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GE Multilin G650 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
E gemultilin@ge.com
Internet: www.GEMultilin.com
GE Consumer & Industrial
Multilin
G650
Generator Protection & Control
System
Instruction manual
GEK-113285A
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
E gemultilin.euro@ge.com

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  • Page 1 G650 Generator Protection & Control System Instruction manual GEK-113285A 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 2: 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 3 TABLE OF CONTENTS 3.5 TRANSCEIVER OPTICAL POWER BUDGET VERSUS LINK LENGTH 4. HUMAN INTERFACES. 4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 4.1.1 INTRODUCTION ....................4-1 SETTINGS & ACTUAL 4.1.2 ENERVISTA 650 SETUP SOFTWARE OVERVIEW..........4-1 VALUES 4.1.3 MAIN SCREEN ....................4-3 4.1.4 COMMUNICATION MENU .................4-4 4.1.5 FILE MANAGEMENT ..................4-6 4.1.6...
  • Page 4 TABLE OF CONTENTS 5.5 CONTROL ELEMENTS 5.5.1 SETTING GROUP ................... 5-77 5.5.2 UNDERFREQUENCY ELEMENT (81U)............5-78 5.5.3 OVERFREQUENCY ELEMENT (81O) ............5-78 5.5.4 SYNCHRONISM CHECK ELEMENT - SYNCHROCHECK (25) ..... 5-79 5.5.5 BREAKER FAILURE ELEMENT (50BF) (ENHANCED MODELS ONLY) ..5-88 5.5.6 VT FUSE FAILURE ELEMENT (VTFF) (ENHANCED MODELS ONLY) ..
  • Page 5 TABLE OF CONTENTS 6.3.4 FREQUENCY ....................6-38 6.4 INPUTS / OUTPUTS 6.4.1 CONTACT INPUTS ..................6-39 6.4.2 CONTACT OUTPUT STATUS................6-40 6.4.3 CONTACT OUTPUT OPERATES ..............6-40 6.4.4 CONTACT OUTPUT RESETS .................6-41 6.4.5 I/O BOARD STATUS ..................6-42 6.4.6 VIRTUAL INPUTS ....................6-42 6.4.7 VIRTUAL OUTPUTS ..................6-42 6.4.8 ANALOG INPUTS.....................6-43 6.5 RECORDS...
  • Page 6 TABLE OF CONTENTS 9.9 CONNECTIONS FOR TESTING PROTECTION ELEMENTS 9.10 INSTANTANEOUS OVERCURRENT (50PH, 50N, 50G Y 50SG) 9.11 TIME OVERCURRENT (51PH, 51PL, 51N, 51G) 9.12 DIRECTIONAL ELEMENTS (67N, 67G) 9.12.1 67N ELEMENT....................9-14 9.12.2 67G ELEMENT ....................9-15 9.13 UNDERVOLTAGE ELEMENTS (27P, 27X) 9.13.1 27P ELEMENT....................
  • Page 7 TABLE OF CONTENTS B.3 DATA TYPE B.4 MODBUS APPENDIX B.4.1 DATA MANAGEMENT ..................B-8 B.4.2 WRITING SETTINGS ..................B-8 B.4.3 SNAPSHOT EVENTS..................B-8 B.4.4 OPERATIONS ....................B-12 B.5 OUTPUT WRITING B.5.1 CONTROL EVENTS ..................B-14 B.5.2 EVENT STRUCTURE..................B-15 B.6 EVENTS STATUS REQUEST(ALARMS) B.6.1 CONTROL EVENTS RETRIEVAL FROM THE COMMAND LINE ....
  • Page 8 TABLE OF CONTENTS G. MISCELLANEOUS G.1 GE MULTILIN WARRANTY GEK-113285A G650 Generator Protection & Control System...

  • Page 9: G650 Generator Protection & Control System

    TABLE OF CONTENTS G650 Generator Protection & Control System GEK-113285A...

  • Page 10: 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 11 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 12 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-113285A G650 Generator Protection & Control System...

  • Page 13: 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 14 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 15: 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 16: 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 17 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 18: 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 19 1.2 OVERVIEW 1 GETTING STARTED Figure 1–7: COMMUNICATIONS ARCHITECTURE (B6816F1) 1-10 G650 Generator Protection & Control System GEK-113285A...

  • Page 20: 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 21 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 22 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 23 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 24: 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 25 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 26: 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 27: 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 28 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 29 1.4 650 HARDWARE 1 GETTING STARTED 1-20 G650 Generator Protection & Control System GEK-113285A...

  • Page 30: 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 31 2.1 OVERVIEW 2 PRODUCT DESCRIPTION Figure 2–2: G650 BLOCK DIAGRAM FOR ENHANCED FUNCTIONALITY MODELS G650 Generator Protection & Control System GEK-113285A...

  • Page 32: 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 33: 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 34: 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 35 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-113285A...

  • Page 36: 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 37 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 38 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 39 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 40 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 41 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 42 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 43 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 Level accuracy ±1% reading ±0.1% Full Scale from 10 to 500 V at nominal frequency...
  • Page 44 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 Level accuracy ±1% reading ±0.1% Full Scale from 10 to 500V at nominal frequency Trip delay 0.00 to 900.00 s.
  • Page 45 2.4 TECHNICAL SPECIFICATIONS 2 PRODUCT DESCRIPTION Level accuracy ±0.01 Hz of the reading 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 46: 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 47 2.4 TECHNICAL SPECIFICATIONS 2 PRODUCT DESCRIPTION Level Accuracy ±0.5% of the reading ± 10 mA from 0.05 to 10 A ±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 48 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 49 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 50 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 51: 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 52 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 53: 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 54: 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 55: Inputs

    2.4 TECHNICAL SPECIFICATIONS 2 PRODUCT DESCRIPTION 2.4.5.7 WAR-HOURS (POSITIVE AND NEGATIVE) Accuracy: ±1.0% of the reading Range: ±0 to 2147 MVArh 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 56 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 57: 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 Maximum Input Voltage: ± 24 V Formats: B000 (*) B001, B002 and B003 (*) (*) Signal combinations recognized in accordance with IRIG Standard 200-95 Isolation:...

  • Page 58: 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 59 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 Fiber type:...

  • Page 60: 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 61: 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 62: External Connections

    2 PRODUCT DESCRIPTION 2.5 EXTERNAL CONNECTIONS 2.5EXTERNAL CONNECTIONS Figure 2–3: G650 WIRING DIAGRAM (189C4216H17R1) GEK-113285A G650 Generator Protection & Control System 2-33...
  • Page 63 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 64: Hardware

    3 HARDWARE 3.1 MODULE DESCRIPTION MODULE DESCRIPTION 3 HARDWARE 3.1 Digital Optional Power Module Digital Supply SCREEN Figure 3–1: BLOCK DIAGRAM G650 units incorporate the following modules: • Power supply, which can be simple or redundant, depending on the selected model •...

  • Page 65: Power Supply

    3.2 POWER SUPPLY 3 HARDWARE 3.2POWER SUPPLY G650 can incorporate a simple or redundant power supply. The power supply module is fixed to the base plate using 4 screws, and the main and backup modules are identical. These modules work in parallel continuously, distributing the 50% of the load for each of them, thus ensuring greater reliability, and an instantaneous load transfer from the failed power supply to the other one, without loss of time or module reset.

  • Page 66: Mechanical Description

    3 HARDWARE 3.3 MECHANICAL DESCRIPTION 3.3MECHANICAL DESCRIPTION The model number and electrical characteristics of the unit are indicated on the label located on the right side of the relay case. The metallic case of the unit is highly resistant to corrosion. It is made of stainless steel (AISI 304), coated with an epoxy layer, and the rest of the metallic pieces are covered with a high quality resistive coating that has successfully passed at least 96 hours in the salt spray chamber (S/N ASTM B-117).
  • Page 67 3.3 MECHANICAL DESCRIPTION 3 HARDWARE 169 ( 6,65 ) 237 ( 9,30 ) (1,38) GE Multilin SIDE VIEW FRONT VIEW 210 ( 8,27 ) 186 ( 7,32 ) 4x O7 ( ,27 ) NOTE: All dimensions are shown in mm ( inches ).
  • Page 68 3 HARDWARE 3.3 MECHANICAL DESCRIPTION Figure 3–5: DIMENSIONS OF THE 19” RACKS 8U HIGH FOR TWO RELAYS GEK-113285A G650 Generator Protection & Control System...

  • Page 69: Rear Description

    3.3 MECHANICAL DESCRIPTION 3 HARDWARE 3.3.2 REAR DESCRIPTION WARNING Module withdrawal and insertion may only be performed when control power has been removed from the unit. Proper electrostatic discharge protection (i.e. a static wrap) must be used when coming in contact with products while the relay is energized.
  • Page 70 3 HARDWARE 3.3 MECHANICAL DESCRIPTION TYPE OF COMMUNICATION CONNECTOR RS485 / CAN cable Plug-in, 3 poles. IRIG B Plug-in, 2 poles. Plastic fiber optic Versatile Link Ethernet 10/100 UTP (10/100BaseTX) RJ45, Class 5. Glass fiber optic (100BaseFX) Ethernet 100 FX (100BaseFX) CAN Fiber Figure 3–7: COMMUNICATIONS MEDIA SELECTOR GUIDE Communication boards are installed at the rear part of the unit, the upper port being reserved for the asynchronous...
  • Page 71 3.3 MECHANICAL DESCRIPTION 3 HARDWARE A grounded antistatic wristband must be used when manipulating the module in order to avoid electrostatic discharges that may cause damage to the electronic components. Figure 3–9: REAR TERMINALS LOCATION G650 Generator Protection & Control System GEK-113285A...

  • Page 72: Wiring

    3 HARDWARE 3.4 WIRING 3.4WIRING 3.4.1 EXTERNAL CONNECTIONS G650 units can hold different options for F module: Board with 16 digital inputs and 8 outputs. Option 1: Board with 8 digital inputs, 4 circuit supervision inputs, 6 conventional outputs, and two current sensing Option 2: outputs Board with 32 digital inputs.

  • Page 73: Cable/Fiber Ethernet Board

    3.4 WIRING 3 HARDWARE 3.4.3 CABLE/FIBER ETHERNET BOARD The Ethernet board is the communication board 2 (COM3) shown in Figure 3–2:. It is located in the bottom at the rear part of the relay. In Models C and D, the 10/100BaseTX port is selected by an internal switch. To select between fiber and cable it is necessary to extract the board, switch the jumper to the selected position, as indicated on Figure 3–10: FIBER/CABLE SELECTION and insert the board again.
  • Page 74 3 HARDWARE 3.5 TRANSCEIVER OPTICAL POWER BUDGET VERSUS LINK LENGTH 3.5TRANSCEIVER OPTICAL POWER BUDGET VERSUS LINK LENGTH Optical Power Budget (OPB) is the available optical power for a fiber optic link to accommodate fiber cable losses plus losses due to in-line connectors, splices, optical switches, and to provide margin for link aging and unplanned losses due to cable plant reconfiguration and repair.
  • Page 75 3.5 TRANSCEIVER OPTICAL POWER BUDGET VERSUS LINK LENGTH 3 HARDWARE 3-12 G650 Generator Protection & Control System GEK-113285A...

  • Page 76: Human Interfaces

    4.1.2 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 77 4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.1.2.4 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 78: Main Screen

    4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 4.1.3 MAIN SCREEN The EnerVista 650 Setup software main window supports the following primary display components: • Title bar • Main menu bar • Main icon bar •...

  • Page 79: Communication Menu

    4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.1.4 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 80 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 4.1.4.1 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 81: File Management

    4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.1.5 FILE MANAGEMENT File management with EnerVista 650 Setup software: 4.1.5.1 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 82 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE Table 4–1: 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 83 4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.1.5.2 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 84 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE Table 4–2: 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 85: 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 86: File Menu Overview

    4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 4.1.7 FILE MENU OVERVIEW Table 4–4: 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 87 4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.1.7.1 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 88 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 4.1.7.2 CONFIG FILE (*650) CONVERTER Figure 4–6: 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 89 4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.1.7.4 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 90: Setpoint Menu Overview

    4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 4.1.8 SETPOINT MENU OVERVIEW Table 4–5: 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 91 4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 4 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 92 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE Table 4–9: 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 93 4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES Table 4–10: 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 94 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 4.1.8.4 CONTROL ELEMENTS This option shows all the control elements available in the relay as shown in Table 4–11:. Some of the elements are grouped ones such as underfrequency, overfrequency and broken conductor. Table 4–11: GENERAL OVERVIEW OF CONTROL ELEMENTS MENU: CONTROL ELEMENTS...
  • Page 95 4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 4 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 96 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE The following figures show an example of the default factory configuration for G650: Figure 4–9: RELAY CONFIGURATION GEK-113285A G650 Generator Protection & Control System 4-21...
  • Page 97 4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES Figure 4–10: HMI CONFIGURATION 4.1.8.7 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 4.1.5. File description: *.pep: Header for Logic project: PLC project file containing the necessary information relative to the relay model, logic...

  • Page 98: Actual Values Menu Overview

    4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 4.1.9 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 99 4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES Table 4–17: 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 100 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE Table 4–19: 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 101: Operations Menu Overview

    4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.1.9.5 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 4–22: GENERAL OVERVIEW OF RECORDS MENU: RECORDS (*) Event recorder (*)

  • Page 102: Communication Menu Overview

    4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 4.1.11 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 103 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 104 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.1 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 105: Security Menu Overview

    Table 4–27: 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 4-30 G650 Generator Protection &...

  • Page 106: Human Machine Interface (Hmi)

    4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.2 HUMAN MACHINE INTERFACE (HMI) 4.2 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 107: Front Led Indicators

    4.2 HUMAN MACHINE INTERFACE (HMI) 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.2.2 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 108: Front Port And Cover Sealing System

    4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.2 HUMAN MACHINE INTERFACE (HMI) 4.2.3.2 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 109: Text Menus

    4.2 HUMAN MACHINE INTERFACE (HMI) 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.2.5 TEXT MENUS 4.2.5.1 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 110 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.2 HUMAN MACHINE INTERFACE (HMI) 4.2.5.2 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 4–28: GENERAL OVERVIEW OF MAIN TEXT MENU: NAME DESCRIPTION...
  • Page 111 4.2 HUMAN MACHINE INTERFACE (HMI) 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.2.5.3 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 4–29: GENERAL OVERVIEW OF ACTUAL VALUES MAIN MENU: Front Panel >...
  • Page 112 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.2 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 113 4.2 HUMAN MACHINE INTERFACE (HMI) 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.2.5.4 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 114 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.2 HUMAN MACHINE INTERFACE (HMI) 4.2.5.5 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 115 4.2 HUMAN MACHINE INTERFACE (HMI) 4 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 116 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.2 HUMAN MACHINE INTERFACE (HMI) 4.2.5.6 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 4–30:. 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 117 4.2 HUMAN MACHINE INTERFACE (HMI) 4 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 118 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.2 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 119 4.2 HUMAN MACHINE INTERFACE (HMI) 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES MAIN SETTINGS MENU FIRST LEVEL SECOND LEVEL THIRD LEVEL Autoreclose Breaker Failure VT Fuse Failure. (Enhanced models only) 4-44 G650 Generator Protection & Control System GEK-113285A...
  • Page 120 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.2 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 121 4.2 HUMAN MACHINE INTERFACE (HMI) 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.2.5.7 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 4–30:. 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 122 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.2 HUMAN MACHINE INTERFACE (HMI) 4.2.5.8 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 123 4.2 HUMAN MACHINE INTERFACE (HMI) 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.2.5.9 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 124 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.2 HUMAN MACHINE INTERFACE (HMI) 4.2.5.10 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 125 [35c0] Cod Commands: [35c0] <Push Enter> 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. 4-50 G650 Generator Protection & Control System...
  • Page 126 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.2 HUMAN MACHINE INTERFACE (HMI) 4.2.5.11 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 127: Graphic Display

    4.2 HUMAN MACHINE INTERFACE (HMI) 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.2.6 GRAPHIC DISPLAY 4.2.6.1 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 128 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.2 HUMAN MACHINE INTERFACE (HMI) 4.2.6.2 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 129 4.2 HUMAN MACHINE INTERFACE (HMI) 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.2.6.3 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 130 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.2 HUMAN MACHINE INTERFACE (HMI) <DETAILS> 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 131 4.2 HUMAN MACHINE INTERFACE (HMI) 4 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. <AT>...
  • Page 132 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.2 HUMAN MACHINE INTERFACE (HMI) 4.2.6.5 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 133 4.2 HUMAN MACHINE INTERFACE (HMI) 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES <ACK ALL> 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 134 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.2 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 135 4.2 HUMAN MACHINE INTERFACE (HMI) 4 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 136: Web Server 4.3.1 Home

    4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.3 WEB SERVER 4.3 WEB SERVER 4.3.1 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 137: Snapshot Events

    4.3 WEB SERVER 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.3.2 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 138: Control Events

    4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.3 WEB SERVER 4.3.3 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 4–35: CONTROL EVENTS SCREEN Unlike the case of Snapshot events, in this screen the highest index corresponds to the most recent event.

  • Page 139: Alarms

    4.3 WEB SERVER 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.3.4 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 4–36: ALARMS SCREEN 4-64 G650 Generator Protection &...

  • Page 140: 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 141: Fault Report

    4.3 WEB SERVER 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.3.6 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 142: Data Logger

    4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.3 WEB SERVER 4.3.7 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 4–40: DATA LOGGER SCREEN GEK-113285A...

  • Page 143: Metering

    4.3 WEB SERVER 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.3.8 METERING This screen includes the primary metering values provided by the relay display. Figure 4–41: METERING SCREEN 4-68 G650 Generator Protection & Control System GEK-113285A...

  • Page 144: Settings

    5 SETTINGS 5.1 OVERVIEW 5 SETTINGS 5.1OVERVIEW 5.1.1 SETTING MAIN MENU Table 5–1: GENERAL OVERVIEW OF SETTING MAIN MENU IN ENERVISTA 650 SETUP: Product Setup Communication settings Serial Ports Network (Ethernet) ModBus Protocol DNP3 Slave IEC 870-5-104 SNTP ModBus User Map Fault Report Oscillography Data Logger...
  • Page 145 5.1 OVERVIEW 5 SETTINGS Voltage Elements Phase UV Phase OV Neutral OV High Negative Sequence OV Auxiliary OV Auxiliary UV Volts per Hertz. (Enhanced models only). Ground OV Power Directional Power Pwr Factor Limiting. (Enhanced models only) Control Elements Setting Group Underfrequency Overfrequency Synchrocheck...

  • Page 146: Product Setup

    5 SETTINGS 5.2 PRODUCT SETUP 5.2PRODUCT SETUP 5.2.1 COMMUNICATION SETTINGS 5.2.1.1 SERIAL PORTS Baud rate and parity for COM1 and COM2 serial communication ports. Table 5–2: SERIAL PORTS SETTINGS PRODUCT SETUP > COMMUNICATION SETTINGS >SERIAL PORTS Name Default Value Step Range COM1 Baud Rate 19200...
  • Page 147 5.2 PRODUCT SETUP 5 SETTINGS 5.2.1.4 DNP3 SLAVE Physical port, Slave Address for DNP, IP Addresses for Masters, TCP/UDP Port, Unsolicited Response parameters, Analog scale factors and deadbands, message fragment size, Binary input block. For more detailed information go to appendix C in this manual.
  • Page 148 5 SETTINGS 5.2 PRODUCT SETUP PRODUCT SETUP>COMMUNICATION SETTINGS >DNP3 SLAVE DNP3 SLAVE 1 > DNP3 SLAVE 2 > DNP3 SLAVE 3 Binary Input Block 6 CTL EVENTS 81-96 Binary Input Block 7 CTL EVENTS 97-112 Binary Input Block 8 CTL EVENTS 113-128 Binary Input Block 9 SWITCHGEAR 1-8 Binary Input Block 10...

  • Page 149: Modbus User Map

    5.2 PRODUCT SETUP 5 SETTINGS To use SNTP in anycast mode, set the Function setting to “ANYCAST”. Anycast mode is designed for use with a set of cooperating servers whose addresses are not known beforehand by the client. The G650 sends a request to a multicast group address assigned by IANA for NTP protocol.

  • Page 150: Fault Report

    5 SETTINGS 5.2 PRODUCT SETUP 5.2.3 FAULT REPORT 5.2.3.1 OVERVIEW The fault report module defines the type of fault (three-phase, phase-to-phase, phase-to-ground), and the distance to the fault. The fault activation signal (FAULT REPORT TRIGG) is programmed at “Setpoint > Relay Configuration > Protection Elements”.
  • Page 151 5.2 PRODUCT SETUP 5 SETTINGS 5.2.3.3 FAULT REPORT STATES States associated to the fault report (“Actual >Status>Records Status > Fault Reports”), are shown on Table 5–10: Table 5–10: FAULT REPORT STATES FAULT REPORT STATES FAULT REPORT TRIGG CLEAR FAULT REPORTS FAULT DATE FAULT TYPE FAULT LOCATION...

  • Page 152: Oscillography

    5 SETTINGS 5.2 PRODUCT SETUP 5.2.4 OSCILLOGRAPHY 5.2.4.1 OVERVIEW G650 elements allocate 1-Mbyte of memory for storing oscillography records. These oscillography records are stored in non-volatile memory. Oscillography records are stored in COMTRADE ASCII - IEEE C37.111-1999 standard format. The oscillography module is in charge of storing the instantaneous values of the 9 analog signals and the 16 programmable digital signals at Setpoint >...
  • Page 153 5.2 PRODUCT SETUP 5 SETTINGS 5.2.4.2 OSCILLOGRAPHY SETTINGS These settings (“Setpoint > Product Setup > Oscillography”) are described in Table 5–11: Table 5–11: OSCILLOGRAPHY SETTINGS SETPOINT > PRODUCT SETUP > OSCILLOGRAPHY Setting Description Name Default Value Step Range Function Permission Function ENABLED [DISABLED –...
  • Page 154 5 SETTINGS 5.2 PRODUCT SETUP 5.2.4.3 OSCILLOGRAPHY STATES States associated to the oscillography module (“Actual >Status>Records Status>Oscillography”), are shown in Table 5– Table 5–12: OSCILLOGRAPHY STATES OSCILLOGRAPHY STATES OSC DIG CHANNEL 1 OSC DIG CHANNEL 2 OSC DIG CHANNEL 3 OSC DIG CHANNEL 4 OSC DIG CHANNEL 5 OSC DIG CHANNEL 6...

  • Page 155: Data Logger

    Clicking on the “Download” button, the three files (*.DAT, *.HDR, *.CFG) that form the oscillography record in the COMTRADE standard will be retrieved, and they will be viewed automatically if the GE-OSC software is installed in the computer. Retrieved oscillographies can be viewed using any Comtrade viewer. The EnerVista 650 Setup software stores by default oscillography records in the folder “.\EnerVista 650 Setup\files\osc”, in the same directory where the program is...
  • Page 156 5 SETTINGS 5.2 PRODUCT SETUP 5.2.5.2 DATA LOGGER ASSOCIATED STATES States associated to the data logger module (“Actual >Status>Records Status>Data logger) are shown on the table below: Table 5–14: DATA LOGGER STATES DATA LOGGER STATES OLDEST SAMPLE TIME NEWEST SAMPLE TIME DATA LOGGER CHANNELS DATA LOGGER DAYS The Date/time of the oldest state with 6 characters.

  • Page 157: Demand

    5.2 PRODUCT SETUP 5 SETTINGS 5.2.6 DEMAND 5.2.6.1 METERING VALUES AND SETTINGS The demand calculation is made according to the following primary parameters: Table 5–15: PRIMARY DEMAND VALUES PRIMARY DEMAND VALUES STEP IA (RMS) IB (RMS) IC (RMS) IG (RMS) ISG (RMS) Three phase active power (W) Three phase reactive power (VAR)
  • Page 158 5 SETTINGS 5.2 PRODUCT SETUP Demand module settings are as follows: Table 5–17: DEMAND SETTINGS SETPOINT > PRODUCT SETUP > DEMAND Setting Description Name Default Value Step Range Function permission Demand Function DISABLED [DISABLED – ENABLED] Demand method for current values CRNT Demand Method THERMAL EXPONENTIAL [BLOCK INTERVAL - ROLLING DEMAND -...
  • Page 159 5.2 PRODUCT SETUP 5 SETTINGS Illustrated bellow is the curve with a 90% characteristic time of 15 minutes. A setting establishes the time to reach 90% of a steady-state value, just as the response time of an analog instrument. A steady-state valve applied for twice the response time will indicate 99% of the value.
  • Page 160 5 SETTINGS 5.2 PRODUCT SETUP Figure 5–1: shows the behavior of the demand, depending on the Selected setting for demand calculation. -0,2 Time (minutes) -0,2 Time (minutes) -0,2 Time (minutes) Block interval -0,2 Time (minutes) Rolling demand Figure 5–1: RESPONSE TO THE DIFFERENT DEMAND METHODS GEK-113285A G650 Generator Protection &...
  • Page 161 5.2 PRODUCT SETUP 5 SETTINGS 5.2.6.3 DEMAND FUNCTION MEASURES AND STATES Demand values are available at Actual > Metering > Primary Values > Demand. Table 5–18: DEMAND MEASURES NAME DEFAULT VALUE STEP DEMAND IA 0.000 DEMAND IA MAX 0.000 DEMAND IA DATE 01-Jan-2000 00:00:00.000 DEMAND IB 0.000...
  • Page 162 5 SETTINGS 5.2 PRODUCT SETUP Three-phase active power Three-phase reactive power Three-phase apparent power The maximum demanded value is stored in non-volatile memory. It is not cleared when the relay is turned off. When the relay is turned on again, the maximum values are updated. States associated to the demand (“Actual>Status>Records Status>Demand”) are the following: Table 5–19: DEMAND ASSOCIATED VALUES DEMAND ASOCIATED STATES...

  • Page 163: System Setup

    5.3 SYSTEM SETUP 5 SETTINGS 5.3SYSTEM SETUP This section shows the settings related to the system setup definition. 5.3.1 GENERAL SETTINGS This section determines the settings of the element configuration regarding its connection to the power system. Access to these settings using the EnerVista 650 Setup software is at Setpoint > System Setup > General settings. The corresponding settings are shown on the table below: Table 5–20: GENERAL SETTINGS SETPOINT >...
  • Page 164 5 SETTINGS 5.3 SYSTEM SETUP In the flex curves menu there are 120 points to define a user curve. 40 points for reset (from 0 to 0.98 times the pickup value) and 80 for operate (from 1.03 to 20 times the pickup). GEK-113285A G650 Generator Protection &...
  • Page 165 5.3 SYSTEM SETUP 5 SETTINGS Table 5–21: FLEX CURVE SETTINGS SETPOINT > SYSTEM SETUP > FLEX CURVES FLEX CURVES A > FLEX CURVES B> FLEX CURVES C > FLEX CURVES D Setting Description Name Default Value Step Range Values for reset points 0.00 pkp Time 0.00xPKP [RST] 0.000 0.001 s...

  • Page 166: Breaker

    5 SETTINGS 5.3 SYSTEM SETUP 5.3.3 BREAKER There are two types of breaker settings: Breaker settings: These settings correspond to the switchgear configured as a breaker in the G650; this switchgear is used in the recloser functions, breaker failure and synchronism. Breaker Maintenance: These settings correspond to the initialization of the (KI) t counters, and the counting of the number of openings and closings of the switchgear configured as a breaker.
  • Page 167 5.3 SYSTEM SETUP 5 SETTINGS 5.3.3.2 BREAKER MAINTENANCE To consider used breakers, the relay allows to set initial I t values as well as an initial number of operations, in order to take into account previous breaker operations, as well as operations produced during testing. Breaker maintenance parameters can be set in the breaker maintenance menu.

  • Page 168: Switchgear

    5 SETTINGS 5.3 SYSTEM SETUP (KI) t PHASE A Accumulated (KI) t value for phase A ((KI) t Counter for Phase A) (KI) t PHASE B Accumulated (KI) t value for phase B ((KI) t Counter for Phase B) (KI) t PHASE C Accumulated (KI) t value for phase C ((KI)

  • Page 169: Protection Elements

    5.4 PROTECTION ELEMENTS 5 SETTINGS 5.4PROTECTION ELEMENTS 5.4.1 CHANGE OF SETTING TABLES IN G650 ELEMENTS G650 relays incorporate the following protection elements: CURRENT ELEMENTS Instantaneous overcurrent: 3 x PHASE IOC HIGH (50PH) 3 x NEUTRAL IOC (50N) 3 x GROUND IOC (50G) 3 x SENSITIVE GROUND IOC (50SG) (Enhanced models only) Time delayed overcurrent: 3 x PHASE TOC HIGH (51PH)
  • Page 170 5 SETTINGS 5.4 PROTECTION ELEMENTS 3 x VOLTS PER HERTZ (24) (Enhanced models only) POWER 3 x DIRECTIONAL POWER (32) 3 x PWR FACTOR LIMITING (55) (Enhanced models only) The G650 elements incorporate also the following control elements: 1 x SETTINGS GROUP 3 x OVERFREQUENCY (81O) 3 x UNDERFREQUENCY (81U) 1 x SYNCHROCHECK(25)
  • Page 171 5.4 PROTECTION ELEMENTS 5 SETTINGS The distribution of protection elements in tabled groups is described in Table 5–27: Table 5–27: DISTRIBUTION OF PROTECTION AND CONTROL ELEMENTS DEVICE NUMBER FUNCTION TABLE 1 TABLE 2 TABLE 3 24 Volt/Hertz (only enhanced model) 1x24 1x24 1x24...
  • Page 172 5 SETTINGS 5.4 PROTECTION ELEMENTS Function: Possible values are: [DISABLED – ENABLED] When this setting is disabled, the relay is working in single setting group mode, with all the available protection elements working at the same time. If this function is enabled, the setting groups will be enabled, and only the setting group indicated by the Active Group setting will be active.

  • Page 173: Inverse Time Curves Characteristics

    5.4 PROTECTION ELEMENTS 5 SETTINGS 5.4.2 INVERSE TIME CURVES CHARACTERISTICS Inverse time curves available in time overcurrent elements are as follows: IEEE extremely/very/moderately inverse IEC Curve A/B/C/Long-Time Inverse/ Short-Time Inverse IAC extremely/very/moderately inverse ANSI extremely/very/normally/moderately inverse Definite time curves Rectifier time curves User Curve - FlexCurve A/B/C/D Recloser Curves The saturation level for the user curve is 20 times the pickup value, for the rest of time overcurrent elements the...
  • Page 174 5 SETTINGS 5.4 PROTECTION ELEMENTS Table 5–29: CONSTANTS FOR IEEE CURVES IEEE CURVE SHAPE NAME IEEE Extremely Inverse IEEE Ext Inv 28.2 0.1217 2.0000 29.1 IEEE Very Inverse IEEE Very Inv 19.61 0.491 2.0000 21.6 IEEE Inverse IEEE Mod Inv 0.0515 0.1140 0.0200...
  • Page 175 5.4 PROTECTION ELEMENTS 5 SETTINGS 5.4.2.2 IEC CURVES This family of curves follows the European standard IEC 255-4, and the British standard BF142 for IEC Curves A, B and C, IEC Long-Time Inverse and IEC Short-Time Inverse. The formulas that define these curves are as follows: Where: t = Operation time in seconds Dial = multiplying factor...
  • Page 176 5 SETTINGS 5.4 PROTECTION ELEMENTS Table 5–32: TRIPPING TIME IN SECONDS FOR IEC CURVES DIAL CURRENT (I/ITAP) 10.0 IEC Curve A 0.05 0.860 0.501 0.315 0.249 0.214 0.192 0.176 0.165 0.156 0.149 0.10 1.719 1.003 0.630 0.498 0.428 0.384 0.353 0.330 0.312 0.297...
  • Page 177 5.4 PROTECTION ELEMENTS 5 SETTINGS 5.4.2.3 IAC CURVES This family of curves follows the time response of the General Electric IAC electromechanical relays. The following formulas define these curves: Where: t = Operation time in seconds Dial = multiplier setting I = Input current Itap = Current pickup value A, B, C, D, E = predefined constants...
  • Page 178 5 SETTINGS 5.4 PROTECTION ELEMENTS Table 5–34: TRIPPING TIMES IN SECONDS FOR IAC CURVES DIAL CURRENT (I/ITAP) 10.0 IAC Extremely Inverse 1.699 0.749 0.303 0.178 0.123 0.093 0.074 0.062 0.053 0.046 3.398 1.498 0.606 0.356 0.246 0.186 0.149 0.124 0.106 0.093 6.796 2.997...
  • Page 179 5.4 PROTECTION ELEMENTS 5 SETTINGS 5.4.2.4 ANSI CURVES This family of curves complies with the American Standard ANSI C37.90 for Extremely inverse, Very inverse, Normally inverse and Moderately inverse curves. The formulas that define these curves are as follows: where: T = Operation time (in seconds).
  • Page 180 5 SETTINGS 5.4 PROTECTION ELEMENTS Table 5–36: TRIPPING TIMES IN SECONDS FOR ANSI CURVES DIAL CURRENT (I/ITAP) 10.0 ANSI Extremely inverse 0.50 2.000 0.872 0.330 0.184 0.124 0.093 0.075 0.063 0.055 0.049 1.00 4.001 1.744 0.659 0.368 0.247 0.185 0.149 0.126 0.110 0.098...
  • Page 181 5.4 PROTECTION ELEMENTS 5 SETTINGS 5.4.2.5 I2T CURVES The following formulas define this type of curves: where: t = Operation time in seconds Dial = multiplier setting I = Input current Itap = Current pickup value = reset time in seconds RESET Table 5–37: TRIPPING TIME IN SECONDS FOR I2T CURVES DIAL...
  • Page 182 5 SETTINGS 5.4 PROTECTION ELEMENTS 5.4.2.8 USER CURVES - FLEXCURVES A/B/C/D The relay incorporates 4 user curves called User Curve A, B, C and D. The points for these curves are defined by the user. Each of the four curves has an operation characteristic (operate), defined by 80 points, and a reset characteristic, defined by 40 points.

  • Page 183: Phase Current

    5.4 PROTECTION ELEMENTS 5 SETTINGS 5.4.3 PHASE CURRENT The G650 Phase current menu incorporates the following overcurrent elements: Phase time overcurrent (51PH/51PL) Phase instantaneous overcurrent (50PH) Generator Thermal Model (49S) 5.4.3.1 PHASE TIME DELAYED OVERCURRENT ELEMENTS – PHASE HIGH/LOW (51PH/51PL) The phase overcurrent element (51P) operates in a time period that depends on the applied current and on the set curve.
  • Page 184 5 SETTINGS 5.4 PROTECTION ELEMENTS Table 5–39: PHASE TIME OVERCURRENT SETTINGS 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 SETTING DESCRIPTION NAME DEFAULT VALUE...
  • Page 185 5.4 PROTECTION ELEMENTS 5 SETTINGS The following diagram shows the logic scheme followed by high range and low range time overcurrent elements (51PH and 51PL) in the following figure Figure 5–5: TOC ELEMENT LOGIC SCHEME (A6632F2) 5-42 G650 Generator Protection & Control System GEK-113285A...
  • Page 186 5 SETTINGS 5.4 PROTECTION ELEMENTS 5.4.3.2 PHASE INSTANTANEOUS OVERCURRENT ELEMENT- PHASE HIGH (50PH) The Phase instantaneous overcurrent element has a setting range from 0.05 A to 160 A. It can be set as instantaneous or timed, with the timer selectable between 0.00 and 900 seconds. The input quantities may be chosen as Fundamental phasor magnitude or RMS magnitude as required by the application.
  • Page 187 5.4 PROTECTION ELEMENTS 5 SETTINGS The following figure shows the logic scheme diagram for high range and low range Instantaneous overcurrent elements (50PH). Figure 5–6: PHASE IOC ELEMENTS LOGIC SCHEME (A6632F1) 5-44 G650 Generator Protection & Control System GEK-113285A...
  • Page 188 5 SETTINGS 5.4 PROTECTION ELEMENTS 5.4.3.3 GENERATOR THERMAL MODEL ELEMENT (49S) This unit provides protection against overheating due to overloading conditions. The operating time curve is set from the time curve family available, as a function of the time constant ô1 (settable between 3 and 600 minutes). The cooling time constant ô2 can be set between 1 and 6 times the heating time constant ô1.
  • Page 189 5.4 PROTECTION ELEMENTS 5 SETTINGS 5.4.4 NEUTRAL CURRENT The Neutral Current menu incorporates the following overcurrent elements: • Neutral time overcurrent (51N) • Neutral instantaneous overcurrent (50N) • Neutral directional element (67N) 5.4.4.1 NEUTRAL TIME DELAYED OVERCURRENT ELEMENT (51N) Neutral TOC is a neutral time delayed overcurrent protection element. This element uses as the input quantity the neutral current, calculated from the phase currents.
  • Page 190 5 SETTINGS 5.4 PROTECTION ELEMENTS The following figure shows the logic scheme for the neutral Instantaneous overcurrent element. Figure 5–7: LOGIC SCHEME FOR NEUTRAL IOC ELEMENT GEK-113285A G650 Generator Protection & Control System 5-47...
  • Page 191 5.4 PROTECTION ELEMENTS 5 SETTINGS 5.4.4.3 NEUTRAL DIRECTIONAL ELEMENT (67N) The Neutral directional element is used for supervising the neutral (3I0) overcurrent elements. This element can be set to use either the neutral voltage, or the polarization current measured by the 5 current input (Ip), or both as polarization magnitude.

  • Page 192: Neutral Current

    5 SETTINGS 5.4 PROTECTION ELEMENTS The Neutral directional element is an independent Protection element that provides Block and Operation signals. These signals can be monitored both through the relay HMI or using EnerVista 650 Setup at “Actual > Status > Protection > Neutral Current”...
  • Page 193 5.4 PROTECTION ELEMENTS 5 SETTINGS Figure 5–8: shows the Operation of the directional element for a Phase A to Ground fault, where the Phase A current grows in magnitude and is delayed with respect to its voltage by an angle similar to the protected line. Va voltage decreases or can even disappear if the fault is close and the fault resistance is very low.
  • Page 194 5 SETTINGS 5.4 PROTECTION ELEMENTS b) CURRENT POLARIZATION OPERATION PRINCIPLES: Operation Magnitude: In = calculated from phase currents. Polarization Magnitude: Ip, measured at input terminals B11-B12. To perform a directional comparison by current, the polarization magnitude used is the current measured at the relay Ip input, terminals B11-B12, with input or “positive”...

  • Page 195: Ground Current

    5.4 PROTECTION ELEMENTS 5 SETTINGS Table 5–47: QUANTITIES POLARIZING MODE DIRECTION COMPARED PHASORS FORWARD Io x 1 MTA VOLTAGE (Vo) REVERSE -Io x 1 MTA FORWARD CURRENT (Ip) REVERSE - Vo FORWARD Vo + Ip - Vo REVERSE - Vo FORWARD Vo * Ip - Vo...
  • Page 196 5 SETTINGS 5.4 PROTECTION ELEMENTS 5.4.5.2 GROUND INSTANTANEOUS OVERCURRENT ELEMENT (50G) Ground IOC is a ground instantaneous overcurrent protection element, with a setting range from 0.05 A to 160 A, which can also be time delayed. The delay is selectable between 0.00 and 900 seconds. The ground current input quantity is measured from the ground input, and it may be programmed as Fundamental phasor magnitude or RMS magnitude as required by the application.
  • Page 197 5.4 PROTECTION ELEMENTS 5 SETTINGS Table 5–51: USED MAGNITUDES ACCORDING TO THE POLARIZATION SETTING POLARIZATION SETTING OPERATION MAG. POLARIZATION MAG. Vo + Ip 3V0 or Isg Vo * Ip 3V0 and Isg The following table shows the management of the element output signals (block and permission) depending on the Polarization Type setting.
  • Page 198 5 SETTINGS 5.4 PROTECTION ELEMENTS Table 5–53: QUANTITIES POLARIZING MODE DIRECTION COMPARED PHASORS FORWARD Io x 1 MTA VOLTAGE (Vo) REVERSE -Io x 1 MTA FORWARD CURRENT (Ip) REVERSE - Vo FORWARD Vo + Ip - Vo REVERSE - Vo FORWARD Vo * Ip - Vo...

  • Page 199: Restricted Ground Fault (Only For Enhanced Models)

    5.4 PROTECTION ELEMENTS 5 SETTINGS 5.4.6 RESTRICTED GROUND FAULT (ONLY FOR ENHANCED MODELS) G650 provides the possibility of having a RGF (Restricted Ground Fault) function, only available for Enhanced models (please see ordering code). This RGF function is based in the comparison of the neutral current calculated from phase currents with ground current measured from the fourth current input (B9-B10).
  • Page 200 5 SETTINGS 5.4 PROTECTION ELEMENTS Figure 5–10: RESTRICTED GROUND FAULT ALGORITHM The elements used in the 87G algorithm are listed in Table 5–55: and Table 5–56: Table 5–55: RGF ALGORITHM ELEMENT INPUTS Input Comment Idiffg Differential Ground Current Imax Maximum phase current Table 5–56: RGF ALGORITHM ELEMENT OUTPUTS Output Comment...
  • Page 201 5.4 PROTECTION ELEMENTS 5 SETTINGS Table 5–58: RESTRICTED GROUND FAULT INTERNAL STATES RESTRICTED GROUND FAULT INTERNAL STATES RESTR GND FLT1 PKP RESTR GND FLT1 OP RESTR GND FLT2 PKP RESTR GND FLT2 OP RESTR GND FLT3 PKP RESTR GND FLT3 OP 5.4.6.1 RESTRICTED GROUND FAULT SETTINGS EXAMPLE SETPOINT >...

  • Page 202: Sensitive Ground Current (Only For Enhanced Models)

    5 SETTINGS 5.4 PROTECTION ELEMENTS 5.4.7 SENSITIVE GROUND CURRENT (ONLY FOR ENHANCED MODELS) The G650 Sensitive ground Current menu incorporates the following overcurrent elements: • Sensitive ground time overcurrent (51SG) • Sensitive ground instantaneous overcurrent (50SG) 5.4.7.1 SENSITIVE GROUND TIME DELAYED OVERCURRENT ELEMENT (51SG) Sensitive Ground TOC is a sensitive ground time delayed overcurrent protection element with a setting range 0.005A to 16A.

  • Page 203: Negative Sequence Current

    5.4 PROTECTION ELEMENTS 5 SETTINGS 5.4.8 NEGATIVE SEQUENCE CURRENT The Negative sequence menu incorporates the following elements: • Negative sequence time overcurrent (51-2) • Negative sequence instantaneous overcurrent (50-2) • Generator unbalance (46) 5.4.8.1 NEGATIVE SEQUENCE OVERCURRENT ELEMENT (51-2) Negative Sequence TOC is an overcurrent protection element that uses the fundamental phasor of the negative sequence current as input magnitude, calculated from the phase currents.
  • Page 204 5 SETTINGS 5.4 PROTECTION ELEMENTS 5.4.8.3 GENERATOR UNBALANCE (46) The generator unbalance element protects the machine from rotor damage due to excessive negative sequence current. Negative sequence current is used as operation element. The element has an inverse time stage (stage 1), typically used for tripping, and a definite time stage (stage 2) typically used for alarm purposes.
  • Page 205 5.4 PROTECTION ELEMENTS 5 SETTINGS Table 5–63: GENERATOR UNBALANCE ELEMENT SETTINGS SETPOINT > PROTECTION ELEMENTS > NEGATIVE SEQUENCE CURRENT > GENERATOR UNBALANCE > GENERATOR UNBALANCE 1> GENERATOR UNBALANCE 2 > GENERATOR UNBALANCE 3 SETTING DESCRIPTION NAME DEFAULT VALUE STEP RANGE Function Permision Function DISABLED...

  • Page 206: Voltage Elements

    5 SETTINGS 5.4 PROTECTION ELEMENTS Figure 5–11: GENERATOR UNBALANCE ALGORITHM 5.4.9 VOLTAGE ELEMENTS The G650 incorporates the following voltage elements: • Phase undervoltage (27P) • Phase overvoltage (59P) • Neutral overvoltage (59NH) • Negative sequence overvoltage (47) • Auxiliary overvoltage (59X) •...
  • Page 207 5.4 PROTECTION ELEMENTS 5 SETTINGS These elements can also be set as inverse time curves. This family of curves is defined by the following formula: − Vpickup Where: T = operation time D = operation time setting (delay) V = voltage applied to the relay Vpickup = pickup setting (Pickup level) Figure 5–12: INVERSE TIME UNDERVOLTAGE CURVES 5.4.9.1 PHASE UNDERVOLTAGE ELEMENT (27P)
  • Page 208 5 SETTINGS 5.4 PROTECTION ELEMENTS Table 5–65: 27P ELEMENT SETTINGS SETPOINT > PROTECTION ELEMENTS > VOLTAGE ELEMENTS > PHASE UV > PHASE UV 1> PHASE UV 2 > PHASE UV 3 SETTING DESCRIPTION NAME DEFAULT STEP RANGE VALUE Function permission Function DISABLED [DISABLED –...
  • Page 209 5.4 PROTECTION ELEMENTS 5 SETTINGS Table 5–66: 59P ELEMENT SETTINGS SETPOINT > PROTECTION ELEMENTS > VOLTAGE ELEMENTS > PHASE OV > PHASE OV 1> PHASE OV 2 > PHASE OV 3 SETTING DESCRIPTION NAME DEFAULT STEP RANGE VALUE Function permission Function DISABLED [DISABLED –...
  • Page 210 5 SETTINGS 5.4 PROTECTION ELEMENTS Table 5–67: 59NHELEMENT SETTINGS SETPOINT > PROTECTION ELEMENTS > VOLTAGE ELEMENTS > >NEUTRAL OV HIGH > NEUTRAL OV HIGH 1> NEUTRAL OV HIGH 2 > NEUTRAL OV HIGH 3 SETTING DESCRIPTION NAME DEFAULT VALUE STEP RANGE Function permission Function...
  • Page 211 5.4 PROTECTION ELEMENTS 5 SETTINGS 5.4.9.6 AUXILIARY UNDERVOLTAGE ELEMENT (27X) This is an Auxiliary undervoltage element for general use that uses as its input magnitude the voltage measured by the 4 VT, terminals A11-A12 (when VX is selected as Auxiliary Voltage in General Settings). Table 5–70: 27X ELEMENT SETTINGS SETPOINT >...
  • Page 212 5 SETTINGS 5.4 PROTECTION ELEMENTS The 1 pu value for V/Hz operation is the Nominal Voltage setting divided by the Nominal Frequency setting adjusted in the General Settings menu. The characteristics of the inverse curves are shown below: • DEFINITE TIME: T (sec) = TD Multiplier. •...
  • Page 213 5.4 PROTECTION ELEMENTS 5 SETTINGS Table 5–71: VOLTS PER HERTZ ELEMENT SETTINGS SETPOINT > PROTECTION ELEMENTS > VOLTAGE ELEMENTS > VOLTS PER HERTZ > VOLTS PER HERTZ 1> VOLTS PER HERTZ 2 > VOLTS PER HERTZ 3 SETTING DESCRIPTION NAME DEFAULT VALUE STEP RANGE...

  • Page 214: Power

    5 SETTINGS 5.4 PROTECTION ELEMENTS Table 5–73: 59G ELEMENT SETTINGS SETPOINT > PROTECTION ELEMENTS > VOLTAGE ELEMENTS > GROUND OV > GROUND OV 1> GROUND OV 2 > GROUND OV 3 SETTING DESCRIPTION NAME DEFAULT VALUE STEP RANGE Function permission Function DISABLED [DISABLED –...
  • Page 215 5.4 PROTECTION ELEMENTS 5 SETTINGS Figures (a, b, c, d, e, f) below shows settings for different power applications. Figure 5–14: DIRECTIONAL POWER ELEMENT SAMPLE APPLICATIONS By adding 90º to the angles shown on figures a, b, c and d, the represented elements would be similar but with Reactive Power instead of Active Power.
  • Page 216 5 SETTINGS 5.4 PROTECTION ELEMENTS We would obtain a mixed Protection Between figure (d) and figure (e). b) SETTINGS Table 5–74: 32 ELEMENT SETTINGS SETPOINT > PROTECTION ELEMENTS > POWER > DIRECTIONAL POWER> DIRECTIONAL POWER 1> DIRECTIONAL POWER 2 > DIRECTIONAL POWER 3 SETTING DESCRIPTION NAME DEFAULT...
  • Page 217 5.4 PROTECTION ELEMENTS 5 SETTINGS The following figure illustrates the conventions established: Figure 5–15: ANGLES 5-74 G650 Generator Protection & Control System GEK-113285A...
  • Page 218 5 SETTINGS 5.4 PROTECTION ELEMENTS Stage (1 - 2) Tap: This setting specifies the minimum Operation three-phase power for the Stage 1 (2) element. The power value defined in this setting is the minimum distance between the source and the directional power characteristic. This value can be positive or negative.
  • Page 219 5.4 PROTECTION ELEMENTS 5 SETTINGS 5.4.10.2 POWER FACTOR LIMITING (55).(FOR ENHANCED MODELS ONLY) This element allows the user to protect the machine against power factor values out of limits. The element has two stages which can be used as alarm or as trip. Table 5–75: POWER FACTOR LIMITING ELEMENT SETTINGS SETPOINT >...

  • Page 220: Control Elements

    5 SETTINGS 5.5 CONTROL ELEMENTS 5.5CONTROL ELEMENTS The G650 incorporates the following control elements: Setting Group Underfrequency Overfrequency Synchrocheck (25) Breaker Failure (50BF) (enhanced models only) VT Fuse Failure (enhanced models only) Pulse Counters Analog Comparators Frequency Rate of Change (81 df/dt) Phase Shift or Loss of Mains (78V) (enhanced models only) Loss of Excitation (40) Accidental Energization (50/27)

  • Page 221: Underfrequency Element (81U)

    5.5 CONTROL ELEMENTS 5 SETTINGS 5.5.2 UNDERFREQUENCY ELEMENT (81U) Setpoint >Control Elements > Underfrequency The steady-state frequency of a power system is a certain indicator of the existing balance between the generated power and the load. Whenever this balance is disrupted through the loss of an important generating unit, the effect will be a reduction in frequency.

  • Page 222: Synchronism Check Element - Synchrocheck (25)

    5 SETTINGS 5.5 CONTROL ELEMENTS 5.5.4 SYNCHRONISM CHECK ELEMENT - SYNCHROCHECK (25) Note: The Switchgear element used in the G650 synchronism element is the one configured in the Number of Switchgear setting inside Breaker settings, at “Setpoint > System Setup > Breaker > Breaker Settings”. WARNING When testing this function do not forget that the relay must detect an open breaker to operate.
  • Page 223 5.5 CONTROL ELEMENTS 5 SETTINGS 5.5.4.1 VOLTAGE INPUTS In order to perform the synchronism check function, the G650 uses only one voltage from each end of the breaker. Voltage values to be compared must be on the same basis, either phase-to-phase or phase-to-ground voltage; they must be the same at both ends of the breaker;...
  • Page 224 5 SETTINGS 5.5 CONTROL ELEMENTS 5.5.4.3 SETTINGS Setpoint > Control Elements > Synchrocheck There is only one synchrocheck element in the G650. Table 5–81: 25 ELEMENT SETTINGS SETPOINT > CONTROL ELEMENTS > SYNCHROCHECK SETTING DESCRIPTION NAME DEFAULT STEP RANGE VALUE Function permission Function DISABLED...
  • Page 225 5.5 CONTROL ELEMENTS 5 SETTINGS This time is considered if the relative slip is higher than 5 mHz; in this case, an anticipative algorithm is executed to calculate the closing signal with the necessary advance for the breaker effective Closing to be produced when voltages are in phase.
  • Page 226 5 SETTINGS 5.5 CONTROL ELEMENTS 5.5.4.4 SYNCHROCHECK STATES Internal signals provided by the G650 (Actual> Status > Control Elements > Synchrocheck) for the synchronism element are as follows: Table 5–82: SYNCHROCHECK INTERNAL STATES SYNCHROCHECK ACTUAL VALUES SYNCROCHECK BLK INP SYNCROCHECK OP SYNCHK CLOSE PERM SYNCROCHECK COND OP DL-DB OPERATION...
  • Page 227 5.5 CONTROL ELEMENTS 5 SETTINGS Actual> Metering > Frequency Line frequency in Hz Line Frequency (Hz) Bus frequency in Hz Bus Frequency (Hz) The voltage angles can be obtained in primary metering values (Actual> Metering > Primary Values > Voltage), being the line voltage angle, the one that corresponds to the voltage set in the frequency reference in General settings (please refer to the voltage correspondence table (Table 5–80:), and the angle of the busbar voltage the one that corresponds to Vx Angle, when the Auxiliary Voltage setting as been selected as V...
  • Page 228 5 SETTINGS 5.5 CONTROL ELEMENTS Table 5–83: SYNCHRONISM CONDITIONS SYNCHRONISM SITUATION SYNCHRONISM CLOSING LOGIC LINE VOLTAGE BUSBAR VOLTAGE CHECK LEVELS LEVELS (1) V < (V & V )< V Not permitted Not permitted V1 > dead line level V2 > dead bus level V1 <...
  • Page 229 5.5 CONTROL ELEMENTS 5 SETTINGS Δϕ Phase Angle Difference In the live line-live bus Condition, once the voltage difference has been successfully verified in magnitude, the system establishes the angle difference between both voltage phasors. If the angle difference is lower than the Δϕ (Max Angle Difference) setting, then the system will verify the frequency slip S (Max Freq Difference).
  • Page 230 5 SETTINGS 5.5 CONTROL ELEMENTS The Closing process using anticipative algorithm is described on the following figure: V’ Figure 5–18: ANTICIPATIVE ALGORITHM Where: Referenced phasor (the one with lower frequency) Actual voltage phasor (the one with lower frequency) Calculated voltage phasor, depending on the set breaker closing time (anticipative algorithm) V’...

  • Page 231: Breaker Failure Element (50Bf) (Enhanced Models Only)

    5.5 CONTROL ELEMENTS 5 SETTINGS 5.5.5 BREAKER FAILURE ELEMENT (50BF) (ENHANCED MODELS ONLY) Note: The Switchgear element used in the Breaker Failure element is the one configured in the Number of Switchgear setting, inside Breaker settings at Setpoint > Protection Elements > Breaker > Breaker settings The breaker failure element is used to determine when a trip command sent to a breaker has not been executed within a selectable delay.
  • Page 232 5 SETTINGS 5.5 CONTROL ELEMENTS Signals relative to breaker failure provided by the relay can be viewed at Actual> Status > Control Elements > Breaker Failure, and they are as follows: Table 5–85: BREAKER FAILURE STATUS BREAKER FAILURE STATUS BKR FAIL INITIATE BKR FAIL NO CURRENT BKR FAIL SUPERVISION BKR FAIL HISET...
  • Page 233 5.5 CONTROL ELEMENTS 5 SETTINGS The following figure shows the logic scheme for the breaker failure element: Figure 5–20: LOGIC SCHEME FOR 50BF The breaker failure element has three levels. The first one is called “Retrip” or “Supervision”. This operation level can be used to give a signal to the breaker on which the initial opening has been executed.

  • Page 234: Vt Fuse Failure Element (Vtff) (Enhanced Models Only)

    5 SETTINGS 5.5 CONTROL ELEMENTS 5.5.6 VT FUSE FAILURE ELEMENT (VTFF) (ENHANCED MODELS ONLY) Note: The Switchgear element used in the VT Fuse Failure element is the one configured in the Number of Switchgear setting, inside Breaker settings at Setpoint > Protection Elements > Breaker > Breaker settings. This switchgear must have previously been configured at Setpoint >...

  • Page 235: Pulse Counters

    5.5 CONTROL ELEMENTS 5 SETTINGS Figure 5–21: FUSE FAILURE ELEMENT BLOCK DIAGRAM 5.5.7 PULSE COUNTERS The G650 includes eight pulse counters, each pulse counter stores the activation number of the input set to that pulse counter. This value can be multiplied for a factor selectable by setting. The inputs used in this pulse counter function can be selected from all the available in the G650 device.
  • Page 236 5 SETTINGS 5.5 CONTROL ELEMENTS It is the maximum value set as result of the CntPulses Factor plus the number of CntPulses Overflow: inputs activation. This means that after reaching that value, the pulse counter value will start counting from zero. Board selection for the pulse counter input.

  • Page 237: Analog Comparators

    5.5 CONTROL ELEMENTS 5 SETTINGS 5.5.8 ANALOG COMPARATORS The G650 provides 20 different analog comparators in an analog comparator module located in the control elements part of the device. Each analog comparator gives indication when the analog variable selected is inside or outside some minimum and maximum threshold values.

  • Page 238: Frequency Rate Of Change

    5 SETTINGS 5.5 CONTROL ELEMENTS Table 5–90: ANALOG COMPARATOR STATUS ANALOG COMPARATORS STATUS Analog Level 01 Analog Level 02 Analog Level 03 Analog Level 04 Analog Level 05 Analog Level 06 Analog Level 07 Analog Level 08 Analog Level 09 Analog Level 10 Analog Level 11 Analog Level 12...
  • Page 239 5.5 CONTROL ELEMENTS 5 SETTINGS Frequency rate of change settings are: Rate of Change Function: This setting allows enabling or disabling the frequency rate of change element. Freq rate trend: This setting allows to configure the element in order to answer to increasing, decreasing or both directions frequency changes.

  • Page 240: Loss Of Mains (78V) (For Enhanced Models)

    5 SETTINGS 5.5 CONTROL ELEMENTS 5.5.10 LOSS OF MAINS (78V) (FOR ENHANCED MODELS) 5.5.10.1 INTRODUCTION The Phase Shift or Loss of main element (78V) measures the length of each cycle of the voltage signal. When a generator becomes disconnected, the sudden change in load causes a sudden change in cycle length. The single cycle becomes shifted with time.Therefore the 78V element can be used to detect disconnection from the grid.
  • Page 241 5.5 CONTROL ELEMENTS 5 SETTINGS Table 5–95: LOSS OF MAINS INTERNAL SIGNALS Signal Comment LOSS OF MAINS 1 (2, 3,) BLOCK Input used to block externally the Loss of mains (1, 2, 3) element LOSS OF MAINS 1 (2, 3,) A OP Output used to indicate a loss of mains in phase A in the (1, 2, 3) elements LOSS OF MAINS 1 (2, 3,) B OP...

  • Page 242: Loss Of Excitation (40)

    5 SETTINGS 5.5 CONTROL ELEMENTS 5.5.11 LOSS OF EXCITATION (40) This function is used to detect loss of excitation on synchronous machines. It includes two mho characteristics looking into the machine, each with adjustable reach, center, and time delay. Excitation can be lost due to inadvertent tripping of the field breaker, open or short circuit on the field winding, regulator failure, or loss of the source to the field winding.
  • Page 243 5.5 CONTROL ELEMENTS 5 SETTINGS Table 5–96: LOSS OF EXCITATION ELEMENT SETTINGS SETPOINT > CONTROL ELEMENTS > LOSS OF EXCITATION > LOSS OF EXCITATION 1> LOSS OF EXCITATION 2 > LOSS OF EXCITATION 3 SETTING DESCRIPTION NAME DEFAULT VALUE STEP RANGE Function Permission Function...

  • Page 244: Accidental Energization (50/27)

    5 SETTINGS 5.5 CONTROL ELEMENTS Figure 5–24: LOSS OF EXCITATION LOGIC SCHEME 5.5.12 ACCIDENTAL ENERGIZATION (50/27) This element provides a protection against the generator energization while the generator is at standstill or reduced speed. This function is armed using either the AND or OR combination of the undervoltage and machine off-line conditions, selected with the ACCDNT ENGR ARMING MODE setting.
  • Page 245 5.5 CONTROL ELEMENTS 5 SETTINGS • Ph Undervoltage pickup: This setting specifies the voltage level required to arm the accidental energization element. All of the line-to-line voltages must drop below the 'Ph Undervoltage pickup' level in order to detect the undervoltage condition.

  • Page 246: Inputs/Outputs

    5 SETTINGS 5.6 INPUTS/OUTPUTS 5.6INPUTS/OUTPUTS 5.6.1 INPUT/OUTPUT PLACEMENT MIXED SUPERVISION INPUTS ANALOG TERMINALS COIL 1 CC1 52/a CC2 COIL 1 CC3 52/b CC4 COMMON 1/8 COMMON 1/4 COMMON 1/8 COMMON 1/8 COMMON 9/16 COMMON 5/8 COMMON 9/16 COMMON 9/16 CC10 CC10 CC10 CC11...

  • Page 247: Control Settings For Inputs/Outputs

    5.6 INPUTS/OUTPUTS 5 SETTINGS 5.6.2 CONTROL SETTINGS FOR INPUTS/OUTPUTS Configuration of settings relative to inputs and outputs can only be accessed through the EnerVista 650 Setup software, and not via the HMI. For this purpose, the user must access Setpoint > Inputs/Outputs > Contact I/O > Board X, being X the corresponding I/O board.
  • Page 248 5 SETTINGS 5.6 INPUTS/OUTPUTS For the I/O board selection in the relay model, associated digits to each board type are as follows: Table 5–102: I/O BOARD TYPE ASSOCIATED DIGIT ENERVISTA 650 SETUP BOARD SETTINGS BOARD TYPE NONE None 16 INP+ 8OUT Mixed 8 INP +8 OUT +SUPV Supervision...

  • Page 249: Inputs

    5.6 INPUTS/OUTPUTS 5 SETTINGS 5.6.3 INPUTS 5.6.3.1 INPUT SETTINGS DESCRIPTION Input Activation Voltage Threshold: The range of this value goes from 20 to 230 volts. There is a single setting for all inputs in the same group (inputs sharing the same common). In mixed and supervision boards there are two groups of inputs, called A and B., in 32DI board there are four groups of 8 inputs each.
  • Page 250 5 SETTINGS 5.6 INPUTS/OUTPUTS 5.6.3.2 INPUT STATUS SIGNALS Actual > Inputs/Outputs > Contact inputs > Board X (being X the corresponding board in each case). Depending on the I/O board, inputs are represented as follows: Table 5–103: CONTACT INPUTS STATUS INPUT STATUS MIXED AND ANALOG BOARD SUPERVISION BOARD...

  • Page 251: Outputs

    5.6 INPUTS/OUTPUTS 5 SETTINGS 5.6.4 OUTPUTS 5.6.4.1 OUTPUT SETTINGS DESCRIPTION Output Logic_0X _0Z: Type of logic applied to outputs. Possible values are positive and negative. The default value is positive. Depending on the type of setting selected, the physical output will be in the same direction (positive) or opposite (negative) the output activation command.
  • Page 252 5 SETTINGS 5.6 INPUTS/OUTPUTS 5.6.4.2 OUTPUT STATUS SIGNALS Boards types 1 and 2 have both 8 outputs, so the representation is the same for both types as shown in Table 5–104: Actual > Inputs/Outputs >Contact Output Status Real status of the contact output, which corresponds to the transformation of the output activation signal (Contact output operate), by the logic applied to this output in “Setpoint >...

  • Page 253: Circuit Supervision And Contact Seal-In Circuits

    5.6 INPUTS/OUTPUTS 5 SETTINGS 5.6.5 CIRCUIT SUPERVISION AND CONTACT SEAL-IN CIRCUITS Circuit Supervision: G650 elements can include supervision boards (type 2), either in their internal slot F, or in an additional CIO module connected to the element via a CAN Bus (slots H and J). This type of board includes 4 voltage detectors for implementing tripping or opening circuit supervision control logics.
  • Page 254 5 SETTINGS 5.6 INPUTS/OUTPUTS In order to implement these schemes, it is not necessary to set any setting in the element. Internal functions are always operative and provide the following logic operands: Table 5–105: SUPERVISION LOGIC OPERANDS ACTUAL > INPUTS/OUTPUTS > CONTACT INPUTS > BOARD X BEING X THE CORRESPONDING BOARD IN EACH CASE OPERAND DESCRIPTION...
  • Page 255 5.6 INPUTS/OUTPUTS 5 SETTINGS b) WITHOUT SUPERVISION This is a very frequent common case, and we must only wire the tripping circuit to terminals F35 and F36, leaving unused terminals F34, F15, F16, F17, F18. Figure 5–30: CIRCUIT WITHOUT TRIPPING CIRCUIT SUPERVISION (A6631F1) 5-112 G650 Generator Protection &...
  • Page 256 5 SETTINGS 5.6 INPUTS/OUTPUTS c) WITH CURRENT SUPERVISION (WITH SEAL-IN) In this case, as shown in Figure 5–31:, the current supervision circuit consists of a circuit connected in series with the output contact, so that the external circuit is wired to terminals F34 and F36. This supervision circuit includes a low impedance reed relay that is activated when the current value exceeds 200 mA, and sends a signal to the main microprocessor.
  • Page 257 5.6 INPUTS/OUTPUTS 5 SETTINGS d) WITH SIMPLE VOLTAGE SUPERVISION Figure 5–32: SUPERVISION APPLICATION WITH AUXILIARY CONTACT 52A AND A RESISTOR (A6631F3) Table 5–106: SUPERVISION WITH 52/A INTERNAL STATE V 52/A SUPERVISION 52 open 52 closed TRIP OK if t < 0.5 s TRIP with 52 open OK if t <...
  • Page 258 5 SETTINGS 5.6 INPUTS/OUTPUTS Table 5–107: SUPERVISION ALGORITHM WITH SIMPLE VOLTAGE SUPERVISION SCHEME STATUS OF INVOLVED ELEMENTS INPUT TO G650 DECISION CIRCUIT OUTPUT BREAKER OPERAND OPERAND STATUS STATUS STATUS CONT IP_X_CC11 CONT IP_X_CC16 (F35-F36) (VA_COIL2) (SUP_COIL2) V 52/A (F15-F16) Healthy Open 52 closed Healthy...
  • Page 259 5.6 INPUTS/OUTPUTS 5 SETTINGS Figure 5–33: shows the possibility of monitoring the circuit only when the breaker is closed. In this case resistance R will not be used, but it must be observed in the element logic that the corresponding signal CONT IP_F_CC16 (SUP_COIL2) will be activated showing a failure when the breaker is open.
  • Page 260 5 SETTINGS 5.6 INPUTS/OUTPUTS e) WITH DOUBLE VOLTAGE SUPERVISION Figure 5–34: SUPERVISION APPLICATION WITH AUXILIARY CONTACTS 52A AND 52B (A6631F4) GEK-113285A G650 Generator Protection & Control System 5-117...
  • Page 261 5.6 INPUTS/OUTPUTS 5 SETTINGS Table 5–108: SUPERVISION ALGORITHM WITH DOUBLE VOLTAGE SUPERVISION SCHEME STATUS OF INVOLVED ELEMENTS INPUTS TO 650 DECISION CIRCUIT OUTPUT BREAKER STATUS OPERAND OPERAND OPERAND STATUS STATUS CONT IP_X_CC11 CONT IP_X_CC12 CONT IP_X_CC16 (F35-F36) (VA_COIL2) (VB_COIL2) (SUP_COIL2) V 52/A (F15-F16) V 52/B (F17-F18) Healthy...
  • Page 262 5 SETTINGS 5.6 INPUTS/OUTPUTS f) WITH DOUBLE VOLTAGE SUPERVISION AND SERIAL RESISTOR IN VOLTAGE MONITORS. Figure 5–35:shows the supervision scheme with an external resistor. An external series resistor is used with the 52a voltage monitor to prevent CB tripping with a short-circuited voltage monitor. With CB open, 52/a is open and 52/b is closed.

  • Page 263: Analog Boards Specific Settings

    5.6 INPUTS/OUTPUTS 5 SETTINGS 5.6.6 ANALOG BOARDS SPECIFIC SETTINGS Hardware and software is provided to receive signals from external transducers and convert these signals into a digital format for use as required. The relay will accept inputs in the range of –1 to +20 mA DC, suitable for use with the most common transducer output ranges;...

  • Page 264: Virtual Outputs

    5 SETTINGS 5.6 INPUTS/OUTPUTS 5.6.7.2 VIRTUAL INPUTS STATUS MONITORING: Actual > Inputs/Outputs > Virtual Inputs > Virtual Input Latched > Virtual Input Self-Reset Table 5–109: VIRTUAL INPUTS STATUS VIRTUAL INPUTS LATCHED VIRTUAL INPUTS SELF-RESET LATCHED VIRT IP 1 SELF-RST VIRT IP 1 LATCHED VIRT IP 2 SELF-RST VIRT IP 2 …...

  • Page 265: Testing

    5.7 TESTING 5 SETTINGS 5.7TESTING 5.7.1 FORCE IO–INPUT TESTING The input testing can only be performed in relay with graphical display, see the human interfaces section in this manual for more detailed information. 5.7.2 FORCE IO–OUTPUT TESTING Output testing can be performed via HMI in models with graphical display and via communications through EnerVista 650 Setup in all models.

  • Page 266: Relay Configuration

    5 SETTINGS 5.8 RELAY CONFIGURATION 5.8RELAY CONFIGURATION Setpoint > Relay Configuration This is the relay configuration section in which the relay can be configured (all input/output and LEDs configuration, protection elements signals, graphic display configuration, etc.) using internal states or already compiled equation on PLC Editor (see section 5.9).
  • Page 267 5.8 RELAY CONFIGURATION 5 SETTINGS Figure 5–38: OUTPUTS CONFIGURATION 5-124 G650 Generator Protection & Control System GEK-113285A...

  • Page 268: Leds

    5 SETTINGS 5.8 RELAY CONFIGURATION 5.8.2 LEDS G650 has 15 LEDs fully configurable from any logical variable, contact or virtual input. The first five are latched by hardware, the rest are self-reset but can be latched through PLC configuration. This window displays the entire relay LEDs with the following setting options for each of them: •...

  • Page 269: Operations

    5.8 RELAY CONFIGURATION 5 SETTINGS 5.8.3 OPERATIONS This menu option shows the settings for the 24 control operations that can be programmed, as follows: • Select checkbox enables the desired operation. • Command Text setting defines the command name. • Interlocks Type setting defines the desired interlock type (An interlock is a condition that must be fulfilled for an operation to be performed).
  • Page 270 5 SETTINGS 5.8 RELAY CONFIGURATION • COM1 (REMOTE) setting: defines whether the operation can be executed by communications through the rear port COM1. • COM2 (LOCAL) setting: defines whether the operation can be executed by communications through the rear port COM2.
  • Page 271 5.8 RELAY CONFIGURATION 5 SETTINGS 5.8.3.1 HOW TO PROGRAM AN OPERATION Example of how to program an operation to close a breaker with an operating time of 90 ms (closing), incorporating 52/b contacts to indicate the change of position, using an interlock logic to enable the operation if there is no autoreclose in progress.
  • Page 272 5 SETTINGS 5.8 RELAY CONFIGURATION This is done in the menu Setpoint > Relay Configuration > Output, selecting an output and choosing the internal signal OPERATION BIT 1, which corresponds to the bit that is activated when the related operation is executed. Figure 5–42: CONTACT OUTPUT CONFIGURATION Note: Operations time out for confirmation Configurable screen in graphical HMI: In the relay HMI the configurable objects wait one minute for confirmation after...

  • Page 273: Protection Elements

    5.8 RELAY CONFIGURATION 5 SETTINGS 5.8.4 PROTECTION ELEMENTS This tab allows assigning operands (logic signals) as inputs to different protection elements. This way, the user assigns etc. In this screen we can also configure a logic signal to perform the LED reset by communications. The settings are as follows: •...
  • Page 274 5 SETTINGS 5.8 RELAY CONFIGURATION Figure 5–43: PROTECTION ELEMENTS GEK-113285A G650 Generator Protection & Control System 5-131...

  • Page 275: Oscillography

    5.8 RELAY CONFIGURATION 5 SETTINGS 5.8.5 OSCILLOGRAPHY This menu is used for selecting the digital channels to be included in oscillography records, and the oscillo trigger signal. As for the above-described settings, the trigger selection can be any of the signals provided by the relay or a logic combination of these.

  • Page 276: Control Events

    5 SETTINGS 5.8 RELAY CONFIGURATION 5.8.6 CONTROL EVENTS This menu is used for defining the CONTROL EVENTS, up to 128 user programmable events. A control event is a logic signal associated to an operand or combination of operands which monitories the change of status of the logic operand.
  • Page 277 5.8 RELAY CONFIGURATION 5 SETTINGS The Alarm panel can be displayed in: HMI screen for models with graphical display. EnerVista 650 Setup: Actual>Event Recorder>Alarm Panel for all models. Web Server application: http://xxx. xxx. xxx. xxx /Alarms.htm for all models. If the event is not selected as an alarm, it can be viewed as an event at: HMI screen for all models in snapshot event screen (with default text).

  • Page 278: Switchgear

    5 SETTINGS 5.8 RELAY CONFIGURATION 5.8.7 SWITCHGEAR This menu is used for defining the SWITCHGEAR elements to be controlled by the relay. A switchgear element can be a breaker, a line selector switch, a grounding selector switch, a busbar selector switch, etc. It is possible to define up to 16 switchgear elements.
  • Page 279 5.8 RELAY CONFIGURATION 5 SETTINGS Figure 5–46: SWITCHGEAR CONFIGURATION Note: when a switchgear device is only monitored (open init and closing init signals are not used), it is not possible to distinguish between the fail to open or fail to close time, the time used to give an error 00 or 11 signal is the maximum of the opening and closing time configured for that switchgear.

  • Page 280: Hmi (Human-Machine Interface)

    5 SETTINGS 5.8 RELAY CONFIGURATION 5.8.8 HMI (HUMAN-MACHINE INTERFACE) This menu shows a scenario to draw a simplified one-line diagram of a bay in a feeder, line, transformer, etc. The menu includes a library for power elements, metering elements, text and drawings. To use the drawing toolbar elements, the desired element must be select with the mouse and then click on the yellow area.
  • Page 281 5.8 RELAY CONFIGURATION 5 SETTINGS Table 5–112: ACTIVE SYMBOLS CONFIGURABLE IN ONE-LINE DIAGRAM FOR GRAPHICAL HMI ACTIVE SYMBOLS ICONS IN SCREEN DESCRIPTION STANDARD AND IEC 1082-1 SWITCHGEAR SYMBOLS SWITCHGEAR SYMBOLS M and C selection for graphic display option in the ordering code STANDARD SWITCHGEAR SYMBOLS These symbols correspond to switchgear elements: breaker (square) and selector switch (rhombus), in vertical and horizontal positions.
  • Page 282 5 SETTINGS 5.8 RELAY CONFIGURATION ACTIVE SYMBOLS ICONS IN SCREEN DESCRIPTION DATE AND TIME SYMBOL Symbol used for displaying in the HMI the date and time provided by the device. OPERATIONS SYMBOL This symbol indicates the possibility to configure and execute operations on the graphic display.
  • Page 283 5.8 RELAY CONFIGURATION 5 SETTINGS Table 5–113: GRAPHIC AND TEXT EDITION SYMBOLS GRAPHIC AND TEXT EDITION SYMBOLS ICONS IN SCREEN DESCRIPTION AVAILABILITY Ground symbols in different positions. The first two are not available in the N model (IEC selection). Voltage Transformers representation Only for standard model M.

  • Page 284: Logic Configuration (Plc Editor)

    5 SETTINGS 5.9 LOGIC CONFIGURATION (PLC EDITOR) 5.9LOGIC CONFIGURATION (PLC EDITOR) Setpoint > Logic Configuration The G650 logic allows setting the relay logic configuration using a sophisticated and complete program based on standard IEC 61131-3, with block diagrams, which is described in this section. 5.9.1 INTRODUCTION The logic configuration (or PLC Editor) tool is a graphical design tool that allows the G650 built complex logic diagram in an easy way using different logic functions.

  • Page 285: Theory Of Operation

    5.9 LOGIC CONFIGURATION (PLC EDITOR) 5 SETTINGS 5.9.2 THEORY OF OPERATION 5.9.2.1 DESCRIPTION As already mentioned in the introduction, this tool uses FBD mode of IEC 61131-3 standard. For this purpose we have defined a series of basic operations with illustrations below. The basic operations available in PLC Editor are located in the tool bar of the application and are as follows: Table 5–114: PLC EDITOR BASIC OPERATION IN G650...
  • Page 286 5 SETTINGS 5.9 LOGIC CONFIGURATION (PLC EDITOR) Example of logic signals in G650 logic configuration: Table 5–115: LOGIC SIGNALS IN G650 LOGIC SIGNALS EXAMPLES SIGNAL DESCRIPTION TIME DIAGRAM When the input signal is set to 1 the output signal Input remain fixed to 1 till a reset signal is received.
  • Page 287 5.9 LOGIC CONFIGURATION (PLC EDITOR) 5 SETTINGS 5.9.2.2 LOGIC COMPILATION The G650 configuration will be made using the basic operations related before and more complex operations can be developed inside libraries. All the graphical configuration performed in the Logic configuration editor must be read and interpreted by the PLC as the G650 engine.

  • Page 288: Main Menu

    5 SETTINGS 5.9 LOGIC CONFIGURATION (PLC EDITOR) 5.9.3 MAIN MENU The PLC Editor tool (Setpoint > Logic Configuration) provides a main menu with different submenus (File, Project, Edit, Run, View, and Window) that allows the user to built customized logic for the G650 devices. 5.9.3.1 FILE MENU The FILE menu includes the following options: allows to create a new project that will include the files of the logic configuration...

  • Page 289: Configuration Generation

    5.9 LOGIC CONFIGURATION (PLC EDITOR) 5 SETTINGS 5.9.3.5 VIEW MENU The VIEW menu includes the following options: Displays in one screen the status name and time stamp of the digital statuses Log: configured in the PLC logic (still not available). Displays the values for the different project inputs, outputs, and variables (still not Debug-Release window: available).

  • Page 290: Generation Of Libraries

    5 SETTINGS 5.9 LOGIC CONFIGURATION (PLC EDITOR) 5.9.4.7 ADD A LIBRARY Click on the “LIB” button and select the corresponding file. Users can build their own libraries and distribute them in their projects in an easy way. The manufacturer provides default libraries such as ORs, ANDs of 3 up to 8 inputs, besides timers (pickup-dropout) and key examples.

  • Page 291: Example Of Application

    5.9 LOGIC CONFIGURATION (PLC EDITOR) 5 SETTINGS Once the library is created and saved it can be selected in the main application menu in Project > Insert Library. The library will have the following object: Figure 5–51: LIBRARY OBJECT 5.9.6 EXAMPLE OF APPLICATION In this section a simple logic application is described step by step, a logic is such that keeping one digital input activated, several outputs will be activated and deactivated in a time window (outputs will remain activated for 200 ms and deactivated for 5 ms).
  • Page 292 5 SETTINGS 5.9 LOGIC CONFIGURATION (PLC EDITOR) After creating the first timer, the second one for output deactivation is made. The set signal will be the virtual output created as an output of the first timer (VO_100_OUTPUT_ACTIVATION), the reset signal will be the output of the second timer (VO_100_OUTPUT_DEACTIVATION), the time delay is set as 200 ms.
  • Page 293 5.9 LOGIC CONFIGURATION (PLC EDITOR) 5 SETTINGS 5-150 G650 Generator Protection & Control System GEK-113285A...

  • Page 294: Actual Values

    6 ACTUAL VALUES 6.1 FRONT PANEL 6 ACTUAL VALUES 6.1FRONT PANEL The menu bar in the main screen of EnerVista 650 Setup software shows the ACTUAL menu option. This option concentrates and displays all status of protection, control elements, metering, counters information, oscillography, events, fault locator, etc.

  • Page 295: Status

    6.2 STATUS 6 ACTUAL VALUES 6.2STATUS 6.2.1 OPERATION BITS (Actual > Status > Operation bits) OPERATION BIT 1...24 These 24 bits are the outputs of each possible Operation modules, programmed in menu Setpoint > Relay Configuration > Operations. The light up LED indicates their status 1 (activation) Table 6–2: OPERATION BITS OPERATION BITS...

  • Page 296: Protection

    6 ACTUAL VALUES 6.2 STATUS 6.2.3 PROTECTION 6.2.3.1 PROTECTION BLOCKS (Actual > Status > Protection > Protection Blocks) This screen shows the entire protection element blocks available. If the protection element is blocked, the green LED located on the right side of the text will light up and will remain lit as long as the element remains blocked. Protection elements block signals are configured at Setpoint >...
  • Page 297 6.2 STATUS 6 ACTUAL VALUES 6.2.3.2 PHASE CURRENT This screen shows the pickup and trip for all phase instantaneous and time overcurrent elements in the G650 and block and operation signals provided by the phase directional units. Any of these two events of any phase element will light up the corresponding LED in this screen, and it will remain lit as the associated function remains in pickup or operation.
  • Page 298 6 ACTUAL VALUES 6.2 STATUS 6.2.3.3 NEUTRAL CURRENT This screen shows the pickup and trip for all neutral instantaneous and time overcurrent elements in the G650 and block and operation signals provided by the neutral directional units. Any of these two events of any neutral element will light up the corresponding LED in this screen, and it will remain lit as the associated function remains in pickup or operation.
  • Page 299 6.2 STATUS 6 ACTUAL VALUES 6.2.3.5 SENSITIVE GROUND CURRENT(ENHANCED MODELS ONLY) This screen shows the pickup and trip for all sensitive ground instantaneous and time overcurrent elements in the G650 . Any of these two events of any ground element will light up the corresponding LED in this screen, and it will remain lit as the associated function remains in pickup or operation.
  • Page 300 6 ACTUAL VALUES 6.2 STATUS 6.2.3.6 NEGATIVE SEQUENCE CURRENT This screen shows the pickup and trip for negative sequence elements in the G650. Any of these two events of any ground element will light up the corresponding LED in this screen, and it will remain lit as the associated function remains in pickup or operation.
  • Page 301 6.2 STATUS 6 ACTUAL VALUES Table 6–10: THERMAL MODEL ACTUAL VALUES THERMAL IMAGE RESET THERMAL IMAGE THERMAL IMAGE THERMAL IMAGE SIGNALS ALARM SIGNALS OPERATION SIGNALS VALUE IN % THERMAL1 49S RST THERMAL1 49S ALARM THERMAL1 49S OP THERMAL IMAGE1 THERMAL2 49S RST THERMAL2 49S ALARM THERMAL2 49S OP THERMAL IMAGE2...
  • Page 302 6 ACTUAL VALUES 6.2 STATUS 6.2.3.8 VOLTAGE This screen shows the activation of all voltage elements available in the G650. It can be accessed from the menu: Actual > Status > Protection > Voltage, and it includes the following signaling LEDs. The values shown are: Pickup and operation signals for phase to ground and phase-to-phase undervoltage elements and the three-phase signal for pickup and operation for the undervoltage element.
  • Page 303 6.2 STATUS 6 ACTUAL VALUES Note (*): Only available for enhanced models (see ordering code) 6-10 G650 Generator Protection & Control System GEK-113285A...
  • Page 304 6 ACTUAL VALUES 6.2 STATUS 6.2.3.9 POWER Directional power and power factor elements These functions may have several applications, for example, small generating plants connected to the power system, to limit the supplied power and not to exceed its rated capacity. If programmed conditions for any of the three elements are met, the corresponding LEDs will light up.

  • Page 305: Control Elements

    6.2 STATUS 6 ACTUAL VALUES 6.2.4 CONTROL ELEMENTS 6.2.4.1 FREQUENCY G650 units incorporate three overfrequency and three underfrequency units as well as three frequency rate of change units. For each of them there are two magnitudes pickup and trip (operation). Frequency elements are often used in generating plants, as well as in the connection of substations to the main system.
  • Page 306 6 ACTUAL VALUES 6.2 STATUS General Closing permission of the Synchronism unit. It contemplates all possible SYNCHK CLOSE PERM: situations, live line-live bus conditions, and the closing permission logics (dead line- dead bus, live line- dead bus, dead line-live bus). Note: in case the Function is disabled, the Closing permission signal will be activated in order not to interfere with possible logics where it is included.
  • Page 307 6.2 STATUS 6 ACTUAL VALUES 6.2.4.3 BREAKER FAILURE(ENHANCED MODELS ONLY) This screen can be accessed at Actual> Status > Control Elements > Breaker Failure, and it includes the following signaling LEDs for the breaker failure function: Table 6–15: BREAKER FAILURE ACTUAL VALUES BREAKER FAILURE ACTUAL VALUES BKR FAIL INITIATE BKR FAIL NO CURRENT...
  • Page 308 6 ACTUAL VALUES 6.2 STATUS Table 6–18: PULSE COUNTERS ACTUAL VALUES PULSE COUNTERS ACTUAL VALUES CntPulses Value 1 CntPulses Value 2 CntPulses Value 3 CntPulses Value 4 CntPulses Value 5 CntPulses Value 6 CntPulses Value 7 CntPulses Value 8 CntPulses Freeze 1 CntPulses Freeze 2 CntPulses Freeze 3 CntPulses Freeze 4...
  • Page 309 6.2 STATUS 6 ACTUAL VALUES 6.2.4.7 ANALOG COMPARATORS G650 units incorporate 20 analog comparators. This screen can be accessed from the menu: Actual> Status > Control Elements >Analog Comparators and it includes the following signalling LEDs showing the ON/ OFF status of the analog level. Table 6–19: ANALOG COMPARATORS ACTUAL VALUES ANALOG COMPARATORS ACTUAL VALUES Analog Level 01...
  • Page 310 6 ACTUAL VALUES 6.2 STATUS 6.2.4.9 LOSS OF EXCITATION This screen can be accessed at Actual> Status > Control Elements > Loss of Excitation, and it includes the following signaling LEDs for the Loss of Excitation function: LOSS OF EXCITATION ACTUAL VALUES LOSS OF EXCITATION ACTUAL VALUES LOSS OF EXC1 ST1 PKP LOSS OF EXC1 STG1 OP...
  • Page 311 6.2 STATUS 6 ACTUAL VALUES 6.2.4.10 ACCIDENTAL ENERGIZATION This screen can be accessed at Actual> Status > Control Elements > Accidental Energization and it includes offline, armed and operation signals for the Accidental Energization elements in the following signaling LEDs: Table 6–21: ACCIDENTAL ENERGIZATION ACTUAL VALUES ACCIDENTAL ENERGIZATION ACTUAL VALUES ACCDNT ENRG1 OFFLINE...
  • Page 312 6 ACTUAL VALUES 6.2 STATUS 6.2.5 PROTECTION SUMMARY Actual > Status > Protection Summary . This screen shows a complete listing of all protection and control elements in the relay, showing their status (enabled or not) through the corresponding LED. Table 6–22: PROTECTION SUMMARY PROTECTION SUMMARY Phase IOC1 High...
  • Page 313 6.2 STATUS 6 ACTUAL VALUES Phase OV2 Phase OV3 Auxiliary OV1 Auxiliary OV2 Auxiliary OV3 Negative Sequence TOC1 Negative Sequence TOC2 Negative Sequence TOC3 Overfrequency1 Overfrequency2 Overfrequency3 Underfrequency1 Underfrequency2 Underfrequency3 Oscillography Fault Report Demand Phase TOC1 Low Phase TOC2 Low Phase TOC3 Low Data Logger Directional Power1...

  • Page 314: Protection Summary

    6 ACTUAL VALUES 6.2 STATUS PROTECTION SUMMARY (CONT.) Frequency rate1 Frequency rate2 Frequency rate3 Restricted Ground Fault1 (*) Restricted Ground Fault2 (*) Restricted Ground Fault3 (*) Loss of Mains1 (*) Loss of Mains2 (*) Loss of Mains3 (*) Generator Unbalance1 Generator Unbalance2 Generator Unbalance3 Volts per Hz1 (*)

  • Page 315: Snapshot Events Summary

    6.2 STATUS 6 ACTUAL VALUES 6.2.6 SNAPSHOT EVENTS SUMMARY Actual > Status > Snapshot Event Summary The G650 provides via setting the possibility to enable or disable the snapshot event generation in the different functions available in the device. This screen shows a complete listing of the snapshot event generation for all the protection, control and inputs/outputs elements in the relay, showing their status (enabled or not) through the corresponding LED.
  • Page 316 6 ACTUAL VALUES 6.2 STATUS Switchgear1 Event Switchgear2 Event Switchgear3 Event Switchgear4 Event Switchgear5 Event Switchgear6 Event Switchgear7 Event Switchgear8 Event Switchgear9 Event Switchgear10 Event Switchgear11 Event Switchgear12 Event Switchgear13 Event Switchgear14 Event Switchgear15 Event Switchgear16 Event Breaker Settings Event Directional Power1 Event Directional Power2 Event Directional Power3 Event...

  • Page 317: Modbus User Map

    6.2 STATUS 6 ACTUAL VALUES Ground OV2 Event Ground OV3 Event (*) Note: Available for enhanced models only (please see ordering code). 6.2.7 MODBUS USER MAP The ModBus User Map consists of a selection of the most important 256 records in the complete ModBus Map regarding the application.
  • Page 318 6 ACTUAL VALUES 6.2 STATUS SWITCH X OPEN Lights up when the associated switchgear is open SWITCH X CLOSED Lights up when the associated switchgear is closed SWITCH X 00_ERROR Output that represents the Switchgear status 00, considered as abnormal. SWITCH X 11_ERROR Output that represents the Switchgear status 11, considered as abnormal.

  • Page 319: Calibration

    6.2 STATUS 6 ACTUAL VALUES FACTORY CALIBRATION: This value will be active when the relay calibration settings are the default values (no calibration). Error shown when there is a problem in the calibration settings (wrong values). CALIBRATION ERROR: 6-26 G650 Generator Protection & Control System GEK-113285A...

  • Page 320: Flex Curves

    6 ACTUAL VALUES 6.2 STATUS 6.2.10 FLEX CURVES This screen can be accessed at Actual> Status > Flex Curves, and it includes the internal flex curves status. If the LED associated to the FlexCurve status is lit up, this indicates that the user curve has been configured with new values (not default values).
  • Page 321 6.2 STATUS 6 ACTUAL VALUES 6.2.12.2 CONTROL EVENTS Actual> Status > Records Status > Control Events In this screen Actual> Status > Records Status > Control Events, the status of the signals configured to launch the control events can be seen, activated or not. The G650 provides the possibility to configure 128 control events (at Settings>Relay Configuration >...
  • Page 322 6 ACTUAL VALUES 6.2 STATUS 6.2.12.4 DATA LOGGER Actual> Status > Records Status > Data Logger Table 6–31: DATA LOGGER STATUS DATA LOGGER OLDEST SAMPLE TIME NEWEST SAMPLE TIME DATA LOGGER CHANNELS DATA LOGGER DAYS Date and time of the oldest value stored in the data logger. OLDEST SAMPLE TIME: Date and time of the most recent value stored in the data logger NEWEST SAMPLE TIME:...
  • Page 323 6.2 STATUS 6 ACTUAL VALUES 6.2.12.7 BREAKER MAINTENANCE Actual> Status > Records Status > Breaker Maintenance This screen shows the breaker status related to breaker maintenance. Other statuses are provided in the different switchgear or breaker status signals. Table 6–34: BREAKER MAINTENANCE STATUS BREAKER MAINTENANCE INPUTS RESET KI2t COUNTERS RESET BKR COUNTERS...
  • Page 324 6 ACTUAL VALUES 6.2 STATUS 6.2.12.8 SNTP/IRIGB Actual > Status > SNTP/IRIGB This screen shows if the relay is synchronized by external devices using or SNTP protocol or IRIGB input port. In case of relays synchronized by both elements at the same time, IRIGB time will be used by the relay. Table 6–35: SNTP-IRIG-B ACTUAL VALUES SNTP-IRIGB ACTUAL VALUES SNTP FAILURE...

  • Page 325: Metering

    6.3 METERING 6 ACTUAL VALUES 6.3METERING Values shown in each section are as follows: 6.3.1 PRIMARY VALUES 6.3.1.1 CURRENT Actual> Metering > Primary Values > Current Table 6–36: CURRENT PRIMARY VALUES DESCRIPTION UNITS CT Ratio CT Ratio Ig CT Ratio Isg Ia Angle Ib Angle Ic Angle...
  • Page 326 6 ACTUAL VALUES 6.3 METERING 6.3.1.2 VOLTAGE Actual> Metering > Primary Values > Voltage Table 6–37: VOLTAGE PRIMARY VALUES DESCRIPTION UNITS PT Ratio Va Angle Vb Angle Vc Angle Vn Angle Vx Angle Vab Angle Vbc Angle Vca Angle Vg Angle V0 Primary V1 Primary V2 Primary...
  • Page 327 6.3 METERING 6 ACTUAL VALUES ments of single phase power value cannot be duly calculated, and therefore, its value will be zero. Measurement for single phase power value only will be provided when Wye connection is selected or when Delta connection and VN as Auxiliary Voltage is selected in General Settings main menu.
  • Page 328 6 ACTUAL VALUES 6.3 METERING DEMAND VA PWR DEMAND VA MAX DEMAND VA DATE dd/mm/yy hh:mm:ss:ms GEK-113285A G650 Generator Protection & Control System 6-35...

  • Page 329: Secondary Values

    6.3 METERING 6 ACTUAL VALUES 6.3.2 SECONDARY VALUES 6.3.2.1 CURRENT Actual> Metering > Secondary Values > Current Table 6–41: CURRENT SECONDARY VALUES DESCRIPTION UNITS Phasor Ia RMS Ia Phasor Ib RMS Ib Phasor Ic RMS Ic Phasor In Phasor Ig RMS Ig Phasor Isg RMS Isg...
  • Page 330 6 ACTUAL VALUES 6.3 METERING 6.3.2.3 POWER Actual> Metering > Secondary Values > Power Table 6–43: POWER SECONDARY VALUES DESCRIPTION UNITS Phase A Apparent Pwr Phase B Apparent Pwr Phase C Apparent Pwr Phase A Real Pwr Phase B Real Pwr Phase C Real Pwr Phase A Reactive Pwr VARS...

  • Page 331: Phasor Diagram

    6.3 METERING 6 ACTUAL VALUES 6.3.3 PHASOR DIAGRAM Actual> Metering > Phasor Diagram This window shows the phasors for voltage and current values, phase to phase, phase to ground and sequence values, provided by the unit. The angles provided by the unit are clockwise, all the angles are positive values, so for a system Va (0,0°), Vb (0,-120°), Vc (0,120°) the relay will provided the following angles Va (0,0°), Vb (0,120°), Vc (0,240°).

  • Page 332: Contact Inputs

    6 ACTUAL VALUES 6.4 INPUTS / OUTPUTS 6.4INPUTS / OUTPUTS Digital inputs and outputs are located in the same board. Depending on the relay model, the number of inputs and outputs will vary. 6.4.1 CONTACT INPUTS Actual > Inputs/Outputs > Contact inputs > Board X (being X the corresponding board in each case). On the inputs screen, the LED associated to the activated input will light up in green, if an input is not activated, the LED will not light up.

  • Page 333: Contact Output Status

    6.4 INPUTS / OUTPUTS 6 ACTUAL VALUES 6.4.2 CONTACT OUTPUT STATUS Actual > Inputs/Outputs > Contact Output Status > Board X (being X the corresponding board in each case). The corresponding Outputs screen will display the activation of a contact output by lighting up in green the associated LED. Boards types 1 and 2 have both 8 outputs, so the representation is the same for both types as shown in Table 6–46: This screen shows the real status of the contact output, which corresponds to the transformation of the output activation signal (Contact output operate), by the logic applied to this output in “Setpoint >...

  • Page 334: Contact Output Resets

    6 ACTUAL VALUES 6.4 INPUTS / OUTPUTS Operation example of output contacts: Figure 6–3: OUTPUT CONTACTS OPERATION 6.4.4 CONTACT OUTPUT RESETS Actual > Inputs/Outputs > Contact Output Resets > Board X (being X the corresponding board in each case). Boards types 1 and 2 have both 8 outputs, so the representation is the same for both types as shown in Table 6–48: If the reset signal is active, the green LED will light up.

  • Page 335: I/O Board Status

    6.4 INPUTS / OUTPUTS 6 ACTUAL VALUES 6.4.5 I/O BOARD STATUS Actual > Inputs/Outputs > I/O Board Status This screen is used for verifying the status of I/O boards. If all the I/O boards, one (F) or both (F and G) depending on the relay model, are correctly inserted in their tracks and are in good state and communicating through the internal CAN Bus, the green LED will remain lit.

  • Page 336: Analog Inputs

    6 ACTUAL VALUES 6.4 INPUTS / OUTPUTS 6.4.8 ANALOG INPUTS Actual > Inputs/Outputs > Analog Intputs > Board X This screen provides the values of the analog inputs. ANALOG INPUTS VALUES Analog_Inp_X_01 Analog_Inp_X_02 Analog_Inp_X_03 Analog_Inp_X_08 GEK-113285A G650 Generator Protection & Control System 6-43...

  • Page 337: Records

    6.5 RECORDS 6 ACTUAL VALUES 6.5RECORDS 6.5.1 EVENT RECORDER 6.5.1.1 ALL SNAPSHOT EVENTS Actual > Records > Event Recorder > All Snapshot Events By selecting this option, the G650 provides a general list of all snapshot events stored in the relay up to the request moment: Figure 6–4: EVENT RECORDER –...
  • Page 338 6 ACTUAL VALUES 6.5 RECORDS 6.5.1.2 NEW SNAPSHOT EVENTS Actual > Records > Event Recorder > New Snapshot Events This screen shows new Snapshot events, updated since the last time that this menu was accessed; there are three possible ways to access new events; in local mode (COM2-HMI), remote mode (COM1) and via Ethernet (COM3). It is the same type of screen as shown on all snapshot event retrieval.

  • Page 339: Waveform Capture

    GE-OSC is GE proprietary software that is not distributed together with EnerVista 650 Setup. This program is A COMTRADE viewer and analysis software for oscillography files. If the user does not have the GE-OSC tool, the oscillography record can be stored and viewed using any other analysis tool capable of reproducing COMTRADE.1999 files.

  • Page 340: Fault Report

    6 ACTUAL VALUES 6.5 RECORDS Figure 6–9: GE-OSC OSCILLOGRAPHY ANALYSIS SOFTWARE It must be taken into account that any settings change in the oscillography will produce the removal of all the information stored up to that moment. 6.5.3 FAULT REPORT When selecting the Actual >...

  • Page 341: Data Logger

    6.5 RECORDS 6 ACTUAL VALUES • Fault current and voltage in primary values • Fault type • Distance to the fault The operation of this screen is similar to that of the previous oscillography screen, being in this case the number of fault reports a fixed number (10), instead of variable and setting-selected like as in the previous case.

  • Page 342: Security

    7 SECURITY 7.1 ADDING USERS 7 SECURITY 7.1 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 343: Changing Passwords

    7.2 CHANGING PASSWORDS 7 SECURITY 7.2CHANGING 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 7–1: 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 344: Enabling Security

    7 SECURITY 7.3 ENABLING SECURITY 7.3ENABLING 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 345: Loging Into Enervista 650 Setup

    7.4 LOGING INTO ENERVISTA 650 SETUP 7 SECURITY 7.4LOGING 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 7–3: LOGIN USER The user name field will display the last log in user name as default, in this example, TestUser.

  • Page 346: Introduction

    8 BOOTCODE AND FIRMWARE UPGRADE 8.1 INTRODUCTION 8 BOOTCODE AND FIRMWARE UPGRADE 8.1INTRODUCTION 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 347: Communication Parameters

    8.1 INTRODUCTION 8 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 348 8 BOOTCODE AND FIRMWARE UPGRADE 8.1 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 349 8.1 INTRODUCTION 8 BOOTCODE AND FIRMWARE UPGRADE Figure 8–4: 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 350: Boot Code Upgrade

    8 BOOTCODE AND FIRMWARE UPGRADE 8.2 BOOT CODE UPGRADE 8.2BOOT 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 351 8.2 BOOT CODE UPGRADE 8 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 8–7: 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 352 8 BOOTCODE AND FIRMWARE UPGRADE 8.2 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 8–10: 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 353 8.2 BOOT CODE UPGRADE 8 BOOTCODE AND FIRMWARE UPGRADE Figure 8–13: 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 8–14:). The requested values are the IP address and the gateway Figure 8–14: ETHERNET PARAMETERS These values should match the LAN structure in which the relay will be connected.

  • Page 354: Firmware Version Upgrade

    8 BOOTCODE AND FIRMWARE UPGRADE 8.3 FIRMWARE VERSION UPGRADE 8.3FIRMWARE 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 355 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 8–18: 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: 8-10 G650 Generator Protection &...

  • Page 356: Boot Code Upgrade (*)

    8 BOOTCODE AND FIRMWARE UPGRADE 8.3 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 357: Firmware Upgrade (*)

    8.3 FIRMWARE VERSION UPGRADE 8 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. 8.3.3 FIRMWARE UPGRADE (*) INSTALL THE PROPER VERSION OF THE ENERVISTA 650 SETUP PROGRAM.

  • Page 358: Commissioning

    9 COMMISSIONING 9.1 VISUAL INSPECTION 9 COMMISSIONING 9.1VISUAL 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 359: General Considerations On The Power Supply Network

    9.2 GENERAL CONSIDERATIONS ON THE POWER SUPPLY NETWORK 9 COMMISSIONING 9.2GENERAL 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 360: Isolation Tests

    9 COMMISSIONING 9.3 ISOLATION TESTS 9.3ISOLATION 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 361: Indicators

    9.4 INDICATORS 9 COMMISSIONING 9.4INDICATORS 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-113285A...

  • Page 362: Power Supply Testing

    9 COMMISSIONING 9.5 POWER SUPPLY TESTING 9.5POWER 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 363: Communications

    9.6 COMMUNICATIONS 9 COMMISSIONING 9.6COMMUNICATIONS 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 364: Verification Of Measurement

    9 COMMISSIONING 9.7 VERIFICATION OF MEASUREMENT 9.7VERIFICATION 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 365: Active, Reactive Power, And Cosj Metering

    9.7 VERIFICATION OF MEASUREMENT 9 COMMISSIONING 9.7.3 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=Pa+Pb+Pc P=V*I*Cosϕ Q=Qa+Qb+Qc Q=V*I*Senϕ Apply the following current and voltage values: APPLIED VOLTAGE AND CURRENT VALUES PER PHASE PHASE A PHASE B...

  • Page 366: Inputs And Outputs

    9 COMMISSIONING 9.8 INPUTS AND OUTPUTS 9.8INPUTS AND OUTPUTS During all tests, the screw on the rear of the relay must be grounded. 9.8.1 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 367: Contact Outputs

    9.8 INPUTS AND OUTPUTS 9 COMMISSIONING 9.8.2 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 368: Connections For Testing Protection Elements

    9 COMMISSIONING 9.9 CONNECTIONS FOR TESTING PROTECTION ELEMENTS 9.9CONNECTIONS 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 369: Instantaneous Overcurrent (50Ph, 50N, 50G Y 50Sg)

    9.10 INSTANTANEOUS OVERCURRENT (50PH, 50N, 50G Y 50SG) 9 COMMISSIONING 9.10INSTANTANEOUS 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 370 9 COMMISSIONING 9.11 TIME OVERCURRENT (51PH, 51PL, 51N, 51G) 9.11 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 371: Directional Elements (67N, 67G)

    9.12 DIRECTIONAL ELEMENTS (67N, 67G) 9 COMMISSIONING 9.12DIRECTIONAL 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 372: G Element

    9 COMMISSIONING 9.12 DIRECTIONAL ELEMENTS (67N, 67G) 9.12.2 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 373: Undervoltage Elements (27P, 27X)

    9.13 UNDERVOLTAGE ELEMENTS (27P, 27X) 9 COMMISSIONING 9.13UNDERVOLTAGE ELEMENTS (27P, 27X) 9.13.1 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 374: Overvoltage Elements (59P, 59X, 59Nh)

    9 COMMISSIONING 9.14 OVERVOLTAGE ELEMENTS (59P, 59X, 59NH) 9.14OVERVOLTAGE ELEMENTS (59P, 59X, 59NH) 9.14.1 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 375: 59Nh Element

    9.14 OVERVOLTAGE ELEMENTS (59P, 59X, 59NH) 9 COMMISSIONING 9.14.3 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 376: Element - Neg Seq Ov

    9 COMMISSIONING 9.14 OVERVOLTAGE ELEMENTS (59P, 59X, 59NH) 9.14.4 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 377: Frequency Elements (81O/81U)

    9.15 FREQUENCY ELEMENTS (81O/81U) 9 COMMISSIONING 9.15 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 378: Application Examples

    10 APPLICATION EXAMPLES 10.1 EXAMPLE 1: COMMUNICATION & PROTECTION SETTINGS PROCEDURE 10 APPLICATION EXAMPLES 10.1EXAMPLE 1: COMMUNICATION & PROTECTION SETTINGS PROCEDURE 10.1.1 DESCRIPTION OF THE EXERCISE The requirements for this setting exercise are: Communicate the relay via serial cable or Ethernet 10/100 Base T cable using EnerVista 650 Setup program. Set some Phase Time Overcurrent protection function to operate at 5A, Inverse curve IEC, Dial 0.1 Set some Output contact on board F to be operated and sealed by the operation of the phase TOC.
  • Page 379 10.1 EXAMPLE 1: COMMUNICATION & PROTECTION SETTINGS PROCEDURE 10 APPLICATION EXAMPLES SEQUENCE ACTION SETTING ACTION ---- IP Address OCT 1 Set to 192 with rotating knob and press it down Move rotating knob clockwise IP Address OCT 2 Set to 168 with rotating knob and press it down Move rotating knob clockwise IP Address OCT 3 Set to 37 with rotating knob and press it down...

  • Page 380: Procedure To Set The Protection Function

    10 APPLICATION EXAMPLES 10.1 EXAMPLE 1: COMMUNICATION & PROTECTION SETTINGS PROCEDURE 10.1.3 PROCEDURE TO SET THE PROTECTION FUNCTION Once the relay has been connected set protection functions and outputs according to the following steps: Open EnerVista 650 SETUP program and under: SETPOINT ⇓...

  • Page 381: Test

    10.1 EXAMPLE 1: COMMUNICATION & PROTECTION SETTINGS PROCEDURE 10 APPLICATION EXAMPLES Under SETPOINT ⇓ RELAY CONFIGURATION ⇒ LEDS SELECT NAME SOURCE Led 5 C Output Op 00 C Output_00_00 Under SETPOINT ⇓ RELAY CONFIGURATION ⇒ OPERATIONS Select Operation 0 Command Text Reset C Output 00 Interlock Type None...

  • Page 382: Example 2: Procedure To Set An Operation

    10 APPLICATION EXAMPLES 10.2 EXAMPLE 2: PROCEDURE TO SET AN OPERATION 10.2EXAMPLE 2: PROCEDURE TO SET AN OPERATION 10.2.1 DESCRIPTION OF THE EXERCISE This simple operation describes how to program and set an operation command on the G650 relay. In the present case the operation is: To configure some G650 output contact to be operated since the front of the relay.
  • Page 383 10.2 EXAMPLE 2: PROCEDURE TO SET AN OPERATION 10 APPLICATION EXAMPLES Under SETPOINT ⇓ RELAY CONFIGURATION ⇒ OPERATIONS Select Operation 0 Command Text Close C_Output_00_00 Interlock Type None Interlocks Final State Type None Final States Frontal Key Contact Input None Virtual Output None Time Out...

  • Page 384: Test

    10 APPLICATION EXAMPLES 10.2 EXAMPLE 2: PROCEDURE TO SET AN OPERATION 10.2.3 TEST In the main front screen press F2 key. A message showing “Press Intro to Confirm Key →F2←” will be displayed. Press down the rotary knob. Check that contact_00_00 (board F) has been closed. Check that the front LED 14 is lit.
  • Page 385 10.2 EXAMPLE 2: PROCEDURE TO SET AN OPERATION 10 APPLICATION EXAMPLES 10-8 G650 Generator Protection & Control System GEK-113285A...

  • Page 386: Frequently Asked

    11 FREQUENTLY ASKED QUESTIONS 11.1 COMMUNICATIONS 11 FREQUENTLY ASKED QUESTIONS 11.1COMMUNICATIONS 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 387 11.1 COMMUNICATIONS 11 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 388: Protection

    11 FREQUENTLY ASKED QUESTIONS 11.2 PROTECTION 11.2PROTECTION 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 389: Control And Hmi

    11.3 CONTROL AND HMI 11 FREQUENTLY ASKED QUESTIONS 11.3CONTROL 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 390: Relay Configuration

    11 FREQUENTLY ASKED QUESTIONS 11.4 RELAY CONFIGURATION 11.4RELAY 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 391 11.4 RELAY CONFIGURATION 11 FREQUENTLY ASKED QUESTIONS 11-6 G650 Generator Protection & Control System GEK-113285A...

  • Page 392: Symptoms And Recommended Actions

    12 G650TROUBLESHOOTING GUIDE 12.1 SYMPTOMS AND RECOMMENDED ACTIONS 12 G650TROUBLESHOOTING GUIDE 12.1SYMPTOMS 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 393 12.1 SYMPTOMS AND RECOMMENDED ACTIONS 12 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 394 12 G650TROUBLESHOOTING GUIDE 12.1 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 395 12.1 SYMPTOMS AND RECOMMENDED ACTIONS 12 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 396: Logic Operands

    APPENDIX A A.1 LOGIC OPERANDS APPENDIX A LOGIC OPERANDSA.1LOGIC OPERANDS OPERANDS - G650 - MODEL FX - GX INTERNAL SYSTEM STATUS AUTOCHECK INTERNAL STATES (CRITICAL) DSP Communication Error: (0) Rignt communications DSP COMM ERROR between DSP and main processor; (1) Communication Error between DSP and main processor Magnetic Module Error: (0) Right Communication MAGNETIC MODULE...
  • Page 397 A.1 LOGIC OPERANDS APPENDIX A Note: It is advisable to use the critical alarms to raise an event or to light a warning led for maintenance purposes. See the example below, the Board X Status depends on the relay model. G650 Generator Protection &...
  • Page 398 APPENDIX A A.1 LOGIC OPERANDS VIRTUAL OUTPUT 000 Configurable logic output 000 VIRTUAL OUTPUT 001 Configurable logic output 001 Configurable Logic Outputs (512 elements) VIRTUAL OUTPUT 511 Configurable logic output 511 Operation bit 001: (0) the configured time expires or OPERATION BIT 1 when success conditions are met;(1) operation 1 is executed and interlocks are fulfilled.
  • Page 399 A.1 LOGIC OPERANDS APPENDIX A OPERANDS - G650 - MODEL FX - GX INTERNAL SYSTEM STATUS (CONT.) CONTROL EVENT 1 Control Event 1 Activation Bit CONTROL EVENT 2 Control Event 2 Activation Bit Control Event Bits (128 elements) CONTROL EVENT 128 Control Event 128 Activation Bit LATCHED VIRT IP 1 Latched virtual input 1...
  • Page 400 APPENDIX A A.1 LOGIC OPERANDS OPERANDS - G650 - MODEL FX - GX INTERNAL SYSTEM STATUS (CONT.) CONT IP_X_CC1 Input 1 (CC1) in Board X CONT IP_X_CC2 Input 2 (CC2) in Board X Contact Inputs Type 4 Board CONT IP_X_CC32 Input 32 (CC32) in Board X CONT IP_X_CC1 Input 1 (CC1) in Board X...
  • Page 401 A.1 LOGIC OPERANDS APPENDIX A OPERANDS - G650 - MODEL FX - GX INTERNAL SYSTEM STATUS (CONT.) SWITCH 1 A STATUS Contact logic output type A from switchgear Function 1 SWITCH 1 B STATUS Contact logic output type B from switchgear Function 1 SWITCH 2 A STATUS Contact logic output type A from switchgear Function 2 SWITCH 2 B STATUS...
  • Page 402 APPENDIX A A.1 LOGIC OPERANDS OPERANDS - G650 - MODEL FX - GX INTERNAL SYSTEM STATUS (CONT.) Ready LED: (0-Red) Relay out of service, protection READY LED OUT OF ORDER (1-Green) Relay in service; protection READY Programmable LED 1 status: Red colour. Latched by LED 1 hardware.
  • Page 403 A.1 LOGIC OPERANDS APPENDIX A OPERANDS - G650 - MODEL FX - GX INTERNAL SYSTEM STATUS (CONT.) I Key I key operation (Programmable signal via PLC) O Key O key operation (Programmable signal via PLC) Programmable Keypad Status (HMI) * Key * key operation (Programmable signal via PLC) F1 Key F1 key operation (Programmable signal via PLC)
  • Page 404 APPENDIX A A.1 LOGIC OPERANDS OPERANDS - G650 - MODEL FX - GX INTERNAL SYSTEM STATUS (CONT.) Oscillography Digital channel 1 : (1) Active ; (0) Not OSC DIG CHANNEL 1 Active Oscillography Digital channel 2 : (1) Active ; (0) Not OSC DIG CHANNEL 2 Active Oscillography Digital channel 3 : (1) Active ;...
  • Page 405 A.1 LOGIC OPERANDS APPENDIX A OPERANDS - G650 - MODEL FX - GX INTERNAL SYSTEM STATUS (CONT.) GROUP 1 ACT ON Group 1 activation, and deactivation of groups 2 &3 GROUP 2 ACT ON Group 2 activation, and deactivation of groups 1 &3 GROUP 3 ACT ON Group 3 activation, and deactivation of groups 1 &2 Setting Groups...
  • Page 406 APPENDIX A A.1 LOGIC OPERANDS Phase instantaneous overcurrent element block Group 1 PH IOC1 HIGH A BLK phase A Phase instantaneous overcurrent element block Group 1 PH IOC1 HIGH B BLK phase B Phase instantaneous overcurrent element block Group 1 PH IOC1 HIGH C BLK phase C Phase instantaneous overcurrent element pickup high...
  • Page 407 A.1 LOGIC OPERANDS APPENDIX A OPERANDS - G650 - MODEL FX - GX INTERNAL SYSTEM STATUS (CONT.) Phase instantaneous overcurrent element block Group 3 PH IOC3 HIGH C BLK phase C Phase instantaneous overcurrent element pickup high PH IOC3 HIGH A PKP level Group 3 phase A Phase instantaneous overcurrent element operation PH IOC3 HIGH A OP...
  • Page 408 APPENDIX A A.1 LOGIC OPERANDS OPERANDS - G650 - MODEL FX - GX INTERNAL SYSTEM STATUS (CONT.) GROUND IOC1 BLOCK Ground instantaneous overcurrent element block Group Ground instantaneous overcurrent element pickup GROUND IOC1 PKP Group 1 Ground instantaneous overcurrent element operation GROUND IOC1 OP (trip) Group 1 GROUND IOC2 BLOCK Ground instantaneous overcurrent element block Group...
  • Page 409 A.1 LOGIC OPERANDS APPENDIX A OPERANDS - G650 - MODEL FX - GX INTERNAL SYSTEM STATUS (CONT.) PH TOC1 HIGH A BLK Phase timed overcurrent element block Group 1 phase A PH TOC1 HIGH B BLK Phase timed overcurrent element block Group 1 phase B Phase timed overcurrent element block Group 1 phase PH TOC1 HIGH C BLK Phase timed overcurrent element pickup Group 1 phase...
  • Page 410 APPENDIX A A.1 LOGIC OPERANDS OPERANDS - G650 - MODEL FX - GX INTERNAL SYSTEM STATUS (CONT.) Phase timed overcurrent element pickup Group 3 phase PH TOC3 HIGH A PKP Phase timed overcurrent element operation (trip) Group PH TOC3 HIGH A OP 3 phase A Phase timed overcurrent element pickup Group 3 phase PH TOC3 HIGH B PKP...
  • Page 411 A.1 LOGIC OPERANDS APPENDIX A OPERANDS - G650 - MODEL FX - GX INTERNAL SYSTEM STATUS (CONT.) Phase timed overcurrent element operation (trip) low PH TOC2 LOW B OP level Group 2 phase B Phase timed overcurrent element pickup low level Group PH TOC2 LOW C PKP 2 phase C Phase timed overcurrent element operation (trip) low...
  • Page 412 APPENDIX A A.1 LOGIC OPERANDS OPERANDS - G650 - MODEL FX - GX INTERNAL SYSTEM STATUS (CONT.) GROUND TOC1 BLOCK Ground timed overcurrent element block Group 1 GROUND TOC1 PKP Ground timed overcurrent element pickup Group 1 Ground timed overcurrent element operation (trip) Group GROUND TOC1 OP GROUND TOC2 BLOCK Ground timed overcurrent element block Group 2 GROUND TOC2 PKP...
  • Page 413 A.1 LOGIC OPERANDS APPENDIX A OPERANDS - G650 - MODEL FX - GX INTERNAL SYSTEM STATUS (CONT.) NEG. SEQ IOC1 BLOCK Negative sequence instantaneous overcurrent element block Group 1 Negative sequence instantaneous overcurrent element NEG. SEQ IOC1 PKP pickup Group 1 Negative sequence instantaneous overcurrent element NEG.
  • Page 414 APPENDIX A A.1 LOGIC OPERANDS OPERANDS - G650 - MODEL FX - GX INTERNAL SYSTEM STATUS (CONT.) GEN UNBAL1 BLOCK Generator Unbalance element block Group 1 GEN UNBAL1 STG1 Generator Unbalance element pickup Stage 1 Group 1 GEN UNBAL1 STG1 OP Generator Unbalance element operation Stage 1 Group 1 GEN UNBAL1 STG2 Generator Unbalance element pickup Stage 2 Group 1...
  • Page 415 A.1 LOGIC OPERANDS APPENDIX A OPERANDS - G650 - MODEL FX - GX INTERNAL SYSTEM STATUS (CONT.) THERMAL1 49S BLOCK Generator Thermal Model element block Group 1 THERMAL1 49S ALARM Generator Thermal Model element alarm Group 1 THERMAL1 49S OP Generator Thermal Model element operation Group 1 THERMAL1 49S RST Generator Thermal Model element reset signal Group 1...
  • Page 416 APPENDIX A A.1 LOGIC OPERANDS OPERANDS - G650 - MODEL FX - GX INTERNAL SYSTEM STATUS (CONT.) PHASE UV1 CA OP Undervoltage element operation CA Group 1 PHASE UV1 PKP Pickup of any of the above mentioned elements PHASE UV1 OP Operation of any of the above mentioned elements PHASE UV2 BLOCK Phase undervoltage element block Group 2...
  • Page 417 A.1 LOGIC OPERANDS APPENDIX A OPERANDS - G650 - MODEL FX - GX INTERNAL SYSTEM STATUS (CONT.) PHASE OV1 BLOCK Phase overvoltage element block Group 1 PHASE OV1 AB PKP Overvoltage element pickup AB Group 1 PHASE OV1 AB OP Overvoltage element operation AB Group 1 PHASE OV1 BC PKP Overvoltage element pickup BC Group 1...
  • Page 418 APPENDIX A A.1 LOGIC OPERANDS OPERANDS - G650 - MODEL FX - GX INTERNAL SYSTEM STATUS (CONT.) NEUTRAL OV1 HIGH Neutral overvoltage element block high level Group 1 NEUTRAL OV1 HIGH Neutral overvoltage element pickup high level Group 1 NEUTRAL OV1 HIGH Neutral overvoltage element operation high level Group NEUTRAL OV2 HIGH Neutral overvoltage element block high level Group 2...
  • Page 419 A.1 LOGIC OPERANDS APPENDIX A OPERANDS - G650 - MODEL FX - GX INTERNAL SYSTEM STATUS (CONT.) NEG SEQ OV1 BLOCK Negative sequence overvoltage element block Group 1 NEG SEQ OV1 PKP Negative sequence overvoltage element pickup Group 1 Negative sequence overvoltage element operation NEG SEQ OV1 OP Group 1 NEG SEQ OV2 BLOCK...
  • Page 420 APPENDIX A A.1 LOGIC OPERANDS OPERANDS - G650 - MODEL FX - GX INTERNAL SYSTEM STATUS (CONT.) OVERFREQ1 BLOCK Overfrequency element block Group 1 OVERFREQ1 PKP Overfrequency element pickup Group 1 OVERFREQ1 OP Overfrequency element operation Group 1 OVERFREQ2 BLOCK Overfrequency element block Group 2 Overfrequency OVERFREQ2 PKP...
  • Page 421