GE Multilin GEK-113328A Instruction Manual
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GE Multilin GEK-113328A Instruction Manual

GE Multilin GEK-113328A Instruction Manual

Generator protection & control system
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GE Multilin
215 Anderson Avenue
L6E 1B3 Markham, ON -CANADA
T (905) 294 6222 F (905) 294 8512
Internet: www.GEMultilin.com
GE Consumer & Industrial
Multilin
G650
Generator Protection & Control
System
Instruction manual
GEK-113328A
Firmware version: 3.74
EnerVista 650 Setup version: 3.76
Copyright © 2008 GE Multilin
GE Multilin
Avda. Pinoa, 10
48170 Zamudio SPAIN
T +34 94 485 88 00 F +34 94 485 88 45
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  • Page 1 G650 Generator Protection & Control System Instruction manual GEK-113328A Firmware version: 3.74 EnerVista 650 Setup version: 3.76 Copyright © 2008 GE Multilin GE Multilin GE Multilin Avda. Pinoa, 10 215 Anderson Avenue 48170 Zamudio SPAIN L6E 1B3 Markham, ON -CANADA...

  • Page 3: Table Of Contents

    TABLE OF CONTENTS 1. GETTING STARTED 1.1 IMPORTANT PROCEDURES 1.1.1 CAUTIONS AND WARNINGS ................1-1 1.1.2 INSPECTION CHECKLIST ................1-4 1.1.3 SAFETY INSTRUCTIONS ................. 1-6 1.2 OVERVIEW 1.2.1 INTRODUCTION TO 650 FAMILY OF RELAYS ..........1-7 1.2.2 HARDWARE ARCHITECTURE ................. 1-7 1.2.3 SOFTWARE ARCHITECTURE................
  • Page 4 TABLE OF CONTENTS 3.1.14 HELP MENU OVERVIEW ................3-30 3.2 HUMAN MACHINE INTERFACE (HMI) 3.2.1 DISPLAY......................3-31 3.2.2 FRONT LED INDICATORS ................3-32 3.2.3 PUSHBUTTONS....................3-32 3.2.4 FRONT PORT AND COVER SEALING SYSTEM..........3-33 3.2.5 TEXT MENUS....................3-34 3.2.6 GRAPHIC DISPLAY ..................3-52 3.3 WEB SERVER 3.3.1 HOME .......................3-61 3.3.2 SNAPSHOT EVENTS..................3-62...
  • Page 5 8. G650TROUBLESHOOTING 8.1 SYMPTOMS AND RECOMMENDED ACTIONS GUIDE A. FACTORY DEFAULT LOGIC A.1 FACTORY DEFAULT LOGIC B. FACTORY DEFAULT B.1 FACTORY DEFAULT SETTINGS CONFIGURATION B.2 FACTORY DEFAULT CONFIGURATION C. MISCELLANEOUS C.1 GE MULTILIN WARRANTY GEK-113328 G650 Generator Protection & Control System...
  • Page 6 TABLE OF CONTENTS G650 Generator Protection & Control System GEK-113328...

  • Page 7: Getting Started

    1 GETTING STARTED 1.1 IMPORTANT PROCEDURES 1 GETTING STARTED 1.1IMPORTANT PROCEDURES 1.1.1 CAUTIONS AND WARNINGS To help ensure years of trouble free operation, please read through the following chapter for information to 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.
  • Page 8 Check that the relay is fully operative. Figure 1–2: MODULE WITHDRAWAL/INSERTION GE Multilin will not be responsible for any damage of the relay, connected equipment or personnel whenever these safety rules are not followed.
  • Page 9 AC Input Terminals Figure 1–3: REAR VIEW OF G650 UNIT will not be responsible for any damage of the relay, connected equipment or personnel GE Multilin whenever these safety rules are not followed. GEK-113328A G650 Generator Protection & Control System...

  • Page 10: Inspection Checklist

    1.1 IMPORTANT PROCEDURES 1 GETTING STARTED 1.1.2 INSPECTION CHECKLIST Unwrap the relay and inspect 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: •...
  • Page 11 1 GETTING STARTED 1.1 IMPORTANT PROCEDURES For product information, instruction manual updates, and the latest software updates, please visit the GE Multilin Home Page www.geindustrial.com/multilin. Note: If there is any physical damage detected on the relay, or any of the contents listed are missing, please...

  • Page 12: Safety Instructions

    GE Multilin will not be responsible for any damage to the relay or connected equipment whenever this elemental safety rule is not followed.

  • Page 13: Overview

    1 GETTING STARTED 1.2 OVERVIEW 1.2OVERVIEW 1.2.1 INTRODUCTION TO 650 FAMILY OF RELAYS Historically, substation protection, control and metering functions were performed with electromechanical equipment. This first generation of equipment was gradually replaced by analog electronic equipment (called static devices), most of which emulated the single-function approach of their electromechanical precursors.
  • Page 14 1.2 OVERVIEW 1 GETTING STARTED Figure 1–6: 650 CONCEPT BLOCK DIAGRAM Contact Inputs/Outputs are signals associated to the physical input/output contacts in the relay CT and VT inputs are signals coming from the inputs of current and voltage transformers, used for monitoring the power system signals.

  • Page 15: Software Architecture

    1 GETTING STARTED 1.2 OVERVIEW 1.2.3 SOFTWARE ARCHITECTURE The firmware (software embedded in the relay) has been designed using object oriented programming techniques (OOP). These techniques are based on the use of objects and classes, and provide the software architecture with the same characteristics as the hardware architecture, i.e., modularity, scalability and flexibility.
  • Page 16 1.2 OVERVIEW 1 GETTING STARTED Figure 1–7: COMMUNICATIONS ARCHITECTURE (B6816F1) 1-10 G650 Generator Protection & Control System GEK-113328A...

  • Page 17: Enervista 650 Setup Software

    1.3.2 INSTALLATION After ensuring the minimum requirements for using EnerVista 650 Setup are met (see previous section), use the following procedure to install the EnerVista 650 Setup from the GE EnerVista CD. Insert the GE EnerVista CD into your CD-ROM drive.
  • Page 18 1.3 ENERVISTA 650 SETUP SOFTWARE 1 GETTING STARTED In the EnerVista Launch Pad window, click the Add Product button and select the “G650 Generator Protection & Control System” relay from the Install Software window as shown below. Select the “Web” option to ensure the most recent software release, or select “CD”...
  • Page 19 1 GETTING STARTED 1.3 ENERVISTA 650 SETUP SOFTWARE EnerVista Launchpad will obtain the installation program from the Web or CD. Once the download is complete, double- click the installation program to install the EnerVista 650 Setup software. Select the complete path, including the new directory name, where the EnerVista 650 Setup will be installed. Click on Next to begin the installation.
  • Page 20 1.3 ENERVISTA 650 SETUP SOFTWARE 1 GETTING STARTED 12. The default program group where 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.

  • Page 21: Connecting Enervista 650 Setup With G650

    Before starting, verify that the Ethernet network cable is properly connected to the Ethernet port on the back of the relay. Install and start the latest version of the EnerVista 650 Setup software (available from the GE EnerVista CD or online from http://www.GEindustrial.com/multilin...
  • Page 22 Before starting, verify that the RS232 serial cable is properly connected to the RS232 port on the front panel of the relay. Install and start the latest version of the EnerVista 650 Setup software (available from the GE EnerVista CD or online from http://www.GEindustrial.com/multilin...

  • Page 23: Hardware

    DB-9 or DB-25 female end is connected to the PC COM1 or COM2 port as described in Figure 1–16:. To communicate through the G650 rear RS485 port from a PC RS232 port, the GE Multilin RS232/RS485 converter box is required. This device (catalog number F485) connects to the computer using a “straight-through” serial cable. A shielded twisted-pair (20, 22 or 24 AWG according to American standards;...

  • Page 24: Faceplate Display

    1.4 650 HARDWARE 1 GETTING STARTED without exceeding driver capability. For larger systems, additional serial channels must be added. It is also possible to use commercially available repeaters to increase the number of relays on a single channel to more than 32. Do not use other connection configurations different to the recommended.
  • Page 25 View the event recorder and oscillography or fault report for correct operation of inputs, outputs and elements. If it is concluded that the relay or one of its modules is of concern, contact GE Multilin or one of its representative for prompt service.
  • Page 26 1.4 650 HARDWARE 1 GETTING STARTED 1-20 G650 Generator Protection & Control System GEK-113328A...

  • Page 27: Product Description

    2 PRODUCT DESCRIPTION 2.1 OVERVIEW 2 PRODUCT DESCRIPTION 2.1OVERVIEW 2.1.1 G650 OVERVIEW The G650 is a machine generator protection and control device. It may be used to protect and control reciprocating machines, as well as to operate as a packaged generator sets mains failure detector. Generally speaking the G650 provides distributed generation management capabilities.
  • Page 28 2.1 OVERVIEW 2 PRODUCT DESCRIPTION Figure 2–2: G650 BLOCK DIAGRAM FOR ENHANCED FUNCTIONALITY MODELS G650 Generator Protection & Control System GEK-113328A...

  • Page 29: Summary

    2 PRODUCT DESCRIPTION 2.2 SUMMARY 2.2SUMMARY 2.2.1 ANSI DEVICE NUMBERS AND FUNCTIONS DEVICE NUMBER FUNCTION Volt/Hertz (only enhanced model) Synchronism Check Phase Undervoltage Auxiliary Undervoltage 32DIR Directional Power Loss of Excitation Generator Unbalance Negative Sequence Overvoltage Generator thermal model 50/27 Inadvertent Generator Energization 50-2/51-2 Negative Sequence IOC/TOC...

  • Page 30: Other Device Functions

    2.2 SUMMARY 2 PRODUCT DESCRIPTION 2.2.2 OTHER DEVICE FUNCTIONS INPUTS/OUTPUTS METERING COMMUNICATIONS 9 Analog Inputs: 5 current inputs (3 for phases, Metering Current for phases, ground and Front RS232 port, Two rear RS485/ 1 for ground, 1 for sensitive ground), 4 voltage sensitive ground inputs fibre optic ports, 10/100 TX and 100 FX inputs (3 for phases, 1 for busbar or auxiliary...

  • Page 31: Ordering Code

    2 PRODUCT DESCRIPTION 2.3 ORDERING CODE 2.3ORDERING CODE G650 units are supplied as ½ 19” rack, 6 units high, containing the following modules: power supply, CPU, I/O modules, communication modules. The required information to completely define an G650 model is shown on Table 2–1: Table 2–1: ORDERING CODE DESCRIPTION Basic Display (4x20 characters) and basic protection functionality...
  • Page 32 2.3 ORDERING CODE 2 PRODUCT DESCRIPTION F1G5 is a valid selection and F5G1 is and invalid selection. 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. G650 Generator Protection & Control System GEK-113328A...

  • Page 33: Technical Specifications

    2 PRODUCT DESCRIPTION 2.4 TECHNICAL SPECIFICATIONS 2.4 TECHNICAL SPECIFICATIONS NOTE: TECHNICAL SPECIFICATIONS ARE SUBJECT TO CHANGE WITHOUT NOTICE 2.4.1 PROTECTION ELEMENTS Phase and ground units use as operation magnitude the current value received by the unit in current inputs, while the neutral unit uses the calculated current value from the three phase currents.
  • Page 34 2.4 TECHNICAL SPECIFICATIONS 2 PRODUCT DESCRIPTION 2.4.1.2 GROUND TIME OVERCURRENT (51G) 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 Values at nominal frequency: Level Accuracy...
  • Page 35 2 PRODUCT DESCRIPTION 2.4 TECHNICAL SPECIFICATIONS 2.4.1.4 SENSITIVE GROUND TIME OVERCURRENT (51SG) 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 Values at nominal frequency:...
  • Page 36 2.4 TECHNICAL SPECIFICATIONS 2 PRODUCT DESCRIPTION 2.4.1.6 NEUTRAL INSTANTANEOUS OVERCURRENT (50N) 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 Values at nominal frequency: Level Accuracy ±0.5% of the reading ±...
  • Page 37 2 PRODUCT DESCRIPTION 2.4 TECHNICAL SPECIFICATIONS Curve Shapes IEEE extremely / very / moderately inverse IEC A/B/C/long-time inverse/short time inverse curve IAC extremely / very / moderately inverse ANSI extremely / very / normally / moderately inverse Definite time Rectifier curve FlexCurve™...
  • Page 38 2.4 TECHNICAL SPECIFICATIONS 2 PRODUCT DESCRIPTION 2.4.1.10 GENERATOR UNBALANCE (46) rated full load Gen. nominal current 0.00 to 10.00 A in steps of 0.01 A ( current of the machine Stages t with linear reset and definite time)) Pickup level 0.00 to 100.00% in steps of 0.01 Dropout level 97% to 98 % of the pickup level...
  • Page 39 2 PRODUCT DESCRIPTION 2.4 TECHNICAL SPECIFICATIONS 2.4.1.13 GENERATOR THERMAL MODEL (49S) Current Input Fundamental Phasor (without harmonics) Rated current For connection to 1 or 5 A CTs. Pickup level 0.05 to 160.0 A in steps of 0.01 A Dropout level 97% to 98% of the pickup level Values at nominal frequency: Level Accuracy...
  • Page 40 2.4 TECHNICAL SPECIFICATIONS 2 PRODUCT DESCRIPTION 2.4.1.16 PHASE UNDERVOLTAGE (27P) Voltage Input Fundamental Phasor of phase-to-ground or phase-to- phase voltages (selectable by setting) Pickup level 3 to 500 in steps of 1 V Dropout level 102% to 103% of the pickup level ±1% reading ±0.1% Full Scale from 10 to 500 V at Level accuracy nominal frequency...
  • Page 41 2 PRODUCT DESCRIPTION 2.4 TECHNICAL SPECIFICATIONS 2.4.1.19 AUXILIARY OVERVOLTAGE (59X) Voltage Input Fundamental Phasor of the auxiliary voltage Pickup level 3 to 500 in steps of 1 V Dropout level 97% to 98% of the pickup level ±1% reading ±0.1% Full Scale from 10 to 500V at Level accuracy nominal frequency Trip delay...
  • Page 42 2.4 TECHNICAL SPECIFICATIONS 2 PRODUCT DESCRIPTION ±0.01 Hz of the reading Level accuracy 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.

  • Page 43: Control

    2 PRODUCT DESCRIPTION 2.4 TECHNICAL SPECIFICATIONS 2.4.1.25 POWER FACTOR LIMITING (55) Lead Pickup level 0.05 to 0.99 in steps of 0.01 Lag Pickup level 0.05 to 0.99 in steps of 0.01 Dropout level 97% to 98 % of the pickup level Level accuracy ±0.02 Stages...
  • Page 44 2.4 TECHNICAL SPECIFICATIONS 2 PRODUCT DESCRIPTION ±0.5% of the reading ± 10 mA from 0.05 to 10 A Level Accuracy ±1.5% of the reading for higher values. Timing accuracy ±3.5% of operate time or 50 ms. (whichever is greater) Snapshot Events Selectable by setting 2.4.2.4 PULSE COUNTERS Number of Pulse counters available...
  • Page 45 2 PRODUCT DESCRIPTION 2.4 TECHNICAL SPECIFICATIONS 2.4.2.6 FREQUENCY RATE OF CHANGE df/dt trend increasing, decreasing, bi-directional df/dt pickup level 0.10 to 10.00 Hz/s in steps 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 <...
  • Page 46 2.4 TECHNICAL SPECIFICATIONS 2 PRODUCT DESCRIPTION 2.4.2.7 INADVERTED GENERATOR ENERGIZATION (ACCIDENTAL ENERGIZATION) (50/27) Operating condition Overcurrent Arming condition Undervoltage and/or Machine Offline Overcurrent Pickup level 0.00 to 160.00 A in steps of 0.01 A Dropout level 97% to 98% of pickup level Level Accuracy Values at nominal frequency ±0.5% of the reading ±...
  • Page 47 2 PRODUCT DESCRIPTION 2.4 TECHNICAL SPECIFICATIONS 2.4.2.10 BREAKER SETTINGS Number of Switchgear 1 to 16 (selection of switchgear for breaker control) Maximum KI 0.00 to 9999.99 in steps of 0.01 (kA) 0.03 to 0.25 s in steps of 0.01 s t integration Time Maximum openings 0 to 9999 in steps of 1...

  • Page 48: Monitoring

    2.4 TECHNICAL SPECIFICATIONS 2 PRODUCT DESCRIPTION 2.4.2.11 BREAKER MAINTENANCE t Breaker Counters for Phases A, B, C 0.00 to 9999.99 in steps of 0.01 (kA) Breaker Openings Counter 0 to 9999 in steps of 1 Breaker Closings Counter 0 to 9999 in steps of 1 2.4.2.12 SWITCHGEAR Switchgear 1 to16 (configurable in “relay configuration”...
  • Page 49 2 PRODUCT DESCRIPTION 2.4 TECHNICAL SPECIFICATIONS Format: Text in ASCII format 2.4.3.3 SNAPSHOT EVENTS Capacity: 479 scrolling events 1 ms using an internal clock of 100 μs Time-tag Timing Accuracy: 1 ms (using the IRIG-B synchronization input) Triggers: Any element pickup, dropout or operation Digital input /output change of state By virtual inputs and control events Data Storage...

  • Page 50: User-Programmable Elements

    2.4 TECHNICAL SPECIFICATIONS 2 PRODUCT DESCRIPTION Samples 1 sec., 1, 5, 10, 15, 20, 30, 60 min. Storage Capacity Fixed, 32768 measures 2.4.4 USER-PROGRAMMABLE ELEMENTS 2.4.4.1 PLC LOGIC Programming language: The logical configuration is performed using graphical functions based on the IEC 61131-3 standard.

  • Page 51: Metering

    2 PRODUCT DESCRIPTION 2.4 TECHNICAL SPECIFICATIONS 2.4.4.4 USER-DEFINABLE DISPLAYS Number of configurable displays: 1 (one line diagram fully configurable). In graphical displays only Number of fixed displays: 6, Metering (in primary values), Snapshot events (all and new), Alarms, Inputs and outputs screen with test functionality for inputs and outputs. In graphical displays only Number of selectable displays: Logotype, metering or both in scrolling mode, can be selectable as default...

  • Page 52: Inputs

    2.4 TECHNICAL SPECIFICATIONS 2 PRODUCT DESCRIPTION 2.4.5.7 WAR-HOURS (POSITIVE AND NEGATIVE) ±1.0% of the reading Accuracy: ±0 to 2147 MVArh Range: Parameters: 3-phase only Update rate: 100 ms 2.4.5.8 POWER FACTOR Accuracy: 0.02 Parameters: 3-Phase and single phase 2.4.5.9 FREQUENCY Metering range from 30 Hz to 80 Hz Accuracy: ±30 mHz at 50 Hz...
  • Page 53 2 PRODUCT DESCRIPTION 2.4 TECHNICAL SPECIFICATIONS 2.4.6.2 AC VOLTAGE INPUTS VT Ratio 1.0 to 6000.0 in steps of 0.1 Rated Voltages 500 Vac Metering range: From 2 to 500 Vac Relay Burden: 0.05 VA at 120 Vac (50 or 60 Hz) Voltage Withstand: Continuous at 500 V to neutral 1 min/hr at 800 to neutral...

  • Page 54: Real Time Clock

    2.4 TECHNICAL SPECIFICATIONS 2 PRODUCT DESCRIPTION 2.4.6.5 IRIG-B INPUT Amplitude modulation: DC SHIFT = Demodulated input (no carrier) Input Voltage: Input Burden: 1.5 mA Input Impedance: 3.3 kOhm Minimum Input Voltage: 2.4 V ± 24 V Maximum Input Voltage: Formats: B000 (*) B001, B002 and B003 (*) (*) Signal combinations recognized in accordance with IRIG Standard 200-95 Isolation:...

  • Page 55: Control Power Supply

    2 PRODUCT DESCRIPTION 2.4 TECHNICAL SPECIFICATIONS 2.4.9 CONTROL POWER SUPPLY LOW RANGE (LO) Nominal DC Voltage: 24 to 48 V Min/Max DC Voltage 19.2 / 57.6 V Note: Low range is DC only HIGH RANGE (HI) Nominal DC Voltage: 110 to 250 V Min/Max DC Voltage 88 / 300 V Nominal AC Voltage:...
  • Page 56 2.4 TECHNICAL SPECIFICATIONS 2 PRODUCT DESCRIPTION Protocols available: ® ModBus RTU / DNP 3.0 Typical distance: 1200 m Isolation: 2 kV CAN PORT: Rear port: CAN port in models X, Y, Z for asynchronous rear ports Type: Multimode glass F.O. port with ST connectors Fiber Wave length: 1300 nm multimode 62.5/125 μm or 50/125 μm...

  • Page 57: Optic Features

    2 PRODUCT DESCRIPTION 2.4 TECHNICAL SPECIFICATIONS 2.4.11 OPTIC FEATURES Wave length: 1300nm Connector types: ST package style Fiber type: multimode 62.5/125 μm or 50/125 μm TRANSMITTER CHARACTERISTICS Parameter Min. Typ. Max. Unit Reference Output Optical Power dBm avg. Note 1 62.5/125 μm, NA = 0.275 Fiber Output Optical Power -22.5...

  • Page 58: Environmental Characteristics

    2.4 TECHNICAL SPECIFICATIONS 2 PRODUCT DESCRIPTION 2.4.12 ENVIRONMENTAL CHARACTERISTICS Operating temperature: - 10°C to + 60°C Storage temperature: - 40°C to + 80°C Humidity (non condensing): Altitude Up to 2000 m Installation category 2.4.13 PACKAGING AND WEIGHT Net weight: 5 kg Packaged: 6 kg Package dimensions:...

  • Page 59: External Connections

    2 PRODUCT DESCRIPTION 2.5 EXTERNAL CONNECTIONS 2.5EXTERNAL CONNECTIONS Figure 2–3: G650 WIRING DIAGRAM (189C4216H17R1) GEK-113328A G650 Generator Protection & Control System 2-33...
  • Page 60 2.5 EXTERNAL CONNECTIONS 2 PRODUCT DESCRIPTION SLOT F CONFIGURATION (BOARD TYPE 1) INPUTS F1 OUTPUTS F1 + CC1 FREQ PICKUP 50P BLOCK + CC2 51P BLOCK + CC3 50-2 BLOCK + CC4 50G BLOCK 27/59 PICKUP + CC5 51G BLOCK + CC6 51-2 BLOCK + CC7...

  • Page 61: Human Interfaces

    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.
  • Page 62 3.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.1.2.4 VIEWING TRIGGERED EVENTS While the interface is in either on-line or off-line mode, you can view and analyze data generated by triggered specified parameters, via one of the following: •...

  • Page 63: Main Screen

    3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 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 •...

  • Page 64: Communication Menu

    3.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.1.4 COMMUNICATION MENU To start communicating with the relay go to “Communication>Computer>Computer settings” section in the main EnerVista 650 Setup menu. Safety instructions must be followed before connecting the computer to the relay. Safety instructions are detailed in section 1.1.3.
  • Page 65 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 3.1.4.1 COMPUTER SETTINGS: Shows the communication parameters necessary in order to establish communication with the unit. Such as slave address, communication port, baud rate, parity, control type and startup mode. Baud rate, parity, data bits, stop bits and ModBus slave address for com2 (RS232 front port and second serial port in the rear communication board) are displayed in the default text logotype main screen.

  • Page 66: File Management

    3.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.1.5 FILE MANAGEMENT File management with EnerVista 650 Setup software: 3.1.5.1 OFF LINE MODE Run EnerVista 650 Setup Open a *.650 file (“File>Open” menu) Modify protection Settings and relay configuration Is it necessary to program...
  • Page 67 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE Table 3–1: TYPES OF FILES GENERATED BY ENERVISTA 650 SETUP SOFTWARE OPERATION MODE OFF-LINE: LOGIC CONFIGURATION FILES (*.PEP, *AUT, *.LIB) SETTINGS & CONFIGURATION FILE *.650 *.PEP *.AUT *.LIB Graphical edition container.
  • Page 68 3.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.1.5.2 ON LINE MODE Run EnerVista 650 Setup Connect to the relay (“Communication>Computer>ON”) Modify and send to the relay protection Settings and relay configuration Is it necessary to program additional logic? Launch the Logic Configuration tool in EnerVista...
  • Page 69 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE Table 3–2: TYPES OF FILES CREATED BY ENERVISTA 650 SETUP– ONLINE OPERATION MODE LOGIC CONFIGURATION FILES (*.PEP, *.AUT, *.LIB) SETTINGS & CONFIGURATION FILE *.650 *.PEP *.AUT *.LIB Graphical edition container.

  • Page 70: Enervista 650 Setup Menu Structure

    COMMUNICATION SECURITY VIEW HELP Instruction New (**) Product Setup Front Panel Computer Login user Traces Manual ModBus Change GE Multilin Open (**) System Setup Status Modem (*) Memory Password on the web About Protection User Save (**) Metering Troubleshooting (*)

  • Page 71: File Menu Overview

    3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 3.1.7 FILE MENU OVERVIEW Table 3–4: GENERAL OVERVIEW OF FILE MENU: FILE Create a new settings and configuration file, with the default relay New (**) settings and no configuration Open (**) Open a settings and configuration file for off-line working.
  • Page 72 3.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.1.7.1 NEW, OPEN, SAVE, SAVE AS AND CLOSE In these options, the program opens a dialog box (with default path to Files>Config program folder) where the setting and configuration files can be selected for their “off-line”...
  • Page 73 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 3.1.7.2 CONFIG FILE (*650) CONVERTER Figure 3–6: CONFIG FILE (*650) CONVERTER MENU This tool provides automatic conversion of configuration files from a firmware version to a previous or later version. Open the source *.650 file and select the version and model to be converted to.
  • Page 74 3.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.1.7.4 PRINTING OPTIONS (PRINT SETUP/PRINT PREVIEW/PRINT/PRINT TO FILE) The printing options are active only in off-line mode, in “File edition”, and not in on-line mode, connected with the relay. a) PRINT SETUP Option to configure the printing options and settings for the printing device.

  • Page 75: Setpoint Menu Overview

    3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 3.1.8 SETPOINT MENU OVERVIEW Table 3–5: GENERAL OVERVIEW OF SETPOINT MENU IN ENERVISTA 650 SETUP: SETPOINT Communications settings for all protocols and physical mediums. Product Setup ModBus user map definition, fault report, oscillography, data logger and demand settings.
  • Page 76 3.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES Serial Ports Baud rate and parity for COM1 and COM2 serial communication ports. Ethernet communication parameters for COM3 (IP Address, Netmask, Gateway IP) NOTE: The ModBus Slave address used by Ethernet ports is the one set Network (Ethernet) for COM2.EnerVista 650 Setup software allows programming two different Ethernet addresses, but the first IP has always to be set as the...
  • Page 77 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE Table 3–9: GENERAL OVERVIEW OF PROTECTION ELEMENTS MENU: PROTECTION ELEMENTS Phase Current All overcurrent grouped functions for phase current. All overcurrent grouped functions for neutral current. (Calculated from Neutral Current phases, not measured) All overcurrent grouped functions for ground current.
  • Page 78 3.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES Table 3–10: PROTECTION ELEMENTS INCLUDED PHASE CURRENT Phase TOC High Phase time overcurrent, high level (51PH) Phase TOC Low Phase time overcurrent, low level (51PL) Phase IOC High Phase instantaneous overcurrent, high level (50PH) Generator Thermal Thermal model or Thermal image unit for phases (49S)
  • Page 79 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 3.1.8.4 CONTROL ELEMENTS This option shows all the control elements available in the relay as shown in Table 3–11:. Some of the elements are grouped ones such as underfrequency, overfrequency and broken conductor. Table 3–11: GENERAL OVERVIEW OF CONTROL ELEMENTS MENU: CONTROL ELEMENTS...
  • Page 80 3.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES Board F Board located in first slot, always connected. Board located in second slot, depends on model definition. If model is Board G type G0 there is no board in second slot. Board H Board located in first slot of CIO Module (external inputs/outputs module) Board located in second slot of CIO Module (external inputs/outputs...
  • Page 81 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE The following figures show an example of the default factory configuration for G650: Figure 3–9: RELAY CONFIGURATION GEK-113328A G650 Generator Protection & Control System 3-21...
  • Page 82 3.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES Figure 3–10: HMI CONFIGURATION 3.1.8.7 LOGIC CONFIGURATION This logic configuration allows creating more complex configurations, using the graphical PLC, than using the tables from Relay Configuration. For file management detailed information go to section 3.1.5. File description: *.pep: Header for Logic project: PLC project file containing the necessary information relative to the relay model, logic...

  • Page 83: Actual Values Menu Overview

    3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 3.1.9 ACTUAL VALUES MENU OVERVIEW The menu bar in the main screen of EnerVista 650 Setup software shows the ACTUAL menu option. This option concentrates and displays all the status of protection, control elements, metering, counters information, oscillography, events, fault locator, etc.
  • Page 84 3.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES Table 3–17: ACTUAL VALUES INCLUDED IN THE PROTECTION MENU PROTECTION Protection Blocks This screen shows all the protection element blocks available. Protection elements block signals can be configured at “Setpoint>Relay Configuration >...
  • Page 85 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE Table 3–19: ACTUAL VALUES RELATED TO RECORDING FUNCTIONS IN THE RECORDS STATUS MENU: RECORD STATUS Fault Reports This menu shows the fault report status signals, as fault report trigger, fault date, fault type and location, besides the fault report number.

  • Page 86: Operations Menu Overview

    3.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.1.9.5 RECORDS The Records menu is only available in on line mode and includes the possibility to retrieve all the records available in the device. By serial or Ethernet. Table 3–22: GENERAL OVERVIEW OF RECORDS MENU: RECORDS (*) Event recorder (*)

  • Page 87: Communication Menu Overview

    3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 3.1.11 COMMUNICATION MENU OVERVIEW The communication menu includes the computer screen to start communicating with the relay, the different update procedures available in device: firmware, operative system, web server and other file storing capabilities (upload and download info files to/from relay).
  • Page 88 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.
  • Page 89 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE Thanks to the use of a double flash memory, one with the Bootcode startup program and the operative system, and a second one with the application program (firmware), a high reliability is guaranteed when updating the unit firmware, as even if the case of a communication breakdown during the firmware upgrade process, we can retry the process for an unlimited number of times.

  • Page 90: Security Menu Overview

    Table 3–27: GENERAL OVERVIEW OF HELP MENU: HELP Instructions Manual Instructions manual in the language selected in “View>Languages” menu. GE Mulitlin on the Web GE Multilin web page link. About EnerVista 650 Release version and date of EnerVista 650 Setup program. Setup 3-30 G650 Generator Protection &...

  • Page 91: Human Machine Interface (Hmi)

    3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.2 HUMAN MACHINE INTERFACE (HMI) 3.2 HUMAN MACHINE INTERFACE (HMI)T The HMI interface consists of several functional panels. The faceplate can be unscrewed to allow easy access to the removable modules. There is also a removable dust cover that fits over the display and other cover that protects the front RS232 Communications port and the commands buttons that can be sealed.

  • Page 92: Front Led Indicators

    3.2 HUMAN MACHINE INTERFACE (HMI) 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.2.2 FRONT LED INDICATORS The relay provides 16 LED indicators, 15 user programmable plus one non-configurable LED (READY) that shows if the relay is in service. Programmable LEDs are divided into groups of 5 LEDs, each of the groups having a different color. The first group of LED indicators is latched by hardware (red color ones), usually configured for trip signals.

  • Page 93: Front Port And Cover Sealing System

    3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.2 HUMAN MACHINE INTERFACE (HMI) 3.2.3.2 COMMAND PUSH BUTTON The unit incorporates a command pushbutton located at the bottom right side of the faceplate, with three options: local, remote, and off. The first option (LOCAL) allows executing operations in local mode (HMI, front RS232 port, and rear COM2 port).

  • Page 94: Text Menus

    3.2 HUMAN MACHINE INTERFACE (HMI) 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.2.5 TEXT MENUS 3.2.5.1 NAVIGATION IN TEXT MENU Text menu is available for all models, this is the main menu for visualizing actual values, metering, changing settings, etc. through the HMI.
  • Page 95 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.2 HUMAN MACHINE INTERFACE (HMI) 3.2.5.2 TEXT MENU HIERARCHY The structure of HMI text menu is similar to the EnerVista 650 Setup in the actual values and settings (view and change) menus. The main menu shows the following options: Table 3–28: GENERAL OVERVIEW OF MAIN TEXT MENU: NAME DESCRIPTION...
  • Page 96 3.2 HUMAN MACHINE INTERFACE (HMI) 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.2.5.3 ACTUAL VALUES The Actual Values menu option in HMI concentrates and displays all the status of protection, control elements, metering, counters information, oscillography, events, fault locator, etc. Table 3–29: GENERAL OVERVIEW OF ACTUAL VALUES MAIN MENU: Front Panel >...
  • Page 97 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.2 HUMAN MACHINE INTERFACE (HMI) Metering > Primary Values > Current Voltage Power Energy Demand Secondary Values > Current Voltage Power Frequency Inputs/Outputs > Contact Inputs > Board F/ Board G/ Board H/ Board J Cont.
  • Page 98 3.2 HUMAN MACHINE INTERFACE (HMI) 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.2.5.4 SNAPSHOT EVENTS To enter this menu press the shuttle key when the option Snapshot events is selected in main menu (). In this menu all the snapshot events stored can be displayed. Snapshot events are changes in the relay internal status.
  • Page 99 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.2 HUMAN MACHINE INTERFACE (HMI) 3.2.5.5 FAULT REPORT To enter this menu press the shuttle key when the option Fault report is selected in main menu (). This menu displays information about the last ten faults recorded in the relay. The Relay HMI allows two types of visualization for the fault reports stored in the Relay: 1.
  • Page 100 3.2 HUMAN MACHINE INTERFACE (HMI) 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES The format of the displayed screens is as follows: Select the Fault report menu in text menu If there is more than one fault record rotate the shuttle key and select the desired record to be displayed.
  • Page 101 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.2 HUMAN MACHINE INTERFACE (HMI) 3.2.5.6 VIEW SETTINGS To enter this menu press the shuttle key when the option “View Settings” is selected in main menu ( ). A secondary level will be displayed with different sublevels as shown on Table 3–30:. Rotating the shuttle key, (left for moving up and right for moving down) select the next level to be displayed ( ), press the shuttle key again to enter in next level and press esc key to return to previous level if desired.
  • Page 102 3.2 HUMAN MACHINE INTERFACE (HMI) 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES MAIN SETTINGS MENU FIRST LEVEL SECOND LEVEL THIRD LEVEL Neutral IOC 1 Neutral IOC 2 Neutral IOC 3 Neutral Dir > Neutral Dir 1 Neutral Dir 2 Neutral Dir 3 Ground Current >...
  • Page 103 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.2 HUMAN MACHINE INTERFACE (HMI) MAIN SETTINGS MENU FIRST LEVEL SECOND LEVEL THIRD LEVEL Phase OV > Phase OV 1 Phase OV 2 Phase OV 3 Neutral OV High > Neutral OV High 1 Neutral OV High 2 Neutral OV High 3 Neg.
  • Page 104 3.2 HUMAN MACHINE INTERFACE (HMI) 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES MAIN SETTINGS MENU FIRST LEVEL SECOND LEVEL THIRD LEVEL Autoreclose Breaker Failure VT Fuse Failure. (Enhanced models only) 3-44 G650 Generator Protection & Control System GEK-113328A...
  • Page 105 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.2 HUMAN MACHINE INTERFACE (HMI) MAIN SETTINGS MENU FIRST LEVEL SECOND LEVEL THIRD LEVEL Freq. Rate of Change > Freq. Rate of Change 1 Freq. Rate of Change 2 Freq. Rate of Change 3 Loss of Mains.
  • Page 106 3.2 HUMAN MACHINE INTERFACE (HMI) 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.2.5.7 CHANGE SETTINGS To enter this menu press the shuttle key when the option “Change Settings” is selected in main menu. A secondary level will be displayed with different sublevels as shown on Table 3–30:. Rotating the shuttle key, (left for moving up and right for moving down) select the next level to be displayed, press the shuttle key again to enter in next level and press ESC key to return to previous level if desired.
  • Page 107 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.2 HUMAN MACHINE INTERFACE (HMI) 3.2.5.8 DATE & TIME The “Date & Time” menu will show the relay date and time information in the following format: Date:Day/Month/Year Time:Hour:Minutes:Seconds To modify date and time, press the shuttle key. The relay will show the year between brackets at the top of the screen. By rotating the shuttle key, reach the desired value for the year, and press the shuttle key to select and store that value.
  • Page 108 3.2 HUMAN MACHINE INTERFACE (HMI) 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.2.5.9 COMMANDS Commands are configured using EnerVista 650 Setup, and they can be executed using the pushbuttons on the relay front. Using EnerVista 650 Setup software, the user can configure up to 24 commands with a descriptive text. When executing the operation from the relay front, the operation description text will be displayed.
  • Page 109 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.2 HUMAN MACHINE INTERFACE (HMI) 3.2.5.10 PASSWORDS G650 units incorporate independent passwords for protection and control, in order to prevent unauthorized keypad and display access to the relay. Settings Password: This password allows restricting access to settings changes in the relay protection elements. Commands Password: This password is required for executing operation commands through the keypad and display.
  • Page 110 [35c0] Cod Commands: [35c0] In order to obtain the decoded password from the encrypted codes provided by the relay, it is necessary to contact GE Multilin and provide these encrypted codes. 3-50 G650 Generator Protection & Control System...
  • Page 111 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.2 HUMAN MACHINE INTERFACE (HMI) 3.2.5.11 SELECT MAIN SCREEN The relay display offers the possibility to select the default main screen. For this purpose, the user must access the “Select Main Screen” menu through the HMI. This menu includes the following options: Logotype This option selects as main screen the relay logotype including the firmware and boot code versions, the relay model and the communication parameters for local port COM2.

  • Page 112: Graphic Display

    3.2 HUMAN MACHINE INTERFACE (HMI) 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.2.6 GRAPHIC DISPLAY 3.2.6.1 ONE-LINE DIAGRAM In models with graphic display (G650M) default main screen is the single-line diagram. This single-line diagram can be configured using EnerVista 650 Setup software by choosing the HMI menu inside Relay Configuration (Setpoint>Relay Configuration>HMI).
  • Page 113 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.2 HUMAN MACHINE INTERFACE (HMI) 3.2.6.2 METERING SCREEN The Metering screen displays relay analog measures in their primary values. Available metering values are as follows: Metering Screen. Total metering 54 Phasor Ia Primary 0.000 KA Phasor Ib Primary 0.000 KA...
  • Page 114 3.2 HUMAN MACHINE INTERFACE (HMI) 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.2.6.3 ALL EVENTS SCREEN This screen shows all events that have been produced in the relay. The top of the screen shows its name (All Events), and the relative and total number of events contained in the screen. All Events (1/479) This legend means that there are a total of 479 events stored in the relay, and that the cursor is located on event number 1.
  • Page 115 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.2 HUMAN MACHINE INTERFACE (HMI)
    The Details screen provides access to metering values, and date and time related with the event. The top of the screen displays a legend with the event text, followed by the date and time, the event status (ON or OFF), and the event index number related to the complete list of events in the relay, for example (1/479).
  • Page 116 3.2 HUMAN MACHINE INTERFACE (HMI) 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES L-R: Scroll. Rotating the shuttle key left (L) or right (R) moves among all the events contained in the all events screen, allowing a preview of the details for each of them. ...
  • Page 117 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.2 HUMAN MACHINE INTERFACE (HMI) 3.2.6.5 ALARMS PANEL Alarms panel can be viewed in all G650 models using communication software EnerVista 650 Setup, however, only models with graphic display allow access to the alarms panel from the HMI. First line shows the relative and total number of alarms existing in that screen.
  • Page 118 3.2 HUMAN MACHINE INTERFACE (HMI) 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES This option acknowledges all alarms. Alarm acknowledgement through the graphic HMI is considered as through communication port COM2, as it is considered to be Local in both cases. When an alarm has been acknowledged, a selection mark will appear to the right of its status.
  • Page 119 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.2 HUMAN MACHINE INTERFACE (HMI) IO Card F. Type: 2, # IN 8, # OUT 8 Input (ON OFF) Output 0 CC1 8 Va COIL1 0 OUT1 1 CC2 9 Vb COIL1 1 OUT2 2 CC3 10 Va COIL2 2 OUT3...
  • Page 120 3.2 HUMAN MACHINE INTERFACE (HMI) 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES Esc: Exit Text. The ESC option returns to the general I/O board menu. Intro: Chg Input. Pressing the shuttle key on the blinking input, this input will be activated in emulation mode. Note: input emulation can only be executed through the TEST INPUT tool on the graphic display.

  • Page 121: Web Server 3.3.1 Home

    3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.3 WEB SERVER 3.3 WEB SERVER 3.3.1 HOME The web server in the G650 can be accessed running the Windows explorer, and keying http://xxx.xxx.xx.xxx, being xxx.xxx.xxx.xxx the relay IP address, which must be configured in Setpoint > Product Setup > Communication Settings >...

  • Page 122: Snapshot Events

    3.3 WEB SERVER 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.3.2 SNAPSHOT EVENTS The Snapshot events screen shows all Snapshot events produced in the relay. This screen is refreshed automatically every minute. The information provided in this screen includes: first, the relative event index, the lowest index corresponding to the most recent event;...

  • Page 123: Control Events

    3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.3 WEB SERVER 3.3.3 CONTROL EVENTS The control events screen provides access to all events that have been configured 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.

  • Page 124: Alarms

    3.3 WEB SERVER 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 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 3-64 G650 Generator Protection &...

  • Page 125: Oscillography

    Download button. The system will then open a window to allow saving the files in Comtrade format in the PC hard drive. Once the records have been saved, the system will ask if the user wants to open GE-OSC tool (Comtrade record viewer) to view the downloaded files.

  • Page 126: Fault Report

    3.3 WEB SERVER 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.3.6 FAULT REPORT The fault report screen provides access to the last 10 fault reports obtained by the relay. These records are stored according to an index that marks their position among all records produced in the relay, with a range from 1 to 999, returning to 1 in case of exceeding the limit of 999.

  • Page 127: Data Logger

    3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.3 WEB SERVER 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 GEK-113328A...

  • Page 128: Metering

    3.3 WEB SERVER 3 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 3.3.8 METERING This screen includes the primary metering values provided by the relay display. Figure 3–41: METERING SCREEN 3-68 G650 Generator Protection & Control System GEK-113328A...

  • Page 129: Security

    4 SECURITY 4.1 ADDING USERS 4 SECURITY 4.1 ADDING USERS New users can only be added by users that have Administrator Access (or Admin Rights) . The Enable Security check box located in the Security->User Management window must be enabled. Remember: (In order to add new users and assign user rights ) •...

  • Page 130: Changing Passwords

    4.2 CHANGING PASSWORDS 4 SECURITY 4.2CHANGING PASSWORDS Users will be prompted to change their password after the first successful log in or through clicking Security from the toolbar, and choose 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.

  • Page 131: Enabling Security

    4 SECURITY 4.3 ENABLING SECURITY 4.3ENABLING SECURITY EnerVista 650 Setup Security Control is disabled by default. Users don't have to log in through user name and password after installation 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.

  • Page 132: Loging Into Enervista 650 Setup

    4.4 LOGING INTO ENERVISTA 650 SETUP 4 SECURITY 4.4LOGING INTO ENERVISTA 650 SETUP Users have to log on in order to use EnerVista 650 Setup program after Security Control has been enabled. After the start up of EnerVista 650 Setup, a dialog will pop up asking for user name and password. Figure 4–3: LOGIN USER The user name field will display the last log in user name as default, in this example, TestUser.

  • Page 133: Bootcode And

    5 BOOTCODE AND FIRMWARE UPGRADE 5.1 INTRODUCTION 5 BOOTCODE AND FIRMWARE UPGRADE 5.1INTRODUCTION This section explains how to upgrade the G650 boot code and firmware. WARNING BEFORE PERFORMING THE UPGRADE PROCEDURE CHECK THAT BOOT AND FIRMWARE VERSION MATCH The boot code and firmware versions can be seen in the relay main screen: The relay firmware version appears after the text "G650"...

  • Page 134: Communication Parameters

    5.1 INTRODUCTION 5 BOOTCODE AND FIRMWARE UPGRADE NOTE RELAYS WITH FIBER OPTIC ETHERNET The upgrade of the boot program (BOOTCODE) must be performed by crossed Ethernet copper cable connected to the PC. It is not necessary to change the internal switch from fiber to RJ45, because the upgrade is made at 10Mb/s. This does not apply to the firmware upgrade, which can be done either via Ethernet Fiber connection, or through the RJ45 cable connection.
  • Page 135 5 BOOTCODE AND FIRMWARE UPGRADE 5.1 INTRODUCTION IP address: 192.168.37.XXX Netmask: 255.255.255.0 and Gateway: 192.168.37.10 (if desired). XXX is a number between 0 and 255 that is not assigned to any other device to avoid collisions. If there are not TCP/IP settings according to this pattern 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).
  • Page 136 5.1 INTRODUCTION 5 BOOTCODE AND FIRMWARE UPGRADE 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. G650 Generator Protection &...

  • Page 137: Boot Code Upgrade

    5 BOOTCODE AND FIRMWARE UPGRADE 5.2 BOOT CODE UPGRADE 5.2BOOT CODE UPGRADE Boot code upgrade is performed using EnerVista 650 Setup. It is required that there is no active communication between the program and the relay, and that no configuration file is open. In this case, menu option Upgrade Boot code will be enabled under the EnerVista 650 Setup Communication menu.
  • Page 138 5.2 BOOT CODE UPGRADE 5 BOOTCODE AND FIRMWARE UPGRADE After accepting to proceed, a window will open up for selecting a temporary IP Address. It is advisable to set the IP Address 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.
  • Page 139 5 BOOTCODE AND FIRMWARE UPGRADE 5.2 BOOT CODE UPGRADE Then the program shows a message requiring switch off and on the relay while the progress bar is in course, to start the upgrading process. Figure 5–10: SWITCH THE RELAY OFF AND ON TO START THE BOOT PROCEDURE It is important to switch the Relay off and on again during the time shown by the progress bar;...
  • Page 140 5.2 BOOT CODE UPGRADE 5 BOOTCODE AND FIRMWARE UPGRADE Figure 5–13: ERASING FLASH MEMORY Once the memory has been erased and the files upgraded in the relay, the parameters for the Ethernet communications must be set (Figure 5–14:). The requested values are the IP address and the gateway Figure 5–14: ETHERNET PARAMETERS These values should match the LAN structure in which the relay will be connected.

  • Page 141: Firmware Version Upgrade

    5 BOOTCODE AND FIRMWARE UPGRADE 5.3 FIRMWARE VERSION UPGRADE 5.3FIRMWARE VERSION UPGRADE The relay settings and configuration will be lost, so it is advisable to save them to a file. Take into account that if the boot code has been previously upgraded, all the data (including calibration settings) was lost. In case of error during the firmware upgrading process, the user could repeat the whole process as many times as necessary, this is possible thanks to an independent boot memory (bootcode).
  • Page 142 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: 5-10 G650 Generator Protection &...

  • Page 143: Boot Code Upgrade (*)

    5 BOOTCODE AND FIRMWARE UPGRADE 5.3 FIRMWARE VERSION UPGRADE • Unit serial number • Current model option (before memory upgrade) • Desired model option (after memory upgrade) • Unit MAC address (available in the identification label) Once the upgrade parameters have been entered, press the “Upgrade Firmware” button. When communication has been established, the program will show a message requesting to turn off and back on the relay to continue with the upgrade process.

  • Page 144: Firmware Upgrade (*)

    5.3 FIRMWARE VERSION UPGRADE 5 BOOTCODE AND FIRMWARE UPGRADE FOLLOW THE INDICATIONS OF THE PROGRAM AND SELECT THE BOOT PROGRAM BIN FILE. WHEN REQUIRED BY THE PROGRAM SWITCH OFF AND BACK ON THE RELAY. CONTINUE WITH THE PROCESS AND SET THE IP ADDRESS AND GATEWAY WHEN REQUIRED. 5.3.3 FIRMWARE UPGRADE (*) INSTALL THE PROPER VERSION OF THE ENERVISTA 650 SETUP PROGRAM.

  • Page 145: Commissioning

    6 COMMISSIONING 6.1 VISUAL INSPECTION 6 COMMISSIONING 6.1VISUAL INSPECTION Verify that the relay has not suffered any damage 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.

  • Page 146: General Considerations On The Power Supply Network

    6.2 GENERAL CONSIDERATIONS ON THE POWER SUPPLY NETWORK 6 COMMISSIONING 6.2GENERAL CONSIDERATIONS ON THE POWER SUPPLY NETWORK All devices running on AC current are affected by frequency. As a non-sine wave is the result of a fundamental wave plus a series of harmonics from this fundamental wave, we can infer that devices running on AC current are influenced by the applied waveform.

  • Page 147: Isolation Tests

    6 COMMISSIONING 6.3 ISOLATION TESTS 6.3ISOLATION TESTS During all tests, the screw located on the rear of the relay must be grounded. For verifying isolation, independent groups will be created, and voltage will be applied as follows: 2200 RMS volts will be applied progressively among all terminals in a group, short-circuited between them and the case, during one second.

  • Page 148: Indicators

    6.4 INDICATORS 6 COMMISSIONING 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. G650 Generator Protection & Control System GEK-113328A...

  • Page 149: Power Supply Testing

    6 COMMISSIONING 6.5 POWER SUPPLY TESTING 6.5POWER SUPPLY TESTING Feed the relay with the minimum and maximum voltage. For each voltage value, verify that the alarm relay is activated when there is voltage, and it is deactivated when there is no feed. If the power supply source incorporates AC feed, this test will be performed also for VAC.

  • Page 150: Communications

    6.6 COMMUNICATIONS 6 COMMISSIONING 6.6COMMUNICATIONS 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: Verification Of Measurement

    6 COMMISSIONING 6.7 VERIFICATION OF MEASUREMENT 6.7VERIFICATION OF MEASUREMENT Set the relay as follows GENERAL SETTINGS NAME VALUE UNITS RANGE PHASE CT RATIO 1.0-6000.0 GROUND CT RATIO 1.0-6000.0 STV GROUND CT RATIO 1.0-6000.0 PHASE VT RATIO 1.0-6000.0 PHASE VT CONNECTION WYE –...

  • Page 152: Active, Reactive Power, And Cosj Metering

    6.7 VERIFICATION OF MEASUREMENT 6 COMMISSIONING 6.7.3 ACTIVE, REACTIVE POWER, AND COSϑ METERING Equations to be applied for powers in a wye connection are as follows: POWER PER PHASE THREE-PHASE POWER P=V*I*Cosϕ P=Pa+Pb+Pc Q=V*I*Senϕ Q=Qa+Qb+Qc Apply the following current and voltage values: APPLIED VOLTAGE AND CURRENT VALUES PER PHASE PHASE A PHASE B...

  • Page 153: Inputs And Outputs

    6 COMMISSIONING 6.8 INPUTS AND OUTPUTS 6.8INPUTS AND OUTPUTS During all tests, the screw on the rear of the relay must be grounded. 6.8.1 DIGITAL INPUTS During this test, the user will determine the activation/deactivation points for every input in the relay for the set voltage value of 30 Volts.

  • Page 154: Contact Outputs

    6.8 INPUTS AND OUTPUTS 6 COMMISSIONING 6.8.2 CONTACT OUTPUTS The correct activation of every output will be verified. For every output, activation command of a single contact must be given, and then verify that only that contact is activated. Go to EnerVista 650 Setup Software (Setpoint>Inputs/Outputs>Force Outputs). For switched contacts, the change of state of both contacts shall be verified.

  • Page 155: Connections For Testing Protection Elements

    6 COMMISSIONING 6.9 CONNECTIONS FOR TESTING PROTECTION ELEMENTS 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 B1-B2 B3-B4 B5-B6 B9-B10 B11-B12 Voltage A5-A6 A7-A8...

  • Page 156: Instantaneous Overcurrent (50Ph, 50N, 50G Y 50Sg)

    6.10 INSTANTANEOUS OVERCURRENT (50PH, 50N, 50G Y 50SG) 6 COMMISSIONING 6.10INSTANTANEOUS OVERCURRENT (50PH, 50N, 50G Y 50SG) Set the relay to trip for the protection element being tested. Configure any of the outputs to be enabled only by the protection element being tested. Apply 0.9 times the Pickup current and check that the relay does not trip.

  • Page 157: Time Overcurrent (51Ph, 51Pl, 51N, 51G)

    6 COMMISSIONING 6.11 TIME OVERCURRENT (51PH, 51PL, 51N, 51G) 6.11 TIME OVERCURRENT (51PH, 51PL, 51N, 51G) Set the relay to trip for the protection element being tested. Configure any of the outputs to be activated only by the protection element being tested. Apply 0.9 times the Pickup current and check that the relay does not trip.

  • Page 158: Directional Elements (67N, 67G)

    6.12 DIRECTIONAL ELEMENTS (67N, 67G) 6 COMMISSIONING 6.12DIRECTIONAL ELEMENTS (67N, 67G) In order to test directional units in the relay, instantaneous trips will be commanded. Two points will be tested, per phase, test element. In order to test the directional units, configure (in the "Setpoint > Relay Configuration > Protection Elements" screen of the EnerVista 650 Setup program), some overcurrent element to be supervised by a directional unit.
  • Page 159 6 COMMISSIONING 6.12 DIRECTIONAL ELEMENTS (67N, 67G) 6.12.2 67G ELEMENT Activate only protection elements 50G and 67G and set the relay as follows: 67G SETTINGS 50G SETTINGS Function ENABLED Function ENABLED -45 Deg Input PHASOR (DFT) Direction FORWARD Pickup Level 0.50 A Polarization Trip Delay...

  • Page 160: Undervoltage Elements (27P, 27X)

    6.13 UNDERVOLTAGE ELEMENTS (27P, 27X) 6 COMMISSIONING 6.13UNDERVOLTAGE ELEMENTS (27P, 27X) 6.13.1 27P ELEMENT Set the relay to trip for the protection element being tested. Configure any of the outputs to be activated only by the protection element being tested. Set the relay as follows: PHASE UV (27P) Function...

  • Page 161: Overvoltage Elements (59P, 59X, 59Nh)

    6 COMMISSIONING 6.14 OVERVOLTAGE ELEMENTS (59P, 59X, 59NH) 6.14OVERVOLTAGE ELEMENTS (59P, 59X, 59NH) 6.14.1 59P ELEMENT Set the relay to trip for the protection element being tested. Configure any of the outputs to be activated only by the protection element being tested. Set the relay as follows: PHSE OV (59P) Function...

  • Page 162: 59Nh Element

    6.14 OVERVOLTAGE ELEMENTS (59P, 59X, 59NH) 6 COMMISSIONING 6.14.3 59NH ELEMENT Set the relay as follows NEUTRAL OV HIGH (59NH) Function ENABLED Pickup Level 120 V Trip Delay 2.00 Reset Delay 0.00 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%).

  • Page 163: Element - Neg Seq Ov

    6 COMMISSIONING 6.14 OVERVOLTAGE ELEMENTS (59P, 59X, 59NH) 6.14.4 47 ELEMENT - NEG SEQ OV Set the relay as follows: NEG SEQ OV (47) Function ENABLED Pickup Level 50 V Trip Delay 2.00 Reset Delay 0.00 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%).

  • Page 164: Frequency Elements (81O/81U)

    6.15 FREQUENCY ELEMENTS (81O/81U) 6 COMMISSIONING 6.15 FREQUENCY ELEMENTS (81O/81U) Set the relay to trip for the protection element being tested. Configure any of the outputs to be activated only by the protection element being tested. Set the relay as follows: GENERAL SETTINGS Nominal Frequency 50 Hz...

  • Page 165: Frequently Asked

    7 FREQUENTLY ASKED QUESTIONS 7.1 COMMUNICATIONS 7 FREQUENTLY ASKED QUESTIONS 7.1COMMUNICATIONS Does the G650 support DNP and ModBus over the Ethernet port? G650 units support both protocols over both the asynchronous serial ports and the Ethernet LAN synchronous port using TCP/IP and UDP/IP layers over the Ethernet. Does this equipment support dual IP access? Yes, it supports two independent IP addresses in aliasing mode.
  • Page 166 7.1 COMMUNICATIONS 7 FREQUENTLY ASKED QUESTIONS Q12. May I connect URs and G650s to the same Ethernet? A12. Yes, either in cable as in fiber, or even mix them. Q13. How do I connect with fiber 10-BASE-FL UR relays with 100-BASE-FX G650 relays? A13.

  • Page 167: Protection

    7 FREQUENTLY ASKED QUESTIONS 7.2 PROTECTION 7.2PROTECTION Does the G650 support IRIG-B signals? Which type and accuracy? How many units may be connected to the same source? Yes, the G650 includes an IRIG-B input for all models, including the basic ones. It uses DC level format B.

  • Page 168: Control And Hmi

    7.3 CONTROL AND HMI 7 FREQUENTLY ASKED QUESTIONS 7.3CONTROL AND HMI What is the difference between Get/Send info from/to relay and Upload/Download info files to/from relay? Get/Send are used for settings and configuration storage that although both are in a unique file, are sent separately in two times.

  • Page 169: Relay Configuration

    7 FREQUENTLY ASKED QUESTIONS 7.4 RELAY CONFIGURATION 7.4RELAY CONFIGURATION Does the "Service" contact on the Power Supply board cover all possible failures or do I have to create an output on the I/O board that includes all the internal errors I can access in the logic? 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.).
  • Page 170 7.4 RELAY CONFIGURATION 7 FREQUENTLY ASKED QUESTIONS G650 Generator Protection & Control System GEK-113328A...

  • Page 171: Symptoms And Recommended Actions

    8 G650TROUBLESHOOTING GUIDE 8.1 SYMPTOMS AND RECOMMENDED ACTIONS 8 G650TROUBLESHOOTING GUIDE 8.1SYMPTOMS AND RECOMMENDED ACTIONS G650 units have been designed and verified using the most advanced and reliable equipment. Mounting and testing automation ensure a high consistency of the final product. Before sending a unit back to the factory, we strongly recommend you follow the recommendations below.
  • Page 172 8.1 SYMPTOMS AND RECOMMENDED ACTIONS 8 G650TROUBLESHOOTING GUIDE CATEGORY SYMPTOM POSSIBLE CAUSE RECOMMENDED ACTION Communications Cannot see properly Disabled Java options in Advanced 1.- Go to Advanced in Internet options server Internet Explorer properties or high for Internet explorer and select the G650 with Windows level of security three selections in Microsoft VM (Java...
  • Page 173 8 G650TROUBLESHOOTING GUIDE 8.1 SYMPTOMS AND RECOMMENDED ACTIONS CATEGORY SYMPTOM POSSIBLE CAUSE RECOMMENDED ACTION Bootware The relay gets stuck at -The Ethernet connection does not Serial communications work properly “Sending file work properly. and the flash memory has been imagen_kernel...” erased but ethernet communication does not work properly, check: •...
  • Page 174 8.1 SYMPTOMS AND RECOMMENDED ACTIONS 8 G650TROUBLESHOOTING GUIDE • EnerVista 650 Setup program do not Firmware During the upgrading - Communication problems during the procces models upgrade procecure. ask for a password if the relay model is with 61850 procedure been IEC61850 procedure...
  • Page 175 APPENDIX A A.1 FACTORY DEFAULT LOGIC APPENDIX A FACTORY DEFAULT LOGICA.1 FACTORY DEFAULT LOGIC LEDS AND OUTPUTS BOOLEANS PICKUPS PHASE OVERCURRENT PH TOC1 HIGH PKP VO_053_51P_PKP PH TOC2 HIGH PKP inOR1 outOR1 inOR2 PH TOC3 HIGH PKP inOR3 PH TOC1 LOW PKP inOR4 inOR5 PH TOC2 LOW PKP...
  • Page 176 A.1 FACTORY DEFAULT LOGIC APPENDIX A RESTRICTED GROUND FAULT (FOR ENHANCED MODELS ONLY) RESTR GND FLT1 PKP VO_040_REST_GND_FLT_PKP inOR1 outOR1 RESTR GND FLT2 PKP inOR2 RESTR GND FLT3 PKP inOR3 VO_049_51G_PKP VO_009_GROUND_OVERCURRENT_PKP inOR1 outOR1 VO_048_50G_PKP inOR2 VO_040_REST_GND_FLT_PKP inOR3 SENSITIVE GROUND FOR ENHANCED MODELS ONLY SENS GND TOC1 PKP VO_003_51SG_PKP inOR1...
  • Page 177 APPENDIX A A.1 FACTORY DEFAULT LOGIC GENERATOR THERMAL MODEL THERMAL1 49S ALARM VO_001_GEN_THERMAL_ALARM inOR1 outOR1 THERMAL2 49S ALARM inOR2 THERMAL3 49S ALARM inOR3 GENERATOR GENERAL OVERCURRENT PICKUP VO_007_PHASE_OVERCURRENT_PKP OVERCURRENT PICKUPS VO_008_NEUTRAL_OVERCURRENT_PKP inOR1 outOR1 inOR2 VO_009_GROUND_OVERCURRENT_PKP inOR3 VO_011_ALL_OVERCURRENT_PKP VO_010_SENSITIVE_GROUND_PKP inOR4 inOR5 VO_035_NEGATIVE_SEQ_OVERCURRENT_PKP inOR6 VO_001_GEN_THERMAL_ALARM...
  • Page 178 A.1 FACTORY DEFAULT LOGIC APPENDIX A VOLTS/HERTZ PICKUP (FOR ENHANCED MODELS ONLY) VOLTS/Hz1 PKP VO_036_VOLTS_HERTZ_PKP inOR1 outOR1 VOLTS/Hz2 PKP inOR2 VOLTS/Hz3 PKP inOR3 VO_045_27P_PKP VO_038_UNDERVOLTAGE_PKP VOLTAGE VO_014_27X_PKP PICKUPS VO_039_OVERVOLTAGE_PKP VO_046_59P_PKP In OR1 OutOR1 VO_012_59NH_PKP In OR2 VO_015_59X_PKP In OR3 VO_016_V2_OV_PKP In OR4 VO_037_59G_PKP In OR5...
  • Page 179 APPENDIX A A.1 FACTORY DEFAULT LOGIC DIR PWR1 STG PKP VO_025_DIRECTIONAL_POWER_PKP DIRECTIONAL inOR1 outOR1 DIR PWR2 STG PKP POWER inOR2 DIR PWR3 STG PKP inOR3 POWER VO_025_DIRECTIONAL_POWER_PKP VO_026_POWER_PKP VO_011_ALL_OVERCURRENT_PKP VO_085_GENERAL_PKP inOR1 outOR1 VO_017_ALL_VOLTAGE_PKP GENERAL inOR2 PICKUP VO_056_ALL_FREQUENCY_PKP inOR3 VO_026_POWER_PKP inOR4 GEK-113328A G650 Generator Protection &...
  • Page 180 A.1 FACTORY DEFAULT LOGIC APPENDIX A TRIPS PHASE OVERCURRENT TRIP PH TOC1 HIGH OP VO_057_51P_TRIP PH TOC2 HIGH OP inOR1 outOR1 inOR2 PH TOC3 HIGH OP inOR3 PH TOC1 LOW OP inOR4 inOR5 PH TOC2 LOW OP inOR6 PH TOC3 LOW OP PH IOC1 HIGH OP VO_058_50PH_TRIP inOR1...
  • Page 181 APPENDIX A A.1 FACTORY DEFAULT LOGIC RESTRICTED GROUND FAULT TRIP (FOR ENHANCED MODELS ONLY) RESTR GND FLT1 OP VO_090_RESTR_GND_FLT_TRIP inOR1 outOR1 RESTR GND FLT2 OP inOR2 RESTR GND FLT3 OP inOR3 VO_067_51G_TRIP VO_069_GROUND_OVERCURRENT_TRIP inOR1 outOR1 VO_068_50G_TRIP inOR2 VO_090_RESTR_GND_FLT_TRIP inOR3 SENSITIVE GROUND OVERCURRENT TRIP (FOR ENHANCED MODELS ONLY) SENS GND TOC1 OP VO_070_51SG_TRIP inOR1...
  • Page 182 A.1 FACTORY DEFAULT LOGIC APPENDIX A GENERATOR GENERAL OVERCURRENT TRIP VO_019_PHASE_OVERCURRENT_TRIP VO_066_NEUTRAL_OVERCURRENT_TRIP inOR1 outOR1 OVERCURRENT inOR2 TRIPS VO_069_GROUND_OVERCURRENT_TRIP inOR3 VO_072_SENSITIVE_GROUND_TRIP inOR4 VO_000_NEGATIVE_SEQ_OVERCURRENT_TRIP inOR5 VO_020_ALL_OVERCURRENT_TRIP VO_062_GEN_THERMAL_TRIP inOR6 PHASE UV1 OP VO_073_27P_TRIP inOR1 outOR1 PHASE UV2 OP inOR2 PHASE UV3 OP inOR3 AUXILIARY UV1 OP VO_078_27X_TRIP inOR1...
  • Page 183 APPENDIX A A.1 FACTORY DEFAULT LOGIC VO_074_59P_TRIP VO_086_OVERVOLTAGE_TRIP In OR1 OutOR1 VO_075_59NH_TRIP In OR2 VO_077_59X_TRIP In OR3 VO_021_V2_OV_TRIP VOLTAGE In OR4 TRIPS VO_047_59G_TRIP In OR5 VO_063_VOLTS_HERTZ_TRIP VO_079_ALL_VOLTAGE_TRIP inOR1 outOR1 VO_084_UNDERVOLTAGE_TRIP inOR2 VO_086_OVERVOLTAGE_TRIP inOR3 OVERFREQ1 OP VO_080_81O_TRIP inOR1 outOR1 OVERFREQ2 OP inOR2 OVERFREQ3 OP inOR3...
  • Page 184 A.1 FACTORY DEFAULT LOGIC APPENDIX A LOSS OF MAINS (78V) TRIP (FOR ENHANCED MODELS ONLY) LOSS OF MAINS1 OP VO_091_LOSS_OF_MAINS_TRIP inOR1 outOR1 LOSS OF LOSS OF MAINS2 OP MAINS inOR2 LOSS OF MAINS3 OP inOR3 GENERAL TRIP VO_020_ALL_OVERCURRENT_TRIP VO_083_GENERAL_TRIP In OR1 OutOR1 VO_079_ALL_VOLTAGE_TRIP GENERAL...
  • Page 185 APPENDIX A A.1 FACTORY DEFAULT LOGIC GEK-113328A G650 Generator Protection & Control System A-11...
  • Page 186 A.1 FACTORY DEFAULT LOGIC APPENDIX A A-12 G650 Generator Protection & Control System GEK-113328A...

  • Page 187: Factory Default Settings

    APPENDIX B B.1 FACTORY DEFAULT SETTINGS APPENDIX B FACTORY DEFAULT CONFIGURATIONB.1 FACTORY DEFAULT SETTINGS Factory Default Settings Example for Enhanced Models PRODUCT SETUP>COMMUNICATION SETTINGS >SERIAL PORTS USER SETTING DESCRIPTION NAME DEFAULT VALUE STEP RANGE VALUE Baud rate for COM1 COM1 Baud Rate 19200 [300 : 115200] Baud rate for COM2...
  • Page 188 B.1 FACTORY DEFAULT SETTINGS APPENDIX B PRODUCT SETUP>COMMUNICATION SETTINGS >DNP3 SLAVE DNP3 SLAVE 1 > DNP3 SLAVE 2 > DNP3 SLAVE 3 USER SETTING DESCRIPTION NAME DEFAULT VALUE STEP RANGE VALUE Communications port assigned to the Physical Port NONE [COM1:COM2:NETWORK] DNP protocol DNP slave address Address...
  • Page 189 APPENDIX B B.1 FACTORY DEFAULT SETTINGS PRODUCT SETUP>COMMUNICATION SETTINGS >DNP3 SLAVE (CONT.) DNP3 SLAVE 1 > DNP3 SLAVE 2 > DNP3 SLAVE 3 USER SETTING DESCRIPTION NAME DEFAULT VALUE STEP RANGE VALUE [0.00001-0.0001-0.001- Scale for power Power Scale Factor 0.01-0.1-1-10-100-1000] [0.00001-0.0001-0.001- Scale for energy Energy Scale Factor...
  • Page 190 B.1 FACTORY DEFAULT SETTINGS APPENDIX B PRODUCT SETUP>COMMUNICATION SETTINGS >IEC 870-5-104 USER SETTING DESCRIPTION NAME DEFAULT VALUE STEP RANGE VALUE Enable or disable the protocol Function DISABLED [DISABLED – ENABLED] operation Listening TCP port in the relay TCP Port 2404 [0 : 65535] Common Addr of Address in the ASDU header...
  • Page 191 APPENDIX B B.1 FACTORY DEFAULT SETTINGS SETPOINT > PRODUCT SETUP > MODBUS USER MAP USER SETTING DESCRIPTION NAME DEFAULT VALUE STEP RANGE VALUE Address 00 for Modbus user map Address 00 [0000 : FFFF] Address 01 for Modbus user map Address 01 [0000 : FFFF] Address 254 for Modbus user map...
  • Page 192 B.1 FACTORY DEFAULT SETTINGS APPENDIX B SETPOINT > PRODUCT SETUP > DEMAND USER SETTING DESCRIPTION NAME DEFAULT VALUE STEP RANGE VALUE Function permission Demand Function DISABLED [DISABLED – ENABLED] [BLOCK INTERVAL - CRNT Demand THERMAL ROLLING DEMAND - Demand method for current values Method EXPONENTIAL THERMAL...
  • Page 193 APPENDIX B B.1 FACTORY DEFAULT SETTINGS SETPOINT > SYSTEM SETUP > BREAKER > BREAKER SETTINGS USER SETTING DESCRIPTION NAME DEFAULT VALUE STEP RANGE VALUE Number of Switchgear selected as Number of Switchgear 1 [1 : 16] breaker 0.01(KA)2 Maximum value of KI2t Maximum KI2t 9999.99 [0.00 : 9999.99]...
  • Page 194 B.1 FACTORY DEFAULT SETTINGS APPENDIX B SETPOINT > PROTECTION ELEMENTS > PHASE CURRENT > > PHASE TOC HIGH > PHASE TOC HIGH 1> PHASE TOC HIGH 2 > PHASE TOC HIGH 3 > PHASE TOC LOW > PHASE TOC LOW 1 > PHASE TOC LOW 2 > PHASE TOC LOW 3 USER SETTING DESCRIPTION NAME...
  • Page 195 APPENDIX B B.1 FACTORY DEFAULT SETTINGS SETPOINT > PROTECTION ELEMENTS > NEUTRAL CURRENT > NEUTRAL TOC NEUTRAL TOC 1> NEUTRAL TOC 2 > NEUTRAL TOC 3 USER SETTING DESCRIPTION NAME DEFAULT VALUE STEP RANGE VALUE Function permission Function DISABLED [DISABLED – ENABLED] Pickup level Pickup Level 1.00...
  • Page 196 B.1 FACTORY DEFAULT SETTINGS APPENDIX B SETPOINT > PROTECTION ELEMENTS > GROUND CURRENT > GROUND IOC GROUND IOC 1> GROUND IOC 2 > GROUND IOC 3 USER SETTING DESCRIPTION NAME DEFAULT VALUE STEP RANGE VALUE Function permission Function DISABLED [DISABLED – ENABLED] Input type Input PHASOR(DFT)
  • Page 197 APPENDIX B B.1 FACTORY DEFAULT SETTINGS SETPOINT > PROTECTION ELEMENTS > SENSITIVE GROUND CURRENT > SENSITIVE GROUND IOC (ENHANCED MODELS ONLY) SENSITIVE GROUND IOC 1> SENSITIVE GROUND IOC 2 > SENSITIVE GROUND IOC 3 USER SETTING DESCRIPTION NAME DEFAULT VALUE STEP RANGE VALUE...
  • Page 198 B.1 FACTORY DEFAULT SETTINGS APPENDIX B SETPOINT > PROTECTION ELEMENTS > VOLTAGE ELEMENTS > PHASE UV > PHASE UV 1> PHASE UV 2 > PHASE UV 3 USER SETTING DESCRIPTION NAME DEFAULT VALUE STEP RANGE VALUE Function permission Function DISABLED [DISABLED –...
  • Page 199 APPENDIX B B.1 FACTORY DEFAULT SETTINGS SETPOINT > PROTECTION ELEMENTS >VOLTAGE ELEMENTS>AUXILIARY OV AUXILIARY OV 1> AUXILIARY OV 2 > AUXILIARY OV 3 USER SETTING DESCRIPTION NAME DEFAULT VALUE STEP RANGE VALUE Function permission Function DISABLED [DISABLED – ENABLED] Pickup Level Pickup Level [3 : 500] Trip Time...
  • Page 200 B.1 FACTORY DEFAULT SETTINGS APPENDIX B SETPOINT > PROTECTION ELEMENTS > POWER > DIRECTIONAL POWER> DIRECTIONAL POWER 1> DIRECTIONAL POWER 2 > DIRECTIONAL POWER 3 USER SETTING DESCRIPTION NAME DEFAULT VALUE STEP RANGE VALUE Function permission Function DISABLED [DISABLED – ENABLED] Block from off-line Blk Time After Close 0.00...
  • Page 201 APPENDIX B B.1 FACTORY DEFAULT SETTINGS SETPOINT > CONTROL ELEMENTS > OVERFREQUENCY OVERFREQUENCY 1 > OVERFREQUENCY 2 > OVERFREQUENCY 3 USER SETTING DESCRIPTION NAME DEFAULT VALUE STEP RANGE VALUE Function permission Function DISABLED [DISABLED – ENABLED] Pickup level Pickup Level 50.50 0.01 Hz [20.00 : 65.00]...
  • Page 202 B.1 FACTORY DEFAULT SETTINGS APPENDIX B SETPOINT > CONTROL ELEMENTS > BREAKER FAILURE(ENHANCED MODELS ONLY) USER SETTING DESCRIPTION NAME DEFAULT VALUE STEP RANGE VALUE Function permission Function DISABLED [DISABLED – ENABLED] Supervision (retrip) pickup level Supervision Pickup 1.00 0.01 A [0.05 : 160.00] Hiset pickup level Hiset Pickup...
  • Page 203 APPENDIX B B.1 FACTORY DEFAULT SETTINGS LOSS OF EXCITATION 1 > LOSS OF EXCITATION 2 > LOSS OF EXCITATION 3 USER SETTING DESCRIPTION NAME DEFAULT VALUE STEP RANGE VALUE Function Permission Function DISABLED [DISABLED – ENABLED] Center point in Ohms (sec) for Stage 1 Stage 1 Center 10.00 0.01 Ohm [0.10 : 300.00]...
  • Page 204 B.1 FACTORY DEFAULT SETTINGS APPENDIX B SETPOINT > CONTROL ELEMENTS > ACCIDENTAL ENERGIZATION ACCIDENTAL ENERGIZATION 1 > ACCIDENTAL ENERGIZATION 2 > ACCIDENTAL ENERGIZATION 3 USER SETTING DESCRIPTION NAME DEFAULT VALUE STEP RANGE VALUE Function Permission Function DISABLED [DISABLED – ENABLED] Arming mode for Accidental Accdnt Enrg Mode UV AND OFF-LINE N/A...
  • Page 205 APPENDIX B B.1 FACTORY DEFAULT SETTINGS SETPOINT > INPUTS/OUTPUTS > CONTACT I/O > BOARD F > BOARD G >BOARD H>BOARD J USER SETTING DESCRIPTION NAME DEFAULT VALUE STEP RANGE VALUE I/O board type (available only for CIO I/O Board Type_X NONE [NONE, modules)
  • Page 206 B.1 FACTORY DEFAULT SETTINGS APPENDIX B NOTE 2: DESCRIPTION OF X, Y AND Z IN INPUT/OUTPUT BOARDS F, G, H or J, the I/O board name, depending on the Relay model. F and G are internal Relay boards, and H and J are additional boards available in CIO modules (remote Bus CAN I/O module) I/O BOARD TYPE ENERVISTA 650...

  • Page 207: Factory Default Configuration

    APPENDIX B B.2 FACTORY DEFAULT CONFIGURATION B.2FACTORY DEFAULT CONFIGURATION NOTE: SOURCE COLUMN: This columns allow selecting the simple or complex (OR signal or Virtual output) operand that actives the selected elements on relay configuration If more than one operands are selected, the relay performs an OR gate with them to activate the selected element. SIGNAL LOGIC COLUMN: Refers to each individual signal selected on its left.
  • Page 208 B.2 FACTORY DEFAULT CONFIGURATION APPENDIX B SETPOINT>RELAY CONFIGURATION>OUTPUTS OUTPUT ID OUTPUT NAME SOURCE SIGNAL LOGIC SOURCE LOGIC CONT OP RESET_G_07 Not Configured CONT OP RESET_G_08 Not Configured SETPOINT>RELAY CONFIGURATION>LEDS LED ID LED NAME SOURCE SIGNAL LOGIC SOURCE LOGIC LED01 TRIP VO_083_GENERAL_TRIP LED02 50/51P TRIP...
  • Page 209 APPENDIX B B.2 FACTORY DEFAULT CONFIGURATION SETPOINT>RELAY CONFIGURATION>PROTECTION ELEMENTS PROTECTION ELEMENT SOURCE SIGNAL LOGIC SOURCE LOGIC NEUTRAL IOC2 BLOCK GROUP 2 BLOCKED NEUTRAL DIR2 OP NEUTRAL IOC3 BLOCK GROUP 3 BLOCKED NEUTRAL DIR3 OP GROUND IOC1 BLOCK GROUP 1 BLOCKED LVI_3_BLOCK 50G GROUND DIR1 OP CONT IP_F_CC5...
  • Page 210 B.2 FACTORY DEFAULT CONFIGURATION APPENDIX B SETPOINT>RELAY CONFIGURATION>PROTECTION ELEMENTS PROTECTION ELEMENT SOURCE SIGNAL LOGIC SOURCE LOGIC CONT IP_F_CC6 (51G BLOCK)(CC6) GROUND TOC2 BLOCK GROUP 2 BLOCKED LVI_7_BLOCK 51G GROUND DIR2 OP CONT IP_F_CC6 (51G BLOCK)(CC6) GROUND TOC3 BLOCK GROUP 3 BLOCKED LVI_7_BLOCK 51G GROUND DIR3 OP CONT IP_F_CC6...
  • Page 211 APPENDIX B B.2 FACTORY DEFAULT CONFIGURATION SETPOINT>RELAY CONFIGURATION>PROTECTION ELEMENTS PROTECTION ELEMENT SOURCE SIGNAL LOGIC SOURCE LOGIC 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...
  • Page 212 B.2 FACTORY DEFAULT CONFIGURATION APPENDIX B SETPOINT>RELAY CONFIGURATION>PROTECTION ELEMENTS PROTECTION ELEMENT SOURCE SIGNAL LOGIC SOURCE LOGIC LOSS OF MAINS1 BLOCK GROUP 1 BLOCKED LOSS OF MAINS2 BLOCK GROUP 2 BLOCKED LOSS OF MAINS3 BLOCK GROUP 3 BLOCKED GEN UNBAL1 BLOCK GROUP 1 BLOCKED GEN UNBAL2 BLOCK GROUP 2 BLOCKED...
  • Page 213 APPENDIX B B.2 FACTORY DEFAULT CONFIGURATION SETPOINT>RELAY CONFIGURATION>PROTECTION ELEMENTS PROTECTION ELEMENT SOURCE SIGNAL LOGIC SOURCE LOGIC DEMAND RESET INP Not Configured FREEZE ENERGY CNT Not Configured UNFREEZE ENERGY Not Configured RESET ENERGY CNT Not Configured RESET KI2t COUNTERS Not Configured RESET BKR COUNTERS Not Configured Note (*): Only available for Enhanced models (see ordering code) SETPOINT>RELAY CONFIGURATION>OSCILLOGRAPHY...
  • Page 214 B.2 FACTORY DEFAULT CONFIGURATION APPENDIX B SETPOINT>RELAY CONFIGURATION>OPERATIONS OPERATION OPERATION TEXT SETTINGS VALUE/SOURCE INTERLOCK(LOGIC) Not configured FINAL STATES AND(LOGIC) BREAKER OPEN FRONT KEY O Key Operation2 OPEN BREAKER INPUT Not configured VIRTUAL OUTPUT Not configured TIMEOUT 1000 CHANNELS INTERLOCK(LOGIC) Not configured FINAL STATES AND(LOGIC) Not configured FRONT KEY...
  • Page 215 APPENDIX B B.2 FACTORY DEFAULT CONFIGURATION SETPOINT>RELAY CONFIGURATION>OPERATIONS OPERATION OPERATION TEXT SETTINGS VALUE/SOURCE INTERLOCK(LOGIC) Not configured FINAL STATES AND(LOGIC) Not configured FRONT KEY Not configured Operation9 Not configured INPUT Not configured VIRTUAL OUTPUT Not configured TIMEOUT Not configured CHANNELS Not configured INTERLOCK(LOGIC) Not configured FINAL STATES AND(LOGIC)
  • Page 216 B.2 FACTORY DEFAULT CONFIGURATION APPENDIX B SETPOINT>RELAY CONFIGURATION>SWITCHGEAR SWITCHGEAR SETTING VALUE/SOURCE SIGNAL LOGIC SOURCE LOGIC 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...

  • Page 217: Ge Multilin Warranty

    24 months from date of shipment from factory. In the event of a failure covered by warranty, GE Multilin will undertake to repair or replace the relay providing the warrantor determined that it is defective and it is returned with all transportation charges prepaid to an authorized service center or the factory.
  • Page 218 C.1 GE MULTILIN WARRANTY APPENDIX C G650 Generator Protection & Control System GEK-113328A...

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