRENT_TRIP 227 VO_069_GROUND_OVERCURRENT_TRIP 228 VO_072_SENSITIVE_GROUND_TRIP 229 OR3 230 NEG SEQ OV1 OP 231 NEG SEQ OV2 OP 232 NEG SEQ OV3 OP 233 VO_021_V2_OV_TRIP 234 OR6 241 inOR1 inOR2 inOR3 outOR1 inOR1 inOR2 inOR3 inOR4 inOR5 ...

Page 183: ... 306 FREQ RATE1 OP 307 FREQ RATE2 OP 308 FREQ RATE3 OP 309 VO_060_81DF DT TRIP 310 VO_060_81DF DT TRIP 311 inOR1 inOR2 inOR3 outOR1 inOR1 inOR2 inOR3 outOR1 inOR1 inOR2 inOR3 outOR1 POWER FACTOR LIMITING LAG OR3 376 PF1 LAG OP 377 PF2 LAG OP 378 PF3 LAG OP 379 inOR1 inOR2 inOR3 outOR1 VO_086_OVERVOLTAGE_TRIP 422 OR5 423 VO_047_59G_TRIP 424 OR3 425 VO_063_VOLTS_HERTZ_TRIP 426 VO_084_UNDERVOLTAGE_TR...

Page 184: ...TRIP FOR ENHANCED MODELS ONLY LOSS OF MAINS OR3 466 inOR1 inOR2 inOR3 outOR1 LOSS OF MAINS1 OP 467 LOSS OF MAINS2 OP 468 LOSS OF MAINS3 OP 469 VO_091_LOSS_OF_MAINS_TRIP 470 OR5 InOR1 InOR2 InOR3 InOR4 InOR5 OutOR1 471 VO_091_LOSS_OF_MAINS_TRIP 472 GENERAL TRIP LEDS MANAGEMENT LATCHED LEDS BY PLC LATCHED LEDS SR S R 477 VO_074_59P_TRIP 478 LED 1 479 NOT 480 VO_100_LED_59P_TRIP 481 SR 482 LED 1 483 ...

Page 185: ...GEK 113328A G650 Generator Protection Control System A 11 APPENDIX A A 1 FACTORY DEFAULT LOGIC A ...

Page 186: ...A 12 G650 Generator Protection Control System GEK 113328A A 1 FACTORY DEFAULT LOGIC APPENDIXA A ...

Page 187: ...VALUE 1st octec of IP address IP Address Oct1 0 N A 0 255 2nd octec of IP address IP Address Oct2 0 N A 0 255 3rd octec of IP address IP Address Oct3 0 N A 0 255 4th octec of IP address IP Address Oct4 0 N A 0 255 1st octec of Netmask Netmask Oct1 0 N A 0 255 2nd octec of Netmask Netmask Oct2 0 N A 0 255 3rd octec of Netmask Netmask Oct3 0 N A 0 255 4th octec of Netmask Netmask Oct4 0 N A 0 255 1s...

Page 188: ...ctect of IP address of DNP master 3 IP Addr Client3 Oct3 0 N A 0 255 4th Octect of IP address of DNP master 3 IP Addr Client3 Oct4 0 N A 0 255 1st Octect of IP address of DNP master 4 IP Addr Client4 Oct1 0 N A 0 255 2nd Octect of IP address of DNP master 4 IP Addr Client4 Oct2 0 N A 0 255 3nd Octect of IP address of DNP master 4 IP Addr Client4 Oct3 0 N A 0 255 4th Octect of IP address of DNP mas...

Page 189: ...ck 1 CTL EVENTS 1 16 N A See DNP note2 Size customization and change of DNP Binary Inputs point list Binary Input Block 2 CTL EVENTS 17 32 N A See DNP note2 Size customization and change of DNP Binary Inputs point list Binary Input Block 3 CTL EVENTS 33 48 N A See DNP note2 Size customization and change of DNP Binary Inputs point list Binary Input Block 4 CTL EVENTS 49 64 N A See DNP note2 Size cu...

Page 190: ...255 N A 0 65535 Number of seconds for instantaneous metering Cyclic Meter Period 0 1 s 0 3600 Not implemented Synchronization Event 0 N A 0 3600 IEC 870 5 104 NOTES Note 1 Cyclic Meter Period 0 value means no spontaneous metering PRODUCT SETUP COMMUNICATION SETTINGS SNTP SETTING DESCRIPTION NAME DEFAULT VALUE STEP RANGE USER VALUE Function permission Function DISABLED N A DISABLED ENABLED Port use...

Page 191: ...equence impedance angle Zero Seq Angle 75 1 Deg 25 90 Line length Line Length 100 0 0 1 0 0 2000 0 Display fault on HMI Show Fault On HMI DISABLED N A DISABLED ENABLED Snapshot Event generation Snapshot Events ENABLED N A DISABLED ENABLED SETPOINT PRODUCT SETUP OSCILLOGRAPHY SETTING DESCRIPTION NAME DEFAULT VALUE STEP RANGE USER VALUE Function Permission Function ENABLED N A DISABLED ENABLED Prefa...

Page 192: ...nection WYE N A WYE DELTA Rated voltage Nominal Voltage 100 0 0 1 1 0 500 0 Rated Frequency Nominal Frequency 50 Hz Hz 50 60 Phase rotation Phase Rotation ABC N A ABC ACB Frequency reference Frequency Reference VI N A VI VII VIII Auxiliary Voltage Auxiliary Voltage VX N A VX VN VG Snapshot Event generation Snapshot Events DISABLED N A DISABLED ENABLED Frequency Tracking Freq Tracking DISABLED N A ...

Page 193: ...switchgear 2 Snapshot Events SWGR 2 DISABLED N A DISABLED ENABLED Snapshot Event generation for switchgear 3 Snapshot Events SWGR 3 DISABLED N A DISABLED ENABLED Snapshot Event generation for switchgear 4 Snapshot Events SWGR 4 DISABLED N A DISABLED ENABLED Snapshot Event generation for switchgear 5 Snapshot Events SWGR 5 DISABLED N A DISABLED ENABLED Snapshot Event generation for switchgear 6 Sna...

Page 194: ...PHASE IOC HIGH 2 PHASE IOC HIGH 3 SETTING DESCRIPTION NAME DEFAULT VALUE STEP RANGE USER VALUE Function permission Function DISABLED N A DISABLED ENABLED Input type Input PHASOR DFT N A PHASOR RMS Pickup level Pickup Level 30 00 0 01 A 0 05 160 00 Trip time Trip Delay 0 00 0 01 s 0 00 900 00 Reset time Reset Delay 0 00 0 01 s 0 00 900 00 Snapshot event generation Snapshot Events ENABLED N A DISABL...

Page 195: ...tion Snapshot Events ENABLED N A DISABLED ENABLED SETPOINT PROTECTION ELEMENTS NEUTRAL CURRENT NEUTRAL DIRECTIONAL NEUTRAL DIRECTIONAL 1 NEUTRAL DIRECTIONAL 2 NEUTRAL DIRECTIONAL 3 SETTING DESCRIPTION NAME DEFAULT VALUE STEP RANGE USER VALUE Function permission Function DISABLED N A DISABLED ENABLED Maximum Torque Angle MTA 45 1 Deg 90 90 Operation Direction Direction FORWARD N A FORWARD REVERSE P...

Page 196: ...tion voltage threshold Pol V Threshold 10 1 V 0 500 Snapshot event generation Snapshot Events ENABLED N A DISABLED ENABLED SETPOINT PROTECTION ELEMENTS GROUND CURRENT RESTRICTED GROUND FAULT ENHANCED MODELS ONLY RESTRICTED GND FAULT 1 RESTRICTED GND FAULT 2 RESTRICTED GND FAULT 3 SETTING DESCRIPTION NAME DEFAULT VALUE STEP RANGE USER VALUE Function permission Function DISABLED N A DISABLED ENABLED...

Page 197: ...EGATIVE SEQUENCE CURRENT NEGATIVE SEQUENCE IOC NEGATIVE SEQUENCE IOC 1 NEGATIVE SEQUENCE IOC 2 NEGATIVE SEQUENCE IOC 3 SETTING DESCRIPTION NAME DEFAULT VALUE STEP RANGE USER VALUE Function name Function DISABLED N A DISABLED ENABLED Pickup level Pickup Level 30 00 0 01 A 0 05 160 00 Trip delay time Trip Delay 0 00 0 01 s 0 00 900 00 Reset delay time Reset Delay 0 00 0 01 s 0 00 900 00 Snapshot eve...

Page 198: ... ENABLED Pickup Level Pickup Level 10 1 V 3 500 Trip time Trip Delay 10 00 0 01 s 0 00 900 00 Reset time Reset Delay 0 00 0 01 s 0 00 900 00 Operation logic Logic ANY PHASE N A ANY PHASE TWO PHASES ALL PHASES Snapshot Event generation Snapshot Events ENABLED N A DISABLED ENABLED SETPOINT PROTECTION ELEMENTS VOLTAGE ELEMENTS NEUTRAL OV HIGH NEUTRAL OV HIGH 1 NEUTRAL OV HIGH 2 NEUTRAL OV HIGH 3 SETT...

Page 199: ... DISABLED ENABLED SETPOINT PROTECTION ELEMENTS VOLTAGE ELEMENTS VOLTS HERTZ ENHANCED MODELS ONLY VOLTS HERTZ 1 VOLTS HERTZ 2 VOLTS HERTZ 3 SETTING DESCRIPTION NAME DEFAULT VALUE STEP RANGE USER VALUE Function permission Function DISABLED N A DISABLED ENABLED V Hz Source for element calculations V Hz Source PHASES N A PHASES AUX VOLTAGE V Hz Minimum operating Voltage V Hz Minimum Voltage 40 00 0 01...

Page 200: ...unction DISABLED N A DISABLED ENABLED Pickup level for PF Lead Stage1 PF Lead Stg1 Level 0 99 0 01 0 05 0 99 Pickup level for PF Lag Stage1 PF Lag Stg1 Level 0 80 0 01 0 05 0 99 Trip time for PF Stage1 PF Stg1 Trip Delay 1 0 0 1 s 0 2 300 0 Pickup level for PF Lead Stage2 PF Lead Stg2 Level 0 99 0 01 0 05 0 99 Pickup level for PF Lag Stage2 PF Lag Stg2 Level 0 75 0 01 0 05 0 99 Trip time for PF St...

Page 201: ...R VALUE Function permission Function DISABLED N A DISABLED ENABLED Dead bus voltage level Dead Bus Level 10 00 0 01 V 0 00 500 00 Live bus voltage level Live Bus Level 50 00 0 01 V 0 00 500 00 Dead line voltage level Dead Line Level 10 00 0 01 V 0 00 500 00 Live line voltage level Live Line Level 50 00 0 01 V 0 00 500 00 Voltage Difference Max Volt Difference 10 00 0 01 V 2 00 500 00 Angle Differe...

Page 202: ...apshot Events ENABLED N A DISABLED ENABLED SETPOINT CONTROL ELEMENTS FREQUENCY RATE OF CHANGE FREQUENCY RATE OF CHANGE 1 FREQUENCY RATE OF CHANGE 2 FREQUENCY RATE OF CHANGE 3 SETTING DESCRIPTION NAME DEFAULT VALUE STEP RANGE USER VALUE Function Permission Function DISABLED N A DISABLED ENABLED Direction of the frequency change Freq Rate Trend INCREASING N A INCREASING DECREASING BI DIRECTIONAL Ope...

Page 203: ...ius 8 00 0 01 Ohm 0 10 300 00 UV Supervision for stage 1 Stage 1 UV Supv DISABLED N A DISABLED ENABLED Trip time for Stage 1 Stage 1 Trip Delay 0 05 0 01 s 0 00 65 54 Center point in Ohms sec for Stage 2 Stage 2 Center 10 00 0 01 Ohm 0 10 300 00 Radius value in Ohms sec for Stage 2 Stage 2 Radius 8 00 0 01 Ohm 0 10 300 00 UV Supervision for stage 2 Stage 2 UV Supv DISABLED N A DISABLED ENABLED Tri...

Page 204: ...DESCRIPTION NAME DEFAULT VALUE STEP RANGE USER VALUE Function Permission Function DISABLED N A DISABLED ENABLED Arming mode for Accidental Energization Accdnt Enrg Mode UV AND OFF LINE N A UV AND OFF LINE UV OR OFF LINE Overcurrent Level to operate Overcurrent pickup 1 50 0 01 A 0 00 160 00 Arming undervoltage value Ph Undervoltage pickup 40 00 0 01 V 0 00 500 00 Snapshot Event generation Snapshot...

Page 205: ... 1 V 10 230 Debounce time for Group A Debounce Time A_X 15 1 ms 1 50 Debounce time for Group B Debounce Time B_X 15 1 ms 1 50 Debounce time for Group C Debounce Time C_X 15 1 ms 1 50 Debounce time for Group D Debounce Time D_X 15 1 ms 1 50 Input type Input Type_X_CCY CCY POSITIVE N A POSITIVE EDGE NEGATIVE EDGE POSITIVE NEGATIVE Input signal time delay Delay Input Time_X_CCY CCY 0 1 ms 0 60000 Out...

Page 206: ...UT Mixed 2 8 INP 8 OUT SUPV Supervision 4 32 INP 32 digital inputs 5 16 INP 8 ANA 16 digital inputs 8 analog inputs CCY Is the name used for inputs in I O boards Mixed 16 digital inputs CC1 CC16 Supervision 8 digital inputs CC1 CC8 32 INP 32 digital inputs CC1 CC32 0Z Is the name used for the different outputs in I O boards 8 outputs available for any of the two types of board 01 08 LIST OF TIME O...

Page 207: ... VO_046_59P_PKP VO_045_27P_PKP CONT OP OPER_F_03 CONT_OP_F_03_50G _PKP VO_048_50G_PKP CONT OP OPER_F_04 CONT_OP_F_04_51G _PKP VO_049_51G_PKP CONT OP OPER_F_05 CONT_OP_F_05_50P _PKP VO_051_50PH_PKP CONT OP OPER_F_06 CONT_OP_F_06_51P _PKP VO_053_51P_PKP CONT OP OPER_F_07 CONT_OP_F_07_MA NUAL_CLOSE OPERATION BIT 1 CONT OP OPER_F_08 CONT_OP_F_08_GE NERAL_TRIP OPERATION BIT 2 VO_083_GENERAL_TRIP CONT O...

Page 208: ...59P_PKP LED14 81U O PICKUP VO_054_81O_PKP VO_055_81U_PKP LED15 81R PICKUP VO_052_81DF DT PKP SETPOINT RELAY CONFIGURATION PROTECTION ELEMENTS PROTECTION ELEMENT SOURCE SIGNAL LOGIC SOURCE LOGIC LED RESET INPUT OPERATION BIT 3 CHANGE LOCAL REMOTE Not Configured CHANGE OP BLOCKED Not Configured HMI BACKLIGHT ON Not Configured HMI BACKLIGHT OFF Not Configured PH IOC1 HIGH A BLK GROUP 1 BLOCKED LVI_1_...

Page 209: ...P 3 BLOCKED LVI_4_BLOCK 50SG PH TOC1 HIGH A BLK GROUP 1 BLOCKED LVI_5_BLOCK 51PH PH TOC1 HIGH B BLK GROUP 1 BLOCKED LVI_5_BLOCK 51PH PH TOC1 HIGH C BLK GROUP 1 BLOCKED LVI_5_BLOCK 51PH PH TOC2 HIGH A BLK GROUP 2 BLOCKED LVI_5_BLOCK 51PH PH TOC2 HIGH B BLK GROUP 2 BLOCKED LVI_5_BLOCK 51PH PH TOC2 HIGH C BLK GROUP 2 BLOCKED LVI_5_BLOCK 51PH PH TOC3 HIGH A BLK GROUP 3 BLOCKED LVI_5_BLOCK 51PH PH TOC3...

Page 210: ...KED NEG SEQ OV3 BLOCK GROUP 3 BLOCKED NEUTRAL DIR1 BLK INP GROUP 1 BLOCKED NEUTRAL DIR2 BLK INP GROUP 2 BLOCKED NEUTRAL DIR3 BLK INP GROUP 3 BLOCKED GROUND DIR1 BLK INP GROUP 1 BLOCKED LVI_10_BLOCK 67G CONT IP_F_CC8 67G BLOCK CC8 GROUND DIR2 BLK INP GROUP 2 BLOCKED LVI_10_BLOCK 67G CONT IP_F_CC8 67G BLOCK CC8 GROUND DIR3 BLK INP GROUP 3 BLOCKED LVI_10_BLOCK 67G CONT IP_F_CC8 67G BLOCK CC8 NEUTRAL ...

Page 211: ...OCK Not Configured PH TOC1 LOW A BLK GROUP 1 BLOCKED LVI_6_BLOCK 51PL PH TOC1 LOW B BLK GROUP 1 BLOCKED LVI_6_BLOCK 51PL PH TOC1 LOW C BLK GROUP 1 BLOCKED LVI_6_BLOCK 51PL PH TOC2 LOW A BLK GROUP 2 BLOCKED LVI_6_BLOCK 51PL PH TOC2 LOW B BLK GROUP 2 BLOCKED LVI_6_BLOCK 51PL PH TOC2 LOW C BLK GROUP 2 BLOCKED LVI_6_BLOCK 51PL PH TOC3 LOW A BLK GROUP 3 BLOCKED LVI_6_BLOCK 51PL PH TOC3 LOW B BLK GROUP ...

Page 212: ...OCKED THERMAL2 49S BLOCK GROUP 2 BLOCKED THERMAL3 49S BLOCK GROUP 3 BLOCKED POWER FACTOR1 BLOCK GROUP 1 BLOCKED POWER FACTOR2 BLOCK GROUP 2 BLOCKED POWER FACTOR3 BLOCK GROUP 3 BLOCKED ACCDNT ENRG1 BLOCK GROUP 1 BLOCKED ACCDNT ENRG2 BLOCK GROUP 2 BLOCKED ACCDNT ENRG3 BLOCK GROUP 3 BLOCKED GND OV1 BLK GROUP 1 BLOCKED GND OV2 BLK GROUP 2 BLOCKED GND OV3 BLK GROUP 3 BLOCKED THERMAL1 49S RST Not Config...

Page 213: ...P DIG_CHANNEL 7 81O81U TRIP VO_081_81U_TRIP VO_080_81O_TRIP DIG_CHANNEL 8 81DFDT TRIP VO_060_81DF DT TRIP DIG_CHANNEL 9 PICKUP VO_085_GENERAL_PKP DIG_CHANNEL 10 50 51P PICKUP VO_007_PHASE_OVERCURRENT_PKP DIG_CHANNEL 11 50 51G PICKUP VO_009_GROUND_OVERCURRENT_P KP DIG_CHANNEL 12 50_2 51_2 PKP VO_033_50 2_PKP VO_006_51 2_PKP DIG_CHANNEL 13 27 PICKUP VO_045_27P_PKP DIG_CHANNEL 14 59 PICKUP VO_046_59P...

Page 214: ...LL Operation5 BRK COUNTERS RESET INTERLOCK LOGIC Not configured FINAL STATES AND LOGIC Not configured FRONT KEY Not configured INPUT Not configured VIRTUAL OUTPUT Not configured TIMEOUT 500 CHANNELS ALL Operation6 ENERGY RESET INTERLOCK LOGIC Not configured FINAL STATES AND LOGIC Not configured FRONT KEY Not configured INPUT Not configured VIRTUAL OUTPUT Not configured TIMEOUT 500 CHANNELS ALL Ope...

Page 215: ...ATES AND LOGIC Not configured FRONT KEY Not configured INPUT Not configured VIRTUAL OUTPUT Not configured TIMEOUT Not configured CHANNELS Not configured SETPOINT RELAY CONFIGURATION EVENTS EVENT NAME SOURCE SIGNAL LOGIC SOURCE LOGIC EV1 Not Configured EV2 Not Configured EV128 Not Configured SETPOINT RELAY CONFIGURATION SWITCHGEAR SWITCHGEAR SETTING VALUE SOURCE SIGNAL LOGIC SOURCE LOGIC SWITCHGEAR...

Page 216: ...ROR 11 TEXT Not Configured ALARM Not Configured OPENING INIT Not Configured CLOSING INIT Not Configured SWITCHGEAR 16 CONTACTS Not Configured OPENING TIME Not Configured CLOSING TIME Not Configured CONTACT A SOURCE Not Configured CONTACT B SOURCE Not Configured OPEN TEXT Not Configured ALARM Not Configured CLOSED TEXT Not Configured ALARM Not Configured ERROR 00 TEXT Not Configured ALARM Not Confi...

Page 217: ... is defective and it is returned with all transportation charges prepaid to an authorized service center or the factory Repairs or replacement under warranty will be made without charge Warranty shall not apply to any relay which has been subject to misuse negligence accident incorrect installation or use not in accordance with instructions nor any unit that has been altered outside a GE Multilin ...

Page 218: ...C 2 G650 Generator Protection Control System GEK 113328A C 1 GE MULTILIN WARRANTY APPENDIXC C ...

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