GE Multilin G650 User Manual

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GE Consumer & Industrial

Multilin

G650

Generator Protection & Control

System

Instruction manual

GEK-113285A

Firmware version: 3.74

GE Multilin

215 Anderson Avenue L6E 1B3 Markham, ON -CANADA T (905) 294 6222 F (905) 294 8512

E [email protected]

EnerVista 650 Setup version: 3.76

GE Multilin

Avda. Pinoa, 10 48170 Zamudio SPAIN T +34 94 485 88 00 F +34 94 485 88 45

E [email protected]

Internet: www.GEMultilin.com

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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.......................................................................... 1-9

1.2.4 COMMUNICATIONS ARCHITECTURE ............................................................ 1-9

1.3 ENERVISTA 650 SETUP SOFTWARE

1.3.1 SYSTEM REQUIREMENTS ............................................................................ 1-11

1.3.2 INSTALLATION................................................................................................ 1-11

1.3.3 CONNECTING ENERVISTA 650 SETUP WITH G650.................................... 1-15

1.4 650 HARDWARE

1.4.1 MOUNTING & WIRING.................................................................................... 1-17

1.4.2 650 COMMUNICATIONS................................................................................. 1-17

1.4.3 FACEPLATE DISPLAY....................................................................................1-18

1.4.4 MAINTENANCE ...............................................................................................1-18

2. PRODUCT DESCRIPTION 2.1 OVERVIEW

2.1.1 G650 OVERVIEW.............................................................................................. 2-1

2.2 SUMMARY

2.2.1 ANSI DEVICE NUMBERS AND FUNCTIONS................................................... 2-3

2.2.2 OTHER DEVICE FUNCTIONS .......................................................................... 2-4

2.3 ORDERING CODE

2.4 TECHNICAL SPECIFICATIONS

2.4.1 PROTECTION ELEMENTS ............................................................................... 2-7

2.4.2 CONTROL........................................................................................................ 2-17

2.4.3 MONITORING.................................................................................................. 2-22

2.4.4 USER-PROGRAMMABLE ELEMENTS...........................................................2-24

2.4.5 METERING ...................................................................................................... 2-25

2.4.6 INPUTS............................................................................................................ 2-26

2.4.7 REAL TIME CLOCK......................................................................................... 2-28

2.4.8 OUTPUTS........................................................................................................ 2-28

2.4.9 CONTROL POWER SUPPLY.......................................................................... 2-29

2.4.10 COMMUNICATIONS........................................................................................2-29

2.4.11 OPTIC FEATURES..........................................................................................2-31

2.4.12 ENVIRONMENTAL CHARACTERISTICS .......................................................2-32

2.4.13 PACKAGING AND WEIGHT............................................................................ 2-32

2.4.14 TYPE TESTS ................................................................................................... 2-32

2.4.15 APPROVALS ...................................................................................................2-32

2.5 EXTERNAL CONNECTIONS

3. HARDWARE 3.1 MODULE DESCRIPTION

3.2 POWER SUPPLY

3.3 MECHANICAL DESCRIPTION

3.3.1 MOUNTING........................................................................................................ 3-3

3.3.2 REAR DESCRIPTION........................................................................................3-6

3.4 WIRING

3.4.1 EXTERNAL CONNECTIONS............................................................................. 3-9

3.4.2 DIGITAL INPUTS WITH TRIP CIRCUIT SUPERVISION ..................................3-9

3.4.3 CABLE/FIBER ETHERNET BOARD................................................................ 3-10

GEK-113285A G650 Generator Protection & Control System 1

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TABLE OF CONTENTS

3.5 TRANSCEIVER OPTICAL POWER BUDGET VERSUS LINK LENGTH

4. HUMAN INTERFACES. SETTINGS & ACTUAL VALUES

4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE

4.1.1 INTRODUCTION ................................................................................................4-1

4.1.2 ENERVISTA 650 SETUP SOFTWARE OVERVIEW..........................................4-1

4.1.3 MAIN SCREEN...................................................................................................4-3

4.1.4 COMMUNICATION MENU .................................................................................4-4

4.1.5 FILE MANAGEMENT .........................................................................................4-6

4.1.6 ENERVISTA 650 SETUP MENU STRUCTURE...............................................4-10

4.1.7 FILE MENU OVERVIEW ..................................................................................4-11

4.1.8 SETPOINT MENU OVERVIEW........................................................................4-15

4.1.9 ACTUAL VALUES MENU OVERVIEW.............................................................4-23

4.1.10 OPERATIONS MENU OVERVIEW ..................................................................4-26

4.1.11 COMMUNICATION MENU OVERVIEW...........................................................4-27

4.1.12 SECURITY MENU OVERVIEW........................................................................4-30

4.1.13 VIEW MENU OVERVIEW.................................................................................4-30

4.1.14 HELP MENU OVERVIEW ................................................................................4-30

4.2 HUMAN MACHINE INTERFACE (HMI)

4.2.1 DISPLAY...........................................................................................................4-31

4.2.2 FRONT LED INDICATORS ..............................................................................4-32

4.2.3 PUSHBUTTONS...............................................................................................4-32

4.2.4 FRONT PORT AND COVER SEALING SYSTEM............................................4-33

4.2.5 TEXT MENUS...................................................................................................4-34

4.2.6 GRAPHIC DISPLAY .........................................................................................4-52

4.3 WEB SERVER

4.3.1 HOME ...............................................................................................................4-61

4.3.2 SNAPSHOT EVENTS.......................................................................................4-62

4.3.3 CONTROL EVENTS.........................................................................................4-63

4.3.4 ALARMS ...........................................................................................................4-64

4.3.5 OSCILLOGRAPHY...........................................................................................4-65

4.3.6 FAULT REPORT ..............................................................................................4-66

4.3.7 DATA LOGGER................................................................................................4-67

4.3.8 METERING.......................................................................................................4-68

5. SETTINGS 5.1 OVERVIEW

5.1.1 SETTING MAIN MENU.......................................................................................5-1

5.2 PRODUCT SETUP

5.2.1 COMMUNICATION SETTINGS..........................................................................5-3

5.2.2 MODBUS USER MAP ........................................................................................5-6

5.2.3 FAULT REPORT ................................................................................................5-7

5.2.4 OSCILLOGRAPHY.............................................................................................5-9

5.2.5 DATA LOGGER................................................................................................5-12

5.2.6 DEMAND .........................................................................................................5-14

5.3 SYSTEM SETUP

5.3.1 GENERAL SETTINGS......................................................................................5-20

5.3.2 FLEX CURVES.................................................................................................5-20

5.3.3 BREAKER.........................................................................................................5-23

5.3.4 SWITCHGEAR .................................................................................................5-25

5.4 PROTECTION ELEMENTS

5.4.1 CHANGE OF SETTING TABLES IN G650 ELEMENTS ..................................5-26

5.4.2 INVERSE TIME CURVES CHARACTERISTICS..............................................5-30

5.4.3 PHASE CURRENT ...........................................................................................5-40

5.4.4 NEUTRAL CURRENT ......................................................................................5-46

5.4.5 GROUND CURRENT .......................................................................................5-52

5.4.6 RESTRICTED GROUND FAULT (ONLY FOR ENHANCED MODELS) ..........5-56

5.4.7 SENSITIVE GROUND CURRENT (ONLY FOR ENHANCED MODELS) ........5-59

5.4.8 NEGATIVE SEQUENCE CURRENT................................................................5-60

5.4.9 VOLTAGE ELEMENTS ....................................................................................5-63

5.4.10 POWER ............................................................................................................5-71

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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)......... 5-91

5.5.7 PULSE COUNTERS ........................................................................................ 5-92

5.5.8 ANALOG COMPARATORS............................................................................. 5-94

5.5.9 FREQUENCY RATE OF CHANGE.................................................................. 5-95

5.5.10 LOSS OF MAINS (78V) (FOR ENHANCED MODELS)..................................5-97

5.5.11 LOSS OF EXCITATION (40)...........................................................................5-99

5.5.12 ACCIDENTAL ENERGIZATION (50/27)........................................................ 5-101

5.6 INPUTS/OUTPUTS

5.6.1 INPUT/OUTPUT PLACEMENT......................................................................5-103

5.6.2 CONTROL SETTINGS FOR INPUTS/OUTPUTS.......................................... 5-104

5.6.3 INPUTS.......................................................................................................... 5-106

5.6.4 OUTPUTS...................................................................................................... 5-108

5.6.5 CIRCUIT SUPERVISION AND CONTACT SEAL-IN CIRCUITS ................... 5-110

5.6.6 ANALOG BOARDS SPECIFIC SETTINGS ................................................... 5-120

5.6.7 VIRTUAL INPUTS.......................................................................................... 5-120

5.6.8 VIRTUAL OUTPUTS...................................................................................... 5-121

5.7 TESTING

5.7.1 FORCE IO–INPUT TESTING ........................................................................ 5-122

5.7.2 FORCE IO–OUTPUT TESTING .................................................................... 5-122

5.8 RELAY CONFIGURATION

5.8.1 OUTPUTS...................................................................................................... 5-123

5.8.2 LEDS..............................................................................................................5-125

5.8.3 OPERATIONS................................................................................................5-126

5.8.4 PROTECTION ELEMENTS ........................................................................... 5-130

5.8.5 OSCILLOGRAPHY ........................................................................................ 5-132

5.8.6 CONTROL EVENTS ...................................................................................... 5-133

5.8.7 SWITCHGEAR .............................................................................................. 5-135

5.8.8 HMI (HUMAN-MACHINE INTERFACE).........................................................5-137

5.9 LOGIC CONFIGURATION (PLC EDITOR)

5.9.1 INTRODUCTION............................................................................................5-141

5.9.2 THEORY OF OPERATION............................................................................ 5-142

5.9.3 MAIN MENU................................................................................................... 5-145

5.9.4 CONFIGURATION GENERATION ................................................................5-146

5.9.5 GENERATION OF LIBRARIES ..................................................................... 5-147

5.9.6 EXAMPLE OF APPLICATION ....................................................................... 5-148

6. ACTUAL VALUES 6.1 FRONT PANEL

6.1.1 LEDS..................................................................................................................6-1

6.2 STATUS

6.2.1 OPERATION BITS .............................................................................................6-2

6.2.2 BREAKER.......................................................................................................... 6-2

6.2.3 PROTECTION.................................................................................................... 6-3

6.2.4 CONTROL ELEMENTS ................................................................................... 6-12

6.2.5 PROTECTION SUMMARY .............................................................................. 6-19

6.2.6 SNAPSHOT EVENTS SUMMARY...................................................................6-22

6.2.7 MODBUS USER MAP......................................................................................6-24

6.2.8 SWITCHGEAR STATUS..................................................................................6-24

6.2.9 CALIBRATION ................................................................................................. 6-25

6.2.10 FLEX CURVES ................................................................................................6-27

6.2.11 SYSTEM INFO................................................................................................. 6-27

6.2.12 RECORD STATUS .......................................................................................... 6-27

6.3 METERING

6.3.1 PRIMARY VALUES..........................................................................................6-32

6.3.2 SECONDARY VALUES ................................................................................... 6-36

6.3.3 PHASOR DIAGRAM ........................................................................................ 6-38

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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

6.5.1 EVENT RECORDER ........................................................................................6-44

6.5.2 WAVEFORM CAPTURE ..................................................................................6-46

6.5.3 FAULT REPORT ..............................................................................................6-47

6.5.4 DATA LOGGER................................................................................................6-48

7. SECURITY 7.1 ADDING USERS

7.1.1 USER RIGHTS ...................................................................................................7-1

7.2 CHANGING PASSWORDS

7.3 ENABLING SECURITY

7.4 LOGING INTO ENERVISTA 650 SETUP

8. BOOTCODE AND FIRMWARE UPGRADE

8.1 INTRODUCTION

8.1.1 COMMUNICATION PARAMETERS...................................................................8-2

8.2 BOOT CODE UPGRADE

8.3 FIRMWARE VERSION UPGRADE

8.3.1 FIRMWARE UPGRADE .....................................................................................8-9

8.3.2 BOOT CODE UPGRADE (*).............................................................................8-11

8.3.3 FIRMWARE UPGRADE (*)...............................................................................8-12

9. COMMISSIONING 9.1 VISUAL INSPECTION

9.2 GENERAL CONSIDERATIONS ON THE POWER SUPPLY NETWORK

9.3 ISOLATION TESTS

9.4 INDICATORS

9.5 POWER SUPPLY TESTING

9.6 COMMUNICATIONS

9.7 VERIFICATION OF MEASUREMENT

9.7.1 VOLTAGES ........................................................................................................9-7

9.7.2 PHASE CURRENTS...........................................................................................9-7

9.7.3 ACTIVE, REACTIVE POWER, AND COSJ METERING....................................9-8

9.7.4 FREQUENCY .....................................................................................................9-8

9.8 INPUTS AND OUTPUTS

9.8.1 DIGITAL INPUTS................................................................................................9-9

9.8.2 CONTACT OUTPUTS ......................................................................................9-10

9.8.3 CIRCUIT CONTINUITY SUPERVISION INPUTS ............................................9-10

9.8.4 LATCHING CIRCUITS......................................................................................9-10

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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................................................................................................. 9-16

9.13.2 27X ELEMENT................................................................................................. 9-16

9.14 OVERVOLTAGE ELEMENTS (59P, 59X, 59NH)

9.14.1 59P ELEMENT................................................................................................. 9-17

9.14.2 59X ELEMENT................................................................................................. 9-17

9.14.3 59NH ELEMENT..............................................................................................9-18

9.14.4 47 ELEMENT - NEG SEQ OV ......................................................................... 9-19

9.15 FREQUENCY ELEMENTS (81O/81U)

10. APPLICATION EXAMPLES 10.1 EXAMPLE 1: COMMUNICATION & PROTECTION SETTINGS

PROCEDURE

10.1.1 DESCRIPTION OF THE EXERCISE ...............................................................10-1

10.1.2 PROCEDURE TO COMMUNICATE WITH THE RELAY................................. 10-1

10.1.3 PROCEDURE TO SET THE PROTECTION FUNCTION ................................ 10-3

10.1.4 TEST ................................................................................................................ 10-4

10.2 EXAMPLE 2: PROCEDURE TO SET AN OPERATION

10.2.1 DESCRIPTION OF THE EXERCISE ...............................................................10-5

10.2.2 PROCEDURE ................................................................................................. 10-5

10.2.3 TEST ................................................................................................................ 10-7

11. FREQUENTLY ASKED

QUESTIONS

11.1 COMMUNICATIONS

11.2 PROTECTION

11.3 CONTROL AND HMI

11.4 RELAY CONFIGURATION

12. G650TROUBLESHOOTING

12.1 SYMPTOMS AND RECOMMENDED ACTIONS

GUIDE

A. LOGIC OPERANDS A.1 LOGIC OPERANDS

B. MODBUS PROTOCOL B.1 ACCESS TO G650 DATA

B.2 MODBUS G650

B.2.1 FUNCTIONS USED ...........................................................................................B-2

B.2.2 PHYSICAL LAYER.............................................................................................B-2

B.2.3 DATA LINK LAYER............................................................................................B-3

B.2.4 GENERIC READING .........................................................................................B-4

B.2.5 GENERIC WRITING ..........................................................................................B-5

B.2.6 FUNCTION CODES ..........................................................................................B-6

B.2.7 EXCEPTIONS AND ERROR RESPONDS ........................................................B-6

GEK-113285A G650 Generator Protection & Control System 5

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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 ................. B-17

B.6.2 SERIAL COMUNICATION...............................................................................B-17

B.6.3 ETHERNET COMMUNICATION ..................................................................... B-17

B.6.4 ACKNOWLEDGEMENT OF EVENTS (ALARMS)...........................................B-18

B.6.5 VIRTUAL INPUTS WRITING........................................................................... B-18

B.6.6 USER MAP ......................................................................................................B-18

B.6.7 RETRIEVING OSCILOGRAPHY ..................................................................... B-19

B.6.8 TIME SYNCHRONIZATION ............................................................................ B-19

B.6.9 ENQUEUEING MESSAGES .......................................................................... B-20

B.6.10 TRACES AND TROUBLESHOOTING.............................................................B-20

B.6.11 MODBUS CHECK FUNCTION........................................................................ B-21

B.7 MEMORY MAP

C. DNP 3.0 PROTOCOL FOR

G650

C.1 DNP 3.0 PROTOCOL SETTINGS C.2 DNP 3.0 DEVICE PROFILE DOCUMENT C.3 IMPLEMENTATION TABLE C.4 BINARY INPUT POINTS C.5 DNP CONFIGURATION EXAMPLES

C.5.1 CONFIGURING DNP USER MAP................................................................... C-11

C.5.2 EXAMPLE OF CUSTOM BINARY INPUT POINTS MAP................................C-13

C.5.3 MULTIPLE DNP 3.0 MASTERS COMMUNICATION WITH G650 .................. C-15

C.6 BINARY OUTPUT AND CONTROL RELAY OUTPUT C.7 BINARY COUNTERS C.8 ANALOG INPUTS

D. IEC 60870-5-104 PROTOCOL D.1 INTRODUCTION

D.2 TECHNICAL DESCRIPTION D.3 BASIC APPLICATION FUNCTIONS D.4 IEC 104 SETTINGS D.5 IEC 60870-5-104 POINT LIST

E. FACTORY DEFAULT LOGIC E.1 FACTORY DEFAULT LOGIC

F. FACTORY DEFAULT

CONFIGURATION

F.1 FACTORY DEFAULT SETTINGS F.2 FACTORY DEFAULT CONFIGURATION

6 G650 Generator Protection & Control System GEK-113285A

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TABLE OF CONTENTS

G. MISCELLANEOUS G.1 GE MULTILIN WARRANTY

GEK-113285A G650 Generator Protection & Control System 7

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TABLE OF CONTENTS

8 G650 Generator Protection & Control System GEK-113285A

Page 10

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.

CAUTION: THE OPERATOR OF THIS INSTRUMENT IS ADVISED THAT IF THE EQUIPMENT IS USED IN A MANNER NOT SPECIFIED IN THIS MANUAL, THE PROTECTION PROVIDED BY THE EQUIPMENT MAY BE IMPAIRED.

Figure 1–1: FRONT VIEW OF G650 UNITS

GEK-113285A G650 Generator Protection & Control System 1-1

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1.1 IMPORTANT PROCEDURES 1 GETTING STARTED

1.1.1.1 COMMUNICATION BOARDS WITHDRAWAL / INSERTION

WARNING: MODULE WITHDRAWAL AND INSERTION SHALL ONLY BE PERFORMED BY DULY QUALIFIED SERVICE PERSONNEL. FOR PERSONAL SECURITY PURPOSES, BEFORE ACCOMPLISHING ANY WITHDRAWAL OR INSERTION OPERATION, THE RELAY MUST BE POWERED OFF AND ALL THE REAR TERMINALS MUST BE POTENTIAL FREE. THE RELAY MUST BE GROUNDED USING THE REAR GROUNDING SCREW.

The modular design of the relay allows for the withdrawal and insertion of the communication module. Figure 1–2: shows the location of communication modules on the rear part of the relay. Qualified personnel must carry out

the insertion or extraction of the communication boards only after interrupting the relay auxiliary voltage and ensuring that all the rear terminals are potential free.

Communication boards are installed on the rear of the unit, the upper port being reserved for the asynchronous communications board and CAN, and the lower port for the ETHERNET board in any of its configurations.

Before performing any of these actions, control power must be removed fro m the relay and all the r ear terminals must be potential free. 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.

WITHDRAWAL: Loosen the small screws that keep the faceplate in place and extract the module. INSERTION: Insert the module and press it firmly in the case, until it is completely fixed. After this, bolt the faceplate

screws and replace the control power. 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.

1-2 G650 Generator Protection & Control System GEK-113285A

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1 GETTING STARTED 1.1 IMPORTANT PROCEDURES

1.1.1.2 MAGNETIC MODULE TERMINALS

The transformer module for the VTs and CTs is already connected to a female connector screwed to the case. The current inputs incorporate shorting bars, so that the module can be extracted without the need to short-circuit the currents externally. It is very important, for safety reasons not to change or switch the terminals for CTs and VTs.

AC Input Terminals

GE Multilin

Figure 1–3: REAR VIEW OF G650 UNIT

will not be responsible for any damage of the relay, connected equipment or personnel

whenever these safety rules are not followed.

GEK-113285A G650 Generator Protection & Control System 1-3

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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:

• Mounting screws for fixing the relay to a cabinet

• CD containing EnerVista 650 Setup software

• Wiring diagram

• Certificate of Compliance

1-4 G650 Generator Protection & Control System GEK-113285A

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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 contact GE Multilin immediately at:

EUROPE, MIDDLE EAST AND AFRICA:

GE MULTILIN

Av. Pi noa, 10

48170 Zamudio, Vizcaya (SPAIN)

Tel.: (34) 94-485 88 54, Fax: (34) 94-485 88 38

E-mail: [email protected]

AMERICA, ASIA AND AUSTRALIA:

GE MULTILIN

215, Anderson Avenue

L6E 1B3 Markham, ON (CANADA)

Tel.: +1 905 294 6222, Fax: +1 905 201 2098

E-mail: [email protected]

The information provided herein is not intended to cover all the details of the variations of the equipment, nor does it take into account the circumstances that may be present in your installation, operating or maintenance activities.

Should you wish to receive additional information, or for any particular problem that cannot be solved by referring to the information contained herein, please contact GENERAL ELECTRIC MULTILIN.

GEK-113285A G650 Generator Protection & Control System 1-5

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1.1 IMPORTANT PROCEDURES 1 GETTING STARTED

1.1.3 SAFETY INSTRUCTIONS

The G650 ground screw shown in Figure 1–5: must be correctly grounded.

Figure 1–5: LOCATION OF GROUNDING SCREW

Before communicating with a G650 unit through the front serial port, please ensure that the computer is grounded. In case of using a laptop, it is recommended not to have it connected to its power supply. In many cases it might not be

correctly grounded either due to the power supply or to the connector cables used.

This is required not only for personal protection, bu t also to avoid a potential voltage difference between the relay’s serial port and the computer’s port, which could produce permanent damage to the computer or the relay.

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

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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. Both of these technologies required expensive cabling and auxiliary equipment to produce functioning systems.

Recently, digital electronic equipment has begun to provide protection, control and metering functions. Initially, this equipment was either single function or had very limited multi-function capability, and did not significantly reduce the cabling and auxiliary equipment required. However, recent digital relays have become quite multi-functional, reducing cabling and auxiliaries significantly. These devices also transfer data to central control facilities and Human Machine Interfaces using electronic communications. The functions performed by these products have become so broad that many users prefer the term IED (Intelligent Electronic Device).

It is obvious to station designers that the amount of cabling and auxiliary equipment installed in stations can be even further reduced, to 20% to 70% of the levels common in 1990, to achieve large cost reductions. This requires placing even more functions within the IEDs.

Users of power equipment are also interested in reducing cost by improving power quality and personnel productivity, and as always, in increasing system reliability and efficiency. These objectives are realized through software which is used to perform functions at both the station and supervisory levels. The use of these systems is growing rapidly.

High speed communications are required to meet the data transfer rates required by modern automatic control and monitoring systems. In the near future, very high speed communications will be required to perform protection signalling.

IEDs with capabilities outlined above will also provided significantly more power system data than is presently available, enhance operations and maintenance, and permit the use of adaptive system configuration for protection and control systems. This new generation of equipment must also be easily incorporated into automation systems, at both the station and enterprise levels.

1.2.2 HARDWARE ARCHITECTURE

650 family of relays has been designed to meet the goals described above that are appearing nowadays in the environment of new substations.

The 650 is a digital-based device containing a central processing unit (CPU) that handles multiple types of input and output signals. The 650 family can communicate over a local area network (LAN) with an operator interface, a programming device, or another 650 or UR device.

The CPU module contains firmware that provides protection elements in the form of logic algorithms, as well as programming logic gates, timers, and latches for control features. It incorporates two internal processors, one for generic use and a second one dedicated for communications.

Input Elements accept a variety of analog or digital signals from the field. The 650 isolates and converts these signals into logic signals used by the relay.

Output Elements convert and isolate the logic signals generated by the relay into digital signals that can be used to control field devices.

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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. Not available for C650 models. CAN Bus Inputs/Outputs: are signals associated to physical input/output contacts from independent modules connected

to the 650 unit via a CAN Bus. Not available for W650 models. PLC: Programmable Logic Controller. Control module that enables the unit configuration (assignment of inputs/outputs)

and the implementation of logic circuits. Protection Elements: Relay protection elements, for example: Overcurrent, overvoltage, etc. Not available for C650

models. Remote inputs and outputs provide a means of sharing digital point state information between remote devices using IEC

61850 GSSE and GOOSE messages.Remote I/O are not available for G650 models. Not available for G650 and C650 models.

Analog Inputs are signals associated with transducers.

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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.

1.2.4 COMMUNICATIONS ARCHITECTURE

The main processor performs protection, control, and communication functions, incorporating two internal processors, one for generic use and a second one dedicated for communications.

A dedicated serial port is used for communication between the main processor and the human-machine interface. The serial connection provides great immunity against electromagnetic disturbances, thus increasing system safety.

All G650 units incorporate an RS232 serial port on the front of the relay. There is also a possibility to incorporate up to two additional communication modules on the rear.

One of the modules provides asynchronous serial communications, using different physical media (RS485, plastic or glass fiber optic) depending on the selected model. The module incorporates two identical ports, COM1 and COM2. The COM2 port is multiplexed with the front port. Additionally, this module may incorporate a port for CAN BUS communications, used for the connection to the Remote CAN BUS I/O module. This feature allows increasing up to 100% the I/O capability, when the maximum number of I/Os available inside the relay is not enough for a specific application.

Available options are:

Table 1–1: REAR SERIAL COMMUNICATIONS BOARD 1

BOARD CODE FUNCTIONALITY

F Without additional communication ports A Two RS485 ports P Two Plastic F.O. ports G Two Glass F.O. ports X Two RS485 ports and a CAN port for remote CAN Bus Inputs/Outputs Y Two Plastic F.O. ports and a CAN port for remote CAN Bus Inputs/Outputs (fiber) Z Two Glass F.O. ports and a CAN port for remote CAN Bus Inputs/Outputs (fiber) C CAN port for remote CAN Bus I/O (cable) M RS485 CAN port for remote CAN bus I/O (cable)

The other module provides Ethernet communications (COM3 port), using 10/100BaseTX (self-negotiable speed) or 100BaseFX connectors, depending on the selected model. The most complete models include a double redundant 100BaseFX fiber optic port. Redundancy is provided at the physical level; the unit incorporates internally duplicated and independent controllers for extended system reliability and accessibility.

Available Options are:

Table 1–2: REAR ETHERNET COMMUNICATIONS BOARD 2

BOARD CODE FUNCTIONALITY

B One 10/100BaseTX port (self-negotiable speed) C One 10/100BaseTX port and one 100BaseFX port. D One 10/100BaseTX port and redundant 100BaseFX ports E Redundant 10/100BaseTX ports

For options C and D it is required to select the active physical media, by means of an internal selector inside the module. The factory configuration for this selection is the 10/100BaseTX port.

Finally, internal communication with input and output modules is performed via an internal CAN bus, independent from the one used for remote CAN BUS I/Os. This fact provides increased communication speed, as well as the possibility of acknowledgement of modules, abnormalities, etc. As this is a serial port supporting a communications protocol, it provides extraordinary immunity against external or internal disturbances.

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1.2 OVERVIEW 1 GETTING STARTED

Figure 1–7: COMMUNICATIONS ARCHITECTURE (B6816F1)

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1 GETTING STARTED 1.3 ENERVISTA 650 SETUP SOFTWARE

1.3ENERVISTA 650 SETUP SOFTWARE 1.3.1 SYSTEM REQUIREMENTS

The EnerVista 650 Setup software interface is the preferred method to edit settings and view actual values because the PC monitor can display more information in a simple comprehensible format.

The following minimum requirements must be met for the EnerVista 650 Setup software to properly operate on a PC:

• Pentium® class or higher processor (Pentium® II 300 MHz or higher recommended)

• Windows® NT 4.0 (Service Pack 3 or higher), Windows® 2000, Windows® XP

• Internet Explorer® 5.0 or higher

• 64 MB of RAM (128 MB recommended)

• 40 MB of available space on system drive and 40 MB of available space on installation drive

• RS232C serial and/or Ethernet port for communications to the relay

1.3.2 INSTALLATION

After ensuring the minimum requirements for using EnerVista 650 Setup are met (see previous section), use the following procedure to install the EnerVista 650 Setup from the GE EnerVista CD.

1. Insert the GE EnerVista CD into your CD-ROM drive.

2. Click the Install Now button and follow the installation instructions to install the no-charge EnerVista software.

3. When installation is complete, start the EnerVista Launchpad application.

4. Click the IED Setup section of the Launch Pad window.

Figure 1–8: LAUNCHPAD WINDOW

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1.3 ENERVISTA 650 SETUP SOFTWARE 1 GETTING STARTED

5. 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” if you do not have a web connection, then click the Add Now button to list software items for the G650.

Figure 1–9: ADD PRODUCT WINDOW

6. If “Web” option is selected, choose the G650 software program and release notes (if desired) from the list and click the

Download Now button to obtain the installation program.

Figure 1–10: WEB UPGRADE WINDOW

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1 GETTING STARTED 1.3 ENERVISTA 650 SETUP SOFTWARE

7. 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.

8. Select the complete path, including the new directory name, where the EnerVista 650 Setup will be installed.

9. Click on Next to begin the installation. The files will be installed in the directory indicated and the installation program

will automatically create icons and add EnerVista 650 Setup to the Windows start menu.

10. Follow the on-screen instructions to install the EnerVista 650 Setup software. When the Welcome window appears,

click on Next to continue with the installation procedure.

Figure 1–11: ENERVISTA 650 SETUP INSTALLATION

11. When the Choose Destination Location window appears, and if the software is not to be located in the default

directory, click Change… and type in the complete path name including the new directory name and click Next to continue with the installation procedure.

Figure 1–12: ENERVISTA 650 SETUP INSTALLATION CONT.

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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 Progra m Folder window. Click Next to begin the installation process, and all the necessary program files will be copied into the chosen directory.

Figure 1–13: SELECT PROGRAM FOLDER

13. To finish with the installation process, select the desired language for startup.

Figure 1–14: LANGUAGE WINDOW

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1 GETTING STARTED 1.3 ENERVISTA 650 SETUP SOFTWARE

14. Click Finish to end the installation. The G650 device will be added to the list of installed IEDs in the EnerVista

Launchpad window, as shown below.

Figure 1–15: ENERVISTA LAUNCHPAD

1.3.3 CONNECTING ENERVISTA 650 SETUP WITH G650

This section is intended as a quick start guide to using the EnerVista 650 Setup software. Please refer to section 4.1 in this manual for more information about the EnerVista 650 Setup software interface.

a) CONFIGURING AN ETHERNET CONNECTION

Before starting, verify that the Ethernet network cable is properly connected to the Ethernet port on the back of the relay.

1. 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 (see previous section for installation instructions).

2. Go to “Communication>Computer” and enter the following data referring to communications:

3. Select Control Type as MODBUS TCP/IP from the drop-down list. This option will display a number of interface

parameters that must be entered for proper Ethernet communications.

4. Enter the relay IP address (from “Setpoint>Product Setup >Communication Settings>Network>IP ADDRESS”) in

the IP Address field in MODBUS TCP/IP SETUP.

5. Enter the relay ModBus address (from “Setpoint>Product Setup >Communication Settings>ModBus

Protocol>ModBus Address COM1/COM2 setting”) in the Unit Identifier (Slave Address) field.

6. Enter the ModBus port address (from “Setpoint>Product Setup >Communication Settings>ModBus

Protocol>ModBus Port Number” setting) in the ModBus Port field.

7. The Device has now been configured for Ethernet communications. Proceed to press the ON button to begin

communicating.

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1.3 ENERVISTA 650 SETUP SOFTWARE 1 GETTING STARTED

b) CONFIGURING AN RS232 CONNECTION

Before starting, verify that the RS232 serial cable is properly connected to the RS232 port on the front panel of the relay.

1. 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 (see previous section for installation instructions).

2. Go to “Communication>Computer” and enter the following data referred to communications:

3. Select Control Type as No Control Type from the drop-down list. This option will display a number of interface parameters that must be entered for proper serial communications.

4. Enter the relay Slave Address (“Setpoint>Product Setup >Communication Settings>ModBus Protocol” menu) in the Slave Address field. The default value is 254.

5. Enter the physical communications parameters (Baudrate and parity settings) from the “Setpoint>Product Setup >Communication Settings>Serial Ports” menu, in their respective fields. Default values are 19200 for baudrate and none for parity.

6. The Device has now been configured for RS232 communications. Proceed to press the ON button to begin communicating.

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1 GETTING STARTED 1.4 650 HARDWARE

1.4650 HARDWARE 1.4.1 MOUNTING & WIRING

Please refer to Chapter 3. Hardware for detailed mounting and wiring instructions.

1.4.2 650 COMMUNICATIONS

The Enervista 650 Setup software communicates to the relay via the faceplate RS232 port or the rear RS485/Ethernet ports. To communicate via the faceplate RS232 port, a standard “straight-through” serial cable is used. The DB-9 male end is connected to the relay and the 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; 0.25, 0.34 or 0.5 mm2 according to European standards) connects the F485 converter to the G650 rear communication port.

In order to minimize communication errors that could be caused by external noise, it is recommended to use a shielded twist pair. In order to avoid loops where external currents could flow, the cable shield must be grounded only at one end.

The converter box (-, +, GND) terminals are connected to the relay (SDA, SDB, GND) terminals respectively. For long communications cables (longer than 1 km), the RS485 circuit must be terminated in an RC network (i.e. 120 ohm, 1 nF). This circuit is shown on Figure 1–17: RS485 CONNECTION FOR 650 UNITS, associated to text Zt(*).

Figure 1–16: RELAY- PC CONNECTION FOR RS232 FRONT PORT

To minimize errors from noise, the use of shielded twisted pair wire is recommended. For correct operation, polarity must be respected, although a different polarity will not damage the unit. For instance, the relays must be connected with all RS485 SDA terminals connected together, and all SDB terminals connected together. This may result confusing sometimes, as the RS485 standard refers only to terminals named “A” and “B”, although many devices use terminals named “+” and “-“.

As a general rule, terminals “A” should be connected to terminals “-“, and terminals “B” to “+”. The GND terminal should be connected to the common wire inside the shield, when provided. Otherwise, it should be connected to the shield. Each relay should also be daisy chained to the next one in the link. A maximum of 32 relays can be connected in this manner

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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.

Lightening strikes and ground surge currents can cause large momentary voltage differences between remote ends of the communication link. For this reason, surge protection devices are internally provided. To ensure maximum reliability, all equipment should have similar transient protection devices installed.

Figure 1–17: RS485 CONNECTION FOR 650 UNITS

To communicate through the G650 rear Ethernet port from a PC a crossover cable is required. If the connection is performed through a hub or a switch, a direct Ethernet cable is required.

1.4.3 FACEPLATE DISPLAY

All messages are displayed on a 20x4 character LCD display. An optional graphic display is also available. Messages are displayed in different languages according to selected model.

1.4.4 MAINTENANCE

G650 requires a minimum amount of maintenance when it is commissioned into service. G650 is a microprocessor based relay and its characteristics do not change over time. As such no further functional tests are required. However, it is recommended that maintenance on the G650 be scheduled with other system maintenance. The maintenance may involve the following:

In-service maintenance:

1. Visual verification of the analog values integrity such as voltage and current (in comparison to other devices on the corresponding system).

2. Visual verification of active alarms, relay display messages and LED indications.

3. Visual inspection for any damage, corrosion, dust or loose wires.

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1 GETTING STARTED 1.4 650 HARDWARE

4. Event recorder file download with further event analysis.

Out-of-service maintenance:

1. Check wiring connections for firmness.

2. Analog values (current, voltages, analog inputs) injection test and metering accuracy verification. Calibrated test

equipment is required.

3. Protection elements setpoints verification (analog values injection or visual verification of setting file entries against

relay settings schedule).

4. Contact inputs and outputs verification. This test can be conducted by direct change of state forcing or as part of the

system functional testing.

5. Visual inspection for any damage, corrosion or dust.

6. Event recorder file download with further events analysis.

Unscheduled maintenance such as during a disturbance causing system interruption:

1. 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.

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1.4 650 HARDWARE 1 GETTING STARTED

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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.

The main features of G650 devices include:

• Protection relay with control capabilities for protection of small and medium generators.

• Replacement for legacy devices in the long term based on improved and open protocols in communications as well as

orientation to machine protection system rather than individual protection functions.

• Based on the 650 platform.

• Full graphic capabilities in large display with control functions and PLC programming.

• Protection elements repeated in three groups, used as independent groups or all elements at the same time.

Figure 2–1: G650 BLOCK DIAGRAM FOR BASIC FUNCTIONALITY MODELS

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2.1 OVERVIEW 2 PRODUCT DESCRIPTION

Figure 2–2: G650 BLOCK DIAGRAM FOR ENHANCED FUNCTIONALITY MODELS

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2 PRODUCT DESCRIPTION 2.2 SUMMARY

2.2SUMMARY 2.2.1 ANSI DEVICE NUMBERS AND FUNCTIONS

DEVICE NUMBER FUNCTION

24 Volt/Hertz (only enhanced model) 25 Synchronism Check 27P Phase Undervoltage 27X Auxiliary Undervoltage 32DIR Directional Power 40 Loss of Excitation 46 Generator Unbalance 47 Negative Sequence Overvoltage 49S Generator thermal model 50/27 Inadvertent Generator Energization 50-2/51-2 Negative Sequence IOC/TOC 50BF Breaker Failure (only enhanced model) 50G

50N Neutral Instantaneous Overcurrent (calculated from the phase currents) 50P Phase Instantaneous Overcurrent 51G

51N Neutral Time Overcurrent (calculated from the phase currents) 51P/V Voltage Restraint Overcurrent 50SG/51SG Sensitive Ground Fault (only enhanced model) 55 Power Factor Limiting (Only enhanced model) 59N Neutral Overvoltage 59P Phase Overvoltage 59X Auxiliary Overvoltage 59G Ground Overvoltage 67N Neutral directional 67G Ground Directional 78V Phase shift / Loss of mains (only enhanced model) 810 Overfrequency 81U Underfrequency 81R Frequency Rate of Change 87G Restricted Ground Fault (only enhanced model) VTFF VT Fuse Failure (only enhanced model)

Ground Instantaneous Overcurrent (measured from 4

Ground Time Overcurrent (measured from 4

current transformer)

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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, 1 for ground, 1 for sensitive ground), 4 voltage inputs (3 for phases, 1 for busbar or auxiliary voltage)

Digital Programmable Contact Inputs (up to 64) Voltages phase to phase and phase to

Digital Programmable Contact Outputs (up to

16) 32 Latched Virtual Inputs

32 Self-Reset Virtual Inputs Virtual Outputs (up to 512) Frequency ModBus User Map Tripping and closing circuit supervision Sequence components of currents and

Analog Inputs (dCmA) Pulse Counters

USER INTERFACE RECORDS OTHERS

Alphanumerical display (4x20) Data Logger Graphic display (16 x 40) Demand Breaker Control

User Programmable LEDs (15) Event Recorder (up to 128 configurable

User Programmable Keys (up to 5) Fault Locator and Fault report (up to 10

Easy menu management thanks to shuttle key Oscillography (up to 20 records) Settings Groups (up to ) Configurable One-Line Diagram (Graphic

model only) Phasor Diagram (available in EnerVista 650

Setup)

Metering Current for phases, ground and sensitive ground inputs

ground Real, Reactive and Apparent Power and

Power Factor Three Phase Energy IEC 870-5-104

voltages

Analog Comparators

events)

records)

Snapshot Events (up to 479) Operations (up to 24)

Front RS232 port, Two rear RS485/ fibre optic ports, 10/100 TX and 100 FX Mbps Ethernet port

ModBus Communications RTU and over TCP/IP

DNP Multimaster (3.0 Level 2)

Breaking Arcing Current (I

IRIG-B synchronization/SNTP

Logic Equations (PLC Editor)

Web Server Application

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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

G650- - - F - G - - - - - DESCRIPTION

B Basic Display (4x20 characters) and basic protection functionality

M Graphic Display (240x128 pixels) with Standard Symbols and basic

N Graphic Display with IEC symbols (240x128 pixels) and basic

E Basic Display (4x20 characters) and enhanced protection

C Graphic Display (240x128 pixels) with Standard Symbols and

D Graphic Display with IEC symbols (240x128 pixels) and enhanced

F None A Redundant RS485 P Redundant plastic fiber optic G Redundant glass fiber optic X Redundant RS485 + fiber remote CAN bus I/O Y Redundant plastic fiber optic + fiber remote CAN bus I/O Z Redundant glass fiber optic + fiber remote CAN bus I/O C Cable Remote CAN Bus I/O

M RS485 + cable Remote CAN Bus I/O

B 10/100 Base TX C 10/100 Base TX + 100 Base FX D 10/100 Base TX + Redundant 100 Base FX E Redundant 10/100 Base TX

1 16 Digital Inputs + 8 Outputs 2 8 Digital Inputs + 8 Outputs + 2 trip/close circuit supervision circuits 4 32 Digital Inputs 5 16 Digital Inputs + 8 Analog Inputs

0 None 1 16 Digital Inputs + 8 Outputs 4 32 Digital Inputs (see Note 1) 5 16 Digital Inputs + 8 Analog Inputs (See Note 1)

LO 24-48 Vdc (range 19.2 – 57.6)

LOR Redundant LO

HIR Redundant HI

Notes:

(1) The digit selected for option G must be equal or higher than the digit selected for option F for models including boards 4 and 5.

(see Note 2)

protection functionality (see Note 2)

functionality (see Note 2)

enhanced protection functionality (see Note 2)

protection functionality (see Note 2)

REAR SERIAL COMMUNICATIONS BOARD 1

REAR ETHERNET COMMUNICATIONS BOARD 2

I/O BOARD IN SLOT F

I/O BOARD IN SLOT G

AUXILIARY VOLTAGE

110-250 Vdc (range 88 – 300) 120-230 Vac (range 96 – 250)

5 Procome, Modbus® RTU,TCP/IP

ENVIRONMENTAL PROTECTION

- Without Harsh (Chemical) Environment Conformal Coating

H Harsh (Chemical) Environment Conformal Coating

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2.3 ORDERING CODE 2 PRODUCT DESCRIPTION

F1G5 is a valid selection and F5G1 is and invalid selection.

(2) The Protection functionality description for basic and enhanced models is listed in section 2.2.1: ANSI DEVICE NUMBERS AND

FUNCTIONS on page 2–3.

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2 PRODUCT DESCRIPTION 2.4 TECHNICAL SPECIFICATIONS

2.4 TECHNICAL SPECIFICATIONS

NOTE: TECHNICAL SPECIFICA TIONS 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.

The isolated ground unit will be used only for those applications where the neutral is completely isolated, and it uses the fifth CT of the unit. This CT has a sensitivity that is 10 times higher than the universal model (connected to 1A or 5A transformers). Therefore, it does not admit such a high permanent overload.

2.4.1.1 PHASE TIME OVERCURRENT (51PH/51PL)

Current Input Phasor (without harmonics) or RMS Rated current For connection to 1 or 5 A CTs. Pickup level 0.05 to 160.00 A in steps of 0.01 A Dropout level 97% to 98% of the pickup level Level Accuracy

Curve Shapes IEEE extremely / very / moderately inverse

Curve Multiplier (Time Dial) 0.00 to 900.00 s in steps of 0.01 s Reset type Instantaneous or time delayed according to IEEE Timing accuracy Operate at > 1.03 times the pickup ±3% of operate time or

Voltage restraint Selectable by setting Saturation Level 48 times the pickup level Snapshot Events Selectable by setting

Values at nominal frequency:

±0.5% of the reading ± 10 mA from 0.05 to 10 A ±1.5% of the reading for higher values.

IEC A/B/C/long-time inverse/short time inverse curve IAC extremely / very / moderately inverse ANSI extremely / very / normally / moderately inverse

I Definite time Rectifier curve FlexCurve™ A/B/C/D user curve

50 ms. (whichever is greater)

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2.4 TECHNICAL SPECIFICATIONS 2 PRODUCT DESCRIPTION

2.4.1.2 GROUND TIME OVERCURRENT (51G)

Values at nominal frequency:

±0.5% of the reading ± 10 mA from 0.05 to 10 A ±1.5% of the reading for higher values.

Curve Shapes IEEE extremely / very / moderately inverse

IEC A/B/C/long-time inverse/short time inverse curve IAC extremely / very / moderately inverse ANSI extremely / very / normally / moderately inverse

I Definite time Rectifier curve FlexCurve™ A/B/C/D user curve

Curve Multiplier (Time Dial) 0.00 to 900.00 s in steps of 0.01 s Reset type Instantaneous or time delayed according to IEEE Timing accuracy Operate at > 1.03 times the pickup ±3% of operate time or

50 ms. (whichever is greater) Saturation Level 48 times the pickup level Snapshot Events Selectable by setting

2.4.1.3 NEUTRAL TIME OVERCURRENT (51N)

Current Input Fundamental Phasor (without harmonics) Pickup level 0.05 to 160.00 A in steps of 0.01 A Dropout level 97% to 98% of the pickup level Level Accuracy

Values at nominal frequency:

±0.5% of the reading ± 10 mA from 0.05 to 10 A ±1.5% of the reading for higher values.

Curve Shapes IEEE extremely / very / moderately inverse

IEC A/B/C/long-time inverse/short time inverse curve IAC extremely / very / moderately inverse ANSI extremely / very / normally / moderately inverse

I2t Definite time Rectifier curve FlexCurve™ A/B/C/D user curve

Curve Multiplier (Time Dial) 0.00 to 900.00 s in steps of 0.01 s Reset type Instantaneous or time delayed according to IEEE Timing accuracy Operate at > 1.03 times the pickup ±3% of operate time or

50 ms. (whichever is greater) Saturation Level 48 times the pickup level Snapshot Events Selectable by setting

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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 Level Accuracy

Curve Shapes IEEE extremely / very / moderately inverse

Curve Multiplier (Time Dial) 0.00 to 900.00 s in steps of 0.01 s Reset type Instantaneous or time delayed according to IEEE Timing accuracy Operate at > 1.03 times the pickup ±3% of operate time

Saturation Level 48 times the pickup level Snapshot Events Selectable by setting

Values at nominal frequency: ±1.5% of the reading ± 1 mA from 0.005 to 16 A

IEC A/B/C/long-time inverse/short time inverse curve IAC extremely / very / moderately inverse ANSI extremely / very / normally / moderately inverse

I2t Definite time Rectifier curve FlexCurve™ A/B/C/D user curve

or 50 ms. (whichever is greater)

2.4.1.5 PHASE AND GROUND INSTANTANEOUS OVERCURRENT (50PH50G)

Overreach < 2% 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. Operate time <50 ms at 3 x Pickup at 50 Hz, typically Timing accuracy at 0 ms time delay (no intentional delay): 50ms

Snapshot Events Selectable by setting

Values at nominal frequency:

±0.5% of the reading ± 10 mA from 0.05 to 10 A ±1.5% of the reading for higher values

at non-zero time delay: ±3% of operate time or 50 ms (whichever is greater)

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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 Level Accuracy

Snapshot Events Selectable by setting

2.4.1.7 SENSITIVE GROUND INSTANTANEOUS OVERCURRENT (50SG)

Snapshot Events Selectable by setting

Values at nominal frequency:

±0.5% of the reading ± 10 mA from 0.05 to 10 A ±1.5% of the reading for higher values

at non-zero time delay: ±3% of operate time or 50 ms (whichever is greater)

Values at nominal frequency: ±1.5% of the reading ± 1 mA from 0.005 to 16 A

at non-zero time delay: ±3% of operate time or 50 ms (whichever is greater)

2.4.1.8 NEGATIVE SEQUENCE TIME OVERCURRENT (51-2)

Current Input Fundamental Phasor (without harmonics) Pickup level 0.05 to 160.0 A in steps of 0.01 A Dropout level 97% to 98% of the pickup level Level Accuracy

2-10 G650 Generator Protection & Control System GEK-113285A

Values at nominal frequency:

±0.5% of the reading ± 10 mA from 0.05 to 10 A ±1.5% of the reading for higher values

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

I2t Definite time Rectifier curve FlexCurve™ A/B/C/D user curve

Curve Multiplier (Time Dial) 0.00 to 900.00 s in steps of 0.01 s Reset type Instantaneous or time delayed according to IEEE Timing accuracy Operate at > 1.03 times the pickup ±3% of operate time

or 50 ms. (whichever is greater) Saturation Level 48 times the pickup level Snapshot Events Selectable by setting

2.4.1.9 NEGATIVE SEQUENCE INSTANTANEOUS OVERCURRENT (50-2)

Current Input Fundamental Phasor (without harmonics) Rated current For connection to 1 or 5 A CTs. Pickup level 0.05 to 160.00 A in steps of 0.01 A Dropout level 97% to 98 % of the pickup level Level Accuracy Values at nominal frequency

±0.5% of the reading ± 10 mA from 0.1 to 10 A

±1.5% of the reading for higher values

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. Operate time 50 ms at 3 x Pickup at 50 Hz, typically Timing accuracy Operate at 1.00 times the pickup ±3% of operate time or

50 ms. (whichever is greater) Snapshot Events Selectable by setting

GEK-113285A G650 Generator Protection & Control System 2-11

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2.4 TECHNICAL SPECIFICATIONS 2 PRODUCT DESCRIPTION

2.4.1.10 GENERATOR UNBALANCE (46)

Gen. nominal current 0.00 to 10.00 A in steps of 0.01 A (rated full load

current of the machine

Stages 2 (

(I2t 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 Level Accuracy Values at nominal frequency

±0.5% of the reading ± 10 mA from 0.1 to 10 A ±1.5% of the reading for higher values

Time dial (K-value) 0.00 to 100.00 in steps of 0.01 Pickup delay 0.0 to 1000.0 s in steps of 0.1 Reset delay 0.0 to 1000.0 s in steps of 0.1 Operate time <50 ms at 50 Hz, typically Timing accuracy ±3% of operate time or 50 ms. (whichever is greater) Snapshot Events Selectable by setting

2.4.1.11 GROUND DIRECTIONAL (67G)

Directionality Forward and reverse selectable by setting Polarizing Voltage, current, dual Polarizing Voltage V

Polarizing Current Operating Current

(measured or calculated, selected by setting)

Isg (measured from 5

current transformer)

Ig (measured from 4th current transformer) Polarizing Voltage threshold 0 to 00 Vac in steps of 1 V Polarizing Current threshold 0.005 A Characteristic angle -90º to +90º in steps of 1º Block Logic Permission or Block selectable by setting Angle accuracy

±2º for I>0.1 A and V>5 Vac Operate time <30ms, typically

2.4.1.12 NEUTRAL DIRECTIONAL (67N)

Directionality Forward and reverse selectable by setting Polarizing Voltage, current, dual Polarizing Voltage V

Polarizing Current Operating Current I

(measured or calculated, selected by setting)

Isg (measured from 5

current transformer)

Polarizing Voltage threshold 0 to 00 Vac in steps of 1 V Polarizing Current threshold 0.005 A Characteristic angle -90º to +90º in steps of 1º Block Logic Permission or Block selectable by setting Angle accuracy

±2º for I>0.1 A and V>5 Vac Operate time <30ms, typically

2-12 G650 Generator Protection & Control System GEK-113285A

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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 Level Accuracy

Timing accuracy ±3.5% of operate time or 50 ms. (whichever is greater) Heating constant 3.0 to 600.0 minutes in steps of 0.1 minute Cooling constant 1.00 to 6.00 times the heating constant in steps of 0.01 K1 constant 0.0 to 8.0 in steps of 0.1 (Negative sequence influence) Snapshot Events Selectable by setting

2.4.1.14 RESTRICTED GROUND FAULT (87G)

Values at nominal frequency:

±0.5% of the reading ± 10 mA from 0.05 to 10 A ±1.5% of the reading for higher values

Pickup level

Dropout level 97% to 98 % of the pickup level Slope 0.00 to 100.00 % in steps of 0.01%

Trip delay Operate time <50 ms at 50 Hz, typically Timing accuracy ±3% of operate time or 50 ms. (whichever is greater) Snapshot Events Selectable by setting

2.4.1.15 PHASE OVERVOLTAGE (59P)

Voltage Input Fundamental Phasor (without harmonics) of phase-to-

Pickup level 3 to 500 in steps of 1 V Dropout level 97% to 98% of the pickup level Level Accuracy

Trip delay 0.00 to 900.00 s. in steps of 0.01 s. Reset delay 0.00 to 900.00 s. in steps of 0.01 s. Timing accuracy ±3.5% of operate time or 50 ms. (whichever is greater) Logic Any/Two/All phases logic selectable by setting Snapshot Events Selectable by setting

0.02 to 20.00 in units of Phase CT Primary in steps of

0.01

0.00 to 600.00 s in steps of 0.01 s

phase voltages

±1% reading ±0.1% Full Scale from 10 to 500 V at nominal frequency

GEK-113285A G650 Generator Protection & Control System 2-13

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

Curve Shapes Fixed time or inverse curve Reset type Instantaneous Curve Multiplier (Time Dial) 0.00 to 900.00 s. in steps of 0.01 s. Timing accuracy ±3.5% of operate time or 50 ms. (whichever is greater) Minimum Voltage Threshold 0 to 500 in steps of 1 V Logic Any/Two/All phases logic selectable by setting Supervised by Breaker Selectable by setting Snapshot Events Selectable by setting

2.4.1.17 NEUTRAL OVERVOLTAGE (59NH)

±1% reading ±0.1% Full Scale from 10 to 500 V at

nominal frequency

Voltage Input Fundamental Phasor of the neutral voltage (calculated

from phases) Pickup level 3 to 500 in steps of 1 V Dropout level 97% to 98% of the pickup level Level accuracy

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 Timing accuracy ±3.5% of operate time or 50 ms. (whichever is greater) Snapshot Events Selectable by setting

2.4.1.18 GROUND OVERVOLTAGE (59G)

Voltage Input Fundamental Phasor of the ground voltage (measured

Pickup level 3 to 500 in steps of 1 V Dropout level 97% to 98% of the pickup level Level accuracy

±1% reading ±0.1% Full Scale from 10 to 500 V at

nominal frequency

from 4th voltage transformer)

±1% reading ±0.1% Full Scale from 10 to 500 V at

nominal frequency

2-14 G650 Generator Protection & Control System GEK-113285A

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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

2.4.1.20 AUXILIARY UNDERVOLTAGE (27X)

Voltage Input Fundamental Phasor of the auxiliary voltage Pickup level 3 to 500 V in steps of 1 V Dropout level 97% to 98% of the pickup level Level accuracy

Curve Shapes Fixed time or inverse curve Reset type Instantaneous Curve Multiplier (Time Dial) 0.00 to 900.00 s. in steps of 0.01 s Timing accuracy ±3.5% of operate time or 50 ms. (whichever is greater) Snapshot Events Selectable by setting

±1% reading ±0.1% Full Scale from 10 to 500V at nominal frequency

±1% reading ±0.1% Full Scale from 10 to 500 V at nominal frequency

2.4.1.21 VOLTS PER HERTZ (24)

Voltage Input Fundamental Phasor of phases or auxiliary voltage input

(selectable by setting) Minimum Voltage 30.00 to 500.00 in steps of 0.01 V Pickup level 0.80 to 4.00 in steps of 0.01 pu V/Hz Dropout level 97% to 98 % of the pickup level Level accuracy ±0.02 pu Timing Curves Definite Time, Inverse A, B and C TD Multiplier 0.05 to 600.00 s in steps of 0.01 Reset delay 0.0 to 900.0 s. in steps of 0.1 s Timing accuracy ±3.5% of operate time or 10 cycles (whichever is

greater) Snapshot Events Selectable by setting

2.4.1.22 UNDERFREQUENCY (81U)

Pickup level 20.00 to 65.00 Hz in steps of 0.01 Hz Dropout level Pickup + 0.03 Hz

GEK-113285A G650 Generator Protection & Control System 2-15

Page 45

2.4 TECHNICAL SPECIFICATIONS 2 PRODUCT DESCRIPTION

Level accuracy Trip delay 0.00 to 900.00 s. in steps of 0.01 s Reset delay 0.00 to 900.00 s. in steps of 0.01 s Minimum voltage threshold 30 to 00V in steps of 1 V Timing accuracy ±3.5% of operate time or 100 ms. (whichever is greater) Snapshot Events Selectable by setting

2.4.1.23 OVERFREQUENCY (81O)

Pickup level 20.00 to 65.00 Hz in steps of 0.01 Hz Dropout level Pickup - 0.03 Hz Level accuracy Trip delay 0.00 to 900.00 s. in steps of 0.01 s Reset delay 0.00 to 900.00 s. in steps of 0.01 s Minimum voltage threshold 30 to 00V in steps of 1 V Timing accuracy ±3.5% of operate time or 100 ms. (whichever is greater) Snapshot Events Selectable by setting

2.4.1.24 DIRECTIONAL POWER (32)

Current, Voltage Fundamental Phasor (primary values) Number of stages 2 Pickup level (two stages) -10000.00 to 10000.00 MW (primary values) in steps of

Characteristic Angle (two stages) 0.00 to 359.99 in steps of 0.01 Accuracy for primary magnitudes ±3% complete range Trip delay (two stages) 0.00 to 900.00 s in steps of 0.01 s Timing accuracy ±3.5% of operate time or 50 ms. (whichever is greater) Block Time after close 0.00 to 900.00 s in steps of 0.01 s Snapshot Events Selectable by setting Operate time: < 45 ms at 50 Hz, typically

±0.01 Hz of the reading

0.01 MW

2-16 G650 Generator Protection & Control System GEK-113285A

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2 PRODUCT DESCRIPTION 2.4 TECHNICAL SPECIFICATIONS

2.4.1.25 POWER FACT OR 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 2 for Lead

2 for Lag Trip delay 0.2 to 300.0 in steps of 0.1 s Timing accuracy ±3.5% of operate time or 100 ms (whichever is greater) Snapshot Events Selectable by setting

2.4.2 CONTROL

2.4.2.1 SYNCHROCHECK (25)

Dead/live levels for line and bus 0.00 to 300.00 in steps of 0.01 V Maximum voltage difference 2.00 to 300.00 V in steps of 0.01 V Maximum angle difference 2.0º to 80.0º in steps of 0.1º Maximum frequency slip 10 to 5000 mHz in steps of 10 mHz Synchronism time 0.01 to 600.00 s in steps of 0.01 s Angle accuracy 3º Dead Source function None

(DL-DB) Dead Line - Dead Bus (LL-DB) Live Line-Dead Bus (DL-LB) Dead Line – Live Bus

Snapshot Events Selectable by setting

2.4.2.2 FUSE FAILURE

Algorithm based on positive sequence of voltage and current Activation by V

2.4.2.3 BREAKER FAILURE (50BF)

Current Input Fundamental Phasor (without harmonics) Rated current For connection to 1 or 5 A CTs. Pickup level for supervision 0.05 to 160.00 A in steps of 0.01 A Pickup level for high level 0.05 to 160.00 A in steps of 0.01 A Pickup level for low level 0.05 to 160.00 A in steps of 0.01 A Pickup level for internal arcing 0.05 to 160.00 A in steps of 0.01 A Dropout level 97% to 98% of the pickup level

GEK-113285A G650 Generator Protection & Control System 2-17

2/V1

ratio

Page 47

2.4 TECHNICAL SPECIFICATIONS 2 PRODUCT DESCRIPTION

Level Accuracy

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 Up to 8 Multiplier factor 0.000 to 65000.000 in steps of 0.001 Overload factor 0 to 1000000 in steps of 1 Board Origin All available input/outputs boards in the device. See

Input origin up to 32 [depending on the board type selection]

2.4.2.5 ANALOG COMPARATORS

Analog Input Any analog value available in the device Analog Maximum Threshold value -100000.000 to 100000.000 in steps of 0.001 Analog Minimum Threshold value -100000.000 to 100000.000 in steps of 0.001 Analog Delay 0.00 to 900.00 in steps of 0.01 Analog Hysteresis 0.0 to 50.00 in steps of 0.1 Analog Direction (for activation inside or outside the

deadband)

±0.5% of the reading ± 10 mA from 0.05 to 10 A ±1.5% of the reading for higher values.

ordering code [F, G, H, J]

IN or OUT

2-18 G650 Generator Protection & Control System GEK-113285A

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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 < 24 cycles Operate time:

at 2 x pickup 12 cycles at 3 x pickup 8 cycles

at 5 x pickup 6 cycles Frequency Rate min. 20.00 to 80.00 Hz in steps of 0.01 Frequency Rate max. 20.00 to 80.00 Hz in steps of 0.01 Frequency Rate delay 0.00 to 60.00 s in steps of 0.01 Snapshot Events Selectable by setting

GEK-113285A G650 Generator Protection & Control System 2-19

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2.4 TECHNICAL SPECIFICATIONS 2 PRODUCT DESCRIPTION

2.4.2.7 INADVERTED GENERA TOR 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 ± 10 mA from 0.1 to 10 A ±1.5% of the reading for higher values

Undervoltage Pickup level 0.00 to 500.00 V in steps of 0.01 V

Dropout level 102% to 103% of pickup level Level accuracy ±1% reading ±0.1% Full Scale from 10 to 500 V at nomi-

nal frequency Operate time <50 ms at 50 Hz, typically Timing accuracy ±3.5% of operate time or 50 ms. (whichever is greater) Snapshot Events Selectable by setting

2.4.2.8 PHASE SHIFT-LOSS OF MAINS (78V)

Loss of Mains Mode One Phase Phase Shift Angle 2.00 to 22.00 in steps of 0.01 degrees Minimum Voltage 30 to 500 in steps of 1 V Level accuracy ± 3º Timing accuracy ±3.5% of operate time or 60 ms (whichever is greater) Snapshot Events Selectable by setting

2.4.2.9 LOSS OF EXCITATION (40)

Operating condition Positive-sequence impedance Characteristic 2 independent offset mho circles (Stages 1 and 2) Center 0.10 to 300.00. Ω (sec.) in steps of 0.01 Radius 0.10 to 300.00. Ω (sec.) in steps of 0.01 Reach accuracy ±3% Undervoltage supervision Selectable by setting UV superv. Level 0.0 to 500.0 v in steps of 0.1 V Trip delay 0.00 to 65.54 s in steps of 0.01 s Operate time <50 ms at 50 Hz, typically Timing accuracy ±3.5% of operate time or 50 ms. (whichever is greater) Snapshot Events Selectable by setting

2-20 G650 Generator Protection & Control System GEK-113285A

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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 KI2t 0.00 to 9999.99 in steps of 0.01 (kA)2 s KI2t integration Time

Maximum openings 0 to 9999 in steps of 1 Maximum Openings in one hour 1 to 60 in steps of 1 Snapshot Events Selectable by setting

0.03 to 0.25 s in steps of 0.01 s

GEK-113285A G650 Generator Protection & Control System 2-21

Page 51

2.4 TECHNICAL SPECIFICATIONS 2 PRODUCT DESCRIPTION

2.4.2.11 BREAKER MAINTENANCE

KI2t Breaker Counters for Phases A, B, C 0.00 to 9999.99 in steps of 0.01 (kA)2 s 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” screen). Snapshot Events Selectable by setting (for each switchgear in “system setup”)

2.4.3 MONITORING

2.4.3.1 OSCILLOGRAPHY

Maximum Records: Up to 20 Oscillography records. Sampling rate: 250, 450, 900, 1800 or 3600 Hz

Full storage capacity: 1 Mb Trigger position:

Trigger: Programmable via PLC Data: 5 current channels and 4 voltage channels

Data Storage: In non volatile memory (flash) without battery Format: International Standard COMTRADE ASCII - IEEE C37.111-1999. Automatic Overwrite: Selectable by setting. (Oscillography records can be concatenated) Snapshot Events: Selectable by setting

5% to 95% of total length

Up to 16 digital channels programmable through PLC

2.4.3.2 FAULT LOCATOR

Method: Single-ended Positive Sequence Module: 0.01 to 250.00 Ohm in steps of 0.01 Ohms Positive Sequence Angle: 25 to 90º in steps of 1º Zero Sequence Module: 0.01 to 750.00 Ohms in steps of 0.01 Ohm Zero Sequence Angle: 25 to 90º in steps of 1º Line Length: 0.0 to 2000.0 in steps of 0.1 (miles or km) Accuracy: 5% (typical) Show Fault on HMI: Selectable by setting Snapshot Events: Selectable by setting Maximum Records: Up to 10 fault report records. Data: Fault date and time, pre-fault currents and voltages, fault currents and voltages,

fault type, distance to the fault (fault location), line parameters, recloser and breaker status information.

Data Storage: In non volatile memory (flash) without battery available through communications

In volatile memory (ram) available through HMI (if selectable by setting)

2-22 G650 Generator Protection & Control System GEK-113285A

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2 PRODUCT DESCRIPTION 2.4 TECHNICAL SPECIFICATIONS

Format: Text in ASCII format

2.4.3.3 SNAPSHOT EVENTS

Capacity: 479 scrolling events Time-tag 1 ms using an internal clock of 100 μs 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 In non volatile memory (flash) without battery The snapshot event recording procedure can be enabled or disabled by setting for each protection function

2.4.3.4 CONTROL EVENTS

Capacity: 128 events programmable through PLC Time-tag:

Timing Accuracy: 1 ms (using the IRIG-B synchronization input) Triggers: By any digital signal programmable through PLC Alarm Possibility to display the event as an alarm on the alarms panel.

Data Storage: In non volatile memory (flash) without battery Control events are also displayed in the snapshot events recording

1 ms plus one plc cycle debounce time of these digital inputs must be added.

Information available always through Communications for all models and also in HMI for models with graphical display (M in ordering code).

using an internal clock of 100 μs. For Digital Inputs, the

2.4.3.5 DEMAND

Channels: 9 Parameters: Ia (kA RMS), Ib (kA RMS), Ic (kA RMS), Ig (kA RMS), Isg (kA RMS), I2 (kA), P

(MW), Q (MVAr) and S (MVA) Current and Power Method Thermal Exponential, Block Interval, Rolling Demand Measurements: Each channel shows the present and maximum measured value, with date and

time for the maximum recorded value. Samples: 5, 10, 15, 20, 30, 60 minutes. Accuracy: Trigger Input Selectable by setting (operation mode selection for the Block Interval calculation

Snapshot Events: Selectable by setting

2.4.3.6 DATA LOGGER

Number of Channels:

Parameters Any available analog actual value

±1%

method)

1 to 16

GEK-113285A G650 Generator Protection & Control System 2-23

Page 53

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. Lines of code: 512 Supported operations: NOT, XOR, OR (2 to 8 inputs), AND (2 to 8 inputs), NOR (2 to 8 inputs),

NAND (2 to 8 inputs), Latch (Reset Dominant), Edge Detectors, Timers.

2 inputs default gates, from 3 to 8 inputs provided in library format. Libraries: Logical gates fully programmable by user. To create user-programmable logic to

be distributed as a single object. Inputs: Any logical variable, contact or virtual input Number of timers: 8 maximum in each logic scheme (provided in library format)

2.4.4.2 FLEXCURVES

Number: 4 (A through D) Reset points: 40 (0 through 1 of pickup) Operate points: 80 (1 through 20 of pickup) Time delay: 0 to 65535 ms in steps of 1 Saturation Level 20 times the pickup level

2.4.4.3 USER-PROGRAMMABLE LEDS

Number: 15 configurable LEDs plus a ready non configurable LED Programmability: from any logical variable, contact, or virtual input Reset mode: Self-reset or Latched.

Reset Signal:

The first 5 LED’s are latched by hardware (red color ones), usually configured for

trip signals.

The following 10 ones (yellow and green) are self-reset but can be latched

through PLC configuration.

The LED’s can be reset by hardware, pressing the front “esc” key during more

than 3 seconds or using the LED reset signal through PLC configuration.

2-24 G650 Generator Protection & Control System GEK-113285A

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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

screen in text display for all models (basic and mimic). The metering screen contains current and voltages for phases and ground in primary values.

2.4.4.5 USER-PROGRAMMABLE FRONT KEYS

Number of configurable Keys: 5 Operation: drive PLC operands

2.4.5 METERING

2.4.5.1 CURRENT

Accuracy: (at nominal frequency)

2.4.5.2 VOLTAGE

Accuracy:

2.4.5.3 REAL POWER (WATTS)

Accuracy:

2.4.5.4 REACTIVE POWER (VARS)

Accuracy:

2.4.5.5 APPARENT POWER (VA)

Accuracy:

2.4.5.6 WATT-HOURS (POSITIVE AND NEGATIVE)

±0.5% of the reading ± 10 mA from 0.05 to 10 A (for phases and ground) ±1.5% of the reading ± 1 mA from 0.005 to 5 A (for sensitive ground) ±1.5% of the reading for higher values

±1% reading ±0.1% Full Scale from 10 to 500 V

±1% of the reading at -0.8 ≤ PF ≤ -1.0 and 0.8 <PF≤1.0

±1% of the reading at-0.2 ≤ PF ≤ 0.2

±1% of the reading

Accuracy: Range: Parameters: 3-phase only Update rate: 100 ms

GEK-113285A G650 Generator Protection & Control System 2-25

±1.0% of the reading ±0 to 2147 MWh

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2.4 TECHNICAL SPECIFICATIONS 2 PRODUCT DESCRIPTION

2.4.5.7 WAR-HOURS (POSITIVE AND NEGATIVE)

Accuracy: Range: Parameters: 3-phase only Update rate: 100 ms

2.4.5.8 POWER FACTOR

Accuracy: 0.02 Parameters: 3-Phase and single phase

2.4.5.9 FREQUENCY

Metering range from 30 Hz to 80 Hz

Accuracy: ±30 mHz at 50 Hz

2.4.5.10 ANGLE

Accuracy: ±3º

±1.0% of the reading

±0 to 2147 MVArh

±36 mHz at 60 Hz

2.4.6 INPUTS

2.4.6.1 AC CURRENT INPUTS

CT Ratio: 1.0 to 6000.0 in steps of 0.1 Rated currents: Appropriate for 1 or 5 A. G650 has universal range for CT (valid for 1 or 5 A to

only one terminal). Relay Burden: < 0.04 Ohm Current Withstand Continuous at 20 A

1 second at 500 A for phases and ground

1 second at 50 A for sensitive ground

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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

VAC inputs do not need varistors, as the impulse test is applied to 100% of the transformers

2.4.6.3 CONTACT INPUTS

Input Activation Voltage Threshold: 10 to 230 Vdc in steps of 1 V (selectable by setting) Impedance: > 100 kOhm Maximum error: Load for voltage supervision inputs: 2 mA + V/100 kOhm Voltage threshold for voltage

supervision inputs: Debounce Time: 1 to 50 in steps of 1 ms Recognition time: < 1ms Timing resolution: 1 ms

For Input Activation Voltage Threshold and Debounce Time there is a single setting for all inputs in the same group (inputs sharing the same common).

Input Type and Delay Input Time are not grouped; there is a different setting for each input. Input Type Positive-Edge / Negative-Edge / Positive/ Negative Delay Input Time 0 to 60000 ms in steps of 1 ms (Input signal time delay)

±10% setting or ± 5 V

< 10 V (fixed)

2.4.6.4 ANALOG INPUTS

Input impedance Current Input (mADC): 0 to -1; 0 to +1; -1 to +1; 0 to 5; 0 to 10; 0 to 20; 4 to 20 (programmable) Conversion Range: -1 to +20mA Accuracy: Type: Passive

GEK-113285A G650 Generator Protection & Control System 2-27

116Ω

±0.2% of full scale

Page 57

2.4 TECHNICAL SPECIFICATIONS 2 PRODUCT DESCRIPTION

2.4.6.5 IRIG-B INPUT

Amplitude modulation: DC SHIFT = Demodulated input (no carrier) Input Voltage: TTL Input Burden: 1.5 mA Input Impedance: 3.3 kOhm Minimum Input Voltage: 2.4 V Maximum Input Voltage: Formats: B000 (*) B001, B002 and B003 (*)

Isolation: 2 kV

± 24 V

(*) Signal combinations recognized in accordance with IRIG Standard 200-95

2.4.7 REAL TIME CLOCK

Accuracy: Backup energy: More than 1 week

Carry continuous: 16 A Make and Carry for 1 sec. 60 A Break at L/R of 40 ms: 0.3 A DC max. at 125 Vdc

Operate Time: < 8 ms Contact material: Silver Alloy

Output Logic Type, Output Type and Pulse Output Time are selectable by setting for each output Output Logic Type Positive / Negative Output Type Normal / Pulse / Latch (Selectable by setting for each output) Pulse Output Time 0 to 60000 ms in steps of 1 ms (applicable only to signals set as pulse type) Separate operate and reset signal can be configured by any digital signal programmable through PLC

Typical ±20 ppm

2.4.8 OUTPUTS

0.25 A DC max. at 250 Vdc

Contact Outputs (F31-F33, F34-F36) for board type 2 (supervision) in slot F:

2-28 G650 Generator Protection & Control System GEK-113285A

The current seal-in circuit is used for verifying the current condition in a circuit during the time that the tripping contact remains closed. If the current in the tripping circuit is maintained over 500 mA, the function is sealed independently of the status of the function that caused the trip.

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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: 120 to 230 V Min/Max AC Voltage 102 / 250 V ALL RANGES Voltage Loss hold-up time 200 ms typical, worst case 100 ms without unit reset Power consumption Typical =25 VA, Maximum =45 VA

Display backlight auto power-off mode after 15 minutes without touching any key, in order to ensure long life and minimum consumption.

2.4.10 COMMUNICATIONS

FRONT PORT:

Front port: COM2 Type RS232 Baud Rate 300, 600, 1200, 2400, 4800, 9600, 19200, 38400, 57600 y 115200 bauds Default Baud Rate 19200 Protocols available:

Typical distance: 1200 m Isolation: 2 kV

ASYNCHRONOUS REAR PORTS:

None or two rear ports (depending on model):

Type (depending on model): Model F None Model A Redundant RS485 Model X Redundant RS485 + fiber CAN for inputs/outputs module Model P Redundant 1mm-plastic F.O. Model Y Redundant 1mm-plastic F.O. + fiber CAN for inputs/outputs module Model G Redundant multimode glass F.O. Model Z Redundant multimode glass F.O. + fiber CAN for inputs/outputs module Model C Cable CAN port for I/O module Model M Cable CAN port for I/O module (cable) + RS485 (ModBus RTU) Optic Features for ST connectors

devices:

Baud Rate: 300, 600, 1200, 2400, 4800, 9600, 19200, 38400, 57600 y 115200 bauds Default Baud Rate 19200

ModBus

COM1, COM2 (rear COM2 multiplexed with front port)

Wave length: 1300nm

Fiber type: multimode 62.5/125 μm or 50/125 μm

RTU / DNP 3.0

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2.4 TECHNICAL SPECIFICATIONS 2 PRODUCT DESCRIPTION

Protocols available: 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: Maximum recommended length 500m Isolation: 2 kV

ETHERNET PORT:

Rear port: COM3 Type (depending on model): Model B: 10/100BaseTX self-negotiable Model C: 10/100BaseTX + 100Base FX Model D: 10/100BaseTX + redundant 100BaseFX (Physical media redundancy) Model E: Redundant 10/100BaseTX self-negotiable ports 10/100BaseTX RJ45 connector 100BaseFX ST connectors Wave length: 1300 nm Fiber type: Protocols available: ModBus® TCP/IP

Typical distance: 1.65 km Response time to ModBus commands: 10 ms Typical Isolation: 2 kV In Models C and D, the 10/100BaseTX port is selected by an internal switch (see 3.3.3) Two witness LED’s for transmission and reception are included

ModBus® RTU / DNP 3.0

multimode 62.5/125 μm or 50/125 μm

DNP over TCP/IP and UDP/IP Http, ftp, tftp (allow the use of a standard Internet browser)

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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 BOL

62.5/125 μm, NA = 0.275 Fiber EOL Output Optical Power BOL

50/125 μm, NA = 0.275 Fiber EOL Output Optical Power at

Logic “0” State

RECEIVER CHARACTERISTICS

Parameter Min. Typ. Max. Unit Reference Input Optical Power

Minimum at Window Edge Input Optical Power

Minimum at Eye Center Input Optical Power Maximum -14 dBm avg. Note 3

-19

-20

-22.5

-23.5

-14 dBm avg. Note 1

-45 dBm avg. Note 2

-33.9 -31 dBm avg. Note 3

-35.2 -31.8 dBm avg. Note 4

Notes:

1. These optical power values are measured with the following conditions: The Beginning of Live (BOL) to the End of Life (EOL) optical power degradation is typically 1.5 dB per industry

convention for long wavelength LEDs. The actual degradation observed in Agilent’s 1300nm LED products is <1 dB, as specified in this data sheet.

Over the specified operating voltage and temperature ranges. With HALT Line State, (12.5 MHz square-wave), input signal. At the end of one meter of noted optical fiber with cladding modes removed. The average power value can be converted to a peak power value by adding 3 dB. Higher output optical power

transmitters are available on special request.

2. The transmitter provides compliance with the need for Transmit_Disable commands from the FDDI SMT layer by providing an Output Optical Power level of <-45 dBm average in response to a logic “0” input. This specification applies to either 62.5/125 μm or 50/125 μm fiber cables.

3. This specification is intended to indicate the performance of the receiver section of the transceiver when Input Optical Power signal characteristics are present per the following definitions. The Input Optical Power dynamic range from the minimum level (with a window time-width) to the maximum level is the range over which the receiver is guaranteed to provide output data with a Bit Error Ratio (BER) better than or equal to 2.5e-10.

At the Beginning of Life (BOL). Over the specified operating temperature and voltage ranges.

4. All conditions for Note 3 apply except that the measurement is made at the center of the symbol with no window timewidth.

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2.4 TECHNICAL SPECIFICATIONS 2 PRODUCT DESCRIPTION

2.4.12 ENVIRONMENTAL CHARACTERISTICS

Operating temperature: Storage temperature:

- 10°C to + 60°C

- 40°C to + 80°C

Humidity (non condensing): 95% Altitude Up to 2000 m Installation category II

2.4.13 PACKAGING AND WEIGHT

Net weight: 5 kg Packaged: 6 kg Package dimensions: 30x40x40 cm (DxWxH)

2.4.14 TYPE TESTS

CATEGORY STANDARD CLASS TEST

EMC IEC 61000-4-1 IEC 60255-22-1 III Oscillatory waves immunity

IEC 61000-4-2 IEC 60255-22-2 IV Electrostatic discharge immunity test IEC 61000-4-3 IEC 60255-22-3 III Radiated electromagnetic field disturbance test IEC 61000-4-4 IEC 60255-22-4 IV Electrical fast transient IEC 61000-4-5 IEC 60255-22-5 IV Surge immunity test IEC 61000-4-6 IEC 60255-22-6 III Conducted electromagnetic field disturbance test IEC 61000-4-8 EN 61000-4-8 IV Power frequency magnetic field immunity ENV50204 III Radiated electromagnetic field disturbance test –

EMC Emisivity IEC 60255-25 EN 61000-6-4 A Conducted and radiated emissions Product IEC 60255-5 2 kV Insulation resistance – dielectric test

IEC 60255-5 6kV .5J Impulse test IEC 60255-11 100 ms Power supply Voltage dips/interruptions/variations:

Mechanical IEC 60255-21-1 I Vibration test (sinusoidal)

IEC 60255-21-2 IEC 60255-21-3

I II

1890 MHz.

Shock and bump Seismic

Type test report available upon request. G650 has been designed to comply with the highest existing requirements. More specifically, UNIPEDE recommendations

for high voltage substations are followed, even if for most applications such high classes are not required. The relay complies with ANSI C37.90 standards, and has been designed to comply with international standards.

2.4.15 APPROVALS

ISO9001 Registered system. CE marking: Meets the CE standards relevant for protections.

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2 PRODUCT DESCRIPTION 2.5 EXTERNAL CONNECTIONS

2.5EXTERNAL CONNECTIONS

Figure 2–3: G650 WIRING DIAGRAM (189C4216H17R1)

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2.5 EXTERNAL CONNECTIONS 2 PRODUCT DESCRIPTION

USER

CONFIGURABLE

INPUTS

SLOT F CONFIGURATION (BOARD TYPE 1)

INPUTS F1 OUTPUTS F1

F1 + CC1 F2 + CC2 F3 + CC3 F4 + CC4 F5 + CC5 F6 + CC6 F7 + CC7 F8 + CC8 F9 - COMMON 1/8 COMMON 1/8 F10 - COMMON 9/16 COMMON 9/16 F11 + CC9 NOT USED F12 + CC10 NOT USED F13 + CC11 NOT USED F14 + CC12 NOT USED F15 + CC13 NOT USED F16 + CC14 NOT USED F17 + CC15 NOT USED F18 + CC16 NOT USED

52b F19 50P BLOCK F20

O1 FREQ PICKUP 51P BLOCK F21 50-2 BLOCK F22 50G BLOCK F23

O2 27/59 PICKUP 51G BLOCK F24 51-2 BLOCK F25 67G BLOCK F26

USER CONFIGURABLE INPUTS

O3 50/67G PICKUP

O4 51/67G PICKUP

O5 50/67P PICKUP

O6 51/67P PICKUP

USER CONFIGURABLE OUTPUTS

O8 TRIP

F27 F28 F29 F30 F31 F32 F33 F34 F35 F36

MANUAL CLOSE

SLOT F CONFIGURATION (BOARD TYPE 2)

INPUTS F2 OUTPUTS F2

F1 + COIL 1

VVVV

SUPERVISION 52/a

O1 FREQ PICKUP

F2 - 52/a F3 + COIL 1

SUPERVISION 52/b

COIL 1

O2 27/59 PICKUP

F4 - 52/b F5 + CC1 F6 + CC2 F7 + CC3 F8 + CC4 F9 - COMMON 1/4 COMMON 1/4

52b F23 50P BLOCK F24 51P BLOCK F25 50-2 BLOCK F26

O3 50/67G PICKUP

O4 51/67G PICKUP

O5 50/67P PICKUP

F10 - COMMON 5/8 COMMON 5/8 F11 + CC5 F12 + CC6 F13 + CC7 F14 + CC8 F15 + COIL 2

50G BLOCK F29 51G BLOCK F30 51-2 BLOCK 67G BLOCK F32

O6 51/67P PICKUP

I SENS

USER CONFIGURABLE OUTPUTS

SUPERVISION 52/a

F16 - 52/a I SENS F17 + COIL 2

SUPERVISION 52/b

COIL 2

F18 - 52/b

F19 F20 F21 F22

F27 F28

F31

MANUAL CLOSE

F33 F34

F35

TRIP

F36

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3 HARDWARE 3.1 MODULE DESCRIPTION

3 HARDWARE 3.1MODULE DESCRIPTION

AAnnaalloog

iinnppuutts

VVTTs

aannd

CCTTs

HHiigghhSSppeeeeddsseerriiaallCCAANNBBuus

CPU

Module

SCREEN

Digital

I/O

Optional

Digital

I/O

Power

Supply

KKeeyyppaad

G650 units incorporate the following modules:

• Power supply, which can be simple or redundant, depending on the selected model

• Front module with alphanumerical (4 x 20) or optional graphical (16 x 40 characters) display. It includes the bus

on its rear, which communicates with the rest of modules via a high speed CAN bus.

• Transformers module with 5 current transformers and 4 voltage transformers

• CPU including a powerful DSP for measure processing as well as synchronous and asynchronous communication

accessories.

• Input/Output module included in basic unit

• Optionally, a second I/O module can be added.

SShhuuttttlleekkeey

RRS

22332

LLooccaall/

RReemmoot

Figure 3–1: BLOCK DIAGRAM

GEK-113285A G650 Generator Protection & Control System 3-1

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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.

A relay connected to the low voltage side of the power supply monitors this voltage. The three contact terminals, normally open, common, and normally closed, are available at the external connector terminals. This relay monitors only the power supply integrity and it is not controlled by the main microprocessor. This way, if we want a relay to monitor whether the unit is ready to protect (READY), we should program one of the auxiliary relays in the unit.

This is a “fly-back” type power supply, providing high efficiency, stability and reliability thanks to the maturity of this technology. There are two available ranges, Hi and Low, in order to optimize efficiency and general performance, including the capability to tolerate auxiliary voltage interruptions (dips).

Oversized components highly resistant to temperature are used. For example, all capacitors are specified to stand up to 105ºC, transformer components are specially designed to stand up to 180ºC, the used MOSFET transistor is of very low resistance, supports high voltage and is refrigerated by an oversized heat sink. This allows to support temperatures over the 60ºC shown in the Technical Characteristics section, and prolonged overloads such as the ones occurring at batteries in deep charge mode (much higher than +15% voltage shown in the Technical Characteristics section).

High capacitance capacitors are also used, providing high tolerance to prolonged dips, 100ms, even in the most unfavorable consumption conditions. This allows the relay to continue with normal operation without undesired resets, which would cause a long time of protection unavailability.

Figure 3–2: shows the location of communications modules over the CPU. These modules have been designed in accordance with the “plug and play” philosophy, so that units can be easily updated after their purchase, allowing for a simple and economical migration of the application.

Figure 3–2: COMMUNICATIONS MODULE

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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).

The front of the relay is made of a thermoplastic, flame retardant (V0), highly resistive material, which guarantees the unit’s immunity to all kinds of EMI/RFI/ESD interferences. As well, an IP51 (IEC 529) protection degree against dust and water through the front and with the relay mounted in the panel.

In order to guarantee safety and preventing access to the unit by unauthorized personnel, the front part of the relay has a sealable cover to protect the RS 232 front port and the operation mode key.

3.3.1 MOUNTING

The unit is designed for semi-flush mounting . The relay is secured to the panel with the 4 M6 screws provided with the unit. The user has access to the front keypad, display and communication port. The wiring is at the rear of the unit. The drilling dimensions are shown on Figure 3–4:

Figure 3–3: PANEL MOUNTING

The relay width allows the mounting of two units on a standard 19’’ panel, 8 units high.

GEK-113285A G650 Generator Protection & Control System 3-3

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3.3 MECHANICAL DESCRIPTION 3 HARDWARE

(1,38)

169 ( 6,65 )

260,7 ( 10,26 )

( 9,30 )

237

ESC

266,7 ( 10,50 )

GE Multilin 650

SIDE VIEW

FRONT VIEW

210 ( 8,27 )

186 ( 7,32 )

4x O7 ( ,27 )

190,5 ( 7,5 )

263 ( 10,36 )

NOTE: All dimensions are shown in mm ( inches ).

PANEL MOUNTING CUTOUT

Figure 3–4: DRILLING DIMENSIONS DIAGRAM

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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 3-5

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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.

The relay is wired through the terminal blocks located at the rear of the unit. The magnetic module, which receives the CT secondary currents and the metering voltages, incorporates a very robust

terminal board (columns A and B). Current inputs provide automatic shorting of external CT circuits. The maximum recommended cable section for this terminal board, with the appropriate terminal, is 6 mm

(AWG 10).

The rest of the terminal blocks, F and G for I/O and H for power supply, incorporate high quality connectors with the capacity to withstand a rated current of 15 A at 300 V. These terminal blocks admit a cable section of up to 2.54 mm2 (AWG

12). The communication boards have a different type of connector depending on the selected media: RS485, glass or plastic

fiber optic.

Figure 3–6: CONNECTORS LOCATION

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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) ST Ethernet 100 FX (100BaseFX) ST CAN Fiber ST

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 communications board and CAN, and the lower port for the ETHERNET board in any of its configurations.

Figure 3–8: DETAIL OF INSERTION/EXTRACTION OF COMMUNICATION MODULES

The transformers module with the VTs and CTs is already connected to a female connector screwed to the case that incorporates shorting bars in the current inputs, so that it can be extracted without the need to short-circuit the currents externally . It is very import ant, for safety reasons not to change or swi f t the terminals for CTs and VTs.

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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

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3 HARDWARE 3.4 WIRING

3.4WIRING 3.4.1 EXTERNAL CONNECTIONS

G650 units can hold different options for F module:

Option 1: Board with 16 digital inputs and 8 outputs. Option 2: Board with 8 digital inputs, 4 circuit supervision inputs, 6 conventional outputs, and two current sensing

outputs

Option 4: Board with 32 digital inputs. Option 5: Board with 16 digital inputs and 8 analog inputs.

For slot G there are four different options:

Option 0: No board Option 1: Board with 16 digital inputs and 8 outputs. Option 4: Board with 32 digital inputs. Option 5: Board with 16 digital inputs and 8 analog inputs.

The number selected for slot G must be equal or higher than the number selected for option F for models including boards 4 and 5.

3.4.2 DIGITAL INPUTS WITH TRIP CIRCUIT SUPERVISION

The Option 2 I/O board includes two groups of 4 inputs with one common, in terminals F9 to F10. It also includes 6 auxiliary outputs, in terminals F19 to F30 with normally open contacts and two current sensing (latching) outputs (F31-F33 and F34F36).

Besides, there are 2 groups of inputs for trip circuit supervision. The first group includes two isolated digital inputs, terminals F1-F2 and F3-F4. The second group, symmetrical and identical to the first, is formed by isolated voltage inputs F15-F16 and F17-F18.

Using voltage detectors and current sensing, it is possible to implement several trip or close circuit supervision schemes, as well as protection of the unit output contact.

In order to implement these schemes, it is not necessary to perform any setting in the unit. Internal functions are always operative. The detailed description of trip circuit supervision is included in chapter 5 in this manual.

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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. As with any other relay manipulation, the relay power supply must be removed and the operation must be performed only by skilled personnel.

The default port selected by switch is 10/100 TX in factory configuration. The switch selects between cable (10/100 TX) and the first fiber port (100 FX). In Ethernet board type D (double fiber port) the backup channel is always fiber.

Figure 3–10: FIBER/CABLE SELECTION

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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.

OPB (DB) FIBER OPTIC CABLE

62.5/125 μm 50/125 μm

11. 4 8 0

10.9 7.4 0.3

10.5 7.1 0.5

9.6 6.2 1.0

8.5 5.3 1.5

7.3 4.3 2.0

63.32.5

LENGTH (KM)

GEK-113285A G650 Generator Protection & Control System 3-11

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3.5 TRANSCEIVER OPTICAL POWER BUDGET VERSUS LINK LENGTH 3 HARDWARE

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4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE

4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.1ENERVISTA 650 SETUP SOFTWARE INTERFACE

4.1.1 INTRODUCTION

The EnerVista 650 Setup software provides a graphical user interface (GUI) as one of two human interfaces to a 650 device. The alternate human interface is implemented via the device’s faceplate keypad and display (see Human Machine Interface section in this chapter).

The EnerVista 650 Setup software provides a single facility to configure, monitor, maintain, and trouble-shoot the operation of relay functions, connected over local or wide area communication networks. It can be used while disconnected (i.e. offline) or connected (i.e. on-line) to a 650 device. In off-line mode, settings files can be created for eventual downloading to the device. In on-line mode, you can communicate with the device in real-time.

The EnerVista 650 Setup software, provided with every G650 relay, can be run from any computer supporting Microsoft Windows interface features. The EnerVista 650 Setup Help File provides details for getting started and using the EnerVista 650 Setup software interface.

This software package uses ModBus protocol, and it is designed to communicate with a single relay at a time. GE offers different communication software packages, such as GE-POWER, which can be used to communicate simultaneously with several relays.

EnerVista 650 Setup software provides an easy way to configure, monitor and manage all G650 features.

® 95, 98, NT, 2000, ME, and XP. This chapter provides a summary of the basic EnerVista 650 Setup software

4.1.2 ENERVISTA 650 SETUP SOFTWARE OVERVIEW

4.1.2.1 ENGAGING A DEVICE

The EnerVista 650 Setup software may be used in on-line mode (relay connected) to directly communicate with a 650 device.

4.1.2.2 USING SETTINGS FILES

The EnerVista 650 Setup software interface supports three ways of handling changes to relay settings:

1. In off-line mode (relay disconnected) to create or edit relay settings files for later download to communicating relays.

2. While connected to a communicating relay to directly modify any relay settings via relay data view windows, and then save the settings to the relay.

3. You can create/edit settings files and then write them to the relay while the interface is connected to the relay.

Settings files are organized on the basis of file names assigned by the user. A settings file contains data pertaining to the following types of relay settings:

•Product Setup

•System Setup

•Protection Elements

•Control Elements

•Inputs/Outputs

•Relay Configuration

•Logic Configuration

4.1.2.3 VIEWING ACTUAL VALUES

You can view real-time relay data such as input/output status and measured parameters.

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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:

• Event Recorder facility: The event recorder captures contextual data associated with the last 479 events, listed in

chronological order from most recent to oldest.

• Oscillography facility: The oscillography waveform traces and digital states are used to provide a visual display of

power system and relay operation data captured during specific triggered events.

4.1.2.5 FIRMWARE UPGRADES

The firmware of a G650 device can be upgraded, locally or remotely, via the EnerVista 650 Setup software. The corresponding instructions are provided by the EnerVista 650 Setup Help file under the topic “Upgrading Firmware”.

Modbus addresses assigned to firmware modules, features, settings, and corresponding data items (i.e. default values, minimum/maximum values, data type, and item size) may change slightly from version to version of firmware.

The addresses are rearranged when new features are added or existing features are enhanced or modified.

4.1.2.6 ONE LINE DIAGRAMS

You can configure an one line diagram (bay mimic) to be used in relays with graphical display.

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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

• Working area

• Status bar

Title

Working Area

Figure 4–1: ENERVISTA 650 SETUP MAIN SCREEN

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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. Connect the relay ground terminal and the communicating computer to a good grounding. Otherwise, communication may not be viable, or even, in worst cases, the relay and/or the computer could result damaged by overvoltages.

For on-line working, previously ensure that all relay communication parameters, such as baudrate, slave ModBus address, etc., match the computer settings.

Figure 4–2: COMMUNICATION PARAMETERS MENU

The “Communication > computer” screen is divided in several subsections:

• Computer settings: Main communication parameters for serial communication and control type selection.

• ModBus/TCP Setup (if ModBus /TCP is selected as control type): Communication parameters for ModBus TCP communication.

• Communication control: Device communication status (communicating or not communicating).

• Communication optimization: allows optimizing the communication time outs and failure establishing.

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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.

ModBus Slave Address: ModBus addresses used for serial and Ethernet communication. Communication ports: port used in the computer for serial communication. Baud Rate: Baud rate for serial communication (from 1200 up to 115200 bauds in EnerVista 650 Setup, from 300 to

115200 in relay).

Parity: parity for serial communication. None, odd or even can be selected. Control Type: The available control modes are:

• No Control Type, this option selects the serial communication mode, for use with serial communication ports (front

port, RS485, or plastic or glass fiber optic).

• MODBUS/TCP, this option selects ModBus TCP/IP communication mode, for communication through the Ethernet

port. In this case, the top right window will show the typical parameters to be programmed; IP address, port address and unit identifier in the MODBUS TCP SETUP section.

• MODEM, this option displays the parameter to set in case of using a modem for the communication, such as Phone

number, Time out (sec.), init. command, type of dialing (tones or pulses).

4.1.4.2 COMMUNICATION CONTROL:

Located at the bottom of the screen, it shows the status of the communication with the relay. With relay not communicating, a message “650 Setup is not talking to an 650” will be shown and ON button will be enable. Pressing this button, 650 Setup start communicating with the relay.

With relay communicating a message “650 Setup is now talking to an 650” will be shown and OFF will be enable. Pressing this button, communications between relay and PC will be closed.

4.1.4.3 COMMUNICATION OPTIMIZATION:

The parameters shown on the bottom right window (Communication optimization) can improve communication, although it is recommended to leave the default values indicated by the EnerVista 650 Setup. These parameters are the maximum time to wait for a response in the relay (in ms) and the maximum attempts to perform before assuming communications failure.

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gn(

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 rela

configuration

Is it necessary to

program

additional logic?

NO NO

YES

Launch the Logic Configuration tool in EnerVista

650 Setu

Create new or modify the existing logic:

Compile and save logic file (*.pep) and drawing

desi

Exit PLC Graphic Editor and save the *.650 file

“Setpoint>Logic Configuration”

“File>Open Project”

*.aut) in Logic Configuration tool

from the main a

lication menu

Is the relay completely

configured?

YES

Save *.650 settings & configuration file

Store in the computer the Logic configuration files (*.pep, *.aut, *.lib) as

4-6 G650 Generator Protection & Control System GEK-113285A

well as the *.650 for further logic changes.

Figure 4–3: OFF-LINE MODE FILE MANAGEMENT

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4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE

T able 4–1: TYPES OF FILES GENERATED BY ENERVISTA 650 SETUP SOFTWARE OPERATION MODE OFF-LINE:

SETTINGS & CONFIGURATION FILE *.650

Description Protection Settings and Configuration Section

Created by EnerVista 650 Setup

Relay configuration file containing all protection

Contents

How to save

How to open

How to transfer to relay

elements Settings, input/output and LEDs configuration, graphic display configuration, etc. Equations corresponding to the logic created and compiled in the PLC Editor

EnerVista 650 Setup:

“File>Save *”

EnerVista 650 Setup:

“File>Open *”

Connect with the relay (“Communications>Computer”) Open the created file (“File>Open *”) Send to relay from the menu: “File>Send info to relay” Note that texts used in the configuration of inputs, outputs, etc. are not sent to the relay. The only texts sent to relay are operations, events, and LEDs.

LOGIC CONFIGURATION FILES (*.PEP, *AUT, *.LIB) *.PEP *.AUT *.LIB

Graphical edition

Header for Logic project

Logic configuration graphic editor (PLC Editor)

PLC project file containing the necessary information relative to the relay model, logic libraries included in the project (*.lib), graphic file name (*.aut), etc.

PLC Editor:

“File>Save Project”

PLC Editor: “File>Open

Project”

Connect with the relay (“Communications>Computer”) Launch Logic equations Editor (“Setpoint>Logic Configuration”) Open the created PLC project (“File>Open Project”) Compile the project (“Run>Compile”) Now the logic (virtual outputs) can be sent directly to relay (“Run>Send Equations to Relay”). Texts of virtual outputs are not stored in the relay, only in the logic configuration files to be edited.

container. Logic equations (Virtual Outputs) in FDB format.

Logic configuration graphic editor (PLC Editor)

PLC Project file containing all the drawings used by the logic, required by 650 relay based on IEC 61131-3 standard. Functional block diagram (FDB).

PLC Editor:

“File>Save Project”

PLC Editor: “File>Open

Project”

User programmable logic objects

Logic configuration graphic editor (PLC Editor)

Library file to be included as an object in a PLC project. Logic packages that can be stored into libraries and be distributed in different PLC projects.

PLC Editor:

“File>Save Library”

PLC Editor: “File>Library>New

Library”

In case of using element libraries (either existing (“File Library>Open Library”) or created by the user (“File Libra r y> New Library”), the program will create and manage the corresponding files (*.lib) in a folder named FDB (Functional Block

Diagram). These files are used for the PLC project compilation. It is necessary to store them with the other logic configuration files that built the PLC project (*.pep, *.aut, *.lib).

Besides sending basic information to the relay (Settings + configuration) in *.650 format, it is recommended to store *.650, *.pep, *.aut and *.lib files inside the relay (“Communication>Upload info files to relay”), to ensure that logic configuration files will be available in the future for further logic modifications; either if these files are not used by the relay, they are required for connecting to a relay and analyzing its configuration. The program manages the logic configuration files globally, so that when the user selects to save file *.pep in the relay, the associated *.aut and *.lib files are also stored.

File storage inside the relay (RECOMMENDED)

Retrieval of files stored in the relay (RECOMMENDED)

“Communication > Upload info files to relay” through Ethernet

“Communication > Download info files from relay” through Ethernet

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(

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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 rela

configuration

YES

Is it necessary to

program

additional logic?

Launch the Logic Configuration tool in EnerVista

650 Setu

“Setpoint>Logic Configuration”

Create new or modify the existing logic

“File>Open Project”

and save logic file (*.pep) and drawing design (*.aut) in Logic Configuration tool (“File>Save

Send logic to relay (“Run>Send Equations to

Is the relay completely

configured?

Compile (“Run>Compile”)

Project”)

”) and Exit PLC Graphic Edito

Rela

YES

Save all settings & configuration (“File>Get info from relay”)

Store in the relay the Logic configuration files (*.pep, *.aut, *.lib) as well as the

*.650 for further logic changes. (“Communication>Upload info files to relay”)

Figure 4–4: ON LINE MODE FILE MANAGEMENT

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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

SETTINGS & CONFIGURATION FILE *.650

Description Protection Settings and Configuration Section

Created by EnerVista 650 Setup

Relay configuration file containing all protection

Contents

How to transfer to relay

elements, settings, input/output and LEDs configuration, graphic display configuration, etc. Equations corresponding to the logic created and compiled in the PLC Editor

Connect with the relay (“Communications>Computer”) Connect with the relay (“Communications>Computer”)

Send settings and configuration from file

LOGIC CONFIGURATION FILES (*.PEP, *.AUT, *.LIB) *.PEP *.AUT *.LIB

Graphical edition

Header for Logic project

Logic configuration graphic editor (PLC Editor)

PLC project file containing the necessary information relative to the relay model, logic libraries included in the project (*.lib), graphic file name (*.aut), etc.

Launch 650 Logic equations editor (“Setpoint>Logic Configuration”)

Open the created PLC project (“File>Open Project”) Compile the project (“Run>Compile”)

Now the logic (virtual outputs) can be sent directly to relay (“Run>Send Equations to Relay”). Texts of virtual outputs are not stored in the relay, only in the logic configuration files to be edited.

container. Logic equations (Virtual Outputs) in FDB format.

Logic configuration graphic editor (PLC Editor)

PLC Project file containing all the drawings used by the logic, required by 650 relay based on IEC 61131-3 standard. Functional block diagram (FDB).

User programmable logic objects

Logic configuration graphic editor (PLC Editor)

Library file to be included as an object in a PLC project. Logic packages that can be stored into libraries and be distributed in different PLC projects.

Modify settings and configuration directly in the relay:

PLC Editor: “File>Save Project” “File>Save Library”

How to save

How to store in the relay “Communication>Upload info files to relay” through Ethernet

How to retrieve from the relay

EnerVista 650 Setup: “File>Get info from relay”. User definable texts retrieved are operations, events, and LEDs.

The relay will not provide this information unless the *.pep file is stored in the relay

To store the logic configuration files in the relay use the “Communication>Upload info files to relay” option

“Communication/Download info files from relay” through Ethernet

The relay will not provide this information unless the *.pep file is stored in the relay.

REMINDER:

Logic programming support files (*.pep, *.aut, *.lib) CANNOT be retrieved directly from the relay.

It is necessary * Either to have stored these files in the PC * Or to have uploaded previously the files into the relay (“Communication>Upload info files to relay”)

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4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES

4.1.6 ENERVISTA 650 SETUP MENU STRUCTURE

The EnerVista 650 Setup menus structure is shown in Table 4–3:.

Unless specified, options are available in both On-line and Off-line mode.

Options enabled only in On-line mode are marked as (*) Options enabled only in Off-line mode are marked as (**) The “View > Langua ge” submenu allows the user to change the default language for the EnerVista 650 Setup program and

it is only enabled when the relay is not communicating and no file has been opened.

Table 4–3: ENERVISTA 650 SETUP MENUS STRUCTURE

FILE SETPOINT ACTUAL

New (**) Product Setup Front Panel NA Computer Login user Traces

Open (**) System Setup Status NA Modem (*)

Save (**)

Save As (**)

Close (**) Inputs/Outputs Records (*) NA

Config File Converter

Properties (**)

Get info from relay (*)

Send info to relay (*)

Print Setup (**)

Print Preview (**)

Print (**) NA Print to file

(**) Exit

Protection Elements

Control Elements

Relay Configuration

Logic Configuration

Clock (*) NA

Metering NA Troubleshooting (*)

Inputs/Outputs NA Calibration (*)

OPERATIONS (*)

COMMUNICATION SECURITY VIEW HELP

Instruction Manual

Upgrade firmware version (*)

Upgrade operating system (*)

Upgrade 650 Web Server

Upload info files to relay

Download info files from relay

Change Password

User Management

ModBus Memory Map

GE Multilin on the web

About

EnerVista

650 Setup

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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

New (**)

Open (**) Open a settings and configuration file for off-line working.

Save (**) Save *.650 settings and configuration file

Save As (**) Save as *.650 settings and configuration file.

Close (**) Close the opened *.650 file in EnerVista 650 Setup. Config File (*.650)

Converter Properties (**) File properties for *.650.

Get info from relay (*)

Send info to relay (*) Send and write the *.650 settings and configuration to the relay.

Print Setup (**) To configure printer settings.

Print Preview (**) Preview of settings and configuration file printing format.

Print (**) Launch the *.650 file to be printed.

Print to file (*.xls) (**) *.650 printed to file in excel format.

Exit Quit the application closing all the open windows.

Create a new settings and configuration file, with the default relay settings and no configuration

Tool to convert the *.650 files from one version to another

Retrieve the *.650 settings and relay configuration compiled equations from the relay.

Options enabled only in On-line mode are marked as (*). Options enabled only in Off-line mode are marked as (**)

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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” edition. For enabling access to this menu, there must be no communication between the PC program and the relay.

Figure 4–5: OPEN FILE MENU

Once the *.650 file with the appropriated relay model (FXGX) is selected, the program will enable the off-line options to fully program the unit. The enabled menus in the EnerVista 650 Setup program are: File, Setpoint, Actual, Communication, View and Help.

The off-line mode displays the File, Setpoint, Actual, Communication, Security, View and Help submenus to program the unit.

The Actual values submenus are for structure purposes only Values are not refreshed while the relay is not communicating. The “Save as” and ”Close” submenus are used to save the *.650 file into the computer and to close the current file. To work

in off line mode for settings and configuration edition it is not necessary to use the ”Close” option, a new *.650 can be opened without closing the previous one. The ”Close” option is used to clear all data in EnerVista 650 Setup program, enabling ”Upgrade firmware version” and “Upgrade Operating system” options.

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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. It is possible to change the model type (FXGX) using the conversion tool. It must be taken into account that part of the logic

can be readjusted to fit the new input and output boards selection. Notice also that the external wiring of inputs and outputs board are different for type 1, 2, 4 and 5.

4.1.7.3 PROPERTIES

When this option is selected, the program will show a screen including the relay model information, firmware version, etc. of the file being edited, as shown on Figure 4–7:

Figure 4–7: FILE PROPERTIES MENU

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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.

b) PRINT PREVIEW

Option to preview the whole settings and configuration file (*.650) in paper format to be printed as shown in Figure 4–8:

Figure 4–8: PRINT PREVIEW OF SETTINGS FILE

c) PRINT

In this option, the program will print the relay configuration using the PC default (active) printer on port COMx or LPT. This option is active only in off-line mode, in file edition, and not in on-line mode, connected with the relay.

d) PRINT TO FILE (*XLS)

Possibility to export the configuration file to an Excel file using the “Print to file (*.xls)” option.

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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

Product Setup

System Setup

Protection Elements

Control Elements

Inputs/Outputs Contact I/O settings for all boards available in device, Remote Comms.

Relay Configuration

Logic Configuration

61850 Configuration

Clock (*)

Options enabled only in On-line mode are marked as (*). Options enabled only in Off-line mode are marked as (**)

Communications settings for all protocols and physical mediums. ModBus user map definition, fault report, oscillography, data logger and demand settings.

General Settings, Flex Curves Definition, Breaker settings and maintenance, and switchgear snapshot events management.

Phase, Neutral, Ground, Sensitive Ground and Negative Sequence Current Settings. Voltage Elements settings and Power Settings management.

Setting groups, under and overfrequency settings, autoreclose, breaker failure VT fuse failure.

Configuration of Outputs, LEDs, Operations, Protection Elements, Oscillography, Control Events, Switchgear, Inputs, Virtual Inputs, Operations and HMI. Whole relay configuration with internal relay signals or user-definable ones as logic (virtual outputs).

Logic configuration graphic editor (PLC Editor). It is a PLC Project file editor that contains all the internal drawings used to make the logic (virtual outputs) based on IEC 61131-3 standard. Functional block diagram (FDB).

61850 Configuration tool. Only available for IEC61850 models (6) when communicating through Ethernet with EnerVista 650 Setup.

Relay synchronization to computer clock or to user-definable date and time. On-line mode only.

4.1.8.1 PRODUCT SETUP

Table 4–6: GENERAL OVERVIEW OF PRODUCT SETUP MENU:

PRODUCT SETUP

Communication Settings

ModBus User Map

Fault Report Fault report settings. Possibility to show fault reports on HMI screen.

Oscillography

Data Logger Data logger configuration

Demand

Options enabled only in On-line mode are marked as (*). Options enabled only in Off-line mode are marked as (**)

Serial Ports, Network (Ethernet), ModBus Protocol, DNP Slave, IEC 8705-104 and SNTP settings .

ModBus user map definition. The ModBus user map is formed by 256 records, selectable from the complete relay ModBus map.

Oscillography settings (trigger position, samples per cycle, etc.). The trigger and digital channels (up to 16) must be configured in “Setpoint>Relay configuration”.

Demand settings. The demand trigger and demand reset signals must be configured in “Setpoint>Relay configuration”

a) COMMUNICATION SETTINGS

This section details the settings related to communication parameters for the different protocols available in the G650.

Table 4–7: GENERAL OVERVIEW OF COMMUNICATION SETTINGS MENU:

COMMUNICATION SETTINGS

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Serial Ports Baud rate and parity for COM1 and COM2 serial communication ports.

Ethernet communication parameters for COM3 (IP Address, Netmask, Gateway IP)

Network (Ethernet)

ModBus Protocol

DNP3 Slave

IEC 870-5-104

SNTP (*) Synchronization over Ethernet settings

Options enabled only in On-line mode are marked as (*). Options enabled only in Off-line mode are marked as (**)

NOTE: The ModBus Slave address used by Ethernet ports is the one set for COM2.EnerVista 650 Setup software allows programming two different Ethernet addresses, but the first IP has always to be set as the second IP Address is an Alias.

ModBus Slave Addresses for serial and Ethernet communication and the ModBus port number used for ModBus TCP/IP

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.Available for standard and IEC61850 models.

TCP Port, Common Addr of ASDU, Cyclic Meter Period and, Synchronization Event settings.Available for standard and IEC61850 models.

4.1.8.2 SYSTEM SETUP

This section shows the settings related to the system setup definition such as shown in the following table.

Table 4–8: GENERAL OVERVIEW OF SYSTEM SETUP MENU:

SYSTEM SETUP

This screen describes and enables the settings of the power system where the relay will operate. Some of these settings will be used only for

General Settings

Flex Curves

Breaker settings

Breaker maintenance

Switchgear Configuration of snapshot events for each switchgear (enable or disable)

metering values presentation purposes; however, some of them apply directly to the sampling and analog-digital conversion process (rated frequency setting). Therefore, these settings need to be adjusted so that they fit the system settings.

Flex Curves – Programmable user curves: The relay incorporates 4 user curves called Flex Curve A, B, C and D. The points for these curves are defined by the user in “Setpoint>System Setup>Flex Curves>Edit Curve” menu in EnerVista 650 Setup. User defined flex curves can be selected as an operation curve in all the time overcurrent functions in the relay.

Breaker settings, maintenance and switchgear selection of the device configured as breaker in the G650. The selected switchgear will be used in recloser, breaker failure and synchronism functions. The settings are

Number of Switchgear, Maximum KI Openings, Max.Openings 1 hour and Snapshot Events.

These settings correspond to the initialization of (KI) counting of number of openings and closings of the switchgear configured as breaker. These Counters allow the breaker Maintenance. They are used to cumulate the breaker ageing produced by a trip or a breaker opening. In order to incorporate the breaker historic, in case of existing breakers, the system allows assigning an initial value to accumulated amperes, and to the number of opening and closing operations.

t, KI2t Integ. Time, Maximum

t counters, and the

Options enabled only in On-line mode are marked as (*). Options enabled only in Off-line mode are marked as (**)

4.1.8.3 PROTECTION ELEMENTS

This option shows all the protection-grouped elements available in the relay as shown in Table 4–9:. Each of these groups includes the specific protection units of the same type. For example phase currents group includes TOC, IOC, directional units, etc. There are three groups available, so there are three protection units of each function that can work in grouped mode or ungrouped (altogether).

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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.

Neutral Current

Ground Current

Sensitive Ground Current

Negative Sequence Current

Voltage Elements

Power All power grouped protection functions.

Options enabled only in On-line mode are marked as (*). Options enabled only in Off-line mode are marked as (**)

All overcurrent grouped functions for neutral current. (Calculated from phases, not measured)

All overcurrent grouped functions for ground current. (Measured from 4 current input)

All overcurrent grouped functions for sensitive ground current. (Measured from 5

All Negative sequence

All voltage grouped functions for phases, neutral, ground and auxiliary voltage

current input)

overcurrent grouped functions.

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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)

NEUTRAL CURRENT

GROUND CURRENT

SENSITIVE GROUND CURRENT

NEGATIVE SEQUENCE CURRENT

VOLTAGE ELEMENTS

POWER

Generator Thermal Model

Neutral TOC Neutral time overcurrent (51N)

Neutral IOC Neutral instantaneous overcurrent (50N)

Neutral Directional Neutral directional unit (67N). Voltage, current and dual polarization.

Ground TOC Ground time overcurrent (51G)

Ground IOC Ground instantaneous overcurrent (50G)

Ground Directional Ground directional unit (67G). Voltage, current and dual polarization. Restricted Gnd Fault Restricted Ground Fault (87G). Enhanced models only.

Sensitive Ground TOC Sensitive ground time overcurrent (51SG)Enhanced models only.

Sensitive Ground IOC

Negative Sequence TOC

Negative Sequence IOC

Generator Unbalance Generator current unbalance (46)

Phase UV Phase undervoltage (27P)

Phase OV Phase overvoltage (59P)

Neutral OV High Neutral overvoltage, high level (59NH) Negative Sequence

OV Auxiliary OV Auxiliary overvoltage (59X)

Auxiliary UV Auxiliary undervoltage (27X)

Volts per Hertz Volts per Hertz (24). Enhanced models only.

Ground OV Ground Overvoltage (59G)

Directional Power Directional power (32), in primary values.

Pwr Factor Limiting Power Factor Limiting (55). Enhanced models only.

Thermal model or Thermal image unit for phases (49S)

Sensitive ground instantaneous overcurrent (50SG). Enhanced models only.

Negative sequence time overcurrent (51-2)

Negative sequence instantaneous overcurrent (50-2)

Negative sequence overvoltage (47). Phase reversal

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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

G650 units incorporate a flexible grouping capability for protection units. This means that protection units can be used in either single setting group (default mode-all units can operate simultaneously) or three setting groups (in this mode, protection units are grouped in three

Setting Group

Underfrequency Underfrequency unit (81U). Grouped element

Overfrequency Overfrequency unit (81O). Grouped element

Synchrocheck Synchronism check unit (25). Not grouped, a single unit provided

Breaker Failure

VT Fuse Failure

Pulse Counters Pulse counters function. 8 counters provided.

Analog Comparators Analog comparator function. 20 analog comparators provided. Frequency rate of

change Loss of Mains Loss of Mains (78V). Grouped element. Enhanced models only.

Loss of Excitation Loss of Field (40). Grouped element Accidental

Energization

independent tables, with only one of them active at a given time). Protection element grouping involves only Protection elements together with broken conductor detection and over and under frequency, which are usually considered as control elements. The rest of control elements such as fuse failure, breaker failure, synchronism, and breaker settings are not involved in the tabled groups concept.

Breaker failure (50BF). Not grouped, a single unit provided. Enhanced models only.

Fuse Failure (VTFF). Not grouped, a single unit provided. Enhanced models only.

Frequency rate of change function (81R).Grouped element.

Inadvertent generator energization (50/27). Grouped element

4.1.8.5 INPUT/OUTPUTS

Section that contains the settings for all input and output boards and the Force Outputs and Virtual inputs activation tools.

Table 4–12: GENERAL OVERVIEW OF “INPUTS/OUTPUTS” SETTINGS MENU.

INPUTS/ OUTPUTS

Contact I/O

Force Outputs (*)

Virtual Inputs (*)

Options enabled only in On-line mode are marked as (*). Options enabled only in Off-line mode are marked as (**)

Inputs and outputs settings for all boards in G650. The I/O settings configuration can only be performed through EnerVista 650 Setup, not HMI available.

This menu allows activating each contact output in the relay, to facilitate maintenance testing. On line mode only.

This menu allows operating virtual inputs. These variables are used as inputs to logic schemes configured in the relay. Virtual inputs can be operated in a latched mode (32 latched virtual inputs) or in Self-reset mode (32 self reset virtual inputs).

This section shows the settings related to inputs and outputs for the different boards available in G650 (F, G, H, J).

Table 4–13: GENERAL OVERVIEW OF “INPUTS/OUTPUTS>CONTACT I/O” SETTINGS MENU.

CONTACT I/O

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4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES

Board F Board located in first slot, always connected.

Board G

Board H Board located in first slot of CIO Module (external inputs/outputs module)

Board J

Board located in second slot, depends on model definition. If model is type G0 there is no board in second slot.

Board located in second slot of CIO Module (external inputs/outputs module)

4.1.8.6 RELAY CONFIGURATION

This is the relay configuration section in which the relay can be configured using internal states or already compiled equation on PLC Editor.

Table 4–14: GENERAL OVERVIEW OF RELAY CONFIGURATION MENU:

RELAY CONFIG

Outputs Configuration of contact output operate and reset signals for all boards.

LEDs

Operations

Protection Elements

Oscillography

Control Events

Switchgear

Inputs

Virtual Inputs

MMI (HMI-Human Machine Interface)

15 LEDs fully configurable from any logical variable, contact or virtual input. First 5

can be latched through PLC configuration. From the LED configuration screen, it is possible to print the vertical LED label for the relay.

Configurable operations up to 24. Operation texts, interlocks, final states, frontal keys, time outs and masters.

This tab allows assigning operands (logic signals) as inputs to different protection elements. To block, reset, initiate the different protection elements inputs.

Trigger and up to 16 digital channels to be included in oscillography records, are programmable from any logical variable, contact or virtual input. Text configuration is only for off-line mode. NOTE: This screen is used for the configuration of digital channels and oscillography trigger. The rest of parameters, such as function enabling/ disabling, sampling rate, number of oscillography files, etc. must be set on the Setpoint>Product Setup>Oscillography menu.

Up to 128 user programmable events from any logical variable, contact or virtual input. Possibility to display the event as an alarm on the alarms panel. Control events are also displayed in the snapshot events recording. 1 ms time tagging. A control event is a logic signal associated to an operand or combination of operands, that allows following the status of that signal.

Up to 16 configurable switchgear elements. A switchgear element can be a breaker, a line selector switch, a grounding selector switch, a busbar selector switch, etc. This screen allows configuration of type of contacts, opening and closing time, contact assignation and text for events related to switchgear. There are 64 pre-established events for switchgear, which correspond to opening, closing, Error01 and Error11 of the 16 programmable switchgear elements.

Text configuration for off-line mode file management for all the contact inputs available in device.

Text configuration for off-line mode file management. 32 latched and 32 self reset virtual inputs.

Screen for one line diagram configuration. 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. See an example in

LEDs are latched by hardware, the rest are self-reset but

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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

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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

libraries included in the project (*.lib), graphic file name (*.aut), etc.

*.aut: PLC Project file containing all the drawings used by the logic, required by 650 relay based on IEC 61131-3

standard. Functional block diagram (FDB).

*.lib: User programmable logic objects: Library file to be included as an object in a PLC project. Logic packages that

can be stored into libraries and be distributed in different PLC projects.

4.1.8.8 CLOCK

This menu allows to update the date and time of the relay, either synchronizing them with the PC clock, or entering the information manually.

Figure 4–11: CLOCK

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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. This section shows only the structure of menus in EnerVista 650 Setup.

Table 4–15: GENERAL OVERVIEW OF ACTUAL VALUES MAIN MENU:

ACTUAL

Front Panel The relay front LEDs status is shown on this menu.

Status

Metering

Inputs/Outputs

Records

Protection and control status signals for all available protection functions in device.

All metering values available in device. Primary and secondary values, frequency and phasor diagram provided.

All input and output status provided. For contact inputs and contact outputs as well as virtual input and virtual output signals.

Only enabled in on line mode, retrieval of all the available records in device. Snapshot events, control events, oscillography and fault reports.

4.1.9.1 FRONT PANEL

The front panel menu shows only the LEDs submenu where all the front LEDs can be monitored.

4.1.9.2 STATUS

The following menu includes all the available protection status in the device.

Table 4–16: GENERAL OVERVIEW OF STATUS MENU:

STATUS

Operation bits

Breaker

Protection Status of all the protection units in the device.

Control Elements Status of all the control units available in the device.

Protection Summary

Snapshots events summary

ModBus User Map

Switchgear Status

Calibration

Flex Curves

System Info

Records Status

SNTP-IRIG-B Information related to synchronization via IRIG_B or SNTP

Up to 24 elements. OPERATION BIT XX is (0) when the configured time out for the operation XX expires or when success conditions are met. And it is (1) if operation XX is executed and interlocks are fulfilled.

Breaker status (open, closed or undefined). The rest of the status signals corresponding to the switchgear XX configured as breaker are in the “Status>Switchgear Status>Switchgear XX” menu.

This screen shows a complete list of all protection and control elements in the relay, showing their status (enabled or not).

Summary of the snapshot events status (enabled or disabled) for protection, control, inputs and outputs boards and switchgear.

Up to 256 elements. Value in SIGNED INT 16 BIT format of the reading for the selected address configured in “Setpoint>Product Setup>ModBus User Map”

Up to 16 blocks of switchgear status signals for the 16 configurable devices. Status signals such as inputs for A and B contacts, status for A and B, open and close status, error 00 and error 11, open init and close init, fail to open and fail to close signals.

Internal states for calibration. Factory calibration and calibration error signals.

Flex curve status for A, B, C and D user curves. (0) if it is not configured, (1) if it is configured. To configure a flex curve go to “Setpoint>System Setup>Flex Curves” menu.

This screen can monitor the system parameters and the internal status of the Relay operative system. Not enabled by default, password required

Information related to the different records stored in the Relay, such as: Fault reports, control events, oscillography, data logger, demand, energy, and breaker maintenance.

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4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES

T able 4–17: ACTUAL VALUES INCLUDED IN THE PROTECTION MENU

PROTECTION

Protection Blocks This screen shows all the protection element blocks available. Protection

Phase Current Protection status signals (pickups and operations) for time overcurrent,

Neutral Current Protection status signals (pickups and operations) for time overcurrent,

Ground Current Protection status signals (pickups and operations) for time overcurrent,

Sensitive Ground Current

Negative Sequence Current

Voltage Protection status signals (pickups and operations) for all voltage

Power Protection status signals (pickups and operations) for all power units .

elements block signals can be configured at “Setpoint>Relay Configuration > Protection Elements”.

instantaneous overcurrent and directional protection functions for phase current.

instantaneous overcurrent and directional protection functions for neutral current (calculated from phases).

instantaneous overcurrent and directional protection functions for ground current (measured from 4

Protection status signals (pickups and operations) for time overcurrent, instantaneous overcurrent, isolated and directional protection functions

for ground current (measured from 5 Protection status signals (pickups and operations) for negative sequence

time overcurrent function.

functions, undervoltage, overvoltage, neutral overvoltage, negative sequence overvoltage and auxiliary under and over voltage, Volts/Hz and ground overvoltage.

current input).

Table 4–18: DIFFERENT CONTROL ACTUAL VALUES INCLUDED IN THE CONTROL ELEMENTS MENU

CONTROL ELEMENTS

Frequency Status signals (pickups and operations) for under, overfrequency and

Synchrocheck Status signals for synchrocheck function (25).

Breaker Failure Status signals for breaker failure function (50BF). Enhanced models only.

VT Fuse Failure Fuse failure detection signal. Enhanced models only.

Setting Groups Status signals (activations and blocks) for the relay setting group change.

Pulse Counters Status signals for pulse counters units.

Analog Comparator Status signals for analog comparator units.

Loss of Mains

Loss of excitation Status signals (pickups and operations) for loss of excitation (40).

Accidental Energization

frequency rate of change units.

By default the “setting group” setting is disabled and all the grouped elements can be enabled at the same time.

Status signals (operations) for loss of mains (78V). only.

Status signals (off-line, armed and operation) for inadvertent generator energization (50/27).

Enhanced models

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4 HUMAN INTERFACES. SETTINGS & ACTUAL VALUES 4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE

T able 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,

Control Events Status of the control events (if the signal configured to launch the control

Oscillography Status of signals related to oscillography recording, such as status or

Data Logger Data logger information about oldest and newest sample time stamp,

Demand Demand trigger and reset inputs status.

Energy Freeze, unfreeze and reset input signals for energy counters.

Breaker Maintenance All signals related to breaker maintenance, such as number of openings,

fault date, fault type and location, besides the fault report number.

event is active or not).

digital channels, oscillography trigger, number of records available, etc.

and number of channels and days configured in data logger settings.

closings, (KI)

t counters, alarm signal for (KI)2t, etc.

4.1.9.3 METERING

The Metering menu includes all the measurements available in the device. Primary and secondary values, and also the data related to the recording functions in the relay.

Table 4–20: GENERAL OVERVIEW OF METERING MENU:

METERING

Primary Values Primary values measurements for currents, voltages, power, energy and

Secondary Values Secondary values measurements for currents, voltages and power.

Phasor Diagram Current, voltage and sequence components.

Frequency Line and Bus frequencies.

demand

4.1.9.4 INPUTS/OUTPUTS

The Inputs/Outputs menu includes all the inputs and outputs signals available in the device. Contact and virtual type.

Table 4–21: GENERAL OVERVIEW OF INPUTS/OUTPUTS MENU:

INPUTS/ OUTPUTS

Contact Inputs Status of digital inputs in the Relay for each board according to the relay

Contact Output Status Status of digital outputs in the Relay for each board according to the relay

Contact Outputs Operates

Contact Outputs Resets

IO Board Status Status of I/O boards. This status provides if the hardware it is OK (boards

Virtual Inputs Status of Virtual inputs latched (32) and self-reset (32).

Virtual Outputs Status of virtual outputs (configured in PLC Editor). Up to 512.

Analog Inputs Measurements coming from analog inputs (DCMA)

Options enabled only in On-line mode are marked as (*). Options enabled only in Off-line mode are marked as (**)

model.

model. Status (activated or not) of the variables used to operate a contact

output. To configure these signals go to “Setpoint>Relay Configuration>Outputs” menu.

Status (activated or not) of the variables used to reset a contact output. To configure these signals go to “Setpoint>Relay Configuration>Outputs” menu. This output reset Command will only be effective if the “latch” option has been Selected for the “Output Type” setting on the I/O board, thus when the contact output has been configured to emulate function 86 (latching relay).

matching relay model, correctly inserted in their tracks, in good state and communicating through the internal CAN Bus).

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